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214-067
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250813 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# KBU 24-06RD 50133204990100 206013 4/2/2025 YELLOWJACKET GPT-PERF MPB-24 50029226420000 196009 7/9/2025 READ CaliperSurvey MPB-34 50029235690000 216139 7/7/2025 READ CaliperSurvey MPF-45 50029225560000 195058 7/30/2025 READ CaliperSurvey ODSK-41 50703205850000 208147 8/9/2025 READ CaliperSurvey ODSN-25 50703206560000 212030 6/22/2025 READ CaliperSurvey ODSN-31 50703205650000 208003 8/11/2025 READ CaliperSurvey PBU 06-11A 50029204280100 225042 7/13/2025 BAKER MRPM PBU 13-19 50029206900000 181180 6/4/2025 HALLIBURTON WFL-TMD3D PBU 14-18C 50029205510300 225040 6/24/2025 BAKER MRPM PBU 14-43A 50029222960100 225041 7/30/2025 BAKER MRPM PBU C-01B 50029201210200 212053 7/19/2025 BAKER MRPM SD-07 50133205940000 211050 7/27/2025 YELLOWJACKET SCBL SP 12-S3 50629235130000 214067 7/18/2025 YELLOWJACKET PERF Please include current contact information if different from above. T40771 T40772 T40773 T40774 T40775 T40776 T40777 T40778 T40779 T40780 T40781 T40782 T40783 T40784SP 12-S3 50629235130000 214067 7/18/2025 YELLOWJACKET PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.15 10:11:56 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________NIKAITCHUQ SP12-SE3 JBR 09/22/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Test with 3-1/2" TJ had FP on CMV #4 Grease and cycle pass. Accumulator bottles 18 with precharge avg. 1113 psi. Was told to come out on 8/8/25 at 20:00 but they were not ready till 08/09/25 at 03:00 test start time which was past due date for test. Test Results TEST DATA Rig Rep:T. Matthews/ E. MunozOperator:Hilcorp Alaska, LLC Operator Rep:B. Bordelon/ P. Stewart Rig Owner/Rig No.:Team Snubbing TSI 101 PTD#:2140670 DATE:8/9/2025 Type Operation:WRKOV Annular: 250/2500Type Test:WKLY Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopKPS250809180422 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.25 MASP: 1008 Sundry No: 325-372 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 10 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8 P #1 Rams 1 2-7/8 x 5 P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA BOP Misc 0 NA System Pressure P2950 Pressure After Closure P1750 200 PSI Attained P17 Full Pressure Attained P129 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 1980 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P22 #1 Rams P6 #2 Rams P6 #3 Rams P1 #4 Rams P1 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 See attached email regarding late start for test - J. Regg 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:Regg, James B (OGC) To:Patrick Stewart - (C) Cc:Keith Lopez; DOA AOGCC Prudhoe Bay; Brandon Bordelon - (C) Subject:RE: TSI-101 BOPE Test 080925 Date:Monday, August 11, 2025 11:16:00 AM Thank you for the explanation. If you encounter a similar situation in the future and an Inspector is not at location, contact AOGCC as soon as you become aware that you will not be able to commence the BOPE test before midnight of the due date and request an extension. Approval of an extension is at the discretion of the AOGCC and must be justified by the operator. I think you will find that the AOGCC is very responsive when we receive timely requests in advance for extensions to weekly BOPE tests. We understand the challenges of workover operations, are willing to work with operator to ensure you remain compliant with our requirements, and frequently grant these types of extensions when appropriate. If you can’t reach an Inspector, my contact information is in this email. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Patrick Stewart - (C) <patrick.stewart@hilcorp.com> Sent: Sunday, August 10, 2025 10:32 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Keith Lopez <Keith.Lopez@hilcorp.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brandon Bordelon - (C) <Brandon.Bordelon@hilcorp.com> Subject: TSI-101 BOPE Test 080925 Good evening Sir, I wanted to follow up on our recent weekly BOPE Test. Mr. St.John recommended that I should send a note to explain why we did not start our pressure testing until 3am , 3 hours past our deadline. This is the first time I’ve been a part of, much less responsible for the operation, where there was a test that did not start within the time window. The trip out of the hole with our Test Packer Assembly from our MIT test at 4894’ MD took much longer than expected. The heavy oil on our workstring caused delays on the trip out of the hole due to slip dies becoming fouled with the heavy oil and required them to be cleaned repeatedly after only a handful of joints each time. Over the course of 9 hours we had tripped out only ~3000’ of pipe. At 8PM that evening we ceased tripping out of the hole at 1907’ MD and began the process of pulling the wear ring and setting the test plug. Operationally, our pass through of the rotary table and wiper head is 11” and required them to be laid down before retrieving the WRB. This took much longer than anticipated. At 11PM we picked up our WRB puller and after 2 attempts to J in, we were successful in pulling our WRB. At 0100 AM we had retrieved the WRB and picked up our test plug. It was not until just before 0300 hrs that we were prepared to test the BOP Stack. All told, it took us 7 hours from shutting down well work operations to testing our well control equipment. When Mr. St.John arrived on location at ~9PM, we did test Gas Alarms and PVT systems. We were prepared to test our choke manifold before midnight, however that would have operationally taken away manpower and delayed the testing process for the other well control equipment further than we were already delayed. I understand that ultimately I’m responsible for ensuring we’re testing in a timely fashion, and it was a lack of planning and understanding of how long it would take to get rigged up for testing with the string in the well. I hope this helps explain the delay in starting our weekly test. Please let me know if I can answer any questions or concerns and welcome feedback if there is any. Respectfully, Pat Stewart Hilcorp Alaska LLC. WNS - Wellsite Supervisor Cell - 907-784-4338 Email: Patrick.stewart@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________NIKAITCHUQ SP12-SE3 JBR 09/12/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:6 2 7/8" and 4.5" test joints used for testing. No audible or visual PVT by the drillers console. It was installed after I left location and a video of it in place and functioning was sent to me on 7/24/25. K-3 valve leaked at its upstream flange. The flange was tightened and it retested for a pass. CMV #8 failed. The valve was serviced and retested for a pass. Dart valve failed and was replaced for a pass. Blind rams failed. The rams were functioned and later passed after troubleshooting leak. After the leak was detected and fixed all the charts were sent to me to get approval to proceed with well work. Test Results TEST DATA Rig Rep:T. Matthews/R. RobsonOperator:Hilcorp Alaska, LLC Operator Rep:Darcy Dunbar/Pat Stewart Rig Owner/Rig No.:Team Snubbing TSI 101 PTD#:2140670 DATE:7/23/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopGDC250722133755 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 24 MASP: 1008 Sundry No: 325-372 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 FP FSV Misc 0 NA 10 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8x5.5" VB P #2 Rams 1 Blinds FP #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 2 3 1/8" 5000 FP Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1750 200 PSI Attained P22 Full Pressure Attained P125 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@ 1940 ACC Misc NA0 NA NATrip Tank FP FPPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P21 #1 Rams P7 #2 Rams P7 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9999 9 9 9 9 99 9 9 9 FP FP FP FP FP FP No audible or visual PVT by the drillers console K-3 valve leaked CMV #8 failed Dart valve failed Blind rams failed 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap and Clean-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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15,216' mainbore 15,245' lateral L1 NA Casing Collapse Conductor NA Surface 2480 Intermediate 4790 Mainbore Liner Slotted L1 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng NA 15,21610,163 5-1/2" Slotted Liners 4,050 Perforation Depth MD (ft): Slotted Liners C.O. 477 B NA 5,193 160 160 3,980 2,878 5,193 4,063 keith.lopez@hilcorp.com Operations Manager July 15, 2025 15,24510,328 4-1/2" 12.6# / L80 Keith Lopez NA 5-1/2" 160 20" 13-3/8" 9-5/8" 2,878 TVD Burst 4,589 Slotted MD NA 5210 6890 2,463 Hilcorp Alaska, LLC Length Size Proposed Pools: 4,063' mainbore 4,050' lateral L1 15,205' mainbore 15,200' lateral L1 4,063' mainbore 4,050' lateral L1 1,008 SCHRADER BLUFF OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388582, ADL0388583, ADL0390615, ADL0391283 214-067 NIKAITCHUQ SP12-SE3 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-629-23513-00-00 NIKAITCHUQ AOGCC USE ONLY Slotted Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 907-777-8438 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:03 am, Jun 20, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.06.18 13:46:09 - 08'00' Sara Hannegan (2519) 325-372 DSR-6/23/25 10-404 MGR30JUN2025 * BOPE test to 2500 psi. 48 hour notice. * 30 minute charted pressure test of IC. No witness necessary. SFD 7/12/2025JLC 7/14/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.07.14 09:17:29 -08'00'07/14/25 RBDMS JSB 071425 Well: SP-12 PTD: 214-067 API: 50-629-23513-00-00 Well Name:SP-12 API Number:50-629-23513-00-00 Current Status:Producer Rig:Team Snubbing 101 Estimated Start Date:07/15/2025 Estimated Duration:12 days Regulatory Contact:Darci Horner Permit to Drill Number:214-067 First Call Engineer:Keith Lopez (907) 777-8438 (O) (907) 903-5432 (M) Second Call Engineer:Ryan Rupert (907) 777-8503 (O) (907) 301-1736 (M) Current Bottom Hole Pressure: 1,400 psi @ 3,923’ TVD |6.9 PPGE Max Potential Surface Pressure: 1,008 psi Gas Column Gradient (0.1 psi/ft) Max Angle: Is an S-shaped well with max deviation of 63° at ESP setting depth of ~4,650’ Brief Well Summary: SP12 was drilled and completed in June 2014 as a dual lateral Schrader Bluff OA producer with an ESP completion. The well has a history of formation sanding issues. The current ESP ran for 5.4 years before plugging and getting seized on 05/30/25. Objectives: Pull ESP completion, run VAC tool to remove sand from ESP setting depth and lateral, pressure test casing, and run new ESP completion. Notes Regarding Wellbore Condition: x Casing test to 1,500 psi passed 07/14/2014. HWO Conditions x Traditional well control approach will be implemented. x KWF will be a barrier at all times during HWO operations. x No snubbing operations are planned during this work. x Team Snubbing’s BOP stack will be used for this operation (see attachment). Pre-Rig Procedure (Non Sundried Work) Operations: 1. Bleed off gas cap from IA before the rig move to the well. HWO Procedure (Begin Sundried Work) 1. MIRU Team Snubbing Hydraulic Workover (HWO) Unit 101, ancillary equipment, and lines. 2. Displace corrosion inhibitor from capillary line prior to pulling ESP. 3. Kill well by bullheading the tubing string and the IA with injection water. a. Tubing volume 71 bbls. b. Annulus volume 282 bbls. c. Monitor OA annulus during kill. 4. Flow check for 30 min to ensure the well is killed. Well: SP-12 PTD: 214-067 API: 50-629-23513-00-00 5. Install BPV/TWC inside tubing hanger as per Vault. 6. Nipple up BOP. 7. Conduct BOP Test. a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 8. Pull BPV/TWC from the tubing hanger per Vault procedure. 9. Call out Centrilift to pull ESP and pull tubing hanger. 10. RU tubing handling equipment. 11. Pump approximately 10 bbl/hour (+ pipe displacement while pulling pipe) of injection water down the annulus throughout the operations to maintain well fill. 12. POOH with 4-1/2” ESP completion laying down tubing and ESP. Record number of clamps recovered. 13. PU cleanout assembly and cleanout casing and liner as deep as practical. 14. RIH with test packer to within 100’ of liner top and test casing to 1,500 psi for 30 minutes. 15. RIH with ESP completion on either 3-1/2” or 4-1/2” tubing to +/- 4,650’. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. 16. Land tubing hanger. Use extra caution to not damage cable. 17. Lay down landing joint. 18. Set BPV/TWC, ND BOP. 19. NU tree and test, pull BPV/TWC. 20. RDMO TS HWO 101. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Snubbing BOP diagram (TSI) 4. HWO Fluid Flow Diagrams (TSI) 5. Snubbing stack stabilization diagram (TSI) 4-½” 12.6 ppf L80 W563 Production TubingHAL 5-½” Oil SwellPackerSP12-SE3Dual Lateral Producerwith ESP LiftNikaitchuq Field –Spy IslandAs completedNovember 24th 20194,917' MD, 3,923'TVD – L1 - BakerSLXP LinerHanger/Packer4,992'-5,009' MD,3,943'-3,946' TVDCasing Exit Window4-½” X-Coupling Cable Protector for ES Power Cable, (1) 3/8" ChemicalInjection Line with 5K psi check valve at bottom4,657' MD, 3,815' TVD, 63º Inc – Bottom of Motor Centralizer Centrilift,66 stages 538PMSXD Flex + 20 stages 538PMSXD GINPSHH ESP Pump,GSB3DB seals, 250HP Motor 562XP, Zenith AL-PT00752 SensorSurf. Casing13-3/8", 68 #2,878' MD,2,463' TVD19º Inc. Interm. Casing9-5/8", 40#5,193' MD, 3,980' TVD83º Inc.5,053' MD, 3,957' TVDBaker MLXP LinerHanger/PackerTD 8 3/4”15,216 MD,4,063' TVD 90º Inc.5-½” 15.5 ppf L80Slotted LinerSilver Bullet Ecc. Nose Guide Shoe 15,205' MD, 4,063' TVD, 90º Inc.Silver Bullet Ecc. NoseGuide Closed Shoe 15,200' MD, 4,050' TVD,90º Inc.TD 8 3/4”15,245' MD,4,050' TVD90º Inc.5-½” 15.5/17 ppfL80 Slotted LinerItem MD (ft)Swell Packer #1 13,947Swell Packer #2 12,462Swell Packer #3 10,992Swell Packer #4 9,570Swell Packer #5 7,948Swell Packer #6 6,614Swell Packer #7 5,478Sealbore Receptacle4.75" ID4,981' MD RAM Hanger4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.68" Seal BoreBottom of SealAssembly4 ½” Lateral EntryModule (LEM) w/ 3.68Seal Bore3.65" Lateral Drift ID3.63" Mainbore Drift IDTOC 9 5/8", 3746'MD, 3257' TVD39' MD/TVD Fast Swivel joint4" ½ 12.6ppf 13Cr L80 W563Doyon 15 RKB 31.80'Date Activity7/17/2014Drill and Complete withTTC_ESP3/17/2017Replace TTC-ESP withconventional ESP5/6/2019Replace conventional ESPand run ESPCP11/24/2019Replace failed ESPCP andrun conventional ESPWell History 3-½” or 4-½” Production TubingHAL 5-½” Oil SwellPackerSP12-SE3Dual Lateral Producerwith ESP LiftNikaitchuq Field –Spy IslandProposedJun 20254,917' MD, 3,923'TVD – L1 - BakerSLXP LinerHanger/Packer4,992'-5,009' MD,3,943'-3,946' TVDCasing Exit Window(2) 3/8" Chemical Injection Lines~4,657' MD, 3,815' TVD, 63º Inc – Bottom of Motor CentralizerSurf. Casing13-3/8", 68 #2,878' MD,2,463' TVD19º Inc. Interm. Casing9-5/8", 40#5,193' MD, 3,980' TVD83º Inc.5,053' MD, 3,957' TVDBaker MLXP LinerHanger/PackerTD 8 3/4”15,216 MD,4,063' TVD 90º Inc.5-½” 15.5 ppf L80Slotted LinerSilver Bullet Ecc. Nose Guide Shoe 15,205' MD, 4,063' TVD, 90º Inc.Silver Bullet Ecc. NoseGuide Closed Shoe 15,200' MD, 4,050' TVD,90º Inc.TD 8 3/4”15,245' MD,4,050' TVD90º Inc.5-½” 15.5/17 ppfL80 Slotted LinerItem MD (ft)Swell Packer #1 13,947Swell Packer #2 12,462Swell Packer #3 10,992Swell Packer #4 9,570Swell Packer #5 7,948Swell Packer #6 6,614Swell Packer #7 5,478Sealbore Receptacle4.75" ID4,981' MD RAM Hanger4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.68" Seal BoreBottom of SealAssembly4 ½” Lateral EntryModule (LEM) w/ 3.68Seal Bore3.65" Lateral Drift ID3.63" Mainbore Drift IDTOC 9 5/8", 3746'MD, 3257' TVDDoyon 15 RKB 31.80'Date Activity7/17/2014Drill and Complete withTTC_ESP3/17/2017Replace TTC-ESP withconventional ESP5/6/2019Replace conventional ESPand run ESPCP11/24/2019Replace failed ESPCP andrun conventional ESPWell History THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stefano Pierfelici Well Ops Project Manager Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP12-SE3 Permit to Drill Number: 214-067 Sundry Number: 319-462 Dear Mr. Pierfelici: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a l o s ko, g c v Enclosed is the approved application for the 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, i� Jerem rice Chair DATED this I day of October, 2019. 14MMS `ACT 10 2019 RECEIVED STATE OF ALASKA OCT 0 8 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCiC 20 AAC 25 280 1. Type of Request: Abandc❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Susper❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 21 - Change Approved Program El Plug for Redr❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change -out n 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Eni US Operating Co. Inc. Exploratory ❑ Development Stratigraphic ❑ Service ❑ 214-067 3. Address: 6. API Number: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 50-629-23513-00-00 ' 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 0 SP12-SE3 9. Property Designation (Lease Number): 10. Field/Pool(s): 0391283, 0388583, 0388582, 0390615 Nikaitchuq Schrader Bluff Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 15216 4063 15,205 4063 1430 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 Surface 2878 13.375" 2878 2463 5210 2480 Intermediate 5193 9.625" 5193 3980 6890 4790 Production Liner 10163 5.5" 15216 4063 1 slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5193-15205 3980-4063 4.5" L80 4582 Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A 12. Attachments: Proposal Summary L41 Wellbore schematic r 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory p Strati ra hic g p ❑ Development ID Service ❑ 14. Estimated Date for October 29th, 2019 15. Well Status after proposed work: Commencing Operations: OIL ❑• WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stefano Pierfelici Contact Name: Amjad Chaudhry Authorized Title: Well Ops. Project Man ger Contact Email: am'ad.Chaudh Eni.COm Contact Phone: 907-865-3379 Authorized Signature: Date: /a `S COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 51q -q(p2 Plug Integrity ❑ BOP Test tj8 Integrity Test E] Location Clearance I�Mechanical Other: 3500 ,05: X30P IeS 2, <'O0 Ain �� '7:;SI i'7 Ll®IY1J —'U�I 1 709 Post Initial Injection MIT Req'd? Yes ❑ No ❑/ Spacing Exception Required? as No Q Subsequent Form Required: APPROVED BY n Approved by: I • 1 COMMISSIONER THE COMMISSION Date: 1 V Form 10-403 Revised 4/2017 Approved applicaUKIUINAL (oI-VI Submit Form an tion is valid for 12 months from the date approval. Attachments in Duplicate Enii fttrolle uiinn� 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierlici Phone(907)865-3320 Email: Stefano.pierfelici@enip.com October 8, 2019 Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SP12-SE3 Rig Workover Dear Commissioners, Eni US Operating Co. Inc. hereby applies for a Workover Sundry for well SP12-SE3. SP12-SE3 was completed on Spy Island on July 17`x', 2014 with an electric submersible pump set at a depth of 4,593' MD. This ESP producer was completed without a packer. The well was started up for production in July 2014 On August 19`h, 2016 an ESP failure iwas occurred. Workover was performed in March 2017, but due to excessive sand production another ESP failure occurred in June 2017 and well was shut down. In April 2019 another workover was performed and a new PCP.piffTfwas installed, but another PCP failure occurred, currently well is shut down. , pu�P The estimated date for beginning this work is October 291h, 2019. 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 SP12-SE3 Workover —Summary Page PTD#:214-067 Current Status Well SP12-SE3 is currently down due to a PCP failure. Scope of Work Scope of this workover is change PCP pump to a new PCP/ESP system. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1830 psi (3,815' TVD) during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB -247/5000 psi BOP configuration: Annular/pipe/blind rams /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 June 2014. ZoLL Well type: Producer Estimated start date: October 29h, 2019 Drilling rig: Sr. Drilling Engineer: Well Ops. Project Manager: Doyon 15 Amjad Chaudhry: ami ad.chaudhrya,eni.com Work: 907-865-3379 Stefano Pierfelici: stefano.pierfelicigeni.com Work: 907-865-3320 Procedure: 1. MIRU Doyon 15. ' 2. Shear upper GLM valve and circulate diesel out through tree. Pump in bull heading 10.3 ppg NaCl/KCl brine in IA. Ensure well is killed. 3. Set BPV. ND tree and NU BOP and test as per AOGCC. (3 5ODfSLI -fe-ltj 4. Pull tubing to upper GLM. Soy 5-- 5. s5. Continue POOH and lay down PCP assembly. 6. MU new ESP/PCP assembly and RIH to setting depth. 7. Land hanger, and test it. 8. Install BPV and nipple down BOP. 9. NU tubing adapter and tree. 10. Pull BPV, install test plug and test tree. 11. Circulate Freeze protect through tree down IA. 12. Shut in well. 13. RDMO. Below the current schematic of the well: Sud Ceang� n-ve-. ea a a]a MO 248d' TVO iPlnc r.0 DS1a lire o »srrr_ 3128' 4-%" 12.6 ppf Production Tubing r 91 13Cr 39.3' TVD Swivel joint 4" % 12.6ppf 92 2090MD, 1798' TVD 41° Ind -GUM, KBMG. 4-%" x V. with 2.000 psi lrni STS -I Tub. To Ann. SOV installed tt F 4.%" x-cplg cable clamps, for ESPCP Power Cable, (1) 318" Chem In) a5 Line with 2500 psi cheek valve at bottom S P 12-S E 3 6,614ke Dual Lateral Producer 5,473 with ESP Lift 4582'MD, 3.783'TVD- VvellLift DGIJ Pressure Discharge 4.5" As completed May 61M1 2019 4,657' MD. 3.815' TVD. 83° Inc-ESPCP ASM 115-1200 LT2200 513 FSA Bottom of Motor Centralizer Centdlift, Motor 562XP 175HP (720-E-1800), 4,917' MD, 3,923' % TVD - Lt - Baker N�� SLXF Liner � Hanger/Packer 4,981' MD RAM Hanger 3.65" Lateral Drift ID 3.63" Mainbore Drift ID 4%"x 9-58" AM Seal Bore Givener w/ 3.68" Seal Bore m MD(hlke r 91 13,947er 92 12.462cker 03 10,992ker B4 M 9570ker a5 7,948ker a6 6,614ke r e7 5,473 Niketchuq Field -Spy Island 4%" Lateral Entry Module (LEM) w/ 3.66 Silver Bullet Eco. Nose Seal Bore Guide Closed Shoe TO 83/4" SBO Slotted15." Lppf 15,200' MD. 4,050' TVD. 15,245' MO.. 4,992'-5,009' MD, L80 Slotted Liner 90- Inc. 4.0SO'TVD 3.943'-3,946' 1rVD Bit- Inc. r Casing Efut Wind. , Sealbore Receptacle HAL 5-Y! OilRe�ptacle HAL Oil Sweli TO 6314" /4.75'ID Parker 'TD MO. 4063' TVD B0° Inc, SOOT MD, 3,11 TVD Baker MLXP Liner HangerlPacker Assembly Id1com Ceaing i 9-518', 41111 5-X" 15.5 PPI L80 5,193' MD, 3,980' TVD Slotted Liner 83° Inc. Silver Bullet Edd. Naso Guide Shoe 15.205' MO. 4,063' TVD. 90° Inc. HYDRIL 13-5/8" ANNULAR "GK" 5000 PSI STUD x FLANGE BX -160 BYDRIL MPL SINGLE GATE 13-5/8" 5000 PSI FLANGE x FLANGE BX -160 10" OPERATORS VARIABLE PIPE RAMS HYDRIL MPL SINGLE GATE 13-5/8" 5000 PSI FLANGE x STUD BX -160 14" OPERATORS BLIND/SHEAR RAMS HYDRIL MPL SINGLE GATE 13-5/8" 5000 PSI FLANGE x FLANGE BX -160 10" OPERATORS VARIABLE PIPE RAMS RIG 15 BOP STACK HYDRI�L Kok, O r IIIA ®�nOAA®)4 36.150' Wetco G ray MB -247 SURFACE COMPLETION SYSTEM PRP 10161, NC i A�+Y �.E iria,l�0tw�i c:.uar4 10 OF 10 23 JANUARY 2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS IECAVE JUL 0 3 2019 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing ✓ ti ut w Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ESP chance out❑✓ 2. Operator Ent US Operating Co. Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Stratigraphic ❑ Exploratory p ry ❑ Service ❑ 214-067 3. Address: 3800 Centerpoint Dr. Ste 300, Anchorage, AK, 6. API Number: 99503 50-629-23513-00 7. Property Designation (Lease Number): 8. Well Name and Number: 0391283, 0388583, 0388582, 390615 SP12-SE3 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 15,216 feet Plugs measured N/A feet true vertical 4,063 feet Junk measured N/A feet Effective Depth measured 15,216 feet Packer measured N/A feet true vertical 4,063 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 160 160 160 Surface 2878 13.375" 2878 2463 5210 2480 Intermediate 5193 9.625' 5193 3980 6890 4790 Production Liner 10163 5.5' 15216 4063 Slotted Slotted Perforation depth Measured depth 5,193-15,205 feet True Vertical depth 3,980-4,063 feet Tubing (size, grade, measured and true vertical depth) 4.5 L-80 4,576 3,790 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: 11179 198 878 -7 1 278 Subsequent to operation: 750 126 628 -13 282 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ✓ Gas U WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 3T9�Q53 319 - Z10 Authorized Name: Stefano Pterfelici Contact Name: Amjad Chaudhry Authorized Title: Well Operations Project Ma ager Contact Email: amiad.chaudhrvraleni.com Authorized Signature: Date: Contact Phone: 907-865-3379 Form 10-404 Revised 4/20176 /3 t4 f #V r1R B DMS '"JUL 0 8 2019 Submit Original Only N N W m ro Z (D m m ro mmC) n (D N (D (D ID wt�i_t n ,n m 0 c A N N = Gip S: O 0 o w -M l�Jt W O �v d yp� on u`o In pi V 0 T A Ol lD =. N A X v w �° A 1p M V i-+ A V tD 3 FD � A W O N 00 N U _ cn 0 J Cl) n 0 W Orn 7C (D d fD w Z7 CD _ _ W CD N W d v = (n _ CC) X00 d =d CA O W _ O Cl) c O (D j (D 02 : pO CO 0 X w � D m CD W d CD D� N O v 3 coO 0) c ra CnN p 3co ^' CDN cn o C) D G o A N y D- < � N C fD O C.7 n -0 .� c N N N d W W N(0 D-' W T '6 (7 0) i '. d W p W m(D O p 0 V co cn Q N p v -O V1 41. (p fp 0 3 d cn W a CT D co (O _ G1 (O W co CD � m (D N (D n CO O W CD N m W„< x (p O Q�`Z - C] 3d CD CQ 0 n ^^ Ut cn o 02. 3 d FT `CC� . p OD p) tD N O o Fa N Q CD O. - W - - n W o y J (D G 4. < 0 0 (D G � o .-. cr U2 ;aO ((D 0 0 � m o (D I f m d cn A 0 Q N � ' T l) d (D 3 o N (D CD W C ((D -0 N N A cn \ I D r r cn (n rn s 6 N co o v I CO T W a cn p o cn -� A co C/7 N N O- N O C N m r CD r J o m o o CD = I ( D O 3 o 0 -n -N cn — D co N�< o v CD 'D m = oW o� W ��° ° 0 D I N �m �?CD m tU a1 � o� I I ool0 cn 0�rt-o O �. 0) Z o Z Q, O rn I I � o� CD N -a w (n I O fD r rn W COD (D <NOD CG rt L (� a S m o 0 cook O Q W comma a. -,NC) ��((A W n (D 0 ` 0 � W o A a G O = Z m ro (D (D m m ro (D N (D (D ID (D (D J A N N Q#1 l�Jt W In pi V 1p O A Ol lD to 1p A 1p M V i-+ A V tD Ol A � A W O N N V OR C Well Name: e: SP12 SE Wellbore Name: SP12-SE3 Well Code: 27979 aniria Job: WORKOVER II WCER Level: Daily Report Date: 412612019 Report #: 1 Page: 1 of 2 Well Header PermiVConcession N° OperatorSubsidiary Initial Letters Cade ALASKA ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL O POGO DI COLTIVAZIONE Rotary Table Elevation(h) Water Depth (ft) First merge in) RKB-Base Flange (h) RKB- Tubing Spool (ft) 53 94 1].23 36]1 31,80 Rigs Rig Name Contractor Rig TYPe Rig Num Rig Start Date Rig Release Data RIG 15 DOYON LAND RIG 6123 42512019 Daily Information Weather Temperature (°F) Wind Days LTI(days) Days Rl(days) POB Overcast 104 SAN @2 MPH 552.00 1552 D0 1000 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (day.) Rig Inspection 1 412612019 42]2019 1 Safety Meeting 1 4/26/2019 42]2019 1 Spill Oral 2 4/262019 5/1012019 14 Casings seat Cas. Type OD (in) ID (in) Grade Top IN(S) Bottom (hKB) TVD Bot, (f1K8) Run Data CONDUCTOR 20 18.25 016906/12014CASING 133/8 12.42 L- 0.1 2,8]8.0 2,463.8 6112/2014 CASING 95/8 8.84 140. L80 04 8,1930 3,9]6.4 6/192014 LINER 5112 4.95 L-80 5,053.4 15,2050 4,052.5 62)2014 Last Cementing Cementing Start Date: 6119/2014 String: CASING, 5,193 OhK6 Comment: Shut down ng pumps and Schlumberger pumped 10 mils. H2O to fill Imes antl testetl lines to 1,16013457 poi: ga. Switched back rig pumping 105 bbls. of Mud Push II @ 10.5 Pig -rate of 5 bpm @ 220 Psi. Shut -down and drop bottom plug. SLB mix 8 pump Lead slurry ]9.5 bible W/ 12.5 ppg Lite CRETE [1.56 hLak YieM, mix water at 5.461 gellsk.] - Pump rate of 5 bpm @ 435 psi. Pump Tail Slurry 49 bbl 12.5 ppg Class G 11.16 1131sk Yield, mix water at 5.109 gallsk.) - Pump rate of 4.6 bpm @ 700 psi. Shut down and tlmp top plug -SLB pump 10 able H2O and wash up. Displace wit 376 bbls MY 9.4 ppg mud what rig pump at 6 bpm w/ 140 psi, final pressure 550 psi., Bump Plug Press. up to 1,050 psi held 5 Min. Bleetl o8 floats holding. Cement in place @ 22:00 firs. Stg # Top (hKB) Top Meas Meth Stm INKS) I Com 1 204].0 3,]46 0 10.5 ppg Mud Push II 2 3,]46.0 Temperature Log 4,663.0 12.5 ppg Lead Cement 3 4,683.0 Temperable Log 5,207.0 15.80 ppg Tail Slurry Job Information Job Phase Pbnnetl Start Date Start Data Entl Data P50 Duration (days) WORKOVER 428201900:00 426201900:00 0.00 Daily Summary Operations 24h Forecast Complete R/U on SP12SE3. RN Halliburton a Imo lubncaum equipment on has and perform gage ding run and SaludGE MPC Incision atom wher. repeat If necessary to circdab. R/D Halliburton E-hae. Kfil well. 24h Summary Prep to skid ng floor and pad for rig move. Move sub and pits to SP12SE3. SW rig into drilling peaikon and W interconnect between modules, RAI stairs and egress on rig and well house. Set suit cases from productionimud plant. Operation at 07.00 Spotting Equipment and Germing around Rig Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opt. Ad. Plan Oper. Descr. 0000 12941 1200 12.00 OB A 2 P Stud ng floo, back aver pipe ahetl for move. Layout Hemulhe in from of SP12-SE3. Move pit module away or sub m cite and lay out matfing boons tor same. Move sub and spot over SP12. Skid rig flow back into drilling position. 1200 00:00 1200 26 00 MOB A 2 P R/U stairways and egress —build scaffolding walkways along well bay to sub structua g up interconnects aro walkways on .mapd modules, Lay Hemuli s and weld seams as Par ACS rep requirements for Rork Washer and 03 mud pump. Continue beaming parameter of rig. RAI hand rage and WO strong back in pipe shed Plug in TO electrical and pit module, swap power to g4 generator. Set suit case extension, M beaver slide and interconnects grain sub to ng floor and pits. Set matting boards for Rack Washer. Nob: Production monitor SP12SE3—tag.= 252 psi. /Annulw B=280 pst. / Annulus A= 240 psi. Gas Readings Avg Background Gas (%) Max Background Gas J%) Avg Connection Geo(%) Max Connection Gas (%) Avg Drill Gas t%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%I Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bat) Additions (bat) Cum Additions (bill Losses (bbl) Cum Lasses (bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Ent remainder. Bruce Simons. Erni Dolling Supv. uddrilling@eni.com 9074685-0715 Em representative Simon. Bdemmi Em Drilling Supv. sidddling@.i.com 90]-685-0]15 Eni representative Wade Thomas Em Rig Clerk AKRigCIw1Wooyonl5@aWoom 90]585-0]22 at representative Pat Mem Eni HSE Eni representative Mark Habler Ent HSE Drilling Supt Sam Dye Doyon pilling Field Superintendent Tool Push Ryan ParMrata Doyon Drilling Tool Pusher ng15@ ft xhdh1Img coin Tod Push Einer Fieagle Doyon Drilling Tool Push Tool Push OWN Owens Doyon pilling HSE covens@doyandrilling.wm 685-0796 Tod Pi Dave Sena Doyon Doling HSE lama@1oprunlling.com 61 Personnel Log (POB) Company Sera. Type Work H (hr) Stand-by H (hr) Count "a Halliburton D 12. 0 6LB Cem 12.50 0 Onlling Drilling Em IF"idn.perv,s.ru 1250 0 Doling GBR Cesirg Casingervice 12.50 0 Dulling orn Well NameOR : Wellbore Name: e: SP12 SP12-SESE3 Well Code: 27979 Job: WORKOVER 2nWCERLevel: Daily Report Date: 4127/2019 Report #: 2 Page: 1 of 2 Weil Header PurritlConcession W Operator Subsidiary Initial Lahee Code ADL -388583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL O PC= DI COLTIVAZIONE Rotary Table Elevation IN) Water Depth IN) First Flange (R) RKB-Base Flange (X) RKB - Tubing spool (ft) 53.94 17.23 3671 31.80 Rigs Num Rig Start Deli se Data Rig Name GPMri4lor Rig Typa Rig Rig Relea RIG 15 DOYON LAND RIG 0723 412512019 Daily Information Weather Temperature ff) Windays LTl(day,) Days RI(days) FOR Overcast 1.4 S @ 6 MPH 'D'3.00 553.00 103.0 Safety Incidents - Near Miss Gets Category Type Subtype Severity Cause Lost lime? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Dale (days) Rig Inspection' 4262019 42]2019 0 Safety Meeting 1 4262019 42]2019 0 Spill Drill 2 4262019 5/102019 13 Casings seat Cas. Type OD (in) ID (in) Grace Top (RKB) Bottom (RKB) TVD BUT. (RKB) Run Date CONDl1CTOR 20 16.25 %65 0.0 160.0 160.0 W1/2014 CASING 13318 12.42 LA0 O.t 2,878.0 2,4838 61122014 CASING 9518 8.84 L80 0.0 5,193.0 3,9]6.4 8/19/2014 LINER 51/2 4.95 L-80 5,053.4 15.205.0 4,052.5 829/2014 Last Cementing Cementing Slari Date: 6/192014 String: CASING, 5,193.0110 Comment: Shut down ng pumps and Schlumberger pumped 10 bible, H2O to fill linea and tested lines to 1,160/3,457 psi,. good. Switched back ng pumping 105 bbls. of Mud Push II ® 10.5 ppg - rate of 5 bpm Q 220 psi. Shutdown arM top bottom plug. SLB mix & pump Lead slurry 79.5 bible WI 12,5 pipe Lite CRETE [1.56 ftWsk Yield, mix water at 5.461 gal/sk] - Pump rate of 5 bpm @ 435 psi. Pump Tail Slurry 49 bbl 12.5 ppg Class G [1.16 hWsk Yield, mix water at 5.109 gallsk.] - Pump rate of 4.5 bpm @ 700 psi. Shut down and drop on plug - SLB Pump 10 hula H2O and wash up. Displace with 376 bbls W/9.4 ppg mud wit rig pump at 6 bpm w/ 140 psi, final pressure 550 psi., Bump Plug Press. up to 1,050 psi held 5 Min. Bleed oft goats holding. Cement in place @ 22:00 hrs. Sig # Top (ftKB) Top Meas Meth I Bpm (RKB) I Cpm 1 2,6azD 3,]46.0 10.5 ppg as Push II 2 3.]46.0 Temperature Log 4.683.0 12.5 pP9 Leatl Cemem 3 4.683.0 Temperature Log 5,20].0 15.80 ppg Tail Slurry Job Information Job Phase Plannetl Sport Date Start Date End Data Pyo Duration (days) WORKOVER 426201800:00 428201900:00 0.00 Daily Summary Operations 24h Forecast POOH lagging and charge tool string to BHA 012. Perform circulation pest RIH to cut slot in TBG (it 4,444'. POOH and isoWte lubricator. Kill well if possible or make cul more slots. WD Hallibumin ¢lime. Kill wall and mondorwell to WD. 24h Summary Rig move - spot outer components and equipment around die sub and pit modules, RN egress and terming around atuipment, WU interconnects between modules. Spot Hellibudion Hine unit and lay out pods, WU lubricator and function test Baker CCLRAPC Incision slot cutter. M/U BHA #1 (CCL & 3.5" GR) - teat Iubricalor to 3500 psi. RIH to 4,473' and POOH logging. Operation at 07.00 Cutting Slots WIE-Line Time Log Steri EM Cum our Time Time our (hr) Phase On, Act. Plan Oper. Descr. 00:00 1130 11.50 1150 MOB A 2 P Rig move- lay out matting borne and bermirg for equipment Spot rock washer, W mud pump, generator #5. VFD house. mud shack, Haliibur on logging unit, accumdafor unit. Continue belming around components as they were set. IWU suit case connection between sedians mom producSoNmud plant. WU interconnection between component, hook-up electrical lines and hydraulic lines from accumulator fo sub. 11:30 14:00 2 50 1400 W.O. R 2 P Spot Halliburton eline Unit, build secant containment to rg. Lay out tool strings and areas aline trough lubricator grease head Continue WU accumulator hoses, interconnection between modules Pull and plug in deoldical to equipment Spot tiger tank for work over Change nut auction rubbers in pilo #1 . RUt Halfbu ft n lagging unit. 1400 18:00 4 00 18.00 W. R 5 p MN GE Vofoo vers, line valve on tree con8nua RUI Halliburton aline sheaves t0 rig floor and top drive -arsembry tads. Take on815 trials. of 11.0 ppg Na/Br brine from mud plant to AS pits. R/U line to tiger tank and RN Halliburfon mud forma instrumentation to dig. 1800 22:00 4.00 22.00 W.O. R 5 P MN Halliburton lubricator and grease head and BHA #i (CCL & 35' GR) train. Test grease rinse to lubricator, prep to fast same. Continue plugging in mud pumps #1 & #2 to VFD house. Fluty pack lubricator. 22'00 00:00 2.00 24.00 W.O. 12 P Test Halliburton lubricant to 3500 psi. for 5 minutes - good test - bleed aR to 280 psi to equities. Open up swab and RIM with BHA *1 to 4473' WLM connotes, to GLM @ 4,359.42'. POOH logging. IR Note: Monitor SP12-SE3: tbg.= 280 psi. / Annulus B =284 psi. / Annulus A = 220 psi. Rig was acceptetl Oh. Gas Readings Avg Background Gas I%) Max Background Gas (%) Avg Connection Gas (%) Mex Connection Gas I%) Avg Drill Gas 1%) Max Drill Gas (%) Avg Trip Gas (%) Max Top Gas (%I Daily Mud Volumes Tansu AddlfonfLoss Type Des Volume(bbp Tank 815.0 Loss 0 a Hole 930 Cumulative Mud Volumes Active Volume@bl) Hob VPlume(bbb Additions(bbl)Cum Additions(bbl) Losses(WI) Cum Losses bbl) 1,40&0 593.0 0.0 0.0 0.0 0.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representativeBruce Simonson Onlling Supv. sitltldilli ani mm 9Wb85-0]15 Eni repreaentauve Simone Belemmi 1" Eni 10 Dulling Supv. sidtldiiling®eni.com 90]4185-0715 Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 4/2712019 Report #: 2 Page: 2 of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Wed. Thomas Eni Rig Clerk AKRigoerksDoyorlS�eni.cOm WE8 95-5022 Eni representative Pal Ahem Eni HSE Eni representative Merl, Nobler Eni HSE Drilling Supt Sam Dye Doyon Drilling Field Superintendent Tool Push Ryan Pankrotz Doyon Drilling Tool Pusher riglStidoyondrilling.wm Tout Push Einar Fleagle Doyon Drilling Tool Push Tool Push Cliff Dean. Doyon DiCHIN HSE covens Qtlyy 685-0796 Tool Pushson Eave Sena Doyon Grilling HSE dilillirg.com dsena®tloyoMNlling.com 685-0796 Personnel Log (P( B) Company Sarv. Type work R (hr) Stand-by H thin) Count Note SL Cement 12.50 0 Drilling Eni Fluids Supervisor 12.50 0 Drilling GBR Casing Casing Service 12.50 0 Drilling ASRC Clark 12.50 1 pilling ASRC SOA 12.50 1 SIDSupport ASRC Crane Arhnsor 12.50 1 SID Support Beacon Madlc 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Eni Company Man 12.50 1 Drilling Nmihem Odleild Services Foster 12.50 1 SID Support Veko(SHGE) Wellhead 12.50 1 Drilling Baker Fishing 12.50 1 Drilling ACS Eniimmental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Seamon HSE 12.50 2 SID Support Dayon Tool push.. 12.50 2 pilling Dayon HSE 12.50 2 Drilling Halliburton Mud Logge. 12.50 2 Drilling Ml Seas. Mutl Engineer 12.50 2 pilling Competent. Logistic 12.50 4 SID Support Halliburton Wireline 12.50 6 Drilling MI Swaw Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support Ml S.. WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Jacobs Tmck driver I Crane operator 12.50 14 Drilling Doyon Rig Personnel 12.50 26 Drilling_Total Grilling Personnel BOP Stack 8 Components Description $tart Date Last CetlRcation DatePressure Ratio sl 9(P 1 Typo Make Motlel IO Nom (in) PRange(psq Last Carl Date Slow Circulation Rates Pump Number. Make: Model: StartDate End Data Liner Size (in) Volume Per Stroke Namide(bbllstk) Maz Pressure 1psii Data Depth(RKB) Slow Slid $bokes (spm) P(psi) EBI%) 0Flow (gpm) Daily Bulk Supply Item DucriaOon: Equipment Fuel Unit Label: Gal Unit Size: t Note: DateConsumetl Receivetl Returned Cum Consumed Cum Receivetl Cum Returned Co. On Loc Note 42]2018 988.0 988.0 9880 888.0 00 00 Supply Item Description: MW PIam BoBers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 426.2019 420 42.0 42 0 42.0 D.0 0.0 Su"'al"Lm Description: Rig Feel Unit Label: gel Us Unit Size: l Note: Data Consumed Received Returnetl Cum Consumetl Cum Receivetl Cum Returned Cum On Loc Note 4862018 1,44].0 10,291.0 1,44].0 10,291.0 0.0 8,844.0 c.Pply item Description: Rig Water Unit Label: ble Unit no, 1 Note: Date Consumetl Receivetl Returned Cum Consumed Cum Receivetl Cum Returned Cum On Loc Note 4862019 80 57.0 60 5].0 0.0 49.0 Supply Item tie scrip Um: WIF Balers Unitlabel: Gal Unit Size: Note: Date Consumetl Recalvetl Returned Cum Consume Cum Received Cum Returned Cum On Luc Note 4262019 198.0 198.0 198.0 198.0 0.0 0.0 Supply Item Description: WIF Injected DfOeel Unit Label: Gm Unit Size: Note: Date Consumed Receivetl Returned Cum Consisted Cum Received Cum Returned Cum On Loc Note 4262019 6400 $40.0 840.0 640.0 000 Last Authority Vi - Dab Tot insp. Nbr Total I.N.C. number Comment General Notes Comment: jr`Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 f'I Job: WORKOVER 211 �n1 II11 WCER Level: Daily Report Date: 4/2812019 Report #: 3 Page: 1 of 3 Well Header PermiUConceesion N° Operator Subsidiary Initial Lahee Code ADL -388563 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL O POZZO DI COLTIVAZIONE Rotary Table Elevation(it) Water Depth(0) First Flats.(K) RKB - Base Flange (it) RKB - Tubing Spent (ft) 53.94 723 36.71 31 80 Rigs Rig Name Connector Rig Type Rig Num Rig Start Deb Rig Release Date RIG 15 DOYON LAND RIG 0723 42512019 Daily Information Weather Temperature (°F) Wind Days LTI(days) Days Fit tdays) OR Clear 10.4 S@12 MPH Na55a.5O 103.0 Safety Incidents - Near Miss Dane Category Type Subtype Seventy Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Rig Inspection 3 412812019 4292019 1 Salary Meeting 3 428/2019 412912019 1 Spill Drill 2 4126/2019 5110/201912 TT Wall Kill 2 4/28/2(119 ]/2]/2019 90 Casings seat Cos. Type OD (in) ID lin) Grade Top Qt6B) Bottom (RKB) TVD Bot. (RKB) Run Date CONDUCTOR 20 18.25 X65 0.0 160.0 160.0 6/12014 CARING 133/8 1242 L -BO 0.1 2,878.0 2,463.8 6/12/2014 CASING 9518 8.84 180 0.0 5,193.0 3.8]6.4 WIM014 LINER 51/2 4.95 L-80 5,053.4 15.205.0 4,052.5 6/292014 Last Cementing Cementing Start Date: W19/2014 String: CASING. 5.193.OI1KB Comment: Shut down rig pumps and Schlumbaiger pumped 10 MIs. H2O to fill lines and tested lines to 1,16013 457 psi: good. Switched back dg pumping 105 bills. of Mud Push 11 @ 10.5 ppg - rete of 5 bpm @ 220 psi. Shut -down antl drop Mttam plug. SLB mix 8 pump Lead slurry TB5 bills W/ 12.5 ppg Lite CRETE [1.56 fl3lsk Yield, mix water at 5.451 gallskl - Pump role of 5 bpm @ 435 psi. Pump Tail Slurry 49 bbl 12.5 ppg Gass G 11.16 flbhk Yield. mix water at 5.109 gallsi - Pump rete d 4.5 bpm @ 700 psi. Shut tlown and drop top plug - SLB pump f 0 bbls H2O antl wash up. Displace with 376 bills Wl 9.4 ppg mud with dg pump at 6 bpm wl 140 psi, final pressure 550 psi., Bump Plug Press. up w 1,050 psi held 5 Min. Bleed off floats holding. Cement in place @ 22 OB Ms. Sig # Top (RKB) Top Maas Meth atm (RKB) I Com 1 0 3,746.0 10.5 ppg Mutl Pmh II 2 3,746.0 Temperature Log 4,683.0 12.5 ppg Leatl Camenl 3 4,683.0 Temperature Log 5,207.0 15.BOppg Tal SIUmy Job Information Job Phase Planned Start Date Start Data End Data P50 Duration (days) WORKOVER 426201900:W 428201900:00 0.00 Daily Summary Operations 24h Forecast Complete NN of SOPE and Wrench test. Test to AOGCC Sundry, Matthew Herera with AOGCC waived witness of test @ 1949 lira 04-28-19. RID from leaf WU to pull ESP assembly with GBR and BHGE centrelift. 24h Summary POOH logging and change tool string W BHA 42. Perform circulation test RIH cut slot in 4-112" lbg @ 4,441' and attempt Of 4,440.5' and 4,437.5' without success. POOH- Baker inspected cutter ted, broken dadus. Bull hand Rig. with 93 bills. and Annulus A with NO bilis. Monier for 1 lour, well on vac. Installed BPV and NID Vee- dress hanger. N/U ROPE. Operation at 07.00 ROPE Test Time Log Stall End Cum our Time Time our (hr) @r) Phase 0" Ad. Plan Oper. easier. 0000 01:00 1.OD 1,00 we JIL 11 P H logging with L (cun&etetl to GLM @ 4,359.4) and 3-1/2' gauge nng no.urfsce from 4,444' W LM 040o 02:30 1.50 2.50 W.O. L 18 P Charge BHA #1 to BFIA #2 (Baker MPC Incision slot culler a4/ CGLt MN and re -teat Wbricaer. SIMOPS: Complete R/U to perform circulation fest. 0230 0300 0.50 300 W.O. L 12 P Fluid pack lines- found leak on 1003 union in the interconnect under fig floor and change out. Teat mud lines to MOO psi. 0300 03'.30 0.50 3.50 W.O. L 9 P Perform cirmimben test- pump down tbg with 11.0 ppg Novi- rates of 1 bpm @ 400 psi12 Who @ 850 pal. / 2.5 bpm @ 1,124 psi. Total 14 bills. Pumped. 0330 11:00 750 11 00 W.O. 17- 18 P RIH with CCUMFC Incision cinder U4A41' and start making first slot mt. Monitor to , (138 Psi.) antl Armulus A (289 Psi.) after cut tubing incremetl W (144 psi.) antl A Annulus remained the same. Attempt second out @ 4,440.5 with no success. Attempt MTM cut @ 4,43].5' with no success- 61MOPS land 130 joins of 412' 12.8#ANetlge 563(L -8D inro pipe shed and d'Rt wNt 3 833'. 1100 12:00 1.00 1200. W.O. L 4 P POOH wth BHA #2 to surface and GE/Baker inspect anter - broken blades. Double isolate with resident, Jiro valve on treel lubricator. 1200 13:M 100 13.00 W.O. L 9 P Bull head down tog. with 1 le ung Nai brine - stage up rate: ICP of 1 top @310 psi. 12 bpm@NO psi, /FCP 2.8 bpm@ 1700 pis. Pump trial of 93 We 1300 ism 2.50 15.50 W.O. L 9 P bull head Annulus A with 110 ppg Naar brine- stage up nate: ICP of 5 bpm@700 Pat 16 bpm@ 820 psi. l FCP 6 bpm@ 470 psi. Pumped natal NO bills. SIMOPS: Rig down Hailiburton e,fine wood lubricator, prep epuipment for storage. 1530 1630 1 00 16.50 W.O. L 11 P Monier well n 15 made larval. ori Mur. 00mim:Tubing=-10,Pd. /Annulus A=-13pW /AmWus B=5Npai. 15 mins: Turing= -12.7 psi. /Amulus A=-6.6 psi./Annulus B= date psi 30 mim: Turing= -13.2 psi. lAnrmNs Aro -7.8 psi. /Mnulus 8=450 psi. 45 mins: TuNn�-10.5 psi. / Annulus A=4.3 poi. / Mnulus 8=4W psi. 60 aim: Tubing= -8.1 psi. / Mm i.A=4.4 psi. I Mnulus 8= 385 psi. SIMOPS: Load S TT 525 ddil pipe (strap S Wily) is pipe shed. 16.30 17:30 1.00 17.50 W.O c 5 P Remove wire line valva ft. tree and at BPV in hanger. SIMOPS: Load A tend 162 µvnts ot T TT 525 OP (shay 6 Wily) into pipe shad. We Matthew Herres with ACGCC waived witness of ten @ 1949 Ms. 04-28-19. 1730 iSW 200 1950. W.O. C5 P mu tree as per GE Vete rep -inspect, Wrtninane cap lino and imW Ind plate on hanger Install blanking plug for testing BOP on 10Irl hrs. in Anndus A 19:30 00'00 4 50 24 W W O. C 5 P NN 13-Y6".stand BOP stack, two sets o choke and WIS valveelhoses (manual/HDR), hell nipple and flow line. I I NOW: Trial Ips to SPf2bE3= en Was, Put 10 bbla.2 hrs. in Annulus A Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Ga. L%) Max Drill Gas (%) Avg TOP Gas (%) Max Trip Gas I%) Well Name: SP12-SE3 OR Wellbore Name: SP12SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 4/2812019 Report #: 3 Page: 2 of 3 Daily Mud Volumes Tank/AddItiONLoss Type Das Volume(bal) Tank 7600 Loss 386.0 Hole 5930 Cumulative Mud Volumes Active Volume Oban)Hole Volume (bbl) Additions pan) Cum Additions IWO Losses (bbl) Com Losses (bbl( 1,353.0 593.0 0.0 0.0 385.0 386.0 Daily Contacts Position Contact Name Company Title Email Office Mobile ni represandmin Bruce Simonson Eni pilling Sups. sidtlnlling@ani.corn 907-685-0715 Eni representative Ssmone Ms., Eni Drilling Supv. siWm1irg@anio. 907685-0715 Eni representative Wetle Thomas Era Rig Cleric AKRsgClerksDoyon15Qemoom 907-685-0722 Eni representa . Pat Mem Eni HSE Eni reprsenative Louis Anreneaux Ens HSE Dulling Supt, Sam Dye Doyon Dnllbg Reld Sup in menden( Tod Push Ryan Peninsular Doyon pilling Tool Pusher n9l5ittloyondnllsng.coin Tool Push Einer Fleagle Dayan OHIO, Tool Push Tool Push CIO Owens Doyon Drilling HSE cowenm@doyon lnllingcom 685-0796 Tad Push Dave Sena Dayan orJling HSE dsenm@doyDoOdling com 685-0796 Personnel Log (POB) Company $a,. Type Work H (hr) Stand-by H (hr) Count None SLB Cement 12.50 0 Drilling Em Fluds Supervisor 12.50 0 Dnllsng GBR Casing Casing Service 12.50 0 Ddling ASM Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Doyen Field Superintendent 12.50 1 Drilling EN Compairy Man 12.50 1 Drilling Northam pleadd Services Fueler 12.50 1 SID Support vetco(SHGE) WNIHead 12.50 1 Drilling Baker Fishing 12.50 1 Drilling ACE Ervnromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Dnllsng Halliburtan MW Logger 12.50 2 Onlliig MI Swsco Mud Engineer 12.50 2 Dnllsng Campaniles Logistic 12.50 4 SID Support Halisburton winsne 12.50 6 Drilling MI Swam Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support NO Swaw WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Jacobs Truck diner/Crane operator 12:50 14 Drilling Doyon Rig Personnel 12.50 26 10611ingTotal Dulling Personnel BOP Stack 8 Components Description Start Data Last Certification Date Pressure Rating (psi) Type Make Model IO Nom(in) I PRising. (pail Last Cert Dale Slow Circulation Rates Pump Number: Make: Mandell: Start Dale End Data Liar S¢e(in)Volume Per Stroke Override Obbil.R) Max Pmssure(psi) Data Depth (RKB) Slawsptl Strait. (spot) PlPss) I Elf I%) I OFlow(gpm) Daily Bulk Supply Item Description: Egupmmd Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumetl Receivetl Returned Cum Consumed Cum Received Cum Returned Cum On Lo[ Note 42812019 889.0 889.0 2,99].0 2,9970 0.0 0.0 Supply Item OescripUon: MW Plant Balers Undt Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 4282019 42.0 42.0 126.0 126g 0.0 100 Supply Item DesulpUm: Rig FuN Unit Label: net us Unit Size: t Note: Data Consumetl Receivetl Returned Cum Lonsumetl Cum Received Cum Returned tum On Lo[ Note 41282019 1986.0 13,828.0 4,984.0 26,622.0 0.0 21,838.0 Supply Item Description: Rig Waar Unit Label: bbl Unit Size: 1 Note: Dale Consumed Received Relarnetl Cum Consumed Cum Receivetl Cum Returned Cum On Loc Note 41282019 39.0 0.0 85.0 192.0 00 107.0 Supply lam Description: WIF BdIer Unit Label: Gal Unit Size: Note: Date Consumetl Kazarian Returned Cum Consumed Cum Received Cum Returned Gum On Loc Note 412812019 198 0 1980. 5940 594.0 0.0 0.0 Supply Item Description: WIFInlectetl Diesel Unit Label: Gal Unit Size: Note: Date Consumetl Received Returned Cum Consumed Cum Receivetl Cum Returned Cum On Loc Note 4/282019 4200 420.0 1,680.0 1,680.0 0.0 0.0 Last Authority Visit Data Tal map. Nbr Total I.N.C. number Comment STOP Cards Submitted Company #Rina Com Doyon Onlling 11 PJSMS Doyon DrslOng Inc 11 HRWS Doyon Drilling Inc. 11 COW Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 4/28/2019 Report M 3 Page: 3 of 3 STOP Cards Submitted Company M Rpts Com Doyon Drilling Inc. MI Swaco MI Swaco 13 8 5 Safe Cares RIR'e HARCIJSA General Notes Cummem: Well Name:E3 OR Wellbore Name: e: SPSP1?-SESE3 Well Code: 27979 Job: WORKOVER cin � WCER Level: Daily Report Date: 4/29/2019 Report #: 4 Page: 1 of 3 Well Header PermiUConcession N° Operator Subsidiary Mittal Lahee Cade ADL -388583 ENIPETROLEUM ENI Pea .Co. Inc. DEVELOPMENT WELL O PORO DI COLTIVA ZONE Rotary Table Still f0) Water DeplM1 ift) First Flangs(11) RKB - Base F,..ga(in RKB-Tubing Spool IN) 53.94 1].23 36.]1 31.80 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Dale Rig Release Data RIG 15 DOYON LAND RIG 0723 4252019 Daily Information Weather Temperature (-F) WindDays LTI (days) Days RI (daysl POB Cloudy 24.8 SW @ 15 MPH 555.00 555.00 108.0 Safety Incidents - Near Miss Data Cale9ory Type Subtype Severity Cause Lost lima? Comment Safety Drills Days Until Next Check Type p Occur Last Date Next one (days) BOP Pressure Test 1 V29/2019 51612019 7 Rig Inspection 4 41292019 41302019 1 Safety Meeting 4 41292019 41392019 1 Split Drill 3 4292019 51132019 14 W Kick While Trippingondl 14/292019 51612019 7 TT Well Kill 2 4/282019 7/272019 S9 Casings seat Cas.Type Colin) ID (in) Grade Top(ftKB) Bottom (ftKB) I TVD Set. like) Run Date OND TOR 2018.25 X65 00 160.0 180.0 6112014 CASING 13318 1242 L-80 0.1 2,8780 2,4638 fi'12 .14 CASING 9518 8.84 L80 00 5,193.0 3,976.4 81192014 LINER 5112 4.95 L-80 5,053.4 15,205.0 4,052.5 61292014 Last Cementing Cementing Start Date: 51192014 farts, CASING, 5,193 OftKB Comment Shut down ng pumps and Schlumberger pumped 10 bids. H2O to fill Tires and Tested Innes to 1,16013,457 psi: good Switched back at pumping 105 bels. of Mud Push II @ 10.5 poll - rate of 5 bpm @ 220 psi. Shut-coan and drop kingdom plug. SLB mix 8 pump Lead slurry 79.5 bels W/ 12.5 ppg Lite CRETE ]1.56 ft3hsk Yield, mix water at seat gatfsk.] - Pump rate of 5 bpm @ 435 psi. Pump Tail Slurry 49 bbl 12 5 ppg Class G [1.16 ft3/sk Yield, mix water at 5.109 gal/skj - Pump ones of 4.5 bpm @ 700 psi. Shut down add tlmp top plug - SLB pump 1D bible H2O and wash up. Displace with 376 ball W/ 94 ppg mud with rig pump at 6 bpm wl 140 psi, fire/ pressure 55D psi., Bump Plug Press. up to 1,050 Psi held 5 Min. Blood 0 floats holding. Cement in place @ 22:09 his. Slga Tap ftKS) Top Was Meth I Ron INKB) Com 1 2,047.0 3,746.0 1 5 pPg MW Push II 2 3,746.0 Temperature Lag 4,683.0 12.5 ppg Lead Cement 3 4,683.0 Temperature Lag 5,207.0 15.50 ON Tail Slurry Job Information Job Phase PwrmW Met oat. Star) Date EM Dew P50 Duration (days) WORKONER 426201900:00 426201900W 0.00 Daily Summary Operations 24h Forecast Finish POOH V2.282'110, 4-112' Mg, to ESP assembly. Baker Centralift UD pump, seals, moor assembly. Clear/clean Noor and install wear bushing. Prep for dean out operation. 24h Summary Compete BOP as per Cason procedure and Surdry. RM) loom test, GE Vetco pulled blaMdng plug and BW PN lending Mint WU to hanger- third pull came Bee @ 175k, GE Vetco/8a1ar d.c mplew hanger and -0 same with Landing Mint. POOH with ESP assembly f/4,566- U2,282% NoteTotal loss for the day =SP12SE3 =156 bible. Operation at 07.00 UD ESP Assy rime Log Stare End Cum Dur Time Time our(hr) (hr) Phase I Op, Act. Plan Oper. Descr. 0000 01:90 1.00 1.00 W.O. L 5 P N1U BOP- Finish installing ow line, sub drip pan, tlrain hoses, inatell accumularor M1ytlraulic hoses on stack. 01:00 03:00 2.00 3.00 W.O. L 5 P ChaWeoWsa rsubontopddwtopW5TT525aMinswllbellguides-PutlGeb6./21ua,mAnnu1usA 0300 04:00 1.00 4.00 W O L 1 P RN W teal BOP- WU S TT525 Dalt and TIW valves -Prep aM P/U 4-12" test joint. 0400 0530 1.S9 5.50 W.O L 12 P Funs ion test SOP from dog house panel. Fluid pack system and perform a shell test U35W psi. Put 10 tbls.2 hrs. in Annuals A. 0530 1130 8.00 1150 W.O L 12 T Perform BOP task to Doyon procedure and A CC Sundry an 4-12" and 5" tuedars-Matt Henere wit AGGCC waived witness of the. Test Annular W 250 psi. 125M psi. and remaining camporenw to 250 psi. / 35M psi. All charted encoded for Burns Pedortn aaumularor tlrew tlown-pass. Tested gas daec5on alarms. M, and flaw show -peas. SIMOPS- Installed! can Np in active piw, Re- Mon and cap sheaves in tlemck. Put 10 bals.2 hrs. in Annulus A. 11'.30 13:09 1.50 1300 W. L 5 P WD test equipment -Law dawn dI test lirres and.,po nts. Suck out coup stack aM put 10 bbl./2 hrs. m Annulus A with 11.0 ppg NmBr bene. SIMOPB: Imtalle i centdPoge in active pits. 1300 1400 1.00 14.00 WO. L 5 P RN- remove blanking plug and pump BPV per GE Veroo rep. 17.00 Wo. L 1 14:00 1700F250 P R/U GER power pack and tongs to ng Boar. WU GE Baker Ce trifift aquipmam demnnpletion. IrewIt emimnmental hose (elephant buck) On ESP sheave in derrick. Load spools into unit. Add 10 bbis.12 his. in Annulus A with 11.0 Filing Natter edge. 17:00 1930 19.50 W 0 L 4 P PJ M - PA) landing jail and WU Into tag hanger, vastly AnnNus A static. Production shot fluid in annulus with eche meter - 370'. Stage up weight and this pulled tag. hangs tree @175k. Up wL=1151,1 Du M.= 100k. Pull Mg harga m ng Boor. Add 10 bbls.2 hrs. in Annulus A withl l 0 ppg Na Br brine. 1930 2100 21.00 W.O. L 5 P GE Veto and! Baker tralift it smrpded BOB hanger, remove penelrawr, prep caP lary line and ESP cable to be WII Mm nigh sheave w spending unit. UD hanger/puPs and [among joint 2100 0900 240 W . L 4 P POOH wiit., Onsomer, as per tally - UD 4-12'ft. 4,565'-U2,MT MD. Up wL=851,/Dn wt=Wk. Atld 5 Dblslt hr.M assist in washing o6 ESP cablei4 112" tbg. No returns M surface. Note: Total loss far the day is SP12SE3 =156 bels. Total sum Rao wdl bare =1135 bans. Gas Readings Avg Background Gas f%j Max Background Gas (%) Av90onnecaon Gas (%) Max Connection Gas ('/.) Avg Drill Gas (%) I Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%) Daily Mud Volumes TaniAddOiordLoss Type Gas Volumafbbl) Tank 594.0 Loss 156.0 Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 4/29/2019 Report #: 4 Page: 2 of 3 Daily Mud Volumes TandgedilbNLoss Type Des Volume(bbp Here 8030 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (6611 Additions (bbl) Cum Adtlilions (bbl) Losses (bbl) Cum Losses (bbl) 1,19].0 6030 0.0 0.0 156.0 542.0 Daily Contacts Position Contact Name Company Title Email OfOce Mobile Eni representative Simone Selemmt Eni Drilling Supv. sidddllingaeni.wm 9D76856715 Enirapresenta8va Bence Simaomn Ent Drilling Supv. adddlling@Smi core 90]685.0]15 Eni representative David SmM Ere Drying Supv. Eni representative waste Thames Eni Rig Clerk WlgChxks0oyan15@orxcm 90]685-0]22 Eni representative Pat Ahem Eni HSE Era representative Louis Arceneebr Eni HSE Drilling Supt Sam Dye Doyon Drilling Field superintendent Tool Pam Ryan Panemixt Doyon Drilling Tool Pusher ngl5Qdoycnd6IImg.wm Tool Push Einer Fleagla Doyon Dnlling Taol Push Ted Push CRY Owena Doyon Dnlling HSE warns®tloyorgrlling.win 685-0796 Tod Pum Devana Sam, Doyon Drilling HSE dsena@doyontlrlling.com 685-D]96 Personnel Log (POB) Company Serv. Type Work IN (hr) Stand-by H(h4 Count Note SLB Cement 12.50 0 Dnlling Eni Fluids Supervisor 12.50 0 Dming ASRC Clerk 12.50 1 Drlling ASRC SOA 12.50 1 SID Support ASRC Crane Adviser 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Won Field Si pens endenl 12.50 1 Onyiig Eni Company Man 12.50 1 Dnlling Norham Oilfaild Services Feeler 12.50 1 SID Support Vetw(BHGE) Weill -lead 12.5o 1 Dnlling ACS Enviromerdal 12.50 2 SID Support ASRC Comparry, Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tad pushem 12.50 2 Drilling Dayan HSE 12.50 2 Drilling Halliburon Mud Loggers 12.50 2 Will, Ml Swam MW Engineer 12.50 2 Willing GSR Casing Casing Service 12.50 2 Doling coopebnka Logistic 12.50 4 SIDSupport Baker Cenblift 12.50 4 Drilling Halliburan Wireline 12.50 6 Drilling MI Sacco Mud Plant 12.50 6 Drilling Parcel Security 12.50 6 SID Support Ml Santos WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Jambs Truck clever /Crane operator 12.50 14 Drilling Doyon Rig Personnel 12.50 26 Dnlling_Total Dnlling Personnel BOP Stack 8 Components Description Start Dab Last Ceriocation Date Pressure Rating(pu) Type Make Model ID Nom (in) P Range (psi) Lasl Ler Date Slow Circulation Rates Pump Number. Make: Model: Star Date End Date Liner Size (in) Volume Per Stmke Override ibbl)slk) Max Pressure (psi) Data Depth (it") Stan, Spy Strokes (spm) P (psi) ER 1%) 0 Flo.lgpm) Daily Bulk Supply Item Description: Equipment Fuel Unit label: Gal Unit Size:1 Note: Date Consumetl Received Returned Cum Consumed Cum Received Co. Returned Cum On Lae Nole 4/292019 853.0 8530 3,850.0 3,8500 00 0.0 Supply Item Descnptlono Mud Plant Boilers Unit Label: Gal Unit Size: Note: Oats Consumetl Receivetl Relurnetl Cum Consumed Cum Received Cu. Rabrn.E Cum On Loa Note 4292019 42.0 420 16B.0 168.0 0.0 00 Supply Ism Description: Fig Fuel Unit Label: gal us Unit Size: 1 Note: DataConsumetl Returnetl Cum Consumed Cum Received Cum Returned Cum On Loc Note reserved 4292019 1,7960 0.0 8,]82.0 26,822.0 0.0 20,040.0 Supply Item Description: NO water Unit Label: bbl Unit Size: t Note: %Date Consumetl Received Returnetl Cum Consumed Cum Received Cum Returned Cum On Loa Note 111019 fi6.0 135.0 151.0 32].0 D.0 1760 Supply Item Description: WIFBdkrs Unit Label: Gal Unit Size: Note: Dafa Consumetl Receivetl Relurnetl Cum Consumetl Cu. Receivetl Cum Returned Cum On Loc Note 4/2912019 198.0 198.0 792.0 792.0 0.0 00 Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Data Consumed Receivetl Returned Cum Consumed Cum Receivetl Cum Relurnetl Cum On Loc Net. 429)2019 4200 4207 2,100.0 2,100.0 00 0.0 Last Authority Visit Date Tot insp. Nbr Tool I.N.C. number Comment STOP Cards Submitted Company 11 Rpts cam Doyon Dnlling13 i.xv. Wyon Drilling Inc. ID Sar. Cards Doyon out, Inc 13 HRWS Doyon Willing Inc. 13 COW Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 4/29/2019 Report #: 4 Page: 3 of 3 STOP Cards Submitted Company a Rpts Com MI Sweco MI SMco 6 8 H UJSN RIRs General Notes Comment WeName: E3 OR Wellbore bore Name: e: SPSP12-SESE3 Well Code: 27979 no rte, i n' Job: WORKOVER e WCER Level: Daily Report Date: 413012019 Report #: 5 Page: 1 of 3 Well Header PermiVConcesshm N° Operator Subsidiary Initial Lahm Code ADL -388583 ENI PETROLEUM ENI Peboleum Co. Inc. DEVELOPMENT WELL O POMO DI COLTIVAZIONE Rotary Table Elevation gin Water Depth Ia) First Flange (K) RKB -Base Flange (K) RKB Tubing Spool (R) 53.94 1]23 36 ]1 31.80 Rigs Rig Name Contractor Rig Type Rig Num Rlg Start Data Rig Release Date RIG 15 MON LAND RIG 0723 41252019 Daily Information Weather Temperature (°F) Wind Days LTI (days) Days RI (days) POB Fag 24.8 NE @ 11 MPH 556 00 556 00 10fi.0 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Data (tlays) BOP Pressure Test 1 4292019 5162019 6 Rig Inspection 5 4/302019 5112019 1 Safety Meeting 5 44302019 5112019 1 Both Drill 3 42)12019 5/132019 13 TT Kick While Tripping Drill 2 9302019 5912019 7 TT Spilt Dtlk 1 44302019 5/142019 14 TT Well Kill 2 4282019 7272019 88 Casings seat Cas. Type Do (in) ID lin) I Grade Top(RKB) I BOKom(RKB) I TVD BoI(KKB) I Run Data CONDUCTOR 20 1825 X65 0.0 1600 169.0 0112014 CASING 13318 12.42 L-80 0.1 2,878A 2,4fi3.a 6/122014 CASING 9548 8.84 Lao 0.0 5,193.0 3,9]64 WlMO14 LINER 512 4.95 LSO 5,053.4 15,205.0 4,052.5 6292014 Last Cementing Cementing Start Date: 0V192014 String: CAsNG, 5,193.011M Comment: Shut down ng pumps and Schlumberger pumped 10 bole. H2O to fill lines and tested lines to 1,16013.457 psi: pod, Switched back ng pumping 105 bits. of Mud Push II @ 10.5 ppg - rate of 5 bpm @ 220 psi. Shutdown and drop bioao n plug. SLB mix a pump Lead slurry 785 Lips W412.5 ppg Lite CRETE [1.56 Nd1sk yield, mix water at 5.461 gadrsk) - Pump rale of 5 bpm @ 435 psi. Pump Tail Sturry49 bbl 12.6 ppg CMss G (1.16 Irldk yield, mix water at SAN gallsk.)- pump rate of 4.5 bpm @ 700 psl. Shut down antl dmp top plug - SLB pump 10 bbls H2O and wash up. Displace with 376 HAs W/ 9.4 ping mud with ng pump at 6 bpm w/ 140 psi, final pressure 560 psi., Bump Plug Pressup to 1,050 psi held 5 Min. Bleed off floats holding. Cement in piece @ 22 00 firs. Stg# Top lftKB) Top Meas Meth Stm(aKB) I Cam 1 2,04].0 3,]46.0 10.5 ppg Mud Push It 2 3,]46.0 Temperature Log ,683.0 12.5 ping Lead Cement 3 4,683.0 Temperature Log 5,207.0 15.80 ppg Tag Slurry Job Information Job Phase Planned Start Data Start Data End Date P50 Duration (days) WORKOVER 412620190000 426201900:00 0.00 Daily Summary Operations 24n Forecast Finish PAJ 5' TT525 dell Pipe - Total 54 stands in derrick. Perform PM2 on equipment. Prep to for cleanout assemoly. PN VACS deanout assembly as per GE Baker rep. RIH with 5° TT525 drill pipe b -4,685' and start wean down to 5,433' as par GE Baker. POOH continue adding 10 When hr. of 1 I ppg NalBr brine. 24h Summary POOH with ESP assembly 12,282'- V91', LID ESP pumpwslarinotorishroutl assembly per GE Baker. R/D GBR tongs arta GE Baker decompletion equipment and Wit damps, dear add dean dg floor. Load 20 joints 2-7f8" PHA into pine shed. GE Vetdd install wear bushing. Seance by drive, draw -works. ST -100 roughneck. PAJ 46 stands of F TT52519.5# drill pipe. Add 10 bbls 2 hr. of 11 o ping Naar brine w well bore. Note: Total loss for the day= SP12-SE3 =141 ibis. Operation at 07.00 Prep Vacs Tool to RIH Time Log Start End Cum our Time Time our (hr) (hr) Phase OF, Act. Plan Oper. Descr. 0000 0300 3.00 3.00 W.O. L 4 P POO w ESP assembly as Ferrell, - LID 4-11 tbg f2,282'- V315' MD, Up wt= 75k Add 5 hil hr. of 11.0 ppg NalBr brine to help wash off ESP cabled -10 flog. SIMCPS: Change out liners in #3 mW pump 114-112% do' 03:00 04.00 1.00 4.00 W O. L 25 P Electrical issues with ESP spooler in writ ENI mountain trouble shoot- probable motor over heed, restart unit Electrician mention while POOH. Atltl 5 bbls.11 M of 114 ppg NWBr bine- SIMOPS: Change not liners in #3 mud pump f14 -1Z -V6'. 04M 0500 1.00 5.0 W.O. L 4 P Continue POOH sum ESP assembly as per rally -L,,4-12" too. 11315'-V91'MD. Atltl 5 Wall hr. of 1 to ppg Na/Br brine to help wash out ESP cebe1412' fig. SIMOPS: Change out liners in 113 mud pump. Remove 4-112" Ib9 from pipe shed. Add 5 bbla/l hr. of 11.0 ppg NalBr bride. 0500 Ugo 300 8.00 W.0 L 5 P Terminate MLE to cable and perform electrical dmcks ESP -no good. Set r shroud in mmry tablo and PAUUQ ESP discharge gauge /gaugegreed jewel pump, seals, and motor from same. Found MILE blown spooled cable at shroud split mg assembly, check motor found good, Note: Found small amount of solids inside shroud an motor. Add 10 plots hr of 11.0 FM Nader brine to wall bore. SIMOPS. Change out liners in #3 mud pump. 08:00 13.00 5.00 13.00 W O. L 1 P UD 7' shroud to pipe shed. Load pipe shed with 20 joints of 2-7/8" 7.9 # P1+6 pipe. RID GSR tangs and GE Baker Carroll tool boxes, damps, spools and Gear rig floor of all nensessen5al equipment and components. Remove shroud and Ibgman pine shed. Geon rg floor. SIMOPS: Charge liners in #3 mud pump 1300 1330 0.50 13.50 W . L 5 P GE Verso rep installed wear pushing -9' ID / 13-12- OD 124' length 13:30 1800 4.50 18.00 W.O. L 1 P Continue cleaning and organiang rig. R/D and dtange art rig tongs from HT -100 t0 HTA5, ramose weight plates hum counterbalance system 0 adjust fortongs weight i iaerences. Mob menMe hole m pipe shed Serviceand inspect top drive. Put 10 bbts.2 hrs. in wall. 18:00 1830 0.50 18.50 W.O. L 4 P Install mouse hose inrotarytable-service T-100 antl tlraw-worts. 1630 00.00 5.5o 24.00 W.O. L 4 P PJSM-PIU 6 TT525 drill pipe MAU stands in mouse hole and rack back in derrick. torque all connection Look Total 46 stands. Atltl 10 bbls2 W. of 110 ppg Na S, /sine to well bore. Nota: Total loss for the day= SP12SE3 =141 bible. Note: Total sum toowal bore =1276 blob. Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas I%) Max Connection Gas (%) An no Gas (%) Max Drill Gas (%) Avg Trip Gas 1%) Max Trip Gas (%) Well Name: SP12SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 4/3012019 Report #: 5 Page: 2 of 3 Daily Mud Volumes Tank/AtltlitiwlLoss Type Des Vol... (W) Tank 813.0 Less 41 0 Hoe 613.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (b4/) Additions, (bbl)Cum 1613D Additions (bbl) Losses (bbl) Cum Losses (bbl) 1 026.0 100 0.0 1141.0 683.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Simone Belemmi Eni pilling Supv. mcidnlling@eni.com 907885-0715 Eni repressertative Bmw Simuskn Em pilling Supe. .iddtllling@enLwm 907885-0715 En representative Dend Smith EN Drilling SW, Eni representative We&Thomas EN Rig Clerk AKRgCler1uDoynnl5@emi.wm 9078854]22 Eni representative Pat Ahem Eni HSE Eni representative Louis Arceneaiu Eni HSE Drilling Suq. Sam Dye Doyon Drilling Field Superintendent Tool Push Ryan Pankm2 Doyon Dulling Tool Pusher ngl5@dopndnlling.wm Tool Push Einer Flmgle Doyon Drilling Tool Push Tool Push Cliff Omens Doyon Wiling HSE coneare c1c,sndnillin,com 685-0796 Tod PushDave Sena Doyon DNling HSE aaene@leyondnlling.win 685-0796 Personnel Log (PA Company Serv. Type Work H (hr) Sbnd-by H (he) Count Note SLB Camara12.50 0 Drilling Eni Fluid. Supervisor 12.50 0 Dolling ASRC CNuc 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Adviwr 12.50 1 SID Support Beaten fund. 12.50 1 SID Support Wien Field Superintendent 12.50 1 pilling Eni Company Man 12.50 1 Dulling Northam Cmuld Services Fueler 12.50 1 SIDSupport Vetw(SHGE) WeflHeatl 12.50 1 Dolling Baker Fi3Nng 12.50 1 Oiling ACS EnviromenWl 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Silicon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Wiling Doyen HSE 12.50 2 pilling Halliburton Mud LNgen 12.50 2 Detling Ml Swaw Mud Engineer 12.50 2 Drilling Baker Conniff 12.50 2 Drilling GBR Casing Casing Service 12.50 2 Drilling Caenpereards Logistic 12.M 4 SID Support Halliburton Wireline 12.50 6 Oiling MI S.. Mud Plant 12.50 6 pilling Purcell Security 12.50 6 SID Support Ml Swann WIF 12.50 7 SID Support ESS Catering 12.50 10 SID Support Jacobs Truck darer/ Crane operator 12.50 14 pilling Doyon Rip personnel 12.50 26 DrillingTotal Dolling Personnel BOP Stack 8 Components Description Start Date fast Certification Dale Pressure Rating(,,) Type Make Model IO Nom (in) PRange (psi) List Cert Dale Slow Circulation Rates Pump Number: Make: Mendel: Start Data End Data Liner Sim (in) Volume Per Stroke Override ibbllstk)ax Pressure (psi) Date Depth(ffli Slow End SVokes(a m) P(psi) ES(%)M OFlow (gpm) Daily Bulk Supply item Description: Equipment Fuel Unit Label: Gel Unit Size:1 Note: Dale Consumetl Received Relumetl Cum Consumetl Cum Received Cum Returned Cum On Loc Note 4/302018 1211.0 1,211.0 5,0810 I 5061.0 0.0 0.0 Supply Item Description: Mud Plant Balbrs UnitLabel: Gal Unit Size: Note: Oate Consumetl Received RNumetl Cum Consumetl Cu. Received Cum Returned Cum On Loc Note 4/302019 42.0 42.0 210 0 210.0 0 0 0.0 Supply Item Daseription: Rig Fuel Unit Label: gal us Unit Size:i Note: Date Consumed Received Returned Cum Consumed Cum Receivetl Cum Returned Cum On Loc Note 4/30/2019 1,5080 00 8,290.0 26,622.0 0.0 18,532.0 Supply Item Description: Rig Wator Unit Label: bbl Unit Size:I Nate: OneConsumetl Receivetl Relumetl Cum Consumetl Cum Receivetl Cum Returned Cum On Loc Note 4/302019 43.0 00 194.D 327.0 0.0 133.0 SupplylNm Description: WIF Balers UnitLabel: Gal Unit Size: Note: Date Consumetl Receivetl Reterned Cum Consumed Cum Received Cu- Returned Cum On Loc Note .302019 198.0 198.0 990.0 9900 0.0 0.0 Supply Item Desen flon: WIF Injected Cancer Unit Label: Gal Unit Size: Note: Dale Consume Receivetl Returned Cum Consumed Gum R. reed Lum Returned Cum On Loc Note 4/302019 420.0 4200 2,520.0 2,520.0 0.0 0.0 Last Authority Visit Data Tolman. Nb7 Total I.N.C. number Comment STOP Cards Submitted Company ft Rents Co. Doyon Dulling 17 PJSM'S Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 413012019 Report M 5 Page: 3 of 3 STOP Cards Submitted Company p Rpts Com Doyon OnIhng 1.. Doyon DMIMg 1.. Doyen Ddi irg Inc. MI Sworn MI Sworn 13 17 17 B 5 safe Cams HRWS COW RIR's W C/JSA General Notes Comment: Well NameOR : Wellbore Name: e: SP12 SP72•SESE3 Well Code: 27979 Job: WORKOVER ani WIDER Level: Daily Report Date: 5/1/2019 Report p: 6 Page: 1 of 3 Well Header PermiVCOncesslon N' Opens Subsltllary Initial Lane¢ Code ADL -388583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL O PO= DI COLTIVAZIONE Rotary Table Elevation RI) Water Depth IN) First Flange(a) RKB -Base Flange(N) RKS - Turing Spod(N) 53.94 1].23 36.]1 31.80 Rigs Me Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON /ANO RIG 0]23 4252019 I Daily Information WeatherTemperature PAI "ad Days LTi jdays) Days III (days) POB Overcast 2].8 E@18 MPH 557.00 55].00 1000 Safety Incidents - Near Miss Data Category Type Subtype Seventy Cause Lost fimaT Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) BOP Pressure Test 1 4292019 57612019 5 Fire Drill 1 51112019 5115I2019 14 Kick While Tripping 1 Slimly 51812019 7 Rig Inspection 6 5112019 522019 1 Safety Meeting 6 5112019 5212019 1 Spill bell 3 4292019 5/132019 12 TT Kick While Tripping Drill 2 41302019 5"2019 6 TT Spill Dril 1 0302019 5/142019 13 TT Well Kill 2 4282019 ]2]2019 87 Casings seat Cas.Type OD (in) to (in) Grade Top(NKB) Roffom(NKB) TVD But. lake) Run Date CONDUCTOR 20 18.25 X65 0.0 1800 ifi00 6/12014 CARING 13318 1242 L-80 0.1 2,8]80 2.463.8 6IZ014 CASING 9518 8.84 LBO 0.0 5,1930 3,976.4 Wl WO14 LINER5112 4.95 L-8() 5,MA 15,205.0 4,052.5 fit&2014 Last Cementing Cemenling Start Dale: fi1192014 String: CASING, 5,193 OVKB Comment Shut down 09 pumps and Schiumberger pumped 10 bis. H2O to fill lines and tested lines to 1,160/3,457 psi.- good. Switched back rig pumping 105 bbb. of MW Push II @ 10.5 ppg - rate of 5 bpm @ 220 psi. Shutdown and drop bottom plug. SLB mix & pump Lead slurry 79.5 bis WI 12.5 ppg Lao CRETE 11.56 ft3/sk Yield mix water at 5.461 gaVsk.) - Pump rate of 5 bpm @ 435 psi. Pump Tail Slurry 49 bbl 12.5 ppg Class G 11.16ItNsk Yla'd, mix water at 5.109 pv.k ) - Pump nate of 4.5 bpm @ 700 psi. Shut down and drop top plug - SLB Pump 10 Wis H2O and wash up. Displace with 376 bis W) 9.4 ppg mud with rig pump at 6 bpm awl 140 psi, final pressure 550 psi., Bump Plug Pressup to 1,050 psi held 5 Min. Masai off floats holding. Cement in place @ 22:00 him Be # Top (NKR) Top Meas Meth Btm (NKB) Cons 1 $04].0 3."'a 10.5 ppg Mud Push II 2 3748.0 T imesmtuhe Lag 4,1383.0 12.5 ppg Lead Cement 3 4,683.0 Temperature Lag 5,207.0 15. SO ppg Tell Slurry Job Information Job Phase Planned! Start Dab=t' tan Gate End Data 450 Duration (clays) WORKOVER 426201900:00 426201900:00 000 Daily Summary operations 24h Forecast Continue POOH with 2-718' PHS tbg b bosom flappers, recover and cunOrm tubulars clear. RIH with BHA #2 (same configure as iii Wash clown f/4,800'- t1-5,450'. POOH to check VACS ton. 24h Summary Finish PN S TT525 dil pipe - Total 54 stands in denick RID GBR ones. Mob GE Baker 001mp0nants to rig door and pipe shed NVU GE Baler 2-718" ibg and VACS clean-out assembly. RIH V4,800and wash down V5,450'. POOH 1/5,450'- V833'. Work VACS BHA #1 as per GE Baker rep ate LID 2-718- PHS ibg. f1622'- t218', continue adding l WIs.2 hi of 11.0 ppg Ni bine. Note: Total lass for the clay on SP12-SE3 = SAID Cis. Operation at 07.00 RIH with VACS BHA Time Log Start End Cam our Time Time Dur/M1r) lhr) Phase Der. I Act. Pian Opef. Desch. 00:00 0200 2.00 2.00 W.0 M 4 P Completed PN 5" TT525 dnil plpe, MN stands in mouse We, set back in derrick, RoMue all connection #501. Total 54 -opens. Add 10 bb¢ 2 fin of 11.0 ppg Naar anise to well bore. 02:Oo 03:30 1.50 3.50 W . M 5 P NU GBR tangs. Perform PM'S on equipment. 03:30 06:30 300 6.50 W.O. M i P PN GE Baker clean out tools m ng flonr and pipe sM1etl. 0630 1130 5.00 11.50 W.O. M 4 P MID Baker dean -out BHA as per rep. MAD tail pipe Min half mule shoe assembly, P1U 201ouda 2-718" PHS29#/P110 tbg. Continue to PAI and M upper section d VACS tad assemNy per GEBsken Add 10 bis.2 M1r. of 11 0 ppg Na'er Mine to -3 well bore. 1130 14.30 So 14.50 WO M 4 P RIH vnth GE Baker VACS 07`90'- 94,800 on 525 drill pipe. Up wt= k I Cum =120k. Add 7 W1sl he o 1 ppg Nx/Br bane to well bore. 1430 77:00 2.50 1100 V-0-- M 9 P Wash clown f/4,800'-115,450 insill, up pump 6 bpm @ 1060 psi to ] bpm @ 1450 psi Tag @ 5,010' with Sk pick-up Sand rotate X tum and contends washing down. WN 528 Wis. pumped retunw to surface, shut down and observed And dropping in hole W,O. M 1700 20.30ji.024.00 4 P Blow dawn and POOH V5.450 '- Off wath 5- TT525 dil pipe. Fill bole wiM 11.0 ppg brine, calculated metal displacement plus 5 Wis.11 fir. Up wt. 851,/ on wt= 75k. 20:30 22:30 W.O. M 4 P Work BHA #1 as per GE Baker rep. Clean magnets and covered 51bs. of fire metals, both boot basket were empty, Recovered''. gal. of difione antl fine sands with som.... ll rock hour VACS banal. Add 7 WN.12 hr. of 11.0 ppg Nak, brine to well bore. 22:30 00:00 W.O. M 9 P Continue POOH W 2d/8" Pfs61Pd10".9# ib9. to the pipe shed 8622- V2 con /ming dear Ul w7.= 55k IOn w7.= 551,. Add 7 bbls 2 hr. of 11.0 ppg Na1Br bene io well bore. Note'TOG/loss far me day=SP12SE3=660W1s. Toolsumw fooellbore=1936bis. Gas Readings Avg Background Gas (%) Maz BackgrouM Gas;%d Avg Connection Gas l%) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas 1%) Avg Trip Gas (%) Max Trip Gas 1%) Daily Mud Volumes TimidAdditlan/LOss Type Des Volumes(bbl) Tank 50 Well Name: SP12SE3 OR Wellbore Name: SP12SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 51112019 Reportk: 6 Page: 2 of 3 Daily Mud Volumes TanklAdditionlLoss Type one Val...(bbi) Loss 6630 Hole 613.0 Cumulative Mud Volumes Active Volume (bat) Hole Volume (bbl) Additions (bbl) 1,338.0 6130 0.0 Cum 0.0 Additions (bbl) Losses (bb0 Cum Losses (bbl) 880.0 1,343.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Ent representative Simon. helemmt Ent Drilling Supv. Uddrilling(Neni.com 907ti65A715 Ent represertafive Bmce Smansan Em Drilling Supv. siddr1fr,@xnj... 9076854715 Em representative David Smith EnI Drilling Supv. Ent representative Mitch Billington Ent Rig Clerk AKRgCleftDoyonl5@eni.c xn 907685-0722 Ent representative Pat Ahem Ere HSE Ent representative Louts Am.neaux Ent HSE Drilling Supt. Sam Dye Doyen Drilling Field Superintendent Tod Push Ryan Pankratz Doyen Dolling Tool Pusher ngl5@doyondrillingcom Tool Push Ted Kroger Doyon Drying Tour Pusher ngl5@enicom 9076850716 Tool Push GIU Ovens Doyon Wiling HSE cowena@doyondi iltng.com 685-07% Tad Push joeve Sena Doyon Wllmg HSE clean S lopildnlltng com 685-0796 Personnel Log (POB) Company Serv. Type Work H(hrl Stand-by H(hr) Count Note Halliburtan Wirmtne 12.50 0 Dniling Baker Centnlifl 12.50 0 Dulling ASRC Clerk 12.50 1 Dnlltng ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Mark. 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Dulling Ent Company Man 12.50 1 Drilling Northern 011faid Services Fu her 12.50 1 SID Support SLB 12.50 1 Drilling Vetco(BHGE) Way -lead 12.50 1 Dulling Ent Management 12.50 1 Drilling Baker Fishing 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Dotson Tom pushers 12.50 2 Ddiing Wynn HSE 12.50 2 Dulling Halribunon Mud Loggers 12.50 2 Wiling MI Swaco Mad Engineer 12.50 2 Wlltry CUR Casing Casing Service 12.50 2 Wiling Wm,Wntta Logistic 12.50 4 SID Support Purcell Security 12.50 6 SID Support Ml Swaco Mud Plant 12.50 7 Drilling MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Jacobs Tmck dwer/Come operator 12.50 14 Wiling Doyon Rig Personnel 1 12.50 124 1 Wlling_Total Drilling Personnel BOP Stack 8 Components Description Start Date Last Certiikation Gate Pressure Rating 1psi) Type Make Model ID Nom kh) PRange (ps0 Last Cert Date Slow Circulation Rates Pump Number: Make: Madel' Start Data Entl Date Liner Shia (in) Volume Per Stroke Override (bbbstk) Max Pressure (psi) Data Depth (HKB) Slow and Strokes Japan) I P (Psi) EH (R) 0 Flow (gpm) Daily Bulk Supply Item Description: Equipment Fuel Ung Cabal: Get Unit Stze: 1 Date Consumetl Receivetl Returned Cum Oonsumetl Cum Re[eivetl Cu- Returned Cum On Loc Note 5112019 986.0 9660 fi,047.0 6,047.0 0.0 0.0 Supply ]tem Description: Mud PWM gagers Unit Label: Gal Unit Size: Note: Data Consumed Receivetl ReturnedCum Consumed Cu. Received Cum Returned Cum On Loc Note 5/1/2019 420 42.0 252.0 252.0 - 0.0 00 Supply Rem Description: Rig Fuel Unit Label: gal us Unit Size:1 Note: Gala Consumed Received Retumetl Cum Consumetl Cum Receivetl Cum Retumetl Cum On Lac Nme 5112019 16750 0.0 9,765.0 26,8220 0.0 17,057.0 Supply learn Description: Rigwater Unk Label: bbl Unit Size:I Note: DataConsumetl Received Retumetl Cum Consumetl Cum Receivetl Cum Returned Cum On Lac Note 51112019 35.0 00 229.0 327.0 C.0 98.0 Supply its. Description: WIF Boilers Unit Labor: Gal Unit Size: Note: Data Consumed Received Retumetl Cum Consumed Cum Received Cum Returnetl Cum On Loc Him. 12 5/019 198.0 198.0 1,188.0 1,188.0 o.0 Ce Supply Item Description: WIF Injected Diesel Unit Label: Get Unit Size: Note: Data Consumed Received Returned Cum -Consumed I Cum Received Cum Returned Cum On Loc Nole 51112019 4200 420, 1 2,940.0 12,940.0 0.0 0.0 Last Authority Visit WW Tot insp. NM Total I.N.C. number Comment STOP Cards Submitted Company Is Rick Com Doyon Dnliing 13 PJSM'S Doyon Drilling Inc. 13 COW Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 5/1/2019 Report #: 6 Page: 3 of 3 STOP Cards Submitted Company # Rpts Com Doyon Odlling Inc. Doyon Dulling Inc. Ml Swaco Ml Swaco 13 B 8 6 HRW6 Safe Cards RIR's HARC/JSA General Notes commem: Well NameOR : Wellbore Name: e: SP12 SP12-SESE3 Well Code: 27979 Job: WORKOVER ani WCER Level: Daily Report Date: 5/2/2019 Report #: 7 Page: 1 of 3 Well Header Permi6Loncesaion N° Operator Subsidiary Initial"hee Code '01388583 ENIPETROLEUM ENIPstroneum Co. Inc. DEVELOPMENT WELL O POaO DI COLTIVA ICNE Rotary Table Elevation(.) Water Depth(.) First Flange (ft) TR -Base Flange (ft) RKB-Tubing Spool (ft) 53.94 1223 36.]1 31.80 Rigs Rig Name Conbacror Rig Type Rig Num Rig Start Data Rig Release Dale RIG 15 OOYON tANO RIG 0]23 Q25IM19 Daily Information Weather Temperature(°F) Wind Days TI (days) Days Rl(days) POB Partly Cloudy 186 E@38 MPH 558.00 55800 96.0 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost lime? Comment Safety Drills Days Until Next Check Type a Occur Last Date Next Date (days) BOP Pressure Test 1 4729/2019 51612019 4 Fire only 2 522019 5/162019 14 Kck While Topping 1 511/2019 Si 6 Rig Inspection 7 522019 5/3/2019 1 Safety Memng 7 5/212019 5WO19 1 Spill Drill 3 412912019 51132019 11 TT Kids While Tripping Drill 2 41301 18 5912019 5 TT Spill Drill 1 4/3012019 5/14/2019 12 TT Wait Cornton Drill 1 52/2019 WIWO19 14 Tr Well Kill 2 428/2019 727/2019 86 Casings seat Cas. Type OD (in) ID (in) Grade Top (.KB) Bottom (RKB) TVD Bot. (IRS) Run Data CONDUCTOR 20 18.25 X65 0.11 160.0 160.0 &112014 CARING 13316 12.42 LEO 0.1 2,878.0 2,4fi3.B 6H22014 CASING 95/8 8.84 180 0.0 6,193.0 3.9]6.4 61192014 LINER 51/2 4.95 LEO 5,053.6 15,205.0 4,0525 6129/2014 Last Cementing Camen6ng Star) Dale: 6/19/2014 String: CASING, 5,1930hKB Comment: Shut dawn no pumps and Schlumberger pumped 10 bbs. H2O to fill lines and tested lines to 1,160/3,457 piL-good. Switched back 69 pumping 105 bola. of Mud NO II @ 10.5 ppg - rate of 5 bpm @ 220 psi. Shut -down and drop bottom plug. SLB mix & Pump Lead slurry 79.5 bids W/ 12.5 ppg Lite CRETE (1.56 ft3/sk Yield, mix water at 5.461 galhkJ - Pump rate of 5 bpm @ 435 psi. Pump Tail Slurry 49 blot 12.5 ppg Class G (1.16li Yield, mix water at 5.109 gaVsk.)- Pump rale of 4 5 bpm @ 700 psi. Shut down and dmp top plug - SLB pump 10 bbls H2O and wash up. Displace with 376 Nils W/ 9.4 ppg mud with ng pump at 6 bpm w/ 140 pal, final pressure 550 on,, Bump Plug Press. up to 1,050 psi heal 5 Min. Bleed o6 floods hokfing. Cement in pace @ 22:00 has, beg p Top (.KB) Top Meas Me@ I BM (RKB) I Com 1 94] 0 3,] 10. ppg Mud Push 11 2 3.]45.0 Temperature Log q,6Bj.o 12.5 ppg Lead Cement 3 4,683.0 Temperaoae Lag 5,20].0 15.80 ppg Tail Siurry Job Information Job PhasePlannetl Start Date Start Data Entl Date P50 Duration (days) WORKOVER 426201900:00 462620190000 000 Daily Summary Operations Zan Forecast Continue SIR with Baker VACS d4,ID5'. STIP and cut drilling line. Continue RIH wasNmtate as per GE Baker rep. POOH with VACS assembly and work BHA M. 20 Summary POOH 0218' with 2-7/8' PHE tog to bottom flappers, recover 2-12 gallon of son'Ms. Replace air boot In bell nipple riser. RIH with Baker clean-out BHA M. Wash down fIQ865'- V5,544'. POOH-workSHAM Baker VACS roof -no recover. Replace air boon element on ball nipple. Redress and conduct 2-7/1 dear. RIH - P/U 2418- PH46 tbg and GE Baker VACS man surface - V 2,474', Note: Tool Toss for the day= SP12-SE3 =1045 ods. Operation et CLOD POOH with clean out BHA at 546(' MD Time log Start End Cum our Time Time our f i (hr) Phase Cox. Act. Plan Oper. Damon 0000 02'0 2.00 2.00 V05- M 4 P CorthansPoOHLiD2-71W PHE rog to surface, rec0varetl 25 gallons insinsumnsfinesandarecondered in upperflapper and hating in lower Cagier. AOd 7 b1Ae 2 hr. of 11.0 ppg Nal& bane m well. 0200 0390 1.00 3.00 W.O. M 25 P Clean m; floor for 2nd clean out run. - Change out leaking air boot on bell nipple riser. D3:00 0500 2.00 5.00 W.O. M 4 P P/U and M1U -7/8" PH -6 mg. and Baker deem BHA M as per rep 1990'. Add 7 MNsQ hr. of IDS ppg Na/Br bona. UP wt= 701, / Dan wt= ]Ikk. 0500 W:00 2.00 7.00 W.O. M 4 P RIH with Baker VACS f99P-04,855' an TTT525 drill pipe. Up wt = 150k Too vn.=701, Add 7 bola /2 hr. of 10.8 ppg NTBr once. It90 1100 4.00 11.00 W . M 9 P Wazh dawn 04.861 V5, 191' pump rate 6 b m @ 1100 psi. Wash/rotate 115,191'- P 05,544same Pump rate 30 runningWis. Min @ 6Ek torque. Got some returns b surface @366 obis. pumped with 0-20% returns flow senses, Loral of 706 bola. wiM of 10.6 ppg NalBr bone. 1190 1430 3.50 14.50 W.O. M 4 P PJ M- POOH rack badk5'TT525 dd11 pipe f/5.545- v]90'. Up w[.= BOk I On w1= BOk. FII pipe displacement plus a ] bbla2 hr.himfame 108ppg abrins. 1430 1900 450 19.00 W.O. M 4 saiith CS 00 wM akar VA assembly and Sb 2-7/B- P dig. to the pipe had - mu e. ecovae7 S Its. meal P Cess fines Iran magneto small amount from fines in VACS baml antl SHB mg. Up win;SSk / on WL, 55k. Add 7 hr. of S 11.0 ppg NalBr bone ro wall boa_ Simops, Clear and Leen ng floor Service and insped top dove, draw-woda, ST -100 floor pe 7-100 roughneck. 19:00 2130 2.50 21.50 W.O M 25 P Foorld Ooo on bell nipple air boot leaking. PIU net nipple riser om annular and change out air Such Atltl ] bible hr of 10, 8 ppg Naar ohne in well after replaced. peg N 2130 2300 1.50 23.00 W.O. M 4 P MN cleBHA #3 az per Baker rep. From mule shoe 0]90'. Add 7 b hr. of 10.6 ppg Nape brineer well Nae. 23'00 0000 1.00 2400 W.O. M 4 P FUH 5' T W 7 f990- 92,414'. Up wt =100k / on vA = 98k. Atltl 7 bible 12 he of 10.6 ppg NalSr brine to well bore. Th S-TT525mu Note Note: Tonal bas too Ue day = SP12-SE3 =1045 bits. day Note: Total sum too wall bore = 2981 bola. Gas Readings Avg Background Gas (%) Max Background Gas (°F) Avg Connection Gas (%) Max Connection Gas 1%) Avg Drill Gas (%) Max Drill Gas (%) Avg Tdp Gas (%) Max Trip Gas )%) Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 5/212019 Report *: 7 Page: 2 of 3 Daily Mud Volumes Tank/Addition/Lose Type Des Volume (bbl) Tank 425.0 Loss 045.0 Hole 598.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (W) Additions (bbl Cum Additions (bbl) Losses (blimit)Cum Loaves (bbl) 1,025.0 5980 00 00 1045.0 2,388.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Enirepesentative Simone Belemrn EN ffnlling Supv siddrilling@eni. com 907E854)715 Em representative Bruce Simonson Ent Drilling Supv. siddnlling@eni.Con 907E85-0715 Ent representafive Dev1C Smith Ent Drilling Supv. Eni representative Mitch Billington Eni Ry Clerk AKRigClerksDoyon155g<em win 907E854)722 Ent rapresartam. Pat Ahem Ent HSE Eni representative Louis Arcereaux Eni HSE Drilling Supt. Sam Dye Dgvn Dilbkg FIeM Supertntentlent Tod Push Ryan Pankreb, Doyon Dolling Tod Pusher ngi5@doymMiling.com Tod Push Ted Kruger Dayon Billing Tour Pusher ngl5@eni.com 907E850716 Tool Push Herald Ridlartivon Doyon Doling HSE Inchardson®doyondnlling_wm 685-0796 Tool Push Dave Sana Doyon Drilling HSE dsena@doyvodelling.con 685-0]96 Personnel Log (POB) Company Serv. Type Work H (hr) Standby H (hr) Count Note Doyon Field Superintendent 1250 0 Drilling Ent Compeer, Men 12.50 0 Wiling Halliburton Wireline 12.50 0 pilling Baker CeMnitfl 12.50 0 Drilling ASRC CIeA 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Northern Olfetld Services Fueler 12.50 1 SID Support SLB 12.50 1 Wiling Vince(BHGE) WellHead 12.50 1 pilling GBR Casing Casing Service 12.50 1 wiling Baker Fishing 12.50 1 Wiling ACS Envaomenlat 12.50 2 SID Support ASRC Company Man 12.50 2 pilling Beacon HSE 12.50 2 SID Support Doyon Tod pence 12.50 2 Wiling Doyon HSE 12.50 2 Wiling Halliburton Mud Loggers 12.50 2 Drilling MI S.C. Mud Engineer 12.50 2 Wiling Competent. Logistic 12.50 4 SID Support MI Samoa Mud Plant 12.50 6 Dicing Purcell Security 12.50 6 SID Support Ml Swaw WIF 12.50 8 SID Support ESS Catering 12.50 /0 SID Support Jacobs Trod driver/Crane meander 12.50 14 Drilling Dmypn Rig Personnel 12.50 25 10,611in9jotal pilling Personnel BOP Stack 8 Components Description Start Data Leal Certification Date Pressure Ragng(Fail Type Make Model ID Nom (in) P Rings pat) Last Cert Dale Slow Circulation Rates Pump Number: Make: Model; Start Data End Data Liner Size (in) Volume Per Stroke Override(bbl/sik) Max Pressure (psi) Data I Depth INKS) $low Sptl I Snake. (sen) P (poi) EN 1%) 0 Flow (gpm) Daily Bulk Supply Item Description: equipment Fuel thrift"Ind! Gal Unitsu.:1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 5/2/2019 1,0710 1,W1.0 7,118.0 7,118.0 0.0 0.0 Supply Itam Description: Mond Plant Bdlers Unit Label: Gal Unit Stze: Note: Dale Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 5YZ2019 42.0 42.0 294.0 294.0 00 0.0 Supplyllem Description: Btg Fud Unit Label: gal us Untt Size:1 Note: Dela Consumed Received Relumetl Cum Consumetl Cum Received Cum Returned Cum On Lac Note 522019 1,543.0 0.0 11,608.0 26.822.0 0.0 15,214.0 Supply Item Description: Rig Water Unit "bet: bbl Unit Size:1 Note: Date Consumetl Receivetl Returned Cum Consumetl Cum Received Cum Returned Cum On Loc Note 5IZ2019 100.0 135.0 329.0 462.0 0.0 133.0 Supply It.. Desedption: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 5122019 1980 198.0 1,38fi.0 1,386.0 0.0 0.0 Sapp ty Item Desaon: WIFlnjedad Dtevel Unit Label: Gat Unit Size: Nate: Data ConsumedReceived Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 522019 4200 420.0 3,360.0 3,360.0 co De Last Authority Visit Dale 7.11..,. Nb, Total I.N.C. number Comment -cards STOP Submitted Company p Rats Com Doyon Oiling 9PJSM'S Doyon Oiling Inc. 10 Bak Cartls Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 5/2/2019 Report #: 7 Page: 3 of 3 STOP Cards Submitted �amWM Y Rpt. Com Doyon Dnng Inc. Doyon DriItIlin9lnc- MIS.. MI Swaco 9 9 S 6 HRWS COW RIRc HARC/JSA General Notes Comment: Well NameOR : Wellbore Name: e: SP12 SP12-SESES Well Code: 27979 Job: WORKOVER 2n i WCER Level: Daily Report Date: 5/3/2019 Report #: 8 Page: 1 of 3 Well Header PermiblConwssion N' 0perabr Subsidiary Initial Lahee Code ADL388583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELLOPOZZO DI COLT"", E Rotary Table Elevation (N) Water Depth (N) First Flange (N) RKB - Base flange pp RKB - Tubing Spool (N) 53.94 117,23 13671 131,80 Rigs RigName Continuator Rig Type Rig Num Rlg lNart Data Rig Release Date RIG 15 OOYON LAND RIG 0723 4/252019 Daily Information Weather Temperature EF) Wind Days LTI(days) Days FU (days) POB Clear 24.9 E@28 MPH 559.00 559.00 104.0 Safety Incidents - Near Miss Data Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type #Occur Last Data Next Date (days) OF Pressure Test 1 429/2019 5/6/2019 3 Fire Drill 2 5212019 5/1612019 13 Rick Will Tripping 15/12019 5/8/2(119 5 R9 Inspection B 5132019 5/42019 1 Safety Meeting 8 5/3/2019 5IV2019 1 Spill Drill 3 42912019 5/13/2019 10 TT Kick While Tripping Orill 2 4/302019 5/22019 4 TT Spill Dull 1 41302019 5/14/2019 11 TT Wall Control Drill 1 5122019 5!162019 13 TT Well Kill 21412812019 17127ROIt, 1 85 Casings seat Cas. Type 1 00 (at) ID (I.) Grade TOp(ftKB) Began (Me) I TVD But.(NKB) Run Date CONDLI TOR 20 18.25 0.0 1 0.0 160.0 Us off120t4 CASING 13 3/8 12 42 0.1 2.8]8.0 "mut 6/122014 CASING 9S/B 8.84O F111DI Ill 5,193.0 39784 6/192014 IMT2014 LINER 51/2 4.950 5,053.4 15,205.0 4,052.5 Last Cementing Cementing Start Date: W19/2014 String: CASING, 5,193.000 Comment Shutdown rig pumps and Schlumberger pumped testae H2O to fill lines and tested lines to 1,16013,457poi: good. Switched back lig pumping 105 bars. of Mud Push II @ 10.5 ppg - rate of 5 bpm @ 220 psi. Shutdown and drop bottom plug. SLB mix 8 pump Lead slung 79.5 table Wl 12.5 plug Lite CRETE (1.56 Welk yield, mix water at 5.461 gaill - Pump rate of 5 bpm @ 435 psi. Pump Tail Slurry 49 bbl 12.5 ppg Class G (1.16 N31ak yield mix water at 5.109 gal/sk.] - Pump rate of 4.5 bpm @ 700 psi. Shut down and tlrop top plug - SLB Wrap 10 bbls H2O and wash up. Displace with 376 bible Wl 9.4 ppg mud with rig pump at 6 bpm wl 140 psi, final pressure 550 psi., Bump Plug Press. up to 1,050 psi held 5 Min. Blood off floats holding. Cement In place @ 22:00 his. Sig # Top (NKBI I Top Meas Meth Bim (NKB) Com 1 2,04 .0 3,748.0 10.5 ppg Mud ush II 2 3,]46.0 Temperature Log 4,683.0 12.5 ppg Leatl Cement 3 4,683.0 Temperature Log 5,207.0 15.80 ppg Tail Slurry Job Information Job Phase Planned SMrt DateStart Date Entl Date P50 Duration (days) WORKOVER 4/26201900:00 428201900:00 0.00 Daily Summary Operations 24h Forecast Continue washing to 5861'eft BHA #4 per Baker rep. POOH and check results of VACS tool. Run same assembly as BHA 45 - g good results -minima dean out trips. 24h Summary RIH with Baker VACS V4p05'. Slip and cut dulling line. Continue RIH washing f/4,705'-115,562' wasNrotats as Per GE Baker rep POOH with VACS assembly BRA K3. Recovered 2 In, metal /0.20 W. of surd/fines in 2-718' PHS Big. Reduce Nal brine weight to 10.5 ppg. RIH with BHA 04 - lead 30 joints 2-71W HP -6 tbg in pipe shed. PN 10 more joints of 2-718' PH -6 tbg and RIH V 4,803'. Wash (14,803'-115,510' as pre GE Baker rep. Note: Total loss for Me day =SPt2-SE3 = 918 bbis, Operation at 07.00 Laying down cleanout BHA Time Log Start End Cum our Time Time Our fhr) (hQ Phase I Opr. Act. Plan Oper, Descr. 00:00 01:00 1 00 1.00 W.O. M 4 P R H with 5 TT525 drill pipe f2,474'- V4,705'. Up wL=1521, / on wt=115k. Add 7 bills./2 hr. of 10 6 ppg Na/Br brine to well -2 bare. 01:00 03 oo 3.00 W.O. M 25 P PJSM- Slip and cut drilling line -cut 94, adjust kink back rollers and brake bands, dean draw -works drip pan, calibrate hack load call for weight ire icaWr 0390 08:00 3.00 600 W 0. M 9 P Wash down f/4,864'-115,363' wit 6 bpm @ 1150 psi. Wa mdhAafe /5,363'- V5,563'same pump rate c 6 bpm @ 1160 psi. Rotation 35 rpm @ 9.2k torque. Stop rotafion @ 5,558' and slack oft to above line top, After pumping 455 billsreturns to surface with 12-21%ft.. Total 505 bible of 10.6 ppg Ne1Br once. Up al 155k on ai 11 51,. 0600 0990 3.00 9.00 W.O. M 4 P PJ M-blowdowntop Cnve,POOHfI, 3'-V883'. Upw!.= en= 70k. Fill withp'pe r di splacement antl edtl ] bbls.2 hr. of 10.6 ppg Na/Bi bnrre to well bore. 09:00 1200 3.00 12.00 W.O. M 4 P POOH f/883- poll le with VACS assembly -Recovered 2 fin, of fine metal from magnets, bes, boot basket where empty and UO to pipe shed. Check VACS assembly banal - found small amount of sludge. Not and rack back in devil Continua POCH UD 2-718' PHS pegto pipe shed, fowl last joint had mlida nes about 0.20 bbl. Add 7 obis n hr. of 10.6 ppg NalBr brine to well bore 1200 1430 2.50 14.50 W . M 1 P Close blind rams and pe rine (fluid level shot with echo meter results 481'. Reduce Nal brine weight to 10.5 ppg in the active pifs and built B91 bbis in mud pant. The 2-718" PHS ibg. amved. Clean and clear floor- service and mail rig equipment, perform PM2 work orders. 1430 1700 2.50 1790 W.O. M 4 P wu Baker BHA #4 flapper assembly onto 2-7/8- P&6 tbg (P1 IW 6#1WTS3) and RIH 11622'. Lead 30 joints of 2-718- PHS big into pipe shed -strap and tldft. 17:00 1900 2.00 19.00 W.O. M 4 P Continue P/U 2-7/8 PHS tag f1622'-1/951 with XO. M7U to remaining Baker VACS assembly combo test as per Baker use (1951'-V1. 101'. 1900 2200 3.00 22.00 W.O. M 4 P RIH wit BHA #4 Baker VACS tool with T TT525 drill pipe f/1,101'-114,803'. Up wt: 1551,1 Do al, 115k. 22:00 0000 2.00 24.00 W.O. M 9 P Wash down V4,80l V 5,390- wit 126 spm @ 280 psi. with no refusal or returns - @ 238 bbisawaygot retums @ 24% - dump 38 bbls.to cuffing box, weighted 10.8 ppg and dean - took returns W pit #5. Common washing 1/5390- V561W with increased rate of 318 gam @ 1710 psi. with 24% return rate. Note. Total Toes for the day = SP12SM = 918 bbis. Nota'. Total sum We well bore = 3899 bills. Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 51312019 Report #: 6 Page: 2 of 3 Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas 1%) Max Trip Gas (%) Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) auk 420 0 Loos 97 0 Hole 57ZO Cumulative Mud Volumes AeUve Volume Irbil) Hole Volume(bbi) Additions(bbl) Cum Additions(bbl) Losses (liked) Cum Losses (bbl) 9970 577.0 0.0 0.0 918.0 3,306.0 Daily Contacts Position Contact Name Company TWO Email office Mobile Ent representative Simone Belemmi Eni Drilling Supv. sitltlnlling@em.wm 901-885-0715 Eni representative Brace Simonson Eni Dulling Be,. siddnlling@enLcom 907-685-0715 Eni representative David Smith Eni Drilling Sup, Eni representative Mitch Gillingham Ed Rig Clerk AKRigCl.r1zDxon15@eni.cem 907-685-0722 Em o presenlals. Pat Mem Eni HSE Ent representative Louie Arce.. Eni HSE Drilling Supt Sam Dye Doyon Drilling Field Superintendent Tool Push Ryan Penkratz Doyon Drilling Tool Pusher rig15@doyondn1ling.rom Tod Push Ted Kroger Own Drying Tour Pusher ugl5@eni..m 907-6050716 Tod Push Harold Richardson Doyon Pilling HSE hrichardeon@dwridnlling.com 685-0796 Tod Pugh Oave Sena Doyon Drilling HSE tlsena@doyondnntng com 685-0796 Personnel Log (POB) Company Sent. Type Work IN (hr) Spn6by H(hr) Count Note Doyon Red Supemdendent 12.50 0 - Drilling Ent Company Man 12.50 0 Drilling Halliburton Wireline 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASPIC SOA 12.50 1 SID Support ASPIC Crane Adviser 12.50 1 SIDSupport Beacon Medic 12.50 1 SID Support Ndrihem Dillard Services Fueler 12.50 1 SID Support BLE 12.50 1 Drilling Vintco(BHGE) WeIlHead 12.50 1 Drithe GBR Casing Casing Service 12.50 1 Drilling Baker I'mbing 12.50 1 Drilling ACS Einiromenlal 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Dulling Doyon NEE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Eamon Mud Engineer 12.50 2 Drilling Compntentia Logistic 12.50 4 SID Support MI Sween, Mud Plant 12.50 6 Drilling Purcell Security 12.50 a SID Support Baker Centmift 12.50 7 Drilling Ml S.. WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Jacobs Truck driver/Crane opmater 12.50 14 Drilling Own Rig Personnel 12.50 26 Drilling Total Pilling Personnel BOP Stack 6 Components Description Start Date Last Certification Data Pressure Rating(psi) Type Make Model 10 Nom (in) P Range god) Last Oen Date Slow Circulation Rates Pump Number: Make: Modelo Start Date End Date Liner Size (in) Volume Per Stroke Override(bblistk) Max Pressure (psi) Data Depth(RKB) $low Slid Strokes (spm) P(psi) EH(%) 1 0Flow(gpm) Daily Bulk Supply Rem Description: Eeuipmmt Fuel link Label: Gal Unit Size:1 Note: Date Consumetl Receivetl Returnetl Cum Consumed Cum Receivetl Cum Returned Cum On Loc Net. 5,32019 906.0 9170 8,038.0 6,0360 0.0 0.0 Supply Item Description: Mud Plant 6oikvs Unit Label: Gal Unit size: Note: Data Consumed Receivetl RemmM Cum Consumetl Lum Received Cum Returned Co. On Lee Note 5132019 42 0 q2.0 336.0 336 0 0.0 0.0 Supply Ilam Description: mg Fuel Unit Label: gal us Unit Size: 0 Note: Dale Consumetl Received Returned Cum Consumed Cum Receivetl Cum Returned Cum On Loc Note 5/32019 1.934.0 00 13,542.0 26,822.0 DO 13,280.0 Supply Item Description: Kg Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned tum Consumetl Cum Received Cum Returned Cum On Lae Note 5132019 6].0 00 3960 462.0 0.0 66.0 Supply Item Description: WIF Bwlers Unit Label: Gal Unit Size: Nate: Date Consumed Receivetl Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 5/32019 1970 19(1.0 1,584.0 1,584.0 0.0 0.0 Supply Rem Description: WIF Injected Diecei UnHLabel: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Receivetl Cum Returned Cum On Loc Note 5,312019 420 4200 3,780.0 3780.0 0.0 00 Last Authority Visit Data Tot insp. Nor Total I.N.C. number Comment Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 5/312019 Report #: 8 Page: 3 of 3 STOP Cards Submitted Company r Rpts Co. Doyon Drilling 11 PJSM'S Doyon Drilling Inc. 11 COW Doyon Dnlling Inc. 11 HRWS Doyon Dnlling Inc. a Safe Cards MI Swaco 8 RIR's Ml Swaco 6 HARClJSA General Notes Comment: Well Name:E3 OR Wellbore Name: e: SPSP12-SESE3 Well Code: 27979 Job: WORKOVER (en i WCER Level: Daily Report Date: 5/4/2019 Report #: 9 Page: 1 of 3 Well Header PermiV(toncession N' Operator SubsitllaryInitial Lobes Code AOL -388583 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL O Pi DI COLTIVAZIONE Rolary Table Elevation (R) Water Depth (R) First Flange (R) RKB - Base Flange IN) RKB - I hung Spool (R) 53.94 17,23 36.]1 31 80 Rtgs Rig Name Cconnector Rig Type Rig Num Rig 81art Data Rig Release Date RIG 15 DOYON IAND RIG 0723 4/2512019 Daily Information Weather Temparature ff) Wind Days LTl(day.) Days RI (day.) POB Overcast 31.1 E @ 22 MPH 550.00 560.00 1102,0 Safety Incidents - Near Miss Dela Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type P Occur Last Date Next Dale (days) BOP Pressure Test 1 412912019 &6/2019 2 Fire Drul 2 5=019 5/16 19 12 Kick While Tripping 2 5/42019 5111/2019 7 Rig Inspection 9 5( 12019 &52019 1 Safety Meeting 9 &42019 5/52019 1 Sell DMI 3 4129/2019 5/13/2019 9 TT Kick While Tripping Drill 2 4/3&2019 6/12019 3 TT Spill Drill 1 4/30?2019 5/142019 10 TT Well Cmaml Drill 1 5,12019 &162019 12 TT Well Kill 2 1 4/28/2019 ]2]2019 84 Casings seat Cas.Type Do (in) to (in) Grade Top UIIKS) Bottom(ME) TVD BaLI2 Run Dale NDUCTOR 20 18.25 %85 0.0 180.0 160.0 &12014 CASING 13318 12A2 LA0 0.1 2.878.0 2,463.8 6/1220/4 CASING 9618 8.84 180 0.0 5,193.0 3,9]6.4 &192014 16gi14 LINER 51/2 4.95 LA0 5,053.4 15,205.0 4,052.5 Last Cementing Cemerding Start Date: 8/192014 String: CASING, 5,193.011 Comment: Shut down ng pumps and Schlumberger pumped 10 oils. H2O to fill lines and tested Imes to 1,16013,457 psi - good. Switched back rig pumping 105 toils. of Mud Push II @ 10 5 not - rate of 5 bpm @ 220 psi. Shut -down and drop bottom plug. SLB mix & pump Lead slurry 78.5 bibs W112.5 ppg Ute CRETE [1.59 ft&sk Yield, mix wanes at 5 451 gaVsk.] - Pump rate a 5 bpm @ 435 psi. Pump Tail Slurry 49 bbl 12.5 ppg Class G [1.16 ftWsk Yield, mix water at 5.109 gallsk] - Pump rate of 4.5 bpm @ 700 psi. Shutdown and drop top dug -SLB pump 10 bila H2O and wash up. Displace wOh 376 bila W/ 9.4 ppg mud with nig pump at 6 bpm w/ 140 psi, final pressure 550 psi., Bump Plug Press. up to 1,050 psi held 5 Min. Bleed off floats holding. Cement in place @ MDO hos. Sig 0 Top (RKB) Top Meas Meth Bim (RKB) I Co. 1 2,04] 0 3,746.0 10.5 ppg Mud Push II 2 3:7 Temperature Log 4,883.0 12.5 ppg Leatl Cement 3 4,683.0 Temperature Log 5,207.0 15.80pm Tail Slumy Job Information Job Phase Planned Sun Dale Start Data End Dale P50 Duration (days) WORKOVER 426201900:00 412&201900:00 O.Op Daily Summary Operations 24h Forecast POOH and check BHA 05 of sands, Clean assembly and reassembly- RIM with BHA O6, wash down V-5880'. POOH possibly W 5' TT525 doll pipe or MU and ran ESP completion assembly 2Ah Summary Wash V5,510'- V5,859' as per GE Baker rep with gardal means. POOH (/5,859'- Vi, I OV- work BHA kV assembly- recovered 7 gal. sludge. Clean rig floor. MN BHA 85Flappers 0 2.7/6" PH-8lig RIM and remaining VACS assembly Vi, 101'. RIM f/1,101' -V4,685'. Wash f/4.NF-V5,880'. POOH 85,860'-0885'- check VACS tool assembly and star UD 2-718" PHA hg. Note: Total loss for the day= SP12SE3 = 803 tabs. Operation at 07.00 POOH & UD 2-718' PHA togto pipe shed found last joint had solkle fines MN & RIM with clean out BHA O6. Time Log Start End Cum Our Time Time on, bit (hr) Phase Opt, Act. Plan Dow, Descr. 00:00 01:30 1 50 1.50 W.O. M 9 P Wash down f/5,510' -V5,857 wih 318 gpm @ 1720 psi. of 10.5 ppg brine with 234 W%. pumped got padlal retums wind 24% and with 325 bblspumpetl took returns to ph 115 with 27%. Increasetl flaw ones to 343 gpm @ 1980 pal. with return rate of 27% on bottom. Up wt.=170k/ Do wL= INk. Add 7 bbls.2 Is. & 10.5 ppg. 01:0 04:30 3 W 4.SO W 0 M 4 P P M -blow down top drive. POOR V5,869i V1,101'. Up wt.= 75k I On wi 70k Fill with pipe displacement and add 7 bbN./2 hrs. of 10.5 ppg Na Tir bone in well. 0430 0700 2 50 7.00 W.O. M 4 P POOH f/1,101'-11951' checkand dean VACS assembly- recovered 1 lb. of fine metal from magnets, both boot basket where empty UD to pipe shed Break and check VACS banal had 5 gallons sludge, WU and rack beck in derrick. Pipe dlsp icemant plus and 7 bbis.2 his. of 10.5 ppg. 0700 1030 350 10.50 W.O. M 4 P PODHI UD 21 PMS rig 0 pigs shed - above tap flapper Ian joint and pert of the second had sludge, recovered 025 bbl. Add 7 bbls.2 hrs. of 10.5 ppg. 10:30 11'.30 1 1 00 11.50 W.O. M 4 P leen rig float and flapper valva assembty ro first pion of 2-]/B" PHA. Add 7 bbls./2 hrs. COS ppg. 11:30 1430 3.00 14.50 W.O. M 4 P Continue P/U 2-718 S fi PHg VS51' wfth %O. WU the remaining Baker VACS assembly combo text as per Baker rep. Ug51'- V1,101'. Add 7 bblsl2 hrs. of 10.5 ppg. 14:30 16:30 200 16.50 W.O. M 4 P RIM with 8HA85 Baker VACS Won 5'TT525 dull pipe V1,101'- , Up wt.=180 n wt.= . Adtl bbla2 hrs. of 10.5 ppg. 16:30 1900 2.50 1900 WO M 9 P Wash dawn 114, '- V 5,345' with 126 gpm @ 260 psi, with no mutton, with 14 Is, away got returns @ 24% -took mums no pit AS Continue washing (/5,345'- VS,SW with increased rare of 316 gpm @ 1710 Psi. with 27%return when pumping, fluid level dropped when Pumps shut own. Add 7 bils2 hrs. of 10.5 ppg. 1900 22:00 3.00 22.00 W.O. M 4 P Blow down top drive - POOH 85,869-V1,101'.Upwt=80kf Onw 8%8%, Flt with ape displacement andadd 7 bblahis of 10.5 ppg Rican brine in wall. 22:00 2330 1.50 23.50 W.O. M 4 P UD upper BHA assembly with Pump out sub,jars/bumper and, magnet (recovered l/2 has of fines), scraper ani hoot baskets (empty). Check VACS tobl (no recover) MN and rock back in derrick. FII with pipe displacement and add 7 hi 12 hrs. of 111.5 ppg Neer brine in well. 23'.30 0000 0.50 24.00 W.O. M 4 P POOH UD 2J PH -6 tog 51'-VS85'. Up wt=58k/Dn urn= 581. Add 7 bbls 12 he of 10.5 ppg Naar bine in well. SIMOPS: Moved work shop. Note: Total lass for the day = SP12SE3 =893 bi Note: Total aura too well bore = 41`92 bible. Well Name: SP12-SE3 OR Wellbore Name: SP12SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: SM12019 Report #: 9 Page: 2 of 3 Gas Readings Avg Background Gas (%) Mae Background Gas (%) Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max Will Gas (%) Avg Ino Gas (%) Max Trip Gas (%j Daily Mud Volumes Ta/L nklAddilionoss Type Des Volume but)Tank 4570 Lass 8930 Hole 6110 Cumulative Mud Volumes Active Volume (bbl) Hole Voluma (bbl) Atlditions ball Cum Addihons (bbl) Losses (hot) Cu- Losses (bull 1,068.0 611.0 00 OA 893.0 4,199.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Simone Selemmi Ent Wiling Supv. siddrilling,@enoom 907-686-0716 Eni represemabve Brace St.... EDI Drilling Su,. siddiling@eni.com 907-685-0715 Ent representative David Smith Em pilling Supv. Ent representative Mitch Billirgbn EN Rig Clark AKRigClerksD gool5®emcorn 907-685-0722 Em representative Pat Ahem En HSE Eni represomlive Louis Arceneaux Eni HSE Drilling Supt. Sam Dye Doyon Calling Field Superintendent Tool Push Ryan Pankratr Doyon Drilling Tool Pusher igtS@doymndulling.win Tool Push Ted Kroger Doyon Dmitri, Tour Pusher rig I5Qeni.wm 907-6850716 Tool Push Hilo old Richartlsan Doyon Drilling HSE h idnardswodoytonEMling.win 685-0]96 Tool Push Dave Sena Doyon Drilling HSE dsena@do ndnlling.com 685-0796 Personnel Log (POB) Company Sam. Type Work H (hr) Standby H (hr) Count Note Dayton Field Superintendent 12.50 0 Dulling Ent Company Man 12.50 0 Dnllilg Heltiburkm Wireline 12.50 D Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Athmer 12.50 1 SID Support Beacon Medk 12.50 1 SID Support Northern Oilfeud Services Fueler 12.50 1 SID Support SLB 12.50 1 Willing yet. gBHGE) Wellhead 12.50 1 Dulling GBR Casing Casing Service 12.50 1 Dulling Baker Fishing 12.50 1 Drilling ACS Environmental 12.50 2 SID Support ASRC Company Man 12.50 2 pilling Beacon HSE 12.50 2 SID Support Doyon Tod pushers 12.50 2 pilling Doyon HSE 12.50 2 Willing Halliburton Mud Loggers 12.50 2 Dulling MI S.. Mud Engineer 12.50 2 Drilling Conn"terma Logistic 12.50 4 SID Support Baker CeMriliR 12.50 5 Drdiirg MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Supped Ml Swaco WIF 12.50 0 SID Suppod ESS catering 12.50 10 SID Support Jacobs Track driver/Cmne operator 12.60 14 Drilling Doyon Rig Personnel 12.50 26 Dnlltng_Total Willing Personnel BOP Stack 8 Components Description Start Date Last Certificatton Data Pressure Rating (Pat) Type Make Model ID Nom(I.) PBe... (,I) Last Cert Data Slow Circulation Rates Pump Number: Make: Model: Start Data End Data Liner Size (in) Volume Per Shake Ovemde (bb11stk) Max Pressure (psi) Date Depth little) Slow Suit Strokes (.pm) P(pi it ERI%) DFlow l9pm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size:1 Note: Data Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 514/2019 1026.0 10260 9,062.0 19,062.0 lao 0.0 Supply Item Descdpgon: Mud! Plant Boilers Unit Label: Gal Unit Size: Note: DaleConsumetl Receivetl Retumetl Cum Consumed Cum Received Cum Returned Cum On Loc Note 5/42019 42.0 42.0 378.0 3]8.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Ddte Consumed Receivetl Relurnetl Cum Consumed Cum Receivetl Cum Returned Cum On Lac Note 5/42019 1,5360 00 15,0]8.0 28,822.0 00 11.]440 supply Item Description: Rig Water UnitLabel: bbl unit size:1 Note: Data Consumed Receivetl Relurnetl Cum Consumed Cum Receivetl Cum Returned Cum On Loc Note 5/4/2019 510 1350 4470 59].D 0.0 150.0 Supply item Delimitation: WIF Buller. WHLabel: Gal Unit Size: Note: Data Consumetl Received Returned Cum Consumed Cu. Receivetl Cum Returned Gum On Loc Note 5/42019 198.0 198.0 1,782A 1 782.0 0.0 0.0 Supply Item Description: WIF Injected easel Unit Label: Gal Unit Size: Note: Data Consumed Receivetl Returned Cum Consumed Cum Received Cum Returned Cum On I.A. Note 5/6/2016 420.0 42Do 4,200.0 4,200.0 0.0 D0 Last Authority Visit Date Tot insp. Nbr Total I.N.C. number Comment Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 5/4/2019 Report M 9 Page: 3 of 3 STOP Cards Submitted Company IN Role Com Doyon Drilling 8 PJSM'S Doyon Drilling Inc. 20 Safe Cerdc Doyon Drilling Inc. 8 HRWS Doyon Drilling Inc 8 cow MI Swaco 8 RIR'a Ml Swaco 6 HARC/JSA General Notes Comment: Well Name:E3 OR Wellbore Name: e: SPSP12-SE3 Well Code: 27979 Job: WORKOVER 2n WCER Level: Daily Report Date: 5/512019 Report #: 10 Page: 1 of 3 Well Header Permi11Co es"'non N'Operator Subsidiary /-id al Lahee Code ADL -388583 ENI PETROLEUM ENI Petroleum Co. Ina DEVELOPMENT W ELL 0 POZZO DI COLTIVAZIONE Rotary Table Elevation (n) water Utath(h) First Flange (11) RKB - Base Flange (it) RKB- Tubing SPool(it) 53.94 1723 36.]1 31.80 Rigs Big Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LANG RIG 0]23 4/2WO19 Daily Information Weather Temperature (°f) Wind Days LTI(days) Days RI (days) POB Overeast 23.9 E @ 36 MPH 561.00 561 OD 111.0 Safety Incidents - Near Miss Date Category Type Subtype Seventy Came Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) BOP Pressure Test 1 429/2019 516/2019 1 Fire Drill 2 51212019 5/16/2019 11 Kick While Tripping 3 5/5/2019 5/122019 7 Rg Inspection 10 5152019 5/6/2019 1 Safety Meeting 10 515/2019 5/612019 1 Spill Drill 3 4WO019 W1312D19 8 TT Kick While Tripping Drill 24/302019 5172019 2 TT Rig Evacuation Drill 1 5/5/2019 813/2019 90 TT Spill Drill 1 4/3012019 5114/2019 9 TT Well Control Drill 1 5/2/2019 51162019 11 TT Weil KiA 1 2 1412812019 17=019 1 83 Casings seat Cas, Type OD (in) ID (in) Grade Top (ftKB) Bottom (f li I TVD Bot. (RKB) Run Date CONDUCTOR20 16.25 465 0 0 1800 160.0 6/112014 CASING 133/8 12.42 L-60 0.1 2,8]8.0 2,463.8 6142(114 CASING 95/8 8.84 L80 0.0 5.193.0 3,9]6.4 61192014 LINER 512 4.95 L-80 5,053.4 15,205.0 4,052.5 61292014 Last Cementing Cementing Stmt Date: 8/192014 String: CASING, 5,193.MKB Comment: Shut down ng pumps and Schlumberger pumped 10 abls. H2O to fill lines and Issued lines to 1,18013,457 psi: good. SwitNa back ng Wmping 105 bbls. of Mutl Push II @ 10.5 ppg - rant of 5 bpm @ 220 psi. Shut -down end dw Wftom plug. SLB mix 8 Pump Lead slurry 79.5 bible W/ 12.5 pg Lite CRETE [1.56 Miss Yied, mix water at 5.461 gallsk] - Pump rete of 5 bpm @ 435 psi. Pump Tail Slurry 49 bbl 12.5 pg Class G [1.16 h31sk Yield, mix water at 5.109 galbk) - Pump rate of 4.5 bpm @ 700 mi. Shut down and bible tap plug -SLB pump 10 bills H2O and wash up. Displace with 376 bills W/ 9.4 ppg mud with rig pump at 6 bpm wl 140 psi, final pressure 550 psi., Bump Plug Pressup to 1,050 poi held 5 Min. Blsetl o8 floats holding. Cement in place @ 22:00 firs. Sig # Top (hKB) Top Meas Meth Btm INKS) I Co. 1 2, .0 4 "' u 105 ppg Mutl Pmh II 2 3,]46.0 Temperature Log 4,883.0 12.5 ppg Lead Cement 3 4,683.0 Temperature Lag 5,20].0 15 80 ppg Tail Slmry Job Information Job Phase Plannetl Start Data Stan Data End Date P50 Duration (days) WORKOVER 4/28120190000 426201900:00 0.00 Daily Summary Operations 24h Forecast Continue washing down V5,859'. POOH -111,101' - UD Baker VACS assembly and 2-718' PHE dig, check BHA #7 for solids. Vetco to pull wear ring and set teat plug. Perform BOP test -updated AOGCC witness. RJU to ern ESP assembly. 24h Summary POOH 1/885'- VAapperhnule shoe. Recovered 0.3 bill. CleaNclem RIM with BHA AS - NUU happens to 2-7/B° PH -6 and VACS ted on 5- 17525 DP V4885. Wash f/4,885'- V5,860with partial returns. POOH U5,859'- 111,101' - UD 2-7/8' PHE tbA rescreened 005 bbl. fine slutlge. Clean and service dg. RIH wish BNA #7 V4,885' and wash down 5,480'to final rate 341 gpm. Notified AOGCC @ 0800 no. for BOP test. Note. Total less for the day = SP12-SE3 = 809 hiss. Operation at 07.00 Laying down cleanout BHA. Time Log Start End Cum our Time Time our fir) )M) Ach. Plan Oper. Descr. 0000 0130 1.50 150 4 P POOH UD 244'PHE ibg 1685'- Uflapper/mule shoe. 01:30 0230 1.00 250 4 P Beak down Iowernupperflappers, recovered 0.3 bills. above the upper flapper valve. MN flapper assembly to 24/8 tag. Atltl 7 bels./2 hr. of 10.5 ppg No/Br bane into wail. 0230 0500 2.50 500 4 P RIH PIU 2d/8 PHE tbg from pipe shed audience-V95T. WU VACS assembly from denick and IU boot based, srraWr. ;PhaseOpr. magnet, antl bumphome assembly from pipe shed V1,101'. Pump 7 bble Q hr. of 10.5 ppg NMBr brine in well. 05:00 0730 .50 7.50 4 P RIH with 5" TT525 drill pipe f/1,101'-V4SM'. Up wt.=1651, / Dn st=120k, Pump 7 bbls.2 hr. of IDS ppg Na1Br brim into wall07:30 1000 2.50 10.00 9 P Wash down, 114,834'- V5400 wish 128 gpm @ 65 psi. of 10.5 W9 bnne increase to 318 glen @ 1950 psi. and wash down 115,859'. Started gelling parmal returns after 161 bills. pumped @ 24%. Took 35 bbls9 to rock washer patent switching to pit 95. ReciWorate string (/5,859'-115,829' while pumping liners volume 4* limes Up en = 175k / on wt= 120k. Total 484 We pumped / lost 3118 bids. Nate: Notified AOGCC @ 0800 his for BOP test. 10 OD 1300 3.00 13.00 W O. M 4 P PJSM-POOMwMFTT525ddlipi,f[5.859'-YI.101'Up art, 7M/ On wt= 70k. Fill with pipe displacementand add 7 blra2In, of 40.5 ppg Niter Nine in well. 1300 1430 1.50 1-450 W -O --M 4 P POOH f/1.101'- V951' -Magnets clean, both hoot basket empty UD to pipe shed Break and check VA banal -dean, MU and rack back in derrick. Atltl pipe diboacemant plus 7 bbls 2 her of 10.5 ppg NalBr bene in well. 14:30 1700 2.50 1700 WO M 4 P PODIA UD 2-718' HE flog -lastldnt Stuns solids above upper rapper. recovered 0.05 bbl. fine sludge. 77-N 18:30 1.5o 18.50 W.O. M 25 P Clear and clean floor. service mM inspect equipment draw -works, top drive, ST -100 iron roughneck, and PW skate. 1830 2i-ol 2.50 21.00 W -0 M 4 P RIH - WU flapper valve assembly to 24/8' PHE ibg VII MN the remaining Baker VACS assembly combo rod as per Baker rep. (1951'-111,101'. Add 7 bles.12 hr. of 10.5 ppg brine to wall. 21:00 2300 2.00 23.00 W . M 4 P RIH with BHA #7 Baker VACS Idol on 5 TT525 tldil pipe f/1,101'-114,685'. Up wt= 1601, / On wl.= 120k. Add ] bbs 2 he of 10.5 ppg brim, to well. Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 515/2019 Report #: 10 Page: 2 of 3 Time Log StartEnd Cum Dur Time Time DurIM) (hr) Phase -pr. Act. Plan other. Was, 23:00 00:00 1.00 24.00 W 0 M 9 P Wash down 1/4 BBs- V 5.390with 126 qpm @ 210 psi. with no excessive dreg, with 162 bbls. away got partial returns @ 24%. Continue washing (/5.390'- V5,480' increased rate of 318 Win @ 1950 psi, with 26% return when pumping, fluid level dropped! when pumps shut down. No excessive deg encountered. Up on- 165k / Do an, 1251, Note: Total loac for to day = SP12-SE3 =609 bhb. Note: Total sum too well bore = 5401 Ms. Gas Reatlings Avg Backgreuntl Gaz (%) Maz Background Gas (%) Avg Connection Gas I%) Max Connection Gas (•b) Avg Will Gas I%) Max Drill Gas I %) Avg Top Gas (%) Max Trip Gas (%) Daily Mu o umes TanklAdditiomLoss Type Des Volume(bb0 Tank 91 0 Loss 6090 thole 5]7.0 Cumulative Mud Volumes Active Volume (bop Hale Volume (bbl) Additions poshCum Additions (bbl) Losses (bbl) Co. Losses (bbl) 968.0 577.0 0.0 0.0 609.0 4.8080 Daily Contacts Position Contact Name Company Tide Email Mae Mobile Eni representative Bmce Simosp n Eni Drilling Supv. siddrilling@eni.mm 90]-685-0]15 Eni repreaenlative Davol Soulth EJ Drilling Supv. Em representative, Mitch Billington Ern Rig Clerk AKR,CiemsDoyonl5@enccam 907-685-0722 Eni representative Pat Ahem Eni HSE Eni represelda8ve Louis Anceneaux Eni HSE Drilling Supt. Sam D, Doyon Drilling Field Superintendent Tool Push Ryan Pantaatz Doyon Drum, Tool Pusher og15@doymddlling.com Tml Push Ted"ar Daysn DdOing Tour Pusher ogl5@em.cmo 907-6850716 Tool Push Harold Richardson Doyon Drilling HSE hiichartlson@d¢yarain ling mm 685-0796 Tool Push Dave Sena Doyon Dnlnng HSE deem@doyoncriing.com 685-0796 Personnel Log (POB) Company there Type Work H(hr) Stand-by H(hr) Count Nob Doypn Fieltl Superm ardent 12.5) 0 Driging Eni Corona, Man 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Gene Aswan, 12.50 1 SID Support Beacon Mich. 12.50 1 SID Supped Northam Oigedd Services Freer 12.50 1 SID Support SLB 12.50 1 Drilling Baker Fishing 12.50 1 Driong ACS Envimmental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.59 2 Dolling Doyon HSE 12.50 2 Dolling Halliburdn Mud Loggers 12.50 2 Dulling All Swam Mud Engineer 12.50 2 Were Value(BHGE) WellHeatl 12.50 2 Dolling Halllburbn Wireline 1250 3 Drilling GBRCasing Casing Service 12.50 3 Drilling Corrosions Logistic 12.50 4 SID Support MI Swam Mud Plant 12.50 6 D ilio, Purcell Security 12.50 6 SID Supmrt Baker Canil 12.50 7 Drilling AN Swam WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Jacobs Truck driver/Crane operator 12.50 15 Drilling Doyon Rig Personnel 1 12 50 1 26 Dohng_Tolal Drilling Personnel BOP Stack 8 Components Description Start Dab Last Certification Dam Pressure Rating (psi) Type Make Abdel IO Norm (in) PRange 1psil I Last Cart Dale Slow Circulation Rates Pump Number: Make: Modal: Start Date End Dale Liner Store (in) Volume Per Stroke Override 16611501 Max Pressure teal) Date Depth lftKa) Show, age Strokes(spin) P(ge) ER(%) I OFt. D,m) Daily Bulk Supply Rem Description: Equgmem Fuel Unit Label: Gal Unit Size: 1 Note: Dam lConsumed Receivetl Returnetl Cum Consumed Cum Recemed Cum Returnetl Cum On Loc Note 5/52019 120].0 1.20].0 10,2690 10.269.0 0.0 0.0 Supply Rem Description: Mud Plant eNmia can Label: Gal Unit Size: Note: Dam Consumetl Received Returned Cum Consumed Cum Recelved Cum Returned Cum On Loc Note 5/52019 42.0 42.0 4200 420.0 0.0 0.0 Supply Rem Description: Me Fuel Unit Label: gal us Unit Size: 1 Note: Data lemournest Received Returnetl Cum Consumed Cum Received Cum Returned Cum On Loc Nom 5152019 1,650.0 00 16,]260 26,822.0 0.0 10.094.0 Supply Item DescripOcn: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 5/512019 52.0 00 499 0 597.0 0.0 98 d Supply Rem Descrip0an: WIF Sol Unit Label: Gal Unit Size: Note: Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 5/5/2019 Report #: 10 Page: 3 of 3 Date Consumetl Receivetl 53/2019 198.0 198.0 Raturnetl Cum Consumed 1,980.0 Cum Received Cum Returnetl 1,980.0 00 Cum On Loc 0.0 Note supply Ram Ceacriptan: WIF Injected Diesel Unit Label: Gal Unit size: Note: Date Consumetl Receivetl 5/512019 4208 820.0 Rommetl Cum Consumetl 4,620.0 Cum Received Cum Returned 4,620.0 11.0 Cum On Loc 0,0 Note Last Authority Visit Data Tot Irian. Nbr Total I.N.C. number Comment STOP Cards Submitted Company p Rpts Com Doyon Drilling Doyon Dulling Inc. Doyon Drilling Inc. Doyon DMling Inc. MI Swaco Ml Swaco 18 18 18 15 8 6 PJSM' COW HRWS Sea Cartls We HARCIJSA General Notes Comment: Well NameOR : Wellbore Name: e: SP12 SP12-SESE3 Well Code: 27979 Job: WORKOVER gni WCERLevel: Daily Report Date: 5/6/2019 Report#: 11 Page: 1 of 2 Well Header PermIVCUDLBSeian N° OperatorSIIbsMiary /,fiat Le" ee Code ADL -388583 ENI PETROLEUM ENI Petroleum Ox. Inc. DEVELOPMENT WELL O PORO DI COLTIVAZIONE Rotary Table Elevation( ij Water Uepth(R) First mange (n) RKB-Base Flange (fl) RKB-Tubing Sped(fl) 53.94 17.23 3fi]1 31.80 Rigs RigName Contrector Rig Type Rig NumRig Start Data Rig Release Data RIG 15 DOYON LAND RIG 0723 425/2019 Daily Information WeatherTemperature(°F) Wind Days LTI(days) Days RI (days) POB Overcast 17.4 NE @ 17 MPH 562.00 552.00 106.0 Safety Incidents - Near Miss Data Category Type Subtype Severity Cause Loat time? Comment Safety Drills Days Until Next Check Type # Occur Last Data Next Date (days) BOP Pressure Test 2 5/612019 5/132019 7 Fire Drill 3 5162019 5/202019 14 Kick While Tripping 3 5/5/2019 5112/2019 6 Rig klspecron 11 5/62019 592019 1 Safety Meeting 11 5/612019 $92019 1 Spill Drill 3 41292019 8/13/2019 7 TT Kick While Tripping Dist 2 4/302019 5912019 1 TT Rig Evacuation Dnll 1 5/52019 BIN2019 Be TT SpiII DTIII 1 4/302019 5/142019 8 TT Well Central DO 1 522019 5/16,2019 10 TT Weil 1011 2 42812019 ]2]2019 82 Well Kill Drill 12 l5fi&2019 15,13M19 7 Casings seat Cas.Type OD (in) ID (in) I Grade Top(fii Bottom(RKB) TVD BOL(RKB) Run Date CONDUCTOR 2U 18.25 X65 0.0 1600 160.0 6/12014 CASING 133/8 1242 L -BO 0.1 2,1]8.0 2,463.8 6/122014 CASING 95/8 8.84 Lite 0.0 5,193.0 3,9]8.4 WIM014 LINER 5 1/2 4.95 L-80 5,053.1 15,2050 4,052.5 6129/2014 Last Cementing Cementing Start Date: 6/1912014 String: CASING, 5,193.0111<13 Comment: Shut dawn ng pumps and Schlumberger unVed 10 bbls. H2O to fill lines and tested /ices to 1,16013,457 psi: good Switched back rig pumping 105 table. of Mud Push II @ 10.5 ppg - rale of 5 bpm @220 psi. Shut -down and drop bottom PIM. SLB mix 8 pump Lead slurry 79.5 We W/ 12.5 Fiat, Ute CRETE (1.56 Toner, Yield, mix water at 5.481 gaVsk.1- Pump rate of 5 bpm @ 435 psi. Pump Tail Slum, 49 bbi 12.5 ppg Class G 11.16 "A Yield, mix water at 5.109 gaysk j - Pump rate of 4.5 bpm @ 700 psi. Shut down and drop top plug - SLB pump 10 bbls H2O and wash up. Displace with ale bila WI 9 4 ppg mutt with ng pump at 6 bpm w/ 140 psi, final Pressure 55D psi., Bump Plug Pressup to 1,M psi held 5 Min. Bleed oR Moats holding. Cement in place @ Mel) hrs. Stg# Top(RKB) Top Meas Meth BIm(f1KB) Can 1 2,04].0 3,746.0 10.5 ppg Mud Puah II 2 3,]48.0 Temperature Log 4,683.0 12.5 ppg Leatl Cement 3 4,883.0 Temperature Log 5,207.0 15.80 ppg Tail Slurry Job In/ormation Job Phase Planned SbH Date Stan Date Entl new P50 Duration (days) WORKOVER 4/26/201900:00 4/26/201900:00 0.00 Daily Summary Operations 24h Forecast Continue as run in hole with Vac system and perform dean up cycle. Recover m inanal and perforin another cycle d needed. 24h Summary Wash down F/5480T/5859' at 339 gpan at 1950 psi. Pull out of hole recovered small amounts of scale, recovered 3' sludge f/top of lower flapper and lastjoint of 2 718" tubm, was113 to 112 full of sludge. Rig up and test ROPE all tests good, wilneas waived by Brian Bixby of AOGCC. Pull test plug and instill wear ling. Make up clean out assembly and can in hole T11288°. Last 24 hours 299 BELS lost to bole, Max gas�-D units. Operation at 07.00 Pulling out of hole with cleanan BHA. Time Log Stan End Cu. Our Time Time Cur (hr) (hq Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1 00 W.O. M 9 P Cont WD 1/5480' V5859'339 gem @ 1950 psi. 01:00 1000 9.00 1000 WO. M 4 P POOH W BHA. Stand boNLD Baker VACS assemW hive and! small amount of scale WACS, LO 2 7/ stinger, break dawn and deanout upper and lower Mapper valves, recovered T sludge f0op of lower flapper and last pars,of 2 7/1" tubing wast/3 to 1/2 MI of sludge. 1UD0 13-0 3.00 13.00 W.O. M 5 P Gear dean ng floor. Pull WB 8 install lest plug. RU to test BOPE. 13:00 18:30 5.50 18.50 W.O. C 12 P Test BOPE 25013500 psi, all tests good AD= Rep Baan Bixby waived witness to test. 1830 2030 2.00 20.50 W.O. 5 P Blow down test equipment, Choke mawfold, mud and tell lines. Gear Moor of test equipment Pull test plug and set wear bushing. 20:30 00:00 3.50 24.00 W . M 4 P Make up 2 7/B" Baker flesper assembly and Ion in hole T/934' (90 jdnts). Make up Vacs combo tool F/934' and mn in hale T/1289',PU=7Ole. S0=10 k. Pump M hole 7 bbls of 10.5 pp; every 2 hours with no returns to surface. Last 24 hours 299 BELS lost to hole, Max gas-�0 units. Gas Readings Avg Background Gas 1%) Max Background Gas /%) Avg Connection Gas 1%) Max Connection Gas (%) Avg Drill Gas I%) Max Drill Gas 1%) Avg Trip Gas (%) Max Trip Gas I%) Daily Mud Volumes TanWAdtlRionlLoss Type Des Volume(bbl) Tank 420. Loss 299.0 Hole 603.0 Cumulative Mud Volumes Active Volume (bbl) Hale Volume (bbl) Additions (bbl) Cum Additions (bbe Losses (bbl) Cum Losses (bbl) 1,032.0 fi030 0.0 D.D 2990 5,107.0 Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 516/2019 Report #: 11 Page: 2 of 2 Daily Contacts Position Contact Name Company Tide Email ORka Mobile Eni representative M. Simonson Eni Dulling Supv. siddnllirgeni.cam 907-685-0715 EN representative Mike Grubb Eni prillirg Supv. citltlnldng@enipetrdeum coin 90]E85-0]15 Eni representative MBch Blllirgtcn Eni Rg Clerk AKRigC1erksDodml5@am.com 9076856]22 Enl representative Pat Ahem Eni HSE Eni representative Louis Arceneeuz Eni HSE Tool Push Ryan Panbalz Doyon Onllirg Tool Pusher ng15@do,mdnl1ing wm Tool Push Ted! Kruger Doyon Dulling Tour Pusher ngl5@em.cam 907-6850716 Tool Push HBmM Richindson Doyon Dnlim, HSE hrimrerdson@dayondnlling.com 6860796 To Push Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 665-0796 Personnel Log (POB) Company Sale. Type Work N (hr) Stand-by H Ru) Count Note Doyon Field Supenmmntlent 12.50 0 Drilling Eni Com,cm, Man 12.50 0 Drilling Halliburton Wireline 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 $ID Support Beacon Medic 12.50 1 SID Support Nodbem Oil aldl Services Fueler 12.50 1 SID SuPwd SLB 12.50 1 Drilling Baker Fishing 12.50 1 DdBirg ACS Enviramental 1250 2 SID Support ASRC Company Man 12.50 2 Dulling Beacon HSE 12.50 2 SID Support Down Taal pushers 12.50 2 Drilling Down HSE 12.50 2 Dulling Halliburton Mud Le,,erc 12.50 2 Drilling MI S. Mud Egineer 12.50 2 Dulling Vetco(BHGE) wellHead 12.50 2 Drilling GBR Casing Casing Service 12.50 3 Drilling Con -w er is Logistic 12.50 4 SID Support Sake, Csomlift 12.50 5 Dnihme Ml Swaw Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Supper ESS Catering 12.50 10 SID Support Jacobs Truck diner/Crone operator 12.50 15 Drilling Doyon Rig Personnel 12.50 26 Dnlling_Tmal Drilling Personnel BOP Stack 8 Components Description Start Date Last Codification DatePressure Ragng (psi) Type Make MUEeI ID Nom Iln) P Range (psi) Last Cert Die Slow Circulation Rates Pump Number. Make: Model: Start Date Entl Dale Liner Size (in) Volume Per Stroke Override(bbpstk) Max Pressure (pail Date Depth Slow Spd Shaken mpm) P(psi) Ed(%) 1 0Flow (gpm) Daily Bulk Supply ftem Description: Equipment Fuel Unit Label: Gal Unit Size: t Nom: Dam Consumed Received ReWmetl Cum Consumatl Lam Received Cum Returned Cum On Loc Note 5/6/2019 1059.0 1059.0 11328.0 11,328.0 0.0 0.0 Supply Item Dand4pbon: Mutl Plant Boilers Unit Label: Gal Unit Size: Note: Data Consumed I Received 1420 Remmetl Cum Consumatl CumReceivetl Cum Returned Cum On Loc Note 51612019 42 D 462 0 462.0 0.0 0.0 Supply Ilam Description: Rig Fuel Use Label: gal on Unit Size: t Note: Dam Consumatl Reserved Returned Cum Comaumetl Cum Received Cum Returned Cam On Loc Note 5162019 156]0 3,1020 18,395.0 29,924.0 0.0 11,529.0 Supply Item Descriptum: Rig Wier Unit Label: bbl Unit Size:1 Note: Dam Consumatl Received Relumetl Cum Consumed Cum Receivetl Cum Returned Cum On Loc Note 6H'd2e19 650 1350 564D ]32.0 00 168.0 Supply Rem Description: WIF Bogers Unit Label: Gal Unit Size: Note: Dam Consumatl Receivetl Returned Cum Consumed Cum Received Lum Returned Cum On Loc Note 5/6/2019 198.0 198.0 2,178.0 2,1]8.0 0.0 0.0 Supply lmm Desmpdon: WIF InameE Diesel Unit Label: Gal Unit Size: Note: Dem Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Lee Not. 5162018 4200 420.0 5,040.0 5,040.0 DO 0.0 Last Authority Visit Date Tminsp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company 9 Rata Lam Doyon Doling 14 PJSM'S Doyon Drilling Inc.19 Sale Calls Doyon Drilling Inc. 14 HRWS Dayan Detling Inc. 14 COW Ml Swaco 8 MR. MI Swaw 6 HARC/JSA General Notes Comment: �� Well Name: e: SPE3 SE Wellbore Name: SP12-SE3 Operator Well Code: 27979 Subsitliery Job: WORKOVER 2 n i WCER Level: Daily Report Date: 517/2019 Report #: 12 Page: 1 of 3 Well Header PermiUConceuirn N° Operator Subsitliery Initial Lames Code ADL -388583 ENIPETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL O PC= DI COLTIVAZIONE Rotary Table Elevation in, Wale, Depth (ill First Flange (ft) RKB-Base Flange(fl) RKB-Tubing Spool (fl) 53.94 1723 36.]1 31.80 Rigs Rig NameCopacton Rig Type Rig Num Rig Start Data Rig Release Date RIG 15 DOYON LAND RIG 0723 412512019 Daily Information Weather Temperature ('F) Wind Days LTI(days) Days Rl(days) POB Overcast 19.0 E @ 13 MPH 563 00 563 00 105.0 Safety Incidents • Near Miss Dab Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type MOccur Last Date Next Date (days) BOP Pressure Test 2 5162019 51132019 6 Fire DnII 3 5/612019 5202019 13 Kick While Topping 3 51512019 5/12/2019 5 Rig Inspection 12 5n2019 5182019 1 Safety Meeting 12 5n2019 5/8/2019 1 Spil DAI 4 WQ019 5121/2019 14 TT Kick While Topping Drell 2 4/302019 522019 0 TT Camp Fire Drill 1 Sn12019 521/2019 14 TT Rig Evacuation Drill 1 5152019 WN2019 SB TT Spill DnII 1 41302019 5/1412019 7 Ti WeII Cadrd DnII 1 5212019 5/162019 9 TT WeII pill 2 4282019 ]2]2019 81 WeII III DnII I2 516/2019 1511312019 1 6 Casings seat Cas.Type OD (in) ID (in) Grade Top(ftKB) SOflan(flKB) TVD Bot. foe) Run Date CONDUCTOR ZO 18.25 K65 0.0 160.0 ifi00 6/12014 CASING 13316 1242 L-80 0.1 2,878.0 2,463.8 6/1V2014 CASING 95/6 8.84 L80 0.0 5,1930 3,W6.4 6/192014 LINER 512 4.95 L -SO 5053.4 15,205.0 4,052.5 6292014 Last Cementing Cementing Start Data: 6/19/2014 String: Cok5lNG, 5,193. We Comment: Shut down rig pumps and Schlumberger pumped 10 bible H2O to fill lines and tested lines 10 1, 16013,457 pat, -good. Switched back lig pumping 105 buts. of Mud Push II @ 10.5 P, - ate of 5 bpm @ 220 Psi. Shut-0own and drop hollom plug. SLB mix 8 pump Lead slurry 79.5 We WI 12.5 ppg lite CRETE (1.66 K3/sk Yield, mix water at 5.461 gawk.) - Pump rate of 5 bpm @ 435 psi. Pump Tail Slurry 49 bbl 12.5 ppg Gass G [1.16 f Wsk Yield, mix water at 5.109 g illsk] - Pump use of als bpm @ 700 psi. Shut down and time tap plug - SLB pump 10 bbls H2O antl wash up. Dispute with 376 We W) 9.4 ppg mud with ng pump at 6 bpm w/ 140 psi, final pressure 550 psi., Bump Plug Pressup to 1,060 psi held 5 Min. Bleed off floats holding, Cement in place @ 22:00 hes. Sig NTop (itKB) Top Maas Mean Slur (WB) Can 1 2,04 9 3,]460 10.5 ppg Mud Push II 2 3,]46.0 Temperature Lag 4,fi83.0 12.5 ppg Leatl Cement 3 4,683.0 Temperature Log 5,207.0 15.80 ppg Tail Slurry Job Information Job Phase Planned Bud Data Bud Date End Dab P50 Duration (tlays) WORKOVER 4261201900:00 428201900:00 o.De Daily Summary Operations 24h Forecast Continue to make up ESPCP assembly, cable splice and urn in hole with ESPCP assembly, 24h Summary Trip in lmle with cleanout assembly g8, Wash dawn to 5859', pull out of hole, Inspect VACS B lay down stinger- remover smell amount from 2 7/e" stinger, Break coven and lay down VACS assembly, stand back drill pipe. Rig up GBR antl Baker Caramel. make up ESPCP assemblyand install cap tube am banding. 24 hour leu to hole=506 bels. Max mi 7 units. Operation at 0700 Making ESP cable splice. Time Log Start End Cum our Time Time our(h,) (hr) Phase Op,. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. M 4 P Continue run in hole from 1288'to 4835'. 0130 11200 0.50 200 WO M 25 P Service ng and top drive. 0290 0590 3.00 500 W.0 M 4 P Wash dawn tram 4835 10 5400' with 126 gallons per m"mute 75 psi, Increase rate to 343 gallons Icer minute 1950 psi and wash down to 5859', at 5859 circulate 100 bM, pumped 550 total bartels of 10.5 pound per gallon brine and hest 405 barrels to the welt. 05 00 1130 6.50 11.50 705-. M 4 P Trip out of Was reck back 5" doll pipe, r y down lar, magnet, boot basket, mck back VACS mbe, by down 2 7/8" drill pipe sfinger, beak down flapper valve assembly, recover a small amount of sludge firm last joint of 2 ]18" above top valve, nothing recovered horn Whom valve. 11:30 16:30 5.00 16.50 Wo. M 4 15 Break down and lay down VACS assembly, Goan tools and make sarvme uptake as per SHGE Rep., down dear ng w 1630 1700 0.50 17.00 W . K 20 P Rig up GSR Volant tool arM 4 `/a handling equipment. 17:00 17'.30 0.501 17,50 W.O. K 211 P Pullwear nog. 1]:30 20:00 2 50 20.00 W.O. K 20 P MOWlize Baker ESPCP equipment to rig floor. String ESPCP cap tube and Cable over sheaves in derrick to ng floor. 2000 00:00 600 2400 W.O. K 0 P PYde up momr assembly and service. Malin up pup and centheizea. Install mop tube and band to mater. rdinue to fill hole 1 with ]bps of 10.5 brine every 2 hours. 24 hour Mss to 1o1e=508 buts. Max limi We. Gas Readings Avg Background Gas (Y.1 Max Background Gas (%) Avg Connection Gas Max Connection Gas (%) Avg Drill Gas (T.) Max Drill Gas (%) Avg Trip use (%) Max Trip Gas (%) Daily Mud Volumes TanWAdditionitou Type Des Volume(bbI) 5060 ff-- Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 51712019 Report #: 12 Page: 2 of 3 Daily Mud Volumes TahklAdditionlLocs Type Des Volume(bbl) tide 613.0 Cumulative Mud Volumes Active Volume (bid)Hole Vdume (bbl) Additions (belt Cu. Additions (bull Losses (bbl) Co. Losses (bbl) 900.0 613.0 0.0 0 0 1 508.0 5,615.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Brow Simonson Eni Chilling Supv. siddnil,n,@en.r.. 90]-885-0]15 Eni representative Mike Grubb Eni Dolling Supv. siddolling®enipetroleumcom 907685-0715 Eni representative Mitch Billington Eni Rig Clerk AKRigC1.z1aWyon15®ed.com 907E05-0722 Eni representative Pat Ahem Eni HSE Eni representative Louis Armneau. Ed HSE Tod Push Ryan Pankralz Doyon Dulling Tool Pusher 6915@doWnddiHng.com Tool Push Ted Kroger Doyon Wiling Tour Pusher dgl5@eni.com 9076850716 Ted Push Harald Rush uchim Doyon Dulling HSE hndham tan@doyonzdling.com 685-0798 Tool Push Deve Sena Doyon Drilling HSE dsena@d1opruiling.com 685-0796 Personnel Log (POB) Company Serve. Type Work H(hd Stand-by H(hr) Count Note Doyon Feld Supenntendent 12.50 0 Willing Eni Company Man 12.50 0 Drilling Halliburton Wireline 12.50 0 Drilling Baker Fishing 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crena Adviser 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Radom Olkeild Services Fouler 12S0 1 SID Support SLB 12.50 1 Wiling Eni Engineer 12.50 1 Drilling ACS Envimmental 12SI3 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Detach Tool pushers 12.50 2 Wiling Desch HSE 12.50 2 Wiling Hatliburtan Mud Loggers 12.50 2 Wiling MI Bwaco Mud Engineer 12.50 2 Dolling Vetco(BHGE) Wellhead 12.50 2 Ddling GBR Geeing Casing Service 12.50 3 Wiling Germanism. Logistic 12.50 4 SID Support Baker Curedik 12.50 5 Drilling Ml Eased Mud Plant 1250 6 Will, Purcell Security 12.50 6 SID Support Ml award WIF 12.50 8 SID Suppmt ESS Catering 12.5D 10 SID Support Jacobs Truck driver l Crane operator 12.50 15 Wiling Doyon I Rig Personnel 12.50 26 1 Ddling_Total Drilling Personnel BOP Stack & Components Description Slat Dale Last Certification Data Pressure Rating(psi) Type Make Model ID No. (in) I PRange Until I last Cert Date Slow Circulation Rates Pump Number. Make: Model: Start Date End Date Liner Sit (in) Volume Per Stroke Override(bbgatk)Max Pressure(psi) Data I Depth(kKB) I Slow Sod Stni(am) Plosi7 Ea(%) T 0Flow (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unk Label: Gat Unit Size:1 Note: Data Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Wy 019 969.0 1 969.0 12,297.0 112,297a 0.0 0.0 Supply Item Description: Mutl Plant Boilem Unit Label: Gal Unit Size: Note: DaleConsumetl Receivetl Returned Cum Consumed Cum Receivetl Cum Returnetl Cum On Lac Note 512019 420 420 5040 5040 0.0 00 Supply lesson Description: Rig Fuel Unit Label: gal us Unit Size: t Note: Dale Consumetl Received Returnetl Cum Consumed Cum Received Cum Returned Cum On Loc Note 512019 1580.0 0.0 19,9750 29,9240 0.0 9,949.0 Supply item DesorlpUon: Rig Wider Wk Label: bbl Unit Size:1 Note: Cele Consumed Receivetl Returnetl Cum Consumed Cum Receivetl Cum Returned Lum On Loc Note 512019 52.0 0.0 816.0 ]32.0 0.0 118.0 supply Item Description: WIF Bothers Unit Label: Gal Unit Size: Note: Dde Consumed Receivetl Returned Cum Consumed Cum Received Cum Returned Cum On Loc Not. 5/!2019 1980 1900 2,376.0 2,3]0.0 00 0.0 Supply item Description: WIF Injected Diesel Unk Label: Gal Unit Size: Note: Date Consumetl Receivetl Returnetl Cum Consumed Cu. Received Cum Returned Cum On Loc Note Sn2049 4200 4200 5,460.0 5460.0 00 0.0 Last Authority Visit DateTotlnsp, Niter TOWI I.N.C. number Comment STOP Cards Suhmitted Company # Rpfs Co. 6 Doyen Wiling 13 PJSM-S Doyon Dolling Inc. 13 COW Doyon Oiling Inc. 13 HRWS Doyon piling Inc. 13 Safe Cams Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 5/7/2019 Report 9: 12 Page: 3 of 3 STOP Cards Submitted Company p Rpts Com MI Swaco MI Swaco 13 8 RIR's HARGJSA General Notes Comment: Well Name:E3 OR Wellbore Name: e: SPSP12-SESE3 Well Code: 27979 ' Job: WORKOVER 2no WCERLevel: Daily Report Date: 51812019 Report #: 13 Page: 1 of 2 Well Header PermiVConcession N° Operator 3ubsitliary Initial Lane. Code ADL -388583 ENI PETROLEUM ENI PeGoleuin Co. Inc. DEVELOPMENT WELL PO7Z0 DI COLTIVA LONE Rotary Table Elevation fill Water Depth (k) First Flange (k) RKB -Base Flange (k) RKB -Tubing Spoil (R) 53.94 17.23 36 71 31.80 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Data RIG 15 DOYON LAND RIG 0723 4/25/2019 Daily Information WeatherTemperature(°F) Wintl Days LTl(tlays) Days RI(days) POB Overcast 1].6 ENE(�28 MPH 564.00 POD105.0 Safety Incidents - Near Miss Gate Category Type Subtype Severity Cause Lost Hine? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) BOP Pressure Test 2 516/2019 5/132019 5 Fire Di it 3 516/2019 51202019 12 Kick While Tripping 3 5/5/2019 5/12/2019 4 Rig inspection 13 5l&2019 519/2019 1 Safety Meeting 13 5/62019 5/92019 1 Spill Nil 4 5//2019 5212019 13 TT Kick Wile Tripping Drill 24/302019 5RI2019 -1 TT Camp Fire Dull 1 502019 5212019 13 TT H2S Dell 2 WW2019 81612019 90 TT Rig Evacuation Wil 1 515/2019 8132019 87 TT Sgll CRIT 1 41302019 5/142019 6 TT Well Control Drill 1 512/2019 5/182019 8 TT well full 2 4282019 71272019 80 Well Kill NU 2 5!62019 1611312019 1 5 Casings seat Cas. Type OD (in) ID (in) Grade Top (RKB) I Bottom IRKS) I TVD Not MKB) I Run Date CONDUCT R 20 18.25 X65 0.0 1660 1600 6/12014 CASING 13318 1242 L-80 0.1 2,816.0 2,463.8 6/122014 CASING 95/8 8.84 L80 0.0 5.1930 3,9iA &192014 LINER 5112 4.95 L-80 5,053.4 15,205.0 4,052.5 &292014 Last Cementing Cementing Start Date: 6/192014 String: CASING, 5.193 (RKB Comment: Shut down dg pumps and Schlumber,er Wmped 10 Ws. H2O to fill lines and tested lines to 1,16&3,457 psi- good. Switched back rig pumping 105 Ws. of Mud Push II @ 10.5 lapg - rate of 5 bpm ® 220 psi. Shut -down and drop whom plug. SLB rax 8 pump Lead slurry 79.5 bis Wl 12.5 pp9 Lite CRETE (1.%k&sk Yield, mix water at &461 gallsk) - Pump rote of 5 blxn @ 435 pale Pump Tail Slurry 49 bbl 12.5 pp, Gass G (1.16 k&ak Yield, mix water at 5.1 D9 gallsk.l - Pump rate of 4.5 bpm Q 700 psi. Shut down and drop top plug - SLB Pump 10 this H2O and wash up. Displace with 376 bbls W/ 9.4 ppg mud with rig pump at 6 bpm w/ 140 psi, final pressure 550 psi., Bump Rug Press. up to 1,050 of held 5 Min. Bleed off goats finding. Cement in place @ 22:00 firs. Sip #Top (RKB) Top Meas Meth Ban NIKB) Com 1 2,047.0 46. 10.5 ppg Mud Push If 2 3,746( Temperature Log 1 4,6630 12 5 pPg Lead Cement 3 4,683.0 Temperature Log 5,207.0 15.80 on Tail Slurry Job Information Job Phase planned start Date Start Data End Date P50 Duration (days) WORKOVER 426/201900:00 426201900:00 0.00 Daily Summary Operations 24h Forecast Gratin, inn in hole with completion, make up hanger, swivel joint, make penstaxor splices, blow dawn all surface lines, land tubing hanger and test seals, prep and lay down dill pipe from hand, Nlppte down DOPE. Nipple up Wellhead and passport test. Empty qts and start cleaning. 20 Summary Make up ESPCP assembly spice electrical cable and cagllary lines to assembly test same, min in hole with ESPCP to 3826'. 24 hour loss to hole=77 We, Max gas=0 units. Operation at 07.00 Prepping to lard tenger. Time Log Start End Cum our Time Time our Mr) Mr) Phase Op, Act. Plan Open. Descr. 00.00 08;308.50 .50 W.O. Compete make up of ESPGP assembly, install electrical connection, capillary line and clamps. Splice ESPCP cable capillary, line to assembly Witnessed by ENI electrician. 0830 1030 200 10.50 WO. K 12 P P preaeure testing an capillary line, Wet eleddca splick, fest well IM sensor as per6 10:30 00:00 13 50 24.00 W.O. K 4 P Run in We with ESPCP completion on 4.&' 12.60 HYMM tuning 17/3628using the Vo ent casing running tad, continue to add 7 bbl 10.5 Fountl par gallon brine to We svery 2 Wars, no rewms. Testing lines every 1000', installing canes collar dem, every culler. 24 hour lose 0 fide=?/ blis. Max gases units. Gas Readings Avg Background Gas I%) Max Background Gas (%) Avg Connection Gas 1%) Max Connection Gas f%) Avg Drill Gas (%) Max Drill Gas (%I Avg Trip Gas (%) Max Tip Gas (Y°) Daily Mud Volumes TendAtltlitionlLon Type Des Volume (bbl) Tank 308.0 Loss 770 Hole 597.0 Cumulative Mud Volumes Active Volume (bbl) Hale Volume (bbl) Additions (bbl) Cum Additions (boll Losses (bbl) Cum Losses (bbl) 9030 597.0 0.0 0.0 77.0 5.692.0 Daily Contacts Position Contact Name Company TRW Email office Mobile Eni representative Brace umanown Eni 1 Drilling Su,. 1 sitlddlli-Weni con90]685-0]15 Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 518/2019 Report #: 13 Page: 2 of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Ent representative Mike Grubb Ent Wiling S upv. 907885-0]15 Eni representative Mitcherirgten Ent Rig Clerk AKFbgCIRkrDipebdlaummm AKRigClarkeDoyonl5(r0eni.mm 8W885-0]22 Eni representative Pat Ahern Eni HSE Eni representative Louis Amens. Eni HSE Tool Push Justin Hays Doyon Drum, Tod Pusher ngl5@0yershilling.com Tool Push Ted Kreger Dayon Drilling Tour Pusher nglS@eRm. 9078850716 Tmt Push Harold Rtllartkon obtain Dolling HSE hrichardson@do,endriging.com oyontlAllin9mm B85-0798 Tod Push Scott Simmon Doyon Drilling HSE Personnel Log (POB) Company Serv. Type Work H (hr) Starl H (hr) Count Note Doyon Field Supenotenuent 12.50 0 N11mg Ed Company Man 12.50 0 Drilling WllibuMn Wireline 12.50 0 Drilling ASRC Clark 1250 1 Wiling ASRC SOA 12.50 1 SID Support ASRC Creme Ativi. 12.50 1 SID Support Deacon Medic 12.50 1 SID Support NoMem Oilfeild Services punier 12.50 1 SIDSupport SLB 12.50 1 Drilling ACS Enam mental 12.50 2 SID Support ASRC Company Men 12.50 2 Drilling Beeson HSE 12.50 2 SIDSupport Caton Tad pushers 12.50 2 Dolling Dayan HSE 12.50 2 Wiling Italllburbn MW Loggers 12.50 2 Willing MI SWaco MW Engineer 12.50 2 Drilling Vatco(BHGE) WdlH.d 12.50 2 Drilling GBR Casing Casing Service 12.50 3 Walling Compatimme Logistic 12.50 4 SID Support Ml Swaco MW Plant 12.50 6 Will, Pmttll Security 12.50 6 SID Support Baker Centdlift 12.50 6 Dnllinp MI Swam VV 12.50 8 SIW Support ESS Clearing 12.50 10 SID Support Jambs Track dnver/ Crane operator 12.50 14 Drilling Doyon Rig Personnel 12.50 28 Dnll,N Total Drying Personnel SOP Stack 8 Components Description Start Data Last Certification Date Pressure Rating (Pat) Type Make Motlel ID Nom (in) P Range (psi) Last Cert Wate Slow Circulation Rates Pump Number. Make: mel. Start Dab End Dale Liner Size lin) Volume Per Stroke Override (bbllstk) Maz Pressure 1psi) Date WPM 118(8) Slow Spd Strokes (spm) P (Psi) ER f41 O Flow (9Pm1 Daily Sulk Supply Item Descdiation: Ecutpnent Fuel Unit Label: Gal Unit Size:1 Note: Date Consumed Received Returnetl Cum Consulletl Cum Remivetl Cum Rebmetl Cum On Lee Net. SI82019 1.145.0 1,1450 13,442.0 13,412.0 0.0 0.0 Supply Ilam Descnption: MW PbM eoger8 URN Label: Gal Unit Size: Nate: Date Received Returned Cum Cormumetl Cum Remived Cum Returned Cum On Lee Note IC 51812019 42.0 62.0 546.0 516.0 0.0 0.0 Supply Item Description: Rig FUN Unit Label: gal us Unit Size: t Note: Date Cons umetl Receivetl Returned Cum Cormumetl Cum Received Cum Returned Cum On Lee Note 5/&2019 184f0 0A 21,816.0 28,924.0 0.0 Bp08.0 Supply Ben Desser"br: etgweter Unh Label: bbl Unit Size:1 Note: Date Consumetl Received Relumed Cum Consumed um RemWM Cum Rebmed Cum On Loe Note 5/82019 49 0 135 C 865.0 86].0 0.0 202.0 supply Item Description: WIF BaIere Unit Label: Gal Unit Size: Note: Wats Consumed Receivetl Rmwnetl Cum Consumed Cum Recebetl Cum Returned Cum On Loc Note 5/&2019 198.0 198.0 2,574.0 2,574.0 0.0 0.0 Supply" an Description: WIFlnjecletl Diesel Unit Label: Gal Unit Size: Note: Dab Consumetl Received Retumetl Cum Consumed Cum Receivetl Cum Rebmetl Cum On Loc Note 5/82019 420.0 620.0 5,880.0 5,880.0 0.0 0.0 Last Abro only Visit We Tot lnap. Nbr TobII.N.C.number Comment STOP ffardS Submitted Company plies Com Doyon Drilling 9 PJSM'S Doyon Wiling Inc. 18 Safe Canis Doyon Drilling Inc. 9 HRWS Doyon Dolling Inc. 99 COW Ml Swaco 8 RIRe Ml6weco 6 HARC/JSA General Notes Comment. Well Name:OR Wellbore Name: e: SP12 SP12-SE3 Well Code: 27979 Job: WORKOVER e n i WCER Level: Daily Report Date: 5/9/2019 Report #: 14 Page: 1 of 3 Well Header PermB/Concessifin N° Operator Subsidiary Initial LzIse Code ADL388583 ENI PETROLEUM ENI Formal Co. Inc. DEVELOPMENT WELL O PC)= DI COLTIVAZIONE Rotary Table Elevation IN, Water Depth (R) First Flange (K) RKB -Bap Fbnga B up" (1111 53.94 1].23 311.71 31.80 Rigs Rig Name Cantraetw Rig Type Rig um Rig Start Data Rig Release Date RIG 15 GOYON LAND RIG 0]23 425/2019 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days In (days) POB Overcast 180 ENE @14 MPH 565.00 565.00 90.0 Safety Incidents - Near Miss Data Category Type Subtype Severity Cause Losfilms? Comment Safety Drills Days Until Next Check Type a Occur Last Date Next Date (days) BOP Pressure Test 2-61019 51132019 4 Fre dill 3 SI62019 S2g12019 11 Kick While Tripping 3 5/52019 5/1211019 3 Rig Inspection 14 5192019 5/102019 1 Safety Meeting 14 5/92019 5/142019 1 Spill dill 4 W2019 5212019 12 TT KICK Mile Tripping Dell 2 41302019 522019 -2 TT Accumulator Drill 1 552019 5232019 14 TT Camp Fre Doll 1 Sn2019 5212019 12 TT Hl Doll 25/8/2019 8/8/2019 89 TT Man Down Nil 1 552019 5232019 14 TT Rig Evacuation Drill 1 5/52019 6/32019 86 TT Spill Dell 1 4 113)19 5/142019 5 TT Weil Cartrol dill 1 5/22019 51162019 ] TT Well 1011 2 4282019 ]2]2019 79 Well ILII Nil 2 !fill lisi 4 Casings seat Cas. Type OD (in) ID (in) Grade Tap (ftKR) Bottom (11148) TVD But (NKB) Ren Data CONDUCTOR 20 18.25 %65 0.0 160.0 you 12014 CASING 13318 12.42 LA0 0.1 2,8]8.0 2,463.8 61122014 CASING 95/8 8.84 L80 0.0 5,193.0 3,9]8.4 WIM014 LINER 512 4.95 LA0 5,053.4 15.205.0 4,052.5 6292014 Last Cementing Cementing Start Date: fi 192014 String: CAGING, 5.193.01 Comment; Shut down ng pumps and Sc)dumberger pumped 10 box H2O to fill lines and tested Ilnes to 1,16013,457 psi - good. Switched back ng pumping 105 bible, of Mud Push II @ 10.5 ppg - rate of 5 bpm Q 220 psi. Shutdown and drop bottom plug. SLB mix 8 pump Lead slurry ]9.5 bids Wl 12.5 ppg Lite CRETE (1.56 ftWsk Yield, mix water at 5.461 dollar] - Pump rate of 5 bpm @ 435 psi. Pump Tail Slurry 49 bbl 12.5 ppg Gass G (1.18 1131sk Yield mix water at 5.109 gallsr) - Pump rete of 4.5 bpm @ 100 psi. Shut down and drop top plug - SLB pump 10 bids H2O and wash up. Displace wim 376 lbs W/ 9.4 ppg mud with dg pump at 6 bpm w/ 140 psi, final pressure 550 psi., Bump Plug Press. up to 1,0511 psi held 5 Min. Bleed o6 floats holding. Cement in place @ 22:00 firs. Stg # Top (RKB) Top Meas Meth atm (RKB) Com 1 2,04]. 3,] 10.5 PPB Mud Push II 2 3,]48.0 Temperature Log 4,8850 12.5 ppg Lead Cement 3 4,683.0 Temperature Log 5,20]0 15.80 on Tail Slurry Job Information Job Phase Planned Start Oate Start Date End Date P50 Duration ldays) WORKOVER 4/28201900:00 41261201900:00 0.00 Daily Summary Operations 24h Forecast Finish cleaning pits. Prepare and move pump #3 and Rock washer. Lay Herouldis and matfing boards. Prepare and move rig. 24h Summary Continue run in hole with completion, make up hanger, swivel joint, make penetrator splices, Max clown all surface lines, find robing hanger and test seals, good lest, prep and lay clown drill pipe from derrick - Nipple down ROPE. Nipple up bee and start shell fest on tree. 24 hour loss to hole= 14 bola. Max gaining unib. Operation at W.00 Prepare dg for moving_ Time Log Start End Cu. Dur Time Time Dur @r) (br) Phase Opr. Act. Plan Over. Descr. 02:30 2.50 2.50 W.O. K 4 P Cautious to urn in hole w -M --TW 12.611. L-80 Hyddl 563 won ESPCP FIMIV T9618i. firmall groes collar amps on every caller.. S0=100 K.PU=128 K Continue to pump 7 barrels per hour of 105 ppg bine every 2 hours. -W 0230 4. K 20 P Rig down Valent tool, Lay clown bele extensions and install el.vetms. Imtell Iwo way check valve in tubing hanger. Mak. up hanger. Blow down surface equipment. 04:30 All 4.50 9. W.O. K 12 P Attach ESPCP cable and cap tube to tubing hanger Test cap lube pass through TI5K for 10 minutes, good test. Ring out Cable to confirm correct position of motor leads far proper rotation. 09-0 1000 1.00 O. W O. K 5 P Land out tuber, hanger and urn in lack clown bets. 114,551 Test hanger seals 17 5K for 10 minutes, good test. PU=128 K. 50=100 K. 10:00 1]:30 7.50 17.50 W.O. 4 P Clear ng Baer. Lay clown lV di pipe from demck to pipe shetl wing moose hole in rotary, bible Lay down mouse hole. Cleaning pits with fresh water and flushing lines with 50 BBL soap pin. 1730 22:00 4.50 M.00 W.0 C 5 P Rig down low pressure riser and flow fine. Nipple down choke and Mil hoses from pinery am secondary. Nipple down BOP stack and mck back on stump. 22:0000: 2.00 24.90 W O. C Nipple up Tree, torque all connections. Test anger /packs T/5k far 10 mines, good test. Nipple down 1502 au Nipple W return line an m. Rig up posspod last equipment and shot body test an tree. K pressure=) psi. CA=150 PN. 24 hour loss to hole= 14 fills. Max gas=0 units, Gas Readings Avg Background Gas 1%) Max Background Gas 1%) Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas (A) Max Drill Gas (%) Avg Trip Gas 1%) Max Trip Gas (%) Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 5/9/2019 Report M 14 Page: 2 of 3 Daily Mud Volumes TanMAdditlONLeas Type Des Volume (bell Tank 9 9 Loss 140 Hole 5920 Cumulative Mud Volumes Active Volume (bbl) We Volume (IUM) Accident (bM Cum Addtions (bbl) Loses (bbl) Cum Losses (bM) 592.0 592.0 0.0 e.0 14.0 5,708.0 Daily Contacts Position Contact Name Company Title Email Once Mobile Eni representative Bmw Simonson Epi Dnliin SSupv. sidtlnllin 9076854715 Ed represenbfive Mike Grubb Em Dnlling Supv, siddrilling@enipebdeum.win 907685-0715 Ens representative Mich Billington Eni Rig Cierk AKRigoerksDoyonl 5@eni.win 907685-0722 Eni representative Pet Ahem Em HSE Eni mpreaenbtiva Louis Arterial Eni HSE Tod Push Justin Hays Doyon Drilling Tool Pusher ng15@Eo,,m1ming.com Tad Push Tetl Kroger Dagen DIBIin9 Tour Pusher rig15@amm. 9076850716 Tod Push Herold RichaNson Doyen ending HSE hnchardson@tloyondriling.con 685-0796 Tod Push SwN Simmms Doyon Dollar, HSE Personnel Log (POB) Company Sam. Type Work H(m) assail H(hr) Count Note Doyon Field Supermt.rmrt 12.50 0 Drilling Eni Company Man 12.50 0 Codling Halliburton Wireline 12.50 0 Drilling Baker Cemnlih 12.50 0 Original GER Caaing Casing Service 12.50 0 Drilling ASPIC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Adviwr 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Northam Offlaild fere. Fuebr 12.50 1 SID Support SLB 12.50 1 Drilling ACS EmAromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Devon Tod pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swam Mud Engineer 12.50 2 Drilling Vetw(SHGE) WellHead 12.50 2 Drilling Compelemia Logistic 12.50 4 SID Support MI Samoa Mud Plant 12.5) 6 Dnlling Purcell Secunty12.50 6 SID Support MI Swaco WIF 12.50 B SID Support ESS Catering 12.50 10 SID Support Jacobs Truck Enver/Crane operator 12.50 14 Drilling Doyon IRI, Personnel 1 12.50 28 1 Dnlling_Totel Drilling Personnel BOP Stack 8 Components Description Start Det. Lest Certification Data Pressure Rating(Psi) Type Make Moroi m Nom (in) P Range (psi) Last Carl Data Slow Circulation Rates Pump Number. Make: Moadd: Start Data Emd Usti, Liner Size (in) r Stroke Override Max Pressure fle-4 Vol;P j Date Oepb (NKB) Slow S ptl Strokes (spin) 1psi) ER 0 Flow (ppm) Daily Bulk Supply been Description: Equipment Fuel Unit Label: Gal Umtsize: 1 Note: Date Consumed Receivetl Returnetl Cum Consumed Cum Received Cum Returned Cum On Loc Note 5512019 10990 1,09e0 14,541.0 id,561.0 0.0 0.0 supply Item Description: Mud Plam Bdbrs Unit Label: Gal Unit Size: Note: Dant Consumetl Received Returned um Consumed Cum Recdved um Relumed Cum On Loc Note 519/2019 42.0 42.0 588.0 588 0 0.0 0.0 Supply Item Dperiptlon: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Oats Consumed Receivetl Returnetl Cum Consumed Cum Received Cum RaWrnsd Cum On Loc Note SIM019 1,564.0 6,2560 23,380.0 36,180.0 0.0 12,800.0 Supply been Description: Rig Water Unit Label: bbl Unit Size:I Note: Dale Consumed Received Relumetl Cum Consumetl Cum Revived Cum Returned n Loc Note 5/8/2019 760 00 743.0 867.0 0.0 Reno 4.0 Supplyltem Description: WIFBmam Unit Label: Gal Unit Size: Note: DateConsumed Receivetl ReWrnetl Cum Consumed Cum ReuNed Cum Returned Cum On Loo Note 552019 198.0 196.0 2,772.0 2,7/2.0 0.0 0.0 Supply Item Description: WIF Injected Diesel Udt Labol: Gd Unit Size: Note: Dab Consumed Received Returned C,um CoumtlC,mRecehave! Returned Cum On Loc Note 0 400 420 05019 0.0 0.0 Last Authority Visit Dab Tot insp. Nor Tobi I.N.C. number Comment STOP Cards Submitted Company a Rite Co. Doyon Wiffing 7 PJSWS Doyon Grilling Inc. 7 COW Coyer, Drilling Inc. 7 HRWS Doyon Drilling Inc. 11 Sade Cards Ml Swam 8 RIR's Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 5/9/2019 Report M 14 Page: 3 of 3 STOP Cards Submitted company p Rpfs Com MI Swaco 6 IiHARCIJSA General Notes comment: OR >a Well Name: e: SP12 SE Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER gni WCERLevel: Daily Report Date: 5/1 012 01 9 Report #: 15 Page: 1 of 2 Well Header PermiVConcession N° Operator Subeitliary Initial Lahee Lotle ADL -388583 ENI PETROLEUM ENI Peboleum Co. lx. DEVELOPMENT WELL O POZZO DI COLTIVA " Rotary Table EPovaBon (R) Water Depth in) First Flange (it) RKB-Base Flma-(R) -Tuing Spool(K) Imus, 53.94 1T23 96.]1 31.80 Rigs Rig Name Contractor Rig Type Rig Num Rig Sart Date Rig Release Data RIG 15 DGYON LAND RIG 0723 4252019 Daily Information Weather Temperature ('F) Wind Days LTI(days) Days RI(days) Overcast / Fog 21.3 ENE l$, 23 MPH 5%.00 586.00 100.0 Safely Incidents - Near Miss Data Category Type Subtype Severity Cause Lost lime) Comment Safety Drills Days Until Next Check Type # Occur Last Dale Next Date (days) BCP Pressure Test 2 Sall V132177-3 Fre Dell 3 58/2019 5202019 10 ock While Tripping 3 5/5/2019 5112/2019 2 Rig Inspection 15 5110/2019 Si112o19 1 Safety Meeting 15 5`102019 5/112019 1 Spill Dell 4 fieri 5212019 11 TT Kick While Trippng pill 2 iK02019 5`72019 41 TT Accumulator 0611 1 Sfil 5232019 13 TT Camp Fre pill 1 Sn2019 5212019 11 IT H2S DMI 2552019 816 19 ae IT Man Down DMI 1 592019 MW2019 13 TT Rig Evacuation pill 1 532019 8/3/2019 85 TT Spill DMI 1 41302019 5`142019 4 TT Well Control pill 1 522019 5/162019 6 TT Well Hill 2 4282019 ]2]2019 78 Well Kill DMI 2 5`62019 5/132019 3 Casings seat Cas.Type OD (in) 10 (in) Grade Top(RKB) Bottom mill TVD Bol.(ftKB) Run Data DUCTOR 1 1 1 .0 6/12014 CASING 133/8 12.42 M 0.1 2,91&0 2,463.8 6112/2014 CASING 9518 &84 LW 0.0 5,193.0 3,9]6.4 1 61192014 16V2962014 LINER 512 4.95 1480 5,053.d 15,20.5.0 4,0525 Last Cementing Cementing Stan Dale: 8!192014 Sell CASING, 5.193A8KB Comment: Shut down ng pumps and Schlumbe,er pumped 10 Wis. H2O to fill lines and tested lines to 1, 16013,457 psi: good. Switched back rig pumping 105 Mils, of Mud Push II @ 10.5 ppg -rate of 5 bpm @ 220 psi. Shutihown and tlmp botlan plug. SLB mix & Pump Lead slurry 79.5 ads W/ 12.5 Mg Lite CRETE [1.56 ftWsk Yield, mix water at 5.461 gaVsk.l - Pump rate of 5 bpm @ 435 psi. Pump Tail Slurry 49 WI 12.5 Fog Class G [1. 16 ft3/sk Yield, mix water at 5.109 gallsk] - Pump rate of 4.5 bpm @'00 psi. Shut down and drop top plug -SLB pump 10 Mals H2O and wash up. Displace with 376 We W19.4 ppg mud with its pump at 6 bpm col 140 psi, final pressure 550 psi., Bump Plug Press, up to 1.050 psi held 5 Min. Bleed off goats holding. Cement in place @ 22:00l rs. Sig # Top (RKB) Top Maas Meth Som (RKB) I Com 1 3,'48.0 05pp Mud Push II 2 3,.46.0 Temperature Log 4,683.0 12.5 ppg Lead Cement 3 4,683.0 Temperature Log 5,207.0 15.80 ppg Tail Slurry Job Information Job Phase Planned Start Date Start Date Entl Date pfi9 Ny# WORKOVER 426`20190000 42620190000 0.09----;�;,:. Daily Summary Operations 24h Forecast Time is the final RWO mWL Move ng W SP33-W3 L1. 24h Summary Nipple up tree and finish passport trading on tree. Finish cleaning pits. Prepare and move pump #3 and Rock weather. Lay repulse and matting boards. Have Halliburton logging unit pad eyes inspected, pick unit with crane and set in slight, area. Prepare and start moving sub and pit system down well May. Rig released from SP12-SE3 5/102019 M 24: W. Operation at 07.00 Moving rig to SP33-W3. Time Log Start End Cum our Time Time Durlhr) (ti Phase op'. Act. Plan Oper. Descr. Well W:W 600 8.00 W.O. C 12 P CorNnue to Passport lest Tme. Shell GM bee TM.000 par for lit minutes. Test swell wake, to 3,000 psi for N minutes. Test wing valve T13, W O fell for 30 minutes, test tree cop for 5 minutes, a0 good test, Pull two way check valve. Finish cleaning pits and rock washer. Disconnect all intoroonneds between sub base and mutt pits. Disconnect lines beNreen pump room and sub. Move mud pump 03 complex. Rig down rock washer. Lowarand pin support braces in pipe shed. W:W 18:W 1200 18.01 WO. A 2 P Move rock washer, Secure top drive and track for move. Blow down water and steam to dg floor and ng down lines. THe up koomy fines in wheel well. Disconnect power and Communication lines to koomy house. Ley He¢ullte and afar) laying matting Wants- Prepers sub and pit module for move Have picking eyes inspected on Halliburton Logging ung, pick and Wipe .no seal set a[ staging area. 00 :W She 24115 W.O. A -7-7- Move Pd module all sub away er well bay. Pull matting boards and continue to lay out along well bay in part pit motto e and sub base San SP12 to SP33, stage module while leap frogging matting boards. W pressure= 0 psi, OA=150 Psi'lubing=0psi, 24 hour loss b hale= o ids, Max gi units. Total losses to holi bis. Gas Readings Avg Background Gas I%) Max Background Gas I%) Avg Connection Gas (%I Ma Connection Gas(%) Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%) Daily Mud Volumes TanklAtlditionlLoss Type Des Volume (Wit Tank 0.0 Loss 0.0 Hole 590L Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 5/1012019 Report #: 15 Page: 2 of 2 Cumulative Mud Volumes Active Volume (bbI) Hole Volume (bbl) Additkum Until Cum Atltlitlons sea (bbl) Cum Losses (bbl) 590.0 590.0 0.0 0.0 0.0 6,282.0 Daily Contacts Position Contact Name Company Title Email 01 Mobile Ens representative Bruce Simonson Eni Dtllling upv. adddlling@hni.com 907-68511715 Eni romemps6ve Mike Grubb Eni Drilling Supv. sidddling@edpetroleum.wif 907-885-0715 Eni representative Mach Billings. Eni Rlg Clerk AKRigClerksDpyonl5Weni.com 907x854722 Eni namesens5ve Cary Houghin Eni HSE Eni representative Louis Arcaneaux Eni HSE Tool Push Juslm Hays Doyon Drilling Tool Pusher dgl5l5sdoyorMnlling.com Tool Push Ted Kruger Doyon Drilling Tour Pusher ng15Qenioom 907-6850716 Tod Push HamM Richardson Doyon Driving HSE hrichardson@yloyondrilling.com 685-0796 Tod Push Soot Simmons Own Oiling HSE Personnel Log (POB) Company Serv. Type Work H (hrl Stand-by H (hr) Count Note Doyon Field 5,vanninterdent 12.50 D Drilling Eni Company Man 12.50 0 Drilling Halliburton Wireline 12.50 0 Dulling GBR Casing Casing Service 12.50 0 Doling ASRC Clerk 12.50 1 Dulling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Northam plsiitl Services Fueler 12.50 1 SID Support SLB 12.50 1 Dulling ACS Enviromentel 12.50 2 SID Support ASRC - Company Men 12.50 2 pilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Dulling Catch HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI S. Mud Engineer 12.50 2 pilling Vetco(BHGE) Wel Head 12.50 2 Drilling Composed. Logan. 12.50 4 SID Support Baker Cenbilih 12.50 5 Dulling MI Svino Mud Rant 12.50 6 Wiling Recall Secuuty12.50 6 SID Support Ml Swaco WIF 12.50 8 SID Support ESS Catering 12.50 9 SID Support Jacobs Truck driver/Crane operator 12.50 14 pilling Option Rig Personnel 12.50 26 Dnlling_Total Dulling Personnel BOP Stack 8 Components Description Start Dale Last Certification Dale Pressure Rating (psi) Type Make Modal ID Nom (in) P Range (psi) I Last Cert Data Slow Circulation Rates Pump Number. Make: Model; Start Das End Date Liner Sire (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) Date Depth (ftl(B) Slaw Spit Slrolms, ppm) P (pai) ER (%) 0 Flow (qpm) - Daily Bulk Supply Ilam Description: Equipment Fuel .Unit Label: Gal unit Size:1 Note: Date Consumed R,ecei.ved Returetl MumedCm Resolved Cum Retumed On Loc C.0 Note 908 1,0200 10230 1m 5 ,564.0 0.0 Supply Nem Description: Mud Plant Sellers Unit Label: Gal Unit Size: Note: Das Consumed Received Returned Cum Consumed Cum Received Cum ReturnedCum On Loc Note 5110/2019 42 0 42.0 630.0 630.0 0.0 OA Supply/turn Descdpman: Rig Fuel Unit Label: gel us Unit Size:1 Note: Date Consumetl Receivetl Returned Cum Consumetl Cum Recehed Cum Returned Cum On tae Note 5/102019 1,5400 00 24,820.0 36,180.0 0.0 11,280.0 Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Das Consumed Received Returned tum Consumed Cum Received Cum Rearmed Cum On Loc Note 9102019 0.0 0.0 743.0 867.0 0.0 124.0 Supply hem Description: WIF Bousrs Unit Label: Gel Unit Size: Note: Data consumed Receivetl Returnetl Cum Consumed Cum Reurvetl Cum Returned Cum On Loc Note &102019 198.0 198.0 2,970.0 2,8/0.0 0.0 OA Supply /turn Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Gate Consumetl Received Returnetl Cum Consumed Cum Received Cum Returned Cum On Loc Note 51102019 4200 420.0 6,720.0 6,720.0 0.0 0.0 Last Authority Visit Des Tot map. Nbr TWO LN.C. number Comment STOP Cards Submitted Company p Ride Com Doyon Drilling 15 PJSM'S opyon Drilling Inc. a Sas Carta Doyon Drilling Inc. 15 HRWS Wean Oiling Inc. 15 COW Ml S.. 8 RIRs MI Swaco 6 HARCIJSA General Notes Comment: Well Name: SP12-SE3 OR Wellbore Name: SP12-SE3 Well Code: 27979 Job: WORKOVER WCER Level: Daily Report Date: 4126/2019 Report #: 1 Page: 2 of 2 Personnel Log (POB) Company Sam. Type Work H(or) Stand-by H(or) Count Note ASRC, Company Man 12.50 1 Dolling ASRC Clark 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Come Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Dulling End Company Man 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support ACS Enviromenbl 12.50 2 SID Support Beacon HSE 12.50 2 SID Support Doyen Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Legge. 12.50 2 Dulling MI Swaco Mud Engineer 12.50 2 Drilling Vetw(BHGE) WellHead 12.50 2 Drilling Commerce Logicac 12.50 4 SID Support Baker CenhlllR Completions 12.50 4 Drilling Ml Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support Ml Swaco WIF 12.50 0 SID Support ESS Catering 1250 10 SID Support Jacobs Truck cover /Come operator12.50 14 Grilling Distant, Rig Personnel 12.50 26 Onlling_Total Drilling Personnel BOP Stack 8 Components Description start Dale Last CeHdrication Date Pressure Rating psi) Type Make Model ID Rom (in) P Range (psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Morbl: Start Dab End Dale Liner Sin (in) Volume Per SVoke Override(bblistk) Max Pressure (psI) Date Depth (BKS) abreast! Strokes (spm) P (pad) Ea (°b) O Flow (gpm) Daily Bulk Supply Ilam Description: Equipment Fuel Unit Label: Gal Unit Size: i Note: Dab Consumed Received Returned Cum Consumed Cum Recaysl I Cu. Returned Cum On Loc Note Supply Nem Description: Mud Plant Boller, Unit Label: Gal Unit Size: Note: Gate Consumetl Received Returned Cum Consumed Cum Resedvetl Cum Returnetl Cum On Loc Note 4/282019 42.0 d2 0 42.0 42.0 0.0 0.0 Supply Hem Description: Rig Fuel Unit Label: gal us Unit Size:1 Note: Data Consumed Re,c2e9iv.e0 m Received um Returned Cum On Loc Note 41262019 1,4470 0lReturned 10,291.0 0.0 8,844.0 Supply game Description: Rig Water Unit Label: bbl Unit Size: 1 Nate: Dale Consumetl Receivetl Returned Cum Consumed Cum Recall oneReturned On Loc Note 4262019 8 0 57.0 8.0 5Z0 0.0 d9.0 14C Supply Nem Description: WIF Bogers Unit Label: Gel Unit Size: Note: Dab Consumetl Receivetl Returnetl m Consumed Cum Receivetl Cum Returned Cum On Los Note 426/2019 198.0 198 0 198.0 198.0 0.0 0.0 Supply Nem Description: WlF bjadetl Obul Unit Leack Gal Unit Size: Note: Date Consumetl Received Returnetl um C"Unruatl Cum Received Cum Returned Cum Or Loc Note 0262019 840.0 840 d 840.0 840.0 0.0 0.0 Last Authority Visit Data Tot map. Nbr Total I.N.C. number Comment STOP Cards Sub mitt Company Y Rpt, Co. Doyon Dulling 8 PJSM'S Doyon Drilling Inc. 8 HRWS Wynn Dtllling Inc. a COW Doyon Drillin, Inc 3 Safe Cams MI Swaco 8 RIR's MI Swaw 9 HARC/JSA General Notes Comment: THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stefano Pierfelici Well Ops. Project Manager Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP12-SE3 Permit to Drill Number: 214-067 Sundry Number: 319-210 Dear Mr. Pierfelici: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a l a s k a. g c v Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner DATED this ZS day of April, 2019. RBp{4S lw Is 105 STATE OF ALASKA APR 2 3 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25 280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ ' Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change -out n 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Eni US Operating Co. Inc. Exploratory ❑ Development Q , 214-067 . Straligraphic ❑ Service ❑ 6. API Number: 3. Address: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 50-629-23513-00-00 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 SP12-SE3 9. Property Designation (Lease Number): 10. Field/Pool(s): 0391283, 0388583, 0388582, 0390615 Nikaitchuq Schrader Bluff Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): • 15216 Y1;�k3 ` 15216 4063 1463 N/A N/A Casing Length Size MD TVD Burst Collapse Structural : L Conductor 160 20" 160 160 Surface 2878 13.375" 2878 2463 5210 2480 Intermediate 5193 9.625" —T1 —93 3980 6890 4790 Production Liner 10163 5.5" 15216 14063 slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5193-15205 3980-4063 4.5" L80 4485 Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A 12. Attachments: Proposal Summary � Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for Ci 7 % 15. Well Status after proposed work: Commencing Operations: OIL WIND ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stefano Pierfelici Contact Name: Amjad Chaudhry Authorized Title: well Ops. Project Mana er Contact Email: amjad.Chaudh eni.com Contact Phone: 907-865-3379 Authorized Signature: t�iJ Date: COMMISSION USE ONLY Conditions of approval: Notify Commission that a representative may witness Sundry Number: n f✓\ q –2– 10 I ,s�o Plug Integrity El BOP Test (/ Mechanical Integrity Test E3Location Clearance El Other: 035"' ys� BoP 'T r -A-zsoa ps,: 4h�J�' — Post Initial Injection MIT Req'd? Yes ❑ No ❑gBDMS�APR 2 6 2019 `' Spacing Exception Required? Yes ❑ No .d Subsequent Form Required: Ci -- �� Q 1 APPROVED BY I �� Approved by: COMMISSIONER THE COMMISSION Date: lvbma Form end T onn 03 evisetl J/7 Approved appllcatiQ a n fr a date of approval. Attachments in Duplicate eni Cinii Petirolle uio n� 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierlici Phone(907)865-3320 Email: Stefano.pierfelici@enip.com April 231, 2019 Alaska Oil and Gas Conservation Commission 333 West 7' Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SP12-SE3 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP12-SE3. SP12-SE3 was completed on Spy Island on July 17`h, 2014 with an electric submersible pump set at a depth of 4,593' MD. This ESP producer was completed without a packer. The well was started up for production in July 2014 On August 19", 2016 an ESP failure was occurred. Workover was performed in March 2017, but due to excessive sand production another ESP failure occurred in June 2017 and well was shut down.5�� The estimated date for beginning this work is April 26' , 2019. 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 SP12-SE3 Workover — Summary Page PTD#:214-067 Current Status Well SP12-SE3 is currently down due a ESP failure. Scope of Work Scope of this workover is change ESP pump to a new PCS system. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1900 psi (3,980' TVD) during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB -247/5000 psi BOP configuration: Annular/pipe/blind rams /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 June 2014. C � y+.v- Well type: Producer Estimated start date: April 26`h 2019 - Drilling rig: Doyon 15 Completion Engineer: Tommaso Mallano: tommaso.mallanona eni.com Work: 907-865-3345 Sr. Drilling Engineer: Amjad Chaudhry: ami ad.chaudhrv&eni.com Work: 907-865-3379 Well Ops. Project Manager: Stefano Pierfelici: stefano.oierfelicigeni.com Work: 907-865-3320 Procedure: 1. MIRU Doyon 15. 2. Shear upper GLM valve and pump in bullheading 11 ppg NaCl/NaBr brine through tree. Pump in bullheading 11 ppg NaCl/NaBr 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 11 ppg NaCl/NaBr 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 CO runs 10. MU new PCP 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: Sud. Cesap 13-318'. 66 a 2371Y MD. 2,487 TVD 19. Inc, 4,91r MO, 3,923' 1," TVD - L9 -Baker SLXP Llnar HangedPaclor 4.981' MD RAM Hanger 36S.' Lateral Dna 10 383" Mainborb Dd6ID 4 -h -x9-518" AM Seel Bore Clasher wl 3.68" Seal Bore m Moth)keral 13,967ker02 pal cheek valva at bottomSP12-SE3 12.462kera3 10,992kere4 N 9,570kera5 4,359'MD. 3.678' TVD. SW Inc - GLM, KBMG. 4-Wx 1'. with 2.948ker x6 6,614cker 47 5,4'28 4-W 12.6 opt Production Tubing 2,235' MD. 1,915' TVD 43a Inc - GLM, KBMG. H%'x 1', with 2.000 psi STS -1 Tub. To Ann, SOV Installed ani ,aYtu T91. ;.a�gT711 x.cplg cable dempa, for ESP Power Cable (1) 318" Chem In Lina with 2500 j pal cheek valva at bottomSP12-SE3 Dual Lateral Producer 4,359'MD. 3.678' TVD. SW Inc - GLM, KBMG. 4-Wx 1'. with 3.100 pal STS -1 SOV msle9ed With ESP Lift 4.498'MD. 3745'TVD- Discharge Gauge Bob As Completed 4.575' MD. 3782'TVD. 620 Inc -Bottom of Motor Centralizer Centrililt, 93 stage 03115/2017 538PMSXD FIex47 r 20 stage 538PMSXD GINPSHH pump, 513 GS93 seals. 336 HP MSP250 motor, gas separator 4.577' MD 320 Shroud Assembly with cable and chemical Injection line feed -Crus. 4'A" Lateral Entry / Module (LEM) wl 3.68 Silver Bullet Ece, Nose Seal Bore 5-h' 15.5/17 ppf Guide Closed Shoe TD 8 314- 15.245' MD 4,992'-5,009' MD, L60 Slotted Liner 15.200' MD. 4,050' TVD. "Inc 4.050' TVO 3,943'-3,948'TVD 9001nc. r Casing Exit Window Seelbore Receptacle HAL 5-f" 00 Swell TD 8 3/4' P Packer15.215 MD. ` /-4175- 10 / \ 4.063'TV�900 5.053' MD. 3.957TVD Baker MLXP Liner - - -- - Hanger/Pecker d Assembly ]his= Caain9 5-H' 185 ppf LBO / 9-516'. 400 Slotted Liner Silver Bullet Ecc. Nose Guide Shoe 5.193' MD. 3,990' TVD 15.205' MD, 4.063' TVD. 900Im, VetcoGray MB -247 SURFACE COMPLETION SYSTEM PRP 10161, NC 00 10 OF 10 23 JANUARY 2009 HYDRIL 13-5/8" ANNULAR "GK" 5000 PSI STUD x FLANGE BX -160 HYDRIL MPL SINGLE GATE 13-5/8" 5000 PSI FLANGE x FLANGE BX -160 10" OPERATORS VARIABLE PIPE RAMS HYDRIL MPL SINGLE GATE 13-5/8" 5000 PSI FLANGE x STUD BX -160 14" OPERATORS BLIND/SHEAR RAMS HYDRIL MPL SINGLE GATE 13-5/8" 5000 PSI FLANGE x FLANGE BX -160 10" OPERATORS VARIABLE PIPE RAMS RIG 15 BOP STACK Cis HYDRIL ® fl i l 36,150' rL STATE OF ALASKA RECEIVED AIL OIL AND GAS CONSERVATION COMWION APR 1 2 2017 REPORT OF SUNDRY WELL OPERATIONS C 1.Operations Abandon Li Plug Perforations LTubing LJ Operations Stimulate LJ Pull ✓ � ��erations 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 out❑✓ 2.Operator Eni US Operating Co.Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development 0 Exploratory ❑ 214-067 3.Address: 3800 Centerpoint Dr.Ste 300,Anchorage,AK, Stratigraphic ❑ Service ❑ 6.API Number: 99503 50-629-23513-00 7.Property Designation(Lease Number): 8.Well Name and Number: 0391283,0388583,0388582,390615 SP12-SE3 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 15,216 feet Plugs measured N/A feet true vertical 4,063 feet Junk measured N/A feet Effective Depth measured 15,216 feet Packer measured N/A feet true vertical 4,063 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 160 160 160 Surface 2878 13.375" 2878 2463 5210 2480 Intermediate 5193 9.625" 5193 3980 6890 4790 Production Liner 10163 5.5" 15216 4063 Slotted Slotted Perforation depth Measured depth 5,193-15,205 feet r E... True Vertical depth 3,980-4,063 feet SCANNEDtrip.'' 0 9 2U<?, Tubing(size,grade,measured and true vertical depth) 4.5 L-80 4,496 3,745 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: 1487 139 787 283 329 Subsequent to operation: 1436 259 691 260 279 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q 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: 317-036 Authorized Name: Marc Kuck Contact Name: Amjad Chaudhry Authorized Title: Drilling&Completion Engineering Manager Contact Email:amiad.chaudhrel2enipetroieum corn Authorized Signature: /nDate: `�/./j• Contact Phone: 907-865-3379 4m Form 10-404 Revised 4/2017 (�Zi f 4/ �� tor 1 ., Zlbmit Original Only RBON1 • • c a o NJ 71- Enp M NSQ o OU J1i1tLi - =maO41 1: II - : >O�cCiM C - rON OoL N0CS) V — 4 0O /0 11 M 0 _1 >o O // hII4 41'o OUI I wi I w `r1N N UOOjW owc w oNrtem o0rn I I 4...o .0 C z U g m � _ � I I 4;) L6 I �o = Uco -a o m 5o I'cc J N M a coM > , ��' I MN N Cl) I IoOaJci 41 °' I Im .CU Oa) IcM ac " �Q � �_ Ilir I U I d -.a, = \ cD oU)x x = aJ I o0 CI) kI IQ 4 4oz (13 O -0 - = 2 � 2m 2 u) ° O 3 fI I a) co m a) X as Y r 3 O Y o o 2 c o � - I I a N C7 0 .3 a) (90 0- w 0 a) cET � � > I aUi � m .a 0 fz in .O u O c c c O C C N U o 0 c)i co ~ c I I° O 7r U _ c O c0,1 Q J II 0 N CA Zip o 0I- cl)E E .Q p> p 0, N gi o f c ri �rS ri W (n �jI I112 c a) Z(;), F- c a) F— O I— F— n m = Ill -"S a) N ih ) < \ - -a in F— a) O —as oo Cr) in N X a) (nEa. `p rn rn .� ., 2 — a6 Co > !!:U N - d W m M C COIR V ,,,,,,c1 0 c� . co a air 2 cn 2 g� O - 0 H � � U U -� X Q N 'v 7 >� O E NMO \ 3 �n • CD ^ OO L � 2 ', > 0 . N ON U Q M M C c Y •O Q V co d' «') In J U O O a_ co m < t O M J a S 0 m 0 2 a) ao c5 gi 40 5 1.0 a) u) 2 m S • x CD n /F. tr) n N N o 0o v o0 0 CO 4 (n v to rn n cY .-1 n c Q rn v rn in m `IT m • \I4 CA co au Y o c) 2 n r ". M m lU6 41 O iliiMI" m�t J X ai rn n x xx xx xc xc a cOo ,_ � J c cco0 v v v v v v v u. 'c o > c) .- 0 � a J 2 G Y Y Y Y Y Y Y L C. u u U ll U CO U CT = a) CO 0 ca 0 CO ro 'C M O (4 CO CO N a) v a) a) N a) CO (n .M— N N Ln M M vii vii v) Ln cn r..n 2 Well Name: SP12-SE. • Daily Report 0114 Wellbore Name: SP72-SE3 Well Code: 27979 Date: 3/4/2017 •enll Paage:ge:Job: MOVING P #: 20 1 of 1 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL 0 POZZO DI COLTIVAZIONE Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.94 17.23 36.71 31.80 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 Clear -20.7 E @ 6 MPH WC-35- 20.00 20.00 64.0 Daily Summary Operations 24h Forecast N/U BOPE,Test BOPE.R/U and pull hanger.R/U GBR and start puling tubing. 24h Summary Finish assembling handling equipment.Pressure test high pressure fines.R/U and kill well.N/D tree and start N/U BOPE. Operation at 07.00 N/U BOP's 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 PREP A 1 P PJSM,Bring handling equipment to rig floor,P/U subs,pressure test#2 MP to 3500 psi,assemble remaining handling equipment,dress#1 shaker. 03:00 06:00 3.00 6.00 PREP A 1 P PJSM,cont to assemble handling equipment returned from Tuboscope,cont working on top drive,run fluid through bleeder on rig floor,pressure test HP mud lines and stand pipe to 3,500 psi,(good test),inventory subs received from Tuboscope,suck out cuttings tank. 06:00 12:00 6.00 12.00 PREP A 1 P Walk through Eni lock out program on well head with crew,take on 11.0 PPG brine to rig pits,cut brine weight bade to 10.1 PPG,move Eger tank and spot,R/O for well kill operations,RIG ACCEPTED 06:00 HOURS, Cont assembling handling equipment,tum on water through out rig. 12:00 14:00 2.00 14.00 PREP A 1 'P Orientation meeting with rig crew/ENI&DOI safety reps/ODI toolpusher&DDI field superintendent. 14:00 ,15:30 1.50 15.50 PREP A 1 P Rig crew change out&Rig orientation cul rig crew tool pusher&DDI field superintendent. 15:30 16:30 1.00 16.50 PREP A 1 P Rig up bleeder line from well head to tiger tank,blow down line from well head through all circulating lines.Rig up to pressure test lines. 16:30 '18:45 2.25 18.75 PREP M 9 P Pressure test fines to 2000psi.Bullhead 75 bbls of 10.1 ppg brine down tubing at 3 bpm at 220 psi,shut down and tubing pressure dropped to 0 psi.Bullhead 350 bbls of 10.1 ppg brine down IA staging up to 8 bpm at 1370 psi.shut down and IA pressure dropped to 50 psi after 30 min. 18:45 '22:00 3.25 22.00 PREP M 9 P Bleed off 10 bbls of brine into pits from tubing and IA and shut in well.IA at 11.7 psi and tubing at 11.5 psi pressure trended down to 2.5 and 4.3 psi. Bleed well to pits until no flow,25 minutes bled back.15 bbls.Shut well in and monitor with production digital gauges for 30 minutes with initial pressures at 2.5 and.6 psi trending down to 3 inches of vacuum.open up well and confirmed well was on a vacuum.Rig down and blow down lines. 22:00 -23:30 1.50 23.50 PREP C 5 P PJSM,Install BPV,nipple down production tree. 23:30 -°00:00 0.50 24.00 PREP C 5 P PJSM,start nipple up BOPE. 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 akrigderksdoyon15(genipetroleum.com 907-685-0722 Eni representative Paul Holley ENI ENI Safety Field Supervisor Sam Dye Doyon Drilling Doyon Superintendent Tool Push Tom Shoves Doyon Drilling Tour Pusher Tool Push Jerry Hansen Doyon Drilling Tour Pusher Last Casing Seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) TVD Bot(ftKB) Run Date LINER 51/2 4.95 L-80 5,053.4 15,205.0 4,052.5 6/29/2014 Well Name: SP12-SEI. Daily Report • Wellbore Name: SP12-SE3 Date: 3/5/2017 • Well Code: 27979 Report#: 21 2n fl Page:MOVINGp 1 of 1 Well Header Permit/Concession N• Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL 0 POZZO DI COLTIVAZIONE • Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.94 17.23 36.71 31.80 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOVON LAND RIG 0723 Daily Information Weather Temperature(•F) Wind Days LTI(days) Days RI(days) FOB Partly Cloudy -18.7 ENE(4115 MPH WC-40° 21.00 21.00 69.0 Daily Summary Operations 24h Forecast Cont testing BOP's,R/D BID BOP test equipment,Cont Troubleshooting Top Drive, pull Vetco test dart&BPV,R/U Sheaves in derrick,R/U GBR,M/U landing jnt,BOLDS pull hanger inspect and disconnect penetrator&control lines,L/D Hanger,POOH with ESP completion. 24h Summary N/U BOPE,flow line,riser,attempt body test to 3500 psi Failed,replace demco valve bonnet and lift stack and work on speed head flange,lower stack re-torque speed head flange,perform body test Good test, begin initial BOP test witnessed by AOGCC Jeff Jones.Cont to troubleshoot top drive NOV rep onsite. Operation at 07.00 Testing BOP's Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 PREP C 5 P PJSM,Cont N/U BOPE,choke hose,kill line,flow line/riser,torque lower flange of BOP's to speed head,change out lower rams to 2 3/8"solid body,obtain RKB measurements. 06:00 12:00 6.00 12.00 PREP C 5 P Torque IBOP's saver sub,update well sign,R/U to test BOP's,hook up secondary kill to IA.Take on fuel for rig,cont torquing up speed head to lower ram flange.fill gap between rig and well house with insulation,rig up heater.to speed head flange. 12:00 14:00 2.00 14.00 PREP C 12 P Cont torquing up speed head to lower ram flange,attempt to body test BOPS to 3,500 psi,Fail at speed head flange and kill demco valve. 14:00 21:30 7.50 21.50 PREP C 5 TRO5 B/D kill line and vac out stack,replace demco bonnet,remove flow line&N/D BOPS to tighten studs to allow more space to tighten speed head flange,install 3 shorter studs,N/U BOPS,perform body test Good Test.Simops work on Top Drive NOV rep onsite to trouble shoot. 21:30 00:00 2.50 24.00 PREP C 12 P PT BOP's 250 psi low/3500 psi high,Test#1 W/5'test jnt,annular,1,12,13,14, upper!BOP,kit line demco valve.#2 upper rams 3 1/2"X 6"W/5"test jnt,10,11,8,kill HCR,lower IBOP#3 choke valves,6,7,9,manual kill,dart valve.#4 choke Valves 2,5,TIW valve.#5 Choke valves 3,4.Test being Witnessed by AOGCC Jeff Jones. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Eni representative Eni representative Eni representative Field Supervisor Tool Push Tool Push Last Casing Seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) ND Bot(ftKB) Run Date LINER 51/2 4.95 L-80 5,053.4 15,205.0 4,052.5 6/29/2014 Well Name: SP12-SE Daily Report Wellbore Name: SP12-SE3 Well Code: 27979 • Date: 3/6/2017 2n ll Job: MOVING Paage:ge:P #: 22 1 of 1 Well Header PermitlConcession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL 0 POZZO DI COLTIVAZIONE Rotary Table Elevation(ft) Water Depth(ft) First Flange(tt) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.94 17.23 36.71 31.80 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 -15.1 SSW 20 MPH WC-42" 22.00 22.00 70.0 Daily Summary Operations 24h Forecast Finish R/U to pull tubing,pull BPV, pickup landing jnt make up hanger,BOLDS,pull and inspect hanger,disconnect penetrator and control lines,L/D hanger,POOH laying down completion. 24h Summary Finish BOP testing,R/U BCL,finish repairing koomey,work on elevators,make procedure for laying do tbg without link tilt,practice laying down tubing with out link tilt assist,start rigging up GBR Operation at 07.00 Mobilize GBR equipment to rig floor,load pipe shed W/5"DP Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:30 5.50 5.50 PREP C 12 P PJSM,Cont testing BOP's to 250 psi low/3500 psi high,5 charted minutes WI 5",4 1/2"and 2 3/8"Test jots,annular,upper rams 3.5 x 6",blinds,lower pipe rams 2 3/8"solid body,#6 choke HCR,#7 blind rams,#8 2 3/8"lower pipe rams W/2 3/8" test jnt,#9 annular W/2 3/8"test jnt,#10 3.5"x 6"upper pipe rams W/4.5"test jot,#11 Man.&super choke to 1500 psi, perform koomey test with start man.=1400 psi system=3075 psi,annular=800 psi,after function manual=1275 psi,system =1300 psi,200 psi increase=36 seconds full system charge=218/seconds,5 bottle average=2400 psi,all test charted successful.AOGCC Jeff Jones witnessed BOP test.test gas alarms audio/visual,test PVT's,gain loss,flow out sensors and alarms. 05:30 '07:00 1.50 7.00 PREP C 5 P 'R/D test equipment,clean and clear rig floor,B/D choke manifold,choke line,kill line,test equipment. 07:00 08:00 1.00 8.00 PREP C 5 P R/D secondary kit line,simops top oft gen#1 radiators W/glycol. 08:00 09:30 1.50 9.50 PREP A 1 P PJSM,Bring centrilift equipment to rig floor,stage on floor for hanging.Simops working on top driver control panel. 09:30 13:00 3.50 13.00 PREP A 1 TR04 Remove test fitting XO from saver sub,install&torque compression rings on saver sub,quit,IBOP connections,MU IBOP actuator and torque wrench onto quill,wire tie topdrive bolts,bleed off hydraulic psi from link tilt actuator. 13:00 1800 5.00 18.00 PREP A 1 P Dig out rock washer and put heater on it.Finish Koomy repairs,finish wire ties on top drive,Install bails and 4 1/2"elevators, PJSM practice with test joint laying down joint with out link tilt assist,Hang ESP and cap sheaves,begin loading 5"dp on short side of pipe shed. 18:00 00:00 6.00 24.00 PREP A 1 P Thaw out ESP sheaves and elephant trunk box with tioga heater,Unable to remove frozen in box.Pull elephant trunks to rig floor and continue to thaw with steam.Send tugger over wind well and pick up hose and attach to ESP sheave.cont loading and strapping 5"DP. Daily Contacts Position Contact Name Company Tide Email Office Mobile Eni representative Eni representative Eni representative Eni representative Field Supervisor Tool Push Tool Push Last Casing Seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(RKB) Run Date LINER 51/2 4.95 L-80 5,053.4 15,205.0 4,052.5 6/29/2014 • • Well Name: SP12-SE3 OR Daily Report 1- Wellbore Name: SP12-SE3 -Al) I Well Code: 27979 Date: 3/10/2017 • Report#: 1 en Q 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 0 POZZO DI COLTIVAZIONE Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.94 17.23 38.71 31.80 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOVON LAND RIG 0723 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast 18.6 S©20 MPH WC 4 26.00 26 00 69.0 Daily Summary Operations 24h Forecast Disconnect penetrator&control lines.LD hanger.POOH laying down 4.5"ESP completion. 24h Summary Repair top drive commission top drive,repair degasser.RIO to kill well,bullhead 330 bbls 10 1 brine in well,monitor well,pull BPV.TT kick while tripping drill.Install landing jot and pull hanger to rig floor �� Operation at 07.00 / POOH with 4.5"ESP completion 5 4,519'MD / Time Log //5 Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Decor. 11 00 13.00 2.00 2,00 W 0 L 5 P Call out Vetco rep,P/U landing int and dress,RIB and MIU landing int to hanger 16 112 turns to WU to hanger.RN circulating lines to tubing and IA,PT lines to 2500 psi 1300 14:00 1.00' 3.00 W.O. L 9 P PJSM,for well kill,unable to read tubing pressure because BPV installed,initial IA pressure 58 psi.bullhead 70 bbls of 10.1 PPG bone dn tubing a 2 BPM 840 psi.shut dn pump tubing pressure bleed off to well bore 5 25 psi.line up to bullhead on LA. 14,00 15:00 1.00 4.00 W.O. L 9 P Bullhead 260 bbls 10.1 PPG brine dn,IA*8 BPM,ICP 1270 psi.FCP 1400 psi. 15,00 19:00 4.00 8.00 W.O. L 1 P Monitor well,unable to read tbg pressure due to BPV installed,Initial IA pressure 60 psi,bleed off to 22 psi over 1 hour,cont monitoring well,bleed.63 bbls over 5 min.to a residual slow drip.shut in 8 psi pressure built up to 19 psi over 30 minutes, cont monitor well for an additional 30 min.psi a 19.3,check IA in well bay through needle valve crude returns from IA.R/U to bleed trailer.IA pressure 28 psi,bleed off for 15 min.gas returns no fluid,bleed to zero allow to vent for 5 minutes,close IA pressure built to 6 psi after 7 min. 19'.00 20:00 1.00 9.00'W.O. L 19 P Cont monitoring well for 1 hour pressure built up from 6 psi to 19 psi. 20:00 22:00 2,00 11.00 W.O. L 19 P Bleed off to zero and leave open to bleed trailer for 30 min. 22.00 23:00 1.00 1200 W.O. L 20 P Rig down tbg circ lines and B/D d prep to pull BPV, 23'.00 0000 1 00 13 00 W.O. L 5 P PJSM,UD landing jnt,pull BPV. Daily Contacts Position Contact Name Company Title Email Office • Mobile En:representative Oliver Amend ENI Drilling Supv. 907-685-0715 En:representative Mike Grubb ENI Dolling Supv. 907-685.0715 En:representative Mitch Bilington ENI Rig Clerk akrigclerksdoyon155enipetroleum.com 907-685-0722 Eni representative Paul Holley ENI ENI Safely Field Supervisor Sam Dye Doyon Drilling Doyon Superintendent Tool Push Tom Shones Doyon Drilling Tour Pusher Tool Push Jerry Hansen Doyon Dnliing Tour Pusher Last Casing Seat Cas.Type OD(in) ID(in) Grade Top ittKB) Bottom(RKB) TVD Bot.(RKB) Run Date LINER 5 12 4 95 LOU- 5,053 4 15.205 0' 4 052 5'6/29/2014 • • Well Name: SPI2-SE3 OR Daily Report Wellbore Name: SPI2-SE3 Well Code: 27979 Date: 3/11/2017 •enII Job: WPage:ORKOVER Page:1 I of 1 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co,Inc DEVELOPMENT WELL 0 POZZO DI COLTIVAZIONE Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53 94 17 23 36.71 31 80 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOYON LAND RIO 0723 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Mostly Cloudy 6.6 WSW @ 17 MPH WC-15' 27 00 27.00 69.0 Daily Summary Operations 24h Forecast Pull Motor W/sick line.pull and lay down ESP components and shroud,Clear floor.install wear nig.P/U M/U Clean out BHA.single in hole with DP. Perform clean out.POOH. 24h Summary L!D hanger.POOH WI ESP completion to Motor,filling hole per procedure 8 complete tubing Bush every 1000'.pull tubing stop.begin R/U Halliburton slick line to pull motor. Operation at 07.00 Laying down ESP components. Time Log Start End Cum Dor Time Time Our(hr( (hr) Phase Opr. Act. Plan Oper.Baser. 00 W 02.00 2 00 2.00 W 0 L 20P PJSM Cont.to inspect Tubing Hanger.Disassemble CAP Tube from Hanger.Make test cut on ESP cable.Install pulling head to ESP cable hook,LID Hanger and Pup joint on bottom of Hanger.R/U FOV to X/0 563 Pin. 02:00 05:00 3.00 5.00 W.O. L 4 P L/D 2 Joints.line disconnected at Spooler Unit.Shut down and fixed.Cont.to L/D 3 more joints.Filling 5.5 bbls 10.1 ppg Brine per hour.Was able to see fluid level(Crude Oil)at Well Head during filling.Shut down and attach control line and ESP to Spooler Unit. 05:00 09.00 4.00 9.00 W 0 L 4 P POOH from 4,591'to 3.069'(total metal displacement 6.9 bbls).PU WT 110K.Fill up annulus(Al)and tubing on the way out using tip tank and mud pump(average rate arm.5.5 Oh). 09.00 11'00 2.00 11.00 W.O. L 20 P Shut down to add Herculite in front of Spooler Unites per 0)0 Rep.SIMOPS RIU Pressure washer to clean ESP cable on rig floor.RIU pump to IA for pumping oil from well to Tiger Tank to prevent Hydro Carbons in pits.(Pump 5.6 bbls in IA every hour). 11'00 11.30 0.50 11 50 W.O. L 7 P Fill hole to bottom of Annular and pump out to Tiger Tank floating crude oil In hole. 11 30 12:00 0 50 12 00 W 0 L1 P PJSM Blow down line to Tiger Tank.M/U TIW Valve to Tubing string and kelly up with lop Drive to pump 47 bbl down tubing as per 1,000'pulled.Lost 90.3 bbl for Tour. 1200 15:00 3 00 1500 W 0 L 7 P PJSM,M/U TIW valve to tubing string and kelly up on top drive,pump 97 4 bbls 10.1 PPG brine®1.5-3 BPM,850 psi-2400 psi maintaining fluid level while pumping crude contaminated brine off IA to ager tank,33 bbls returned to tiger tank.BID top drive and return lines. 15.00 17:15 2.25 17.25 W.O. L. 4 P Cont to POOH laying do 4 1/2"L-80 12 6*Hyd 563 tubing from 3079'MD to 1950'MD,run continuous hole fill to keep ESP cable&cap line clean,fill IA WI 21.5 bbls with hole fill pump with no retums to surface. 17.15 16'00 0.75 18.00 W 0 L 7 P M/U TIW valve to tbg string and kelly up with top drive.pump 35 bbls 10 1 PPG brine 5 3 BPM,1800 psi maintaining fluid level while pumping crude contaminated brine out of IA to tiger tank,17 bbls returned to tiger tank.BID top drive and retum line. 18'00 19'15 1.25 19.25'W O L 4 P Cont to POOH F/1950'MD to 1023'MD.run continuous hole fill to keep ESP cable and cap line clean,fill IA with 30 bbls with no returns to surface. 19:15 19'45 0.50 19.75 W 0 L 7 P M/U TIW valve to tbg stung and belly up Wi top drive,pump 15 bbls 16.1 PPG bnne 5 3 BPM,1450 psi maintaining fluid level pumping crude contaminated brine off IA to tiger tank,8 bbls returned to tiger tank,B/D top drive&return line. 19,45 2190 1 25 21.00 W.O. L 4 P Cont to POOH Ff 1023'to 157'MD,run continuous hole fill to keep ESP cable&cap tube clean,fill IA WI 30 bbls with hole fill pump no returns to surface. 21 00 23100 ' 2 00 23.00 W.O. L 4 P Terminate ESP and cap tube L/D two more jnts&DGU assembly and inspect&clear minimal sand debris for string,spot Halliburton slick line unit and stage equipment,M/U tbg stop retrieval tool and run inside and pull tubing stop by hand I PJSM. Filling hole every hour with 10 bbls 10.1 PPG bene. 23.00 00:00 1.00 24.00 W 0 L 20 P PJSM,P/U 1 jnt tubing and RIH,begin RIU Halliburton slick line to pull motor Daily Contacts Position Contact Name Company Title Email Office Mobile Enl representative Oliver Amend 'ENI Drilling Supv. 907-685-0715 Eni representative Mike Grubb ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk akrigcierksdoyonl S5enipetroleum corn 907-685-0722 Enl representative Paul Holley ENI ENI Safety Field Supervisor Sam Dye Doyon Drilling Doyon Superintendent Tool Push Tom Shones Doyon Drilling Tour Pusher Tool Push Jerry Hansen Doyon Drilling Tour Pusher Last Casing Seat Cas.Type OD(in) ID(In) Grade Top(RKB) Bottom(RKB) TVD Bot.(ftKB) Run Date LINER 51/2 4.95 L-60 5053.4 15.2050 4,0525 6/29/2014 • • Well Name: SP12-SE3 OR Daily Report Wellbore Name: SP12-SE3 Well Code: 27979 Date: 3112/2017 nc Job: WORKOVER Page: #: 3 ePage: t 1 of 1 Well Header Permit/Concession N` Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc DEVELOPMENT WELL 0 POZZO DI COLTIVAZIONE Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB•Tubing Spool(ft) 53.94 17 23 36.71 3120 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 Clear -15.8 NI @ 10 MPH WC-36 28 00 28.00 67.0 Daily Summary Operations 2411 Forecast M/U BHA#2.RIH.Clean Main Lateral Bore.Mal BHA#3.RIM Clean Out Leg Bore.Prep for Completion 24h Summary Performed 3 Fishing runs w/slickllne.recover inner string.L/D ESP Assy M/U BHA#1 Single In hole w/BHA#1 with 5"D.P.and perform clean as per plan POOH and check for Debris.LID BHA#1,minnimal debris.minnimal sand. Operation at 07.00 PIU Mill BHA#2 with 2 3/8"Tubing Time Log Start End Cum Dur Time Time Dar(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 0000 0130 1.50 1.50 W.O. R 5 P PJSM with all essential personnel.Perform 3 Slickline runs for Tubing Stop,Pack Off and Pump.LID Wireline tools and Equip There appeared to some sand on top of the pack off but no issue pulling with Wireline. 01 30 06:00 4.50 6,00 W.0, L 5 P L/D Upper and Lower Perforated housing,Upper and Lower Tandem Seals.210 HP Motor,Well Lift MCU Sensor,Motor Centralizer,7"Shroud and Gas Dispersion Tuba.Shroud appeared to packed with light sand. 0600 08:30 2.50 8,60 W.O. L 5 P Clean and clear rig floor,clean Cannon Clamps,L/D 90 cross collar clamps.12 sp clamps.2 single collar clamps,1 splice clamp and 2 centralizers. 08.30 10:00 1.50 10,00 W.O. L 5 P PJSM LID ESP Elephant Trunk from Derrick and Super Sack from rig floor. 10.00 11.30 1.50 11,50 W.O. L 5 P PIU Baker Fishing tools and Equip.Break down X/0 on door valve. 11 30 12.00 0.50 12.00 W.O. L 5 P Set Wear Bushing as per Vetco Rep onsite.Total hole fill for tour 115 bbls. 12 00 14.30 2.50 14.50 W 0 L 5 P PJSM WI all essential personnel.P/U MIU Clean Out BHA#1,8.5"Junk Mill,Bit Sub,Pup Jnt,5,5'VACS Tool,Pump Out Sub,X/0,8.25"Magnet,Bumper Sub,Oil Jar and X10. 14:30 20,00 5.50 20.00 W.O. L 5 P PIU D.P T/4811'BREAKING CIRCULATION every 1,000'to ensure string la clear and filling annulus every hour with 10 bbls 10.1 ppg S,W with no returns/stand back 3 stands TI 4244'Cont.T/PIU D.P 714611'/Obtain parameters 180K P/U WT/ 140K S/C WT I(50K ROT WT a 10 RPM WI 4K Free Torque 13 BPM 400 PSI/4 BPM 650 PSI/Act Disp=90.5 bbls/Cal Disp=35,91 Total loss 126.4 Bbls. 20:00 22.00 200' 22.00 W.0, L 5 P Wash&Rotate Dn @ 10RPM VV/4K Free Torque Fl 4611'T/4855'@ 3-4 Bpm 450-650 Psi/Wash Dn with no rotation Fl 4885'and tag liner top©4915'/Wash&Recip. 3 Bpm 450 Psi F/4915'up to 4813'3 times/B/D Top Drive and prep to POOH/Pumped away 109 Bbla while wash down. 22',00 23:30 1.50 23.50 W 0 L 5 P POOH F14915'T/2745' Metal Displacement 154.Pumped total 31 Bbls. 23:30 00:00 0,50 24,00 W.O. L 5 P Service Draw Works 1 Brakes/Iron Roughneck Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mike Grubb ENI Drilling Supv. 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Em representative Paul Holley ENI ENI Safety Field Supervisor Sam Dye Doyon Drilling Doyon Superintendent Tool Push Tom Shones Doyon Drilling Tour Pusher Tool Push Jerry Hansen Doyon Dulling Tour Pusher Last Casing Seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(R(B) TVD Bot.(ftK8) Run Date LINER 512 4.95 L-80 5,053.4 15,205.0 4,052.5 8(292014 • • Well Name: SP12-SE3 OR Daily Report • Wellbore Name: SP12-SE3 • Well Code: 27979 Date: 3/13/2017 2nfl Pagge:e:• 1 Job: WORKOVER Pa #:1 of 1 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA EM PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL 0 POZZO DI COLTIVAZIONE Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.94 1;23 36-71 31.80 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOVON LAND RIG 0723 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Partly Cloudy -14 4 N @ 13 MPH WC-36 29 00 29.00 66.0 Daily Summary Operations 24h Forecast Run In hole with vacs bha assembly and clean bore leg.Pull out of hole and lay down BHA,lay down DP.Prepare to run completion. 24h Summary Make cleanout run on morn bore.9 518"less than one gallon of sand in VACS tool.Make up and run cleanout assy and clean upper lateral. make up and run clean out assy#3 in hole to 901'. Operation at 07.00 Run in hole with vacs bha assembly and clean bore leg. Time Log Start End Cum Dor Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Decor. 00:00 01:30 1.50 1.50 W.O. L 5 P PJSM Cont to POOH F/1,998'to 190'MD.Monitor well.Filling hole every 5 stands DBL metal displacement 7.5 bbls,total metal disp.28 bbl.Plus 10 bph down IA with no returns to surface. 01:30 -02:30 1.00 2.50 W.O. L 5 P PJSM L/D BHA#1.Magnets showed minimal debris.VACS tool was emptied with minimal fine sand.Rack back VACS tool 02'30 03:00 0.50' 3.00 W.0 L 5 P Clean and clear rig floor. 03:00 04:00 1.00 4.00 W.O. L 5 P PJSM R/U GBR Power Tongs and FOV. 04'00 06'30 2.50 650 W.O. L 5 P PJSM PIU MIS BHA#2 as per Baker Rep onsite BHA 2 15118"Mule Shoe.1 2 318"PH6 Jot,X10,Clapper Valve,X/O.12 3/8'PH8 Jnt,X/0,2 ea Clapper Valves.X10.16 ea 2 3/8"PH6 Jnts,5/0,Locator Sub.X10,5 ea 2 3/8'PH6 Jnts,X10,Pup. 5.5'VACS Tool,Pump Out Sub,0/0.Extreme Magnet,Bumper Sub,Oil Jar,X10 total length 872'MD. 06.30 07:00 0.50 7.00 W.O. L 5 P Break down FOV,M/U X/0 to TT525.RID Power Tongs and C/O Elevators. 0700 12.00 5 00 12.00 W,O, L 5 P RIH W/5'D.P.P1872'to To 4,900'MD Kelly up at 4.885'MD.PWT 170K,SLK 140K,Pumps at 3 bpm 350 PSI.Wash down slowly watching for liner top 5 4.915'MD.No indication of TOL,Cant to wash down to 5,830'MD.Did not see Locator tag 5) 5,612'MD.P/U 2 5"single and Cont.to wash down to 5,686 MD.Appeared to enter lateral hole by verification tag with VACS tool on TOL.Decision was made to pull back above TOL and try putting 0.5 wrap in string.L/D 1 5°single.Pumped away 132 bbl 10.1 ppg Brine during washing down Hole fill every hour 97 bbl total for tour,total loss for tour 257 bbl. 1200 15:30 3.50 15.50 W.O. L 5 P POOH F/5,863'10 4,925'MD.PWT 185 K.SLK 1404,Put 0.5 wrap in string and work up and down.RIH to 5,658'MD PWT 170K,SLK 140K,no indication of main bore.Cont.to RIH and tag Vac Tool on seal bore Aesy.At 5,886'MD W/10K verification.POOH F/5,686'to 4,925'MD PWT 185K,SLK 140K.Put 2.5 wraps in string and work up and down.RIH to 5,631' MD no tag at 5,612'MD.Decision was made to POOH and evaluate debris in VACS tool and PIU bent joint 15,30 17:00 1.50 17.00 W.O. L 5 P POOH F15,631'T/2,458'ACT DISP=45BBLS I CAL DISP=22.5 17.00 18:30 150 18.50 W.O. L -5 TR01 Repair Glycol Hose On Draw Works 18.30 19:00 0.50 19.00 W.O. L 5 P CONT.T/POOH F/2,458'T/872'/ACT DISP=34.52/CAL DISP=17.26 1900 21.30 2.50 21.50 W.O. L 5 P L/D JARS,BUMPER SUB 8 EXT MAGNET/STAND BACK 5-1/2"VACS TOOL/L/D 23 JTS OF 2 3/8 PH6/CLEAN FLAPPERS/FLAPPERS HAD 2 GAL.OF DEBRIS/JNT 4 HAS 10'OF DEBRIS/JNT 3 WAS FULL OF DEBRIS 21.30 22.00 0.50 22.00 W.O. L 5 P CLEAN RIG FLOOR 2200 00.00 2.00 24.00 W.0 L 5 P PJSM/M/U CLEAN OUT BHA#3 T/901'/FILLING IA 10 BPH Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv 907.585-0715 Eni representative Mike Grubb ENI Drilling Supv. 507..585-0715 Eni representative Wade Thomas ENI Rig Clerk 507.695-0722 Eni representative Paul Holley ENI ENI Safety Field Supervisor Sam Dye Doyon Dulling Doyon Superintendent Tool Push Tom Shones Doyon Drilling Tour Pusher Tool Push Jerry Hansen Doyon Drilling Tour Pusher Last Casing Seat Can.Type OD(in) ID(In) Grade Top(ftKB) Bottom(1KB) TVD Bot.(ftKB) Run Date LINER 5 1/2 4.95 L-80 5,053.4 15.205 0 4.052 5 6/29/2014 • • Well Name: SPI2-SE3 OR Daily Report Wellbore Name: SPI2-SE3 Well Code: 27979• Ret ort#:as 017 2n0 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 0 POZZO DI COLTIVAZIONE Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.94 17 23 36.71 31-80 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 -13 7 N cQ 12 MPH WC-35 30.00 70 00 65.0 Daily Summary Operations 24h Forecast Run in hole with ESP Completion Assembly. 24h Summary Ran in hole with BHA#3 Clean Out Assembly.Pulled BHA#3 out of hole and Layed Down.Clean&Cleared Rig Floor and Prep for RIC W/ESP Completion. Operation at 07.00 Assembling ESP Equipment to RIH. Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Deccr. 00 00 01:00 1.00 1.00 W 0 L 5 P PJSM Cont.to RIH WI 5"D P.FI 901'MD to 1.647 MD.Filling 10 bbl every hour. 01 00 02'.00 1.00 2 00 W 0 L 5 P Service rig,grease Top Drive and Dravworks. 02'00 03.30 1.50 3 50 W 0 L 5 P Cont.to RIH WI 5'D.P El 1.647'to 4,915'MD at Mule Shoe TOL PWT 170K,SLK 140K. 03:30 05:30 2.00 5.50 W.O. L 0 P Kelly up and wash down at 3 bpm.350 PSI F/4,915'to 5,660'Mule Shoe depth.Locator Sub did not tag 3.58"Camco DB Nipple la 5,033'MD P/5 2 singles and confirm tag up at the VACS tool at TOL was in the same spot.Mule Shoe depth 5,714' MD. 05:30 06:00 0.50 6.00 W 0 L 5 P POOH F/5,714'to 4,915'MD.Filling double metal displacement. 0600 08:00 200 8.00 W.0 L 5 p Turn string 180°and work string"Wash down at 3 bpm,350 PSI F/4.915'to 5.660"Mule Shoe Depth.Locator Sub did not tag 3.56"Camco DB Nipple rtg 5,033'MD. 08.00 '0630 0 50 8.50 W.O. L 5 P POOH F/5,660'to 4,915'MD.Filling double metal displacement. 08.30 11:00 2.50 11.00 W.O. L S P Turn string 270°and work string.Wash down at 3 bpm.350 PSI F/4,915'to 5,660'Mule Shoe Depth,Locator Sub did not tag 3,56"Camco DB Nipple 6 5.033'MD.Decision was made to POOH laying down D.P. 11:00 1200 1.00 1200 W.O. L 5 P 'PJSM L/D 5"D.P.to Pipe Shed 6/5.660'to 5,007'MD.Cont.to fill double metal displacement and 10 bph.Pumped away 259 bbl washing in hole,57 bbl pumped during none pumping operation for the hourly fill.Total losses for tour 316 bbl. 12:00 12130 0.50 12.50 W.O. L 5 P Blow down Choke and Kill lines.PJSM for stp and cut drilling line, 12'30 14:00 1.50 1400 W.O. L 5 P Slip and cut 7 wraps of drilling line 59'.Service Drawworks. 14:00 17.30 3.50 17.50 W 0 L 5 P Continue To Lay Down 5"DP F/5007'7/910' 17:30 20:30 3.00 20 50 W.O. L 5 P L/D and Clean out BHA#3/2 Gal.Thick Oily Mud&2 Cups of sand found in VACS Tool.ACT Displacement=76.76 Cal Displacement=38.38/Filling the hole with double displacement=10 BPH 20.30 21:30 1,00 21.50 W.O. L 5 P Clean&Clear Rig Floor I Unload 2 3/8"PH6 F/Pipe Shed f Load GLM's in Shed. 21,30 22:00 0.50 22.00 W L 5 P Pull Wear Ring 22.00 23:30 1.50 23.50 W.0. L 5 P Mobilize CRT&Dog Bones TI Rig Floor/Mobilize 2 Boxes Of Clamps,Centrilift tool boxes and splice table to Rig Floor. 23.30 00:00 0.50 24.00 W 0 L 5 P R/U 7"Pick Up Sling,MWU Floor VaNe and Rig Up to Pick Up 7"Shroud Assy. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv. "907-665-0715 Eni representative Mike Grubb ENI Drilling Supv. 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Paul Holley EN) ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15®doyondrillingrem 907-685-0716 Tool Push Jerry Hansen Doyon Drilling Tour Pusher Last Casing Seat Cas.Type OD OM ID(in) Grad* Top MKS) Bottom(ftKB) TVD Bot.(ftKB) Run Date LINER 51/2 4.95 L-80 5.053.4 15,205.0 4.052.5 6/29/2014 11111 • • Well Name: SPI2-SE3 OR Daily Report Wellbore Name: SPI2-SE3 Well Code: 27979• Ret ort#:5/G2017 en fl Job: WORKOVER Page: ge:1 of 1 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc DEVELOPMENT WELL 0 POZZO DI COLTIVAZIONE Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53 94 17 23 36 71 31.80 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 Mostly Cloudy -24.3 N @ 12 MPH WC-48 31.00 31.00 65.0 Daily Summary Operations 24h Forecast P/U M/U Hanger and make up ESP Ire and CAP line to Hanger.Land Hanger and N/D BOP,NIU Tubing Head Adapter. 24h Summary P/U ESP Assembly,M/IJ&Test ESP Cable.RIH With 4 5"Completion.Testing ESP Cable&Cap Tube EVery 1.000'. Operation at 07.00 M/U Tubing Hanger&ESP Penetrator Splice Time Log Start End Cum Dur Time Time Dar(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01.00 1.00 1.00 W.O. K 20 P PJSM R/U 7"Shroud. 01:00 0130 0 50 1 50 W 0 K 20 P PJSM Hold table top discussion on Kick while running completion drill. 0130 0200 0 50 2 00'W 0. K 4 P PJSM PIU motor and MGU and fill with oil. 02:00 04.30 2.50 4.50 W.O. K 4 P PJSM P/U upper and lower seal sections,intake.2-pumps,well/8()GU,XO pup.7"casing centralizer and pup jt Service seals and fill with oil. 0430 0600 1.50 6 00 W 0 K 20 P PJSM 9/U and pull ESP and control lines over sheaves to rig floor. 06:00 07.30 1 50 7 50 W 0. K 12 P PJSM M/U Tech wire to MGU.terminate to DGU.PT Tech Wire to 5000 psi. 07:30 09:00 1.50 9.00 W.0 K 4 P PJSM R/U motor lead and capillary line.Install 2-clamps on seals,6-pump clamps and clamp above DGU 09:00 10.30 1.50 10.50 W.0 K 20 P PJSM R/U Volant tool and long bail extensions. 1030 11:00 0.50 11.00 W.O. K 4 P PJSM M/U first It.and RIO table for Gator Splice. 11 00 1130 0 50 11.50 W.0.. K 20 P PJSM Prep wire for Gator Splice. 11 30 14.30 3.00 14.50 W.O. K 12 P PJSM Perform Gator Splice witnessed by ENI Electrician.PT Cap Tube and test splice.Winessed.Fill hole @ 10 BPH. 1430 00.00 9 50 24 00 W.O. K 4 P PJSM RIH wl 4.5"12.6 9/8 L60 Hyd 563 tubing as per tally to 3966'.130k puw.120k sow,Sling hdtw 10 bph,testing cable and cap tube every 1000'. Daily Contacts Position Contact Name Company Title Email Office Mobile Err representative Oliver Amend ENI 'Drilling Supv. '907-685-0715 Eel representative Russ Wimmer ENI Dolling Supv. SIDDniling@enipetroleum com 907-685-0715 907-320-0058 Em representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Paul Holley ENI ENI Safety Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyendrilling.com 907-685-0716 Tool Push Jerry Hansen Doyon Dolling Tour Pusher Eni representative Marc Kuck ENI Engineer Last Casing Seat Cas.Type OD(in) ID(in) Grade Top(f8KB) Bottom(ftKB) TVD Bot.(ttKB) Run Date LINER 51/2 4.95 L-80 5,053.4 15.2050 4.0525 6/29/2014 • • Well Name: SP12-SE3 OR Daily Report Wellbore Name: SP12-SE3 Well Code: 27979 Date: 3/16/2017 ern!' Job: 1 Job: WORKOVER Report o 7 of 1 Well Header Permit/Concession fir Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc DEVELOPMENT WELL 0 POZZO DI COLTIVAZIONE Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 5394 1723 36.71 31.80 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 0000N LAND RIG 0723 Daily Information Weather Temperature("F) Wind Days LTI(days) Days RI(days) FOB Clear -20.5 N(g8 MPH WC-39 32.00 32 00 61.0 Daily Summary Operations 24h Forecast Complete Tree Test Test ESP,and Cap.Pull TWC Valve,CLean Pits and Prep to Move Rig. 24h Summary RIH W/4 5"Completion Land Hanger.Pull BPV.Set TWC,N/D BOPE,N/U and test Tubing Head Adapter.NAL Tree,and fill with diesel,perform low pressure test 500 psi for 5 Min Operation at 07.00 testing Tree. Time Log Start End Cum Our Time Time Our(hr) (hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02.00 2.00 2.00 W.O. K 4 P PJSM Cont.to RIH ESP and 4.5"563 HVD F/3,985 to 4,561'Mb.Test ESP and CAP lines every 1,200'.Cont.to fill hole 10 every hour. 02,00 04:00 2.00 4.00 W.O. K5 P PN M/U Tubing Manger to landing joint as per Vecto Rep onsite. 04:00' 0700 ' 3.00 7.00 W.O. K 5 P Install check valve below Hanger.Cut CAP and ESP lines and space out for Hanger Penetrator.Make final ESP splice cable to Penetrator pig tail Assy.Test ESP cable and attempt to test CAP line. 07.00 08.30 1,50 8.50 W.O. K5 T003 C/O fitting on chemical injection line.Purge air out of lines as per Centrals#.Fin failed fitting 3/8'X 5'under Hanger.Fitting failures on test pump.re valve and set up test pump properly, 08:30 11-.00 2.50 11 00 W 0 K5 TD03 Perform numerous Press.tests F12.150 to 1.850 PSI.Pumped 8 gallons of Dalfrost to purge air CO)3,500 PSI.Pressure bleed down F13,500 to 800 PSI over 35 Min,Held 800 PSI for 20 Min.Witnessed by Co Rep onsite.Decision was made to land the Hanger 11:00 11.30 050 11.50 W.O. K 5 P PJSM Land Hanger as per Vetco Grey Rep onsite.PWT 136K SLK 121K 11'30 1290 0.50 12 00 W.O. K 5 P RILDS as per Vetco Grey onsite.Test upper and lower body seals to 5,000 PSI for 10 Min.Witnessed by Co Rep.Total lost for tour 127 bbl. 12:00 12:30 0.50 12.50 W.O. K 5 P 'LID landing joint and install BPV as per Vetco Grey rep onsite. 12:30 13:00 0.50 13.00 W.O. K 5 P RIU and pull ESP and CAP lines back to spooling unit. 13.00 14,30 1.50 14.50 W.O. K 5 P RID Volant toot from Top Once,Clear GBR and Baker Centrilitt tools and Equip.from rig floor. 14.30 -15:30 1 AO 15.50 W.O. K 5 P Flush Mud Pumps.BOP Stack,Choke&Kill Lines w/hot water and deep dean.Blow Down Lines. 15.30 -16:30 1.00 16.50 W.O. K 5 P PJSM.Revove 2-38"Solid Rams&Install 4-12"X 7"in Lower Ram Cavity -16:30 1&OO 1.50 18.00 W.O. K 5 P Clean Drip Pan,LID Mouse Hole.Pull Rotary Riser. 18.00 20:00 2.00 20.00 W.O. K 5 P PJSM.N/D BOPE. 20.00 23:30 3.50 23.50 W O. K5 P PJSM,Pull Riser.Remove Circ Lines and second IIA Valve,install hardline from VA to production line.Clean Hanger, Terminate ESP and Cap Tube,Fill Hanger Void,Install TREE,PIT Hanger Void Q 5K Psi.for 10 Min,Pull BPV,Install TWC. 2330 00.00 0 50 24.00 W 0 K5 P Fill Tree W/Diesel.RIO 8 PIT Tree Body,Swab,and Wing Valves,500 Psi Low for 5 Min. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Dnlling Sup, 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnllingt(enipetroleuincom 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Tool Push Chad Johnson Doyon Drilling Tool Pusher rigl5(2doyondrilling.com 907-685-0716 Tool Push Jerry Hansen Doyon Drilling Tour Pusher Last Casing Seat Cas.Type OD(sn) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot(RKB) Run Date LINER 51/2 495 1.-80 50534 15.2050 4,052.5 8/292014 • 0 Well Name: SP12-SE3 OR Daily Report Wellbore Name: SP12-SE3 Well Code: 27979 Date: 3117/2017 • Report#: 8 en Il 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 0 POZZO DI COLTIVAZIONE Rotary Table Elevation(ft) Water Depth(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.94 17 23 36.71 31.80 Rig Information Rig Name Contractor Rig Type Rig Num RIG 15 DOVON LAND RIG 0723 Daily Information Weather Temperature OF) Wind Days LTI(days) Days RI(days) POB Clear -176 Ncex 1 MPH WC-18 3300 3300 63.0 Daily Summary Operations 24h Forecast Move Rlg to SP26NW3 24h Summary Completed Tree,Master.and Swab Valve Test Pulled TWC Secure Well.Cleaned Well Bay. Operation at 07.00 Rig Released to SP28-NW3 @ 0600 Hrs. Time Log Start End Cum Dur Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Decor. 00-00 04:00 4.00. 4.00 W O K .5 'P PJSM.continue Tree,Master.and Wing Valve Test,(PASSED)Continue to 0/0 Upper IBOP;and Saver Sub on Top Drive. 0400 05.00 1 00' 5 00 W O K '5 P Pull TWC,Secure Well,Clean Up Well Bay&Tree. 05:00 0600 1 00' 6 00 W 0 K .5 P Clean Pits.Take on Fuel,Blow DOwn Water to Rig Floor.Pull Caps on Mud Pumps. 0/A Psi=150 PSI I/A Psi=O TBG Psi=O Rig Released @ 0600 Hrs I Rig Accepted on SP26-NW3 @ 0601 Hrs Daily Contacts Position Contact Name Company Title Email _ Office Mobile Eni representative Oliver Amend ENI Dnuing Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enlpetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Tool Push Chad Johnson Doyon Drilling Tool Pusher rigs 5@doyondrilling core 907-685-0716 Tool Push Jerry Hansen Doyon Drilling Tour Pusher Last Casing Seat Cas.Type OD lin) ID(In) Grade Top(RKB) Bottom(ftKB) TVD Bot.(RKB) Run Date LINER 51/2 4.95 L-80 5,0534 15,205.0 4.052.5 6129/2014 • • g\�o���y�,,� THE STATE Alaska Oil and Gas Of A T c K Conservation Commission A. 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 A ,S -- •---- Fax: 907.276.7542 www.aogcc.alaska.gov Marc Kuck Well Operations Project Manager Eni US Operating Co. Inc. SCANNED MAR 0 9 2017. 3800 Centerpoint Dr., Ste. 300 Anchorage,AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP12-SE3 Permit to Drill Number: 214-067 Sundry Number: 317-036 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 P. oerster Chair / SI- DATED this ! day of February, 2017. RBDMS PMEa - 3 2017 III- • I• RECEIVED STATE OF ALASKA JAN 2 4 2017 ' ALASKA OIL AND GAS CONSERVATION COMMISSION �;s 2 APPLICATION FOR SUNDRY APPROVALS AOG ? 20 AAC 25.280 1.Type of Request: Abandon E 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 0 Other. ESP Change-out ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Eni US Operating Co.Inc. Exploratory ❑ Development 0- 214-067 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-629-23513-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A SP12-SE3 ` Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 7 9.Property Designation(Lease Number): Pit 10.Field/Pool(s): 0391283, 0388583, 0388582t 3/0 ipIS' Nikaitchuq Schrader Bluff Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15216 k 4063 ' 15216 N 4063 ' 1065 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 Surface 2463 13.375" 2878 2463 5210 2480 Intermediate 5193 9.625" 5193 3980 6890 4790 Production Liner 10163 5.5" 15216 4063 slotted slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5193-15205 ‘ 3980-4063 4.5" L80 4485 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary E Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development❑✓ t Service ❑ 14.Estimated Date for 2/28/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 , WINJ ❑ WDSPL ❑ Suspended ❑ 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 ar>ljad.chaudhry(.enipetroleum.com Printed Name Marc Kuck Title Well Operations Project Manager 907-865-3379 Signature , 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 ❑ US BOP Test Mechanical Integrity Test ❑ Location Clearance III ,_f t Other: ,› 3'ca) Psi GO? 1 C i Post Initial Injection MIT Req'd? Yes ❑ No ❑ l' Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: t 0 — 4l✓4J - 3 20 7 FZS®6°�i AFL 7p APPROVED BY Approved by: aie / 9COMMISSIONER THE COMMISSION Date: 2. — / — /7 Submit Form and Form 10-403 Revi d 11/2015 rz�pVac4ti i valid for 12 mont s fr m the date of approval. Attachments in Duplicate PI'3 l/2 4��- flGhMPLI - . '�4i �r 2, , RECErin u tIrolkmum ,AN 2 4 201 AO 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 SP12-SE3 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP12-SE3. SP12-SE3 was completed on Spy Island on July 17th, 2014 with an electric submersible pump set at a depth of 4,593' MD. This ESP producer was completed without a packer. The well was started up for production in July 2014 On August 19th, 2016 an ESP failure was occurred. / The estimated date for beginning this work is February 28th, 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, Marc Kuck Well Operations Project Manager • SP12-SE3 Workover— Summary Page PTD#:214-067 Current Status Well SP12-SE3 is currently down due a ESP failure. 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 1500 psi (3,923' 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 June 2014. Well type: Producer Estimated start date: February 28th 2017 Drilling rig: Doyon 15 Completion Engineer: Amjad Chaudhry: amj ad.chaudhry(a�enipetroleum.com Work: 907-865-3379 • • Procedure: 1. MIRU Doyon 15. 2. Shear upper GLM valve and pump in bullheading 8.6 ppg KCl 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 35.00 psi. ✓ 4. Pull tubing to upper GLM. 5. Shear lower GLM valve and pump in bullheading 8.6 ppg KC1 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 7""i 2.266'MD,1.938'TVD 43°Inc-GLM.KBMG. 4-A"x 1",with I` 2,000 psi STS-1 SOV installed eni _' petH"tOeuhYll 4-'A"x-cplg cable clamps.for ESP Power Cable.(1)3/8"Chem Inj Line with 2500 SP12-SE3 psi check valve at bottom 4,392'MD.60°Inc-GLM.KBMG, 4-Y,"x 1".with 3.100 psi STS-1 Dual Lateral Producer SOV installed with ESP Lift 4,485'MD,3.739'TVD-Discharge Gauge Sub As Completed ` 4.593'MD.3.790'TVD,62°Inc-Bottom of Motor Centralizer Centrilift,TIC-ESP. 7/17/2014 I 57+52 stage 380P35MSXD+25 stage G42 380MSXD pump,513 GSB3 seals,210 HP MSP250 motor.gas separator 4.P/\'c 4.637'MD 32#Shroud Assembly with cable and chemical Surf-Casing !j=-' injection line feed-thrus,3.5"perforated gas dispersion tube 13-3/8".68# '�j .;\ 4'A"Lateral Entry 2,878'MD, '! Module(LEM)wl 3.68 Silver Bullet Ecc.Nose TO 8 314" 2,463'TVD Seal Bore . Guide Closed Shoe 19°Inc. /( 5-%"155/17 ppf 15.245'8 MD L80 Slotted Liner 15,200'MD.4.050'TVD. l / 4,992'-5,009'MD, 90°Inc. 4,050'TVD TVO MD,3,923'Baker ,- -/Casing Exit 'TVD i 90°Inc. 7VD-Lt-Baker ` \` Casing Exit Window SLXP Liner - �- 1 Hanger/Packer 4,981'MD RAM Hanger ''-'-'-.«:�.,«.�. ''aew.'s''''..,."'"'''.'', ''''.'a:' _..�.,.�t..z�.=.m,.nerasr a,,..t�;=,��,.ay. ."'""'''- 4 1 3.G5"Lateral Drift ID ^ 3.83"Mainbore Drift ID r l 4-'/"x 9-5/8"'AM { �, HAL 5-%"Oil Swell TD 8 3/4" Seal Bore Diverter �'{\., Sealbore Receptacle Packer 15,216 MD. w/3.68"Seal Bore A '? 4.75"ID y 4.063'TVD 90°Inc. Item MD(ft) �v, _..�,; „-° Swell Packer al 13,947 5.053'MD,3,957'TVD ' hH, . -4, Swell Packer#2 12,462 Baker MLXP Liner Swell Packer#3 10,992 Hanger/Packer 4,# 1 Swell Packer 94 9,570 Bottom of Seal ' y ANIM rte' Swell Packer#5 7,948 Assembly Interm.Casing Swell Packer#6 6,6145-V,"15.5 ppf 180 9-5/8".40# Slotted Liner Silver Bullet Ecc.Nose Guide Shoe Swell Packer#7 5,478 5,193'MD.3,980'TVD 15.205'MD.4,063'TVD 90°Inc. Nikaitchuq Field-Spy Island 83°Inc. • • b �N - E ot I5 . ,g O s O _ r P L N Q 8 P_ NU Z c g a w .O% .. ,O .O O - b ii mz K CO0 m m O H II i 6 N M IA ID I---- Z .. D P;In In h g LL 9 0 = 1 o❑ N .J Z O W gg n O=W g3� ON = tD °D._N r-, ♦p- • t -�_ c$: !.. ,C.7 g rA 1-a.. c'3 v J a am _ z • 5 S N $ I S S : S dt Si N E g gl >r x R g1 I0 -2s N. :1EX 13 h v I -- ' ii . - ii' i . j i . v Z AIIUiflhfIiIIi:IipI 5. _ ____ . 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ZO 12A08 8 s msMaND '-Zn Wb z n W z n z M w 33 Sm " vc ? a a V n co ln Z Z LL Z Z Z ' in Ea Oa ON8d C 4 6 tr 0) o Ud 6 b h ¢ 4. . tt 14 6 aaa a )3 a a a a a a a a a a a a a a a a a aa a aCO aa. ¢_ r aCO w O O O O O O O O O O O O co co co to co co to co co co co co co co 0 U co 0 _ Technical Report Title Date Client: Eni Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: July 25, 2014 Surface Data Logging End of Well Report SP12-SE3 SP12-SE3 L1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 6. Show Reports 7. Mud Record 8. Bit Record 9. Morning Reports 10. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ENI Petroleum Rig: Doyon 15 Well: SP12-SE3 & SP13-SE3 L1 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23513-00-00 (SP12-SE3) 50-629-23513-60-00 (SP13-SE3 L1) Sperry Job Number: AK-XX-0901412968 Job Start Date: 6 June 2014 Spud Date: 8 June 2014 Total Depth: 15,216’ MD, 4,063’ TVD (SP12-SE3) 15,245’ MD, 4,050’ TVD (SP12-SE3 L1) North Reference: True Declination: 19.260° Dip Angle: 81.055° Total Field Strength: 57623 nT Date Of Magnetic Data: 6 June 2013 Wellhead Coordinates N: North 70° 33’ 28.067” Wellhead Coordinates W: West 149° 54’ 16.167“ Drill Floor Elevation 53.93’ Ground Elevation: 13.10’ Permanent Datum: Mean Sea Level SDL Engineers: Leigh Ann Rasher, Kori Jo Plowman Doug Acker, Jane Grundin, Danielle Dawson SDL Sample Catchers: Hilary Garney, Danielle Dawson, David Durst, Megan Cardenas Company Geologist: Andrew Buchanan Company Representatives: Ben Perry, Jack Keener, Russ Wimmer, Mike Ross, Oliver Amend SSDS Unit Number: 110 DAILY SUMMARY 06/06/2014 SDL continued on location from previous well. Spott and set mudlogging shack. Wait on the unit to warm up before rigging up. Rig up mudlogging unit. Nipple up diverter system and make up hanger. Perform a dummy run and diverter test. 06/07/2014 Nipple up diverter stack and test. Rig up secondary kill line, kill well SI11 with 200 barrels of 9.6 ppg brine, and perform dummy run on 13 ⅜" hanger, install diverter pup. Rig up and bleed OA pressure, rig down equipment. Perform diverter test. Load rig floor with BHA tools. 06/08/2014 Install skirt around stack, prepare handling equipment for BHA. Pick up BHA #1. Pre SPUD meeting, flood conductor, test surface lines. Clean out conductor to 160 MD'. Pull out of hole to 33' MD and then picked up BHA #2. Troubleshoot MWD software. Shallow hole test Gyropulse / MWD at 160' MD. Drill from 160' MD to 392' MD. Pump out of hole. Make up remaining BHA #2, wash down to 392' MD. Drill from 392' MD to 1059’ MD. Gas: The maximum gas was 37 units at 1023’ MD and the average gas was 9 units. 06/09/2014 Drill from 1059' MD to 2883' MD. Monitor static well. Back ream out of hole from 2883' MD to 2783' MD. Gas: The maximum gas was 752 units at 1962’ MD and the average gas was 119 units. 06/10/2014 Backed ream out of hole as per K&M from 2783' MD to 406' MD. Pull out of hole from 406' MD to 123' MD. Set back 2 stands of heavyweight drill pipe. Blow down the top drive. Lay down BHA #2 as per SLB. Rig up Volant casing equipment. Make up 13 ⅜" shoe track to 121' MD and test. Run in hole with casing to 1000' MD. Continue running in with casing from 1000' MD to 1780' MD. Pull back to 1760' MD, would not go past 1780' MD. Attempt to break circulation and pressure up to 650 psi with no returns (shoe plugged). Then attempted to free with 3000psi; no returns. Rotate out of hole from 1760' MD to 1485' MD. Gas: The maximum wiper gas was 798 units. 06/11/2014 Pull out of hole from 1485' MD to 82' MD with 13 ⅜" casing, laid down in pipe shed. Drain shoe track and cut all connections, laid down same. Clean/clear rig floor, rig down Volant, laid down GBR casing tongs, bring 15 ⅞" stab and 12 ¼" bit to floor. Clean rig floor. Lubricate rig. Pick up and make up BHA #3 to 576' MD; trip in hole from 576' MD to 2817' MD. At 2817' MD break circulation, wash down and tag bottom at 2883' MD. Back ream out of hole from 2883' MD to 1275' MD as per K&M Gas: The maximum wiper/trip gas was 133 units. 06/12/2014 Back ream out of hole as per K&M from 1276' MD to 297' MD. Laid down BHA #3. Blow down top drive, clean and clear rig floor. Rig up to run casing as per GBR. Run in hole to 2202' MD with 13 ⅜" casing as per detail, fill and circulate every 10 joints. Continue to run in the hole with casing from 2202' MD to 2837’ MD. Break circulation every 10 joints. Make up landing joint/hanger, land at 2877' MD. Circulate and condition mud for cementing, weight up mud push. Pump cement as per plan. Pressure test cement line, pump 103 barrels mud push, 469 barrels lead slurry, 65 barrels tail slurry, chase with spud mud, bump plug at 405 barrels, with 75 barrels cement returns. Rig down all equipment and rig down casing equipment. Gas: No gas was observed. 06/13/2014 Nipple down surface stack and nipple up BOPE. Prepare surface hanger. Nipple up wellhead, test connections to 2000 psi. Nipple high-psi riser. Nipple up BOP and test plug, perform BOP and choke body test, rigged down test equipment (good test). Prepare to change saver sub and install a new saver sub, load and process 5" drill pipe in shed. Lubricate rig. Continue to load and process 5" drill pipe. Make up stands and rack back. Gas: No gas was observed. 06/14/2014 Make up stands of 5" drill pipe and rack back in derrick. Rig up and begin testing BOPE. Change out upper seals on pipe rams. Change out upper and lower IBOP's. Rig up to test BOP. BOP test, witness waived by Jonnie Hill with AOGCC. Test completed successfully. Pull test plug & set wear bushing. Break down and rig down test equipment. Rig up and test 13 ⅜" casing to 2500psi. Break down and rig down test equipment. Pick up and make up BHA #4. Gas: No gas was observed. 06/15/2014 Pick up BHA #4 as per SLB. Run in hole from 655' MD to 2534’ MD. Shallow hole test at 1500' MD. Wash and ream from 2534' MD to 2795' MD. Drill out float equipment, shoe track and 22' of new hole to 2905' MD. Displace to 9.25 ppg LSND, pump 45 barrels of high viscosity spacer, 410 barrels of LSND. Blow down top drive. Cut and slip drill line, inspect brakes. Circulate bottoms up for formation integrity test, recip. from 2814' MD to 2721' MD. Rig up and perform leak off test to 10.6ppg equivalent mud weight. Break circulation and wash and ream from 2814' MD to 2905' MD. Drill from 2905' MD to 3247' MD, 2815' TVD. Gas: The maximum gas was 52 units at 3268’ MD and the average gas was 23 units. Geology: Samples consisted of 100% clean sandstone. 06/16/2014 Continue to drill from 3268' MD to 4215' MD. 2815' TVD Gas: The maximum gas was 22 units at 3980’ MD and the average gas was 12 units. Geology: Samples consisted of 90% sandstone with 10% siltstone. 06/17/2014 Continue to drill 12.25 '' hole; TD intermediate section at 5207' MD. Circulating and back reaming out of hole. Gas: The maximum gas was 988 units at 4806’ MD and the average gas was 83 units Geology: Samples consisted of 100% clean well sorted sandstone 06/18/2014 Circulate bottoms up two times. Rack stands back from 5165' MD to 5056' MD. Back ream out of hole at 850 gpm, 1400 psi & 80 rpm to 2878' MD. At 4175' MD and 3217' MD, work through twice with no pump psi increase. At 3217' MD to 2878' MD; 4" to 5" clay returns observed and circulated bottoms up 4.5 times from 2878' MD to 2627' MD. Monitor well to be static for 10 minutes. Pull out of the hole to 2160’ MD. Pumped 25 barrels 11.4 lb/gal dry job. Laid down BHA #4. Gas: The maximum gas was 190 units. 06/19/2014 Float 9 ⅝" casing to 126' MD. Test floats successfully. Run in hole with casing from 126' MD to 5192' MD. Rig down Tesco equipment and rig up cement head. Fill casing at 3 bpm. Cement Job:105 bbls MudPush, 79.5 barrels 12.5 lb/gal lead cement and 51 barrels 15.8 lb/gal tail cement. Gas: The maximum gas was 172 units. 06/20/2014 Nipple down BOP. Set e-slips and cut 9⅝” casing. Nipple up BOP and test BOP. Test 9 ⅝” casing to 3000 psi for 30 minutes. Pick up BHA #5 Gas: The maximum gas was 0 units. 06/21/2014 Run in hole with BHA #5. Shallow hole test MWD tools. Continue to run in hole. Displace from LSND mud to FazePro mud. Drill out shoe and 20’ of new hole. Drill ahead to 6203’ MD. Gas: The maximum gas was 2341 units. Geology: Samples consisted of 100% clean sandstone 06/22/2014 Drill 8.75” hole from 6203’ MD to 8296’ MD Gas: The maximum gas was 2272 units. Geology: Samples consisted of 100% clean sandstone 06/23/2014 Continue to drill 8.75” hole from 8296’ MD to 10803’ MD. Gas: The maximum gas was 2651 units. Geology: Samples consisted of 100% clean sandstone 06/24/2014 Continuing to drill 8.75” hole from 10803’ MD to 12110’ MD. Gas: The maximum gas was 2964 units. Geology: Samples consisted of 100% clean sandstone 06/25/2014 Continue to drill 8.75” hole from 12110’ MD to 14306’ MD. Gas: The maximum gas was 3420 units. Geology: Samples consisted of 100% clean sandstone 06/26/2014 Continue to drill 8.75” hole from 14306’ MD to 15216’ MD. TD production section. Backream out of hole Gas: The maximum gas was 3166 units. Geology: Samples consisted of 100% clean sandstone 06/27/2014 Continue to backream out of hole Gas: The maximum gas was 17 units. 06/28/2014 Continue to backream out of hole. Lay down BHA #5. Rig up liner equipment and run in hole with 5 ½” liner Gas: The maximum gas was 7 units. 06/29/2014 Continue to run in the hole with 5 ½” liner. Pick up power tongs, make up seal assembly, and set slim pulse in collar. Make up one stand of 5” drill pipe. Shallow test MWD. Clean pump room. Run in hole with 5” drill pipe. Orient MWD and hanger. Tag bottom and pick up to 15205’ MD. Set hanger and test. Gas: The maximum gas was 8 units 06/30/2014 Unsting from top of liner. Pull out of hole 3 stands. Cut and slip drill line. Service rig. Pull out of hole and lay down running tool. Pick up Whipstock BHA #6 and run in hole to 4922’ MD. Orient Whipstock to 5064’ MD and set. Gas: The maximum gas was 12 units. 07/01/2014 Mill 8 ¾” window in 9 ⅝” casing from 4992’ MD to 5032’ MD. Pump sweep, monitor well and pump dry job. Pull out of hole and lay down BHA. Service rig. Pick up BHA #7 and run in hole. Perform formation integrity test to 13.0 ppg. Orient MWD and motor. Gas: The maximum gas was 18 units and the average gas was 14 units. 07/02/2014 Continue to drill from 5031’ MD to 5232’ MD. Circulate bottoms up three times and pull out of hole. Laydown BHA, rig up and test BOP. Pick up BHA #8 and run in hole. Gas: The maximum gas was 48 units and the average gas was 25 units. Geology: Samples consisted of 90% siltstone and 10% sandstone. 07/03/2014 Run in hole with BHA. Shallow hole test MWD, Ecoscope failure. Pull out of hole and change out Ecoscope. Run in hole and MAD Pass from 5030’ MD to 5232’ MD. Drill ahead to 7096’ MD. Gas: The maximum gas was 1954 units and the average gas was 629 units. Geology: Samples consisted of 100% clean sandstone. 07/04/2014 Drill ahead from 7096’ MD to 9745’ MD. Gas: The maximum gas was 2204 units and the average gas was 975 units. Geology: Samples consisted of 100% clean sandstone. 07/05/2014 Drill ahead from 9745’ MD to 12387’ MD. Gas: The maximum gas was 2756 units and the average gas was 1183 units. Geology: Samples consisted of 100% clean sandstone. 07/06/2014 Drill ahead from 12387’ MD to 13775’ MD. Gas: The maximum gas was 2246 units and the average gas was 1160 units. Geology: Samples consisted of 100% clean sandstone. 07/07/2014 Drill ahead from 14775’ MD to TD at 15245’ MD. Begin backreaming out of hole. Gas: The maximum gas was 2063 units and the average gas was 1554 units. Geology: Samples consisted of 100% clean sandstone. 07/08/2014 Backream out of hole from 9922’ MD to 5117’ MD. Work DS through tight spots and pack offs to 5462’ MD. Reduce RPM and continue backreaming out of hole, working BHA across whipstick slide. Gas: The maximum gas was 139 units and the average gas was 10 units. 07/09/2014 Backream out of hole from 4800’ MD to 3476’ MD. Circulate bottoms up twice. Pull out of hole from 3476’ MD to 957’ MD. Pull out of hole from 957’ MD to 397’ MD. Lay down BHA #9 and clean rig floor. Pick up HWDP and make up BHA #1B as per Baker Hughes. Trip in hole with BHA #1B from 490’ MD to 1421’ MD. Gas: The maximum gas was 137 units and the average gas was 9 units. 07/10/2014 Pull out of hole from 4940’ MD to 490’ MD. Laid down BHA #1B, no whipstock on hook. Make up BHA #1B. Trip in hole from 491’ MD to 1518’ MD. Shallow hole test MWD tools. Trip in hole from 4942’ MD to whipstock slide at 5002’ MD. Pull up and observe hook latch at 4996’ MD. Jar whipstock free. Slight static loss. Drop ball rod at 4941’ MD and pick up to 4911’ MD. Pull out of hole from 4942’ MD to 490’ MD. Gas: The maximum gas was 6 units and the average gas was 2 units. 07/11/2014 Lay down Whipstock Retrieval BHA and clean rig floor. Make up Baker cleanout BHA to 454' MD run in hole from 454' MD to 4937' MD washing down to 5051' MD observe top of liner hanger. Wash down to 5078' MD increasing flow rate. Wash up to 4990' MD. Circulate bottoms up @400 GPM. Pull out of hole from 4937' MD to 80' MD Laid Cleanout BHA As per Baker Rep. Clean BHA. Load Comp. Tools and MWD in Shed. Make up Diverter with hanger seal assembly. Stage up pumps to verify tool release. Test was Unsuccessful. Prepare well for well control and wait on replacement diverter. Gas: The maximum gas was 5 units and the average gas was 2 units. 07/12/2014 Make up BHA and run in the hole with seal assembly on 5" DP. From 150' MD to 4917' MD. With shallow hole test @ 1500' MD Was down from 4917' MD to 5086' MD Verify Anchor latch up. Release tool. Monitor well. Static; Pulled out of hole from 5086' MD to 65' MD. Loaded casing tools and make up liner shoe. Run in the hole with 5.5' Liner to 3292' MD. 80 Jts Run. 07/13/2014 Run in hole with 5.5" Liner from 3292' MD to 10176' MD Entry into SBD At 4985' MD with Window Exit at 5007' MD Pick up and make up ported crossover with Volant tool. Make up RAM liner Hanger. Make up Bumper sub and crossover. Run in hole to to 15093' MD. Break Circulation. Wash down to 15183' MD. Observe drop into Alignment slot. Drop Setting Ball. Picked up to Ensure Ram is Set. Top at 4981' MD. Shoe at 15200' MD. Displace 9.2+ OBM w/9.1+ Brine. Pulled out of hole on Elevators and laid down liner running tools. Serviced brake liner packer. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 0 5 10 15 20 25 30 35 40 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: SP12-SE3 & SP12-SE3 L1 OPERATOR: ENI Petroleum MUD CO: MI Swaco RIG: Doyon 15 SPERRY JOB: AK-XX-0901412968 Days vs. Depth 06 June 2014 Sperry SDL continue on location from previous well LOCATION: Spy Island AREA: North Slope Borough STATE: Alaska SPUD: 8-Jun-2014 TD: 7-Jul-2014 Commenced 16.0" Surface Hole Section On Bot: 01:40 8 Jun 2014 TD Surface Hole Section 2883' MD, 2465' TVD Off Bot: 22:00 9 Jun 2014 Landed 13.375" Casing 2878' MD, 2463' TVD 12 Jun 2014 Commenced 12.25" Intermediate Hole Section On Bot: 16:08 15 Jun 2014 TD Intermediate Hole Section 5207' MD, 3981' TVD Off Bot: 22:34 17 Jun 2014 Landed 9.625" Casing 5193' MD, 3980' TVD 19 Jun 2014 Commenced 8.75" Production Hole Section On Bot: 14:45 21 Jun 2014 TD Production Hole Section 15216' MD, 4063' TVD Off Bot: 13:10 26 June 2014 TD Production Hole Section 15245' MD, 4050' TVD Off Bot: 02:58 07 Jul 2014 POOH for Ecoscope MWD tool failure 03 Jul 2014 Drill 8.75" hole to 5232' MD POOH to test BOPs 02 Jul 2014 Commenced 8.75" L1 Production Hole Section On Bot: 07:10 01 Jul 2014 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Doyon 15 HOLE SECTION:Surface EMPLOYEE NAME:DATE: Recommendations: Have a standard for swapping out computers. Innovations and/or cost savings: N/A Douglas Acker 19-Jun-2014 What went as, or better than, planned: Rigging up after the rig move went as well as planned Difficulties experienced: After changing out the Iris and 4th computer everything seemed to be working as it should until we tried to connect Wits to SLB. As usual we went through and double checked the screen shots to make sure everything was set up as it was before. After working on the issue for several hours I thought it might be a network issue. I double checked the settings and everything looked ok. I thought maybe there was a communication issue with the new computer since I used the same IP address as before. I changed them to a new IP address that was not in use and that solved the problem. SP12-SE3 Spy Island ENI Petroleum North Slope Borough AK-XX-0901412968 Alaska Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Doyon 15 HOLE SECTION:Intermediate EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 AK-XX-0901412968 Alaska SP12-SE3 Spy Island ENI Petroleum North Slope Borough Danielle Dawson 21-Jun-2014 What went as, or better than, planned: During the section, all of the gas gear performed as required without any problems. Also, the networking problem with not being able to connect to SLB's WITSed data was resolved, and no further issues were encountered. Difficulties experienced: As experienced previously, Insite was having issues tracking depths. During connections, it was not switching in and out of slips correctly, so that after a connection had been made, the bit depth was off by one stand causing about 90 feet of lost gas data. Recommendations: The bit depth needs to be manually corrected after each correction to reflect the actual depth. Innovations and/or cost savings: N/A Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Doyon 15 HOLE SECTION:Production EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Recommendations: The network issue with Insite should be resolved ASAP so we can get back to using Insite as we normally do. Make sure all crew members check pump configurations before starting each well to avoid having wrong liner ID's, etc. It is important for trainees to beaware of the bit depth while making a connection to avoid having to make depth corrections. Also make sure to keep an eye on the chromatograph while drilling to make sure it does not stop cycling while drilling. Innovations and/or cost savings: N/A Leigh Ann Rasher 26-Jun-2014 What went as, or better than, planned: No major issues were experienced with gas equipment. Difficulties experienced: Insite software ran super slow on all computers except the ADI. We had to use the ADI for most Insite operations (adding comments, data statistics, etc) due to this problem. WITs froze several times a day while drilling and had to be completely shut down and restarted. We think the WITs issue has to do with the Insite issues. Pump 3 configuration had to be corrected due to lag being off when using pump 3. The bit tracker unnoticably got stuck in slips a few times during connections causing depth corrections to be made. The chromatograph also stopped cycling by itself and had to be restarted once or twice while drilling. SP12-SE3 Spy Island ENI Petroleum North Slope Borough AK-XX-0901412968 Alaska Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Doyon 15 HOLE SECTION:Production EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Recommendations: Continue to monitor going in and out of slips and adjust when needed. Innovations and/or cost savings: Near the end of the well the block weight, the hookload threshold and the block speed was changed allowing Insite to track slips, and therefore depth, much better than before. 7-Jul-2014 What went as, or better than, planned: Sample collection went well with no problems. Regular maintenance and properly installed equipment did not result in condensation causing issues with the gas gear. Filters were changed on the shaky panel and have been filtering out more water from the lines. Did not experience the networking problems encountered previously with the SLB MWD data. Difficulties experienced: Chromatograph lost connection with computer from 12,331-12,368'. Insite was having difficulty tracking depth and going in and out of slips at inapproriate time, necessitating manual bit depth corrections. Also, an Insite problem causing block height trace and pit trace display issues on the time log has occurred. Megan Cardenas, Danielle Dawson SP12-SE3 L1 Spy Island ENI Petroleum North Slope Borough AK-XX-0901412968 Alaska Surface Data Logging After Action Review Surface Data Logging WELL NAME:SP12-SE3 & SP12-SE3 L1 LOCATION:Spy Island OPERATOR:ENI Petroleum AREA:North Slope Borough MUD CO:MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:8-Jun-2014 SPERRY JOB:AK-XX-0901412968 TD:7-Jul-2014 Marker MD INC AZ TVD TVDSS 16" Surface Borehole SV-4 777.0 18.6 318.6 767.9 -714.0 SV-3 1,172.0 33.7 321.0 1,118.9 -1,065.0 SV-2 1,503.0 41.8 317.6 1,378.8 -1,324.9 Permafrost Base 2,038.0 42.0 315.4 1,768.9 -1,715.0 SV-1 2,263.0 43.4 328.5 1,936.1 -1,882.2 Ugnu Top (UG4)2,658.0 25.7 332.7 2,258.2 -2,204.3 12 1/4" Intermediate Borehole UG-2 Coal Bed Marker 3,225.0 19.2 50.2 2,793.8 -2,739.9 Lower Ugnu 4,072.0 46.4 98.4 3,500.4 -3,446.5 Schrader Bluff 4,556.0 61.7 105.0 3,773.0 -3,719.1 N Sequence Top 4,623.0 62.4 105.9 3,804.5 -3,750.6 N Sand Top 4,711.0 64.2 108.3 3,844.1 -3,790.2 N-2 Top 4,746.0 65.1 109.1 3,859.2 -3,805.3 N-3 Top 4,762.0 65.5 109.5 3,865.9 -3,812.0 N Sand Bottom 4,855.0 68.7 112.2 3,902.1 -3,848.2 N Sequence Base 5,029.0 77.0 117.2 3,951.5 -3,897.6 8 3/4" Lateral Leg OA Sand Top 5,519.0 76.8 116.9 4,014.3 -3,960.4 OA-2 5,600.0 86.0 128.3 4,020.2 -3,966.3 OA-3 5,689.0 86.2 129.1 4,026.2 -3,972.3 OA-3 6,543.0 92.0 124.0 4,039.8 -3,958.9 OA-2 6,643.0 91.2 123.5 4,037.0 -3,983.1 OA-2 7,858.0 87.2 124.9 4,060.0 -4,006.5 OA-3 7,961.0 86.1 125.1 4,066.4 -4,012.5 OA-3 9,547.0 91.4 125.0 4,074.3 -4,020.4 OA-2 9,605.0 90.8 125.5 4,073.1 -4,019.2 OA-2 10,875.0 88.5 125.4 4,069.5 -4,015.6 OA-3 11,018.0 88.2 125.3 4,074.0 -4,020.1 OA-3 12,382.0 91.9 125.5 4,070.9 -4,017.0 OA-2 12,498.0 91.4 125.6 4,067.6 -4,013.7 OA-2 13,856.0 89.1 124.7 4,054.9 -4,001.0 OA-3 14,046.0 87.2 124.5 4,061.4 -4,007.5 8 3/4" L1 Lateral Leg OA-Sand Top 5,710.0 86.2 117.3 4,023.1 -3,969.2 OA-2 6,546.0 86.6 128.1 4,040.7 -3,986.8 OA-3 6,670.0 87.0 127.9 4,047.9 -3,994.0 OA-3 8,022.0 90.6 124.7 4,069.9 -4,016.0 OA-2 8,193.0 91.1 123.2 4,068.2 -4,014.2 OA-2 9,405.0 89.0 127.3 4,076.5 -4,022.6 OA-3 9,652.0 87.2 126.1 4,079.6 -4,025.7 OA-3 10,966.0 92.9 126.8 4,078.9 -4,025.0 OA-2 11,042.0 92.5 126.5 4,075.3 -4,021.4 OA-2 12,295.0 87.5 124.8 4,070.1 -4,016.2 OA-3 12,406.0 86.9 123.9 4,075.8 -4,021.9 OA-3 13,975.0 92.6 123.7 4,067.5 -4,013.6 OA-2 14,237.0 91.4 123.4 4,059.8 -4,005.8 TD 8 3/4" L1 lateral 15,245.0 90.0 124.9 4,049.8 -3,995.8 Formation Tops Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: No Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 1 SP12-SE3 5655 7090 Spy Island 4024 4041 ENI Petroleum Kori Jo Plowman OA Sands Andrew Buchanan 6/27/2014 Interpretation: This interval displays non-producible hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, fine to very fine grain, subangulat to subrounded, well sorted, quartz sand. There is no free oil in the sample, trace dull yellow to white sample flourescence, streaming or blooming dull yellow cut fluorescence, clear cut, a light amount of clear residual ring, and dull yellow to white residual flourescence ring. Cuttings Analysis: Odor none Fluorescence Cut Fluorescence Residual Cut clr Color Intensity dull Color yel Residual Flourescence none-fnt Amount none Distribution pchy Intensity dull Color Stain Amount tr Type stmg-bloom Amount yel-wh Oil Show Rating Free Oil in Mud dull Color clr Color Cut Color yel-wh Intensity 214865 6259 208606 1003 1 Hydrocarbon Ratios 5655 Gas Units 1937 Mud Chlorides (mg/L) =80000 142 16 126 4346 222 14 208 2065 110 9 101 1656 51 3 48 2 6044 Gas Units 2227 Mud Chlorides (mg/L) =78000 252437 7911 244526 867 307 25 282 1430 Hydrocarbon Ratios 188 17 171 944 293 34 259 2374 76000 256058 9582 246476 742 116 13 103 3 394 62 332 1018 298 56 242 698 6405 Gas Units 2272 Mud Chlorides (mg/L) = 4 7090 Gas Units 2035 Mud Chlorides (mg/L) = 494 141 353 1408 202 27 175 78000 219185 2011 217174 674 322 0 322 905 188 8 180 247 7 240 553 412 19 393 1207 Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: No Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Leigh Ann Rasher OA Sands Andrew Buchanan 6/23/2014 Interpretation: This interval displays non-producible hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, fine to very fine grain, subrounded to subangular, well sorted, quartz sand. There is no free oil in the sample, uniform dull yellow sample flourescence, a dull yellow streaming flourescence cut, straw to light amber cut, a light amount of pale straw to light amber residual ring, and dull yellow residual fluorescence ring. Show Report Report # 2 SP12-SE3 7700 8900 Spy Island 4055 4074 ENI Petroleum 1 Hydrocarbon Ratios 7724 Gas Units 2093 Mud Chlorides (mg/L) =76000 Amount 100% even dull yel Distribution 2 436 82 354 1649 305 30 275 984 252 29 223 620 264394 7656 256738 800 348 27 321 1131 8674 Gas Units 2424 Mud Chlorides (mg/L) =72000 234 104 130 Hydrocarbon Ratios 270 57 133 233722 14341 219381 798 4 8837 Gas Units 2651 Mud Chlorides (mg/L) =72000 1366 221 33 188 261 34 227 711 3 213 664 490 150 340 1737 287726 9308 278418 884 467 106 361 237308 11516 225792 875 313 55 258 1060 8131 Gas Units 2144 Mud Chlorides (mg/L) =75000 203 70 Residual Cut strmg dull yel Fluorescence 0.00 Cuttings Analysis: 533 136 397 1961 251 109 142 358 43 315 1136 293 48 245 701 Color Free Oil in Mud Intensity Color none none straw-lt amb Cut Fluorescence Oil Show Rating wh Intensity Color Odor Stain Color Amount Cut Color ltAmount ambColor Residual Flourescence dull Type Intensity 1 10 100 1000 Oil Gas NPH NPH 1.0 10.0 100.0 1000.0 NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: No Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Leigh Ann Rasher OA Sands Andrew Buchanan 6/23/2014 Interpretation: This interval displays non-producible hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, fine to very fine grain, subrounded to subangular, well sorted, quartz sand. There is no free oil in the sample, uniform dull yellow sample flourescence, a dull yellow streaming flourescence cut, pale straw to light amber cut, a light amount of amber residual ring, and dull white residual fluorescence ring. Show Report Report # 3 SP12-SE3 9100 10900 Spy Island 4079 4069 ENI Petroleum 1 Hydrocarbon Ratios 9119 Gas Units 2296 Mud Chlorides (mg/L) =70000 Amount 100% even dull yel Distribution 2 508 222 286 2399 312 70 242 1270 263 76 187 830 271389 18612 252777 1114 286 59 227 1470 10240 Gas Units 2410 Mud Chlorides (mg/L) =66000 278 145 133 Hydrocarbon Ratios 273 53 99 250863 13376 237487 981 4 10852 Gas Units 2306 Mud Chlorides (mg/L) =62000 1337 235 46 189 229 57 172 926 3 220 754 532 181 351 1990 256553 12481 244072 1135 445 172 273 276379 11653 264726 932 327 43 284 1203 9403 Gas Units 2558 Mud Chlorides (mg/L) =70000 255 156 Residual Cut strmg dull yel Fluorescence 0.00 Cuttings Analysis: 306 115 191 3487 173 103 70 255 40 215 2068 152 34 118 1278 Color Free Oil in Mud Intensity Color none none pl straw Cut Fluorescence Oil Show Rating wh Intensity Color Odor Stain Color Amount Cut Color ltAmount ambColor Residual Flourescence dull Type Intensity 1 10 100 1000 Oil Gas NPH NPH 1.0 10.0 100.0 1000.0 NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: No Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 4 SP12-SE3 L1 5232'7200' Spy Island 3962'3760' ENI Petroleum Danielle Dawson OA Sands Andrew Buchanan 7/8/2014 Interpretation: This interval displays non-producible hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, fine to very fine grain, subrounded to subangular, well sorted, quartz sand. There is no free oil in the sample, uniform dull yellow sample flourescence, a dull yellow streaming flourescence cut, pale straw cut, a light amount of amber residual ring, and dull to bright white residual fluorescence ring. Cuttings Analysis: Odor fnt Fluorescence Cut Fluorescence Residual Cut med-lt straw Color brn Intensity dul Color yel Residual Flourescence none-fnt Amount tr Distribution uni Intensity dul Color Stain Amount 30%Type stmg Amount yel Oil Show Rating Free Oil in Mud bri Color pl straw Color Cut Color yel Intensity 167515 23817 143698 604 1 Hydrocarbon Ratios 6311 Gas Units 1426 Mud Chlorides (mg/L) =69000 315 112 203 2024 311 73 238 1005 197 54 143 708 125 54 71 2 6747 Gas Units 1705 Mud Chlorides (mg/L) =69000 196075 65079 130996 609 308 93 215 757 Hydrocarbon Ratios 250 77 173 487 429 160 269 1394 69000 222128 3752 218376 581 179 85 94 3 376 0 376 786 296 18 278 469 6886 Gas Units 1954 Mud Chlorides (mg/L) = 4 6970 Gas Units 1923 Mud Chlorides (mg/L) = 509 43 466 1050 214 6 208 69000 217376 223 217153 646 336 0 336 698 239 0 239 311 0 311 398 554 8 546 909 Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Yes Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 240 138 102 234 64 170 602 466 183 283 1671 69000 198463 28039 170424 782 279 61 218 1002 4 8933 Gas Units 1768 Mud Chlorides (mg/L) = 432 140 292 722 225 43 182 222 32 190 773 211 41 170 450 7960 Gas Units 1628 Mud Chlorides (mg/L) =69000 139349 7996 131353 691 302 225 77 3 Hydrocarbon Ratios 331 211 120 520 636 432 204 1378 69000 245422 139349 106073 676 379 222 157 884 298 146 152 2 7997 Gas Units 2204 Mud Chlorides (mg/L) = 625 234 391 1249 350 96 254 805 334 98 236 486 242308 52411 189897 748 1 Hydrocarbon Ratios 8001 Gas Units 1717 Mud Chlorides (mg/L) =69000 yel Oil Show Rating Free Oil in Mud dul Color pl-med straw Color Cut Color yel-wh Intensity pl straw Color Intensity br Color yel Residual Flourescence none-fnt Amount none Distribution uni Intensity dull Color Stain Amount abd Type stmg Amount Cuttings Analysis: Odor fnt Fluorescence Cut Fluorescence Residual Cut Andrew Buchanan 7/8/2014 Interpretation: This interval displays non-producible hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, fine to very fine grain, subrounded to subangular, well sorted, quartz sand. There is no free oil in the sample, uniform bright yellow or white sample flourescence, a dull yellow streaming flourescence cut, pale to medium straw cut, a clearr residual ring, and dull white residual fluorescence ring. Show Report Report # 5 SP12-SE3 L1 7200'9200' Spy Island 3760'3554' ENI Petroleum Danielle Dawson OA Sands Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: No Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 6 SP12-SE3 L1 9200'11200' North Slope 3554'3347' ENI Petroleum Danielle Dawson OA Sands Andrew Buchanan 7/8/2014 Interpretation: This interval displays a good oil show, but is not associated with any heavy hydrocarbon gases. It is dominated by unconsolidated, fine to very fine grain, subrounded to subangular, well sorted, quartz sand. It is slightly silty in part. There is free oil in the sample with a very faint oil odor, uniform dull orange sample flourescence, an immediate bright blue bursting to streaming flourescence cut, bright greenish yellow residual ring flourescence, and no visible residual ring. Cuttings Analysis: Odor none Fluorescence Cut Fluorescence Residual Cut pl-med straw Color Intensity fnt-dul Color yel Residual Flourescence fnt Amount none Distribution patchy Intensity dull Color Stain Amount 10%Type stmg Amount wh Oil Show Rating Free Oil in Mud bri Color pl straw Color Cut Color yel Intensity 213932 4382 209550 754 1 Hydrocarbon Ratios 9694 Gas Units 1913 Mud Chlorides (mg/L) =60500 426 120 306 1776 304 26 278 1121 218 31 187 685 230 112 118 2 10434 Gas Units 2230 Mud Chlorides (mg/L) =6900 248031 75700 172331 1084 290 131 159 1706 Hydrocarbon Ratios 193 92 101 1026 392 224 168 2825 6900 264850 33160 231690 772 208 147 61 3 353 53 300 1466 201 43 158 788 10623 Gas Units 2434 Mud Chlorides (mg/L) = 4 11195 Gas Units 2192 Mud Chlorides (mg/L) = 418 124 294 1207 225 33 192 6900 241287 46190 195097 916 303 90 213 1790 177 110 67 163 54 109 1043 330 143 187 2912 Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: No Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 153 66 87 137 29 108 962 303 89 214 2367 69000 244601 38696 205905 710 345 55 290 1907 4 12800 Gas Units 2203 Mud Chlorides (mg/L) = 382 0 382 1576 191 0 191 355 0 355 1645 183 0 183 788 11868 Gas Units 2756 Mud Chlorides (mg/L) =72000 301060 70 300990 848 188 30 158 3 Hydrocarbon Ratios 172 7 165 767 354 26 328 1591 72000 256739 5301 251438 892 282 0 282 1524 176 20 156 2 11405 Gas Units 2337 Mud Chlorides (mg/L) = 325 15 310 1554 283 0 283 1637 152 4 148 782 243820 1474 242346 856 1 Hydrocarbon Ratios 11311 Gas Units 2214 Mud Chlorides (mg/L) =72000 wh Oil Show Rating Free Oil in Mud bri Color pl straw Color Cut Color yel Intensity light straw Color brn Intensity dul Color straw Residual Flourescence none-fnt Amount tr Distribution uni Intensity dull Color Stain Amount tr Type stmg Amount Cuttings Analysis: Odor fnt Fluorescence Cut Fluorescence Residual Cut Andrew Buchanan 7/8/2014 Interpretation: This interval displays non-producible hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, fine to very fine grain, subrounded to subangular, well sorted, quartz sand. There is no free oil in the sample, uniform dull yellow sample flourescence, a dull yellow streaming flourescence cut, pale straw to light amber cut, a light amount of amber residual ring, and dull to bright white residual fluorescence ring. Show Report Report # 7 SP12-SE3 L1 11200'13200' Spy Island 3347 3141 ENI Petroleum Danielle Dawson OA Sands Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH SP12-SE3 & SP12-SE3 L1 ENI Petroleum MI Swaco Doyon 15 AK-XX-0901412968 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 7-Jun 160 8.70 150 35 52 20/36/50 6.3 122/87/71/49/19/15 2/-2.0 0/98 AREA:0.20 9.9 20.0 .15/.30 1200 72 Lubricate Rig 8-Jun 600 9.10 113 29 35 28/45/56 5.8 93/64/53/39/18/16 2/-3.0 1/96 0.10 0.20 9.5 21.0 .10/.25 1650 64 Drilling 16" Hole 9-Jun 2800 9.40 93 23 38 25/48/61 5.4 84/61/50/38/19/17 2/-4.0 1/95 0.15 0.25 10.4 22.0 .15/.50 1850 64 BROOH 10-Jun 2883 9.40 64 23 25 19/35/48 5.4 71/48/39/28/16/14 2/-4.0 1/95 0.15 0.20 95.0 20.0 .05/.35 1650 72 POOH w/Casing 11-Jun 2883 9.50 75 65 33 20/41/53 5.4 89/61/49/36/17/15 2/-5.0 1/94 0.15 0.20 9.3 20.0 .05/.35 1500 40 Clean out run 12-Jun 2883 9.40 44 19 15 7/8/8 -53/34/27/20/8/7 ----------Cement Casing 13-Jun 2883 9.40 44 20 13 7/8/8 ------------BOPs Test - P/U Drill pipe 14-Jun 2883 9.40 46 20 14 7/8/8 ------------BOP Test / Picking up BHA #4 15-Jun 3161 9.30 47 11 25 13/16/18 5.9 47/36/31/25/13/11 2/-4.0 2/94 -0.30 0.30 9.7 2.0 .15/1.00 800 52 Drilling 12.25'' Hole 16-Jun 4140 9.30 55 16 31 14/22/27 5.1 63/47/40/31/14/12 2/-4.5 2/94 0.15 0.30 9.6 11.0 .15/1.10 1300 56 Continue Drilling 12.25" Hole 17-Jun 5147 9.30 55 15 29 13/26/34 4.4 59/44/38/30/14/12 2/-4.9 2.75/92.3 0.10 0.20 9.7 14.5 .10/1.10 1600 64 Drilled to Intermediate TD 18-Jun 5207 9.35 59 14 27 16/28/36 4.8 55/41/35/28/13/11 2/-5.0 2.5/92.5 0.10 0.20 9.8 16.0 .10/1.00 1500 60 R/U Tesco Tools 19-Jun 5207 9.40 48 9 16 8/16/28 4.6 34/25/22/17/8/6 2/-5.0 0.0 0.10 0.15 9.0 15.0 .10/1.80 15000 60 RIH w/ casing & pump cement 20-Jun 5207 9.40 50 9 16 8/16/28 4.6 34/25/22/17/8/6 1/-5.0 2.5/92.5 0.10 0.15 9.0 15.0 .10/.80 1500 60 RIH BHA #5 Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Alka POM Excess Lime Elec Stab CaCl2 WPS LGS/HGS ASG Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%ml ppb volts ppb ppm ppb ASG 21-Jun 5768 9.25 46 14 19 8/8/9 4.6 47/33/28/22/8/7 NA/2 6.81 67/33 2.65 3.45 673 28.92 -0.8/6.1 2.8 Drilling 8.75" hole 22-Jun 8024 9.2 41 12 12 7/7/8 4.6 38/26/21/16/7/6 NA/2 7.17 69/31 2.4 3.12 620 29.35 -0.9/6.3 2.8 Drilling 8.75" hole 23-Jun 10565 9.2 43 12 17 8/8/8 4.6 41/29/24/18/8/7 NA/2 7.64 70/30 2.9 3.77 612 36.17 -0.9/6.7 2.8 Drilling 8.75" hole 24-Jun 12062 9.2 42 12 15 7/7/8 4.6 39/27/23/18/8/7 NA/1 8.08 69/31 3.1 4.03 644 32.88 -1.1/7 2.8 Drilling 8.75" hole 25-Jun 14215 9.2 46 12 17 7/7/8 4.4 41/29/23/18/8/7 NA/1 8.29 71/29 3 3.9 640 30.69 -1.5/6.8 2.8 Drilling 8.75" hole 26-Jun 15216 9.2 43 12 18 7/78 4.6 42/30/25/19/8/7 NA/1 8.15 71/29 2.9 3.77 647 26.21 -13.18/65.62 2.8 BROOH 27-Jun 15216 9.2 41 12 13 7/7/7 -37/25/20/16/7/6 NA/-8.28 72/28 2.6 3.38 690 25.58 -12.97/67.15 2.8 BROOH 28-Jun 15216 9.2 40 12 13 7/7/7 -37/25/20/16/7/6 NA/-8.28 72/28 2.6 3.38 670 25.58 -12.97/67.15 2.8 RIH 5.5" Liner 29-Jun 15216 9.2 40 11 12 6/7/7 -34/23/17/13/7/6 NA/-7.99 71/29 2 2.6 665 26.84 -9.43/68.15 2.8 Test backside 30-Jun 15216 9.2 40 11 12 6/7/7 -34/23/17/13/7/6 NA/-7.99 71/29 2.3 2.99 660 26.51 -9.99/68.01 2.8 Orient Whipstock 1-Jul 5032 9.2 41 11 12 6/7/7 4.6 34/23/17/13/7/6 NA/1 7.99 71/29 2.35 3.06 661 26.51 -9.99/68.01 2.8 Orient MWD/Motor 2-Jul 5232 9.2 42 10 14 6/7/7 4.5 34/24/18/14/7/6 NA/2 7.99 71/29 2.00 2.6 650 26.75 -27.78/49.58 3 M/U BHA 3-Jul 6619 9.25 44 14 14 8/8/9 4.2 42/28/23/18/8/7 NA/2 9.54 73/27 2.20 2.86 712 28.29 -79.85/7.46 2.6 Drilling 8.75" hole 4-Jul 9548 9.25 44 12 17 7/8/8 4.2 41/29/24/18/8/7 NA/2 9.1 72/28 2.10 2.73 677 29.8 -44.87/36.48 3 Drilling 8.75" hole 5-Jul 12208 9.30 44 12 18 8/8/9 4.0 42/30/24/18/8/7 NA/2 8.5 71/29 2.30 2.99 746 30.7 -47.37/32.33 3 Drilling 8.75" hole 6-Jul 14684 9.30 44 11 20 8/8/9 4.0 42/31/24/18/8/7 NA/1 9.1 73/27 2.10 2.73 743 31.0 -51.75/33.64 3 DrIlling 8.75" hole 7-Jul 15245 9.30 44 12 19 8/8/9 4.0 42/31/24/18/8/7 NA/2 8.7 72/28 2.60 2.89 789 30.0 -45.45/25.65 3 Reach TD 15245' 8-Jul 15245 9.30 43 12 16 8/9/9 4.1 40/28/24/18/8/7 1/32"8.7 70/30 2.60 3.38 902 31.9 -31.95/42.74 2.6 BROOH 9-Jul 15245 9.30 43 11 17 8/8/9 3.1 39/28/22/17/8/7 1/32"8.6 73/27 2.40 3.12 874 34.3 -77.88/0.05 2.6 Retrieve Whipstock 10-Jul 15245 9.25 43 11 16 8/8/9 3.8 38/27/22/17/8/7 1/32"8.7 73/27 2.30 2.99 847 33.7 -78.77/0.09 2.6 Retrieve/Fish for Whipstock 11-Jul 15245 9.25 43 11 18 8/8/8 -40/29/23/17/8/7 -8.1 73/28 2.30 2.99 780 33.5 -73.98/0 2.6 L/D Cleanout BHA 12-Jul 15245 9.25 43 12 15 8/8/9 -39/27/22/18/8/7 -8.2 72/28 2.20 2.60 772 33.3 -74.45/0 2.6 RIH 5.5" Liner Casing Record 20" Conductor @ 160' MD, 160'TVD 13.375" Casing @ 2878' MD, 2463'TVD 9.625" Casing @ 5193' MD, 3979'TVD 9.625 Casing Window@ TOW: 4992' MD, 3943'TVD; BOW: 5009' MD, 3947' TVD WELL NAME:LOCATION:Spy Island OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:8-Jun-2014 SPERRY JOB:TD:7-Jul-2014 Remarks W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 2 100 1 Hughes Milltooth MX-1 16.00 160 2883 2723 17.60 1.117 155.1 20 40 1700 800 1-1-WT-A-E-I-NO-TD Surface TD 3 200 1RR Smith GF15B Insert 12.25 2883 2883 0 13.00 1.117 -----2-7-BT-G-E-5-WT-BHA Cleanout 4 300 2 Smith GF15B Insert 12.25 2883 5207 2324 34.30 1.117 67.8 25 40 1350 750 1-3-BT-G-E-1-WT-TD Intermediate TD 5 400 3 Hycalog SKH616M-E1D PDC 8.75 5207 15216 10009 82.30 0.902 121.7 15 160 2450 550 1-1-CT-A-X-IN-NO-TD Production TD 6 500 4 Baker 8.5" OD Window Mill 8.75 4992 5032 40 --------Mill Window 7 600 4RR Smith XR+CPS Milltooth 8.75 5032 5232 200 2.60 0.746 77.8 18 40 1400 450 1-1-WT-A-E-1-No-BHA Kick off whipstock 8 700 5 Hycalog SKH616M-E1D PDC 8.75 5232 ----------Production section, Ecoscope failure 9 700 5RR Hycalog SKH616M-E1D PDC 8.75 5232 15245 10013 157.5 0.902 179.1 15 160 2600 550 1-2-BT-A-X-In-CT-TD Production TD WELL NAME:SP12-SE3 & SP12-SE3 L1 LOCATION:Spy Island OPERATOR:ENI Petroleum AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0901412968 TD:7-Jul-2014 MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:8-Jun-2014 B i t R e c o r d . . * 24 hr Recap:Waiting power to finish rigging up Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 0 6-Jun-2014 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: ConditionBit #Size 2731' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) WOB EVEMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Hydril 563 Type 120' Depth in / out YP (lb/100ft2) 000 00 Intermediate CementCht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Rig Move/Rig up PV Footage B. Perry/R. Wimmer ShClyst TuffGvlCoal cP 40.0 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 120' 120' 0' Max @ ft Current Date: Time: No gas to report over the last 24 hours. in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth L-80 Oil / Water Alkal 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Jane Grundin / Doug Acker Set AtSize 178.9 X-65 Grade L-804949' 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap:N/U diverter stack and test. N/U diverter and test. R/U secondary kill line, kill SI11 w/200bbls 9.6ppg brine, perfrom Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 20.00 0 7-Jun-2014 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: ConditionBit # 2.08.708.70 Size HWDP/Jars/NMFDC and rack back. Load rig floor w/BHA tools. 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) WOB EVEMAR Avg Min Comments Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type Spud Mud 6.3120'52 Depth in / out YP (lb/100ft2) 0.20 000 00 Intermediate CementCht Silt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Rig Move/Rig up PV Footage B. Perry/R. Wimmer ShClyst TuffGvlCoal cP 35 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 120' 120' 0' Max @ ft Current Date: Time: No gas to report over the last 24 hours. in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth /98150 Oil / Water Alkal 0 0 0 Siltst Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Jane Grundin / Doug Acker Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) 0 0 Cly 0 . . * 24 hr Recap: (max)(current) 0 0 Cly 4024 Set AtSize 178.9 X-65 Grade 20.00'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Jane Grundin / Doug Acker 985 0 654 132 Units* Casing Summary Lithology (%) 0 Oil / Water 1059' Alkal 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth /98150 C-5n 1023' 63.0 C-2 37 in 1 130'Minimum Depth Time: 9 The maximum gas was 37 units at 1023’ MD and the average gas was 9 units. 120' 1059' 939' Max @ ft Current 930'265.0 Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 278.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Perry/R. Wimmer ShClyst TuffGvlCoal cP 35 Footage Ss Ratio C-1 C-5i AK-AM-0901412968 Drilling ahead PV 24 hr Max Weight 0 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 0.20 000 Spud Mud 6.3120'52 Depth in / out Mud Type Lst Type Average 16Background (max) Trip 9.609.80 Avg Min Comments Mud RPM ECD (ppg) ml/30min Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 160' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 f/160' t/360' Drill f/360' t/392', Pump out of hole, M/U remaining BHA #2, wash down t/392'. Drill f/392' t/1059'. 160' ConditionBit # 1 2.0 16 8.70 Hughes MX-1 Mill Tooth 8.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 9.90 DOYON15 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 8-Jun-2014 12:00 AM Current Pump & Flow Data: 901 Max 0 Lime (lb/bbl) 20.00 Install skirt around stack, prep handling equip for BHA. P/U BHA #1. Pre spud meeting, flood conductor, test surface Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drilled from 1059' to 2883', Monitor well (static), BROOH f/2883' t/2783' @850gpm. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 22.00 0 9-Jun-2014 12:00 AM Current Pump & Flow Data: 1576 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.00 DOYON15 Report For: ConditionBit # 1 4.0 16 9.50 Hughes MX-1 Mill Tooth 9.40 Size The maximum gas was 752 units at 1962’ MD and the average gas was 119 units. 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 160' WOB EVEMAR 9.809.90 Avg Min Comments Mud RPM ECD (ppg) ml/30min 23Background (max) Trip Average Mud Type Lst Type Spud Mud 5.4120'38 Depth in / out YP (lb/100ft2) 0.25 000 00 CementCht Silt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Drilling ahead PV Footage B. Perry/R. Wimmer ShClyst TuffGvlCoal cP 23 Gas Summary 0 0 0 (current) Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 348.0 Flow In (gpm) Flow In (spm) 1059' 2883' 1824' Max @ ft Current 2480'177.0 Date: Time: 119 in 4 1059'Minimum Depth C-5n 1962' 0.0 C-2 752 SPP (psi) Gallons/stroke TFABit Type Depth 1/9593 Oil / Water 2883' Alkal 1.117 0 0 0 Siltst 852 172 Units* Casing Summary Lithology (%) 011895 403 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Jane Grundin / Doug Acker Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) 0 0 Cly 73133 . . * 24 hr Recap: (max)(current) 0 0 Cly 79505 Set AtSize 178.9 X-65 Grade 20.00'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Jane Grundin / Doug Acker 5168 0 Units* Casing Summary Lithology (%) 0 Oil / Water 2883' Alkal 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1/9564 C-5n 1952' C-2 798 in Minimum Depth Time: 52 The maximum wiper gas 798 units 2883' 2883' 0' Max @ ft Current Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Perry/O. Amend ShClyst TuffGvlCoal cP 23 2723' Footage 17.60 Ss Ratio C-1 C-5i AK-AM-0901412968 Pulling Casing PV 24 hr Max W eight 0 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 0.20 000 40 Spud Mud 5.4120'25 Depth in / out Mud Type Lst Type Average 79823Background (max) Trip 9.809.90 Avg Min Comments Mud RPM ECD (ppg) ml/30min Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 20160' 2883' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 650psi w/no returns (shoe plugged). Attempt to free @3000psi, no returns. Rotate out of hole f/1760' t/1485' observed slack off weight fall f/140k t/90-100k. Pull back t/1760', would not go past 1780'. Attempt to break circ, pressure up to 160' Condition 1-1-WT-A-E-I-NO-TD Bit # 1 4.0 16 9.40 Hughes MX-1 Mill Tooth 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.00 DOYON15 Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 10-Jun-2014 12:00 AM Current Pump & Flow Data: Max 0 Chlorides (mg/L) 1650 BROOH as per K&M f/2783' t/406'. POOH f/406' t/123', stand back 2 std HWDP & NMFC, B/D Top drive. L/D BHA #2 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 0 0 Cly 13548 Set AtSize 178.9 X-65 Grade 20.00'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Jane Grundin / Doug Acker 864 0 Units* Casing Summary Lithology (%) 0 Oil / Water 2883' Alkal 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1/9575 C-5n 2883' C-2 133 in Minimum Depth Time: 8 The maximum Trip Gas 133 units 2883' 2883' 0' Max @ ft Current Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Perry/O. Amend ShClyst TuffGvlCoal cP 28 2723' Footage 17.60 Ss Ratio C-1 C-5i AK-AM-0901412968 Clean out run PV 24 hr Max W eight 0 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 0.20 000 40 Spud Mud 5.4120'33 Depth in / out Mud Type Lst Type Average 1335Background (max) Trip 9.809.90 Avg Min Comments Mud RPM ECD (ppg) ml/30min Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 20160' 2883' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 as per K&M cycle, P/U & M/U BHA #3 t/576'MD. TIH f/576' t/2817'MD. @2817' break circ, wash down and tag btm @2883'. BROOH f/2883' t/1275' 160' Condition 1-1-WT-A-E-I-NO-TD Bit # 1 5.0 16 9.50 Hughes MX-1 Mill Tooth 9.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.00 DOYON15 Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 11-Jun-2014 12:00 AM Current Pump & Flow Data: Max 0 Chlorides (mg/L) 1500 POOH f/1485' t/82' w/13-3/8" casing, L/D in pipe shed. Drain shoe track and cut all connections, L/D same. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:BROOH as per K&M f/1276' t/297'. L/D BHA #3 . B/D Top Drive, clean/clear rig floor. R/U t/run CSG as per GBR. RIH Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (mg/L) 0 12-Jun-2014 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.00 DOYON15 Report For: Condition 1-1-WT-A-E-I-NO-TD Bit # 1 16Hughes MX-1 Mill Tooth 9.40 Size returns. B/D, R/D all equip, R/D csg equip pump 103bbls mud push, 469bbls lead slurry, 65bbls tail slurry, chase with Spud mud, bump plug @405bbls, 75bbls cement jt/hanger, land @2877'. Circ. & condition mud for cementing, weight up mud push. Pump cement as per plan, PT cement line, 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 20160' 2883' WOB EVEMAR 9.809.90 Avg Min Comments Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type 40 Spud Mud120'15 Depth in / out YP (lb/100ft2) 000 00 CementCht Silt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Clean pits PV 2723' Footage 17.60 B. Perry/O. Amend ShClyst TuffGvlCoal cP 19 Gas Summary 0 0 0 (current) Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2883' 2883' 0' Max @ ft Current Date: Time: No Gas was Observed over the last 24 hrs in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 44 Oil / Water 2883' Alkal 1.117 0 0 0 Siltst Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Kori Jo Plowman / Doug Acker Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) 0 0 Cly 0 . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize 178.9 X-65 Grade 20.00'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Kori Jo Plowman / Doug Acker 0 0 Units* Casing Summary Lithology (%) 0 Oil / Water 2883' Alkal 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 44 C-5nC-2 No Gas was Observed over the last 24 hrs in Minimum Depth Time: 2883' 2883' 0' Max @ ft Current Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Perry/O. Amend ShClyst TuffGvlCoal cP 20 2723' Footage 17.60 Ss Ratio C-1 C-5i AK-AM-0901412968 P/U Pipe PV 24 hr Max W eight 0 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 000 40 Spud Mud120'13 Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments Mud RPM ECD (ppg) ml/30min Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 20160' 2883' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 load/process 5" drill pipe in shed. Lubricate rig. Cont. to load/process 5" drill pipe. M/U stands and rack back. 160' Condition 1-1-WT-A-E-I-NO-TD Bit # 1 16Hughes MX-1 Mill Tooth 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 13-Jun-2014 12:00 AM Current Pump & Flow Data: Max 0 Chlorides (mg/L) N/D surface stack. N/U BOPE, prep surface hanger, N/U wellhead test connections t/2000psi, N/U hi-psi riser. N/U Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:M/U stands of 5" DP and rack back in derrick, 408jts picked up. R/U begin testing BOPE. C/O upper seals on pipe Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (mg/L) 0 14-Jun-2014 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 9 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-I-NO-TD Bit # 1 16Hughes MX-1 Mill Tooth 9.40 Size No Gas was Observed over the last 24 hrs wear bushing. B/D & R/D test equip. R/U & test 13-3/8" casing t/2500psi, R/D test equip. P/U & M/U BHA #4. 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 20160' 2883' WOB EVEMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type 40 Spud Mud120'14 Depth in / out YP (lb/100ft2) 000 00 CementCht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 P/U BHA #4 PV 2723' Footage 17.60 B. Perry/O. Amend ShClyst TuffGvlCoal cP 20 Gas Summary 0 0 0 (current) Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2883' 2883' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 46 L-80 Oil / Water 2883' Alkal 1.117 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Kori Jo Plowman / Doug Acker Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 5263 Set AtSize 178.9 X-65 Grade 20.00'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Kori Jo Plowman / Doug Acker 2338 0 13.38'' 747 150 Units* Casing Summary Lithology (%) 0 L-80 Oil / Water 3268' Alkal 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 47 C-5n 3268' 178.0 C-2 52 in 0 2955'Minimum Depth Time: 23 2883' 3268' 385' Max @ ft Current 3193'97.9 Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 374.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Perry/O. Amend ShClyst TuffGvlCoal cP 11 2723' 12.25 1.117 Footage 17.60 Ss Ratio C-1 C-5i AK-AM-0901412968 Drilling Ahead PV 24 hr Max 68.0 Weight 0 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 0.30 000 40 Smith GF15B Insert Spud Mud 5.9 2883' 120'25 Depth in / out Mud Type Lst 100 Type Average 12Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 20160' 2883' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 2 The maximum gas was 52 units at 3268’ MD and the average gas was 23 units Drill f/2905' t/3268'. inspect brakes. CBU for FIT test, recip. f/2814' t/2721'. R/U & perfrom LOT, LOT 10.6ppg EMW. Break circ.& wash/ream f/2814' t/2905'. Drill f/2905' t/3247', 2815' TVD. 2878' 160' Condition 1-1-WT-A-E-I-NO-TD Bit # 1 4.0 16 9.35 Hughes MX-1 Mill Tooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 10 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 15-Jun-2014 12:00 AM Current Pump & Flow Data: 1019 Max 0 Chlorides (mg/L) 800 P/U BHA #4 as per SLB. RIH f/655' t/2534, SHT @1500'. Wash/Ream f/2534' t/2795', drill out float equip. shoe track Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Conitue to drill from 3268' MD to 4215' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (mg/L) 1300 0 16-Jun-2014 12:00 AM Current Pump & Flow Data: 1154 Max Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 9.60 DOYON15 Report For: Condition 1-1-WT-A-E-I-NO-TD Bit # 1 4.5 16 9.35 Hughes MX-1 Mill Tooth 9.30 Size 2 The maximum gas was 22 units at 3980’ MD and the average gas was 12 units 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 20160' 2883' WOB EVEMAR 9.409.50 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 5Background (max) Trip Average Mud Type Lst 85 Type 40 Smith GF15B Insert Spud Mud 5.1 2883' 120'31 Depth in / out YP (lb/100ft2) 0.30 000 00 CementCht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Drilling Ahead PV 2723' 12.25 1.117 Footage 17.60 B. Perry/O. Amend ShClyst TuffGvlCoal cP 16 Gas Summary 0 0 0 (current) Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 306.0 Flow In (gpm) Flow In (spm) 3268' 4215' 947' Max @ ft Current 3306'117.0 Date: Time: 12 in 0 2883'Minimum Depth C-5n 3980' 16.0 C-2 22 SPP (psi) Gallons/stroke TFABit Type Depth 2/9455 L-80 Oil / Water 4201' Alkal 1.117 0 0 0 Siltst 13.38'' 744 150 Units* Casing Summary Lithology (%) 0 15 1286 0 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Kori Jo Plowman / Doug Acker Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 0 0 Cly 2278 . . * 24 hr Recap: (max)(current) BTC 115 0 Cly 120937 Set AtSize 178.9 X-65 Grade 20.00'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Kori Jo Plowman / Doug Acker 8324 655 13.38'' 848 170 Units* Casing Summary Lithology (%) 0 L-80 Oil / Water 5206' Alkal 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.75/92.355 C-5n 4806' 0.0 C-2 988 in 6 4380'Minimum Depth Time: 83 4215' 5207' 992' Max @ ft Current 4308'98.7 Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 385.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Perry/O. Amend ShClyst TuffGvlCoal cP 15 2723' 12.25 1.117 Footage 17.60 Ss Ratio C-1 C-5i AK-AM-0901412968 TD Intermediate PV 24 hr Max 68.0 Weight 9 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 0.20 000 40 Smith GF15B Insert Spud Mud 4.4 2883' 120'29 Depth in / out Mud Type Lst 100 Type Average 12Background (max) Trip 9.9010.00 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 20160' 2883' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 12 2 The maximum gas was 988 units at 4806’ MD and the average gas was 83 units 2878' 160' Condition 1-1-WT-A-E-I-NO-TD Bit # 1 5.0 16 9.35 Hughes MX-1 Mill Tooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.10 DOYON15 Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 17-Jun-2014 12:00 AM Current Pump & Flow Data: 1594 Max 1 Chlorides (mg/L) 1600 Conitue to drill 12.25 '' hole; TD intermediate section at 5207' MD. Circulating and backreaming out of hole. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Circulate bottomes up two times. Rack stds back f/5165' to 5056'. BROOH at 850 gpm 1400 psi & 80 rpm to 2878'. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (mg/L) 1500 0 18-Jun-2014 12:00 AM Current Pump & Flow Data: Max 1-3-BT-G-E-1-WT-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-I-NO-TD Bit # 1 5.0 16 9.35 Hughes MX-1 Mill Tooth 9.35 Size 2 The maximum gas was 190 units Monitor well. 10 min. Static. POH to 2160'. Pump 25 bbl 11.4 lb/gal dry job. POH. L/D BHA #4. 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 25 20160' 2883' WOB EVEMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 9Background (max) Trip Average Mud Type Lst 100 Type 40 40 Smith GF15B Insert Spud Mud 4.8 2883' 120'27 5207' Depth in / out YP (lb/100ft2) 0.20 000 00 CementCht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Run Casing PV 2723' 12.25 1.117 Footage 34.30 2324' 17.60 J. Keener/O. Amend ShClyst TuffGvlCoal cP 14 Gas Summary 0 0 0 (current) Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 5207' 5207' 0' Max @ ft Current Date: Time: 13 in 0Minimum Depth C-5n 0.0 C-2 190 SPP (psi) Gallons/stroke TFABit Type Depth 2.5/92.559 L-80 Oil / Water 5207' Alkal 1.117 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 01328 0 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Kori Jo Plowman / Doug Acker Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 0 0 Cly 19026 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 17286 Set AtSize 178.9 X-65 Grade 20.00'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Kori Jo Plowman / Doug Acker 0 0 13.38'' Units* Casing Summary Lithology (%) 0 L-80 Oil / Water 5207' Alkal 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3/9348 C-5nC-2 172 in 0Minimum Depth Time: 5207' 5207' 0' Max @ ft Current Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J. Keener/O. Amend ShClyst TuffGvlCoal cP 9 2723' 12.25 1.117 Footage 34.30 2324' 17.60 Ss Ratio C-1 C-5i AK-AM-0901412968 Cement Job PV 24 hr Max 68.0 Weight 0 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 0.15 000 40 40 Smith GF15B Insert Spud Mud 4.6 2883' 120'16 5207' Depth in / out Mud Type Lst 100 Type Average 1729Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools TeleScope 825,ARC 825,GyroPulse Collar API FL Chromatograph (ppm) 25 20160' 2883' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 2 The maximum gas was 172 units 2878' 160' Condition 1-1-WT-A-E-I-NO-TD Bit # 1 5.0 16 9.40 Hughes MX-1 Mill Tooth 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 14 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-3-BT-G-E-1-WT-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 19-Jun-2014 12:00 AM Current Pump & Flow Data: Max 0 Chlorides (mg/L) 1500 Float 9 5/8" csg to 126'. Test floats. OK. RIH csg f/126' to 5192' MD. Calc disp observed. R/D Tesco equip. R/U cmt Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:N/D BOP. Set e-slips & cut 9 5/8" csg. N/U BOP & test BOP. Test 9 5/8" csg to 3000 psi for 30 min. P/U BHA #5. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides (mg/L) 1500 0 20-Jun-2014 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-3-BT-G-E-1-WT-TD Bit # 2 5.0 12.25Smith GF15B Insert 9.40 Size 3 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed675, PeriScope675, TeleScope675, EcoScope675 API FL Chromatograph (ppm) 252883' 5207' WOB EVEMAR Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type 40 Hycalog SKH616M-E1D PDC LSND 4.6 5207' 5207'16 Depth in / out YP (lb/100ft2) 9.00 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901412968 RIH BHA #5 PV 2324' 8.75"0.902 Footage 34.30 J. Keener/O. Amend ShClyst TuffGvlCoal cP 9 40.0 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 5207' 5207' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 1550 L-80 MBT 5207' pH 1.117 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 0 0 Cly . . * 24 hr Recap: (max)(current) BTC 264 0 Cly 268387 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 24 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 129586 14 13.38'' 601 120 Units* Casing Summary Lithology (%) 33 L-80 Oil/Water 6203' Alkal 1.117 0 105 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 67/3346 C-5n 5867' 126.0 C-2 2341 in 0 5207'Minimum Depth Time: new hole. Drill ahead to 6203' MD. Samples were mostly sltst f/ 5207' MD to 5500' MD & clean sst f/ 5500' MD to 6200' MD. 942 Max Gas: 2341u Avg Gas: 942u 5207' 6203' 996' Max @ ft Current 5908'241.0 Date: Avg to5207' Yesterday's Depth: Current Depth: 24 Hour Progress: 440.5 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 107 58 (current) J. Keener/O. Amend ShClyst TuffGvlCoal cP 14 2324' 8.75"0.902 Footage 34.30 Ss Ratio C-1 C-5i AK-AM-0901412968 Drilling ahead PV 24 hr Max 68.0 Weight 97 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.65 53016 40 Hycalog SKH616M-E1D PDC FazePro 4.6 5207' 5768'19 Depth in / out Mud Type Lst 100 Hydril S53 Type Average 302Background (max) Trip 9.7511.31 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed675, PeriScope675, TeleScope675, EcoScope675 API FL Chromatograph (ppm) 252883' 5207' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 151 3 2878' 160' Condition 1-3-BT-G-E-1-WT-TD Bit # 2 6.8 12.25Smith GF15B Insert 9.25 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 16 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 21-Jun-2014 12:00 AM Current Pump & Flow Data: 1628 Max 50 Lime (lb/bbl) 3 RIH w/ BHA #5. SHT MWD tools. Continue to RIH. Displace f/ LSND to FazePro. Drilled out shoe then 20' Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill ahead f/ 6203' MD to midnight depth of 8296' MD. Samples consisted of clean sst. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 3 178 22-Jun-2014 12:00 AM Current Pump & Flow Data: 1722 Max Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 17 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.73 DOYON15 Report For: Condition 1-3-BT-G-E-1-WT-TD Bit # 2 7.2 12.25Smith GF15B Insert 9.20 Size 3 2878' 160' 100% Gas In Air=10,000 UnitsConnection 298 Tools Xceed675, PeriScope675, TeleScope675, EcoScope675 API FL Chromatograph (ppm) 252883' 5207' WOB EVEMAR 9.9910.36 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 96Background (max) Trip Average Mud Type Lst 100 Hydril S53 Type 40 Hycalog SKH616M-E1D PDC FazePro N/A 5207' 8024'14 Depth in / out YP (lb/100ft2) 2.40 50170104 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 215 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Drilling ahead PV 2324' 8.75"0.902 Footage 34.30 J. Keener/O. Amend ShClyst TuffGvlCoal cP 12 40.0 Gas Summary 0 259 140 (current) Avg to5207' Yesterday's Depth: Current Depth: 24 Hour Progress: 569.8 Flow In (gpm) Flow In (spm) 6203' 8296' 2093' Max @ ft Current 6376'272.8 Date: Time: 1002 Max Gas: 2272u Avg Gas: 1002u in 10 6471'Minimum Depth C-5n 6405' 27.0 C-2 2272 SPP (psi) Gallons/stroke TFABit Type Depth 69/3141 L-80 Oil/Water 8296' Alkal 1.117 0 235 0 Siltst 13.38'' 591 139 Units* Casing Summary Lithology (%) 155128207 67 907-685-0772Unit Phone: 62 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 394 0 Cly 256058 . . * 24 hr Recap: (max)(current) BTC 380 0 Cly 286845 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 82 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 104543 155 13.38'' 552 120 Units* Casing Summary Lithology (%) 124 L-80 Oil/Water 10803' Alkal 1.117 0 248 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 70/3043 C-5n 8837' 165.0 C-2 2651 in 16 8391'Minimum Depth Time: 1291 Max Gas: 2651u Avg Gas: 12910u 8296' 10803' 2507' Max @ ft Current 9645'290.7 Date: Avg to5207' Yesterday's Depth: Current Depth: 24 Hour Progress: 465.6 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 280 170 (current) J. Keener/O. Amend ShClyst TuffGvlCoal cP 12 2324' 8.75"0.902 Footage 34.30 Ss Ratio C-1 C-5i AK-AM-0901412968 Drilling ahead PV 24 hr Max 68.0 Weight 158 Hours C-3 04 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.90 54142107 40 Hycalog SKH616M-E1D PDC FazePro NA 5207' 10565'17 Depth in / out Mud Type Lst 100 Hydril S53 Type Average 33Background (max) Trip 10.1212.20 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed675, PeriScope675, TeleScope675, EcoScope675 API FL Chromatograph (ppm) 252883' 5207' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 289 3 2878' 160' Condition 1-3-BT-G-E-1-WT-TD Bit # 2 7.6 12.25Smith GF15B Insert 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 18 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 23-Jun-2014 12:00 AM Current Pump & Flow Data: 2036 Max 122 Lime (lb/bbl) 4 Drill ahead f/ 8296' MD to midnight depth of 10803' MD. Samples consisted of clean sst. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill ahead f/ 10803' MD to midnight depth of 12110' MD. Samples consisted of clean sst. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 4 67 24-Jun-2014 12:00 AM Current Pump & Flow Data: 1964 Max Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 19 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-3-BT-G-E-1-WT-TD Bit # 2 8.1 12.25Smith GF15B Insert 9.20 Size 3 2878' 160' 100% Gas In Air=10,000 UnitsConnection 173 Tools Xceed675, PeriScope675, TeleScope675, EcoScope675 API FL Chromatograph (ppm) 252883' 5207' WOB EVEMAR 9.8410.93 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 72Background (max) Trip Average Mud Type Lst 100 Hydril S53 Type 40 Hycalog SKH616M-E1D PDC FazePro NA 5207' 15 Depth in / out YP (lb/100ft2) 3.10 297559 65 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 135 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Drilling ahead PV 2324' 8.75"0.902 Footage 34.30 J. Keener/R. Wimmer ShClyst TuffGvlCoal cP 12 40.0 Gas Summary 8 173 116 (current) Avg to5207' Yesterday's Depth: Current Depth: 24 Hour Progress: 605.8 Flow In (gpm) Flow In (spm) 10803' 12110' 1307' Max @ ft Current 11725'268.2 Date: Time: 1094 Max Gas: 2964u Avg Gas: 1094u in 16 11012'Minimum Depth C-5n 11751' 2.3 C-2 2964 SPP (psi) Gallons/stroke TFABit Type Depth 69/3142 L-80 Oil/Water 12110' Alkal 1.117 0 169 0 Siltst 13.38'' 541 118 Units* Casing Summary Lithology (%) 71129763 94 907-685-0772Unit Phone: 53 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 338 0 Cly 321304 . . * 24 hr Recap: (max)(current) BTC 453 22 Cly 350884 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 43 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 153715 5020 13.38'' 551 120 Units* Casing Summary Lithology (%) 116 L-80 Oil/Water 14306' Alkal 1.117 12 187 17 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 71/2946 C-5n 13824' 0.0 C-2 3420 in 18 12271'Minimum Depth Time: 1513 Max Gas: 3420u Avg Gas: 1513u 12110' 14306' 2196' Max @ ft Current 14125'290.5 Date: Avg to5207' Yesterday's Depth: Current Depth: 24 Hour Progress: 572.4 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 25 180 104 (current) J. Keener/R. Wimmer ShClyst TuffGvlCoal cP 12 2324' 8.75"0.902 Footage 34.30 Ss Ratio C-1 C-5i AK-AM-0901412968 Drilling ahead PV 24 hr Max 68.0 Weight 240 Hours C-3 1423 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 3.00 3711578 40 Hycalog SKH616M-E1D PDC FazePro NA 5207' 14215'17 Depth in / out Mud Type Lst 100 Hydril S53 Type Average 112Background (max) Trip 10.0212.00 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed675, PeriScope675, TeleScope675, EcoScope675 API FL Chromatograph (ppm) 252883' 5207' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 182 3 2878' 160' Condition 1-3-BT-G-E-1-WT-TD Bit # 2 8.3 12.25Smith GF15B Insert 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 20 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 25-Jun-2014 12:00 AM Current Pump & Flow Data: 2263 Max 94 Lime (lb/bbl) 4 Drill ahead f/ 12110' MD to midnight depth of 114306' MD. Samples consisted of clean sst. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill ahead f/ 14306' MD to production section of 15216' MD. BROOH. Samples consisted of clean sst. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 3.77 78 26-Jun-2014 12:00 AM Current Pump & Flow Data: 2201 Max Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 21 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-3-BT-G-E-1-WT-TD Bit # 2 8.2 12.25Smith GF15B Insert 9.20 Size 3 2878' 160' 100% Gas In Air=10,000 UnitsConnection 145 Tools Xceed675, PeriScope675, TeleScope675, EcoScope675 API FL Chromatograph (ppm) 252883' 5207' WOB EVEMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 94Background (max) Trip Average 104 Mud Type Lst 100 Hydril S53 Type 40 Hycalog SKH616M-E1D PDC FazePro NA 5207' 15216'18 Depth in / out YP (lb/100ft2) 2.90 227849 1413 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 259 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 BROOH PV 2324' 8.75"0.902 Footage 34.30 J. Keener/R. Wimmer ShClyst TuffGvlCoal cP 12 40.0 Gas Summary 23 132 76 (current) Avg to5207' Yesterday's Depth: Current Depth: 24 Hour Progress: 447.7 Flow In (gpm) Flow In (spm) 14306' 15216' 910' Max @ ft Current 14777'278.5 Date: Time: 1458 Max Gas: 3166u Avg Gas: 1458u in 18 14325'Minimum Depth C-5n 14946' C-2 3166 SPP (psi) Gallons/stroke TFABit Type Depth 71/2943 L-80 Oil/Water 15216' Alkal 1.117 0 147 6 Siltst 13.38'' 546 110 Units* Casing Summary Lithology (%) 86166286 226 907-685-0772Unit Phone: 31 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 429 0 Cly 331764 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 0 0 13.38'' 546 110 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water 15216' Alkal 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 72/2841 C-5nC-2 in Minimum Depth Time: Max Gas: 17u 15216' 15216' 0' Max @ ft Current Date: Avg to5207' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) J. Keener/R. Wimmer ShClyst TuffGvlCoal cP 12 2324' 8.75"0.902 Footage 34.30 Ss Ratio C-1 C-5i AK-AM-0901412968 BROOH PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.60 000 40 Hycalog SKH616M-E1D PDC FazePro NA 5207' 15216'13 Depth in / out Mud Type Lst Hydril S53 Type Average 17Background (max)Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed675, PeriScope675, TeleScope675, EcoScope675 API FL Chromatograph (ppm) 252883' 5207' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 3 2878' 160' Condition 1-3-BT-G-E-1-WT-TD Bit # 2 8.3 12.25Smith GF15B Insert 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 22 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 27-Jun-2014 12:00 AM Current Pump & Flow Data: 1434 Max 0 Lime (lb/bbl) 3.38 Cont to BROOH. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Cont to BROOH. L/D BHA #5. R/U liner equip & RIH w/ 5.5" liner. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 3.38 0 28-Jun-2014 12:00 AM Current Pump & Flow Data: Max 1-1-CT-A-X-IN-NO-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 23 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-3-BT-G-E-1-WT-TD Bit # 2 8.3 12.25Smith GF15B Insert 9.20 Size 3 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 15 252883' 5207' WOB EVEMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max) Trip Average 7 Mud Type Lst Hydril S53 Type 160 40 Hycalog SKH616M-E1D PDC FazePro NA 5207' 15216'13 15216' Depth in / out YP (lb/100ft2) 2.60 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 RIH 5.5" Liner PV 2324' 8.75"0.902 Footage 82.30 10009' 34.30 J. Keener/R. Wimmer ShClyst TuffGvlCoal cP 12 40.0 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 15216' 15216' 0' Max @ ft Current Date: Time: Max Gas: 7u in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 72/2840 L-80 Oil/Water Alkal 1.117 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap:Run 5.5" liner from 2722' MD to 10112' MD. Pick up power tongs, M/U seal assembly, set slim pulse in collar. M/U Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.60 0 29-Jun-2014 12:00 AM Current Pump & Flow Data: Max 1-1-CT-A-X-IN-NO-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 24 Customer: Well: Area: Location: Rig: SP12-SE3 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-3-BT-G-E-1-WT-TD Bit # 2 8.0 12.25Smith GF15B Insert 9.20 Size 3 Set hanger and test.OK 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 15 252883' 5207' WOB EVEMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Hydril 563 Type 160 40 Hycalog SKH616M-E1D PDC FazePro NA 5207' 15216'12 15216' Depth in / out YP (lb/100ft2) 2.00 000 00 Intermediate CementCht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Test Backside PV 2324' 8.75" 0.902 Footage 82.30 10009' 34.30 J. Keener/R. Wimmer ShClyst TuffGvlCoal cP 11 40.0 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 15216' 15216' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 71/2940 L-80 Oil/Water Alkal 1.117 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap:Unsting f/ TOL. POOH 3 stnds. Cut & slip. POOH & L/D running tool. P/U Whipstock BHA & RIH to 4922' MD. Orient Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.99 0 30-Jun-2014 12:00 AM Current Pump & Flow Data: Max 1-1-CT-A-X-IN-NO-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 25 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-3-BT-G-E-1-WT-TD Bit # 2 8.0 12.25Smith GF15B Insert 9.20 Size 3 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 15 252883' 5207' WOB EVEMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Hydril 563 Type 160 40 Hycalog SKH616M-E1D PDC FazePro NA 5207' 15216'12 15216' Depth in / out YP (lb/100ft2) 2.30 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 RIH w/ Whipstock PV 2324' 8.75"0.902 Footage 82.30 10009' 34.30 J. Keener/R. Wimmer ShClyst TuffGvlCoal cP 11 40.0 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 15216' 15216' 0' Max @ ft Current Date: Time: whipstock to 5064' MD & set. in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 71/2940 L-80 Oil/Water Alkal 1.117 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 965 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 681 42 13.38'' 447 90 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water 5031' Alkal 0.902 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 71/2941 C-5n 5019' C-2 18 in 10 4998'Minimum Depth Time: milling BHA. Service rig. P/U BHA #7 & RIH. Perform FIT to 13.0ppg. Orient MWD/Motor. 14 5009' 5031' 22' Max @ ft Current 5015'18.3 Date: Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: 27.6 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) M. Ross/R. Wimmer ShClyst TuffGvlCoal cP 11 10009' 8.75"0.746 Footage 82.30 Ss Ratio C-1 C-5i AK-AM-0901412968 Orient MWD/Motor PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.35 000 160 Smith XR+CPS Mill Tooth FazePro NA 5031' 5032'12 Depth in / out Mud Type Lst Hydril 563 Type Average 5Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools SP Motor, TeleScope 675 API FL Chromatograph (ppm) 155207' 15216' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 4RR 2878' 160' Condition 1-1-CT-A-X-IN-NO-TD Bit # 3 8.0 8.75"Hycalog SKH616M-E1D PDC 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 26 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 1-Jul-2014 12:00 AM Current Pump & Flow Data: 1398 Max 0 Lime (lb/bbl) 3.06 Mill 8.75" window in 9 5/8" csg f/ 4992' MD to 5032' MD. Pump sweep, monitor well & pump dry job. POOH & L/D Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 5540 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 90 2267 580 13.38'' Units* Casing Summary Lithology (%) 0 L-80 Oil/Water 5031' Alkal 0.746 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 71/2942 C-5n 5152' C-2 48 in 2 5031'Minimum Depth Time: 48u & the avg gas was 25u. Samples consisted of 50-90% sltst w/ some sst. 25 Max Gas: 48u Average Gas: 25u 5031' 5232' 201' Max @ ft Current 5106'83.2 Date: Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: 297.4 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) M. Ross/R. Wimmer ShClyst TuffGvlCoal cP 10 200' 8.75"0.902 Footage 2.60 Ss Ratio C-1 C-5i AK-AM-0901412968 RIH w/ BHA #8 PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.00 000 40 Hycalog SKH616M-E1D FazePro NA 5232' 5232'14 Depth in / out Mud Type Lst 10 Hydril 563 Type Average 2415Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 185031' 5232' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 5 2878' 160' Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 8.0 8.75"Smith XR+CPS Mill Tooth 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 27 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 2-Jul-2014 12:00 AM Current Pump & Flow Data: Max 0 Lime (lb/bbl) 2.60 Drill f/ 5031' MD to 5232' MD. CBU x3 & POOH. L/D BHA. R/U & Test BOP. P/U BHA #8 & RIH. The max gas was Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) BTC 376 0 Cly 222128 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 68 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 0 94784 571 13.38'' 546 110 Units* Casing Summary Lithology (%) 109 L-80 Oil/Water 5031' Alkal 0.746 0 240 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 73/2744 C-5n 6887' 54.1 C-2 1954 in 0 5448'Minimum Depth Time: ahead to 7096' MD. Max gas was 1954u. Samples consist of mostly clean sst. 629 Max Gas: 1954u Average Gas: 629u 5232' 7096' 1864' Max @ ft Current 6937'290.9 Date: Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: 550.4 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 268 145 (current) M. Ross/R. Wimmer ShClyst TuffGvlCoal cP 14 200' 8.75"0.902 Footage 2.60 Ss Ratio C-1 C-5i AK-AM-0901412968 Drill 8.75" L1 Hole PV 24 hr Max 68.0 Weight 150 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.20 4013282 40 Hycalog SKH616M-E1D FazePro NA 5232' 6619'14 Depth in / out Mud Type Lst 100 Hydril 563 Type Average 715Background (max) Trip 10.04 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 185031' 5232' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 296 5 2878' 160' Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 9.5 8.75"Smith XR+CPS Mill Tooth 9.25 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 28 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 3-Jul-2014 12:00 AM Current Pump & Flow Data: 1829 Max 123 Lime (lb/bbl) 2.86 RIH w/ BHA. SHT MWD, Ecoscope failure. POOH & C/O Ecoscope. RIH & MADD Pass f/ 5030' MD to 5232' MD. Drill Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill ahead / 7096' MD to 9745' MD. Max gas was 2204u @ 7998' MD. Samples consisted of sst. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.73 170 4-Jul-2014 12:00 AM Current Pump & Flow Data: 1986 Max Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 29 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 9.1 8.75"Smith XR+CPS Mill Tooth 9.25 Size 5 2878' 160' 100% Gas In Air=10,000 UnitsConnection 331 Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 185031' 5232' WOB EVEMAR 10.3411.70 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 66Background (max) Trip Average Mud Type Lst 100 Hydril 563 Type 40 Hycalog SKH616M-E1D FazePro NA 5232' 9548'17 Depth in / out YP (lb/100ft2) 2.10 70199136 03 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 209 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Drill 8.75" L1 Hole PV 200' 8.75"0.902 Footage 2.60 M. Ross/R. Wimmer ShClyst TuffGvlCoal cP 12 40.0 Gas Summary 0 338 203 (current) Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: 520.4 Flow In (gpm) Flow In (spm) 7096' 9745' 2649' Max @ ft Current 7814'290.6 Date: Time: 975 Max Gas: 2204u Average Gas: 975u in 10 7681'Minimum Depth C-5n 7998' 67.6 C-2 2204 SPP (psi) Gallons/stroke TFABit Type Depth 72/2844 L-80 Oil/Water 5031' Alkal 0.746 0 298 0 Siltst 13.38'' 541 109 Units* Casing Summary Lithology (%) 165 0 111973 92 907-685-0772Unit Phone: 99 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 379 0 Cly 245422 . . * 24 hr Recap: (max)(current) BTC 355 0 Cly 301060 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 62 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker 0 136730 182 13.38'' 541 109 Units* Casing Summary Lithology (%) 112 L-80 Oil/Water 5031' Alkal 0.746 0 182 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2 13/2944 C-5n 11868' 289.0 C-2 2756 in 17 11921'Minimum Depth Time: 1183 Max Gas:2756u Average Gas: 1183u 9745' 12387' 2642' Max @ ft Current 11140'294.0 Date: Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: 437.0 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 200 128 (current) M. Ross/R. Wimmer ShClyst TuffGvlCoal cP 12 200' 8.75" 0.902 Footage 2.60 Ss Ratio C-1 C-5i AK-AM-0901412968 Drill 8.75" L1 Hole PV 24 hr Max 68.0 Weight 175 Hours C-3 04 Intermediate CementCht Silt C-4i C-4n YP (lb/100ft2) 2.30 5013199 40 Hycalog SKH616M-E1D FazePro NA 5232' 9548'18 Depth in / out Mud Type Lst 100 Hydril 563 Type Average 248Background (max) Trip 11.1011.20 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 185031' 5232' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 183 5 2878' 160' Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 8.5 8.75" 9.30 Smith XR+CPS Mill Tooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 30 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 5-Jul-2014 12:00 AM Current Pump & Flow Data: 1986 Max 101 Lime (lb/bbl) 2.99 Drill ahead / 9745' MD to 12387' MD. Max gas was 2756u @ 11868' MD. Samples consisted of sst. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill ahead / 12387' MD to 14775' MD. Max gas was 2246u @ 13332' MD. Samples consisted of sst. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.73 92 6-Jul-2014 12:00 AM Current Pump & Flow Data: 2282 Max Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 31 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.40 DOYON15 Report For: Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 9.1 8.75" 9.30 Smith XR+CPS Mill Tooth 9.30 Size 5 2878' 160' 100% Gas In Air=10,000 UnitsConnection 152 Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 185031' 5232' WOB EVEMAR 11.1011.20 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 109Background (max) Trip Average Mud Type Lst 100 Hydril 563 Type 40 Hycalog SKH616M-E1D FazePro NA 5232' 14684'20 Depth in / out YP (lb/100ft2) 2.10 3411477 04 Intermediate CementCht Silt C-4i C-4n 24 hr Max 68.0 Weight 264 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Drill 8.75" L1 Hole PV 200' 8.75" 0.902 Footage 2.60 M. Ross/R. Wimmer ShClyst TuffGvlCoal cP 11 40.0 Gas Summary 0 180 112 (current) Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: 432.0 Flow In (gpm) Flow In (spm) 12387' 14775' 2388' Max @ ft Current 14665'274.0 Date: Time: 1160 Max Gas: 2246u Average Gas: 1160u in 15 7681'Minimum Depth C-5n 13332' 251.0 C-2 2246 SPP (psi) Gallons/stroke TFABit Type Depth 2 19/2744 L-80 Oil/Water 14684' Alkal 0.746 0 167 0 Siltst 13.38'' 500 110 Units* Casing Summary Lithology (%) 109 0 134691 152 907-685-0772Unit Phone: 53 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 394 0 Cly 250903 . . * 24 hr Recap: (max)(current) BTC 399 0 Cly 218740 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 51 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker 0 185003 123 13.38'' 556 111 Units* Casing Summary Lithology (%) 118 L-80 Oil/Water 15245' Alkal 0.746 0 159 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 72 / 2844 C-5n 15109' 0.0 C-2 2063 in 12 14960'Minimum Depth Time: 1554 Max Gas: 2063u Average Gas: 1554u 14775' 15245' 470' Max @ ft Current 15060'293.0 Date: Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: 424.0 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 162 111 (current) M. Ross/R. Wimmer ShClyst TuffGvlCoal cP 14 200' 8.75" 0.902 Footage 2.60 Ss Ratio C-1 C-5i AK-AM-0901412968 Drill 8.75" L1 Hole PV 24 hr Max 68.0 Weight 297 Hours C-3 04 Intermediate CementCht Silt C-4i C-4n YP (lb/100ft2) 2.00 3812382 40 Hycalog SKH616M-E1D FazePro NA 5232' 14684'15 Depth in / out Mud Type Lst 100 Hydril 563 Type Average 118Background (max) Trip 11.1011.20 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 185031' 5232' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 128 5 2878' 160' Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 9.1 8.75" 9.25 Smith XR+CPS Mill Tooth 9.25 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.40 DOYON15 Report For: Morning Report Report # 32 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 7-Jul-2014 12:00 AM Current Pump & Flow Data: 1976 Max 96 Lime (lb/bbl) 2.60 Drill ahead / 14775' MD to TD 15245' MD. Max gas was 2063u @ 15109' MD. Samples consisted of sst. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:BROOH from 9922' to 5117'. Work DS through tight spots and pack offs as hole will allow T/5462' MD @5406' MD Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.60 0 8-Jul-2014 12:00 AM Current Pump & Flow Data: 1077 Max Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 33 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.20 DOYON15 Report For: Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 9.1 8.75" 9.25 Smith XR+CPS Mill Tooth 9.25 Size 5 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 185031' 5232' WOB EVEMAR 10.9011.00 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 7Background (max) Trip Average Mud Type Lst 100 Hydril 563 Type 40 Hycalog SKH616M-E1D FazePro NA 5232' 14684'15 Depth in / out YP (lb/100ft2) 2.00 000 00 Intermediate CementCht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 BROOH PV 200' 8.75" 0.902 Footage 2.60 M. Ross/O. Amend ShClyst TuffGvlCoal cP 14 40.0 Gas Summary 0 0 0 (current) Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 15245' 15245' 0' Max @ ft Current Date: Time: 10 Max Gas: 139u Average Gas: 10u in 0Minimum Depth C-5nC-2 139 SPP (psi) Gallons/stroke TFABit Type Depth 72 / 2844 L-80 Oil/Water 15245' Alkal 0.746 0 0 0 Siltst 13.38'' 450 99 Units* Casing Summary Lithology (%) 0 0 1535 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 0 0 Cly 15358 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 14286 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker 1053 13.38'' 152 25 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water 15245' Alkal 0.746 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2 19/2743 C-5nC-2 137 in 0Minimum Depth Time: 9 Max Gas: 137u Average Gas: 9u 15245' 15245' 0' Max @ ft Current Date: Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) M. Ross/O. Amend ShClyst TuffGvlCoal cP 11 200' 8.75" 0.902 Footage 2.60 Ss Ratio C-1 C-5i AK-AM-0901412968 RIH W/BHA # 1B PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementCht Silt C-4i C-4n YP (lb/100ft2) 2.40 000 40 Hycalog SKH616M-E1D FazePro NA 5232' 14684'17 Depth in / out Mud Type Lst Hydril 563 Type Average 5Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 185031' 5232' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 5 2878' 160' Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 8.6 8.75" 0.00 Smith XR+CPS Mill Tooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 34 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 9-Jul-2014 12:00 AM Current Pump & Flow Data: 1077 Max 0 Lime (lb/bbl) 3.12 BROOH F/ 4880' MD to 3476' MD Circ. B/U 2X. POOH F/3476' MD T/957' MD. POOH F/957' MD to 397' MD. L/D BHA Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:POOH F/4940' MD T/490' MD. L/D BHA #1B, NO Whipstock on Hook. M/U BHA #1B. RIH F/491' MD to 1518' MD SHT Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.99 0 10-Jul-2014 12:00 AM Current Pump & Flow Data: Max 1-2-BT-A-X-In-CT-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 35 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 8.7 8.75" 0.00 Smith XR+CPS Mill Tooth 9.25 Size 5 Static Loss. Drop Ball rod @ 4942' MD P/U T/4911' MD. POOH F/4942' MD T/490' MD 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 15 185031' 5232' WOB EVEMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 0Background (max) Trip Average Mud Type Lst Hydril 563 Type 160 40 Hycalog SKH616M-E1D FazePro NA 5232' 14684'16 15245' Depth in / out YP (lb/100ft2) 2.30 000 00 Intermediate CementCht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 POOH w/ Whip Stock PV 200' 8.75" 0.902 Footage 55.90 4050' 2.60 M. Ross/O. Amend ShClyst TuffGvlCoal cP 11 40.0 Gas Summary 0 0 0 (current) Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 15245' 15245' 0' Max @ ft Current Date: Time: 2 Max Gas: 6u Average Gas: 2u in 0Minimum Depth C-5nC-2 6 SPP (psi) Gallons/stroke TFABit Type Depth 73 / 27'43 L-80 Oil/Water 15245' Alkal 0.746 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 0235 0 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 0 0 Cly 721 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 508 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker 289 13.38'' Units* Casing Summary Lithology (%) 0 L-80 Oil/Water 15245' Alkal 0.746 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2 19/2743 C-5nC-2 5 in 0Minimum Depth Time: 2 Max Gas: 5u Average Gas: 2u 15245' 15245' 0' Max @ ft Current Date: Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) M. Ross/O. Amend ShClyst TuffGvlCoal cP 11 200' 8.75" 0.902 Footage 55.90 4050' 2.60 Ss Ratio C-1 C-5i AK-AM-0901412968 Waiting On Diverter PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementCht Silt C-4i C-4n YP (lb/100ft2) 2.30 000 160 40 Hycalog SKH616M-E1D FazePro NA 5232' 14684'18 15245' Depth in / out Mud Type Lst Hydril 563 Type Average 2Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 15 185031' 5232' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 5 Prep well for well control. wait on replacement diverter. Load Comp. Tools and MWD in Shed. M/U Diverter w/hanger seal assy. Stage up pumps to verify tool release. Unsuccessful. flow rate. Wash Up T/4990' MD. Circ. B/U @400 GPM. POOH F/4937' MD T/80' MD L/D Cleanout BHA As per Baker Rep. Clean BHA. r. 2878' 160' Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 8.1 8.75" 72 / 28' Smith XR+CPS Mill Tooth 9.25 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 36 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-2-BT-A-X-In-CT-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 11-Jul-2014 12:00 AM Current Pump & Flow Data: Max 0 Lime (lb/bbl) 2.99 L/D Whipstock Retrieval BHA, Whipstock and Anchor Assy As Per Baker Rep. Clean rig floor. M/U Baker cleanout Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:M/U BHA. RIH w/seal assy on 5" DP. F/150' MD T/4917' MD. w/SHT @ 1500' MD W/D F/4917' MD T/5086' MD Verify Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.60 0 12-Jul-2014 12:00 AM Current Pump & Flow Data: Max 1-2-BT-A-X-In-CT-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 37 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 8.2 8.75"Smith XR+CPS Mill Tooth 9.25 Size 5 T/3292' MD. 80 Jts Run. 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 15 185031' 5232' WOB EVEMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 0Background (max) Trip Average Mud Type Lst Hydril 563 Type 160 40 Hycalog SKH616M-E1D FazePro NA 5232' 14684'15 15245' Depth in / out YP (lb/100ft2) 2.20 000 00 Intermediate CementCht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 RIH w/ Liner PV 200' 8.75" 0.902 Footage 55.90 4050' 2.60 B. Perry/O. Amend ShClyst TuffGvlCoal cP 12 40.0 Gas Summary 0 0 0 (current) Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 15245' 15245' 0' Max @ ft Current Date: Time: 0 Max Gas: 0u Average Gas: 0u in 0Minimum Depth C-5nC-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 72/2843 L-80 Oil/Water 15245' Alkal 0.746 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker 0 0 13.38'' Units* Casing Summary Lithology (%) 0 L-80 Oil/Water 15245' Alkal 0.746 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 72/2843 C-5nC-2 0 in 0Minimum Depth Time: 0 Max Gas: 0u Average Gas: 0u 15245' 15245' 0' Max @ ft Current Date: Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) B. Perry/O. Amend ShClyst TuffGvlCoal cP 12 200' 8.75" 0.902 Footage 55.90 4050' 2.60 Ss Ratio C-1 C-5i AK-AM-0901412968 RIH w/LEM Tool PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementCht Silt C-4i C-4n YP (lb/100ft2) 2.20 000 160 40 Hycalog SKH616M-E1D FazePro NA 5232' 14684'15 15245' Depth in / out Mud Type Lst Hydril 563 Type Average 0Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 15 185031' 5232' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 5 liner packer. Top @ 4981' MD. Shoe @ 15200' MD. Displace 9.2+ OBM w/9.1+ Brine. POOH on Elevators. L/D liner running tools. Service brake T/15093' MD. Break Circ. W/D T/15183' MD.Observe drop into Alignment slot. Drop Setting Ball. P/U Ensure Ram is Set. Successful. 2878' 160' Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 8.2 8.75"Smith XR+CPS Mill Tooth 9.25 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 38 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-2-BT-A-X-In-CT-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 13-Jul-2014 12:00 AM Current Pump & Flow Data: Max 0 Lime (lb/bbl) 2.60 RIH w/5.5" Liner F/3292' MD T/10176' MD Entry into SBD @ 4985' MD. w/Window Exit @ 5007' MD P/U & M/U Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:L/D liner top Packer, P/U & M/U LEM tool. M/U Liner top Packer to slim hole MWD. Orient as per Baker and SLB reps. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 0 14-Jul-2014 12:00 AM Current Pump & Flow Data: Max 1-2-BT-A-X-In-CT-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 39 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 8.75"Smith XR+CPS Mill Tooth 9.15 Size 5 RIH w/5.5' DP T/3000' MD POOH Set mouse hole. R/U to test BOPs POOH and L/D 5.5" DP. F/4970' MD T/ 3755' MD Cont. POOH F/3755' MD L/D DP, L/D LEM Running tool and MWD. M/U Shoe, and W/D Through top of RAM hanger. Seat packer. Packer Set. Test Packer. Successful. Un-sting from LEM. Monitor Well.(Static) 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 15 185031' 5232' WOB EVEMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 0Background (max) Trip Average Mud Type Lst Hydril 563 Type 160 40 Hycalog SKH616M-E1D FazePro 5232' 15245' 15245' Depth in / out YP (lb/100ft2) 000 00 Intermediate CementCht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Testing BOPs PV 200' 8.75" 0.902 Footage 55.90 4050' 2.60 B. Perry/O. Amend ShClyst TuffGvlCoal cP 40.0 Gas Summary 0 0 0 (current) Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 15245' 15245' 0' Max @ ft Current Date: Time: 0 Max Gas: 0u Average Gas: 0u in 0Minimum Depth C-5nC-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 28 L-80 Oil/Water 15245' Alkal 0.746 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker 0 0 13.38'' Units* Casing Summary Lithology (%) 0 L-80 Oil/Water 15245' Alkal 0.746 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 28 C-5nC-2 0 in 0Minimum Depth Time: 0 Max Gas: 0u Average Gas: 0u 15245' 15245' 0' Max @ ft Current Date: Avg to5031' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) B. Perry/O. Amend ShClyst TuffGvlCoal cP 200' 8.75" 0.902 Footage 55.90 4050' 2.60 Ss Ratio C-1 C-5i AK-AM-0901412968 Run 4.5” completion tubing PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementCht Silt C-4i C-4n YP (lb/100ft2) 000 160 40 Hycalog SKH616M-E1D FazePro 5232' 15245' 15245' Depth in / out Mud Type Lst Hydril 563 Type Average 0Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed, Periscope, TeleScope, EcoScope API FL Chromatograph (ppm) 15 185031' 5232' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 5 sec. Terminate gauge line, motor lead & capillary line. to shroud. Set pack off & test to 1000 psi for 15 min. Good. R/D equip. POH f/138'. RBU upper comp in derrick. M/U & service motor 2878' 160' Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 8.75"Smith XR+CPS Mill Tooth 9.15 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 40 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-2-BT-A-X-In-CT-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 15-Jul-2014 12:00 AM Current Pump & Flow Data: Max 0 Lime (lb/bbl) Test BOPE's. C/O lower rams & replace inserts & air pump on Koomey. Complete BOPE test. R/U 4.5" comp Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker 0 0 13.38'' Units* Casing Summary Lithology (%) 0 L-80 Oil/Water Alkal 0.746 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 28 C-5nC-2 0 in 0Minimum Depth Time: 0 Max Gas: 0u Average Gas: 0u 15245' 15245' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) B. Perry/O. Amend ShClyst TuffGvlCoal cP 200' 8.75" 0.902 Footage 55.90 4050' 2.60 Ss Ratio C-1 C-5i AK-AM-0901412968 L/D 5" Drill Pipe PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementCht Silt C-4i C-4n YP (lb/100ft2) 000 160 40 Hycalog SKH616M-E1D FazePro 5232' 15245' 15245' Depth in / out Mud Type Lst Hydril 563 Type Average 0Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 15 185031' 5232' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 5 R/D Centrilift. SIMOPS: Lay down 5" drill pipe via mousehole and bullhead 130 bbls down OA at 2 bpm. 2878' 160' Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 8.75"Smith XR+CPS Mill Tooth 9.15 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 41 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-2-BT-A-X-In-CT-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth 16-Jul-2014 12:00 AM Current Pump & Flow Data: Max 0 Lime (lb/bbl) M/U top seal section to TTC & connect to shroud. Connect TEC to PSI discharge sub. R/U Volant tool. RIH 4.5" tbg to Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:L/D 5" DP. Clean & clear rig floor. N/D BOP. N/U tree. R/U and install TWC. SIMOPS: move rockwasher and mud Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 0 17-Jul-2014 12:00 AM Current Pump & Flow Data: Max 1-2-BT-A-X-In-CT-TD Conductor ROP ROP (ft/hr) 4.96 @ Mud Data Depth Morning Report Report # 42 Customer: Well: Area: Location: Rig: SP12-SE3 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-1-NO-BHA Bit # 4RR 8.75"Smith XR+CPS Mill Tooth 9.15 Size 5 2878' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 15 185031' 5232' WOB EVEMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 0Background (max) Trip Average Mud Type Lst Hydril 563 Type 160 40 Hycalog SKH616M-E1D FazePro 5232' 15245' 15245' Depth in / out YP (lb/100ft2) 000 00 Intermediate CementCht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901412968 Moving Rig PV 200' 8.75" 0.902 Footage 55.90 4050' 2.60 B. Perry/O. Amend ShClyst TuffGvlCoal cP 40.0 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 15245' 15245' 0' Max @ ft Current Date: Time: 0 Max Gas: 0u Average Gas: 0u in 0Minimum Depth C-5nC-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 28 L-80 Oil/Water Alkal 0.746 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Doug Acker Maximum Report By:Logging Engineers:Dani Dawson / Doug Acker Set AtSize 178.9 X-65 Grade L-805193' 20.00'' 9.63'' (max)(current) BTC 0 0 Cly 0 WELL INFORMATION Created On : Aug 11 2014 Customer :ENI Petroleum Well Name :SP12-SE3 Job Number :AK-XX-0901412968 Rig Name :Doyon 15 Field Name :Nikaitchuq Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 316.50 0.00 0.00 N 0.00 E 0.00 0.00 40.83 0.00 316.50 40.83 0.00 N 0.00 E 0.00 0.00 114.22 0.46 338.08 114.22 0.27 N 0.11 W 0.27 0.63 129.82 0.50 332.13 129.82 0.39 N 0.17 W 0.39 0.41 159.83 0.54 330.96 159.83 0.63 N 0.30 W 0.63 0.14 191.44 0.87 309.86 191.44 0.92 N 0.55 W 0.92 1.31 221.82 1.39 327.30 221.81 1.37 N 0.93 W 1.37 2.03 252.46 1.10 327.34 252.44 1.93 N 1.29 W 1.93 0.95 283.44 1.79 323.97 283.41 2.57 N 1.73 W 2.57 2.24 314.47 2.82 309.39 314.42 3.45 N 2.61 W 3.45 3.79 345.15 3.90 312.14 345.04 4.63 N 3.96 W 4.63 3.56 389.81 5.33 314.45 389.56 7.10 N 6.57 W 7.10 3.23 451.49 7.51 317.76 450.85 12.09 N 11.33 W 12.09 3.58 544.38 11.58 314.38 542.43 23.11 N 22.08 W 23.11 4.42 636.94 13.40 315.27 632.80 37.23 N 36.26 W 37.23 1.98 730.31 16.67 317.72 722.96 54.83 N 52.89 W 54.83 3.57 823.74 20.61 319.33 811.47 77.23 N 72.63 W 77.23 4.25 917.05 25.09 320.44 897.44 104.95 N 95.95 W 104.95 4.82 1010.60 28.90 320.05 980.78 137.58 N 123.11 W 137.58 4.08 1103.96 32.09 320.42 1,061.22 174.00 N 153.40 W 174.00 3.42 1197.35 34.23 321.14 1,139.39 213.58 N 185.69 W 213.58 2.33 1290.72 35.84 317.40 1,215.85 254.15 N 220.68 W 254.15 2.87 1348.98 38.80 316.24 1,262.18 279.90 N 244.85 W 279.90 5.22 1442.46 42.12 316.19 1,333.29 323.69 N 286.82 W 323.69 3.55 1535.80 41.55 318.37 1,402.84 369.41 N 329.05 W 369.41 1.67 1628.84 40.33 316.32 1,473.13 414.25 N 370.35 W 414.25 1.95 1722.21 43.92 314.72 1,542.37 458.91 N 414.24 W 458.91 4.01 1815.64 45.47 313.91 1,608.78 504.81 N 461.26 W 504.81 1.77 1908.95 44.23 314.72 1,674.93 550.77 N 508.35 W 550.77 1.46 2002.39 42.88 314.61 1,742.65 596.03 N 554.14 W 596.03 1.45 INSITE V8.1.0 Page 1Job No:AK-XX-0901412968 Well Name:SP12-SE3 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2095.82 40.71 316.69 1,812.30 640.54 N 597.68 W 640.54 2.76 2189.20 42.97 322.78 1,881.90 688.06 N 637.84 W 688.06 4.98 2282.60 43.58 329.94 1,949.94 741.31 N 673.24 W 741.31 5.29 2375.88 38.84 333.46 2,020.11 795.34 N 702.44 W 795.34 5.66 2469.25 33.76 333.07 2,095.33 844.70 N 727.28 W 844.70 5.45 2562.66 31.41 331.67 2,174.03 889.27 N 750.59 W 889.27 2.64 2656.08 25.78 332.63 2,256.02 928.77 N 771.50 W 928.77 6.05 2749.36 20.43 334.86 2,341.79 961.55 N 787.76 W 961.55 5.81 2801.15 19.87 344.66 2,390.43 978.22 N 793.93 W 978.22 6.60 2883.00 19.00 354.00 2,467.63 1,004.89 N 799.00 W 1004.89 3.94 2947.38 17.69 1.31 2,528.75 1,025.10 N 799.87 W 1025.10 4.11 2978.97 16.93 7.87 2,558.91 1,034.46 N 799.13 W 1034.46 6.63 3008.92 16.52 12.65 2,587.59 1,042.93 N 797.60 W 1042.93 4.79 3102.35 17.14 31.95 2,677.09 1,067.59 N 787.40 W 1067.59 5.99 3195.78 19.18 47.01 2,765.91 1,089.75 N 768.88 W 1089.75 5.46 3289.07 19.34 57.01 2,854.00 1,108.62 N 744.70 W 1108.62 3.54 3382.45 22.59 66.96 2,941.22 1,124.07 N 715.21 W 1124.07 5.15 3475.86 25.48 79.28 3,026.58 1,134.84 N 678.93 W 1134.84 6.18 3569.19 29.15 84.34 3,109.50 1,140.81 N 636.57 W 1140.81 4.65 3662.60 34.16 87.21 3,188.99 1,144.34 N 587.70 W 1144.34 5.60 3756.02 37.97 87.46 3,264.49 1,146.89 N 532.77 W 1146.89 4.08 3849.37 38.92 88.63 3,337.60 1,148.86 N 474.77 W 1148.86 1.28 3942.80 43.07 92.81 3,408.12 1,148.00 N 413.53 W 1148.00 5.32 4036.20 45.01 97.22 3,475.27 1,142.28 N 348.89 W 1142.28 3.88 4129.52 48.76 100.14 3,539.05 1,131.95 N 281.58 W 1131.95 4.62 4222.91 51.13 102.28 3,599.15 1,118.04 N 211.48 W 1118.04 3.08 4316.28 56.25 104.41 3,654.42 1,100.63 N 138.31 W 1100.63 5.78 4409.66 61.33 104.94 3,702.79 1,080.40 N 61.08 W 1080.40 5.46 4503.10 61.23 104.96 3,747.69 1,059.26 N 18.09 E 1059.26 0.11 4596.45 61.97 105.09 3,792.09 1,037.97 N 97.40 E 1037.97 0.80 4689.90 63.60 107.76 3,834.84 1,014.46 N 177.10 E 1014.46 3.08 4783.24 66.03 109.97 3,874.56 987.14 N 257.01 E 987.14 3.37 4876.70 69.54 112.85 3,909.89 955.54 N 337.53 E 955.54 4.72 4970.14 75.78 115.47 3,937.73 919.02 N 418.85 E 919.02 7.19 5063.50 77.75 118.14 3,959.11 878.04 N 499.94 E 878.04 3.49 5124.67 81.29 119.17 3,970.24 849.20 N 552.72 E 849.20 6.02 5207.00 84.00 120.50 3,980.77 808.58 N 623.54 E 808.58 3.66 5278.22 83.68 117.26 3,988.42 774.38 N 685.53 E 774.38 4.55 5372.30 83.88 117.24 3,998.61 731.56 N 768.68 E 731.56 0.21 5464.99 83.69 120.95 4,008.65 686.76 N 849.18 E 686.76 3.98 5558.46 86.30 127.58 4,016.81 634.36 N 926.08 E 634.36 7.60 5651.83 85.72 129.24 4,023.31 576.50 N 999.06 E 576.50 1.88 5745.32 86.88 128.79 4,029.34 517.77 N 1,071.55 E 517.77 1.33 5838.67 88.05 127.47 4,033.47 460.19 N 1,144.90 E 460.19 1.89 5932.03 88.05 127.17 4,036.65 403.62 N 1,219.11 E 403.62 0.32 INSITE V8.1.0 Page 2Job No:AK-XX-0901412968 Well Name:SP12-SE3 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6025.43 88.08 126.95 4,039.80 347.36 N 1,293.60 E 347.36 0.24 6119.33 87.87 126.73 4,043.12 291.10 N 1,368.70 E 291.10 0.32 6212.23 89.36 126.79 4,045.37 235.52 N 1,443.10 E 235.52 1.61 6305.65 89.99 125.51 4,045.90 180.41 N 1,518.53 E 180.41 1.53 6399.08 91.89 125.49 4,044.36 126.17 N 1,594.58 E 126.17 2.03 6492.50 92.18 124.57 4,041.05 72.58 N 1,671.03 E 72.58 1.03 6585.85 91.75 123.56 4,037.85 20.32 N 1,748.32 E 20.32 1.18 6679.20 90.89 123.53 4,035.70 31.25 S 1,826.10 E -31.25 0.92 6772.60 89.61 124.72 4,035.29 83.65 S 1,903.41 E -83.65 1.87 6865.94 91.01 127.08 4,034.78 138.37 S 1,979.01 E -138.37 2.94 6959.32 88.30 125.40 4,035.34 193.57 S 2,054.32 E -193.57 3.41 7052.78 86.94 125.14 4,039.23 247.49 S 2,130.55 E -247.49 1.48 7146.24 88.89 126.01 4,042.63 301.82 S 2,206.52 E -301.82 2.28 7239.52 87.99 126.48 4,045.17 356.95 S 2,281.72 E -356.95 1.09 7333.36 88.64 125.26 4,047.93 411.91 S 2,357.73 E -411.91 1.47 7426.36 87.56 126.10 4,051.01 466.12 S 2,433.22 E -466.12 1.47 7519.77 87.73 124.66 4,054.85 520.16 S 2,509.32 E -520.16 1.55 7613.19 90.43 123.65 4,056.35 572.59 S 2,586.61 E -572.59 3.09 7706.58 90.28 124.48 4,055.77 624.90 S 2,663.97 E -624.90 0.90 7799.95 88.00 124.60 4,057.17 677.83 S 2,740.87 E -677.83 2.45 7893.46 86.63 125.04 4,061.55 731.17 S 2,817.55 E -731.17 1.54 7986.86 85.92 125.10 4,067.62 784.72 S 2,893.83 E -784.72 0.76 8080.15 89.09 126.12 4,071.68 838.98 S 2,969.59 E -838.98 3.57 8173.58 89.68 127.39 4,072.68 894.88 S 3,044.44 E -894.88 1.50 8267.03 90.20 128.95 4,072.78 952.63 S 3,117.91 E -952.63 1.76 8360.38 87.95 126.69 4,074.29 1,009.86 S 3,191.63 E -1009.86 3.42 8453.79 89.80 125.60 4,076.12 1,064.94 S 3,267.04 E -1064.94 2.30 8547.20 91.40 125.36 4,075.14 1,119.15 S 3,343.10 E -1119.15 1.73 8640.66 90.43 124.45 4,073.65 1,172.62 S 3,419.74 E -1172.62 1.42 8734.06 90.29 123.68 4,073.06 1,224.94 S 3,497.11 E -1224.94 0.84 8827.75 89.86 123.42 4,072.94 1,276.72 S 3,575.19 E -1276.72 0.54 8920.82 87.71 121.62 4,074.91 1,326.74 S 3,653.64 E -1326.74 3.01 9014.36 88.88 122.12 4,077.70 1,376.10 S 3,733.04 E -1376.10 1.36 9107.72 88.88 122.37 4,079.52 1,425.90 S 3,811.99 E -1425.90 0.27 9201.05 88.87 123.25 4,081.35 1,476.46 S 3,890.41 E -1476.46 0.94 9294.85 90.44 123.86 4,081.92 1,528.31 S 3,968.58 E -1528.31 1.80 9387.78 92.52 124.48 4,079.52 1,580.48 S 4,045.43 E -1580.48 2.34 9482.03 92.22 124.44 4,075.62 1,633.77 S 4,123.08 E -1633.77 0.32 9574.65 91.01 125.18 4,073.01 1,686.62 S 4,199.09 E -1686.62 1.53 9668.96 90.33 126.30 4,071.91 1,741.70 S 4,275.63 E -1741.70 1.39 9761.41 89.88 126.81 4,071.74 1,796.76 S 4,349.90 E -1796.76 0.74 9855.66 90.69 127.75 4,071.27 1,853.85 S 4,424.89 E -1853.85 1.32 9949.99 90.89 128.05 4,069.97 1,911.79 S 4,499.32 E -1911.79 0.38 10041.68 90.55 128.24 4,068.82 1,968.41 S 4,571.42 E -1968.41 0.42 10135.10 90.92 128.18 4,067.62 2,026.19 S 4,644.82 E -2026.19 0.40 INSITE V8.1.0 Page 3Job No:AK-XX-0901412968 Well Name:SP12-SE3 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10228.46 90.96 128.10 4,066.09 2,083.84 S 4,718.24 E -2083.84 0.10 10321.95 88.67 126.56 4,066.39 2,140.53 S 4,792.57 E -2140.53 2.95 10415.28 88.91 126.64 4,068.36 2,196.16 S 4,867.48 E -2196.16 0.27 10508.70 90.16 126.57 4,069.12 2,251.87 S 4,942.47 E -2251.87 1.34 10602.11 90.27 126.11 4,068.77 2,307.22 S 5,017.71 E -2307.22 0.51 10695.44 90.71 125.43 4,067.97 2,361.77 S 5,093.43 E -2361.77 0.87 10788.87 89.75 124.55 4,067.60 2,415.35 S 5,169.97 E -2415.35 1.39 10882.34 88.40 125.48 4,069.10 2,468.97 S 5,246.51 E -2468.97 1.75 10975.78 87.85 125.79 4,072.16 2,523.38 S 5,322.41 E -2523.38 0.68 11069.14 88.53 124.62 4,075.11 2,577.17 S 5,398.66 E -2577.17 1.45 11162.53 90.59 125.16 4,075.83 2,630.59 S 5,475.26 E -2630.59 2.28 11255.91 90.39 125.31 4,075.03 2,684.46 S 5,551.53 E -2684.46 0.27 11349.32 90.39 125.30 4,074.39 2,738.44 S 5,627.75 E -2738.44 0.01 11442.68 90.46 124.75 4,073.70 2,792.02 S 5,704.20 E -2792.02 0.59 11536.12 90.29 124.63 4,073.09 2,845.20 S 5,781.03 E -2845.20 0.22 11629.49 90.85 124.30 4,072.16 2,898.04 S 5,858.01 E -2898.04 0.70 11723.21 87.95 123.15 4,073.14 2,950.06 S 5,935.94 E -2950.06 3.33 11816.23 87.98 123.85 4,076.44 3,001.37 S 6,013.46 E -3001.37 0.75 11910.06 90.90 124.15 4,077.36 3,053.83 S 6,091.24 E -3053.83 3.13 12003.49 89.64 122.66 4,076.92 3,105.27 S 6,169.23 E -3105.27 2.09 12096.80 91.07 123.30 4,076.34 3,156.06 S 6,247.50 E -3156.06 1.68 12190.26 91.89 123.24 4,073.93 3,207.31 S 6,325.61 E -3207.31 0.88 12283.71 90.20 123.84 4,072.23 3,258.93 S 6,403.49 E -3258.93 1.92 12377.14 91.90 125.46 4,070.51 3,312.04 S 6,480.33 E -3312.04 2.51 12470.48 91.44 125.47 4,067.79 3,366.17 S 6,556.32 E -3366.17 0.49 12564.36 91.41 125.83 4,065.46 3,420.87 S 6,632.58 E -3420.87 0.38 12657.28 90.59 127.57 4,063.84 3,476.39 S 6,707.07 E -3476.39 2.07 12750.61 92.12 129.67 4,061.63 3,534.62 S 6,779.96 E -3534.62 2.78 12843.97 90.64 129.28 4,059.38 3,593.96 S 6,852.00 E -3593.96 1.64 12937.32 90.75 128.66 4,058.25 3,652.66 S 6,924.57 E -3652.66 0.67 13031.68 90.20 128.38 4,057.47 3,711.43 S 6,998.40 E -3711.43 0.65 13126.02 90.48 127.83 4,056.91 3,769.64 S 7,072.63 E -3769.64 0.65 13217.36 90.77 127.26 4,055.91 3,825.30 S 7,145.05 E -3825.30 0.70 13310.79 90.83 127.33 4,054.61 3,881.91 S 7,219.37 E -3881.91 0.10 13404.21 90.68 127.14 4,053.38 3,938.43 S 7,293.74 E -3938.43 0.26 13498.65 90.38 126.62 4,052.50 3,995.10 S 7,369.28 E -3995.10 0.64 13591.01 89.51 125.59 4,052.59 4,049.53 S 7,443.90 E -4049.53 1.46 13684.40 89.71 124.91 4,053.23 4,103.42 S 7,520.16 E -4103.42 0.76 13777.77 89.82 124.24 4,053.61 4,156.41 S 7,597.04 E -4156.41 0.73 13871.21 88.97 124.81 4,054.60 4,209.36 S 7,674.02 E -4209.36 1.10 13964.69 87.72 124.75 4,057.30 4,262.66 S 7,750.76 E -4262.66 1.34 14058.03 87.17 124.47 4,061.46 4,315.63 S 7,827.51 E -4315.63 0.66 14151.09 89.72 125.12 4,063.98 4,368.71 S 7,903.89 E -4368.71 2.83 14244.44 89.78 124.20 4,064.39 4,421.79 S 7,980.68 E -4421.79 0.99 14337.87 90.44 123.33 4,064.21 4,473.72 S 8,058.34 E -4473.72 1.17 INSITE V8.1.0 Page 4Job No:AK-XX-0901412968 Well Name:SP12-SE3 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14431.18 88.97 123.03 4,064.69 4,524.79 S 8,136.44 E -4524.79 1.61 14524.62 90.72 123.89 4,064.94 4,576.30 S 8,214.39 E -4576.30 2.09 14618.05 90.87 123.54 4,063.65 4,628.16 S 8,292.10 E -4628.16 0.41 14711.43 90.41 124.36 4,062.60 4,680.30 S 8,369.55 E -4680.30 1.01 14804.83 90.28 125.87 4,062.04 4,734.02 S 8,445.95 E -4734.02 1.62 14898.11 90.29 126.57 4,061.58 4,789.14 S 8,521.20 E -4789.14 0.75 14992.09 89.68 125.81 4,061.60 4,844.63 S 8,597.05 E -4844.63 1.04 15085.53 90.08 125.75 4,061.80 4,899.26 S 8,672.85 E -4899.26 0.43 15151.59 89.57 125.99 4,062.00 4,937.97 S 8,726.38 E -4937.97 0.85 15216.00 89.57 125.99 4,062.48 4,975.82 S 8,778.50 E -4975.82 0.00 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (True) - A total correction of 19.26 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 15,216.00 feet is 10,090.63 feet along 119.55 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.0 Page 5Job No:AK-XX-0901412968 Well Name:SP12-SE3 Survey Report WELL INFORMATION Created On : Aug 11 2014 Customer :ENI Petroleum Well Name :SP12-SE3 L1 Job Number :AK-XX-0901412968 Rig Name :Doyon 15 Field Name :Nikaitchuq Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 316.50 0.00 0.00 N 0.00 E 0.00 0.00 40.83 0.00 316.50 40.83 0.00 N 0.00 E 0.00 0.00 114.22 0.46 338.08 114.22 0.27 N 0.11 W 0.27 0.63 129.82 0.50 332.13 129.82 0.39 N 0.17 W 0.39 0.41 159.83 0.54 330.96 159.83 0.63 N 0.30 W 0.63 0.14 191.44 0.87 309.86 191.44 0.92 N 0.55 W 0.92 1.31 221.82 1.39 327.30 221.81 1.37 N 0.93 W 1.37 2.03 252.46 1.10 327.34 252.44 1.93 N 1.29 W 1.93 0.95 283.44 1.79 323.97 283.41 2.57 N 1.73 W 2.57 2.24 314.47 2.82 309.39 314.42 3.45 N 2.61 W 3.45 3.79 345.15 3.90 312.14 345.04 4.63 N 3.96 W 4.63 3.56 389.81 5.33 314.45 389.56 7.10 N 6.57 W 7.10 3.23 451.49 7.51 317.76 450.85 12.09 N 11.33 W 12.09 3.58 544.38 11.58 314.38 542.43 23.11 N 22.08 W 23.11 4.42 636.94 13.40 315.27 632.80 37.23 N 36.26 W 37.23 1.98 730.31 16.67 317.72 722.96 54.83 N 52.89 W 54.83 3.57 823.74 20.61 319.33 811.47 77.23 N 72.63 W 77.23 4.25 917.05 25.09 320.44 897.44 104.95 N 95.95 W 104.95 4.82 1010.60 28.90 320.05 980.78 137.58 N 123.11 W 137.58 4.08 1103.96 32.09 320.42 1,061.22 174.00 N 153.40 W 174.00 3.42 1197.35 34.23 321.14 1,139.39 213.58 N 185.69 W 213.58 2.33 1290.72 35.84 317.40 1,215.85 254.15 N 220.68 W 254.15 2.87 1348.98 38.80 316.24 1,262.18 279.90 N 244.85 W 279.90 5.22 1442.46 42.12 316.19 1,333.29 323.69 N 286.82 W 323.69 3.55 1535.80 41.55 318.37 1,402.84 369.41 N 329.05 W 369.41 1.67 1628.84 40.33 316.32 1,473.13 414.25 N 370.35 W 414.25 1.95 1722.21 43.92 314.72 1,542.37 458.91 N 414.24 W 458.91 4.01 1815.64 45.47 313.91 1,608.78 504.81 N 461.26 W 504.81 1.77 1908.95 44.23 314.72 1,674.93 550.77 N 508.35 W 550.77 1.46 2002.39 42.88 314.61 1,742.65 596.03 N 554.14 W 596.03 1.45 INSITE V8.1.0 Page 1Job No:AK-XX-0901412968 Well Name:SP12-SE3 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2095.82 40.71 316.69 1,812.30 640.54 N 597.68 W 640.54 2.76 2189.20 42.97 322.78 1,881.90 688.06 N 637.84 W 688.06 4.98 2282.60 43.58 329.94 1,949.94 741.31 N 673.24 W 741.31 5.29 2375.88 38.84 333.46 2,020.11 795.34 N 702.44 W 795.34 5.66 2469.25 33.76 333.07 2,095.33 844.70 N 727.28 W 844.70 5.45 2562.66 31.41 331.67 2,174.03 889.27 N 750.59 W 889.27 2.64 2656.08 25.78 332.63 2,256.02 928.77 N 771.50 W 928.77 6.05 2749.36 20.43 334.86 2,341.79 961.55 N 787.76 W 961.55 5.81 2801.15 19.87 344.66 2,390.43 978.22 N 793.93 W 978.22 6.60 2883.00 19.00 354.00 2,467.63 1,004.89 N 799.00 W 1004.89 3.94 2947.38 17.69 1.31 2,528.75 1,025.10 N 799.87 W 1025.10 4.11 2978.97 16.93 7.87 2,558.91 1,034.46 N 799.13 W 1034.46 6.63 3008.92 16.52 12.65 2,587.59 1,042.93 N 797.60 W 1042.93 4.79 3102.35 17.14 31.95 2,677.09 1,067.59 N 787.40 W 1067.59 5.99 3195.78 19.18 47.01 2,765.91 1,089.75 N 768.88 W 1089.75 5.46 3289.07 19.34 57.01 2,854.00 1,108.62 N 744.70 W 1108.62 3.54 3382.45 22.59 66.96 2,941.22 1,124.07 N 715.21 W 1124.07 5.15 3475.86 25.48 79.28 3,026.58 1,134.84 N 678.93 W 1134.84 6.18 3569.19 29.15 84.34 3,109.50 1,140.81 N 636.57 W 1140.81 4.65 3662.60 34.16 87.21 3,188.99 1,144.34 N 587.70 W 1144.34 5.60 3756.02 37.97 87.46 3,264.49 1,146.89 N 532.77 W 1146.89 4.08 3849.37 38.92 88.63 3,337.60 1,148.86 N 474.77 W 1148.86 1.28 3942.80 43.07 92.81 3,408.12 1,148.00 N 413.53 W 1148.00 5.32 4036.20 45.01 97.22 3,475.27 1,142.28 N 348.89 W 1142.28 3.88 4129.52 48.76 100.14 3,539.05 1,131.95 N 281.58 W 1131.95 4.62 4222.91 51.13 102.28 3,599.15 1,118.04 N 211.48 W 1118.04 3.08 4316.28 56.25 104.41 3,654.42 1,100.63 N 138.31 W 1100.63 5.78 4409.66 61.33 104.94 3,702.79 1,080.40 N 61.08 W 1080.40 5.46 4503.10 61.23 104.96 3,747.69 1,059.26 N 18.09 E 1059.26 0.11 4596.45 61.97 105.09 3,792.09 1,037.97 N 97.40 E 1037.97 0.80 4689.90 63.60 107.76 3,834.84 1,014.46 N 177.10 E 1014.46 3.08 4783.24 66.03 109.97 3,874.56 987.14 N 257.01 E 987.14 3.37 4876.70 69.54 112.85 3,909.89 955.54 N 337.53 E 955.54 4.72 4970.14 75.78 115.47 3,937.73 919.02 N 418.85 E 919.02 7.19 5278.32 83.39 104.76 3,993.56 815.35 N 702.93 E 815.35 4.21 5371.76 83.79 108.41 4,004.00 788.85 N 791.91 E 788.85 3.91 5465.15 85.32 111.30 4,012.86 757.27 N 879.34 E 757.27 3.49 5558.61 87.38 113.07 4,018.81 722.06 N 965.69 E 722.06 2.90 5651.98 86.78 115.45 4,023.57 683.75 N 1,050.70 E 683.75 2.63 5745.47 85.80 117.93 4,029.62 641.85 N 1,134.05 E 641.85 2.85 5838.82 86.99 120.42 4,035.49 596.43 N 1,215.38 E 596.43 2.95 5932.18 89.38 123.66 4,038.45 546.94 N 1,294.47 E 546.94 4.31 6025.58 89.47 125.07 4,039.38 494.22 N 1,371.56 E 494.22 1.51 6118.98 90.27 126.38 4,039.60 439.69 N 1,447.38 E 439.69 1.64 6212.38 90.27 127.50 4,039.16 383.56 N 1,522.03 E 383.56 1.20 INSITE V8.1.0 Page 2Job No:AK-XX-0901412968 Well Name:SP12-SE3 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6305.80 90.80 124.87 4,038.28 328.41 N 1,597.42 E 328.41 2.87 6399.23 89.16 126.08 4,038.32 274.19 N 1,673.50 E 274.19 2.18 6492.65 86.87 127.81 4,041.55 218.08 N 1,748.11 E 218.08 3.07 6586.00 86.42 128.36 4,047.01 160.60 N 1,821.46 E 160.60 0.76 6679.35 87.07 127.82 4,052.31 103.11 N 1,894.81 E 103.11 0.90 6772.75 88.00 127.78 4,056.33 45.91 N 1,968.55 E 45.91 1.00 6866.09 88.61 128.91 4,059.09 11.97 S 2,041.72 E -11.97 1.38 6959.47 89.76 130.29 4,060.42 71.48 S 2,113.66 E -71.48 1.92 7052.93 87.84 129.30 4,062.38 131.28 S 2,185.45 E -131.28 2.31 7146.39 87.85 129.03 4,065.89 190.27 S 2,257.86 E -190.27 0.29 7239.67 89.12 126.04 4,068.36 247.07 S 2,331.79 E -247.07 3.48 7333.11 88.97 124.72 4,069.92 301.16 S 2,407.96 E -301.16 1.42 7426.51 89.82 126.74 4,070.90 355.70 S 2,483.77 E -355.70 2.35 7519.92 88.68 125.38 4,072.13 410.68 S 2,559.28 E -410.68 1.90 7613.34 88.96 125.38 4,074.05 464.75 S 2,635.43 E -464.75 0.30 7706.73 89.43 126.15 4,075.36 519.33 S 2,711.20 E -519.33 0.97 7800.10 89.87 124.63 4,075.93 573.40 S 2,787.31 E -573.40 1.69 7893.61 90.64 124.36 4,075.52 626.36 S 2,864.38 E -626.36 0.87 7987.01 90.96 124.01 4,074.21 678.83 S 2,941.64 E -678.83 0.51 8080.30 90.57 123.36 4,072.97 730.57 S 3,019.26 E -730.57 0.81 8173.73 91.16 123.17 4,071.56 781.81 S 3,097.37 E -781.81 0.66 8267.18 90.98 124.26 4,069.81 833.67 S 3,175.08 E -833.67 1.18 8360.53 90.46 124.55 4,068.64 886.41 S 3,252.10 E -886.41 0.64 8453.94 89.71 125.19 4,068.50 939.82 S 3,328.74 E -939.82 1.06 8547.35 90.03 126.47 4,068.71 994.49 S 3,404.47 E -994.49 1.41 8640.81 90.01 126.46 4,068.68 1,050.04 S 3,479.63 E -1050.04 0.02 8734.21 88.26 125.18 4,070.09 1,104.69 S 3,555.35 E -1104.69 2.32 8827.58 88.54 125.07 4,072.70 1,158.39 S 3,631.69 E -1158.39 0.32 8920.97 88.64 125.19 4,074.99 1,212.12 S 3,708.04 E -1212.12 0.17 9014.51 89.38 126.15 4,076.61 1,266.65 S 3,784.02 E -1266.65 1.30 9107.87 89.53 127.09 4,077.50 1,322.34 S 3,858.95 E -1322.34 1.02 9201.20 90.18 127.06 4,077.73 1,378.60 S 3,933.41 E -1378.60 0.70 9294.54 89.31 127.04 4,078.15 1,434.84 S 4,007.91 E -1434.84 0.93 9387.93 88.62 127.08 4,079.84 1,491.11 S 4,082.42 E -1491.11 0.74 9481.41 90.43 127.88 4,080.61 1,547.99 S 4,156.59 E -1547.99 2.12 9574.80 89.36 126.31 4,080.78 1,604.31 S 4,231.08 E -1604.31 2.03 9668.23 86.61 126.20 4,084.07 1,659.53 S 4,306.37 E -1659.53 2.95 9761.56 89.06 126.25 4,087.59 1,714.64 S 4,381.60 E -1714.64 2.63 9854.98 89.84 125.88 4,088.49 1,769.63 S 4,457.11 E -1769.63 0.92 9948.43 91.07 125.31 4,087.75 1,824.02 S 4,533.10 E -1824.02 1.45 10041.83 89.22 124.59 4,087.51 1,877.52 S 4,609.65 E -1877.52 2.13 10135.25 90.07 123.82 4,088.09 1,930.04 S 4,686.91 E -1930.04 1.23 10228.61 90.07 123.59 4,087.98 1,981.84 S 4,764.57 E -1981.84 0.25 10322.10 89.54 123.48 4,088.29 2,033.49 S 4,842.50 E -2033.49 0.58 10415.43 90.03 123.68 4,088.65 2,085.11 S 4,920.25 E -2085.11 0.57 INSITE V8.1.0 Page 3Job No:AK-XX-0901412968 Well Name:SP12-SE3 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10508.85 90.30 125.22 4,088.38 2,137.96 S 4,997.29 E -2137.96 1.67 10602.26 89.89 125.99 4,088.22 2,192.34 S 5,073.23 E -2192.34 0.93 10695.59 89.35 123.58 4,088.84 2,245.58 S 5,149.88 E -2245.58 2.65 10789.02 90.77 126.72 4,088.74 2,299.36 S 5,226.26 E -2299.36 3.69 10882.49 92.21 127.12 4,086.31 2,355.49 S 5,300.96 E -2355.49 1.60 10975.93 92.98 127.22 4,082.08 2,411.88 S 5,375.34 E -2411.88 0.83 11069.29 92.33 126.36 4,077.76 2,467.73 S 5,450.02 E -2467.73 1.15 11162.68 92.16 125.79 4,074.10 2,522.68 S 5,525.45 E -2522.68 0.64 11256.06 90.19 125.35 4,072.18 2,576.99 S 5,601.38 E -2576.99 2.16 11349.47 89.79 125.53 4,072.20 2,631.15 S 5,677.49 E -2631.15 0.47 11442.83 89.58 125.70 4,072.71 2,685.52 S 5,753.38 E -2685.52 0.29 11536.27 90.01 127.05 4,073.05 2,740.93 S 5,828.61 E -2740.93 1.52 11629.64 90.98 126.84 4,072.24 2,797.05 S 5,903.23 E -2797.05 1.06 11723.09 91.31 126.21 4,070.37 2,852.66 S 5,978.31 E -2852.66 0.76 11816.48 90.57 126.24 4,068.84 2,907.84 S 6,053.64 E -2907.84 0.79 11910.21 89.98 125.51 4,068.39 2,962.76 S 6,129.59 E -2962.76 1.00 12003.64 89.91 125.36 4,068.48 3,016.93 S 6,205.71 E -3016.93 0.18 12096.95 89.86 125.10 4,068.67 3,070.76 S 6,281.93 E -3070.76 0.28 12190.41 88.45 124.57 4,070.05 3,124.14 S 6,358.63 E -3124.14 1.61 12283.86 87.51 124.85 4,073.34 3,177.32 S 6,435.41 E -3177.32 1.05 12377.29 86.80 123.71 4,077.98 3,229.87 S 6,512.51 E -3229.87 1.44 12470.63 87.12 124.52 4,082.93 3,282.15 S 6,589.68 E -3282.15 0.93 12564.07 89.17 124.64 4,085.95 3,335.15 S 6,666.56 E -3335.15 2.20 12657.43 91.23 124.85 4,085.63 3,388.36 S 6,743.27 E -3388.36 2.22 12750.76 90.44 125.04 4,084.27 3,441.81 S 6,819.77 E -3441.81 0.87 12844.12 90.40 124.74 4,083.58 3,495.21 S 6,896.34 E -3495.21 0.32 12937.47 90.32 124.57 4,083.00 3,548.29 S 6,973.13 E -3548.29 0.20 13030.86 90.90 125.20 4,082.00 3,601.70 S 7,049.73 E -3601.70 0.92 13124.14 90.68 125.50 4,080.72 3,655.66 S 7,125.81 E -3655.66 0.40 13217.51 90.42 125.31 4,079.82 3,709.76 S 7,201.91 E -3709.76 0.34 13310.94 90.38 125.30 4,079.17 3,763.75 S 7,278.15 E -3763.75 0.04 13404.36 91.12 125.31 4,077.95 3,817.74 S 7,354.39 E -3817.74 0.79 13497.80 90.24 125.44 4,076.84 3,871.83 S 7,430.57 E -3871.83 0.95 13591.16 90.18 125.44 4,076.49 3,925.96 S 7,506.63 E -3925.96 0.06 13684.55 89.83 125.04 4,076.49 3,979.85 S 7,582.91 E -3979.85 0.57 13777.92 89.30 125.16 4,077.19 4,033.53 S 7,659.30 E -4033.53 0.58 13872.08 92.40 125.52 4,075.80 4,087.98 S 7,736.09 E -4087.98 3.31 13964.84 92.74 123.82 4,071.64 4,140.70 S 7,812.30 E -4140.70 1.87 14058.18 92.10 123.45 4,067.70 4,192.35 S 7,889.94 E -4192.35 0.79 14151.93 90.96 122.72 4,065.19 4,243.51 S 7,968.46 E -4243.51 1.44 14244.59 91.44 123.47 4,063.25 4,294.09 S 8,046.07 E -4294.09 0.96 14338.02 92.62 124.62 4,059.94 4,346.36 S 8,123.43 E -4346.36 1.76 14431.33 90.48 123.95 4,057.42 4,398.90 S 8,200.50 E -4398.90 2.40 14524.77 89.61 124.86 4,057.35 4,451.70 S 8,277.59 E -4451.70 1.35 14618.20 90.49 126.02 4,057.27 4,505.87 S 8,353.71 E -4505.87 1.56 INSITE V8.1.0 Page 4Job No:AK-XX-0901412968 Well Name:SP12-SE3 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14711.58 90.93 126.61 4,056.11 4,561.17 S 8,428.95 E -4561.17 0.79 14804.98 90.78 126.39 4,054.71 4,616.72 S 8,504.02 E -4616.72 0.29 14898.26 90.01 126.33 4,054.07 4,672.02 S 8,579.13 E -4672.02 0.83 14991.63 89.93 125.80 4,054.12 4,726.99 S 8,654.61 E -4726.99 0.57 15085.04 90.12 125.46 4,054.08 4,781.40 S 8,730.53 E -4781.40 0.42 15180.31 89.99 124.92 4,053.99 4,836.30 S 8,808.39 E -4836.30 0.58 15245.00 89.99 124.92 4,054.00 4,873.33 S 8,861.43 E -4873.33 0.00 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (True) - A total correction of 19.26 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 15,245.00 feet is 10,113.08 feet along 118.81 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.0 Page 5Job No:AK-XX-0901412968 Well Name:SP12-SE3 L1 Survey Report
