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Home My WebLink About212-049Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025010 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 211-26 50283201280000 208112 1/27/2025 AK E-LINE PPROF T40287 END 1-41 50029217130000 187032 3/13/2025 HALLIBURTON MFC40 T40288 END 2-14 50029216390000 186149 3/12/2025 HALLIBURTON MFC40 T40289 END 3-33A 50029216680100 203215 3/23/2025 HALLIBURTON COILFLAG T40290 GP AN-17A 50733203110100 213049 12/29/2024 AK E-LINE Perf T40291 KALOTSA 3 50133206610000 217028 3/3/2025 AK E-LINE PPROF T40292 KU 12-17 50133205770000 208089 1/28/2025 AK E-LINE Perf T40293 MPI 2-14 50029216390000 186149 2/17/2025 AK E-LINE Plug/Cement T40294 NCIU A-21 50883201990000 224086 3/28/2025 AK E-LINE Plug-Perf T40295 ODSN-25 50703206560000 212030 3/7/2025 HALLIBURTON CORRELATION T40296 PBU 02-08B 50029201550200 198095 3/17/2025 HALLIBURTON RBT T40297 PBU D-08B 50029203720200 225007 3/22/2025 HALLIBURTON RBT T40298 PBU J-25B 50029217410200 224134 3/10/2025 HALLIBURTON RBT T40299 PBU K-12D 50029217590400 224099 3/18/2025 HALLIBURTON RBT T40300 PBU K-19B 50029225310200 215182 3/27/2025 HALLIBURTON RBT T40301 PBU L1-15A 50029219950100 203120 3/27/2025 HALLIBURTON PPROF T40302 PBU M-207 50029238070000 224141 3/18/2025 HALLIBURTON IPROF T40303 PBU P1-04 50029223660000 193063 3/28/2025 HALLIBURTON PPROF T40304 PBU W-220A 50029234320100 224161 3/11/2025 HALLIBURTON RBT T40305 Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40291GP AN-17A 50733203110100 213049 12/29/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 13:48:56 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Eric Dickerman Subject:20250410 1407 APPROVAL - : PTD 213-049, Sundry 324-720, Granite Pt St 18742 - Add eline contingency step Date:Thursday, April 10, 2025 2:10:08 PM Attachments:EXTERNAL RE PTD (213-049) Granite Point State 18742 17A (Anna-17A) Sundry #324-720.msg Standard Well Procedure - Nitrogen Operations.pdf Eric, Hilcorp’s contingency (in red below) is approved for Sundry 324-720. Please assure well site has a copy of the Standard Well Procedure for Nitrogen operations (attachment) on location to assure safety in Nitrogen operations. In the future, please include contingency descriptions of this type in the sundry request. 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: Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent: Thursday, April 10, 2025 1:18 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PTD 213-049, Sundry 324-720, Granite Pt St 18742 - Add eline contingency step Mel, As discussed on the phone, regarding Sundry 324-720 for eline to add perforations on Granite Pt St 18742, the sundry procedure does not specifically call out the contingency for setting a bridge plug within the target perf interval if any zone makes unwanted solids or water after perforating. Hilcorp is requesting approval to add the contingency section below (in red text) to have the ability to isolate an unwanted interval as needed. Please note that 28ft of cement was dump bailed on top of the CIBP at 6,800’ on 2/8/25 as per the conditions of approval. Wellwork Plan is: E-Line Perf Procedure: (from sundry 324-720) 1. MIRU E-line and pressure control equipment. 2. PT lubricator to 250 psi low / 3,000 psi high. 3. GPT to confirm fluid level is acceptable (added per conditions of approval). 4. RIH and perforate Gas Sands from ±4,090’ – 5,250’ md (±4,010’ – 5,114’ tvd). 5. RDMO EL. CONTINGENCY Eline plug: (if any zone makes unwanted solids or water) 1. RU nitrogen to tubing and pressure test lines to 3,000 psi (or higher if needed). 2. Pressure up on tubing to displace water back into formation. 3. MIRU Eline and pressure control equipment. 4. Pressure test lubricator to 250 psi low / 3,000 psi high. 5. Set CIBP for water/solids shut off per OE. 6. RDMO Nitrogen and Eline. Thank you, Eric Dickerman Hilcorp – CIO Ops Engineer Cell: 307-250-4013 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 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Monday, February 10, 2025 12:40 PM To:Eric Dickerman Subject:[EXTERNAL] RE: PTD (213-049), Granite Point State 18742 17A (Anna-17A), Sundry # 324-720 Eric, Hilcorp has approval to proceed with the plan below and then perforate assuming the results indicate that the plug is not leaking. Please send me the results of the GPT log and a plot of the tubing pressure over the course of the negative pressure test, as soon as they become available. It the GPT log indicates a fluid level above the cement, obtain approval from AOGCC before perforating. Otherwise, perforations can proceed according to sundry 324-720. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent: Monday, February 10, 2025 12:11 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: PTD (213-049), Granite Point State 18742 17A (Anna-17A), Sundry #324-720 Bryan, Per our discussion regarding Granite Point State 18742 17A (Anna-17A). Hilcorp will run a GPT looking for fluid level rise on the well before perforating. If a fluid level is seen, we will review with you prior to perforating. Recent notes:  The reservoir pressure below the CIBP at 6,800’ is estimated at 2,898 psi at 6,634’ tvd. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2  12/29/24: The well was stacked out with Nitrogen prior to setting the CIBP at 6,800’. A GPT logged the fluid level at 6,990’ prior to setting CIBP.  2/8/25: the tubing pressure was bleed oƯ to 500 psi to drawdown on the CIBP, and 27.9 gallons (28 ft) of cement was dumped on top of the CIBP at 6,800’. The plug was tested with 2,400 psi drawdown.  Prior to perforating the tubing well be re-pressurized with N2 to prevent excessive underbalance. Thank you, Eric Dickerman Hilcorp – CIO Ops Engineer Cell: 307-250-4013 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. STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 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: ESP Changeout_ 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 21,097 feet N/A feet true vertical 3,796 feet N/A feet Effective Depth measured 21,100 feet N/A feet true vertical 3,796 feet N/A feet Perforation depth Measured depth 11600-21,097 feet True Vertical depth 3,833-3,796 feet Tubing (size, grade, measured and true vertical depth)4.5 L-80 10,250' 3,677' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 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: Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 Stefano Pierfekici Well Operations Project manager Eni US Operating Co. Inc. WINJ WAG 53 Water-Bbl MD 160 3274 2973 Oil-Bbl measured true vertical Packer 3700 Centerpoint Dr. Ste. 500, Anchorage, AK, 99503 3. Address: 4. Well Class Before Work: 912 Representative Daily Average Production or Injection Data 1443310 Casing Pressure Tubing Pressure ADL 0391283, 0388583, 0388574, 0388571, 0388572 124 0 SP16-FN3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 212-049 50-629-23467-00-00 N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 553 Gas-Mcf measuredPlugs Junk measured 5. Permit to Drill Number: 45 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-299 154 Size Nikaitchuq Schrader Bluff Oil Pool Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: Liner Length 160 3274 11600 9497 Casing Structural 20" 13.375" 9.625" 5.5" 11600 21097 TVD 160 2440 3883 3796 slotted Burst 5210 6890 2. Operator Name Senior Engineer:Senior Res. Engineer: slotted Collapse 2480 4790 t Fra O 6. A G L PG , R _ Form 10-404 Revised 3/2020 Submit Within 30 days of Operations 07/14/2021 By Samantha Carlisle at 10:27 am, Jul 14, 2021 Digitally signed by: Stefano PierfeliciDN: CN = Stefano Pierfelici C = ADDate: 2021.07.14 09:08:21 -08'00' Stefano Pierfelic i SFD 7/16/2021 21,097 21,100 SFD SFD DSR-7/14/21 RBDMS HEW 7/14/2021 VTL 8/9/21 Surf. Casing13-3/8", 68 #3,274' MD, 2,440' TVD67º Inc.Interm. Casing9-5/8", 40# 11,600' MD, '3,833'TVD84º Inc.4-½” 12.6 ppf TK-15 InternalCoated Production TubingSlotted Liner,5-½” 15.5 ppf21,097' MD, 3,796' TVD89º Inc.4-½” x-cplg cable clamps, for ESPPower Cable, (1) 3/8" Chem Inj LineSP16-FN3Dual Lateral Producer withESP LiftNikaitchuq Field–Spy IslandAs CompletedJune 26, 202110,256' MD/ 3677' TVD ,Discharge Gauge Sub10,336' MD, 3,690' TVD,81º Inc–Conventional ESP: 400 HP Motor, 75 stages Flex 80 + 20Stage GINPSHH SXD and 538 GSVHV gas separatorItemMD (ft)Resman tracer Sub #1 - ROS 377 / RWS 41112988Resmantracer Sub #2 - ROS 378 / RWS 412 14345Resman tracer Sub #3 - ROS 379 / RWS 41315876Resman tracer Sub #4 - ROS 380 / RWS 41417272Resman tracer Sub #5 - ROS 381 / RWS 41519650ItemMD (ft)5-1/2" Swell Pkr #1129415-1/2" Swell Pkr #2142985-1/2" Swell Pkr #3158285-1/2" Swell Pkr #4172255-1/2" Swell Pkr #519602TD 21,100' MD,3,796' TVD11,237-11,254 MD, 3800’- 3802’ TVD,Casing Exit WindowSlotted Liner,5-½” 15.5 ppf21,020' MD, 3,795'TVD 90º Inc.TD +/- 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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: _ESP Change-out____ 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): Schrader Bluff Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 21097 1204 N/A Casing Collapse Structural Conductor Surface 2480 Intermediate 4790 Production Liner slotted 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 Well Operations Project manager 6/16/2021 SP16-FN3 N/A Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 COMMISSION USE ONLY Authorized Name: slotted Tubing Grade:Tubing MD (ft): 3,833-3,796 N/A Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0391283, 0388583, 0388574, 0388571, 0388572 Nikaitchuq 212-049 3700 Centerpoint Drive, Ste. 500, Anchorage, AK 99503 50-629-23467-00-00 Eni US Operating Co. Inc. Length Size 3796 21097 3796 N/A L80 TVD Burst 10,300 MD 6890 5210 160 2440 3883 160 3274 20" 13.375" 160 9.625"11600 3274 Perforation Depth MD (ft): 11600 11600-21,097 5.5" Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 6/21/2021 210979497 4.5" 3796 N/A Stefano Pierfelici 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 5:52 pm, Jun 16, 2021 321-299 Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.06.16 14:31:21 -08'00' Stefano Pierfelic i VTL 6/18/21 X BOP test to 3500 psig Annular preventer test to 2500 psig X SFD 6/18/2021 DSR-6/17/21 10-404 dts 6/18/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.18 15:41:55 -08'00' RBDMS HEW 6/21/2021 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3322 Email: stefano.pierfelici@eni.com June 16, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SP16-FN3 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP16-FN3. SP16-FN3 was completed on Spy Island on June 12, 2012 with an electric submersible pump set at a depth of 10,314’ MD. This ESP producer was completed without a packer. The well was started up for production in June 2012. In April 2017, a workover was performed to swap TTC-ESP to a conventional ESP. In May 2021, a second lateral was added and well was put on production in June 2021, on June 11 an electrical failure occurred and well is shut in. The estimated date for beginning this work is June 21, 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: 2021.06.16 14:34:35 -08'00' Stefano Pierfelic i p,p In May 2021, a second lateral was added and well was putpy, on production in June 2021, on June 11 an electrical failure occurred and well is shut in. The estimated date for beginning this work is June 21, 2021. RECEIVED STATE OF ALASKA • AlilkA OIL AND GAS CONSERVATION COM ION APR 2 7 2017 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon [J Plug Perforations LI Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ESP change outE 2.Operator Eni US Operating Co.Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development Q Exploratory ❑ 212-049 3.Address: 3800 Centerpoint Dr.Ste 300,Anchorage,AK, Stratigraphic ❑ Service ❑ 6.API Number: 99503 50--629-23467-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: 391283,388583,388574,388572,388671 SP16-FN3 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Schrader Bluff Oil Pool 11. Present Well Condition Summary: Total Depth measured 21,100 feet Plugs measured N/A feet true vertical 3,796 feet Junk measured N/A feet Effective Depth measured 21,097 feet Packer measured N/A feet true vertical 3,796 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 160 160 160 Surface 3274 13.375" 3274 2440 5210 2480 Intermediate 11600 9.625" 11600 3883 6890 4790 Production Liner 9706 5.5" 21097 3796 Slotted Slotted Perforation depth Measured depth 11,600-21,097 feet swim MAY 1 72017 True Vertical depth 3,833-3,796 feet Tubing(size,grade,measured and true vertical depth) 4.5 L-80 10,245 3,665 Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 633 46.9 1357 -15 263 Subsequent to operation: 858.5 52.4 1227 -15 261 14.Attachments(required per 20 PAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations E Exploratory ❑ Development['.] Service ❑ Stratigraphic Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-037 Authorized Name: Marc Kuck Contact Name: Amjad Chaudhry Authorized Title: Drilling&Completion Engineering Manager Contact Email: amiad chauchry(dienioetroleum corn Authorized Signature: j/7/ Date: "..d?' Contact Phone: 907-865-3379 S i p r 7 7y'/7 Form 10-404 Revised 4/2017 RBDMS V� MAY - 3 2G I/ 0 R I 0 I N A L Submit Original O ly "A 37;//(7 • • a C) > 0 C) > . W SC L SC N 2 U) C Q.N U E N m O -� M C M M Z G, (� N c a) 7-Lr) O (6'„ W V J Q. , . U) C l �L✓, I 0. O W (,)^ � � pppp acv ��-'_ U) CL N C) m O1 M W N (I $ N cr V1 ^ 01 a ' ' R0� .-I r1 Ct•= M== ^L, G — Vii l L fl- vi I (I) _O E T13 , L X 2I` M E J =w U r+ N m Cr U, N O m _c a a c v e v U) U d LC) II v� Cn 'n M 4 ( E m 0 D x 3 3 3 3 O C J J z z s CC CC X a) LL Cr) 03 U) < „ w Ca [n N g3 E m m m m m 4 In 0 I u) (a COQJ e�.I I `: — 0 0 0 0 0 Y a) 2 _ 0 m , CD g ' n- a L. o CO > 00 r^ - 1/) ` :.. . ,�. .0 a .n .0 .a CD ' CD (L) p a) 0 -• 6, a) `I I I_ CU CU C O (B co LO i ,L° 4- +L° � Y (n J N U) �. V1 C7 i m m m m U W e O .- > (Y, l o u) -• p 1 O 5 ---� E E E E E o °° > H °' E ai p C � LI L , :n co cn N c o in M 0 CO •• 4- .. c6 a or) X o a� - E H • a o _ C c) LULo > E U ao U) N W N S U) �i Q O a) L i_j (� 00 C .`'' �, > � UCO C..0 (/) N " C- — ICO O I- I I6j„ C'O C C C H 0 — co E C U) O N U c O D O O c0 U) Q Lo O O O CO O = a) N CO > U 2 C O H CO Q O V r— C) C� r— r- .C 03 CO f C • a) co a) ' n c� co ' Q CO �— O O E O CO co • CN 3 C- o U d •t cY, co Tv 2 o x a) 0 c co- ...., c) O =N 3 0 3 .. Co C � Lo rn � Z , N ' � iik*:," ' .-i Co CO Lft NN NNy � N ONO o .1 .e-1 e-4 1-1 r-i / H (6 T C .-i N M 41 V1 Cl lib 2k 3k �k U 3k U) c O 'r o i L L L L L �j N o a a a a ar. C' 44 Tli CO c;) c N N N N N Q z N N N N N (N v-.4e`i - .�4 ,-4 CO_ V) III Vi LA, Y Z Well Name: SP16-ISR • Daily Report Wellbore Name: SP16-FN3 Date: 3/26/2017 • Well Code: 26438 Report#: 1 en it Job: WORKOVER Page:1 of 1 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co-Inc. DE VT)OMEN T WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RK8-Base Flange(ft) RKB-Tubing Spool(ft) 53 92 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature("F) Wind Days LTI(days) Days RI(days) POB Panty Cloudy -3.2 SW @ 17 MPH WC-19" 63.0 Daily Summary Operations 24h Forecast 9/U over well SP16 and check well pressures.If well is dead,Vetco will install BPV.N/D Free arid NIU BOPE and lest as per AOGCC specs Witness waived by Jeff Jones 24h Summary Prep ng for move.set matiing boards.move sub and pits over SP16-FN3.Skid floor.begin berming ng and hooking up interconnect lines Operation at 07.00 Rigging up over SP16-FN3 Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Opor.Descr. 1200 14:00 2.00 2.00 PREP A1 P PJSM,Prep for rig move.blow down steam.disconnect electrical lines and interconnects,remove rig berming.set rig mats 14 00 16:30 2.50 4.50 PREP A1 P Set herculite and matting boards. 16.30 17:30 - 1.00 5.50 PREP A 2 P PJSM,move pits and sub off well SP28-NW3. 17.30 20:00 2.50 8.00 PREP A 2 P Move sub over well SP16-FN3. 20:00 22:00 2.00 10.00 PREP A 2 P Spot pita on to sub. 22:00 23:00 1.00 11.00 PREP A 2P PJSM,Skid rig floor Simops berming rig. 23:00 00:00 1.00 12.00 PREP A 20P Cont berming rig.hook up electrical.water,steam.air and interconnects. Protected handover date to production 4/4/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Sup,/ 507-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilhng@enipetroleurn cam 907-685-0715 907-320-0058 Em representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipelroleum.com 907-685-0722 Eni representative Troy England ENI HSE Tool Push Justin Hays Doyon Drilling Tool Push Tool Push Dave Sena Doyon Drilling Tour Pusher Tool Push Sam Dye Doyon Drilling Superintendent Last Casing Seat Cas.Type OD(in) ID(In) Grade Top(ftKB) Bottom 1@K8) TVD Bot.(tt(B) Run Date LINER 5 1/2 4 95 L80 2.019 0 21.097.0 3,796.2 6/6/2012 Well Name: SP16-ISR • Daily Report Wellbore Name: SP16-FN3 Well Code: 26438 Ret ort#' 2 3/27/2017 e) no Job: WORKOVER Rep 21I II� Page:1 of 1 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation Ift) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RK8-Tubing Spool(ft) 53 92 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature("F) Wind Days LTI(days) Days RI(days) POB Partly Cloudy -6 1 NNE a 30 MPH WC-26' 64 0 Daily Summary Operations 24h Forecast RU to pull 4.5"ESP completion slang,RU GBR&BCL.MU landing joint,pull hanger&disconnect penetrator.POOH laying down completion 24h Summary Berm around rig,hookup interconnect lines,install stairs and landings.spot cuttings box,hook up electrical to plain powerbleed down tubing install SPV,NO tree.N/U BOP's Test BOP',R/D test equipment Operation at 07.00 Installing elephant trunk Time Log Start End Cum Dur Time Time Our(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03'00 3.00 3.00 PREP A 1 P Cont.berming around rig,cont.hook up hi psi mud line interconnects.RU support braces ODS,flow line,steam water&air. 0300 08:00 3.00 8.00 PREP A 1 P Work on well acceptance checklist,get steam circulating,set&berm cuttings tank,install landings below exterior doors, update well sign,RU beaver slide,insulate between rig&well bay 06.00 09:00 3.00 9.00 PREP A 1 P Set&berm tiger tank,raise floor skid support braces in pipe shed,plug in electrical interconnects&swap power to main generators,function test top drive,hook up shop to rig power.remove completion tools Volpe shed 09.00 10:00 1,00 10.00 PREP A 20 P RU bleed tank,bleed tubing to 0 psi,shut in monitor f/5min-no build up,install BPV.RD bleed tank. 10.00 12:00 2.00 12.00 PREP C 0 P ND tree.terminate cap tube,install blanking plug,NU riser,set GOP's,MU choke line&kill line.NU ROPE,simops-spot GBR power unit,grease choke manifold,offload 9.9 ppg brine to pits 12.00 15:30 3.50 15.50 PREP C 5 P PJSM,cont N/U GOP's,simops R/U test equipment. /5 30 16:00 0.50 16.00 PREP M 1 P R/U install test jnt per Vetco rep.cont R/U test equipment. 1600 17.30 1.50 17.50 PREP C 12 P ,PJSM,flush MP,flood stack&choke Ihru kill line W/charge pump,perform body test on BOPE&choke manifold. 17.30 22.00 4.50 22.00 PREP C 12 P PJSM,Test BOPE,Test all choke valves 1-14 to 250 13500 psi,test annular to 250/3500 psi WI 4.5"test jnt,test upper& lower pipe rams W/4.5"test jnt 250/3500 psi,&blind rams to 250/3500 psi,test TT525 dart&FOSV,man.kill and choke, HCR kill and choke,kill line demco,upper and lower IBOP's to 250/3500 psi,test man and super choke to 1500 psi.Koomey test,system pressure=2995 psi,after close=1500 psi,200 psi attained=47 sec.,full pressure attained=211 sec.,5 bottle average=2350 psi,AOGCC Jeff Jones waived witness to BOP test. 22.00 23.00 1.00 23.00 PREP C 5 P R/D les/equipment,back out test dart,LID test jnt,BID choke&kill lines. 23.00 23:30 0.50 23.50 PREP M 1 P Check well for pressure,pull BPV,fill hole W/12 bbls 9.9 brine with no returns. 23.30 00,00 0.50' 2400 PREP L 1 P PJSM,HRWS,R/U elephant trunk. Total losses to hole today 12 bbls. Projected handover to production 4/4/2017 Daily Contacts Position Contact Name Company Title Email • Office Mobile Eni representative Bruce Simonson "ENI Drilling Sups +907-685-0715 Eni representative Russ Wimmer ENI Drilling Sup,/. SIDDrilling@enipelroleum coin 907-685-0715 907-320.0058 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyonl 5@enipetroleum cow 907-685-0722 Em representative Troy England ENI HSE Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15(gdoyondrilling.corn 907-685-0716 Tool Push Dave Sena Doyon Drilling Tour Pusher Last Casing Seat Can.Typo OD(in) ID(In) Grade Top(ft1(8) Bottom(ftKB) TVD Bot.MKS) Run Date LINER 51/2 4.95 L80 2,019.0 21,0970 3,796.2 6/8/2012 Well Name: SP16-ISR • Daily Report Wellbore Name: SP16-FN3 Well Code: 26438 Ret ort#: 3 3/28/2017 enll Job: WORKOVER 'I II Page:1 of 1 Well Header PermiUConcession N' Operator Subsidiary Initial Lahee Code ALASKA ENI PE TROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange Ittl RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53 92 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature(`F) Wind Days LTI(days) Days RI(days) FOB Partly L.lourly 9 5 SSE`,6 MPH WC-22 70.0 Daily Summary Operations 24h Forecast Make up 880 bbls of 10.5 ppg bone and Bullhead 160 bions down tubing and 650 bbls down IA Monitor well for 30 ruin Unseat hanger and terminate at surface Continue to POOH and L/D 4 5'tubing and ESP completion. 24h Summary R/U to pull 4.5"ESP completion and well was not dead.Pump 150 bbls of 9.9 ppg down tubing and 500 bbls do IA.WO kill weight brine to be made Operation at 07.00 Pumping 650 bbls 10.5 ppg bone do IA Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4,00 4.00 PREP 'L X20 P PJSM Feed ropes through sheaves.R/U elephant trunk and dram hose. Problems with high winds.Clear and clean rig floor. 04:00 08:30 2.50 9.50 PREP .L 20 P PJSM R/U G6R tongs and bring thread protectors to floor.Circulate brine through mud line and lest to 3000 psi. 08:30 0730 1,00 7.50 PREP '17. 20 P PJSM P/U and M/U landing jt,BOLDS and open IA valve prior to unseating hanger.IA was leaking ml and was closed for further well killing operations(4 psi).Run in lock down screws and R/U to kill well, 07.30 08.30 1,00 8.50 PREP .L 20 P PJSM R/U IA on secondary kill.cement line to tubing. 08:30 10:30 2.00 10.50 PREP L 9 P PJSM Bullhead 150 bbls of 9.9 ppg down tubing©3 bpm/1300 psi/2500 psi then.5 bpm/3000 psi/2800 psi.Bleed of tubing pressure,R/D&B/D cement line. 1030 1200 1.50 12 00 PREP 'I. 9 P PJSM Bullhead 500 bbls of 9,9 ppg brine down IA a 8 bpm/1300 psi.Sim Ops;Remove stabbing board camera,replace winch line cable in BOP deck,install mousehole 650 bbls sourly fluid losses. 12.00 14:30 2.50 id 50 PREP L 11 TP03 PJSM Monitor well;IA TBG 80 70 13 3 Open up well and both on vac.Shut in and monitor. 1430 23.30 9.00 23.50 PREP 'L 11 TP03 PJSM Monitor well IA,3.8,1.2 psi;Tbg, 9,4.8 psi.WO kill weight brine. 23.30 00.00 0.50 24.00 PREP 'L 20 TP03 PJSM bring on 11.4 ppg brine to pits to mix w/9.9 ppg for 10.5 ppg kill brine.3.3 psi IA,13 psi Tbg. Total losses for the day 850 bbls, Projected handover to production 4/4/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson .ENI Drilling Supv. 1)07-080-0715 Eni representative Russ Wimmer ENI Drilling Supv SIDDrilling@enipetroleum.com 907-680-0710 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon1587penipelroleum com 9(77-685-0722 Eni representative Troy England ENI HSE Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15l doyondrilling.com 907-885.071(7 Tool Push Dave Sena Doyon Drilling Tour Pusher Last Casing Seat Cas.Type OD(in) ID(In) Grade Top(RKB) Bottom(ftKB) TV()Bot.(ftKB) Run Date LINER 51/2 490 180 2,019.0 21,097.0 3,798.2,6/9/2012 Well Name: SP16-00R • Daily Report Wellbore Name: SP16-FN3 Well Code: 26438• Ret ort#:94 017 enfl Job: WORKOVER Page:1 of 1 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 5392 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature("F) Wind Days LTI(days) Days RI(days) POB Partly Cloudy -9 2 SW©12 MPH WC-28 66.0 Daily Summary Operations 24h Forecast POOH WI ESP completion stony perlormory hole 511 displacement procedures LID ESP assembly and shroud,Rh/to RIH.pull ESP cable&Cap lines thru sheaves,M/U shroud.P/U Motor assembly and till W/oil install ESP cable and cap tube. 24h Summary Take on bone to pits.bullhead tubing&IA volumes w/10.5 ppg brine,monitor well,observed psi&flow al tubing,pump tubing volume w/10.5 ppg brine,monitor well.bleed off.no psi no flow.BOLOS unseat hanger&pull to ng floor.L/D hanger and landing int,string cable and cap tube through sheaves.POOH l0 7.730'MD,performing hole 511 procedures and tubing flush. Operation at 07.00 POOH W/4.5"ESP Completion @ 6,130'MD Time Log Start End Cum Our Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Dascr. 00:00 01:30 1.50 1.50 PREP M 8 U Cont.to take on 11.4 ppg brine,blend wl9.9 to make 10.5 ppg. 01 30 0590 3.50 5.00 PREP M 9 U Bullhead 180 bbl 10.5 ppg brine down tubing( 1BPM 2800 psi.RD BD circ line.Bullhead 650 bbl 10.5 ppg brine down IA(r)8 bpm 1340 psi. 05:00 10:30 5.50 10.50 PREP M 1 U BD lines,monitor well f/30 min.Initial psi after pumps off IA on vac,tubing 15.after 30 min tubing 15,IA on vac.bleed offto 0.. shut In f/30 min tubing 5 psi IA on vac,bleed off&shut in,psi built to 7psi on tubing with flow to bleed tank,IA on vac. 10:30 13,00 2.50 13.00 PREP M 9 U Bullhead 180 bbl 10.5 ppg brine down tubing staging up 1/1.2 bpm 3500 psi,shut in.Tubing 5 psi,IA on vac.bleed off tubing 0 psi IA on vac. 13:00 14:00 1.00 14 00 W.O. L 4 P PJSM,BOLDS,unseat hanger w/220k,pull hanger to floor, 14:00 15:00 1.00 15,00 W.O. L 4 P Terminate ESP cable and Cap tube.L/D hanger and landing Joint. 15:00 16:00 1.00 16.00 W.O. L 4 P LID pup joints,string cable and cap tuber through shieves in derrick. 16:00 17:30 1.50 17.50 W.O. L 4 TS03 Repair Centerlift camera. 17:30 22:30 5.00 22.50 W.O. L 4 P Pull out of hole and L/D 4.5"12.68 Hydril 563 tubing F/10,315'117730',83 joints.Pumping double metal displacement 25 bbls. and 10 bbls per hour-120 bbls,P/U=130k,S/0=102k. 2230 00:00 1.50 24.00 W.O. K 9 P R/U to pump a tubing volume down tubing.Staging up to 1 bpm at 2875 psi.pumped 42 bbls Tour losses 227 bbls,Total losses for the day 1,177 BBLS, Projected handover to production 4/4/2017. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907.685-0715 Em representative Mike Grubb ENI Drilling Supv. 907-685-0715 Eni representative Mach Billington ENI Rig Clerk akrlgclerksdoyon l 5aenipetroleum corn 907-685-0722 Eni representative Troy England ENI HSE Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15Qdoyondnlling.com 907.685-0716 Tool Push Dave Sena Doyon Drilling Tour Pusher Last Casing Seat Cas.Type OD(In) ID(In) Grade Top(NKB) Bottom(f9KB) TVD But.iftKB) Run Date LINER 51/2 4.95 L80 2,019.0 21.097.0 3.796.2 6/6/2012 Well Name: SP16-1R • Daily Report • Wellbore Name: SP16-FN3 Well Code: 26438 • Ret ort#:05 017 If en n Job: WORKOVER Ii �' Page:1 of 1 Well Header PermitlConcession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PE TOOLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB•Tubing Spool(ft) 5392 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 0070N LAND RIG 0723 Daily Information Weather Temperature(`F) Wind Days LTI(days) Days RI(days) POB Partly Cloudy -2 7 NW g 5 MPH WC-11 70.0 Daily Summary Operations 24h Forecast Continue loading pipe shed with 260 jots new 4 1/2"12.66 L-80 Hyd 563 tubing.rabbit and strap tubing,RIM to RIH.P/U M/U shroud and ESP assembly,RIH WI 4 1/2"ESP completion string. 24h Summary Coot F'OOH laying down 4.5"completion,pump tubing volume every 3000'add double displacement every 10 joints and 10 bbl per hour 117730 MD.R/U slick line pull tbg stop.pack off&motor,RID slick line,L/D ESP motor assembly and shroud,clear floor simops load pipe shed WI 4.5"12.6#L-80 Hyd 563 tbg. Operation at 07.00 Processing Tubing in pipe shed.changing spools on spooler unit Time Log Start End Cum Our Time Time Out)hr) (hr) Phase Opr. Act. Plan Oper.Closer. 00.00 01.30 1.50 1.50 W.O. L 9 P Cont pumping 80 bbl 10.5 ppg of the 120 total down tubing Q lbpm 2900 psi.increase 1/1.3 bpm 03500 psi,RD BD circ equip. 01 30 05.30 4.00 5.50 W.O. L 4 P Cont.POOH laying down 4.5"completion 117730'1/4678'adding double displacement every 10 joints&10 bbl per hour to hole. Calc disp=14.32 bbl actual disp.Pumped=28.64 bbl,number/strap/rabbit/talley,mark bad joints 0530 '07.00 1.50 7.00 W.O. L 9 P Swap reels in spooling unit,UR&clrc tubing volume 75 bbl 10.5 ppg,1.3-2 bpm 3500 psi,RD DB circ equip. 07:00 11:00 4.00 11.00 W.O. L 4 P Cont.POOH laying down 4.5"completion U4678'1/1858'adding double displacement every 10 joints&10 bbl per hour to hole. Calc disp=13.76 bbl actual disp.pumped=27.52 bbl,number/strap/rabbit/talley,mark bad joints 11 00 12'.00 1.00 1200 W.O. L 9 P Pump tubing volume of 30 bbl 10,5 down tubing 2 bpm 3200 psi,RD BD circ lines. Total Losses for tour 368 blots 12:00 13:30 1.50 13.50 W.O. L 4 P Cont.POOH laying down 4.5"completion 51658'1/400',observed brine/oil mix at break.RU&pump tl clear tubing,add 10 bbls per hour,double displacement every 10 jots=8.8 bbls, 13:30 14:30 1.00 14.50 W.O. L 9 P R/U&pump 15 bbls On tbg,double disp 1 BPM,900 psi,R/D circ equipment. 14:30 15:00 0.50 15.00 W.O. L 4 P Cont POOH WI 4 1/2"12.68 L-80 Hyd 563 tubing F/1,252'to 109'MD. 02 disp v 3.6 bbls,actual=5.42 bbls 15:00 1510 0.50 15,50 W.O. L 20 P Terminate ESP&Cap lubes,flush out PDS 15 30 16:00 0.50 18.00 W.O. L 20 P M/U 1 jnt tbg install clamp for ESP cable and cap tube and RIH to 150'MD. 16.00 16:30 0,50 18.50 W.O. L 1 P PJSM,R/U Halliburton slick line,bring equipment to floor. 16:30 17:30 1.00 17.50 W.0 R 1 P M/U slick line tools RIH retrieve tubing stop,pack off and pump.Visual Inspection of pump was done and three hole were found on pump. 17.30 18:00 0.50 18.00 W.O. L 20 P RID slick line,simops R/U GBR 7"tongs. 18:00 20:00 2 00 20.00 W.O. 1. 20 P R/U LID ESP assembly. 2000 2030 0.50 20.50 W.O. L 20 P L/D 7"shroud 2 jots,fill hole with 10 bbls 10.5 ppg brine every hour. 20311 0000 3.50 24.00 W.O. L 1 U PJSM,clear rig floor.L/D ESP&cap tube lines,clear pipe shed of ESP egiup.Visual inspection of tubing revealed heavy scale build up on inside of tubing and corrosion on pin ends (nose seal)throughout the tubing string,183 jilts flagged bad. load pipe shed W/new 4.5"12.88 L-80 Hyd 563 tubing,mount camera bracket in derrick,recovered 554 pins,274 cross collar clamps,3 protectolizers.2 splice clamps,2 single clamps.Losses for tour 150 BBLS,Total daily losses 518 bbls. Projected handover to production 4/2/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mike Grubb ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyonl 5ienipetroleum cow 907-685-0722 Em representative Paul Holley ENI ENI Safely Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.coln 907-885.0718 Tool Push Dave Sena Doyon Drilling Tour Pusher Tool Push Sam Dye Doyon Drilling Superintendent Last Casing Seat Cas,Type OD(in) ID In) Grade Top(ftKB) Bottom(ftKB) TVO Sot.(ttKB) Run Date LINER 5112 4.95 L80 2.019.0 21,0970 3,796.2 6/6/2012 Well Name: SP16- 0RDaily Report Wellbore Name: SP16-FN3 • Well Code: 26438• Ret ort#:11G2017 pn ii Job: WORKOVER Page:1 of 1 Well Header Permit/Concession N" Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 5392 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature("F) Wind Days LTI(days) Days RI(days) POB Partly Cloudy 1 0 WNW @ 5 MPH WC-11 68.0 Daily Summary Operations 24h Forecast Cool with MLE splice and cap tube,Rip with 4 1/2"12.68 L-80 Hyd 563 tubing filling hole W/10 bbls every hour and complete tubing flush every 3000'. testing cap tube as per procedure 24h Summary Load and process tubing In pipe shed.R/D equipment from POOH.R/U equipment for RIH,P/U M/U shroud and ESP assembly.begin splice on MLE and ESP power cable and cap tube. Operation at 07,00 Performing ESP cable test and cap tube test. Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 W.O. K1 U Cont.loading 4 5"12.671 L-80 Hyd 563 tubing in shed,drift strap&telley.Sunops inspect#1 MP.mount stabbing board camera,remove elephant trunk f/sheave.send out DP elevators&pup jots f/rig floor,add 10 bbl 10.5 ppg every hour to hole. 03.00 09:00 6.00 9.00 W.O. K1 U Cont.load,drift,strap&telley 4.5"tubing in shed,bring 270 cannon clamps to rig floor.RU CRT.RU bail extensions&single joint elevators.Add 10 bbl 10.5 ppg brine to hole. 09:00 12:00 3.00 12.00 W.O. K1 U Cont loading new tubing in shed,drift,strap&telley.Add 10 bbl 10.5 ppg brine to hole.130 bbl losses this tour. 12.00 14:30 2.50 14.50 W.O. K1 U Load Centrilift equipment in pipe shed,strap&inspect shroud assembly.L/D 6'section of shroud and mobilize new shroud to rig floor. 14:30 22'.00 7.50 22.00 W.O. K 4 P PJSM.BO X0 on dispersion tube&L/D dispersion tube.M/U 7"shroud&ESP assembly as per Baker reps,fill motor with oil &service witnessed by company rep,cont to P/U ESP to DOU tie in tec wire. 22:00 00:00 2.00 24,00 W.O. K 5P Spice MLE to ESP power cable,make up cap tube.Losses this tour 120 bbls,Total losses for the day 250 bbls. Projected handover to production 4/3/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mike Grubb ENI Drilling Supv. 007-685-0715 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon l 5©enipetroleur corn 907-685-0722 Eni representative Paul Holley ENI ENI Safely Tool Push Chad Johnson Doyon Drilling Tool Pusher rig 15@doyondniling.coo 907-685-0716 Tool Push Dave Sena Doyon Drilling Tour Pusher Tool Push Sam Dye Doyon Drilling Superintendent Last Casing Seat Cas.Type OD(in) ID lin) Grade Top(ftKB) Bottom(ttKB) TVD Bot.(8KB) Run Date LINER 5 1/2 4 95 L80 2,019.0 21,097.0 3,796.2 6/6/2012 Well Name: SP16-•OR • Daily Report Wellbore Name: SP16-FN3 Well Code: 26438• Ret ort#:4/1/ 017 Pa en il Job: WORKOVER Rep Date: 1 of 1 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53 92 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature(`F) Wind Days LTI(days) Days RI(days) FOB Overcast -2 7 N/6 7 MPH WC-14 69.0 Daily Summary Operations 24h Forecast Cool RIH w/4.5"completion 1119.314',testing cap tube&ESP cable as per baker procedure.PU MU hanger.land completion,RILDS 24h Summary Re-splice MLE lead to ESP cabletest cap tube&ESP cable per procedure.change oul spool on spooling unit,RIH F/155'to 7788'MD WI 4 112"ESP completion string filling hole 10 BPH,Flushing tubing every 3000' Operation at 07.00 NIH WI ESP Completions©8.395'MD Time Log Start End Cum Our Time Time Our(hr) (hr) Phase Opr. Act, Plan Oper.Descr. 00:00 02:30 2.50 2.50 W.O. K 20 U PJSM complete MLE splice,PU out of slips.splice connection pulled free and cable went to sheave.bring cable back to floor. inspect&recut cable.Remake splice with new connections,splice cap tube. 02:30 04:30 2.00 4.50 W.O. K 12 P Conduct electrical&cap tube tests.Cap tube integrity test 1000 psi f110 min.CV open&pump through 3000 psi,CV close 2500 psi,all test good. 04.30 05:30 1.00 5.50 W.O. K 4 P RIH w/4,5"completion f1155't/253',flush 5bb1 down hole past splice&retest ESP.add 10 bbl 10.5 ppg brine to hole every hour 05:30 11:00 5.50 11.00 W.O. K 4 P Cont RIN 1/253'1/3001'testing cable every 1000'.monitor displacement every 10 joints-no returns,add 10 bbl 10.5 brine every hour 11:00 11 30 0.50 11.50 W.O. K 0 P Pump tubing volume of 45 bbl©3 bpm 1900 psi w/no returns,BD TD 11 30 12.00 0.50' 12.00 W.O K 4 P Cont RIH t/3001'113400'testing cable every 1000'.monitor displacement every 10 joints-no returns,add 10 bbl 10.5 brine every hour P/U 110K,SO 100K,Total fluid losses for tour 175 bbls. 12.00 19:10 7.50 19.50 W.O. K 4 P Cont RIH 1/3400'to 8300'MO testing cable every 1000',monitor displacement every 10 joints-no returns.add 10 bbl 10.5 brine every hour. 1980 20:00 0.50 20.00 W.O. K 9 P Pump tubing volume 95 bbls 0 27 SPM,2000 psi,no returns.BID top drive. 20:00 '22:30 2.50 22.50 W.O. K 4 P Cont RIH WI 4 112"12.60 L-80 Hyd 583 tbg F/8300'to 7788'MD,testing ESP cable every 1000',monitoring diap every 10 jnt, no returns,adding 10 bbls 10.5 ppg brine every hour. 22:30 00:00 1.50 24.00 W 0. K 5 P C/O spools In spooling unit crimp splice ESP cables.Total losses for tour 215 bbls,total losses for the day 390 bbls, Projected handover to production 4/4/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI 'Drilling Supv. 907-685-0715 Eni representative Mike Grubb ENI Drilling Supv. 907-885.0715 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyonl5/6empetroleum.com 907.685-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15/doyondrilling.com 907-085-0718 Tool Push Dave Sena Doyon Drilling Tour Pusher Tool Push Sam Dye Doyon Drilling Superintendent Last Casing Seat Cas.Type OD(in) ID(In) Grade Top lftKB) Bottom(ftKB) TVD Bot.(RKB) Run Date LINER 51/2 4.95 L80 2.0190 21.097.0 3.798.2 8/8/2012 Well Name: SP16-•OR • Daily Report Wellbore Name: SP16-FN3 re Well Code: 26438 Ret ort#:i 8 4/2/2017 enll Job: WORKOVER Page:1 of 1 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA EM PETROLEUM ENI Petroleum Co.Inc DEVELOPMENT WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 5392 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature(`F) Wind Days LTI(days) Days RI(days) P08 Partly Cloudy .2 0 NE Q 9 MPH WC-11 70.0 Daily Summary Operations 24h Forecast Finish tree test.pull TWC.BCL perform final checks on ESP equipment,finish pit cleaning.ROMO SP16-FN3move rig.spot Halliburton slick line unit&LRS on SP22-FN1,pressure up&shear upper GLM valve.. displace fluid in tube,RIH WI slick line set catcher.POOH,RIH retrieve upper sheared valve.POOH,RIH set durnmy valve&POOH,RIH retrieve catcher&POOH R/D Halliburton slick line,Pressure up and shear lower GLM valve.Pump tubing volume RID Slick line and LRS.Move in and R/U Doyon 15. 24h Summary RIH WI 4.5"ESP Completion string F/7788'MD to 10,309'MD,M/U landing jnt and hanger.Splice ESP cable and cap tub&test.land hanger a 10,348'MD.RILDS.test hanger seals.install BPV, flush stack, N/D BOP's.N/U tree&test void and pack off,begin tree test. Operation at 07.00 RID lest equipment and prepping In Inoue rig Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act, Plan Open.Descr. 0000 01:00 1.00 1.00 W.O. K 4 P Cont RIH w/4.5"completion 1/7788'118165'.monitor displacement every 10 jts,no returns,add 10bhl 10.5ppg brine every hour. 01 00 03:00 2.00 3.00 W.O. K 12 P Splice ESP cable&test same. 03:00 05'00 2.00 5.00 W.O. K 4 P Cont RIH 98165"1(8297'.flush 5 bbl by ESP line&test.RIH 08297'1/9033T testing cable every 1000',monitor displacement every 10 joints-no returns,add 10 bbl 10.5 brine every hour 05.00 06:00 1.00 6.00 W.O. K 9 P Pump tubing volume of 140 bbl a 2.5bpm 1500 psi wino returns.BO To 09 00 0800 2.00 8 00 W.O. K 4 P Cont RIH(19033'1/10.309'testing cable every 1000',monitor displacement every 10 joints-no returns.add 10 bbl 10.5 brine every hour 08.00 09:10 1.50 9.50 W.O. K 20 P RD CRT.bail extensions.single joint elevators,RU 250 ton elevators&GBR power tongs.Add 10 bbl 10.5 ppg to hole every hour 09.30 12.00 2.50 12.00 W.O. K 20 P MU landing joint&hanger.test cap tube prior to cutting for splice 1000 psi f/10 min,open @ 3000 psi pumping 1/5min,bleed off(110 min,make penetrator splices wlcable&cap tube,re-test cap tube after splice 1000 psi f/10 min,open 0 3000 psi pumping f/5min,bleed off(110 min,(note:no CV installed under hanger as per well plan)PU wtx150k SO wh105k,Losses for tour 260 bbls 12:00 '12.30 0.50 12.50 W.O. K 12 P Cont testing cap tube to 1000 psi for 10 min,open psi for 5 min,close psi for 10 min,simops pull cap tube&ESP cable back to spooling unit. 12.30 14:00 1.50 14.00 W.O. K 4 P Land Hanger,RILDS,test hanger seals @ 5000 psi for 10 min,PU 150K,SO 105K,L/D landing jnt,install BPV. 14 00 '15.00 1.00 15 00 W.O. K 20 P Flush stack&mud lines W/deep clean,B/D choke,kill,mud lines&top drive. 15.00 15 30 0.50 15.50 W.O. K 20 P R/D ESP sheave for inspection. 15.30 17:30 2.00 17.50 W 0 C 5 P PJSM,clean drip pan and N/D BOP's&riser. 17.30 19:30 2.00 19.5(1 W.0 5 P Prep well head,NIU tree.PT hanger void&pack off @ 5000 psi for 10 min. 19:30 22.00 2.50 22 00'W 0 C 12 P Test ESP cable and cap tube as per Baker SOP 22 00 '00:00 2 00 24 110 W C). C 12 P Fill tree WI diesel,Rn&PT tree and wing valve, tree PT 500 psi for 5 min,5000 psi for 10 min.wing valve PT @ 500 for 5 min,2000 psi for 5 min.3000 psi for 30 min.Total losses for ther day 260 bbls, Projected handover to production 4/3/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mike Grubb ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.corn 907-885-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilhng corn 007-685-0716 Tool Push Dave Sena Doyon Drilling Tour Pusher Tool Push Sam Dye Doyon Drilling Superintendent Last Casing Seat Can.Type OD(In) ID(in) Grado Top(ftKBl Bottom(ftKB) TVD Bot.(ftKB) Run Date LINER 51/2 4.95 L80 2,019.0 21,097.0 3.798.2 6/6/2012 Well Name: SP16-•OR • Daily Report Wellbore Name: SP16 FN3 Well Code: 26438• Ret ort#:I9 4/317 2no Job: WORKOVER Page:1 of 1 Well Header Permit/Concession N° -Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Ca Inc. [WWI OPLirff ll WELL Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RK8-Tubing Spool(ft) 53 92 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIG 0723 Daily Information Weather Temperature("F) Wind Days LTI(days) Days RI(days) FOB Clew I 0 ENE a 18 MPH-20 63.0 Daily Summary Operations 24h Forecast RDMO SP16-FN3 This is last Workover Report for SP16-FN3 24h Summary Con(testing tree swab 8 wing valves.test completed.pull lest plug,install bleed flange on IA,install tree cap.dress tree 8 secure well,clean well bay.prep for rig move. Operation at 07.00 Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03.00 3.00 3.00 W.O. C 12 P PJSM,con)testing tree swab valve 500,2000.3000 psi for 5/5/30 min.charted min.Test wing valve 500/2000/3000/psi for 5/5/30 charted min..simops cont disconnecting HP interconnects,secure beaver slide for move,BO rig floor steam,off load fluid F/pits and clean.work on floor skidding checklist,remove top plate on berm around rig,prep pipe shed for move,clean up well bay,move rig equipment to SP22. 03-00 04.0(1 1.00 4.00 W.O. C 20 P Pull test plug.install tree cap.dress tree,install bleed flange on IA,clean around well head and secure area,simops start 3512,swap power over to moving gens,suck out water and cuttings tank,freeze protect wash do pumps and cloths washer. 04:00 06.(10 2011 6.00 W.O. A1 P Remove berming around rig,swap shop power over to Cold start.un-plug shop power F/rig end secure,blow do steam in pits. pipe shed,pump room.blow On water throughout rig,top off diesel day tanks.disconnect air,grey water,fuel and steam F) interconnects.Begin skidding rig floor. Rig released from SP18-FN3 0 08:00 4/3/2017 Daily Contacts Position Contact Name Company Title Email Office Mobile - Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mike Grubb ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyonl 5genipetroleum.coni 907-885-0722 Eni representative Paul Holley ENI EM Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher dg15(gdoyondnlling com 907-685-07t6 Tool Push Dave Sena Doyon Drilling Tour Pusher Tool Push Sam Dye Doyon Drilling Superintendent Last Casing Seat Can.Type 00 lin) ID(in) Grade Top(RK8) Bottom(RKB) TVD Bot.INKS) Run Date LINER 51/2 4.95 1-80 2,019.0. 2107,0 3,798,2 8/8/2012 • . VOF Ty Ofr,A1/ ,s, THE STATE Alaska Oil and Gas 71 Of LAS Conservation Commissioni®n A 11•1W-f-zAik _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 p�� ° p, :'•'^".- . +--...,.,, ,,5, Main: 907.279.1433 ALASFa :907.276.7542 www.aogcc.alaska.gov Marc Kuck Drilling and Completion Engineering Manager Eni US Operating Co. Inc. SCANPlE 11/t' tl 3800 Centerpoint Dr., Ste. 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP16-FN3 Permit to Drill Number: 212-049 Sundry Number: 317-037 Dear Mr. Kuck: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this � day of February, 2017. RBDMS FEB - 3 2317 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 2 4 2017 APPLICATION FOR SUNDRY APPROVALS !,®G �1,7 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q ' Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-gslt ❑ • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Eni US Operating Co.Inc. Exploratory ❑ Development ❑✓ , 212-049 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-629-23467-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A SP16-FN3 , Will planned perforations require a spacing exception? Yes 0 No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 039283, 03885783, 0388574, 0388571, 0388572 Nikaitchuq Schrader Bluff Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total e h MD ): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 21097 " 3796 21097 " 3796 1131 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 Surface 3274 13.375" 3274 2440 5210 2480 Intermediate 11600 9.625" 11600 3883 6890 4790 Production Liner 9497 5.5" 21097 3796 slotted slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11600-21,097 . 3,833-3,796 4.5" L80 10,210 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development 2 ' Service ❑ 14.Estimated Date for 3/22/2017 15.Well Status after proposed work: Commencing Operations: OIL Q ' WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Amjad Chaudhry Email arrljad.chaudhry@enipetroleum.com Printed Name Marc Kuck Title Drilling&Completion Engineering Manager 907-865-3379 Signature yi, Phone 907-865-3322 Date 1/23/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test' Mechanical Integrity Test ❑ Location Clearance ❑ 1-6F- 21, It� Other: Ps i, QU OS' c Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: '0 404 4 RBDIVIS Lv- FE3 - 32017 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: L--'- / 7 Submit Form and Form 10-40314e ised 11/2015 0 oR1GFNAL peivalid f ;2 7n7 from the date of approva ��S p tachments in Duplicate • • ijiyik. ..... Enu ' iirolI - uuni Recolep .0tion? 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907) 865-3322 Email: marc.kuck@enipetroleum.com January 23rd , 2017 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for SP16-FN3 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP 16-FN3. SP16-FN3 was completed on Spy Island on June 12th, 2012 with an electric submersible pump set at a depth of 10,314' MD. This ESP producer was completed without a packer. The well was started up for production in June 2012 We are swapping out TTC-ESP to the conventional ESP system The estimated date for beginning this work is March 22nd, 2017. 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, ,40a17'---a___ Marc Kuck Well Operations Project Manager • S SP16-FN3 Workover— Summary Page PTD#:212-049 Current Status Well SP16-FN3 is currently not performing as it supposed to be Scope of Work Scope of this workover is change ESP pump. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1550 psi (3,813' TVD) during the time of workover, which places the fluid level well below surface. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind rams/Mudcross/pipe TIFL/MIT-IA/MIT-OA: Due to the completion design these tests were not performed. Intermediate csg 9 5/8" was tested prior to drill out on May 2012. Well type: Producer Estimated start date: March 22nd 2017 Drilling rig: Doyon 15 Completion Engineer: Amjad Chaudhry: amjad.chaudhry@enipetroleum.com Work: 907-865-3379 • Procedure: 1. MIRU Doyon 15. 2. Shear upper GLM valve and pump in bullheading 8.6 ppg KC1 brine through tree. Pump in bullheading 8.6 ppg KC1 brine in IA. Ensure well is killed. 3. Set BPV. ND tree and NU BOP and test to 3500 psi.,/ 4. Pull tubing to upper GLM. 5. Shear lower GLM valve and pump in bullheading 8.6 ppg KCl brine. 6. Pull tubing to lower GLM. Rig up wireline and pull tubing stop check valve. 7. Circulate out remaining production fluid. 8. Continue POOH and lay down ESP assembly. 9. Perform a CO run 10. MU new ESP assembly and RIH to setting depth. 11. Land hanger, and test it. 12. Install BPV and nipple down BOP. 13. NU tubing adapter and tree. 14. Pull BPV, install test plug and test tree. 15. Circulate Freeze protect through tree down IA. 16. Shut in well. 17. RDMO. Below the current schematic of the well: 4-W 12.6 ppf Production Tubing antpetroleum 2,172'MD,1,858'TVD 450 Inc-GLM,KBMG, 4-W x 1", SP1 6-FN3 with 2,000 psi STS-1 SOV installed Oil Producer with 4-W x-cplg cable clamps,for ESP ESP Lift Power Cable,(1)3/8"Chem Inj Line As Completed lit\ 10,110'MD,3,655'TVD,80°Inc-GLM,KBMG, 4-W x 1", 6112/2012 with 3,100 psi STS-1 SOV installed 4 10,210'MD-Discharge Gauge Sub Tracer June 2012 "`�'°. 10,314'MD,3,889'TVD,80°Inc—Bottom of Motor .1040, Centralizer Cantu-gift,TTC-ESP,134-stage 380P18SXD pump. 513 GSB3 seals,150 HP MSP325 motor Surf.Casing . / 7" 20#Shroud Assembly with cable and chemical 13-3/8",68# injection line feed-thrus 3,274'MD,2,440'TVD ��. 87°Inc. f 11,391'MD—3,813'TVD Baker SLXP Liner Hanger/Packer , j Resman Oil/Water HAL 5-W Oil Swell 5-r4 Silver Bullet Ecc. Tracers Packer Nose Guide Shoe Item MD(ft) iimilli millmam lisiggilla 1 5-1/2"Swell Pkr#1 12941 '+_'_ _ JENS i. . 5-1/2"Swell Pkr#2 14298 5-1/2"Swell Pkr#3 15828 Interm.Casing Rem Mote) Slotted Liner, 5-1/2"Swell Pkr#4 17225 9-5/8".40811.600'MD.' Resnwntmcersab#1-ROS 377/RWS411 12980 Resmen tracer Sub*2'ROS 378/RWS412 14343 5-4'15.5 ppf 5-1/2"Swell Pkr#5 19602 3.833'TVD Reunion hater Sub 03-R05379/RWS 413 15878 21.097'MD,3,796'TVD $4°Inc Resman tracer Sub 44-R03380/RWS 414 17273 89°Inc. Nik aitchuq Field-Spy islantl Reunion tracer Sub 05.R05381/RWS415 19656 • • Vetco G ray MB-247 SURFACE COMPLETION SYSTEM • _-. /ANN /CI- . /CL n-15- 37.19—._ ---1 .. u ii 4100,414-ti pi / _, I. iiiijim _drimilaatt '''' i rl - !KID:,t Re: i__ iiii,-*Imm‘, II.. i. ' �i11/ 1t T.O.S. EL 26' 5-3/4" 1.062 OFFSET CIL B.O.S_ EL 25' 7-1/4" FEL 0 TOP OF WELLHEAD 51°' '00 EL 25' 2-1/4" d C PFT Y or d ' ELECTRICAL .. FEEOTHRU 21.61 - 1,1- 13-5/8" 5000 PSI :1. VG S137 CLAMP • p oio q 411.iri ,.,o�:,,:, II 4-1/16" IN $000 PSI ir_ T-a, .�17i11II = C J I ■p■H . 3.437 OFFSET 6.50"- PLR ••1_ 2-1/18" �I 1 j 5000 PSI '." _ 2-1/16" �` "41"IS= 'ri 5000 PSI :111 "''•.�"'♦ _ . It'T 66.71 POSMON .:rismI ) I I 13" 5000 PSI VG 134 MOO. /0 52.96" 1101 CM zGNI II 34.00" 2__1,1'=C; .A - �� OUT OF I 24.2 I-5000 .1 (• "' 15.25" POSfTION ■_ I �. TOG f TOP OF GRADING �� _" -�1 1 f EL 16' 1-1/4" I 1.00 p0CRETARY NOTICE 6e 1.77= vetcogr - .1�: r. .0411.81 r 20" OD 133# K-55 — s:1=., ` 13-3/8" OD 68# L-80 0.„,,,,V ATODO ENI ALASKA 9-5/8" OD 53.5 L-BO .nem n, HORIZONTAL MULTIBOWLSYSTEM 4-1/2" OD WITH 6-5/8 VIT /0.110.141 20 X 13-3/8 X 9-5/8 X E X 4-1/2 WITH 6-5/8 VIT MAW MP AND ESP FLAT CABLE ML2.3 m ^ate®.� 13`IG H173370-1 ipp;' wr[0.11.110vtaOP.OM XXXIl IW 0 1"a+ >l PRP 10161, NC 10 OF 10 23 JANUARY 2009 41, GE Imagination o work . • • ot . .a ! s cn 01 ! .'-:" ' Rig,E 'n°1 g . N De Lo m E52 p J N �,,� 0 . 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Days vs. Depth Digital Data to include: Formation Evaluation Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI Backup GENERAL WELL INFORMATION Company: Eni Petroleum Rig: Doyon 15 Well: SP16-FN3 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23467-00-00 Sperry Job Number: AK-AM-0009113848 Job Start Date: 4 May 2012 Spud Date: 8 May 2012 Total Depth Date: 01 Jun 2012 Total Depth: 21,110’ MD, 3796.50’ TVD North Reference: True Declination: 20.516˚ Dip Angle: 81.080˚ Total Field Strength: 57646.724 nT Date Of Magnetic Data: 01 Jun 2012 Wellhead Coordinates N: North 70° 33’ 27.90” Wellhead Coordinates W: West 149° 54’ 18.69“ Drill Floor Elevation: 53.92’ Ground Elevation: 13.10’ Permanent Datum: Mean Sea Level SDL Engineers: Zachary Beekman, Matthew Smith Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 DAILY SUMMARY Begin SP16-FN3 05/04/2012 Rig is being moved. Mudloggers are on standby. 05/05/2012 Rig is being moved. Mudloggers are on standby. 05/06/2012 Rig is being moved. Rig crew working on installing the WEI Subs. Mudloggers on standby. 05/07/2012 Mudloggers and loader operator got the mudlogging unit spotted. Mudloggers got with the rig electrician to get the unit plugged in and powered up so the heat and lights could be turned on. Once the unit and equipment were warmed up, the mudloggers were able to rig up their computers and gas equipment. 05/08/2012 Rig up the WEI system. Pick up 90 joints of drill pipe and 14 joints of heavy weight drill pipe. Make up the jars, crossover subs to heavy weight drill pipe. Function test the diverter system. Continue to work on WEI system. Cut and slip drill line. Weld hard lines. Test the new stand pipe section to 5000 psi. Make up BHA #1. Clean out the conductor to 160’ MD and drill ahead to 191’ MD. Circulate the hole clean. Make up BHA #2. Rig up Gyro wireline. Drilling ahead from 191’ MD to 289’ MD as of midnight. 05/09/2012 Pick up heavy weight drill pipe and jars. Acquire rotating parameters as per K&M. Crossed the tolerance line and had to call town. Drilling from 289’ MD taking Gyro surveys every stand to 848’ MD. Drilling ahead from 848’ MD to 2058’ MD as of midnight. Max gas observed in the last 24 hours was 517 units at a depth of 1970’ MD. 05/10/2012 Drilling and sliding from 2058’ MD to 2712’ MD. Stopped drilling for anti collision, contacted Eni and SLB offices for go ahead. Drilling from 2712’ MD to 3289’ MD. TD 16” surface hole at 1200. Circulate and reciprocate the hole clean at 800 gpm. Back ream out of the hole as per K&M rep, while working through tight spots until smooth from 3289’ MD to 800’ MD. Noticed tight spots at 2937’ MD, 2230’ MD, and 1540’ MD. Max gas observed for the last 24 hours was 284 units at a depth of 2243’ MD. 05/11/2012 Back ream out of the hole from 800’ MD to 270’ MD. Circulate the hole clean. Lay down BHA #2. Rig up and run 13 3/8” casing from surface to 1360’ MD. Break to circulate and condition the mud at 1360’ MD. Run in hole with casing from 1360’ MD to 3274’ MD. Make up the landing joint and hanger assembly. Land casing at 3274’ MD. Circulate and condition the mud for the cement job as of midnight. 05/12/2012 Cement 13 3/8” casing in place. Drop the bottom plug, mix and pump 510 bbls of 10.7 lead slurry and 63 bbls of 12.5 tail slurry. Displace with 9.2 ppg WBM and bump the plug at 4662 stokes. Flush the stack, riser, and flow line. Lay down the casing equipment and cement head. Nipple down the surface equipment. Nipple up the BOP and set the test plug. Rig up the BOP test equipment and test the BOP as of midnight. 05/13/2012 Continue testing BOPE’s. Install the wear bushing. Pick up 5” drill pipe. Run in hole to 2304’, pull out of the hole and rack back stands. Pick up 20 stands of 5” drill pipe and rack back. Perform accumulator draw down test. Lay down 4 stands of 5” heavy weight drill pipe. Mobilize BHA tools to the rig floor and begin building BHA as of midnight. 05/14/2012 Pick up BHA #3. Trip in hole with BHA #3 to 2992’ MD. Break circulation and wash to 2995’ MD. Circulate and test casing to 2500 psi. Slip and cut drill line. Wash to 3180’ MD. Tag cement at 3186’ MD. Drill out cement, shoe track, and casing shoe at 3274’ MD. Drill to 3310’ MD and displace the well to 9.25 ppg LSND mud. Circulate and perform the LOT at 11.4 ppg EMW. Drill ahead with 12.25” intermediate hole from 3310’ MD to 4391’ MD as of midnight. Max gas observed during the last 24 hours was 292 units at a depth of 4113’ MD. 05/15/2012 Continue to drill ahead with the 12.25” intermediate hole from 4391’ MD to 7278’ MD as of midnight. The max gas observed during the last 24 hours was 202 units at a depth of 4582’ MD. 05/16/2012 Continue to drill the 12.25” intermediate hole section from 7278’ MD to 9290’ MD. Max gas observed during the last 24 hours was 176 units at a depth of 8381’ MD. 05/17/2012 Continue to drill the 12.25” intermediate hole from 9290’ MD to TD at 11625’ MD. Max gas observed during the last 24 hours was 1670 units at a depth of 11584’ MD. Free oil was observed on shakers once into the N-sands. 05/18/2012 Circulate two bottoms up at TD of 11625’ MD at 900 gpm, 2920 psi, and 120 rpm. Follow K&M circulating schedule. Backream out of the hole at drill rate per K&M from 11625’ MD to 6537’ MD as of midnight. Monitor well periodically. Static. 05/19/2012 Continue to backream out of the hole from 6537’ MD to 2995’ MD. Monitor the well. Static. Pull out of the hole on elevators to 2704’ MD. Pump a dry job. Pull out of the hole. Lay down the BHA. Flush the BOP stack. Perform a derrick inspection. Make up BHA #4 as of midnight. 05/20/2012 Run in the hole with BHA #4 to 3185’ MD. Cut and slip drill line. Run in the hole to 10931’ MD. Ream in hole and tag bottom at 11625’ MD. Circulate. Drop a carbide test down the drill string and circulate it to surface. The carbide gas came up 2000 stokes over actual giving 11-12% hole washout. Monitor the well. Static. Pull out of the hole with elevators to 10740’ MD. Backream out of the hole and MWD log to 10185’ MD. Blow down the top drive and monitor the well as of midnight. 05/21/2012 Pull out of the hole from 10185’ MD to 9344’ MD and pump a 30 bbl, 10.8 ppg dry job. Pull out of the hole to 3185’ MD. Circulate two bottoms up at 800 gpm, 1400 psi, and 120 rpm. Pump a 30 bbl, 11.1 ppg dry job. Pull out of the hole and lay down the BHA at 292’ MD. Pull wear bushing and change out the top rams to 9 5/8” and test. Rig up Tesco casing equipment. Make up 9 5/8” shoe track as of midnight. 05/22/2012 Float 9 5/8” casing to 11600’ MD per K&M representative. The correct displacement was observed, 294 joints total. The Tesco equipment was rigged down. The cement head and circulation equipment was rigged up. Held a prejob safety meeting. Began filling 9 5/8” casing, 360 bbls of cement pumped at 3 bpm and 50 psi as of midnight. 05/23/2012 Continue to fill casing at 3 bpm and 50 psi. Circulate and condition 3 bottoms up at 50 spm and 460 psi, no losses noted. Pumped 70 bbls of 10.5 ppg mudpush, 205 bbls cement, and 10 bbls water. Chased with 9.6 ppg LSND to 8643 strokes. Plug not bumped. FCP: 480 psi, check floats, OK. CIP: 13:30hrs. No losses noted. Injection test: final psi 600. Rig down the cement head. Nipple down BOP. Cut 9 5/8” casing. Set packoff. Start nipple up BOP as of midnight 05/24/2012 Nipple up BOP and test. Test packoff: 2470 psi. OK Freeze protect 13 3/8” x 9 5/8” annulus with 196 bbls diesel. Change rams to variables. Fill stack and test casing to 1000 psi for 15 minutes, OK. Run in hole with 5” drill pipe. Circulate due to mud run over pipe. Cement contaminated mud at shakers. Run in hole and circulate at 7000’, 8969’, and 10089’ MD. Circulate until 9.4 ppg even all around. Pump dry job. Pull out of hole and install WEI subs each stand out. 05/25/2012 Pull out of the hole and install WEI subs on each stand from 9249’ MD out. Rig up and test BOPE’s. Pull the test plug and set wear ring. Pick up mule shoe and run into the hole with 10 stands 5” drill pipe to install WEI-ECD subs as of midnight. All Sperry gas equipment was calibrated and tested prior to the lateral section. 05/26/2012 Pull out of the hole and finish installing WEI-ECD subs each stand. Service rig and equipment. Make up 8 ¾” BHA #5. Change over handling equipment to 4.5” drill string. Pick up 4.5” drill pipe and wash down to 11331’ MD at 5 bpm and 850 psi as of midnight. 05/27/2012 Circulate at 11424’ MD. Casing pressure test for 30 minutes at 3000 psi., OK. Displace LSND to FazePro OBM. Clean the surface equipment. Drill out the float collar at 11512’ MD, shoe at 11597’ MD, and 20’ of new formation to 11645’ MD. Circulate and condition the mud. Perform LOT to 12.2 ppg EMW. Drill ahead with tapered string: 5” with WEI-ECD subs and 4.5” drill pipe at 550 gpm, 3260 psi and 90 rpm. The max gas observed during the past 24 hours was 437 units at 11383’ MD. 05/28/2012 Continue drilling ahead from 11857’ MD to 14016’ MD at 550 gpm, 3430 psi, and 180 gpm. The max gas observed during the past 24 hours was 1642 units at 13204’ MD. Average gas was 494 units with a background average of 100 units. 05/29/2012 Continue drilling ahead from 14016’ MD to 16104’ MD. The max gas observed during the past 24 hours was 1709 units at 15102’ MD. The average background gas was 97 units. 05/30/2012 Continue drilling ahead from 16104’ MD to 16977’ MD. Stop to troubleshoot MWD tools. Continued drilling ahead from 16977’ MD to 18350’ MD at midnight. The max gas observed during the past 24 hours was 1608 units at 16382’ MD. The average background gas was 107 units. 05/31/2012 Continued drilling from 18350’ MD to 19262’ MD. Troubleshoot MWD communication issues with downhole tools. Drilled ahead from 19305’ MD to 19402’ MD. Stopped to troubleshoot MWD tools. Drilled ahead from 19402’ MD to 19594’ MD. Troubleshoot #1 and #2 motors (ground fault in #2 generator). Drilled ahead from 19402’ MD to 19633’ MD. Troubleshoot motors and removed rig doors to aid in circulation. Drilled ahead from 19633’ MD to 19825’ MD at midnight. The max gas observed during the past 24 hours was 1839 units at 18383’ MD. 06/01/2012 Continue to drill ahead from 19825’ MD to TD at 21100’ MD. Shot survey as per Schlumberger, monitored the well for ten minutes. Back reamed out of the hole from 21100’ MD to 20848’ MD as of midnight. The max gas observed during the past 24 hours was 506 units at 20150’ MD. 06/02/2012 Backream out of the hole from 21100’ MD to 21174’ MD. Circulate one bottoms up per stand for the first 5 stands, then two stands per bottoms up for the next 5 stands, break out and lay down the WEI subs. Backream out of the hole from 21174’ MD to 19212’ MD. Replace WEI hammer union o-ring seal. Backream out of the hole from 19212’ MD to 17670’ MD. Line up on the WEI manifold and shoot surveys at 17670’ MD as per MWD/DD to test the signal strength. Ream in hole from 17670’ MD to 20400’ MD as of midnight. 06/03/2012 Continue reaming in hole from 20400’ MD to 21100’ MD. Schlumberger performed their telemetry test and the performed service on the top drive. Backream out of the hole from 21100’ MD to 18570’ MD. Performed a fire drill. Continue to backream out of the hole from 18570’ MD to 15650’ MD. Noticed signs of packing off at 16085’ MD and reamed the area two times. Continued to backream out of the hole from 15650’ MD to 13538’ MD as of midnight. The max gas observed after reaming back to bottom was 52u. 06/04/2012 Continue backreaming out of the hole from 13538’ MD to the shoe at 11600’ MD. Circulate and reciprocate at the shoe while doing two bottoms up. Observe the well. Static. Backream out of the hole from 11600’ MD to 10642’ MD. Performed a man down drill. Backream out of the hole from 10642’ MD to 9375’ MD. Change out the saver sub and rig down the 5” equipment. Rig up the 4.5” equipment. Backream out of the hole from 9375’ MD to 5000’ MD. Monitor the well for 10 minutes. Well is static. Pull out of the hole on elevators as per K&M schedule monitoring the well for swabbing from 5000’ MD to 4534’ MD as of midnight. 06/05/2012 Continue to pull out of the hole on elevators as per K&M schedule from 4534’ MD to 270’ MD. Lay down BHA #5. Pull the wear bushing and install the test plug. Rig and test rams. Pull the test plug and install the wear bushing and change out the saver sub. Pick up and rig up the 5.5” slotted liner running equipment. Pre-job safety meeting for running the slotted liner. Begin running in hole with the 5.5” slotted liner. Run the slotted liner to 6734’ MD as of midnight. 6/06/2012 Continue running in the hole with the 5.5” slotted liner. Pick up the liner hanger. Run the liner in hole on 5” drill pipe from 9720’ MD to 21093’ MD. Take on 625 bbls of 9.0 KCl Brine to the pits. Pick up a single and tag bottom at 21100’ MD. Set liner at 21097’ MD. The top of the liner is at 11391’ MD. Drop the ball and observe 1645 strokes to seat the ball. Pull out of the liner hanger. Slip and cut drill line, and adjust the breaks. Displace with 9.0 ppg KCl Brine as of midnight. 6/07/2012 Clean the surface equipment and the pits of OBM. Single out of the hole with the 5” drill pipe from 11391’ MD to 5103’ MD and lay down the WEI subs. Improper hole fill, the hole fill pump packed off. Filled the hole with rig pumps (well was static). Pulled out of the hole while laying down the 5” drill pipe from 5103’ MD to the BHA. Laid down the liner running tools. Laid down the mule shoe. Rig down the 5” equipment. Rig up the 4.5” equipment. As of midnight, began laying down the 4.5” drill pipe using the mouse hole. . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL 6.0 GEL Depth Mud Type 78 Cor Solids (lb/100ft 2) 1,700 9.30 Condition 35.0 Chlorides 289' YP 2 8.80 Weight 160' - 129' Type 20" 16" (current) 1.00 12.5 28 1.117 26 Size 1 8-May-2012 24:00:00 Time: Report #: Date: ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg PV MBT MWD Summary Depth 0' to 289' Sh Clyst Cly Ss Depth in / out Hughes MX-1 Mill Tooth 160' Lithology (%) Total Charges: 3.0 Drilling 16" hole Rig Activity: Flow In (spm) 676.0 $2,810.00 (ppb Eq) cP $11,240.00 Report For: Ross/Smith/Buchanan 71.0 0' 289' 289' Current Pump & Flow Data: 173' Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 490 116 SPP (psi) Gallons/stroke 555 @4.23 0.0 Max @ ft 15.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade Tuff Silt Siltst Lst Cht * Trip 907-685-0772 Unit Phone: 24 hr Recap: Background Maximum 0 0 000 Depth Units* 0 hard lines. Test the new stand pipe section to 5000 psi. Make up BHA #1. Clean out the conductor at 160' MD and drill ahead to 191' MD. Circulate the hole clean. Make up BHA #2. Rig up Gyro wireline. Drilling ahead from 190' to 289' MD as of midnight. 0 0 C-4n subs to heavy weight drill pipe. Function test the diverter system. Continue to work ok WEI system. Cut and slip drill line. Weld Rig up WEI system. Pick up 90 joints of drill pipe and 14 joints of heavy weight drill pipe. Make up the jars, crossover md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Emil Opitz / Leigh Ann Rasher (max) (current) Report By: Emil Opitz C-3 0 Gas Summary C-2 C-5n C-5i C-1 000 0 0 100% Gas In Air =10,000 Units Connection (max) . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Cht Mud Data Casing Summary Grade ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 1295 @4.23 286.6 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 644 152 SPP (psi) Gallons/stroke % EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $14,050.00 Report For: Ross/Smith/Buchanan 90.3 289' 2123' 1834' Current Pump & Flow Data: 2116' Yesterday's Depth: Total Charges: 6.0 Drilling 16" hole Rig Activity: Flow In (spm) 643.7 $2,810.00 (ppb Eq) cP Depth in / out Hughes MX-1 Mill Tooth 160' Lithology (%) Ss Sh Clyst Cly PV MBT MWD Summary Depth 289' to 2123' ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg 2 9-May-2012 24:00:00 Time: Report #: Date: 20.0 31 1.117 27 Size 20" 16" (current) Weight 160' - 1963' Type 1557' YP 2 9.40 Cor Solids (lb/100ft 2) 1,900 9.10 Condition Chlorides GEL Depth Mud Type - ml/30min RPM mg/l Coal Gvl API FL 4.6 Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD * 100% Gas In Air =10,000 Units Connection (max) C-5n C-5i C-1 0025 0 0 Gas Summary C-2 Zachary Beekman C-3 0 Logging Engineers: Zachary Beekman / Leigh Ann Rasher (max) (current) Report By: 8110 5 63991 Chromatograph (ppm) 00 0 0 Minimum C-4i 1970' 310' to call town. Drilling from 289' MD taking Gyro survey every stand to 848' MD. Drilling ahead from 848' MD to 2058' MD as of Pick up heavy weight drill pipe and jars. Acquire rotating parameters as per K&M. Crossed the tolerance line and had 89 md. Average 0 0 0 C-4n 517 midnight. Max gas oberved in the last 24 hours was 517 units at a depth of 1970' MD. 0 Depth Units* 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: 149 Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL 5.2 GEL Depth Mud Type - Cor Solids (lb/100ft 2) 1,000 9.00 Condition Chlorides 3289' YP 2 9.40 Weight 160' - 3129' Type 20" 16" (current) 20.0 24 1.117 21 Size 3 10-May-2012 24:00:00 Time: Report #: Date: ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg PV MBT MWD Summary Depth 2123' to 3289' Sh Clyst Cly Ss Depth in / out Hughes MX-1 Mill Tooth 160' Lithology (%) Total Charges: 6.5 BROOH Rig Activity: Flow In (spm) 688.1 $2,810.00 (ppb Eq) cP $16,860.00 Report For: Ross/Smith/Buchanan 66.0 2123' 3289' 1166' Current Pump & Flow Data: 2341' Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade Tuff Silt Siltst Lst Cht * Trip 907-685-0772 Unit Phone: 24 hr Recap: Background Maximum 0 0 000 Depth Units* 0284 Backream out of the hole as per K&M rep, while working through tight spots until smooth from 3289' MD to 800' MD. Noticed tight spots at 2937' MD, 2230' MD and 1540' MD. Max gas observed for the last 24 hours was 284 units at a depth of 2243' MD. 0 0 C-4n ahead. Drilling from 2712' MD to 3289' MD. TD 16" surface hole at 12:00. Circulate and reciprocate the hole clean at 800 gpm. Drilling and sliding from 2058' MD to 2712' MD. Stopped drilling for anti collision, contacted Eni and SLB offices for go 142 md. Average 0Minimum C-4i 2243' 2763' Chromatograph (ppm) 00 0 0 16178 56 36397 Logging Engineers: Zachary Beekman / Leigh Ann Rasher (max) (current) Report By: Zachary Beekman C-3 0 Gas Summary C-2 C-5n C-5i C-1 00226 0 0 100% Gas In Air =10,000 Units Connection (max) . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Cht Mud Data Casing Summary Grade ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 25.0 @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $19,670.00 Report For: Ross/Smith/Buchanan 3289' 3289' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: Cementing Rig Activity: Flow In (spm) $2,810.00 (ppb Eq) cP Depth in / out Hughes MX-1 Mill Tooth 160' Lithology (%) Ss Sh Clyst Cly PV MBT MWD Summary Depth 3289' to 3289' ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg 4 11-May-2012 24:00:00 Time: Report #: Date: 18.20 16 1.117 20 Size 20" 16" (current) Weight 160' 3289' 3129' Type 3289' YP 2 9.35 1-1-WT-A-E-I-NO-TD Cor Solids (lb/100ft 2) Condition 40.0 Chlorides GEL Depth Mud Type ml/30min RPM mg/l Coal Gvl API FL Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD * 100% Gas In Air =10,000 Units Connection (max) C-5n C-5i C-1 000 0 0 Gas Summary C-2 Zachary Beekman C-3 0 Logging Engineers: Zachary Beekman / Leigh Ann Rasher (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i casing from surface to 1360' MD. Break to circulate and condition the mud at 1360' MD. Run in hole with casing from 1360' MD to Back ream out of the hole from 800' MD to 270' MD. Circulate the hole clean. Lay down BHA #2. Rig up and run 13 3/8" md. Average 0 0 0 C-4n 3274' MD. Make up landing joint and hanger assembly. Land casing at 3274' MD. Circulate and condition the mud for the cement job as of midnight. 0 Depth Units* 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL GEL Depth Mud Type 1-1-WT-A-E-I-NO-TD Cor Solids (lb/100ft 2) Condition 40.0 Chlorides 3289' YP 2 9.20 Weight 160' 3289' 3129' Type 20" 13 3/8" 16" (current) 68.0 18.20 20 1.117 10 Size 5 12-May-2012 24:00:00 Time: Report #: Date: ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg PV MBT MWD Summary Depth 3289' to 3289' Sh Clyst Cly Ss Depth in / out Hughes MX-1 Mill Tooth 160' 3274' Lithology (%) Total Charges: Test BOP Rig Activity: Flow In (spm) $2,810.00 (ppb Eq) cP $22,480.00 Report For: Ross/Smith/Buchanan 3289' 3289' 0' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft 25.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Tuff Silt Siltst Lst Cht * Trip 907-685-0772 Unit Phone: 24 hr Recap: Background Maximum 0 0 000 Depth Units* 0 equipment and cement head. Nipple down the surface equipment. Nipple up the vetco well head. Nipple up the BOP, set test plug. Rig up BOP test equipment and test the BOP as of midnight. 0 0 C-4n Displace with 9.2 ppg WBM and bump the plug at 4662 strokes. Flush the stack, riser, and flow line. Lay down the casing Cement 13 3/8" casing. Drop the bottom plug, mix and pump 510 bbls of 10.7 lead slurry and 63 bbls of 12.5 tail. md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Zachary Beekman / Leigh Ann Rasher (max) (current) Report By: Zachary Beekman C-3 0 Gas Summary C-2 C-5n C-5i C-1 000 0 0 100% Gas In Air =10,000 Units Connection (max) . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Cht Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 25.0 @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $26,890.00 Report For: Ross/Smith/Buchanan 3289' 3289' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: P/U BHA #3 Rig Activity: Flow In (spm) $4,410.00 (ppb Eq) cP Depth in / out Hughes MX-1 Mill Tooth 160' 3274' Lithology (%) Ss Sh Clyst Cly PV MBT MWD Summary Depth 3289' to 3289' ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg 6 13-May-2012 24:00:00 Time: Report #: Date: 18.20 20 1.117 10 Size 20" 13 3/8" 16" (current) 68.0 Weight 160' 3289' 3129' 3289' Type 12 1/4" 1.167 3289' YP 2 3 Smith MDSi716 PDC 8.90 1-1-WT-A-E-I-NO-TD Cor Solids (lb/100ft 2) Condition 40.0 Chlorides GEL Depth Mud Type ml/30min RPM mg/l Coal Gvl API FL Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD * 100% Gas In Air =10,000 Units Connection (max) C-5n C-5i C-1 000 0 0 Gas Summary C-2 Zachary Beekman C-3 0 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i rack back stands. Pick up 20 stands of 5" drill pipe and rack back. Perform accumlator draw down test. Lay down 4 stands of Continue testing BOPE's. Install the wear bushing. Pick up 5" drill pipe. Run in hole to 2304', pull out of the hole and md. Average 0 0 0 C-4n 5" heavy weight drill pipe. Mobilize BHA tools to the rig floor and begin building BHA as of midnight. 0 Depth Units* 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL 6.3 LSND Depth Mud Type 51 Cor Solids (lb/100ft 2) 700 9.90 Condition Chlorides 3965' YP 2 9.25 Weight 3289' 4391' 1102' Type 20" 13 3/8" 12 1/4" (current) 68.0 3.0 26 1.167 9 Size 7 14-May-2012 24:00:00 Time: Report #: Date: ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg PV MBT MWD Summary Depth 3289' to 4391' Sh Clyst Cly 10 Ss 90 Depth in / out Smith MDSi716 PDC 160' 3274' Lithology (%) Total Charges: 4.0 Drilling Ahead Rig Activity: Flow In (spm) 432.3 $3,410.00 (ppb Eq) cP $26,890.00 Report For: Ross/Smith/Buchanan 145.7 3289' 4391' 1102' Current Pump & Flow Data: 4190' Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 905 214 SPP (psi) Gallons/stroke 1522 @4.23 253.4 Max @ ft Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Tuff Silt Siltst Lst Cht * Trip 907-685-0772 Unit Phone: 24 hr Recap: Background Maximum 0 0 000 Depth Units* 0 was 292 units at a depth of 4113' MD. 292 shoe at 3274' MD. Drill to 3310' MD and displace the well to 9.25 ppg LSND mud. Circulate and perform the LOT at 11.4 ppg EMW. Drill ahead with 12.25" intermediate hole from 3310' MD to 4391' MD as of midnight. Max gas observed during the last 24 hours 0 0 C-4n casing to 2500 psi. Slip and cut drill line. Wash to 3180' MD. Tag cement at 3186' MD. Drill out cement, shoe track, and casing Pick up BHA #3. Trip in hole with BHA #3 to 2992' MD. Break circulation and wash to 2995' MD. Circulate and test 71 md. Average 0Minimum C-4i 4113' 3367' Chromatograph (ppm) 00 0 0 7150 25 15747 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: Zachary Beekman C-3 0 Gas Summary C-2 C-5n C-5i C-1 001520 0 0 100% Gas In Air =10,000 Units Connection (max) . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Cht Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 1971 @4.23 254.7 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 893 211 SPP (psi) Gallons/stroke % BTC EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $33,710.00 Report For: Ross/Wimmer/Buchanan 128.0 4391' 7278' 2887' Current Pump & Flow Data: 6078' Yesterday's Depth: Total Charges: 6.3 Drilling Ahead Rig Activity: Flow In (spm) 554.8 $3,410.00 (ppb Eq) cP Depth in / out Smith MDSi716 PDC 160' 3274' Lithology (%) Ss 90 Sh Clyst Cly 10 PV MBT MWD Summary Depth 4391' to 7278' ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg 8 15-May-2012 24:00:00 Time: Report #: Date: 16.0 35 1.167 13 Size 20" 13 3/8" 12 1/4" (current) 68.0 Weight 3289' 4391' 3989' Type 7154' YP 2 9.30 Cor Solids (lb/100ft 2) 1,000 9.60 Condition Chlorides LSND Depth Mud Type 60 ml/30min RPM mg/l Coal Gvl API FL 4.7 Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD * 100% Gas In Air =10,000 Units Connection (max) C-5n C-5i C-1 00660 0 0 Gas Summary C-2 Zachary Beekman C-3 0 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: 2731 10 22540 Chromatograph (ppm) 00 0 0 Minimum C-4i 4582' 7311' observed during the last 24 hours was 202 units at a depth of 4582' MD. Continue to drill ahead with the 12 1/4" intermediate hole from 4391' MD to 7278' MD as of midnight. The max gas 29 md. Average 0 0 0 C-4n 202 0 Depth Units* 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: 9Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL 5.0 LSND Depth Mud Type 48 Cor Solids (lb/100ft 2) 1,200 9.60 Condition Chlorides 9245' YP 2 9.35 Weight 3289' 4391' 6001' Type 20" 13 3/8" 12 1/4" (current) 68.0 14.5 23 1.167 12 Size 9 16-May-2012 24:00:00 Time: Report #: Date: ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg PV MBT MWD Summary Depth 7278' to 9290' Sh Clyst Cly 10 Ss 90 Depth in / out Smith MDSi716 PDC 160' 3274' Lithology (%) Total Charges: 6.5 Drilling Ahead Rig Activity: Flow In (spm) 763.2 $3,410.00 (ppb Eq) cP $37,120.00 Report For: Ross/Wimmer/Buchanan 87.5 7278' 9290' 2012' Current Pump & Flow Data: 7825' Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 903 213 SPP (psi) Gallons/stroke 2424 @4.23 54.2 Max @ ft Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Tuff Silt Siltst Lst Cht * Trip 907-685-0772 Unit Phone: 24 hr Recap: 20 Background Maximum 0 0 000 Depth Units* 0176 0 0 C-4n 24 hours was 176 units at a depth of 8381' MD. Continue to drill the 12 1/4" intermediate hole section from 7278' MD to 9290' MD. Max gas observed during the last 28 md. Average 0Minimum C-4i 8373' 7582' Chromatograph (ppm) 00 0 0 2557 8 21831 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: Zachary Beekman C-3 0 Gas Summary C-2 C-5n C-5i C-1 00454 0 0 100% Gas In Air =10,000 Units Connection (max) . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Cht Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 2962 @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 903 213 SPP (psi) Gallons/stroke % BTC EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $40,530.00 Report For: Ross/Wimmer/Buchanan 93.4 9290' 11625' 2335' Current Pump & Flow Data: 10109' Yesterday's Depth: Total Charges: 9.0 Circulating at TD Rig Activity: Flow In (spm) 599.2 $3,410.00 (ppb Eq) cP Depth in / out Smith MDSi716 PDC 160' 3274' Lithology (%) Ss 100 Sh Clyst Cly PV MBT MWD Summary Depth 9290' to 11625' ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg 10 17-May-2012 24:00:00 Time: Report #: Date: 16.0 27 1.167 15 Size 20" 13 3/8" 12 1/4" (current) 68.0 Weight 3289' 11625' 8336' Type 11570' YP 2 9.60 Cor Solids (lb/100ft 2) 1,500 9.60 Condition Chlorides LSND Depth Mud Type 56 ml/30min RPM mg/l Coal Gvl API FL 4.4 Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD * 100% Gas In Air =10,000 Units Connection (max) C-5n C-5i C-1 001025 1636 0 Gas Summary C-2 Zachary Beekman C-3 646 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: 14594 13 84490 Chromatograph (ppm) 96 69 1300 1719 Minimum C-4i 11584' 9553' 24 hours was 1670 units at a depth of 11584' MD. Free oil was observed on shakers once into the N-sands. Continue to drill the 12 1/4" intermediate hole from 9290' MD to TD at 11625' MD. Max gas observed during the last 183 md. Average 0 1117 0 C-4n 1670 1800 Depth Units* 48 84 165 85 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL 4.5 LSND Depth Mud Type 47 Cor Solids (lb/100ft 2) 1,200 9.80 Condition Chlorides 11625' YP 2 9.50 Weight 3289' 11625' 8336' Type 20" 13 3/8" 12 1/4" (current) 68.0 16.0 19 1.167 13 Size 11 18-May-2012 24:00:00 Time: Report #: Date: ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg PV MBT MWD Summary Depth 11625' to 11625' Sh Clyst Cly Ss 100 Depth in / out Smith MDSi716 PDC 160' 3274' Lithology (%) Total Charges: 6.0 BROOH Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP $43,940.00 Report For: Ross/Wimmer/Buchanan 11625' 11625' 0' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Tuff Silt Siltst Lst Cht * Trip 907-685-0772 Unit Phone: 24 hr Recap: Background Maximum 0 0 000 Depth Units* 0 0 0 C-4n Backream out of the hole at drill rate per K&M from 11625' MD to 6537' MD as of midnight. Monitor well periodically. Static. Circulate two bottoms up at TD of 11625' MD at 900 gpm, 2920 psi, and 120 rpm. Follow K&M circulating schedule. md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: Zachary Beekman C-3 0 Gas Summary C-2 C-5n C-5i C-1 000 0 0 100% Gas In Air =10,000 Units Connection (max) . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Cht Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $47,350.00 Report For: Ross/Wimmer/Buchanan 11625' 11625' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: M/U BHA #4 Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP Depth in / out Smith MDSi716 PDC 160' 3274' Lithology (%) Ss 100 Sh Clyst Cly PV MBT MWD Summary Depth 11625' to 11625' ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg 12 19-May-2012 24:00:00 Time: Report #: Date: 20 1.167 14 Size 20" 13 3/8" 12 1/4" (current) 68.0 Weight 3289' 11625' 8336' Type 11625' YP 2 9.40 Cor Solids (lb/100ft 2) 9.80 Condition Chlorides LSND Depth Mud Type 50 ml/30min RPM mg/l Coal Gvl API FL Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD * 100% Gas In Air =10,000 Units Connection (max) C-5n C-5i C-1 000 0 0 Gas Summary C-2 Zachary Beekman C-3 0 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i elevators to 2704' MD. Pump a dry job. Pull out of the hole. Lay down the BHA. Flush the BOP stack. Perform a derrick inspection. Continue to backream out of the hole from 6537' MD to 2995' MD. Monitor the well. Static. Pull out of the hole on md. Average 0 0 0 C-4n Make up BHA #4 as of midnight. 0 Depth Units* 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL LSND Depth Mud Type 53 Cor Solids (lb/100ft 2) 9.90 Condition Chlorides 11625' YP 2 9.50 Weight 3289' 11625' 8336' Type 20" 13 3/8" 12 1/4" (current) 68.0 22 1.167 14 Size 13 20-May-2012 24:00:00 Time: Report #: Date: ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg PV MBT MWD Summary Depth 11625' to 11625' Sh Clyst Cly Ss 100 Depth in / out Smith MDSi716 PDC 160' 3274' Lithology (%) Total Charges: POOH Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP $50,760.00 Report For: Ross/Wimmer/Buchanan 11625' 11625' 0' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Tuff Silt Siltst Lst Cht * Trip 907-685-0772 Unit Phone: 24 hr Recap: Background Maximum 0 0 000 Depth Units* 0 hole with elevators to 10740' MD. Backream out of the hole and MWD log to 10185' MD. Blow down the top drive and monitor the well as of midnight. 0 0 C-4n bottom at 11625' MD. Circulate. Drip a carbide test down the drill string and circulate it to surface. Monitor well. Static. Pull out of Run in the hole with BHA #4 to 3185' MD. Cut and slip drill line. Run in the hole to 10931' MD. Ream in hole and tag md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: Zachary Beekman C-3 0 Gas Summary C-2 C-5n C-5i C-1 000 0 0 100% Gas In Air =10,000 Units Connection (max) . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Cht Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 20.0 @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $54,170.00 Report For: Ross/Wimmer/Buchanan 11625' 11625' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: M/U 9 5/8" shoe Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP Depth in / out Smith MDSi716 PDC 160' 3274' Lithology (%) Ss 100 Sh Clyst Cly PV MBT MWD Summary Depth 11625' to 11625' ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg 14 21-May-2012 24:00:00 Time: Report #: Date: 52.80 23 1.167 14 Size 20" 13 3/8" 12 1/4" (current) 68.0 Weight 3289' 11625' 8336' Type 11625' YP 2 9.60 2-6-BT-S-X-I-RO-TD Cor Solids (lb/100ft 2) 9.90 Condition 120.0 Chlorides LSND Depth Mud Type 49 ml/30min RPM mg/l Coal Gvl API FL Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD * 100% Gas In Air =10,000 Units Connection (max) C-5n C-5i C-1 000 0 0 Gas Summary C-2 Zachary Beekman C-3 0 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i Circulate two bottoms up at 800 gpm, 1400 psi, and 120 rpm. Pump a 30 bbl 11.1 ppg dry job. Pull out of the hole and lay down Pull out of the hole from 10185' MD to 9344' MD and pump a 30 bbl, 10.8 ppg dry job. Pull out of the hole to 3185' MD. md. Average 0 0 0 C-4n the BHA at 292' MD. Pull wear bushing. Change top rams to 9 5/8" and test. Rig up Tesco casing equipment. Make up 9 5/8" shoe track as of midnight. 0 Depth Units* 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL LSND Depth Mud Type 63 2-6-BT-S-X-I-RO-TD Cor Solids (lb/100ft 2) 9.80 Condition 120.0 Chlorides 11600' 11625' YP 2 9.60 Weight 40.0 L-80 3289' 11625' 8336' Type 20" 13 3/8" 12 1/4" (current) 68.0 52.80 23 1.167 15 Size 15 22-May-2012 24:00:00 Time: Report #: Date: ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg PV MBT MWD Summary Depth 11625' to 11625' Sh Clyst Cly 9 5/8" Ss 100 Depth in / out Smith MDSi716 PDC 160' 3274' Lithology (%) Total Charges: Fill 9 5/8" Csg Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP $57,580.00 Report For: Keener/Wimmer/Buchanan 11625' 11625' 0' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR Hydril 563 % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft 20.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Tuff Silt Siltst Lst Cht * Trip 907-685-0772 Unit Phone: 24 hr Recap: Background Maximum 0 0 000 Depth Units* 0 Rig up the cement head and circulating equipment. A prejob safety meeting was held before filling 9 5/8" casing. 360 bbls of cement was pumped at 3 bpm and 50 psi as of midnight. 0 0 C-4n use as the active pit. Move all other fluid to other surface pits and vac truck. Dump volume as needed. Rig down Tesco equipment. Float 9 5/8" casing to 11600' MD per K&M rep. Correct displacement was observed, 294 joints total. Isolate pit 4 to md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: Zachary Beekman C-3 0 Gas Summary C-2 C-5n C-5i C-1 000 0 0 100% Gas In Air =10,000 Units Connection (max) . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Cht Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 20.0 @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC EVAMAR Hydril 563 ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $60,990.00 Report For: Keener/Smith/Buchanan 11625' 11625' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: N/U Stack Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP Depth in / out Smith MDSi716 PDC 160' 3274' Lithology (%) 9 5/8" Ss 100 Sh Clyst Cly PV MBT MWD Summary Depth 11625' to 11625' ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg 16 23-May-2012 24:00:00 Time: Report #: Date: 52.80 18 1.167 11 Size 20" 13 3/8" 12 1/4" (current) 68.0 Weight 40.0 L-80 3289' 11625' 8336' Type 11600' 11625' YP 2 9.60 2-6-BT-S-X-I-RO-TD Cor Solids (lb/100ft 2) 9.50 Condition 120.0 Chlorides LSND Depth Mud Type ml/30min RPM mg/l Coal Gvl API FL Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD * 100% Gas In Air =10,000 Units Connection (max) C-5n C-5i C-1 000 0 0 Gas Summary C-2 Zachary Beekman C-3 0 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i losses were noted. Pumped 70 bbls of 10.5 ppg mudpush, 205 bbls cement, and 10 bbls of water. Chased with 9.6 ppg LSND to Continue to fill casing at 3 bpm and 50 psi. Circulate and condition 3.5 bottoms up at 50 spm and 460 psi and no md. Average 0 0 0 C-4n 8643 strokes. Plug not bumped. FCP: 480 psi, check floats. OK. CIP: 13:30. No losses noted. Inject test: final psi 600. Rig down the cement head. Nipple down BOP. Cut the 9 5/8" casing. Set packoff. Nipple up the BOP as of midnight. 0 Depth Units* 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL LSND Depth Mud Type 2-6-BT-S-X-I-RO-TD Cor Solids (lb/100ft 2) 10.70 Condition 120.0 Chlorides 11600' 11625' YP 2 9.40 Weight 40.0 L-80 3289' 11625' 8336' Type 20" 13 3/8" 12 1/4" (current) 68.0 52.80 25 1.167 15 Size 17 24-May-2012 24:00:00 Time: Report #: Date: ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg PV MBT MWD Summary Depth 11625' to 11625' Sh Clyst Cly 9 5/8" Ss 100 Depth in / out Smith MDSi716 PDC 160' 3274' Lithology (%) Total Charges: M/U WEI-ECD Subs Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP $64,400.00 Report For: Keener/Smith/Buchanan 11625' 11625' 0' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR Hydril 563 % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft 20.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Tuff Silt Siltst Lst Cht * Trip 907-685-0772 Unit Phone: 24 hr Recap: Background Maximum 0 0 000 Depth Units* 0 over pipe. Cement contaminated mud observed at shakers. Run in hole and circulate at 7000', 8969', and 10089' MD. Circulate until 9.4 ppg mud in and out. Pump a dry job. Pull out of hole and install WEI subs each stand. 0 0 C-4n rams to variables. Fill stack and test casing to 1000 psi for 15 minutes. OK. Run in hole with 5" drill pipe. Circulate due to mud run Nipple BOP and test. Test packoff: 2470 psi. OK. Freeze protect 13 3/8" x 9 5/8" annulus with 196 bbls diesel. Change md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: Zachary Beekman C-3 0 Gas Summary C-2 C-5n C-5i C-1 000 0 0 100% Gas In Air =10,000 Units Connection (max) . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Cht Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC EVAMAR Hydril 563 ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $67,810.00 Report For: Keener/Smith/Buchanan 11625' 11625' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: R/H w/ 5" drill pipe Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP Depth in / out 160' 3274' Lithology (%) 9 5/8" Ss 100 Sh Clyst Cly PV MBT MWD Summary Depth 11625' to 11625' ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg 18 25-May-2012 24:00:00 Time: Report #: Date: 11 6 Size 20" 13 3/8" (current) 68.0 Weight 40.0 L-80 Type 11600' 11625' YP 9.40 Cor Solids (lb/100ft 2) 10.20 Condition Chlorides LSND Depth Mud Type 39 ml/30min RPM mg/l Coal Gvl API FL Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD * 100% Gas In Air =10,000 Units Connection (max) C-5n C-5i C-1 000 0 0 Gas Summary C-2 Zachary Beekman C-3 0 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i plug and set the wear ring. Pick up mule shoe and run in the hole with 10 stands of 5" drill pipe to install WEI-ECD subs as of Pull out of the hole and install the WEI-ECD subs on each stand from 9249' MD. Rig up and test BOPE's. Pull the test md. Average 0 0 0 C-4n midnight. All Sperry gas equipment was calibrated and ready for the lateral section. 0 Depth Units* 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL LSND Depth Mud Type 68 Cor Solids (lb/100ft 2) Condition Chlorides 11600' 11625' YP 3 9.45 Weight 40.0 L-80 11625' Type 20" 13 3/8" 8.35" (current) 68.0 28 0.900 15 Size 19 26-May-2012 24:00:00 Time: Report #: Date: ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg PV MBT MWD Summary Depth 11625' to 11625' Sh Clyst Cly 9 5/8" Ss 100 Depth in / out Hycalog SKH616M-E1D 160' 3274' Lithology (%) Total Charges: Wash down std #116 Rig Activity: Flow In (spm) $3,410.00 (ppb Eq) cP $71,220.00 Report For: Keener/Smith/Buchanan 11625' 11625' 0' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR Hydril 563 % BTC Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade L-80 Tuff Silt Siltst Lst Cht * Trip 907-685-0772 Unit Phone: 24 hr Recap: Background Maximum 0 0 000 Depth Units* 0 the 5" drill pipe handling equipment. Run in hole with 5" drill pipe and wash down to 11331' MD at 5 bpm and 850 psi as of midnight. 0 0 C-4n Change over handling equipment to 4.5" drill string. Pick up 4.5" drill pipe to 9374' MD while filling pipe every 20 stands. Rig up Pull out of the hole and install WEI-ECD subs at each stand. Service rig and equipment. Make up 8 3/4" BHA #5. md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Zachary Beekman / Matt Smith (max) (current) Report By: Zachary Beekman C-3 0 Gas Summary C-2 C-5n C-5i C-1 000 0 0 100% Gas In Air =10,000 Units Connection (max) . . Density (ppg) Viscosity out (sec/qt) 20" 9 5/8" BTC MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type Set At Size 178.9 X-65 Casing Summary Cly Siltst Area: Location: 96% 529 125 SPP (psi) Gallons/stroke 3230 ROP (ft/hr) 13 3/8" @ Yesterday's Depth: 210.1 Rig: Job No.: Condition in Mud Data % ROP RPM Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 11717'79.9 4.23 11625' 11857' 232' Current Depth: 24 Hour Progress: Drilling Ahead Rig Activity: Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 11857' Avg to 11625' $3,410.00 9.9 Alkal Lime $74,630.00 684.7 Report For: 160' 3274' Tuff Gvl Coal Lithology (%) (current) Sh Clyst Ss Cht Silt Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 0.900 15 47 8.35" 232' PV cP Hycalog SKH616M-E1D Ratio 20 27-May-2012 24:00:00 Time: Report #: Date: Customer: Well: 68.0 Weight Size Hours Type 65/35 10 9.40 150.0 3 11803' FazePro 100 HYDRIL YP Cor Solids (lb/100ft 2) 2.73 2.10 Mud (lb/bbl) ml/30min Depth Mud Type Lst 10.84 Avg Min Max ECD (ppg) Tools API FL 20.0 11625' WOB EVAMAR * Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) 907-685-0772 Unit Phone: 23 Zachary Beekman 50904 389 23 11211 45 121 19 76 1007 27 437 11751'Minimum Depth 11838' C-2 md. Units* 22 equipment. Drill float collar at 11512' MD, shoe at 11597' MD, and 20' of new formation to 11645' MD. Circulate and condition the Circulate at 11424' MD. Casing pressure test for 30 minutes at 3000 psi. OK. Displace LSND to OBM. Clean surface 176 Gas Summary 0 mud. Perform LOT to 12.2 ppg EMW. Drill ahead with tapered string: 5" with WEI ECD subs and 4.5" drill pipe at 550 gpm, 3260 psi, and 90 rpm. The max gas observed during the last 24 hours was 437 units at a depth of 11383' MD. 9 127 52 C-5n C-1 C-5i 23 108 24 C-4i C-4n C-3 951 Trip Average 24 hr Recap: 36 Background (max) Chromatograph (ppm) 100% Gas In Air =10,000 Units Connection 233 . . Density (ppg) Viscosity out (sec/qt) EVAMAR ECD (ppg) Tools API FL 10.0 11625' WOB 11.46 Avg Min Max Mud (lb/bbl) ml/30min Depth Mud Type Lst 100 HYDRIL YP Cor Solids (lb/100ft 2) 2.08 1.60 9.30 180.0 3 13854' FazePro Type 65/35 16 Customer: Well: 68.0 Weight Size Hours Hycalog SKH616M-E1D Ratio 21 28-May-2012 24:00:00 Time: Report #: Date: 0.900 16 47 8.35" 2391' PV cP Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 Lithology (%) (current) Sh Clyst Ss Cht Silt 160' 3274' Tuff Gvl Coal $3,410.00 10.9 Alkal Lime $78,040.00 641.2 Report For: Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 14016' Avg to 11857' 11857' 14016' 2159' Current Depth: 24 Hour Progress: Drilling Ahead Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 13183'100.3 4.23 ROP RPM % Condition in Mud Data @ Yesterday's Depth: 3.3 Rig: Job No.: ROP (ft/hr) 13 3/8" Area: Location: 96% 546 129 SPP (psi) Gallons/stroke 3398 Cly Siltst Set At Size 178.9 X-65 Casing Summary MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type 20" 9 5/8" BTC * 100% Gas In Air =10,000 Units Connection 445 Chromatograph (ppm) 24 hr Recap: 120 Background (max) Average Trip 58 200 C-4i C-4n C-3 110 382 88 C-1 C-5i C-5n 64 314 175 background has been 100 units during past 24 hours. the last 24 hours was 1642 units at a depth of 13204' MD. Average gas during the last 24 hours was 494 units. The average Continue drilling ahead from 11857' MD to 14016' MD at 550 gpm, 3430 psi, and 180 rpm. Max gas observed during 494 Gas Summary 32 md. Units* 30 13204' C-2 1642 13662'Minimum Depth 71 43596 175 274 68 272 2163 90049 674 54 907-685-0772 Unit Phone: 96 Zachary Beekman Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) . . Density (ppg) Viscosity out (sec/qt) 20" 9 5/8" BTC MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type Set At Size 178.9 X-65 Casing Summary Cly Siltst Area: Location: 96% 533 126 SPP (psi) Gallons/stroke 3609 ROP (ft/hr) 13 3/8" @ Yesterday's Depth: 284.2 Rig: Job No.: Condition in Mud Data % ROP RPM Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 14024'91.8 4.23 14016' 16104' 2088' Current Depth: 24 Hour Progress: Drilling Ahead Rig Activity: Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 16104' Avg to 14016' $3,410.00 11.6 Alkal Lime $81,450.00 599.0 Report For: 160' 3274' Tuff Gvl Coal Lithology (%) (current) Sh Clyst Ss Cht Silt Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 0.900 15 47 8.35" 4479' PV cP Hycalog SKH616M-E1D Ratio 22 29-May-2012 24:00:00 Time: Report #: Date: Customer: Well: 68.0 Weight Size Hours Type 66/34 17 9.30 180.0 3 16021' FazePro 100 HYDRIL YP Cor Solids (lb/100ft 2) 2.08 1.60 Mud (lb/bbl) ml/30min Depth Mud Type Lst 11.87 Avg Min Max ECD (ppg) Tools API FL 10.0 11625' WOB EVAMAR * Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) 907-685-0772 Unit Phone: 127 Zachary Beekman 99227 789 8 52777 205 353 12 293 208 11 1709 14043'Minimum Depth 15102' C-2 md. Units* 25 max gas observed during the last 24 hours was 1709 units at a depth of 15102' MD. The average background gas during the last Continue drilling ahead with the tapered string and WEI ECD subs from 14016' MD to 16104' MD as of midnight. The 678 Gas Summary 10 24 hours was 97 units. 14 410 229 C-5n C-1 C-5i 148 410 20 C-4i C-4n C-3 83 241 Trip Average 24 hr Recap: 65 Background (max) Chromatograph (ppm) 100% Gas In Air =10,000 Units Connection 542 . . Density (ppg) Viscosity out (sec/qt) EVAMAR ECD (ppg) Tools API FL 7.0 11625' WOB 12.30 Avg Min Max Mud (lb/bbl) ml/30min Depth Mud Type Lst 100 HYDRIL YP Cor Solids (lb/100ft 2) 1.82 1.40 9.30 170.0 3 18343' FazePro Type 36.10 67/33 17 Customer: Well: 68.0 Weight Size Hours Hycalog SKH616M-E1D Ratio 23 30-May-2012 24:00:00 Time: Report #: Date: 0.900 15 47 8.35" 6725' PV cP Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 Lithology (%) (current) Sh Clyst Ss Cht Silt 160' 3274' Tuff Gvl Coal $3,410.00 12.0 Alkal Lime $84,860.00 607.3 Report For: Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 18350' Avg to 16104' 16104' 18350' 2246' Current Depth: 24 Hour Progress: Drilling Ahead Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 17575'103.3 4.23 ROP RPM % Condition in Mud Data @ Yesterday's Depth: 210.7 Rig: Job No.: ROP (ft/hr) 13 3/8" Area: Location: 96% 512 121 SPP (psi) Gallons/stroke 3695 Cly Siltst Set At Size 178.9 X-65 Casing Summary MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type 20" 9 5/8" BTC * 100% Gas In Air =10,000 Units Connection 703 Chromatograph (ppm) 24 hr Recap: 113 Background (max) Average Trip 93 277 C-4i C-4n C-3 167 494 88 C-1 C-5i C-5n 81 511 272 background gas for the last 24 hours was 107 units. 18350' MD as of midnight. Max gas observed during the last 24 hours was 1608 units at a depth of 16382' MD. The average Continue drilling from 16104' MD to 16977' MD. Stop to trouble shoot MWD tools. Continue drilling from 16977' MD to 789 Gas Summary 49 md. Units* 73 16382' C-2 1608 17514'Minimum Depth 54 62125 236 455 64 333 2792 163275 1132 44 907-685-0772 Unit Phone: 146 Zachary Beekman Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) . . Density (ppg) Viscosity out (sec/qt) 20" 9 5/8" BTC MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type Set At Size 178.9 X-65 Casing Summary Cly Siltst Area: Location: 96% 503 119 SPP (psi) Gallons/stroke 3713 ROP (ft/hr) 13 3/8" @ Yesterday's Depth: 82.5 Rig: Job No.: Condition in Mud Data % ROP RPM Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 19262'65.4 4.23 18350' 19825' 1475' Current Depth: 24 Hour Progress: Drilling Ahead Rig Activity: Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 19825' Avg to 18350' $3,410.00 11.9 Alkal Lime $88,270.00 687.6 Report For: 160' 3274' Tuff Gvl Coal Lithology (%) (current) Sh Clyst Ss Cht Silt Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 0.900 15 47 8.35" 8200' PV cP Hycalog SKH616M-E1D Ratio 24 31-May-2012 24:00:00 Time: Report #: Date: Customer: Well: 68.0 Weight Size Hours Type 67/33 17 9.30 3 19774' FazePro 100 HYDRIL YP Cor Solids (lb/100ft 2) 2.22 1.71 Mud (lb/bbl) ml/30min Depth Mud Type Lst 12.30 Avg Min Max ECD (ppg) Tools API FL 11625' WOB EVAMAR * Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) 907-685-0772 Unit Phone: 146 Zachary Beekman 137892 1122 20 28945 120 459 26 165 1630 22 1389 19773'Minimum Depth 18383' C-2 md. Units* 41 tools. Drill ahead from 19305' MD to 19402' MD. Troubleshoot communication issues with MWD tools. Drill ahead from 19402' MD Continue drilling ahead from 18350' MD to 19262' MD. Troubleshoot MWD communication issues with downhole 381 Gas Summary 19 to 19594' MD. Troubleshoot #1 and #2 motors (ground fault on #2 generator). Drill ahead from 19402' MD to 19633' MD. Troubleshoot motors (remove doors on rig to aid in air circulation). Drilled ahead from 19633' MD to 19825' MD as of midnight Max gas observed during the last 24 hours was 1389 units at a depth of 18383' MD. 32 514 271 C-5n C-1 C-5i 88 242 37 C-4i C-4n C-3 49 143 Trip Average 24 hr Recap: 65 Background (max) Chromatograph (ppm) 100% Gas In Air =10,000 Units Connection 710 . . Density (ppg) Viscosity out (sec/qt) EVAMAR ECD (ppg) Tools API FL 11625' 21100' WOB Avg Min Max Mud (lb/bbl) ml/30min Depth Mud Type Lst 90 HYDRIL YP Cor Solids (lb/100ft 2) 1.63 1.25 9.30 3 21100' FazePro Type 67/33 17 Customer: Well: 68.0 Weight Size Hours Hycalog SKH616M-E1D Ratio 25 1-Jun-2012 24:00:00 Time: Report #: Date: 0.900 14 48 8.35" 9475' PV cP Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 Lithology (%) (current) Sh Clyst Ss Cht Silt 160' 3274' Tuff Gvl Coal $3,410.00 12.0 Alkal Lime $91,680.00 434.7 Report For: Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 21100' Avg to 19825' 19825' 21100' 1275' Current Depth: 24 Hour Progress: BROOH Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 20461'51.9 4.23 ROP RPM % Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) 13 3/8" Area: Location: 96% 503 119 SPP (psi) Gallons/stroke 3845 Cly 10 Siltst Set At Size 178.9 X-65 Casing Summary MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type 20" 9 5/8" BTC * 100% Gas In Air =10,000 Units Connection 242 Chromatograph (ppm) 24 hr Recap: 24 Background (max) Average Trip 28 81 C-4i C-4n C-3 50 139 49 C-1 C-5i C-5n 35 186 98 24 hours was 506 units at a depth of 20150' MD. well for ten minutes. Backream out of the hole from 21100' MD to 20848' MD as of midnight. The max gas observed during the last Continue drilling ahead from 19825' MD to TD at 21100' MD. Shoot a survey as per Schlumberger, then monitor the 198 Gas Summary 1 md. Units* 43 20150' C-2 506 20585'Minimum Depth 33 17538 66 160 36 88 1708 56088 429 28 907-685-0772 Unit Phone: 54 Zachary Beekman Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) . . Density (ppg) Viscosity out (sec/qt) EVAMAR ECD (ppg) Tools API FL 11625' 21100' WOB Avg Min Max Mud (lb/bbl) ml/30min Depth Mud Type Lst HYDRIL YP Cor Solids (lb/100ft 2) 2.02 1.55 9.30 3 21100' FazePro Type 67/33 15 Customer: Well: 68.0 Weight Size Hours Hycalog SKH616M-E1D Ratio 26 2-Jun-2012 24:00:00 Time: Report #: Date: 0.900 15 47 8.35" 9475' PV cP Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 Lithology (%) (current) Sh Clyst Ss Cht Silt 160' 3274' Tuff Gvl Coal $3,110.00 12.5 Alkal Lime $94,790.00 Report For: Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 21100' Avg to 21100' 21100' 21100' 0' Current Depth: 24 Hour Progress: Running in hole Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 ROP RPM % Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) 13 3/8" Area: Location: 96% 508 120 SPP (psi) Gallons/stroke 3844 Cly Siltst Set At Size 178.9 X-65 Casing Summary MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type 20" 9 5/8" BTC * 100% Gas In Air =10,000 Units Connection 0 Chromatograph (ppm) 24 hr Recap: Background (max) Average Trip 00 C-4i C-4n C-3 00 0 C-1 C-5i C-5n 0 0 0 19212' MD. Replace WEI hammer union o-ring seal. Backream out of the hole from 19212' MD to 17670' MD. Line up on the WEI manifold and shoot surveys at 17670' MD as per MWD/DD to test the signal strength. Ream in hole from 17670' MD to 20400' MD as of midnight. 2 stands per bottoms up for the next 5 stands, break out and lay down the WEI subs. Backream out of the hole from 21174' MD to Backream out of the hole from 21100' MD to 21174' MD. Circulate 1 bottoms up per stand for the first 5 stands, then Gas Summary 0 md. Units* C-2 Minimum Depth 0 0 0 0 0 0 0 0 0 0 907-685-0772 Unit Phone: 0 Zachary Beekman Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) . . Density (ppg) Viscosity out (sec/qt) EVAMAR ECD (ppg) Tools API FL 11625' 21100' WOB Avg Min Max Mud (lb/bbl) ml/30min Depth Mud Type Lst HYDRIL YP Cor Solids (lb/100ft 2) 2.08 1.60 9.30 3 21100' FazePro Type 67/33 15 Customer: Well: 68.0 Weight Size Hours Hycalog SKH616M-E1D Ratio 27 3-Jun-2012 24:00:00 Time: Report #: Date: 0.900 15 48 8.35" 9475' PV cP Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 Lithology (%) (current) Sh Clyst Ss Cht Silt 160' 3274' Tuff Gvl Coal $3,110.00 12.4 Alkal Lime $98,200.00 Report For: Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 21100' Avg to 21100' 21100' 21100' 0' Current Depth: 24 Hour Progress: BROOH Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 ROP RPM % Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) 13 3/8" Area: Location: 96% 541 128 SPP (psi) Gallons/stroke 3276 Cly Siltst Set At Size 178.9 X-65 Casing Summary MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type 20" 9 5/8" BTC * 100% Gas In Air =10,000 Units Connection 0 Chromatograph (ppm) 24 hr Recap: Background (max) Average 52 Trip 00 C-4i C-4n C-3 00 0 C-1 C-5i C-5n 0 0 0 of the hole from 18570' MD to 15650' MD. Noticed signs of packing off at 16085' MD and reamed the area two times. Continue to backream out of the hole from 15650' MD to 13538' MD as of midnight. Max gas observed after reaming back to bottom was 52u. service on the top drive. Backream out of the hole from 21100' MD to 18570' MD. Performed a fire drill. Conitnue to backream out Ream in hole from 20400' MD to 21100' MD. Schlumberger performed their telemetry test and the rig performed Gas Summary 0 md. Units* C-2 Minimum Depth 0 0 0 0 0 0 0 0 0 0 907-685-0772 Unit Phone: 0 Zachary Beekman Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) . . Density (ppg) Viscosity out (sec/qt) 20" 9 5/8" BTC MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type Set At Size 178.9 X-65 Casing Summary Cly Siltst Area: Location: 96% SPP (psi) Gallons/stroke ROP (ft/hr) 13 3/8" @ Yesterday's Depth: Rig: Job No.: Condition in Mud Data % ROP RPM Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 21100' 21100' 0' Current Depth: 24 Hour Progress: BROOH Rig Activity: Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 21100' Avg to 21100' $2,810.00 16.0 Alkal Lime $101,010.00 Report For: 160' 3274' Tuff Gvl Coal Lithology (%) (current) Sh Clyst Ss Cht Silt Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 0.900 14 47 8.35" 9475' PV cP Hycalog SKH616M-E1D Ratio 28 4-Jun-2012 24:00:00 Time: Report #: Date: Customer: Well: 68.0 Weight Size Hours Type 67/33 16 9.30 3 21100' FazePro HYDRIL YP Cor Solids (lb/100ft 2) 1.95 1.50 Mud (lb/bbl) ml/30min Depth Mud Type Lst Avg Min Max ECD (ppg) Tools API FL 11625' 21100' WOB EVAMAR * Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) 907-685-0772 Unit Phone: 0 Zachary Beekman 0 0 0 0 0 0 0 0 0 0Minimum Depth C-2 md. Units* while doing two bottoms up. Observe the well. Static. Backream out of the hole from 11600' MD to 10642' MD. Performed a man Continue backreaming out of the hole from 13538' MD to the shoe at 11600' MD. Circulate and reciprocate at the shoe Gas Summary 0 down drill. Backream out of the hole from 10642' MD to 9375' MD. Change out the saver sub and rid down the 5" equipment. Rig up the 4.5" equipment. Backream out of the hole from 9375' MD to 5000' MD. Monitor well for 10 minutes. Well static. Pull out of hole on elevators as per K&M schedule monitoring the well for swabbing from 5000' MD to 4534' MD as of midnight. 0 0 0 C-5n C-1 C-5i 00 0 C-4i C-4n C-3 00 Trip Average 24 hr Recap: Background (max) Chromatograph (ppm) 100% Gas In Air =10,000 Units Connection 0 . . Density (ppg) Viscosity out (sec/qt) EVAMAR ECD (ppg) Tools API FL 10.0 11625' 21100' WOB Avg Min Max Mud (lb/bbl) ml/30min Depth Mud Type Lst HYDRIL YP 1-1-CT-A-X-I-NO-TD Cor Solids (lb/100ft 2) 1.95 1.50 9.30 150.0 3 21100' FazePro Type 54.60 67/33 15 Customer: Well: 68.0 Weight Size Hours Hycalog SKH616M-E1D Ratio 29 5-Jun-2012 24:00:00 Time: Report #: Date: 0.900 15 48 8.35" 9475' PV cP Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 Lithology (%) (current) Sh Clyst Ss Cht Silt 160' 3274' Tuff Gvl Coal $2,810.00 12.3 Alkal Lime $103,820.00 Report For: Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 21100' Avg to 21100' 21100' 21100' 0' Current Depth: 24 Hour Progress: RIH w/ 5 1/2"Slotted Liner Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 ROP RPM % Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) 13 3/8" Area: Location: 96% SPP (psi) Gallons/stroke Cly Siltst Set At Size 178.9 X-65 Casing Summary MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type 20" 9 5/8" BTC * 100% Gas In Air =10,000 Units Connection 0 Chromatograph (ppm) 24 hr Recap: Background (max) Average Trip 00 C-4i C-4n C-3 00 0 C-1 C-5i C-5n 0 0 0 and rig up 5.5" slotted liner running equipment. Pre-job safety meeting for running slotted liner. Begin running in hole with 5.5" slotted liner. Run slotted liner to 6734' MD as of midnight. wear bushing and install test plug. Rig up and test rams. Pull test plug and install wear bushing and change out saver sub. Pick up Continue to pull out of hole on elevators as per K&M schedule from 4534' MD to 270' MD. Lay down BHA #5. Pull the Gas Summary 0 md. Units* C-2 Minimum Depth 0 0 0 0 0 0 0 0 0 0 907-685-0772 Unit Phone: 0 Matt Smith Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) . . Density (ppg) Viscosity out (sec/qt) 20" 9 5/8" BTC MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type Set At Size 178.9 X-65 Casing Summary Cly Siltst Area: Location: 96% SPP (psi) Gallons/stroke ROP (ft/hr) 13 3/8" @ Yesterday's Depth: Rig: Job No.: Condition in Mud Data % ROP RPM Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 21100' 21100' 0' Current Depth: 24 Hour Progress: Clean pits Rig Activity: Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 21100' Avg to 21100' $2,810.00 Alkal Lime $106,630.00 Report For: 160' 3274' Tuff Gvl Coal Lithology (%) (current) Sh Clyst Ss Cht Silt Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 0.900 8.35" 9475' PV cP Hycalog SKH616M-E1D Ratio 30 6-Jun-2012 24:00:00 Time: Report #: Date: Customer: Well: 68.0 Weight Size Hours Type 54.60 9.00 150.0 3 21100' Brine HYDRIL YP 1-1-CT-A-X-I-NO-TD Cor Solids (lb/100ft 2)Mud (lb/bbl) ml/30min Depth Mud Type Lst Avg Min Max ECD (ppg) Tools API FL 10.0 11625' 21100' WOB EVAMAR * Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) 907-685-0772 Unit Phone: 0 Matt Smith 0 0 0 0 0 0 0 0 0 0Minimum Depth C-2 md. Units* brine to pits. P/U single and tag bottom at 21100' MD. Set liner at 21097' MD. Top at 11391' MD. Drop ball 1645 strokes to seat RIH w/ %.%" slotted liner. P/U Liner hanger. Run liner in hole on 5" DP f/ 9720' MD to 21093' MD. Take on 625 bbl 9.0 Gas Summary 0 ball. Pull out of liner hanger. Slip and cut drill line, adjust breaks. Displace with 9.0ppg brine. 0 0 0 C-5n C-1 C-5i 00 0 C-4i C-4n C-3 00 Trip Average 24 hr Recap: Background (max) Chromatograph (ppm) 100% Gas In Air =10,000 Units Connection 0 . . Density (ppg) Viscosity out (sec/qt) 20" 9 5/8" BTC MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 11600' Bit Type Set At Size 178.9 X-65 Casing Summary Cly Siltst Area: Location: 96% SPP (psi) Gallons/stroke ROP (ft/hr) 13 3/8" @ Yesterday's Depth: Rig: Job No.: Condition in Mud Data % ROP RPM Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 21100' 21100' 0' Current Depth: 24 Hour Progress: L/D 4.5" DP Rig Activity: Ross/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 21100' Avg to 21100' $2,810.00 Alkal Lime $109,440.00 Report For: 160' 3274' Tuff Gvl Coal Lithology (%) (current) Sh Clyst Ss Cht Silt Footage ENI Petroleum SP16-FN3 Spy Island 24 hr Max North Slope AK-AM-0009113848 0.900 8.35" 9475' PV cP Hycalog SKH616M-E1D Ratio 31 7-Jun-2012 24:00:00 Time: Report #: Date: Customer: Well: 68.0 Weight Size Hours Type 54.60 9.00 150.0 3 21100'KCL/NaCl Brine HYDRIL YP 1-1-CT-A-X-I-NO-TD Cor Solids (lb/100ft 2)Mud (lb/bbl) ml/30min Depth Mud Type Lst Avg Min Max ECD (ppg) Tools API FL 10.0 11625' 21100' WOB EVAMAR * Maximum Report By: Logging Engineers: Zachary Beekman / Matt Smith (max) (current) 907-685-0772 Unit Phone: 0 Matt Smith 0 0 0 0 0 0 0 0 0 0Minimum Depth C-2 md. Units* subs. Improper hole fill, hole fill pump packed off. Fill hole with rig pumps (well static). POOH laid down 5" DP f/ 5103' to BHA. Clean surface equipment and pits of OBM. Single out of hole with 5" DP from 11391' MD to 5103'MD laid down WEI Gas Summary 0 Laid down liner running tools. L/D mule shoe. R/D 5" equipment. R/U 4.5" equipment. L/D 4.5" DP using mouse hole. 0 0 0 C-5n C-1 C-5i 00 0 C-4i C-4n C-3 00 Trip Average 24 hr Recap: Background (max) Chromatograph (ppm) 100% Gas In Air =10,000 Units Connection 0 W E L L N A M E : SP 1 6 - F N 3 LO C A T I O N : Spy Island OP E R A T O R : EN I P e t r o l e u m AR E A : North Slope MU D C O : MI S w a c o ST A T E : Alaska RI G : Do y o n 1 5 SP U D : 8-May-12 SP E R R Y J O B : AK - A M - 0 0 0 9 1 1 3 8 4 8 TD : 1-Jun-12 BI T R E C O R D MW D BH A # SD L RU N # Bi t # B i t T y p e B i t Si z e De p t h In ( f t ) De p t h Ou t ( f t ) Fo o t a g e B i t Ho u r s TF A A V G RO P WO B (m a x ) RP M (m a x ) SP P (m a x ) FL O W G P M (m a x ) Bi t G r a d e R e m a r k s 2 1 0 0 1 H u g h e s M X - 1 M i l l T o o t h 1 6 " 1 6 0 3 2 8 9 3 1 2 9 1 8 . 2 0 1 . 1 1 7 1 7 0 . 7 2 5 4 0 1 2 5 0 6 5 0 1- 1 - W T - A - I - E - N O - T D Surface TD reached 3 2 0 0 2 S m i t h M D S i 7 1 6 1 2 1 / 4 " 3 2 8 9 1 1 6 2 5 8 3 3 6 5 2 . 8 0 1 . 1 6 7 1 5 7 . 8 2 0 1 8 0 3 0 9 3 9 8 5 2 - 6 - B T - S - X - I - R O - T D I n t e r m e d i a t e T D r eached 5 3 0 0 3 H y c a l o g S K H 6 1 6 M - E 1 D 8 3 / 4 " 1 1 6 2 5 2 1 1 0 0 9 4 7 5 5 4 . 6 0 0 . 9 0 0 1 7 3 . 5 1 0 1 5 0 4 2 0 0 5 2 0 1 - 1 - C T - A - X - I - N O - T D P r o d u c t i o n TD reached W E L L N A M E : L O C A T I O N : OP E R A T O R : A R E A : MU D C O : S T A T E : RI G : S P U D : SP E R R Y J O B : T D : Mu d R e c o r d W a t e r B a s e d M u d R e c o r d 16 0 ' t o 3 , 2 8 9 ' LS N D M u d I n t e r m e d i a t e S e c t i o n 3 , 2 8 9 ' t o 1 1 , 6 2 5 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oi l / W a t e r Sd P m p H M B T P f / M f C h l o r H a r d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l m g / l C a + + 8- M a y 2 8 9 8 . 8 0 7 8 2 6 2 8 1 4 / 2 9 / 3 6 6 . 0 8 0 / 5 4 / 4 3 / 2 9 / 1 3 / 1 0 1 / - 3 . 0 0 . 0 - 0 . 0 4 9 . 3 1 2 . 5 . 0 4 / . 2 0 1 7 0 0 1 1 0 D r i l l i n g 1 6 " O p e n H o l e 9- M a y 2 1 2 3 9 . 4 0 - 2 7 3 1 1 5 / 4 3 / 5 0 4 . 6 8 5 / 5 8 / 4 7 / 3 4 / 1 7 / 1 5 1 / - 6 . 0 2 / 9 3 0 . 0 5 0 . 0 2 9 . 1 2 0 . 0 . 0 3 / . 2 7 1 9 0 0 8 0 D r illing 16" Open Hole 10 - M a y 3 2 8 9 9 . 4 0 - 2 1 2 4 1 5 / 3 2 / 4 4 5 . 2 6 6 / 4 5 / 3 2 / 2 8 / 1 5 / 1 3 1 / - 6 . 5 1 / 9 3 0 . 0 5 0 . 0 2 9 . 0 2 0 . 0 . 0 5 / . 3 0 1 0 0 0 4 0 B R O O H 11 - M a y 3 2 8 9 9 . 3 5 - 2 0 1 6 8 / 1 3 / - - - - - - - - - - - - - C e m e n t S u r f a c e C a s i n g 12 - M a y 3 2 8 9 9 . 2 0 - 1 0 2 0 6 / 1 0 / - - - - - - - - - - - - - T e s t B O P 13 - M a y 3 2 8 9 8 . 9 0 - 1 0 2 0 - - - - - - - - - - - - - P / U B H A # 3 14 - M a y 4 3 9 1 9 . 2 5 5 1 9 2 6 1 1 / 1 5 / 1 7 6 . 3 4 4 / 3 5 / 3 1 / 2 5 / 1 2 / 1 0 1 / - 4 . 0 2 / 9 4 - 0 . 2 2 9 . 9 3 . 0 . 1 7 / 1 . 1 6 7 0 0 6 0 D r illing 12.25" Open Hole 15 - M a y 7 2 7 8 9 . 3 0 6 0 1 3 3 5 1 7 / 3 3 / 4 0 4 . 7 6 1 / 4 8 / 4 1 / 3 3 / 1 7 / 1 5 1 / - 6 . 3 2 / 9 1 . 7 5 0 . 0 5 0 . 1 3 9 . 6 1 6 . 0 . 1 0 / . 9 2 1 0 0 0 6 0 D r illing 12.25" Open Hole 16 - M a y 9 2 9 0 9 . 3 5 4 8 1 2 2 3 1 0 / 2 3 / 3 0 5 . 0 4 7 / 3 5 / 3 0 / 2 4 / 1 2 / 1 0 1 / - 6 . 5 2 / 9 1 . 5 0 . 1 0 0 . 1 4 9 . 6 1 4 . 5 . 1 2 / 1 . 0 5 1 2 0 0 6 0 D r illing 12.25" Open Hole 17 - M a y 1 1 6 2 5 9 . 6 0 5 6 1 5 2 7 1 2 / 3 6 / 4 9 4 . 4 5 7 / 4 2 / 3 5 / 2 7 / 1 3 / 1 1 1 / - 9 . 0 2 / 8 9 0 . 1 0 0 . 1 2 9 . 6 1 6 . 0 . 0 9 / . 9 5 1 5 0 0 4 0 D r illing 12.25" Open Hole 18 - M a y 1 1 6 2 5 9 . 5 0 4 7 1 3 1 9 1 0 / 2 2 / 3 3 4 . 5 4 5 / 3 2 / 2 7 / 2 0 / 9 / 8 1 / - 6 . 0 2 . 5 / 9 1 . 5 0 . 0 5 0 . 1 7 9 . 8 1 6 . 0 . 1 2 / 1 . 2 3 1 2 0 0 4 0 B R O O H 19 - M a y 1 1 6 2 5 9 . 4 0 5 0 1 4 2 0 1 0 / 2 3 / - - 4 8 / 3 4 / 2 8 / 2 1 / 1 0 / 8 - - - - - 9 . 8 - - - - M / U B H A # 4 20 - M a y 1 1 6 2 5 9 . 5 0 - 1 4 2 2 9 / 2 4 / - - 5 0 / 3 6 / 2 9 / 2 2 / 9 / 8 - - - - - 9 . 9 - - - - P O O H w / B H A # 4 21 - M a y 1 1 6 2 5 9 . 6 0 4 9 1 4 2 3 9 / 2 5 / - - 5 1 / 3 7 / 3 0 / 2 2 / 9 / 8 - - - - - 9 . 9 - - - - P O O H , R / U 9 5 / 8 " C s g 22 - M a y 1 1 6 2 5 9 . 6 0 6 3 1 5 2 3 1 0 / 2 7 / - - 5 3 / 3 8 / 3 2 / 2 4 / 1 0 / 9 - - - - - 9 . 8 - - - - R u n 9 5 / 8 " C s g 23 - M a y 1 1 6 2 5 9 . 6 0 - 1 1 1 8 7 / 1 4 / - - 4 0 / 2 9 / 2 4 / 1 8 / 7 / 6 - - - - - 9 . 5 - - - - C e m e n t I n t e r m e d i a t e C s g 24 - M a y 1 1 6 2 5 9 . 4 0 6 3 1 5 2 5 1 0 / 3 9 / - - 5 5 / 4 0 / 3 3 / 2 5 / 1 1 / 1 0 - - - - - 1 0 . 7 - - - - N i p p l e D o w n , I n s t a l l W E I s u b s 25 - M a y 1 1 6 2 5 9 . 4 0 3 9 6 1 1 6 / 1 1 / 1 - - 2 3 / 1 7 / 1 3 / 1 1 / 6 / 5 - - - - - 1 0 . 2 - - - - T e s t B O P Oi l B a s e d M u d R e c o r d 11 , 6 2 5 ' t o 2 1 1 0 0 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e C or r . So l i d Oi l / W a t e r Oi l P m L i m e S a l t C l - E mu l St a b i l i t y S d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l l b / b b l % W t m g / L m g / l % v o l 26 - M a y 1 1 6 2 5 9 . 4 5 6 8 1 5 2 8 1 2 / 3 8 / - - 5 8 / 4 3 / 3 6 / 2 9 / 1 2 / 1 1 - - - - - - - - - - M / U B H A # 5 , S w i t c h t o O B M 27 - M a y 1 1 8 5 7 9 . 4 0 4 7 1 5 1 0 5 / 6 / 6 5 . 6 4 0 / 2 5 / 1 9 / 1 4 / 6 / 5 - / 2 9 . 9 1 6 5 / 3 5 5 6 2 . 1 0 2 . 7 3 3 3 . 3 7 9 6 0 0 0 3 4 0 0 . 0 0 D r illing 8.75" Open Hole 28 - M a y 1 4 0 1 6 9 . 3 0 4 7 1 6 1 6 7 / 7 / 8 5 . 0 4 8 / 3 2 / 2 5 / 1 8 / 7 / 6 - / 2 1 0 . 8 6 6 5 / 3 5 5 6 1 . 6 0 2 . 0 8 2 9 . 8 4 8 1 0 0 0 6 4 5 0 . 1 0 D r illing 8.75" Open Hole 29 - M a y 1 6 1 0 4 9 . 3 0 4 7 1 5 1 7 7 / 7 / 8 4 . 9 4 7 / 3 2 / 2 5 / 1 8 / 7 / 6 - / 1 1 1 . 6 4 6 6 / 3 4 5 6 1 . 6 0 2 . 0 8 3 0 . 4 2 8 1 0 0 0 1 0 0 0 0 . 1 0 D r illing 8.75" Open Hole 30 - M a y 1 8 4 3 9 9 . 3 0 4 7 1 5 1 7 7 / 7 / 8 4 . 7 4 7 / 3 2 / 2 6 / 1 8 / 7 / 6 - / 1 1 2 . 0 1 6 7 / 3 3 5 7 1 . 4 0 1 . 8 2 3 2 . 0 8 8 3 0 0 0 9 3 0 0 . 1 5 D r illing 8.75" Open Hole 31 - M a y 1 9 7 9 2 9 . 3 0 4 7 1 5 1 7 7 / 8 / 8 4 . 7 4 7 / 3 2 / 2 6 / 1 8 / 7 / 6 - / 1 1 1 . 8 5 6 7 / 3 3 5 7 1 . 7 1 2 . 2 2 3 2 . 8 6 8 6 0 0 0 9 4 0 0 . 1 0 D r illing 8.75" Open Hole 1- J u n 2 1 1 0 0 9 . 3 0 4 8 1 4 1 7 7 / 8 / 8 4 . 7 4 5 / 3 1 / 2 5 / 1 7 / 7 / 6 - / 1 1 2 . 0 2 6 7 / 3 3 5 7 1 . 2 5 1 . 6 3 3 1 . 6 9 8 3 0 0 0 8 7 0 0 . 1 0 D r illed 8.75" Open Hole to TD 2- J u n 2 1 1 0 0 9 . 3 0 4 7 1 5 1 5 7 / 7 / 8 4 . 9 4 5 / 3 0 / 2 3 / 1 6 / 6 / 5 - / 1 1 2 . 4 7 6 7 / 3 3 5 6 1 . 5 5 2 . 0 2 3 1 . 9 5 8 4 0 0 0 9 5 0 0 . 1 0 B R O O H 3- J u n 2 1 1 0 0 9 . 3 0 4 8 1 5 1 5 7 / 7 / 8 - 4 5 / 3 0 / 2 3 / 1 7 / 6 / 5 - / 1 1 2 . 3 7 6 7 / 3 3 5 6 1 . 6 0 2 . 0 8 3 2 . 4 6 8 6 0 0 0 - 0 . 1 0 B R O O H 4- J u n 2 1 1 0 0 9 . 3 0 4 7 1 4 1 6 7 / 7 / 8 - 4 4 / 3 0 / 2 2 / 1 6 / 5 / 4 - / - 1 6 . 0 0 6 7 / 3 3 5 6 1 . 5 0 1 . 9 5 3 2 . 4 6 8 6 0 0 0 1 0 0 0 0 . 1 0 B R O O H 5- J u n 2 1 1 0 0 9 . 3 0 4 8 1 5 1 5 7 / 8 / 8 - 4 5 / 3 0 / 2 2 / 1 7 / 6 / 5 - / - 1 2 . 3 2 6 7 / 3 3 5 6 1 . 5 0 1 . 9 5 3 2 . 7 2 8 7 0 0 0 8 9 0 0 . 1 0 R I H w / 5 . 5 " L i n e r Br i n e 6- J u n 2 1 1 0 0 9 . 0 0 - - - - - - - - - - - - - - - - C l e a n P i t s / S w i t c h t o K C l B r i n e 7- J u n 2 1 1 0 0 9 . 0 0 - - - - - - - - - - - - - 6 9 0 0 0 - - P O O H a n d L / D 5 " a n d 4 . 5 " D P SP 1 6 - F N 3 Pr o d u c t i o n S e c t i o n Sp y I s l a n d No r t h S l o p e Al a s k a 8- M a y - 1 2 1- J u n - 1 2 EN I P e t r o l e u m MI S w a c o Do y o n 1 5 9 5 / 8 " I n t e r m e d i a t e @ 1 1 , 6 0 0 ' M D Su r f a c e S e c t i o n Fa z e P r o MI S p u d M u d AK - A M - 0 0 0 9 1 1 3 8 4 8 13 3 / 8 " S u r f a c e @ 3 , 2 7 4 ' M D Ca s i n g R e c o r d 20 " C o n d u c t o r @ 1 6 0 ' M D Marker MD INC AZ TVD TVDSS 16" Surface Borehole 20" Conductor Shoe 160.00 0.90 302.00 160.00 -106.08 SV-4 776.00 19.70 311.40 765.60 -711.68 SV-3 1175.00 31.80 307.20 1122.20 -1068.28 SV-2 1501.00 44.80 306.50 1378.20 -1324.28 Permafrost Base 2040.00 42.70 309.00 1762.20 -1708.28 SV-1 2277.00 46.80 307.20 1931.00 -1877.08 Ugnu Top (UG4)2813.00 58.80 312.40 2254.00 -2200.08 13 3/8" Casing Shoe 3274.00 67.20 302.20 2440.50 -2386.58 TD 16" Borehole 3289.00 66.90 302.10 2446.40 -2392.48 12 1/4" Intermediate Borehole UG-2 Coal Bed Marker 4596.00 80.10 300.30 2740.50 -2686.58 Lower Ugnu 8369.00 80.40 302.00 3369.20 -3315.28 Schrader Bluff 9850.00 80.70 302.20 3613.40 -3559.48 N Sequence Top 9987.00 80.60 301.80 3635.80 -3581.88 N Sand Top 10254.00 80.60 302.60 3679.20 -3625.28 N-2 Top 10344.00 80.90 303.40 3693.80 -3639.88 N-3 Top 10365.00 81.00 303.60 3697.10 -3643.18 N Sand Bottom 10435.00 81.50 304.40 3707.80 -3653.88 N Sequence Base 10929.00 83.90 314.60 3768.90 -3714.98 OA Sand Top 11517.00 84.30 318.00 3824.60 -3770.68 OA-sbl2 11595.00 84.50 317.50 3832.20 -3778.28 9 5/8" Intermediate Casing 11600.00 84.40 317.40 3832.60 -3778.68 OA-sbl3 11625.00 84.20 317.40 3834.10 -3780.18 TD 12 1/4" Borehole 11625.00 84.00 317.30 3835.20 -3781.28 8 3/4" Lateral Borehole OA-sbl4 11,792.00 88.60 318.90 3,846.20 -3,792.28 OA-sbl4 11,948.00 92.90 319.30 3,844.10 -3,790.18 OA-sbl3 12,858.00 91.80 319.80 3,825.90 -3,771.98 OA-sbl2 13,115.00 91.70 321.50 3,817.80 -3,763.88 OA-sbl2 14,272.00 87.70 316.60 3,809.70 -3,755.78 OA-sbl3 14,405.00 87.20 316.50 3,817.10 -3,763.18 Fault A 14,564.00 86.60 316.00 3,825.00 -3,771.08 OA Sand Bottom 14,812.00 95.50 311.70 3,824.00 -3,770.08 OA-sbl4 14,907.00 94.60 312.40 3,815.20 -3,761.28 OA-sbl3 15,738.00 92.10 313.10 3,803.80 -3,749.88 OA-sbl2 15,900.00 91.80 313.50 3,797.80 -3,743.88 OA Sand Top 15,990.00 91.10 313.40 3,795.50 -3,741.58 OA Sand Top 16,111.00 87.80 313.60 3,797.50 -3,743.58 OA-sbl2 17,185.00 87.70 307.60 3,802.50 -3,748.58 OA-sbl3 17,369.00 87.40 311.90 3,811.50 -3,757.58 OA-sbl4 17,579.00 88.50 309.00 3,819.20 -3,765.28 OA-sbl4 17,747.00 92.70 308.20 3,816.90 -3,762.98 OA-sbl3 18,829.00 91.40 312.80 3,805.20 -3,751.28 OA-sbl2 19,033.00 92.50 313.90 3,799.20 -3,745.28 Fault B 19,498.00 88.90 315.80 3,797.80 -3,743.88 OA-sbl3 19,666.00 88.90 315.20 3,800.50 -3,746.58 OA-sbl4 20,289.00 87.20 311.90 3,810.00 -3,756.08 OA Sand Bottom 20,453.00 87.50 310.00 3,818.40 -3,764.48 OA Sand Bottom 20,707.00 94.40 308.50 3,816.80 -3,762.88 OA-sbl4 20,785.00 95.00 308.80 3,810.50 -3,756.58 TD 8 3/4" Borehole 21,100.00 89.80 309.30 3,796.50 -3,742.58 SP16-FN3 Interpolated Tops 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 11,000 12,000 13,000 14,000 15,000 16,000 17,000 18,000 19,000 20,000 21,000 22,000 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 SP16-FN3 Days vs. Depth 10 May 2012 Reached surface TD at 1350 hrs 3,289' MD / 2,446' TVD 22 May 2012 Run & Land 9 5/8" casing to 11,600' MD 1 June 2012 TD reached 21,100' MD / 3,794' TVD 11 May2012 Run & Land 13 3/8" casing to 3,274' MD 7 May 2012 SDL rig up unit and gas equipment 8 May 2012 Pre Spud Meeting and Spud well 17 May 2012 Reached intermediate TD 11,625' MD / 3,834' TVD 13 May 2012 RIH, LOT 11.4 ppg EMW, Drill ahead 27 May 2012 RIH, LOT 12.2 ppg EMW, Drill ahead Surface Data Logging After Action Review Employee Name: Zachary Beekman Date: 30 Apr 2012 Well: SP16-FN3 Hole Section: Production What went as, or better than, planned: Both gas traps functioned well. Insite and our network performed well. We were able to get a remote access feed to town so INSITE could be double checked by the ROC during the daytime. Lag was calculated properly. Difficulties experienced: We still have constant accumulations of moisture in our gas system. The WEI-ECD subs were utilized this well. We had constant pumping for 5 days, and we were not able to blow back our gas lines without relinquishing the ablilty to monitor gas in an open hole that was being pumped. We are still awating a "vortex cooler", which was ordered in Feb 2012 and is being shipped and should be here for next well. Recommendations: Blow back gas lines whenever the possibility arises. Innovations and/or cost savings: None for this section.