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Home My WebLink About214-1821. 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, Cleanout 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): 22,454 NA Casing Collapse Conductor NA Surface 2,260psi Intermediate 3,090psi Production Liner Slotted Production Liner Slotted Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Keith Lopez Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388574, ADL0388575, ADL0388577, ADL0391283 214-182 NIKAITCHUQ SP31-W7 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-629-23532-00-00 NIKAITCHUQ Hilcorp Alaska, LLC Length Size Proposed Pools: 3,429 21,889 3,489 975 SCHRADER BLUFF OIL Same 160 160 6.4#, L-80 TVD Burst 11,243 Slotted MD NA Slotted 13,320 5,020psi 5,750psi 2,422 3,503 3,502 2,663 13,320 See Schematic 3,4895-1/2" (mainbore) 160 20" 13-3/8" 9-5/8" 2,663 5-1/2" (L1)9,835 See Schematic 907-777-8438 keith.lopez@hilcorp.com Operations Manager November 26, 2025 2-7/8" Perforation Depth MD (ft): PHL Retrievable and NA 11,356' MD/ 3,263' TVD and NA NA 21,889 22,775 8,724 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:12 am, Oct 20, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.10.17 08:41:46 - 08'00' Sara Hannegan (2519) 325-642 10-404 A.Dewhurst 24OCT25 DSR-10/30/25 * BOPE pressure test to 2500 psi. 48 hour notice to AOGCC for opportunity to witness. MGR29OCT25JLC 10/31/2025 10/31/25 Well: SP31 PTD: 214-182 and 214-203 API: 50-629-23532-00-00 and 06-00 Well Name:SP31-W7 /L1 API Number:50-629-23532-00-00 Current Status:Producer Rig:Team Snubbing 101 Estimated Start Date:11/15/25 Estimated Duration:10 days Regulatory Contact:Darci Horner Permit to Drill Number:214-182 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: 1,300 psi @ 3,256 TVD |7.7 PPGE Max Potential Surface Pressure: 975 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 87° Sail Angle from 3,663 MD to ESP setting depth of 11,300 MD Brief Well Summary: SP31 was drilled and completed as a dual lateral Schrader Bluff Oa sand producer in February 2015. This well has had 4 conventional ESPs with a history of sand production problems causing short run lifes. The current ESP ran for 3.0 years before suffering a shaft part on 10/03/25. A 7 scab liner and a 2-7/8 middle completion was installed in 2022. Objectives: Pull ESP completion, perform wellbore cleanout as necessary, and run new ESP completion. Notes Regarding Wellbore Condition: 9-5/8 casing was tested above the 7 scab liner on 10/08/22 from 11,356 to 1,500 psi for 30 minutes (good test). HWO Conditions Traditional well control approach will be implemented. KWF will be a barrier at all times during HWO operations. No snubbing operations are planned during this work. Team Snubbings 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 65 bbls. b. Annulus volume 768 bbls. c. Monitor OA annulus during kill. 4. Flow check for 30 min to ensure the well is killed. Not to exceed formation fracture pressure at sand face. - mgr Well: SP31 PTD: 214-182 and 214-203 API: 50-629-23532-00-00 and 06-00 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 ESP Contractor 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 2-7/8 ESP completion with shroud and seal assembly laying down. Record number of clamps recovered. 13. PU cleanout assembly and cleanout casing and liner as deep as practical. 14. RIH with ESP completion on 3-1/2 or 4-1/2 tubing to +/- 11,300. a. Check electrical continuity every 1000. b. Note PU and SO weights on tally. 15. Land tubing hanger. Use extra caution to not damage cable. 16. Lay down landing joint. 17. Set BPV/TWC, ND BOP. 18. NU tree and test, pull BPV/TWC. 19. 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) Lubricate if possible stored pressure under BPV. - mgr Nikaitchuq Field Last Completed: Oct 2022 PTD: 214-182 (mainbore), 214-203 (Lateral L1) API #: 50-629-23532-00-00 (mainbore), -60-00 (lateral L1) 20" Casing 20" 13-3/8" Size ID Top 20" Surface TOC est 10,820'13-3/8" 12.415 Surface 9-5/8" 8.835 Surface A 5-1/2" 4.950" 12,940' B 5-1/2" 4.950" 13,165' C 2-7/8"2.441 Surface 2-7/8"2.441 11,319' No Top MD TVD Inc ID D A 11,201' 3,232' 78 2.205 E B 11,252' 3,242' 78 F C 11,286' 3,249' 78 D 11,322' 3,256' 78 G,H E 11,325' 3,257' 79 I F 11,326' 3,257' 79 3.95 G 11,330' 3,258' 79 4.176 H 11,340' 3,260' 79 3.9 I 11,356' 3,263' 79 3.85 J J 11,378' 3,268' 79 3.82 K K 11,379' 3,268' 79 2.42 L 11,446' 3,279' 80 6.18 M 12,951' 3,480' 86 4.95 Schrader Bluff Producer SP31-W7 Schematic Top of 10' Seal Bore, 5" 18# TH521 HAL Ratcheting Muleshoe 4.5" 12.6# BTC Box JEWELRY DETAIL Slotted Production (SP31-W7L1 15.5#, L-80, HYD 521 22,775' Slotted Production (SP31-W7)15.5#, L-80, HYD 521 21,889' 13,335' Driven 160 Wt/ Grade/ Conn 11,243' 16" hole cemeted with Lead: 404 bbls 10.7 ppg ASL Tail: 73 bbls 12.5 CRETE , 93bbls returned to surface Tubing 6.4#, L-80, Tenaris Blue 13,037' 13,320' Top of ESP 4.5" 12.6# VAM GOT 'GXN' Nipple, BHI 4-1/2" 12.6# VT B x 2-7/8" 6.4# L-80 IBT P XO Top of 7" Scab Liner BHI SLZXP LTP/HGR TUBING DETAIL CASING DETAIL Cement Details 68#, L-80, BTC 40#, L-80, HYD 563 Hole MD 2663' 2,677' Intermediate Surface Conductor Type 13-3/8" 12-1/4" hole cemented with Lead: 172.4 bbls 12.5 ppg CRETE Tail: 49.4 bbls 15.8 ppg class 'G'9-5/8" Tubing CEMENT INFORMATION Btm 160 6.4#, L-80, Tenaris Blue Bottom of Shroud 7-5/8" 29.7# VAM FJL Box x 4.5" 12.6# BTC Pin XO Item 'XN' Nipple, SLB 2.313, OSXN 2.205 No-Go Top of Shroud Bottom of ESP HAL PHL Retrievable PKR L N 12,952' 3,480' 86 6.17 O 13,037' 3,485' 86 2.441 P 13,178' 3,494' 86 2-7/8" 6.4# L-80 IBT with 1/2 moon mule shoe MLZXP LTP/HGR Bottom of 7" Scab Liner Replace ESP; Tubing install Event Date Complete Feb 2015 June 2021 Drill and Complete w/ ESP M,N O 13122' - 13139' MD Window Lateral L1 8-3/4" hole TD of 22,795' reached on 2/8/2015 Nose Guide Shoe @ 22,775' MD, 3,501' TVD, 89° Inc Resman Tracers HAL 5-1/2" Oil Swell Packers P 9-5/8" Main Bore 8-3/4" hole TD of 22,454' MD reached on 1/25/2015 Blind Guide Shoe @ 21,889' MD 3,489' TVD, 92° Inc Replace ESP Run Scab; Middle/Upper Completion; Replace ESP Mar 2022 Oct 2022000XN XN SP31-W7 Schematic 10-16-2025 Last edited by: GP 10/16/2025 Nikaitchuq Field Last Completed: Oct 2022 PTD: 214-182 (mainbore), 214-203 (Lateral L1) API #: 50-629-23532-00-00 (mainbore), -60-00 (lateral L1) 20" Casing 20" 13-3/8" Size ID Top 20" Surface TOC est 10,820'13-3/8" 12.415 Surface 9-5/8" 8.835 Surface 5-1/2" 4.950" 12,940' A 5-1/2" 4.950" 13,165' 3-1/2"2.992 Surface 2-7/8"2.441 11,319' No Top MD TVD Inc ID B A ~11,252 3,242' 78 C B ~11,322 3,256' 78 C ~11,325 3,257' 79 D 11,330' 3,258' 79 4.176 D, E E 11,340' 3,260' 79 3.9 F F 11,356' 3,263' 79 3.85 G 11,378' 3,268' 79 3.82 H 11,379' 3,268' 79 2.42 I 11,446' 3,279' 80 6.18 G J 12,951' 3,480' 86 4.95 H K 12,952' 3,480' 86 6.17 L 13,037' 3,485' 86 2.441 M 13,178' 3,494' 86 9.3#, L-80 Item Bottom of ESP Bottom of Shroud Intermediate Surface Conductor Type 13-3/8" 12-1/4" hole cemented with Lead: 172.4 bbls 12.5 ppg CRETE Tail: 49.4 bbls 15.8 ppg class 'G'9-5/8" Tubing CEMENT INFORMATION Btm 160 TUBING DETAIL CASING DETAIL Cement Details 68#, L-80, BTC 40#, L-80, HYD 563 Hole MD 2663' 2,677' HAL PHL Retrievable PKR 4.5" 12.6# VAM GOT 'GXN' Nipple, BHI 4-1/2" 12.6# VT B x 2-7/8" 6.4# L-80 IBT P XO Top of 7" Scab Liner BHI SLZXP LTP/HGR Bottom of 7" Scab Liner 2-7/8" 6.4# L-80 IBT with 1/2 moon mule shoe MLZXP LTP/HGR 16" hole cemeted with Lead: 404 bbls 10.7 ppg ASL Tail: 73 bbls 12.5 CRETE , 93bbls returned to surface Tubing 6.4#, L-80, Tenaris Blue 13,037' 13,320' Top of ESP Schrader Bluff Producer SP31-W7 Proposed Schematic Top of 10' Seal Bore, 5" 18# TH521 HAL Ratcheting Muleshoe 4.5" 12.6# BTC Box JEWELRY DETAIL Slotted Production (SP31-W7L1 15.5#, L-80, HYD 521 22,775' Slotted Production (SP31-W7)15.5#, L-80, HYD 521 21,889' 13,335' Driven 160 Wt/ Grade/ Conn ~11,243 I Event Date Complete Feb 2015 June 2021 Drill and Complete w/ ESP Replace ESP; Tubing install J, K L 13122' - 13139' MD Window Lateral L1 8-3/4" hole TD of 22,795' reached on 2/8/2015 Nose Guide Shoe @ 22,775' MD, 3,501' TVD, 89° Inc M Resman Tracers HAL 5-1/2" Oil Swell Packers 9-5/8" Main Bore 8-3/4" hole TD of 22,454' MD reached on 1/25/2015 Blind Guide Shoe @ 21,889' MD 3,489' TVD, 92° Inc Run Scab; Middle/Upper Completion; Replace ESP Mar 2022Replace ESP Oct 2022000XN SP31-W7 Proposed Schematic 10-16-2025 Last edited by: DH 10/16/2025 TEAM SNUBBINGINTERNATIONALSP-12BOP Stack Drawing54.13"33.8"33.8"24.0"13 5/8"00 PSI Annular5000 PSI Single Gae VBR:2 7/8" - 5 1/2"5000 PSI Single GaeBlinds5000 PSI Flow Cross5000 PSI Riser5013 5/8" 13 5/8" 13 5/8" 13 5/8" 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&RQWLQXHWRFOHDQSLWV5LJJLQJGRZQLQWHUFRQQHFWV2UJDQL]HSDGDQGSUHSDUHSDGLQIURQWRI6,/D\+HUFXOLWHDQGVWDUW OD\LQJPDWWLQJERDUGV 1RWH 0D[*DV 8QLWV KRXU33*.&/1D&OLQKLELWHGEULQHORVVWRKROH EEOV Daily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / 1 Regg, James B (OGC) From:Rig 15 <rig15@doyondrilling.com> Sent:Friday, October 7, 2022 9:15 AM To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC) Cc:Enipetroleum SIDDrilling; Chaudhry Amjad; Enipetroleum AKRigClerksDoyon15 (AKRigClerksDoyon15 @eni.com) Subject:Emailing: Doyon 15 10-7-2022 .xlsx Attachments:Doyon 15 10-7-2022 .xlsx; BOP Test Chart 10-7-2022.pdf; BOP Test Sequence 10-7-2022.pdf 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. Your message is ready to be sent with the following file or link attachments: Doyon 15 10‐7‐2022 .xlsx Note: To protect against computer viruses, e‐mail programs may prevent sending or receiving certain types of file attachments. Check your e‐mail security settings to determine how attachments are handled. Nikaitchuq SI31-W7 PTD 2141820 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:15 DATE:10/7/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2141820 Sundry #322-483 Operation:Drilling:Workover:x Explor.: Test:Initial:Weekly:x Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:650 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 2 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13.625 5K P Pit Level Indicators P P #1 Rams 1 2-7/8"" x 5"P Flow Indicator P P #2 Rams 1 Blind Shear 5K P Meth Gas Detector P P #3 Rams 1 3-1/2" x6"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 3.125 5K P Time/Pressure Test Result HCR Valves 4 3.125 5K P System Pressure (psi)3000 P Kill Line Valves 2 3.125 5K P Pressure After Closure (psi)2250 P Check Valve 0 NA 200 psi Attained (sec)10 P BOP Misc 0 NA Full Pressure Attained (sec)44 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):10 @ 4000 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 12 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 10 P Inside Reel valves 0 NA #3 Rams 9 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10-05-2022 12:47 Waived By Test Start Date/Time:10/7/2022 0:00 (date)(time)Witness Test Finish Date/Time:10/7/2022 5:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Doyon Tested with 2-7/8" and 5" TJ. Tested 1 ea. TT 525 FOSV, 1 ea. TT 525 Dart Valve, 1 ea. 2-7/8" FOSV and 1 ea. 2-7/8" Dart Valve. All tests from primary remote station. Preformed draw down on Super choke and Manual choke to 2000 psi. Torres / Yochum ENI Petroleum Simonson / Dillon / Grubb Nikaitchuq SP31-W7 Test Pressure (psi): SIDDrilling@eni.com rig15@doyondrilling.com Form 10-424 (Revised 08/2022)2022-1007_BOP_Doyon15_Nikaitchuq_SP31-W7          J. Regg; 11/15/2022 BOPE Test - Doyon 15Nikaitchuq SI31-W7PTD 214182010/7/2022J. Regg; 11/15/2022 Nikaitchuq SI31-W7 PTD 2141820 J. Regg; 11/15/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOPE - Doyon 15 Date:Tuesday, November 15, 2022 3:58:55 PM Attachments:2022-1007_BOP_Doyon15_Nikaitchuq_SP31-W7.pdf Nikaitchuq SI31-W7 (PTD 2141820) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 5HJJ-DPHV%2*& )URP5LJULJ#GR\RQGULOOLQJFRP! 6HQW7KXUVGD\2FWREHU30 7R'2$$2*&&3UXGKRH%D\5HJJ-DPHV%2*&%URRNV3KRHEH/2*& &F6,''ULOOLQJ#HQLFRP&KDXGKU\$PMDG(QLSHWUROHXP$.5LJ&OHUNV'R\RQ$.5LJ&OHUNV'R\RQ #HQLFRP 6XEMHFW(PDLOLQJ'R\RQ[OV[ $WWDFKPHQWV'R\RQ[OV[%237HVW6HTXHQFHSGI%237HVW&KDUWSGI hd/KE͗dŚŝƐĞŵĂŝůŽƌŝŐŝŶĂƚĞĚĨƌŽŵŽƵƚƐŝĚĞƚŚĞ^ƚĂƚĞŽĨůĂƐŬĂŵĂŝůƐǇƐƚĞŵ͘ŽŶŽƚĐůŝĐŬůŝŶŬƐŽƌŽƉĞŶĂƚƚĂĐŚŵĞŶƚƐ ƵŶůĞƐƐǇŽƵƌĞĐŽŐŶŝǌĞƚŚĞƐĞŶĚĞƌĂŶĚŬŶŽǁƚŚĞĐŽŶƚĞŶƚŝƐƐĂĨĞ͘ ŚĂŶŐĞĚdŽƉƌĂŵƐĨƌŽŵϮϳͬϴǆϱƚŽϰ͘ϱǆϳƚŽƌƵŶϳΗƐĐĂďůŝŶĞƌ͘WĞƌĨŽƌŵĞĚϯƚĞƐƚ͘dŚĂŶŬƐ sŝĐƚŽƌdŽƌƌĞƐ ZŝŐϭϱdŽŽůWƵƐŚĞƌ ϵϬϳͲϲϴϱͲϬϳϭϲ zŽƵƌŵĞƐƐĂŐĞŝƐƌĞĂĚǇƚŽďĞƐĞŶƚǁŝƚŚƚŚĞĨŽůůŽǁŝŶŐĨŝůĞŽƌůŝŶŬĂƚƚĂĐŚŵĞŶƚƐ͗ ŽǇŽŶϭϱϭϬͲϬϱͲϮϬϮϮ͘ǆůƐǆ EŽƚĞ͗dŽƉƌŽƚĞĐƚĂŐĂŝŶƐƚĐŽŵƉƵƚĞƌǀŝƌƵƐĞƐ͕ĞͲŵĂŝůƉƌŽŐƌĂŵƐŵĂǇƉƌĞǀĞŶƚƐĞŶĚŝŶŐŽƌƌĞĐĞŝǀŝŶŐĐĞƌƚĂŝŶƚǇƉĞƐŽĨĨŝůĞ ĂƚƚĂĐŚŵĞŶƚƐ͘ŚĞĐŬǇŽƵƌĞͲŵĂŝůƐĞĐƵƌŝƚǇƐĞƚƚŝŶŐƐƚŽĚĞƚĞƌŵŝŶĞŚŽǁĂƚƚĂĐŚŵĞŶƚƐĂƌĞŚĂŶĚůĞĚ͘ 1LNDLWFKXT63: 37' ŚĂŶŐĞĚdŽƉƌĂŵƐĨ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:15 DATE: 10/5/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2141820 Sundry #322-483 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: Bi-Weekly: Other: X Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:650 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1NT Permit On Location P Hazard Sec.P Lower Kelly 1NT Standing Order Posted P Misc.NA Ball Type 2NT Test Fluid Water Inside BOP 2NT FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PNT Annular Preventer 1 13.625 5K P Pit Level Indicators PNT #1 Rams 1 4-1/2" x 7"P Flow Indicator PNT #2 Rams 1 Blind Shear 5K NA Meth Gas Detector PNT #3 Rams 1 3-1/2" x6"NT H2S Gas Detector PNT #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 3.125 5K P Time/Pressure Test Result HCR Valves 4 3.125 5K NT System Pressure (psi)3000 NT Kill Line Valves 2 3.125 5K P Pressure After Closure (psi)2200 NT Check Valve 0NA200 psi Attained (sec)10 NT BOP Misc 0NAFull Pressure Attained (sec)47 NT Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:NT Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 4000 NT No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 15 P #1 Rams 8 P Coiled Tubing Only:#2 Rams 0 P Inside Reel valves 0NA #3 Rams 0 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:2.0 HCR Choke 0 NT Repair or replacement of equipment will be made within days. HCR Kill 0 NT Remarks: AOGCC Inspection 24 hr Notice Date/Time Waived By Test Start Date/Time:10/5/2022 13:30 (date) (time)Witness Test Finish Date/Time:10/5/2022 15:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Doyon Tested with 5" and & 7" Test Jt. (Test #1 4.5 x 7 VBR with 5" test Jt,) (Test #2 Annular With Test 7" test Jt.) (Test #3 4.5 x7 VBR with 7" test Jt.) Changed out top set of VBR's to run7" scab Liner. From 2 7/8 x 5 to 4.5 x 7. Torres / Yochum ENI Petroleum Lawrence / Dillon Nikaitchuq SP31-W7 Test Pressure (psi): SIDDrilling@eni.com rig15@doyondrilling.com Form 10-424 (Revised 08/2022) 2022-1005_BOP_Doyon15_ram-change_Nikaitchuq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y Anne Prysunka at 11:50 am, Oct 06, 2022 6)' <HV %U\DQ 0F/HOODQ '65 WR EH FRPELQHG ZLWK IRU 6XQGU\ 2FW %-0 2FWREHUWK *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date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¶ZHUDQOHDN GHWHFWLRQORJV EXWWKHUHVXOWZDVQRWFRQFOXVLYH VR(QLGHFLGHGWRUXQSUHFDXWLRQDU\DVFDEOLQHU WRFRYHUWKHOHDN]RQH7KHSODQLVWRUXQD=;3SDFNHUZLWK´OLQHUDQGZLWKVHDODVVHPEO\DQG VHWWKHSDFNHUDW¶0'DQG´VFDEOLQHUZLWKVHDOVLQWRERWWRP6/=;3DW¶0' :HGRKDYHFHPHQWEHKLQGFDVLQJDWWKLVSDFNHU VHWWLQJGHSWKDVRXUFDOFXODWHG72&ZDV¶ 0'IRUWKLVZHOOWKDQNV 7KHHVWLPDWHGGDWHIRUEHJLQQLQJ WKLVZRUN LV 2FWREHU WK 3OHDVH ILQG DWWDFKHG IRU WKH UHYLHZ RI WKH &RPPLVVLRQ IRUPV DQG VXSSRUWLQJ GRFXPHQWDWLRQ ,I \RXKDYHDQ\TXHVWLRQVRUUHTXLUHIXUWKHULQIRUPDWLRQSOHDVHFRQWDFW $PMDG&KDXGKU\ DW 6LQFHUHO\ 6WHIDQR 3LHUIHOLFL :HOO2SHUDWLRQV 3URMHFW0DQDJHU 6W I 3L I OL L JS JS HVWLPDWHGGDWHIRUEHJLQQLQJ WKLVZRUN LV 2FWREHUWK SSP31-W7 Workover – Summary Page PTD#:214-182 Current Status Well, SP31-W7 is currently being worked over. Scope of Work Scope of this Sundry is to change in approved program in Sundry number 322-483 General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1000 psi (3,503’ TVD) during the time of workover. Wellhead type/pressure rating: Vault PC, MB-247/5000 psi BOP configuration: Annular/VBR/shear rams/VBR TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8” was tested to 3000 psi prior to drill out on January 19, 2015. Well type: Producer Estimated start date: October 5th, 2022 Drilling rig: Doyon Rig 15 Senior Drilling Engineer Amjad Chaudhry Amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations project Manager Stefano Pierfelici Stefano.pierfelici@eni.com Work: 907-865-3320 PProcedure: 1.PU Tie back seal assembly, 7” Scab liner and baker ZXP liner hanger and RIH. 2.RIH to +/- 11,488’ MD and engage seal into bottom SLZXP @12,951’ MD and set ZXP hanger. 3.Purpose of this scab liner is precautionary cover the suspected leak below 11,488’ MD. 4.Continue ESP running completion as per original program. Below the proposed schematic of the well: 5HJJ-DPHV%2*& )URP5LJULJ#GR\RQGULOOLQJFRP! 6HQW6DWXUGD\2FWREHU30 7R'2$$2*&&3UXGKRH%D\5HJJ-DPHV%2*&%URRNV3KRHEH/2*& &F6,''ULOOLQJ#HQLFRP&KDXGKU\$PMDG(QLSHWUROHXP$.5LJ&OHUNV'R\RQ$.5LJ&OHUNV'R\RQ #HQLFRP 6XEMHFW(PDLOLQJ'R\RQ[OV[ $WWDFKPHQWV'R\RQ[OV[63:%237HVWVHTXHQFHSGI63:%237HVWFKDUW SGI63:%237HVWFKDUWSGI hd/KE͗dŚŝƐĞŵĂŝůŽƌŝŐŝŶĂƚĞĚĨƌŽŵŽƵƚƐŝĚĞƚŚĞ^ƚĂƚĞŽĨůĂƐŬĂŵĂŝůƐǇƐƚĞŵ͘ŽŶŽƚĐůŝĐŬůŝŶŬƐŽƌŽƉĞŶĂƚƚĂĐŚŵĞŶƚƐ ƵŶůĞƐƐǇŽƵƌĞĐŽŐŶŝǌĞƚŚĞƐĞŶĚĞƌĂŶĚŬŶŽǁƚŚĞĐŽŶƚĞŶƚŝƐƐĂĨĞ͘ ŽǇŽŶϭϱϭϬͲϬϭͲϮϬϮϮ͘ǆůƐǆ sŝĐƚŽƌdŽƌƌĞƐ ZŝŐϭϱdŽŽůWƵƐŚĞƌ ϵϬϳͲϲϴϱͲϬϳϭϲ EŽƚĞ͗dŽƉƌŽƚĞĐƚĂŐĂŝŶƐƚĐŽŵƉƵƚĞƌǀŝƌƵƐĞƐ͕ĞͲŵĂŝůƉƌŽŐƌĂŵƐŵĂǇƉƌĞǀĞŶƚƐĞŶĚŝŶŐŽƌƌĞĐĞŝǀŝŶŐĐĞƌƚĂŝŶƚǇƉĞƐŽĨĨŝůĞ ĂƚƚĂĐŚŵĞŶƚƐ͘ŚĞĐŬǇŽƵƌĞͲŵĂŝůƐĞĐƵƌŝƚǇƐĞƚƚŝŶŐƐƚŽĚĞƚĞƌŵŝŶĞŚŽǁĂƚƚĂĐŚŵĞŶƚƐĂƌĞŚĂŶĚůĞĚ͘ 1LNDLWFKXT63: 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:15 DATE: 10/1/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2141820 Sundry #322-483 Operation: Drilling: Workover: x Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:650 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 2P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13.625 5K FP Pit Level Indicators PP #1 Rams 1 2-7/8"" x 5"P Flow Indicator PP #2 Rams 1 Blind Shear 5K P Meth Gas Detector PP #3 Rams 1 3-1/2" x6"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 3.125 5K P Time/Pressure Test Result HCR Valves 4 3.125 5K P System Pressure (psi)3000 P Kill Line Valves 2 3.125 5K P Pressure After Closure (psi)2200 P Check Valve 0NA200 psi Attained (sec)10 P BOP Misc 0NAFull Pressure Attained (sec)47 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 4000 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 15 P #1 Rams 8 P Coiled Tubing Only:#2 Rams 8 P Inside Reel valves 0NA #3 Rams 8 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:19.0 HCR Choke 3 P Repair or replacement of equipment will be made within days. HCR Kill 3 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9-28-2022 09:02 Waived By Test Start Date/Time:9/30/2022 13:00 (date) (time)Witness Test Finish Date/Time:10/1/2022 8:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Doyon Tested with 2-7/8" and 5" TJ. Tested 1 ea. TT 525 FOSV, 1 ea. TT 525 Dart Valve, 1 ea. 2-7/8" FOSV and 1 ea. 2-7/8" Dart Valve. All tests from primary remote station. Preformed draw down on Super choke and Manual choke to 2000 psi. Annular failed on 2 7/8" test jt. Changed out the Elment and seals and retested with 2 7/8" and 5" test joint. performed draw down on Accumalator all good. Test from 9-30-22 13:00 to 19:00 6 hrs. Change out annular element and seals To 06:30 11.5 hrs.Retest to 08:00 1.5 hrs. 1-1-22. Torres / Kruger ENI Petroleum Lawrence / Dillon Nikaitchuq SP31-W7 Test Pressure (psi): SIDDrilling@eni.com rig15@doyondrilling.com Form 10-424 (Revised 08/2022) 2022-1001_BOP_Doyon15_Nikaitchuq_SP31-W7 9 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ 7HVWFKDUWVDWWDFKHG FP Annular failed 7HVWFKDUWVDWWDFKHG #01&5FTU%PZPO/JLBJUDIVR41815%- 5(JJ$QQXODU)DLO$QQXODU)DLO #01&5FTU%PZPO/JLBJUDIVR41815%-5HJJ 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW7KXUVGD\6HSWHPEHU30 7R5LJ &F5HJJ-DPHV%2*& 6XEMHFW5('63: $WWDFKPHQWV'R\RQ5HYLVHG[OV[ ZǇĂŶ͕ dŚĞWdηǁĂƐŵŝƐƐŝŶŐĨƌŽŵƚŚŝƐKWƚĞƐƚ͖ϮϭϰϭϴϮϬǁĂƐĂĚĚĞĚĨŽƌE/<^WϯͲtϳ͘WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗ZŝŐϭϱфƌŝŐϭϱΛĚŽǇŽŶĚƌŝůůŝŶŐ͘ĐŽŵх ^ĞŶƚ͗^ĂƚƵƌĚĂǇ͕^ĞƉƚĞŵďĞƌϭϳ͕ϮϬϮϮϭϬ͗ϬϲD dŽ͗KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗ϭϱ^WϯϭͲtϳϵͲϭϲͲϮϮ ƚƚĂĐŚĞĚŝƐKWƚĞƐƚƌĞƉŽƌƚĨŽƌϵͲϭϲͲϮϮ dŚĂŶŬǇŽƵ͘͘ Ryan Pankratz ZŝŐϭϱdŽŽůƉƵƐŚĞƌ ϵϬϳͲϲϴϱͲϬϳϭϲŽĨĨŝĐĞ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 1LNDLWFKXT63: 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:15 DATE: 9/16/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2141820 Sundry #322-483 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:650 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1FP Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 2P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13.625 5K P Pit Level Indicators PP #1 Rams 1 2-7/8"" x 5"P Flow Indicator PP #2 Rams 1 Blind Shear 5K P Meth Gas Detector PP #3 Rams 1 3-1/2" x6"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 3.125 5K P Time/Pressure Test Result HCR Valves 4 3.125 5K P System Pressure (psi)3000 P Kill Line Valves 2 3.125 5K P Pressure After Closure (psi)2100 P Check Valve 0NA200 psi Attained (sec)10 P BOP Misc 0NAFull Pressure Attained (sec)48 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 4100 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 15 P #1 Rams 10 P Coiled Tubing Only:#2 Rams 10 P Inside Reel valves 0NA #3 Rams 10 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:12.5 HCR Choke 3 P Repair or replacement of equipment will be made within days. HCR Kill 3 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9-13-2022 18:54 Waived By Test Start Date/Time:9/16/2022 4:00 (date) (time)Witness Test Finish Date/Time:9/16/2022 16:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Doyon Tested with 2-7/8" and 5" TJ. Tested 1 ea. TT 525 FOSV, 1 ea. TT 525 Dart Valve, 1 ea. 2-7/8" FOSV and 1 ea. 2-7/8" Dart Valve. All tests from primary remote station. Performed draw down on Super choke and Manual choke to 2000 psi. Failure on upper IBOP. Replaced and re-tested- good. Pankratz / Yochum ENI Petroleum Lawrence / Grubb Nikaitchuq SP31-W7 Test Pressure (psi): SIDDrilling@eni.com rig15@doyondrilling.com Form 10-424 (Revised 08/2022) 2022-0916_BOP_Doyon15_Nikaitchuq_SP31-W7 9 9 9 9999 9 9 9 9 9 9 -5HJJ FP By Samantha Carlisle at 9:52 am, Aug 15, 2022 ; %23 WHVW WR SVL 6FKUDGHU %-0 6)' 6)''65 GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.08.23 09:49:11 -08'00' RBDMS JSB 082422 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Friday, October 7, 2022 2:06 PM To:Rig 15 Cc:Regg, James B (OGC) Subject:RE: D15 SP31-W7 9-22-22 Attachments:Doyon 15 09-23-22 Revised.xlsx Ryan, Attached is a revised report adding the PTD # 2141820 for NIK SP31‐W7 and changing the report date to 9/23/22 based on the finish date/time. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Rig 15 <rig15@doyondrilling.com> Sent: Saturday, September 24, 2022 9:57 AM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: D15 SP31‐W7 9‐22‐22 Please see the attached report for our 9‐22‐22 BOP test Thank you.. Ryan Pankratz Rig 15 Toolpusher 907‐685‐0716 office 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. Nikaitchuq SI31-W7 PTD 2141820 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:15 DATE:9/23/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2141820 Sundry #322-483 Operation:Drilling:Workover:x Explor.: Test:Initial:Weekly:x Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:650 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 2 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13.625 5K P Pit Level Indicators P P #1 Rams 1 2-7/8"" x 5"P Flow Indicator P P #2 Rams 1 Blind Shear 5K P Meth Gas Detector P P #3 Rams 1 3-1/2" x6"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 3.125 5K P Time/Pressure Test Result HCR Valves 4 3.125 5K P System Pressure (psi)3000 P Kill Line Valves 2 3.125 5K P Pressure After Closure (psi)2160 P Check Valve 0 NA 200 psi Attained (sec)11 P BOP Misc 0 NA Full Pressure Attained (sec)44 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):10 @ 4000 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 14 P #1 Rams 8 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0 NA #3 Rams 8 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:7.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 3 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9-21-2022 06:01 Waived By Test Start Date/Time:9/22/2022 22:30 (date)(time)Witness Test Finish Date/Time:9/23/2022 5:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Doyon Tested with 2-7/8" and 5" TJ. Tested 1 ea. TT 525 FOSV, 1 ea. TT 525 Dart Valve, 1 ea. 2-7/8" FOSV and 1 ea. 2-7/8" Dart Valve. All tests from primary remote station. Preformed draw down on Super choke and Manual choke to 2000 psi. Pankratz / Smith ENI Petroleum Lawrence / Smith/ Dillon Nikaitchuq SP31-W7 Test Pressure (psi): SIDDrilling@eni.com rig15@doyondrilling.com Form 10-424 (Revised 08/2022)2022-0923_BOP_Doyon15_Nikaitchuq_SI31-W7         J. Regg; 11/15/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Doyon 15 (9-23-2022) Date:Tuesday, November 15, 2022 4:26:54 PM Attachments:2022-0923_BOP_Doyon15_Nikaitchuq_SI31-W7.pdf Nikaitchuq SI31-W7 (PTD 2141820) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage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'ULOOLQJ6XSYVLGGULOOLQJ#HQLFRP (QLUHSUHVHQWDWLYH 0LWFK%LOOLQJWRQ $65&(QHUJ\6HUYLFHV 5LJ&OHUN $.5LJ&OHUNV'R\RQ#HQLFRP 6DIHW\5HSUHVHQWDWLYH 0DUN+XEOHU $65&(QHUJ\6HUYLFHV +6( PDUNKXEOHU#H[WHUQDOHQLFRP 7RRO3XVK 5\DQ3DQNUDW] 'R\RQ'ULOOLQJ 7RRO3XVKHU ULJ#GR\RQGULOOLQJFRP 7RRO3XVK 7HG.UXJHU 'R\RQ'ULOOLQJ 7RXU3XVKHU ULJ#GR\RQGULOOLQJFRP 6DIHW\5HSUHVHQWDWLYH &OLII2ZHQV 'R\RQ'ULOOLQJ +6( FRZHQV#GR\RQGULOOLQJFRP 6DIHW\5HSUHVHQWDWLYH 'DYH6HQD 'R\RQ'ULOOLQJ +6( GVHQD#GR\RQGULOOLQJFRP Last Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________NIKAITCHUQ SP31-W7 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 Tested all Gas Alarms and PVT's Tested with 2 7/8", 4 1/2" and 5" test joints. Primary manual kill valve was greased and passed retest. Accumulator Closer times Annular =12sec, UPR, LPR and Blinds = 8 sec each, 4 each HCR = 2 sec each. Precharge Bottle 36 total, 34 with 1000psi, 1 with 950 psi and 1 with 600 psi. Test Results TEST DATA Rig Rep:V. Torres / A. YochumOperator:Eni US Operating Company Inc.Operator Rep:S. Lawrence / M. Grubb Contractor/Rig No.:Doyon 15 PTD#:2141820 DATE:2/27/2022 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopBDB220228060657 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7 MASP: 650 Sundry No: 322-053 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 2 P FSV Misc 0 NA 15 PNo. 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 blind/shear P #3 Rams 1 3 1/2 x 6 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 2 3 1/8 P HCR Valves 4 3 1/8 P Kill Line Valves 2 3 1/8 FP Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2200 200 PSI Attained P11 Full Pressure Attained P58 Blind Switch Covers:PYES Nitgn. Bottles (avg):P10@3800 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA 9 9 9 9 9 9 9 999 9 9 9 7HVWFKDUWVDWWDFKHGMEU -%5 FP Accumulator Closer times Annular =12sec, UPR, LPR and Blinds = 8 sec each, 4 each HCR = 2 sec each. 'R\RQ1LNDLWFKXT63: 37' -5HJJ $0DQXDONLOOYDOYHIDLO %3DVVMEU 'R\RQ1LNDLWFKXT63: 37' -5HJJ 9 -5HJJ 1 Regg, James B (OGC) From:Rig 15 <rig15@doyondrilling.com> Sent:Sunday, March 6, 2022 7:23 AM To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC) Subject:Doyon 15 3-6-22 Attachments:Doyon 15 3-5-22.xlsx Please see attached report for yesterday’s BOP test Thank you.. Ryan Pankratz Rig 15 Toolpusher 907‐685‐0716 office 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. Nikaitchuq_SP31-W7 PTD 2141820 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor:Rig No.:15 DATE:3/5/22 Rig Rep.:Rig Phone:685-0716 Operator:Op. Phone:685-0715 Rep.:E-Mail Well Name:PTD #2141820 Sundry #322-053 Operation:Drilling:Workover:X Explor.: Test:Initial:Weekly:X Bi-Weekly:Other: Rams:250/3500 Annular:250-3500 Valves:250/3500 MASP:650 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly 1 P PTD On Location P Hazard Sec.P Ball Type 1 P Standing Order Posted P Misc.NA Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13.625 5K P Pit Level Indicators P P #1 Rams 1 2 7/8" X 5"P Flow Indicator P P #2 Rams 1 Blind Shear 5K P Meth Gas Detector P P #3 Rams 1 3-1/2" x 6"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 2 3.125 5K P Inside Reel valves 0 NA HCR Valves 4 3.125 5K FP Kill Line Valves 2 3.125 5K P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2200 P Quantity Test Result 200 psi Attained (sec)10 P No. Valves 15 FP Full Pressure Attained (sec)54 P Manual Chokes 1 P Blind Switch Covers:All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles # & psi (Avg.):10 @ 3800 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures:2 Test Time:5.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/3/22 10:36PM Waived By Test Start Date/Time:3/4/2022 20:30 (date)(time)Witness Test Finish Date/Time:3/5/2022 2:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Doyon Tested with 5" test joints. Tested 1 ea. TT 525 FOSV 1 ea. TT 525 Dart. All tests from primary remote station. Preformed draw down on Super choke and Manual choke to 2500 psi. Test # 2 A Primary Kill HCR failed greased funtioned and retested test # 2 B good test. Test # 7A choke valve # 3 failed greased and retested test # 7B good test PANKRATZ / YOCHUM ENI PETROLEUM LAWRENCE / GRUB Nikaitchuq SP31-W7 Test Pressure (psi): rig15@doyondrilling.com Form 10-424 (Revised 02/2022)2022-0305_BOP_Doyon15_Nikaitchuq_SP31-W7     J. 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Scope of Work Scope of this workover is pull out existing tubing and run new tubing and new ESP. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1000 psi (3,503’ TVD) during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/VBR/shear rams/VBR TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8” was tested to 3000 psi prior to drill out on January 19, 2015. Well type: Producer Estimated start date: February 20th, 2022 Drilling rig: Doyon Rig 15 Senior Drilling Engineer Amjad Chaudhry Amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations project Manager Stefano Pierfelici Stefano.pierfelici@eni.com Work: 907-865-3320 PProcedure: 1.MIRU Doyon Rig 15. 2.Kill well by using 8.6 ppg 3 % KCl kill fluid through tree. 3.Set BPV. ND tree and NU BOP and test as per AOGCC approved Sundry. 4.POOH and lay down tubing and ESP assembly. 5.MU new ESP assembly and RIH to setting depth. 6.Land hanger and test it. 7.Install BPV and nipple down BOP. 8.NU tubing adapter and tree. 9.Pull BPV, install test plug and test tree.(5000 psi test) 10.Freezes protect through tree down IA. 11.RDMO. Below the current schematic of the well: Proposed new completion will be the same and ESP setting depth will be within +/- 100’ of current depth %23 WHVW WR SVL EMP 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Changeout_ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 22,454 feet N/A feet true vertical 3,430 feet N/A feet Effective Depth measured 21,889 feet N/A feet true vertical 3,489 feet N/A feet Perforation depth Measured depth 13,178-22,454 feet True Vertical depth 3,469-3,430 feet Tubing (size, grade, measured and true vertical depth)4.5 L-80 11,240' 3,241 Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 7/28/2021 Contact Phone: Eni US Operating Co. Inc. Stefano Pierfelici Well Operations project Manager Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 WINJ WAG 17.7 Water-Bbl MD 160 2663 310 Oil-Bbl 8629.1 13.375 9.625 measured true vertical Packer 3700 Centerpoint dr Suite 500, Anchorage, AK, 99503 3. Address: SP31-W7 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 503 Gas-Mcf 4. Well Class Before Work: 350 Representative Daily Average Production or Injection Data 345166 Casing Pressure Tubing Pressure ADL 0391283, 0388583,0388574, 0388577, 0388575 142 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-182 50-629-23532-00-00 N/A 5. Permit to Drill Number: Nikaitchuq Scharader Bluff Oil 2. Operator Name measuredPlugs Junk measured Casing Structural 20 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-268 167 Size Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: Liner Length 160 2663 13178 0 8711 0 5.5 13178 0 21889 TVD 160 2422 3469 3489 slotted Burst 5,210 6,890 0 Senior Engineer:Senior Res. Engineer: slotted Collapse 2,480 4,790 0 t Fra O 6. A G L PG , R _ Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 10:00 am, Jul 28, 2021 Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.07.28 09:52:35 -08'00' Stefano Pierfelic i RBDMS HEW 7/28/2021 DSR-7/29/21VTL 8/9/21 SFD 7/28/2021 4-½” 12.6, HYD563 (TK-15 ICP W CB rings) ppfProduction Tubing4-½” x-cplg cable clamps, for ESPPower Cable, (1) 3/8" Chem Inj LineSP31-W7Dual Lateral Producerwith ESP LiftNikaitchuq Field–Spy Island5-½” Silver BulletBlind Guide Shoe21,889' MD, 3,489' TVD92º Inc.As CompletedJuly 10, 2021Resman Oil/WaterTracersInterm. Casing9-5/8", 40#13,320' MD,3,505' TVD87º Inc.13,178' MD, 3,469' TVDBaker MLZXP LinerHanger/Packer andCasing Seal BoreReceptacleSurf. Casing13-3/8", 68 #2,663' MD, 2,422' TVD52º Inc.11,279' MD, 3,249' TVD, 78º Inc–Centrilift Conventioal 67 stage, Flex 27, +20StageGINPSHH, 250 HP MTR 562XP, gas separator 538GSTHVEVX11,249' MD , 3,240' TVD Discharge Gauge Sub12,951' MD, 3,479' TVDBaker SLXP LinerHanger/PackerHAL 5-½” Oil Swell Packer13,122'-13,139' MD,Casing Exit WindowTD 8-¾” 22,454' MD,3,430' TVD97º Inc.5-½” 15.5 ppf SlottedLiner5-½” Silver Bullet Ecc.Nose Guide Shoe22,775' MD, 3,503' TVD89º Inc.TD 8-¾” 22,795' MD,3,503' TVD89º Inc.Item (Upper Lateral) MD (ft)Swell Packer #1 21,619Swell Packer #2 20,615Swell Packer #3 19,713Swell Packer #4 18,436Swell Packer #5 18,075Swell Packer #6 16,032Swell Packer #7 15,790Swell Packer #8 13,182Item (Mainbore) MD (ft)Swell Packer #1 21,828Swell Packer #2 21,066Swell Packer #3 19,759Swell Packer #4 18,352Swell Packer #5 17,773Swell Packer #6 17,380Swell Packer #7 16,319Swell Packer #8 15,808Swell Packer #9 15,496Tracers (Upper Lateral) MD (ft)ROS 1110/RWS 115118,472ROS 1107/RWS 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Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Changeout 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 22,454 3,430 21,889 3,489 650 n/a Casing Collapse Structural Conductor Surface 2,480 Intermediate 4,790 Production Liner slotted Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: June 5th, 2021 21,8898,711 4.5" 3,489 N/A Stefano Pierfelici Well Operations project Manager Perforation Depth MD (ft): 13,178 13,178-22,454 5.5 20 13.375 160 9.62513,178 2,663 5,210 160 2,422 3,469 160 2,663 L80 TVD Burst 11,207 MD 6,890 Length Size SP31-W7 Nikaitchuq Schrouder Bluff Oil n/a PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0391283, 0388583,0388574, 0388577, 0388575 214-182 3700 Centerpoint Drive Suite 500, Anchorage 99503 50-629-23532-00-00 Eni US Operating Co. Inc. slotted Tubing Grade:Tubing MD (ft): 3,469-3,430 N/A Perforation Depth TVD (ft):Tubing Size: Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 COMMISSION USE ONLY Authorized Name: Authorized Title: m n P s 2 6 5 6 t geoueouoeoeoeooeoeoeooeoooeeoooeet Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 05/25/2021 By Samantha Carlisle at 9:19 am, Jun 01, 2021 321-268 Schrader Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.05.25 15:34:00 -08'00' Stefano Pierfelic i X VTL 6/9/21 DLB 06/01/2021 BOP test to 3500 psig Annular preventer test to 2500 psig X 10-404 DSR-6/1/21 X dts 6/9/2021 JLC 6/9/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.09 14:49:18 -08'00' RBDMS HEW 6/10/2021 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com May 25, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SP31-W7 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP31-W7. SP31-W7 was recompleted on Spy Island on February 2015 with a conventional electric submersible pump set at a depth of 11,301’ MD. This ESP producer was completed without a packer. The well was started up for production in February 2015. Plan is to replace existing ESP with an n upsized ESP to increase production The estimated date for beginning this work is June 7th, 2021 Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.05.25 15:34:59 -08'00' Stefano Pierfelic i Plan is to replace existing ESP with an n upsized ESP to increase production Procedure: 1. RU Slickline and pull out shear valve from the GLM @ 2079’and replace it with dummy valve .Pump in bull heading 8.6-ppg NaCl brine through tree. Pump in bull heading 8.6 ppg 3% KCl/NaCl in IA. Ensure well is killed. Set BPV. 2. MIRU Doyon Rig 15. 3. ND tree and NU BOP and test. 4. Remove BPV and Pull tubing to upper GLM. 5. Shear lower GLM valve and pump in bull heading 8.6 ppg 3%KCl/NaCl brine. 6. Pull tubing to lower GLM. Rig up Slickline and pull tubing stop check valve. 7. POOH and lay down ESP assembly. 8. MU new ESP assembly on new tubing and RIH to setting depth. 9. Land hanger, and test it. 10. Install BPV and nipple down BOP. 11. NU tubing adapter and tree. 12. Pull BPV, install test plug and test tree. 13. Circulate Freeze protect through tree down IA. 14. Shut in well. 15. RDMO. 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Q. 0 0 U0 C c G N O a M EQ1 C cn V ti m o J Q }U E M 0 , Q o1 1 ° to a.co 0 _ o co coa N c (0o to 03 SWE CO ' N O E _ w 3 V cp 715 c & U a) A i— p co c C a Q c @ O (6 Z N c C cp 1, t a Q o O c73O E > Q Z ° 2 N -,T, �1 '1 11 co Z m O M Z N Q co V O N 01 CO F , N 1 r VE °a I O a> N W .0 c ' COd N , h re O c H c 1— m Z c as O v O N Q 0 CO2 4 O 0 C cRI V Oa 0 acOH E a E E o E E E O 0a 2 cd a 2 Z U a 0 0 U 0 0 olLe--fez ( 541 1 HALLIBURTON Sperry Drilling o2 ('- 1 5L To: AOGCC 333 West 7th Avenue; Suite 100 Anchorage, AK 99501 Attn: Meridith Guhl 907-793-1235 From: ENI Petroleum 0/0 Sperry Drilling Alaska 301 East 92nd Avenue; Suite 2 Anchorage, AK 99515 Re: ENI Petroleum (SID) North Slope AK Well — SP31-W7 AFE # 6929 AFE # 6930 L1 API: 50-629-23532-00-00 Rig — Doyon 15 Shipment Includes: 1 set of dry samples; Depth 2700'-22450 Depth 13150'-22795' L1 Repe ✓ed By: / eve,"„/(4-6 C Print Name RECEIVED MAY 6 2015 LA Sign Name4eit AOGCC Aare Date Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg .-pe, 3)24�� DATE: 3-13-15 P. I. Supervisor /7 FROM: Bob Noble SUBJECT: No Flow Test Petroleum Inspector Nikaitchuq SP31-W7 ENI PTD 2141820 - 3-13-15: I witnessed a No-Flow test on ENI's Nikaitchuq SP31-W7. This well also has a lateral section SP31-W7L1 (PTD 2142030). I met with ENI lead operator Scott Hime. We went over their test procedure. Scott told me that the ESP pump had been shut down at 8 am 3-12-15 and the well was allowed to bleed down. We then went out to the well and I inspected their rig up. They did not have the IA line connected to flow through the No-Flow meter so I had them rig it up so both the tubing and the IA were going through the No-Flow meter. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 10:45 0 0 0 S/I to start test 11:00 0 0 0 11:30 0.2 0 0 12:00 0.4 0 0 12:30 0.6 0 0 13:00 0.8 0 0 13:30 1 0 0 14:00 1.2 3 0 Opened up 14:02 0 0 0 Well bleed off in 2 min. 1 Pressures are T/IA/OA Summary: The well bled to 0 psi and 0 flow in 2 minutes. I could barely feel a flow on the back of my hand. This well meets the criteria for a no flow determination. Attachments: none 2015-0313_No-Flow Nikaitchuq_SP31-W7_bn.docx Page 1 of I 214182 214203 RECEIVED HALLIBURTON MAR 1 1 2OF L 5 4 9 2 Sperry Drilling .AOGCG 225549 5 4 9 3 25494 To: Alaska Oil and Gas Conversation Commission DATA LOGGED 333 W 7th Ave Suite 100 3 ''t i2015 BENDER Anchorage, AK 99501 Attn: Meredith Guhl From: Sperry Drilling - Alaska Attn: Robert Haverfield 6900 Arctic Blvd. Anchorage, AK 99518 907-273-3559 Office 907-273-3535 Fax Robert.Haverfield@Halliburton.com Re: Eni Petroleum Well — SP31-W7, SP31-W7 L1 , & SP31-W7 L1 PB1 AFE # 6929 Rig — Doyon 15 Spy Island —Nikaitchuq, Alaska Shipment Includes: 1 End of Well Reports 1 Final Data Listing on CD-ROM 1 Sets of Final Logs — for each well contains: • 2" Color Log — Formation Evaluation TVD • 2" Color Log — Formation Evaluation MD • 2" Color Log — Drilling Engineering MD • 2" Color Log — Gas Ratio MD Received By: Print Name o_eAteeet Sign Name Date Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. tt,;tivcv STATE OF ALASKA MAR 0 2 2015 ALAS. OIL AND GAS CONSERVATION COMM. iON WELL COMPLETION OR RECOMPLETION REPORT AN[ C la.Well Status: Oil E , Gas ❑ SPLUG ❑ Other ❑ Abandoned L Suspended iii lb.Well Class: 20AAC 25 105 20AAC 25.110 Development L • Exploratory ❑ GINJ ❑ WNJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5. Date Comp.,Susp.,or 12. Permit to Drill Number: ENI US Operating Co. Inc. . Aband.: •2/17/2015 214-182 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 • 1/1/2015 50-629-23532-00-00' 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 4433.4 FSL 1459.7 FEL S19T14N R9E UM • 1/25/2015 SP31-W7 • Top of Productive Horizon: 8. KB(ft above MSL): 53.6 15. Field/Pool(s): 2481 FSL 5035 FEL 25 T14N R8EUM GL(ft above MSL): 13.08 Nikaitchuq/Schrader Bluff Oil Pool . Total Depth: 9. Plug Back Depth(MD+TVD): 2272 FSL 1184 FEL 22 T14N R8EUM N/A 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: L , Surface: x- 511450.17 y- 6053614.95 Zone- 4 • 22454'MD!3,430'TVD . ADL 391283,388583,388574,388577,388575 TPI: x- 510825.96 y- 6053019.068 Zone- 4 11. SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 496088.09 y- 6051445.49 Zone- 4 N/A ADL 417493 18. Directional Survey: •Yes Li No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 13.1 (ft MSL) 1,819'MD/1,756'TVD 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES/NEU/DEN N/A 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT TOP PULLED 20 178.89 X-65 36.85 160 36.85 160 Driven N/A N/A 13.375 68 L-80 36.85 2663 36.85 2422 16 10.7 ppg :404 bbls N/A 12.5 ppg :73 bbls 9.625 40 L-80 35.53 13320 35.53 3505 12.25 12.5 ppg: 172.4 bbls N/A 15.8 ppg:49.4 bbls 5.5 15.5 L-80 13178 21889 3469 3489 8.75 Slotted Liner N/A 24.Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): _ 4.5 11,328 N/A Slotted Liner COMPLETION L. /337-cY - 224S-4 ' MO I 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ 3808_ - 3y 3o T�'� V IE DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 2/26/2015 E S P Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 2/25/2015 24h Test Period 2495.0 0.0 30.5 128/64 0 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 322 0 psi 24-Hour Rate - 2495.0 0.0 30.5 20.5 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑✓ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. Form 10-407 Revised 10/2012 r L - 7-g 7-icCONTINUED ON REVERSE Submit original only ?Kt\ 71kclir3 RBDMS MAR - 5 2015 0 7/I/(," Gi 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1819 1756 Top Ugnu 2378 2228 Top Lower Ugnu 10225 3073 Top Schrader Bluff 11418 3275 Top N Sand 11820 3348 Top OA Sand 12891 3475 Formation at total depth: OA sand ✓ 22454 3430 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary,Cementing Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Giuseppe Maugeri Email: giuseppe.maugeri@enipetroleum.com Printed Name: Marc Kuck Title: Drilling&Completion Engineering Manager Signature: /O'v Phone: (907)865-3328 Date: 3/2/2015 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 DO _ 00 > L ooEn -Cr) el - oo - c 0) p H 1- I- N co V V Q NN M NNM CO > t •0 C C tr W d ~ o 5M-> — r CO CO -0 M C ._ Cl) CO � N = off, }; I I ' � m � M — vj C ti Q > 2 co 111 I I N _ ; _ r .. . N C Qu; gli ma 'I cn 1. en I Nk, _ 1n ,I I N cCIti z _oZ r rUp U ill =-c 'N N U l a T � E IA Q U .'r NO i + E 2 n CC ilk O Q E U Ri C� - 0 o � 73 .3cji� a) ii I •Nop0 Nr ca U C Y OLLN N 5Y ; I I ETM � co 2 a) m a) `n(Ni _ `"� (n N ++ (1- _1 J a J (� Q N \ d 0.f, 4 C l�rJl (� _ L U O I -c O NLc) M J c U W e m U M N Q �; O �O E Y Q d7 2 _ _ r II: F'� I- 0 al O M c O-U U' Q ❑ W M O p �� en _l CD co o 6 Oa G1 M C - M (N N N W M X V co €13 ++ o a) — Min c Q c . N co CC N 0_ Q H U O Q Q Q O N N o 7 W d C a) co 7:1 �•- II co Q . Q 03 o 2 2 0 m M N N C sP 1 N. 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Daily Report Well Code:28998 Field Name: NIKAITCHUO • APIIUWI:50-629-23532-00-00 2^ Date:12/28/2014 - Report#: 1 I' II page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type ADL 214-182 ENI PETROLEUM _ 100.00 HORIZONTAL _ Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 -2.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 110.0 10.0 Clear WC-8° SSW @ 18 MPH Daily summary operation 24h Summary Prep rig to move,blow down R/D service lines.Move and stage Rockwasher.Move Mats and weld Herculite for Rockwasher and Pump#3.Move and stage Pit Complex.Prep and skid ng floor.Move Sub off SP05-FN7 and stage down pad.Move and set Mats at SP31-W7.Have a safety stand down with all personnel working nights.Discussed the hazards and preparedness for evacuation.Talked about ENI policy on posting and reporting to social media. Operation at 07.00 Move rig to SP31-W7. 24h Forecast Cont.to move rig to SP31-W7. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time _Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 12:00 18:00 6.00 6.00 MOB A 2 P PJSM Prep rig to move,blow down R/D service lines.Move and stage Rockwasher.Move Mats and weld Herculite for Rockwasher and Pump#3.Move and stage Pit Complex. 18:00 23:00 i 5.00 11.00 MOB A 2 P 'PJSA Prep and skid rig floor.Move Sub off SPO5-FN7 and stage down pad.Move and set Mats at SP31-W7. 23:00 00:00 ' 1.00 12.00'MOB A 20 P 'Have a safety stand down with all personnel working nights.Discussed the hazards and preparedness for evacuation. Talked about ENI policy on posting and reporting to social media. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Mike Ross I ENI Senior Drilling Supv 'SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Dulling Supv 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Mats Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15Idoyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) cfli* Eni E&P Division Well Name:ar -W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ • API/UWI:50-629-23532-00-00 2^ Date:12/29/2014 - Report#: 2 II iI page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 -1.67 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 113.0 0.0 Clear WC-16" NW@ 10 MPH Daily summary operation 24h Summary Move Sub,Rockwasher,Pump#3 and Pit Mod.Stage Mat boards to spot Sub over well.Transfer Equip.out of old Well Bay#1 to Well Bay#3.Stage Diverter for installation.Clean up old Herculite and Mat Boards.Skid rig floor and put Diverter in place W/Crain on top of Well Bay#3.Move Pit Mod in place and start rigging up lines.Move Pump#3 in place.Spot Rockwasher.finish rigging up service lines.Spot and rig up support buildings.Spot and rig up driller side and off driller side suitcases.Build berming around ng.R/U brake coolant lines.R/U service lines to Pump#3. Operation at 07.00 Cont.To Rig Up 24h Forecast Cont.to rig up.N/U Diverter Stack.Function and test Diverter stack. Fluid and check all lines.P/U M/U BHA#1.Drill out 20"Conductor and Cont.to P/U BHA#1. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr)-Due(hr) Phase Opr. Act. Plan Oper.Descr. 12:00 -00.00 12.00- 12.00 MOB 'A -2 P PJSM Move Sub,Rockwasher.Pump#3 and Pit Mod.Stage Mat boards to spot Sub over well.Transfer Equip.out of old Well Bay#1 to Well Bay#3.Stage Diverter for installation.Clean up old Herculite and Mat Boards.Skid rig floor and put Diverter in place W/Crain on top of Well Bay#3.Move Pit Mod in place and start rigging up lines.Move Pump#3 in place. • 0000 -12.00 12.00° 24.00 MOB •A °2 P PJSM Finish Spotting Pump#3.Spot Rockwasher,finish rigging up service lines.Spot and rig up support buildings.Spot and rig up driller side and off driller side suitcases.Build berming around rig.R/U brake coolant lines.R/U service lines to Pump#3. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dolling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Dulling Supv 907-685-0715 Eni representative Bemie Leas ENI Rig Clerk akngclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rigs 5@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(MB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) !� Eni E&P Division Well Name:SI-41-W7 Petroleum Co.Inc. Daily Report Well Code:28998 Field Name: NIKAITCHUQ • API/UW:50-629-23532-00-00 2, II� Date:12/30/2014 - Report#: 3 II page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 -1.17 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 112.0 0.0 Overcast WC-30° NE @ 45 MPH Gusts To 53 MPH Daily summary operation 24h Summary Cont.to rig up suit cases.R/D ESP and Cap tube sheaves.Bring surface riser to ng floor.Perform Crown inspection in Derrick.Put landing and steps around the rig.Work on PM's.Start N/U Surface Stack.Set Starter Head and High Press.Riser as per Vetco Grey Rep onsite.Test seals to 500 PSI for 10 Min.Set Surface Stack on riser.SIMOPS W/Crane remove old grating off Dog House roof and bring in new grating.Remove old skid cylinder off sub floor.Finish N/U Diverter Stack.Test lower diverter T Seal to 500 PSI for 10 Min.Finish install on Diverter line to Knife valve.SIMOPS Load Spud Mud onto Pits.Load BHA#1 components into Pipe Shed.M/U Hanger to Landing Joint and dummy run as per Vetco Grey Rep onsite.Energize Accumulator and function test.Perform Diverter test E/5" D.P.Annular closed 29 Sec.Knife valve open 3 Sec.System Press.3,000 PSI,Manifold Press.1,500 PSI,Annular Press.900 PSI.After function System Press.1,800 PSI,Manifold Press.1,400 PSI, Annular Press.900 PSI.200 PSI increase in 33 Sec.Total system recharge 150 Sec.5 bottle Nitrogen average 2.400 PSI.Update Hazard Recognition Work Sheet on Beaver slide Operations.PJSM Process HWDP and Jars.Load BHA#1 tools to rig floor.SIMOPS Prep Gyro Collar,UD X/O's from rig floor for inspection.Wait on weather due to high winds and Phase 2. Operation at 07.00 Wading On Weather.Phase 3 Conditions. 24h Forecast Cont,to wait on weather due to high winds.P/U M/U BHA#1 to clean out 20"Conductor and 140'of new hole.POOH and P/U M/U smart tools.Drill ahead 16"Surface hole as per Schlumberger DD and MWD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.70 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 06:00 6.00 6.00 MOB A 2 P PJSA Cont.to rig up suit cases.R/D ESP and Cap tube sheaves.Bong surface riser to rig floor.Perform Crown inspection in Derrick.Put landing and steps around the rig.Work on PM's. 06:00 12:00 ' 6.00 12.00 MOB E 20 -P PJSA Start N/U Surface Stack.Set Starter Head and High Press.Riser as per Vetco Grey Rep onsite.Test seals to 500 PSI for 10 Min.Set Surface Stack on riser.SIMOPS W/Crane remove old grating off Dog House roof and bring in new grating.Remove old skid cylinder off sub floor. • 12:00 18:00 6.00 18.00 MOB E 20 P PJSM Finish N/U Diverter Stack.Test lower diverter T Seal to X00 PSItrip Min.Finish install on Diverter line to Knife valve.§IMOPS Load Spud Mud onto Pits.Load BHA#1 components into Pipe Shed.M/U Hanger to Landing Joint and dummy run as per Vecto Grey Rep onsite. • 18:00 19:00 1.00 19.00'MOB C 12 P PJSA.Energize Accumulator and function test.Perform Diverter test E/5"D.P.Annular closed 29 Sec.Knife valve open 3 Sec.System Press.3,000 PSI,Manifold Press.1,500 PSI,Annular Press.900 PSI.After function System Press.1,800 PSI, Manifold Press.1,400 PSI,Annular Press.900 PSI.200 PSI increase in 33 Sec.Total system recharge 150 Sec.5 bottle Nitrogen average 2,400 PSI. 19:00 21:00 2.00 21.00 MOB E 20 P Update Hazard Recognition Work Sheet on Beaver slide Operations.PJSM Process HWDP and Jars.Load BHA#1 tools to rig floor.SIMOPS Prep Gyro Collar,L/D X/O's from rig floor for inspection. 21:00 00:00 3.00 24.00 MOB E 22 TWO1 Wait on weather due to high winds and Phase 2. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com -907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) Eni E&P Division Well Name:SP31-W7 l fill* ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUO 2^ Date:1213112014 - Report#: 4 • APIIUWI:50-629-23532-00-00 " n page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(f1.1hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 -0.17 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 112.0 -3.0 Clear WC-30' NE @ 30 MPH Daily summary operation 24h Summary Waiting on weather Phase 3 conditions.PJSA Clean rig,work on PM's.Double check BHA component measurements.Press.test mud line to 3,000 PSI.Work on JSEA.Trouble shoot hydraulic system. Inspect Drawworks chains and sprockets.C/O alignment cylinder accumulator on TDS-8.Service gear reduction on Rotary Table.Attend EM JSHA work shop.Service Man Rider gear reduction.Repair hydraulic leak on TS-8.Inspect Skate and service. Operation at 07.00 P/U M/U BHA#1 24h Forecast Cont.to wait on Phase 3 weather condition.Work on P/U M/U 5"HWDP from Pipe Shed and rack back in Derrick.P/U M/U 16"clean out BHA.POOH and M/U BHA#1.Drill to 300'MD and POOH to P/U smart tools.Cont.to drill 16"Surface. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 8.70 Time Log Start End Cum Time Time _Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00'00 .00'00 24.00 24.00 MOB E 22 U Waiting on weather Phase 3 conditions.PJSA Clean rig,work on PM's.Double check BHA component measurements. Press.test mud line to 3,000 PSI.Work on JSEA.Trouble shoot hydraulic system.Inspect Drawworks chains and sprockets.C/O alignment cylinder accumulator on TDS-8.Service gear reduction on Rotary Table.Attend ENI JSHA work shop.Service Man Rider gear reduction.Repair hydraulic leak on TS-8.Inspect Skate and service. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dolling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) * Eni E&P Division Well Name:Si-.11-W7 Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUO • APIIUWI:50-629-23532-00-00 2^ Date:1/1/2015 - Report#: 5 If II page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name •Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 0.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 682.0 681.7 641.32 4.26 150.5 113.0 -8.0 Clear WC-36° E @ 21 MPH Daily summary operation 24h Summary Weather hold for Phase 3.PJSA P/U M/U 12 joints 5"HWDP,Collars and 5"Jars from Pipe Shed and rack back in Derrick.Flow check lines and connections.Fill 20"Conductor W/32 bbl of Spud Mud. Had leak on air boot,fixed leak.PJSM W/all essential personnel.P/U M/U 16"Bit and Motor W/Schlumberger DD Rep onsite.Establish flow rate @ 450 GPM,350 PSI,35 RPM,TRQ 2K.Tagged up at 98'MD.Clean out 20"Conductor to 160'MD.Pump out to 60'W/350 GPM,35 RPM.TRQ 2K.Rack back 1 stand HWDP W/X/O.P/U M/U NM Stab,X/O,Gyro Pulse,TeleScope,ARC,X/O,NM UBHO and 8"NM Flex.Orient SLB&Gyro W/Reps onsite.Drill F/160'to 203'MD.Drill 16"Surface F/203'to 390'MD.(390'TVD).BROOH F/390'to 110'MD.500 GPM,500 PSI,30 RPM,TRQ 1-2K.P/U M/U remaining BHA#2 components,NMFDC,Saver Sub,Stab and Jars to 343'MD.Wash down F/343'to 390'MD.350 GPM,410 PSI,SLK 90K.Drill 16"Surface F/390'to 682'MD.(682'TVD)600 GPM,860 PSI,40 RPM,WOB 1-12K,TRN 1-4K,TQF 2K,HST 120K,SLK 120K,ROT 120K.Max Gas 0.ADT 4.26,ART 1.9,AST 2.36,Bit Hrs 4.26,Jar Hrs 4.26. Operation at 07.00 Drill 16"Surface @ 962'MD. 24h Forecast Cont.drilling 16"Surface F/682'to TD as per Schlumberger DD,MWD and Gyro Data. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.90 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 DRILL E 20 TWO1 'Weather hold for Phase 3.PJSA P/U M/U 12 joints 5"HWDP,Collars and 5"Jars from Pipe Shed and rack back in Derrick. 04:00 04:30 0.50' 4.50 DRILL E 12 P PJSM Flow check lines and connections.Fill 20"Conductor W/32 bbl of Spud Mud.Had leak on air boot,fixed leak. 04:30 05:30 1.00 5.50 DRILL E 20 P PJSM W/all essential personnel.P/U M/U 16"Bit and Motor W/Schlumberger DD Rep onsite. 05:30 08:00 2.50 8.00 DRILL E 3 P Establish flow rate @ 450 GPM,350 PSI,35 RPM,TRQ 2K.Tagged up at 98'MD.Clean out 20"Conductor to 160'MD. Pump out to 60'W/350 GPM,35 RPM,TRQ 2K.Rack back 1 stand HWDP WI X/O. 08:00 12:00 4.00 12.00'DRILL E 3 P PJSA P/U M/U NM Slab,X/O,Gyro Pulse,TeleScope,ARC,X/O,NM UBHO and 8"NM Flex.Orient SLB&Gyro W/Reps onsite.Drill F/160'to 203'MD 650 GPM,730 PSI,35 RPM.TRO 2K,HST 102K,SLK 105K.ADT.21,Bit Hrs.21,Jar Hrs.21. • 12:00 16:00 ' 4.00 16.00'DRILL E 3 P PJSM Drill 16"Surface F/203'to 390'MD.(390'TVD)530 GPM,550 PSI,40 RPM,TRO 1-2K,WOB 1-10K,HST 90K, SLK 90K,ROT 90K.Max Gas 0.ADT 1.83,ART 1.19,AST 0.64,Bit Hrs 2.04,Jar Hrs 2.04. 16:00 '17:00 1.00 17.00 DRILL E 6 P BROOH F/390'to 110'MD.500 GPM,500 PSI,30 RPM,TRQ 1-2K. 17:00 1730 0.50 17.50 DRILL E 20 P PJSM P/U M/U remaining BHA#2 components,NMFDC,Saver Sub,Stab and Jars to 343'MD. 1730 18:00 0.50 18.00'DRILL E 6 P Wash down F/343'10 390'MD.350 GPM,410 PSI,SLK 90K. 18:00 00:00 ' 6.00 24.00'DRILL E 3 P PJSM Drill 16"Surface F/390'to 682'MD.(682'TVD)600 GPM,860 PSI,40 RPM,WOB 1-12K,TRN 1-4K,TQF 2K,HST 120K,SLK 120K,ROT 120K.Max Gas 0.ADT 2.22,ART.5,AST 1.72,Bit Hrs 4.26,Jar Hrs 4.26. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 V Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dnlling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division Well Nme a :SrJ1-W7 II* ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name: NIKAITCHUO � API/UWI:50-629-23532-00-00 2 n Date:1/2/2015 - Report#: 6 II I' page 1 of 1 Wellbore name: SP31-W7 Well Header PermiVConcession N° Operator ENI Share)%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22.951.0 22,413.32 193.72 115.7 1.83 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,547.0 2,347.7 1.865.00 11.77 158.5 113.0 -5.0 Partly Cloudy WC- SSW @ 5 MPH 16" Daily summary operation 24h Summary Drill 16"Surface F/682'to 2,547'MD.(2,340'TVD)700 GPM.1,540 PSI,40 RPM,WOB 2-28K,TRN 5-6K,TQF 4-5K,HST 152K,SLK 138K,ROT 145K.ECD 10.20 ppg W/9.3 ppg MW.Max Gas 772 units.ADT 11.77,AST 7.97,ART 3.8,Bit Hrs 16.03,Jar Hrs 16.03.Monitor well static. Operation at 07.00 BROOH as per K&M schedule @ 2,380'MD. 24h Forecast Cont.to drill 16"Surface F/2,547'to 2,677'MD.BROOH as per K&M schedule.L/D BHA#2 as per Schlumberger DD and MWD. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 3 P PJSM Drill 16"Surface F/682'to 1,205'MD.(1,194'TVD)600 GPM,1,010 PSI,40 RPM,WOB 10-30K,TRN 1-4K,TQF 1- 2K,HST 130K,SLK 129K,ROT 130K.ECD 10.10 ppg W19.1 ppg MW.Max Gas 0.ADT 3.95,AST 3.16,ART.79,Bit Hrs 8.21,Jar Hrs 8.21.First excepted MWD survey @ 1,070'MD. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 16"Surface F/1,205'to 1,522'MD.(1,488'TVD)650 GPM,1,424 PSI,40 RPM,WOB 10-30K,TRN 4-9K,TQF 2-4K,HST 140K,SLK 133K,ROT 133K.ECD 10.17 ppg W/9.1 ppg MW.Max Gas 28 units.ADT 2.01,AST 1.25,ART.76, Bit Hrs 10.22,Jar Hrs 10.22.Monitor well static. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSM Drill 16"Surface F/1,522'to 2,081'MD.(1,968'TVD)700 GPM,1,420 PSI,40 RPM,WOB 2-20K,TRN 4-5K,TQF 4K,HST 148K,SLK 135K,ROT 141K.ECD 10.10 ppg W/9.3 ppg MW.Max Gas 772 units.ADT 3.35,AST 1.72,ART 1.63.Bit Hrs 13.57,Jar Hrs 13.57.Monitor well static. 18:00 00.00 6.00 24.00 DRILL E 3 P PJSM Drill 16"Surface F/2,081'to 2,547'MD.(2.340'TVD)700 GPM,1,540 PSI,40 RPM,WOB 2-28K,TRN 5-6K.TOP 4- 5K,HST 152K,SLK 138K,ROT 145K.ECD 10.20 ppg W/9.3 ppg MW.Max Gas 332 units.ADT 2.46,AST 1.84,ART 0.62.0d Hrs 16.03,Jar Hrs 16.03.Monitor well static. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.corn 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.corn 907-685-0716 1 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(kKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) • V91* Eni E&P DivisionWell Name: Srs1-W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name: NIKAITCHUO • API(UWI:50-629-23532-00-00 2^ Date:1/3/2015 - Report#: 7 I' Ii II page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..,Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-5V7 ,DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 2.83 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,677.0 2,430.3 130.00 0.71 183.1 111.0 -10.0 Partly Cloudy WC- SW @ 4 MPH 22" Daily summary operation 24h Summary Drill 16"Surface F/2,547'to 2,677'MD.(2,430'ND)700 GPM,1,460 PSI,40 RPM,WOB 2-25K.TRN 5-8K,TQF 4-5K,HST 157K,SLK 135K,ROT 146K.ECD 10.22 ppg W/9.35 ppg MW.Max Gas 177 units.ADT 0.71,AST 0.47,ART 0.24,Bit Hrs 16.74,Jar Hrs 16.74.Monitor well static.BROOH as per K&M BROOH schedule.CBU lx for 1 stand 5"D.P.F/2,677'to 2,550'MD.BROOH W/5"D.P. as per K&M schedule FI 2,550'to 1,700'MD.BROOH W/5"D.P.as per K&M schedule F/1,700'to 345'MD 700 GPM,1,050 PSI,40 RPM.At 345'MD Circ.until Shakers are clean as per K&M Rep onsite.POOH 5"HWDP,Jars and NM Flex Collars on elevators F/345'to 120'MD.Cont.LID BHA#2 components as per Schlumberger DD and MWD onsite.16"Bit Grade 1-1-WT-A-E-In-No-TD.Clean and clear rig floor of all BHA tools and Equip.Monitor well,static.PJSM W/all essential personnel.R/U GBR Volant and Equip.as per GBR Rep onsite.PJSM W/all essential personnel.P/U M/U 13 3/8" L-80,68.0#,BTC Shoe track and Baker Loc to 125'MD.Check Floats,good.RIH F/125'to 202'MD.Cont.RIH 13 3/8"F/202'to 2,585'MD,HST 250K,SLK 180K.Filling every joint and topping off every 10 joints.Wash down F/2.585'to 2,622'MD,1 bpm,180 PSI total of 67 joints picked up.P/U M/U Hanger as per Vetco Grey Rep onsite. Operation at 07.00 Circulate And Condition Hole For Cement Job 24h Forecast M/U Hanger and land @ 2,663'MD.Circ.and condition mud to<18 YP.Perform cement job.R/D cement Equip.N/D Diverter Stack.N/U BOPE, Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dar(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 DRILL E 3 P PJSM Drill 16"Surface F/2.547'to 2.67T MD.(2.430'TVD)700 GPM,1,460 PSI,40 RPM,WOB 2-25K,TRN 5-8K.TQF 4- 5K,HST 157K,SLK 135K,ROT 146K.ECD 10.22 ppg W/9.35 ppg MW.Max Gas 177 units.ADT 0.71.AST 0.47,ART 0.24.Bit Hrs 16.74,Jar Hrs 16.74.Monitor well static. 01 00 02:30 1.50 2.50 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule.CBU lX for 1 stand 5"D.P.F/2,677'to 2,550'MD 850 GPM.1,750 PSI,40- 60 RPM,TQF 5K,HST 156K,SLK 135K.ROT 145K.ECD 10.11 ppg W/9.35 ppg MW. 02:30 06:00 3.50 6.00 DRILL E 6 P PJSA BROOH W/5"D.P.as per K&M schedule F/2,550'to 1,700'MD 850 GPM,1 750 PSI,40-60 RPM,TQF 3-4K,HST 135K,SLK 133K,ROT 140K. 06:00 11:00 5.00 11.00 DRILL E 6 P PJSA BROOH W/5"D.P.as per K&M schedule F/1,700'to 345'MD 700 GPM,1,050 PSI,40 RPM,TQF 3K,HST 108K. SLK 110K,ROT 111K.At 345'MD Circ.until Shakers are clean as per K&M Rep onsite. 11:00 12:00 1.00 12.00 DRILL E 4 P PJSM POOH 5"HWDP.Jars and NM Flex Collars on elevators F/345'to 120'MD.HST 98K,SLK 100K. 12:00 14:00 2.00 14.00 DRILL E 4 P PJSM Cont.LID BHA#2 components as per Schlumberger DD and MWD onsite.16"Bit Grade 1-1-WT-A-E-In-No-TD 14:00 14:30 0.50 14.50 DRILL E 20 P PJSA Clean and clear ng floor of all BHA tools and Equip.Monitor well,static. 14:30 16:00 1.50 16.00 DRILL G 1 P .PJSM W/all essential personnel.R/U GBR Volant and Equip.as per GBR Rep onsite. 16:00 18:00 2.00 18.00 DRILL G 4 P PJSM W/all essential personnel.P/U M/U 13 3/8"L-80,68.09,BTC Shoe track and Baker Loc to 125'MD.Check Floats, good.RIH F/125'to 202'MD.HST 90K,SLK 90K. 18:00 23.30 5.50 23.50 DRILL G 4 P PJSA Cont.RIH 13 3/8"F/202'to 2,585'MD,HST 250K,SLK 180K.Filling every joint and topping off every 10 joints. Wash down F/2,585'to 2,622'MD,1 bpm,180 PSI total of 67 joints picked up. 23.30 00:00 0.50 24.00 DRILL G 4 P PJSA P/U M/U Hanger as per Vetco Grey Rep onsite. Daily Contacts r Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Dolling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson jDoyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2.663,0 1/3/2015 Last Leakoff Test Depth(ftKB) TVD(11KB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) re* Eni E&P DivisionWell Name:Sr-a1-W7 Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ • API/IAM:50-629-23532-00-00 2 Date:1/4/2015 - Report 8 �f h page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N' Operator ENI Share)%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(11KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 3.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature('F) Weather Wind 2,677.0 2,430.3 0.00 113.0 -10.0 Light Snow WC-28' SSW@ 10 MPH Daily summary operation 24h Summary Cont.to M/U 13 3/8"Hanger as per Vetco Grey Rep onsite.Wash down and land Hanger to 2,663'MD W/CO Rep onsite.Break Circ.and stage up pump rate F/1.5 bpm to 6 bpm 220 PSI in.5 bpm increments.Condition mud to<18 YP for cement job as per MI Swaco plan forward.Stop Circ.and R/U cement lines and Equip.PJSM W/all essential personnel.Blow down cement line and fluid pack. Test W/Schlumberger unit to 600 PSI low and 3,500 PSI high.Pump 100 bbl 10.1 ppg Mud Push II,drop bottom plug followed by 404 bbl 10.7 ppg Lead Slurry and 73 bbl 12.5 ppg Tail Slurry.Drop top plug and kick out W/10 bbl H20.Turn over to rig pumps.Pump376 bbl 9.3 ppg Spud Mud.Plug bumped and Press.up to 950 PSI for 5 Min.All charted W/CO Rep onsite.CIP @ 12:00.93 bbl cement was seen at surface.R/D cement Equip and blow down all lines and Equip.R/D GBR Volant tools and Equip.as per GBR Rep Onside.Install Bell Guide and 5"Elevators to TDS-8.R/U X/O and stack washer.Flush stack W/Vetco Grey Rep onsite.Blow down TDS-8.Pull mouse hole.Prep for N/D Diverter Slack.SIMOPS Load Pipe Shed W/5"D.P.and process.Clean Pits.N/D Diverter Stack,High Press.Riser and Diverter Line as per Vetco Grey Rep onsite.SIMOPS Cont.Pit cleaning and loading 5"D.P.Remove Starter Head and prep Well Head for installation for Multi Bowl.Install Multi Bowl. Test Well Head to 2,000 PSI for 10 Min.Install Grey Lock clamps as per Vetco Grey.SIMOPS Cont.D.P.processing and pit cleaning.Install high Press.riser,BOP Stack,Choke and Kill Line,Bell Nipple and Flow Line.SIMOPS Processing D.P.and pit cleaning. Operation at 07.00 P/U M/U 5"D.P.from Pipe Shed and rack back in Derrick. 24h Forecast Finish nipple up BOPE.Finish loading and processing 5"D.P.in Pipe Shed.Finish cleaning pits.P/U M/U 5"D.P.from Pipe Shed and rack back in Derrick.Test BOPE. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00-.00 00.30 0.50 0.50 DRILL G 4 P PJSM Cont.to M/U 13 3/8"Hanger as per Vetco Grey Rep onsite.Wash down and land Hanger to 2,663'MD W/CO Rep onsite. 41 00.30 06.30 6.00 6.50 DRILL H 8 'P PJSA Break Circ.and stage up pump rate F/1.5 bpm to 6 bpm 220 PSI in.5 bpm increments.Condition mud to<18 YP for 4cement job as per MI Swaco plan forward.Stop Circ.and R/U cement lines and Equip. 0630 12.00 5.50 12.00 DRILL H 9 -P PJSM W/all essential personnel.Blow down cement line and fluid pack.Test W/Schlumberger unit to 600 PSI low and 3,500 PSI high.Pump 100 bbl 10.1 ppg Mud Push II,drop bottom plug followed by 404 bbl 10.7 ppg Lead Slurry and 73 bbl ) I 12.5 ppg Tail Slurry.Drop top plug and kick out W/10 bbl H2O.Turn over to rig pumps.Pump376 bbl 9.3 ppg Spud Mud. Plug bumped and Press.up to 950 PSI for 5 Min.All charted W/CO Rep onsite.CIP @ 12:00.93 bbl cement was seen at ( /J I surface. 1 r 12:00 12:30 0.50 12.50 DRILL H 20 'P PJSA R/D cement Equip and blow down all lines and Equip. 12:30 13:30 1.00 13.50 DRILL G 20 -P PJSA R/D GBR Volant tools and Equip,as per GBR Rep Onsite. 13:30 14:00 0.50 14.00 DRILL G 20 'P PJSA Install Bell Guide and 5"Elevators to TDS-8. 14:00 15:30 1.50 15.50 DRILL C 20 'P PJSA R/U X/O and stack washer.Flush stack W/Vetco Grey Rep onsite. 15:30 16:00 0.50 16.00 DRILL E 20 �P PJSA Blow down TDS-8.Pull mouse hole.Prep for N/D Diverter Stack.SIMOPS Load Pipe Shed W/5"D.P.and process. Clean Pits. 16:00 16:00 2.00 18.00 DRILL C 5 'P PJSM N/D Diverter Stack,High Press.Riser and Diverter Line as per Vetco Grey Rep onsite.SIMOPS Cont.Pit cleaning and loading 5"D.P. 18:00 21:00 3.00 21.00 DRILL C 5 'P PJSA Remove Starter Head and prep Well Head for installation for Multi Bowl.Install Multi Bowl.Test Well Head to 2.000 PSI for 10 Min.Install Grey Lock clamps as per Vetco Grey.SIMOPS Cont.D.P.processing and pit cleaning. 21:00 00:00 3.00 24.00 DRILL C 5 'P PJSA Install high Press,riser,BOP Stack,Choke and Kill Line,Bell Nipple and Flow Line.SIMOPS Processing D.P.and pit cleaning. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dolling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondnlling.cow 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) �r� Eni E&P Division Well Name:Sr31-W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name: NIKAITCHUQ • API/UWI:50-629-23532-00-00 2 Date:1/512015 - Report#: 9 �fh page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL214-182 ENI PETROLEUM 100.00 HORIZONTAL _ Rotary Table Elevation(ft) Ground Level(ft) •Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 4.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2.677.0 2,430.3 0.00 118.0 10.0 Overcast WC-7° NW @ 14 MPH Daily summary operation 2411 Summary Cont.N/U BOPE.Install Mouse Hole.Align BOPE Stack,install drip pan drain hose and tighten Choke Line bolls.SIMOPS Cont.loading 5"D.P.in Pipe Shed.L/D 9 joints 5"HWDP F/Derrick.P/U M/U 5"D.P.from Pipe Shed and rack back in Derrick.(total 348 joints)Pull Mouse Hole.Set test plug as per Vetco Grey Rep onsite.R/U test Equip.for BOPE test.Flush and purge all lines and Choke Manifold of air.Test BOPE.Test waived by AOGCC Matt Herrera on 1-3-15.Blow down and R/D test Equip.Pull test plug and install Wear Bushing as per Vetco Grey Rep onsite.(12.3"ID)Flush all lines and test 13 3/8"Csg.to 2,500 PSI for 30 Min W/CO Rep onsite.Pumped 4.7 bbl and bleed back 4.7 bbl.R/D and blow down all lines from Csg.test. Operation at 07.00 RIH W/12.25"BHA#3 W/5"D.P. 24h Forecast PJSM P/U M/U 12.25"BHA#3 as per Schlumberger DD and MWD ensile.RIH W/5"D.P.to plug.Drill out shoe track and 20'of new hole to 2,697'MD.Displace Spud Mud to LSND.Clean surface Equip. and Cut and slip drilling line.Condition mud and perform FIT to 13.0 ppg EMW.Drill ahead. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '02:00 2.00 2.00 DRILL C 5 P PJSM Cont.N/U BOPE.Install Mouse Hole.Align ROPE Stack,install drip pan drain hose and tighten Choke Line bolts. SIMOPS Cont.loading 5"D.P.in Pipe Shed. 02:00 02:30 0.50 2.50 DRILL E 20 P PJSM L/D 9 joints 5"HWDP F/Derrick. 02 Tii 13:30 11.00' 13.50 DRILL E 20 P PJSM P/U M/U 5"D.P.from Pipe Shed and rack back in Derrick.(total 348 joints) 13.30- 14:00 0.50 14.00 DRILL E 20 P PJSA Pull Mouse Hole.Set test plug as per Vetco Grey Rep onsite. 14:00 14:30 0.50 14.50 DRILL C 20 P PJSA R/U test Equip.for BOPE test. 14:30 16:00 1.50 16.00 DRILL C 20 P PJSA Flush and purge all lines and Choke Manifold of air. ,, 16:00 21:00 5.00 21.00 DRILL C 12 P PJSA Test BOPE.Test W/5"test joint.Annular to 250 PSI low and 2,500 PSI high.Choke valves 1-14.Kill and Choke HCR,Mnaual and Demco Kill,Upper and Lower IBOP,Upper and Lower Rams,Blind Rams,4.5"8 5"TIW and Dart valve .� to 250 PSI low and 3,500 PSI high.Manual Choke and Hydraulic Choke to 1,500 PSI.All rig alarms.Flow test Gas Buster 15 bbl to fill.Function test Koomey:Before function System Press.3,00 PSI,Annualar 750 PSI,Manifold 1,500 PSI.After C.i' ' function System 1,450 PSI,Annular 750 PSI,Manifold 1,500 PSI,200 PSI increase in 45 Sec.Full charge 211 Sec.5 bottle average 2,400 PSI.Test waived by AOGCC Matt Herrera on 1-3-15. 21:00 21:30 0.50' 21.50 DRILL C 20 P PJSA Blow down and R/D test Equip. 21:30 22:30 1.00' 22.50 DRILL C 20 P PJSA Pull test plug and install Wear Bushing as per Vetco Grey Rep onsite.(12.3"ID) 22:30 23:30 1.00 23.50 DRILL E 12 P PJSA Flush all lines and teslJ,, 3/8"Coo to 2.500 PSI for 30 Min W/CO Rep onsite.Pumped 4.7 bbl and bleed back 4.7 bbl. '23:30 00:00 0.50 24.00 DRILL E 20 P -PJSA R/D and blow down all lines from Csg.test. Daily Contacts Position Contact Name Company Title E-mail Office Mobile En representative presentative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test bepth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) Eni E&P DivisionWell Name: Srs 1-W7 1111* ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ • API/UWI:50-629-23532-00-00 2^ Date:1/6/2015 - Report#: 10 o II II page 1 of 1 Wellbore name: SP31-W7 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P31-14/7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 5.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 2,881.0 2,537.9 204.00 1.23 165.9 118.0 -16.0 Clear WC-37° E @ 9 MPH Daily summary operation 24h Summary M/U BHA#3 and RIH to FC @ 2575'.DrIg.shoe track and 20'of new hole.Perform FIT to 13.0 ppg EMW.Drill ahead to 2861'MD.. Operation at 07.00 Drilling 12-1/4"hole @ 3,480'MD. 24h Forecast Drill ahead as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.25 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 DRILL E 20 P PJSA Clean and clear rig floor of test equipment.Blow down kill line and place equipment back into service position. Mobilize BHA#3 to rig floor.Load and process 9 5/8"casing. 01:00 04:00 3.00 4.00 DRILL E 4 P PJSA M/U BHA#3 and RIH to 350',100k puw,105k sow. 04:00 06:30 2.50 6.50 DRILL E 4 P PJSA RIH f/350'-2575'.Perform shallow hole test @ 600 qpm,700 psi,148k puw,128k sow,138k rotw.Tag float collar @ 2575'. 06:30 12:00 5.50 12.00 DRILL E 3 P PJSA Set parameters and drill float collar f/2575'-2579'. 12:00 15:30 3.50 15.50 DRILL E 3 P PJSA Cont.to drill out shoe track f/2579'-2677'@ 350-600 qpm,250-740 psi,20-80 rpm,4-9k tq,5-10k wob,145k puw,130k sow,140k rotw. 15:30 16:00 0.50- 16.00 DRILL E 3 P PJSA DrIg.f/2677'-2697'@ 700 gpm,930 psi,5-8k wob,5-10k tq,145k puw,130k sow,140k rotw. 76:00 17:30 1.50' 17.50 DRILL E 7 P PJSA with all personnel and displace spud mud w/50 bbls hi-vis sweep followed w/380 bbls of 9.25 ppg LSND mud @ 9.5 bpm.300 psi/16 bpm,670 psi. 17:30 19:00 1.50 19.00 DRILL E 25 P PJSA Cut and slip 107'of ddg.line and adjust brakes.Cleaning surface equipment. 19:00 20:00 1.00 20.00 DRILL E 7 P PJSA Cont.circulating until mud balanced @ 650 gpm,600 psi. -'; 20:00 21:00 1.00' 21.00 DRILL E 9 P PJSA Perform FIT to 13 ppg EMW w/1.4 bbls pumped and.5 bbls bleed back. I 21:00 21:30 0.50 21.50 DRILL E '12 P PJSA Obtain slow pump rates,#1/#2 @ 30-100,#3 @ 30-80,#1/#2 @ 40-120,#3 @ 40-100 697'MD(2455'TVD) I w/9.25 MW. 21:30 00:00 2.50 24.00 DRILL E 3 P PJSA Drlg.f/2679'-2881'MD(2544'TVD)@ 800 gpm,920 psi,4-10k web,5k tqn,2-5k tqf,149k puw,128k sow.138k rotw,9.93 ECD,Max Gas 102,1.23 ADT/BIT,17.97 Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dolling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 2,663.0 2,421.86 LSND 9.30 466.0 13.00 1,636.0 Eni E&P Division Well Name:Srs1-W7 rif* ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name: NIKAITCHUO • APIIUWI:50-629-23532-00-00 2^n Date:1/712015 - Report#: 11 If II II page 1 of 1 Wellbore name. SP31-W7 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-5V7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 6.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 4,876.0 2,786.5 1.995.00 17.31 115.3 116.0 -11.0 Clear WC-41` ENE @ 19 MPH Daily summary operation 24h Summary Drill 12 1/4"hole f/2881'-4876'MD(2786'TVD). Operation at 07.00 Drilling 12 1/4"hole @ 5,330'MD 24h Forecast Drill ahead as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deser. 00.00 06:00 6.00 6.00"DRILL E 3 P PJSA Ddg.f/2881'-3708'MD(2731'ND)@ 900 gpm,1430 psi,140 rpm,4-10k wob,5-7k tqn,3-5k tqf,140k puw. 128k sow,133k rotw,9.76 ECD,Max Gas 277.4.17 ADT,5.40 Bit.22.14 Jars.SPR @ 3705'MD(2731'TVD)wl 9.2 MW: #1/82 @30-140,@40-180,#3 @30-125,@40-145. 06:00 12:00 6.00 12.00'DRILL E 3 P PJSA Ddg.f/3708'-4063'MD(2745'TVD)@ 900 gpm,1450 psi,160 rpm,4-10k web,6-12k tqn,5-6k tqf,143k puw, 118k sow,133k rotw,9.68 ECD,Max Gas 55,4.30 ADT,9.70 Bit,26.44 Jars. 12'.00 18:00 6.00 18.00'DRILL E 3 P PJSA Drlg.f/4063'-4583'MD(2772'ND)@ 900 gpm,1560 psi,160-180 rpm.4-15k wob,7-8k tqn.5-6k tqf.150k puw,103k sow,132k rotw,9.89 ECD,Max Gas 12,5.4 ADT,15.10 Bit,31.84 Jars. 18.00 00:00 6.00 24.00"DRILL E 3 P PJSA DrIg.1/4583'-4876'MD(2786'TVD)@ 900 gpm,1600 psi,160-180 rpm.4-15k wob,9-10k tqn,4-7k tqf,148k puw,112k sow,133k rotw,9.86 ECD,Max Gas 16,3.44 ADT,18.54 Bit,35.28 Jars.SPR @ 4734'MD(2780'TVD)w/9.2 MW;#1/02 @ 30-200,@ 40-220;83 @ 30-180,@ 40-200. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative 'Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 v Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondrillinq com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak OH Pressure(psi) 2663.0 2,421.86 LSND 9.30 466.0 13.00 1,636.0 Eni E&P Division Well Name: Sr -W7 I rii* EN!Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ •2^ Date:1/8/2015 - Report#: 12 API/UW1.50 629-23532-00-00 II II page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 7.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 7,256.0 2,913.1 2.380.00 18.15 131.1 118.0 0.0 Clear WC-22' ENE @ 18 MPH Daily summary operation 24h Summary Drill 12 1/4"hole f/4876'-7256'MD(2913'TVD). Operation at 07.00 Drilling 12 1/4"hole @ 7536'MD. 24h Forecast Drill ahead as per SLB. Lithology Shows _ - MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00-DRILL E 3 P PJSA DrIg.9 4876'-5481'MD(2820'TVD)@ 900 gpm,1750 psi,160 rpm,8-10k mob,7-8k tqn,4-5k tqf,146k puw. 120k sow,135k rotes.9.94 ECD,Max Gas 18,5.02 ADT.23.56 Bit,40.30 Jars. 06:00 12.00 6.00 12.00 DRILL E 3 P -PJSA DrIg.f/5481'-5756'MD(2834'TVD)@ 900 gpm,1810 psi,160-180 rpm.4-10k wob,8-10k tqn,4-5k tqf,142k puw,119k sow,133k rotw,9.94 ECD,Max Gas 12,4.57 ADT,28.13 Bit,44.87 Jars,SPR @ 5668'MD(2829'TVD)w19.2 MW;#1/#2 @ 30-200,@ 40-240;#3 @ 30-190,@ 40-220. 12:00 18:00 6.00 18.00'DRILL E 3 P PJSA DrIg.f/5756'-6513'MD(2873'TVD)@ 890 gpm,1910 psi,160 rpm,4 14k wob,11-12k tqn.6k tqf,150k puw,112k sow,133k rotw,10.23 ECD,Max Gas 10,4.25 ADT.32.38 Bit,49.12 Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA DrIg.f/6513'-7256'MD(2913'TVD)@ 900 gpm,2110 psi,160 rpm,8-10k wob,10k tqn,5-6k tqf,155k puw,111k sow.137k rotw,10.24 ECD.Max Gas 4,4.31 ADT,36.29 Bit,53.03 Jars.SPR @ 6694'MD(2883'TVD)w/9.25 MW;#1/ #2 @ 30-240,@ 40-280;#3 @ 30-220,@ 40-260. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Dolling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,663.0 2,421.86 LSND 9.30 466.0 13.00 1,636.0 ft* Eni E&P Division Well Name:Si-.51-W71 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name: NIKAITCHUQ • API/UWI:50-629-23532-00-00 2^ Date:1/9/2015 - Report#: 13 I� II page 1 of 1 Wellbore name: SP31-W7 Well Header PermitiConcession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13,10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 8.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(`F) Weather Wind 9,220.0 3,015.5 1,964.00 16.31 120.4 120.0 6.0 Overcast WC-15" W @ 15 MPH Daily summary operation 24h Summary Drill 12 1/4"hole f/7256'-9220'MD(3015'TVD). Operation at 07.00 Drilling 12 1/4"hole @ 9,278'MD 24h Forecast Drill ahead as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9,30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA DrIg.f/7256'-7805'MD(2942'TVD)@ 900 gpm,2210 psi,160 rpm,4-15k wob,10-11k tqn,6-7k tqf,154k puw, 115k sow,135k rotw,10.32 ECD,Max Gas 3,3.22 ADT,39.51 Bit,56.25 Jars.SPR @ 7628'MD(2932'TVD)w/9.35 MW; #1/#2 @ 30-240,@ 40-290;#3 @ 30-220,@ 40-260. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA DrIg.f/7805'-8522'MD(2977'TVD)@ 900 gpm,2170 psi,180 rpm,10-15 wob,9-12k tqn,7k tqf.159k puw,111k sow.135k rotw,10.45 ECD,Max Gas 11,3.81 ADT,43.32 Bit,60.06 Jars. 12:00 18:00 6.00 18.00 DRILL E 3 - P PJSA Ddg.f/8522'-9111'MD(3008'TVD)@ 900 gpm,2200 psi,180 rpm,2-10k web,11-12k tqn,7-Bk tqf,160k puw, 108k sow,138k rotw,10.38 ECD,Max Gas 12,3.95 ADT,47.27 Bit,64.01 Jars.SPR @ 8656'MD(2984'TVD)w/9.4 MW: #1/#2 @ 30-290,@ 40-310;#3 @ 30-280,@ 40-300. 18:00 00:00 6.00 24.00 DRILL E 3 'P PJSA DrIg.f/9111'-9220'MD(3015'TVD)@ 900 gpm,2160 psi,180-200 rpm,2-12k wob,1l k tqn,7k tqf,160k puw, 110k sow,135k rotw,10.25 ECD,Max Gas 7,5.33 ADT,52.6 Bit,69.34 Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI 'Senior Drilling Supv .SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyont5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Mails Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dolling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2 663.0 2.421.86 LSND 9.30 466.0 13.00 1,636.0 1111* Eni E&P Division ,,,i ,,,, ---.,..: 51-..51-W7 a ENI Petroleum Co.Inc. Daily ReportWell Code:28998 Field Name:NIKAITCHUQ • API/UW1:50-629-23532-00-00 2�" ,II Date:111012015 - Report#: 14 page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 9.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,301.0 3019.9 81.00 9.54 8.5 119.0 -10.0 Overcast WC-32' NNE©15 MPH Daily summary operation 24h Summary Drill f/9220'-9301'MD(3019'TVD).BROOH,do to low ROP and metal in cuttings,to check/CO BHA.BROOH to 4084'. Operation at 07.00 BROOH @ 2,836'MD 24h Forecast Cont.to BROOH to 2700'and CBU until clean.POOH and CIO BHA as needed.RIH and perform SHT and cont.to bottom.Set parameters and drill ahead. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00- 6.00 DRILL E 3 P PJSA DrIg.f/9220'-9282'MD(3018'TVD)@ 900 gpm,2120 psi,160-200 rpm.12-14k wob,11k tqn,7k tqf.160k puw. 110k sow,135k rotw,10.18 ECD,Max Gas 6,5.9 ADT,58.5 Bit,75.24 Jars. 0600 09:30 3.50 9.50 DRILL E 3 P PJSA Ddg.f/9282'-9301'MD(3019'TVD)@ 900 qpm,2160 psi,165-200 rpm,12-14k wob,ilk tqn,7k tqf,162k puw, 110k sow,136k rotw,10.18 ECD,Max Gas 4,3.64 ADT,62.14 Bit,78.88 Jars.SPR @ 9301'MD(3019'TVD)w/9.3 MWS. #1/#2 @ 30-270,@ 40-320;#3 @ 30-250,@ 40-300. 09.30 12:00 2.50 12.00 DRILL E 4 TD01 PJSA BROOH f/9301'-8846'@ 900 gpm,2120 psi,120 prm,8-9k tq,160k puw,110k sow,135k rotw,10.15 ECD. 1200 18:00 6.00 18.00 DRILL E 4 TD01 PJSA BROOH f/8846'-6310'@ 900 gpm,1830 psi,120 rpm,5-6k tq,153k puw.110k sow,132k rotes. 18:00 0000 6.00 24.00'DRILL E 4 TD01 PJSA BROOH f/6310'-4084'@ 900 gpm,1680 psi,120 rpm,5k tq,160k puw,108k sow,130k rotw.15 bbls Tourly fluid losses. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.corn 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 2,663.0. 2421.86 LSND 9.30 466.0 13.00 1,636.0 "Ii* Eni E&P Division well Name:Srs l-W7 1 EN!Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ • APIIUW1:50-629-23532-00-00 2^ Date:1/11/2015 - Report#: 15 �f 'I page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 10.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr( Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,301.0 3,019.9 0.00 119.0 -12.0 Clear WC-33` NNE @ 12 MPH Daily summary operation 24h Summary BROOH f/4084'-350'do to swabbing when POOH.L/D BHA#3 and M/U BHA#4 and RIH.C/O worn DP while RIH.Perform SHT and cont.RIH to 7352'. Operation at 07.00 Drilling Ahead as per SLB @ 9.405'MD 24h Forecast Cont.to RIH to 9300'.set parameters and drill ahead as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.35 Time Log Start End Cum Time Time Dur(hr( Dur(hr( Phase Opr. Act. Plan Oper.Descr. 00.00 04:00 4.00 4.00 DRILL E 4 TD01 PJSA BROOH f/4084'-2663'@ 900 gpm,1470 psi,120 rpm.6-7k tq,80 rpm.4k tq w/BHA through casing shoe 2663'- 2590',140k puw,135k sow,138k rotw,10.17 ECD. 04:00 05:00 1.00 5.00 DRILL E 7 TD01 PJSA CBU X 3 @ 950 gpm,1570 psi,120 rpm.4k 1g. 05:00 05:30 0.50 5.50 DRILL E 4 TD01 PJSA POOH f/2590'-2497'.Swabbing. 05:30 07:00 1.50 7.00 DRILL E 4 TD01 PJSA BROOH f/2497'-1843'@ 900 gpm,1370 psi,80 rpm,2.5k tq,130k puw,sow/rotw. 07:00 07:30 0.50 7.50 DRILL E 4 TD01 PJSA POOH f/1843'-1750'.Swabbing. 07:30 09:00 1.50 9.00 DRILL E 4 TD01 PJSA BROOH f/1750'-350'@ 900 gpm,1170 psi,80 rpm,1.5k tq,105k puw/sow/rotw. 09:00 '11:00 2.00 11.00 DRILL E 4 TD01 PJSA POOH stand back jar stand and HWDP.UD BHA#3 as per SLB. 11:00 12:00 1.00 12.00 DRILL E 20 TD01 PJSA Clear and clean ng floor and load BHA#4.19 bbls Toady fluid losses. 12:00 13:00 1.00 13.00 DRILL E 25 TD01 PJSA Service top-dove,blocks,draw works and ST 80.Down load smart tools and load DP in shed. 13.00 15:30 2.50 15.50 DRILL E 4 TD01 PJSA M/U BHA#4 as per SLB and RIH to 351'. 15.30 18:30 3.00 18.50 DRILL E 4 TD01 PJSA RIH C/O wom DP f/351'-1751'(21 total),120k puw,115k sow. 18:30 19:00 0.50 19.00 DRILL E 12 TD01 PJSA Perform shallow hole test @ 670 gpm,740 psi. 19.00 00:00 5.00 24.00 DRILL E 4 TD01 PJSA RIH f/1751'-7352',141k puw,110k sow,fill pipe every 20 stands. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Dnlling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12,415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,663.0 2,421.86 LSND 9.30 466.0 13.00 1,636.0 1"#1 Eni E&P DivisionWell Name:Srs1-W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name: NIKAITCHUQ • API/UW:50-629-23532-00-00 2^n Date:1/12/2015 - Report#: 16 I' II II page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 11.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wed 11,035.0 3,199.7 1.734.00 15.50 111.9 117.0 -15.0 Clear WC-39' NNE @ 15 MPH Daily summary operation Q24h Summary RIH w/BHA#4 to 9220'.Wash down to 9301'.Drill ahead f/9301'-11,035'MD(3199'TVD). Operation at 07.00 Drilling 12 1/4"hole @ 11,469'MD 24h Forecast Drill ahead as per SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 '01:30 1.50 1.50 DRILL E 4 TD01 -PJSA RIH f/7352'-9220'and wash down to 9301'@ 900 gpm,2270 psi,120 rpm,8k tq,155k puw,110k sow,136k rotw. 01:30 06:00 4.50 6.00 DRILL E 3 P 'PJSA Ddg.f/9301'-9684'MD(3039'TVD)@ 1050 gpm,2770 psi,140-180 rpm,2-8k wob,12-13k tqn.8-11k tqf,165k puw,95k sow,137k rotw,10.31 ECD,Max Gas 35,2.8 ADT/Bit.81.68 Jars.SPR @ 9310'MD(3019'TVD)w/9.3 MW, #1/#2 @ 30-280,@ 40-340;#3 @ 30-260,@ 40-310. 0600.•12:00 6,00 12.00 DRILL- E 3 P PJSA Ddg.f/9684'-10,240'MD(3073'TVD)@ 1050 gpm,2940 psi,180 rpm,6-12k wob,11k tqn.8k tqf,162k puw,102k sow.137k rotw,10.38 ECD,Max Gas 23,4.35 ADT.7.15 Bit,86.03 Jars. 12:00 '18.00 6.00 18.00 DRILL E 3 P •PJSA Ddg.1/10,240'-10,605'MD(3116'TVD)@ 1050 gpm,2860 psi,140-180 rpm,2-12k wob,13-15k tqn,8-10k tqf. 180k puw,96k sow,139k rotw,10.27 ECD,Max Gas 21,4.68 ADT,11.83 Bit,90.71 Jars.SPR @ 10.337'MD(3082'TVD) w/9.4 MW;#1/#2 @ 30-300,@ 40-360;#3 @ 30-280,@ 40-300. 100 00'00 6.00 24.00 DRILL E 3 P ' 8. PJSA DrIg.f/10,605'-11,035'MD(3199'11/D)@ 1050 gpm,2900 psi,140-180 rpm,2-12k wob,11-12k tqn,6-7k tqf. 175k puw,110k sow.143k rotw,10.35 ECD.Max Gas 123,3.67 ADT,15.50 Bit,94.38 Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 v Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikof ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dolling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) 'P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,663.0 2,421.86 LSND 9.30 466.0 13.00 1,636.0 IP* Eni E&P Division Well Name:Srs I-W7 ENI Petroleum Co.Inc. Daily Report l Well Code:28998 Field Name:NIKAITCHUQ • API/UW1:50-629-23532-00-00 2^n II Date:1/13/2015 - Report#: 17 I� II page 1 of 1 Wellbore name. SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 5P31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 12.83 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 12,374.0 3,428.3 1,339.00 17.82 75.1 120.0 -21.0 Partly Cloudy WC- NNE @ 15 MPH 45" Daily summary operation 24h Summary Drill 12 1/4"hole 6 11,035'-12,374'MD(3428'TVD). Operation at 07.00 Drilling 12 1/4"hole @ 12,673 24h Forecast Drill ahead as per SLB to an estimated TD of 13,321'. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 6.00 DRILL E 3 P PJSA Ddg.f/11,035'-11,711'MD(3326'TVD)@ 1050 gpm,2950 psi,180 rpm.8-12k wob,13k tqn,7k tqf,175k puw, 112k sow,145k rotw,10.37 ECD,Max Gas 147,3.97 ADT,19.47 Bit.98.35 Jars.SPR @ 11.271'MD(3247'TVD)w/9.3 MW,#1/#2 @ 30-320,@ 40-380,#3 @ 30-310,@ 40-360, 06.00 12:00 6.00 12.00 1 DRILL E 3 P PJSA Ddg.f/11.711'-11,948'MD(3370'TVD)@ 1000/1050 gpm,2730/2960 psi,180 rpm,8-12k wob,12k tqn,8k tqf. 178k puw,112k sow,146k rotw,10.31 ECD,Max Gas 228,3.72 ADT,23.19 Bit,102.07 Jars.13 bbls Tourty fluid losses. 12 00 18:00 6.00 18.00'DRILL E '3 P PJSA Ddg.1/11,948'-12,277'MD(3418'TVD)@ 1050 gpm,2970 psi,180 rpm,2-12k wob,12k tqn,8k tqf,175k puw, 112k sow,148k rotw,10.46 ECD,Max Gas 550,5.24 ADT,28.43 Bit,107.31 Jars.Monitor well-breathing.SPR @ 12,203' MD(3408'TVD)w/9.35 MW;#1/62 @ 30-380,@ 40-400:#3 @ 30-340,@ 40-400. 100 0 .00 6.00 24.00-DRILL E ' 8. 0 3 P PJSA Ddg.f/12,277'-12,374'MD(3428'TVD)@ 975 gpm,2790 psi,180 rpm,10-12k wob,11k tqn,9-10k tqf,175k puw, 112k sow,143k rotw,10.24 ECD,Max Gas 70,4.89 ADT,33.32 84,112.20 Jars.Monitor well-breathing, Daily Contacts Position Contact Name Company Title E-mail Office Mobile Em representative Mike Ross ENI Senior Drilling Supv 'SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 r Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikof ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dnlling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 2.663.0 2,421.86 LSND 9.30 466.0 13.00 1,636.0 Eni E&P DivisionWell Name:Srsl-W7 1 fill* ENI Petroleum Co.Inc. Daily ReportWell Code:28998 Field Name:NIKAITCHUO Date:1/14/2015 - Report#: 18• APIIUW:50 629-23532-00-00 i i l ii page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22.951.0 22,413.32 193.72 115.7 13.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) POB Temperature(°F) Weather Wind 13,335.0 3,506.2 961.00 9.94 96.7 122.0 -10.0 Clear WC-37' NNE @ 25 MPH Daily summary operation 24h Summary Drill 12 1/4"hole f/12,374'-13,335'MD(3504'TVD).Put MWD tools in neutral.BROOH to 11,616'. Operation at 07.00 BROOH @ 10,050'MD 24h Forecast Cont.to BROOH to 2000',POOH L/D BHA#4. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 6.00 DRILL E 3 P PJSA Ddg.f/12,374'-12,812'MD(3467'TVD)@ 1000-1050 gpm,3080-3300 psi.180 rpm,10-12k wob,13k tqn,8-9k tqf,175k puw,110k sow,143k rotw,10.57 ECD.Max Gas 243,4.43 ADT,37.75 Bit,116.63 Jars. 0600 12:00 6.00 12.00 DRILL E 3 P PJSA Drlg.f/12,812'-13,134'MD(3491'TVD)@ 1000 gpm,3140 psi,180 rpm,10-12k wob,12.5k tqn,8-12k tqf,178k puw,105k sow,145k rotw,10.68 ECD,Max Gas 2280.4.45 ADT,42.20 Bit,121.08 Jars.SPR @ 13,134'MD(3491'TVD) w/9.45 MW;#1/#2 @ 30-420,@ 40-460;#3 @ 30-390,@ 40-440. 12:00 13:30 1.50 13,50 DRILL E 3 P PJSA Ddg.f/13,134'-13.335'MD(3504'TVD)@ 1010 gpm,3330 psi,180 rpm,10-12k wob,14k tqn,9-10k tqf,178k puw,110k sow,145k rotw,10.80 ECD,Max Gas 2570,1.06 ADT,43.26 Bit,122.14 Jars, 13:30 14:00 0.50 14.00 DRILL E 12 P PJSA Down Link to put MWD tools in neutral.SPR @ 13,335'MD(3504'TVD)wl 9.5 MW;#1/#2 @ 30-420,@ 40-480. #3 @ 30-400,@ 40-460. 14:00 17:30 3.50 17.50 DRILL E 4 P PJSA BROOH while CBU f/13,335'-13,201'@ 1010 gpm.3350 psi,120 rpm,9-10 tq,175k puw.105k sow,143k rotw. 17:30 00:00 6.50 24.00 DRILL E 4 P PJSA BROOH f/13,201'-11,616'@ 920 gpm,2590 psi,120 rpm,8-9k tq,205k puw,95k sow,141k rotw. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv 'SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jack Kvasnikott ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,663.0 2,421.86 LSND 9.30 466.0 13.00 1,636.0 Ill* Eni E&P Division Well Name:Sr i-W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUO • API/UW1:50-629-23532-00-00 2'f II�, Date:1/15/2015 - Report#: 19 page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-9V7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 14.83 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 13,335.0 3,506.2 0.00 122.0 -7.0 Overcast WC-31° ENE @ 28 MPH Daily summary operation 24h Summary BROOH f/11,616'-1907',POOH 5 stands and monitor well.Dry job and line up on trip tank. Operation at 07.00 Backing out lock down screws on wear ring,prepare to change rams to 9 5/8". 24h Forecast POOH and LD BHA#4.R/U and test BOPE as per AOGCC Regs.R/U and RIH w/9 5/8"casing. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 4 P PJSA BROOH f/11,616'-9190'@ 900 gpm,2240 psi,120 rpm,10k tq,160k puw,98k sow,128k rotw. 06:00 12.00 6.00 12.00 DRILL E '4 P PJSA BROOH f/9190'-6575'@ 900 gpm,1920 psi,120 rpm,8k tq,152k puw,108k sow,132k rotw.52 bbls Toady fluid losses. 12:00 23.00 11.00 23.00 DRILL 'E 4 'P PJSA BROOH f/6575'-1907'@ 900 gpm,1240 psi,120 rpm,4-3k t1q,130k puw.128 sow,133k rotw.Monitor well- Static. 23:00 '23:30 0.50 23.50 DRILL E 4 -P PJSA Blow down top-drive.POOH f/1907'-1471',130k puw.128k sow. 23:30 00:00 0.50 24.00 DRILL 'E 7 P PJSA Pump dry job,B/D top-drive and line upon trip tank. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross 'ENI Senior Drilling Supv -SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher hg15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,663.0 1/3/2015 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak OH Pressure(psi) 2,663.0 2,421.86 LSND 9.30 466.0 13.00 1636.0 Eni E&P Division Well Name:Sr.s-W7 fig* ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name: NIKAITCHUQ • API/UW:50-629-23532-00-00 2^ Date:1/16/2015 - Report#: 20 II II page 1 of 1 Wellbore name: SP31-W7 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) _ _ 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-VV7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 15.83 Daily Information End Depth(kKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13,335.0 3,506.2 0.00 122.0 -6.0 Overcast WC-33 ENE @ 34 MPH Daily summary operation 24h Summary POOH and L/D BHA#4.C/O Upper rams to 9 5/8"and test.R/U and run 9 5/8"40#L80 Hyd 563 casing to 9724'. Operation at 07.00 RIH w/9 5/8"casing @ 11.291'MD 24h Forecast Cont.RIH w/9 5/8"csg.to 13,320'.Fill casing vd LSND mud in calculated intervals,CBU and condition mud for cementing operations. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 00:30 0.50 0.50 DRILL E 4 P PJSA POOH f/1471'-351',105k puw/sow. 00:30 02:30 2.00 2,50 DRILL E 4 P PJSA UD BHA#4. 0230 03:30 1.00 3.50 DRILL E 20 P PJSA Clear and clean rig floor. 03:30 04:00 0.50 4.00 DRILL C 19 P PJSA Pull wear bushing and set lower test plug. 04.00 05:30 1.50 5.50 DRILL C 20 P PJSA C/O upper rams to 9 5/8". 05.30 06:30 1.00 6.50 DRILL C 12 P PJSA R/U and test 9 5/8"rams to 250/3500 psi.R/D testing equipment. 06:30 07:00 0.50 7.00 DRILL C 19 P PJSA Pull test plug and install modified wear bushing. 07:00 09:30 2.50 9.50 DRILL G 20 P PJSA R/U Tesco CRT and equipment.R/U equipment for possible casing collapse. 09:30 12:00 2.50 '12.00 DRILL G 4 P_PJSA M/U 9 5/8"shoe track and test floats.M/U and RIH to 1109'w/9 5/8"40#L80 Hyd 563 casing as per detail.6 bbls Tourly fluid losses. 12:00 0000 12.00 24.00 DRILL G 4 'P PJSA CONT.RIH w/9 5/8"casing to 7873',rotate in to 9724',50 rpm,9-10k tq,83k rotw. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dulling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HOE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ngl 5@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 13,320.0 1/17/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,6630 2,421.86 LSND 9.30 466.0 13.00 1,636.0 1 Eni E&P Division Well Name:Sr -W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUO • API/UWI:50-629-23532-00-00 2^ Date:1/17/2015 - Report#: 21 'f I' page 1 of 1 Wellbore name: SP31-W7 Well Header PermitlConcession N° Operator ENI Share)%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(f1KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22.951.0 22,413.32 193.72 115.7 16.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 13,335.0 3,506.2 0.00 123.0 -8.6 Overcast WC-35' ENE 27 MPH Daily summary operation 24h Summary Run 9 5/8"casing fl 9724'-to TD @ 13,320'.R/D Tesco and equip.Fill 9 5/8"casing w/treated LSND.Break circulation @.5 bpm and stage rates to 7 bpm,560 psi.Load Cmt.plugs,hold Cmt.meeting and blow down cmt.lines. Operation at 07.00 Performing Cement job,currently displacing cement. 24h Forecast Cement 9 5/8"casing inplace as per plan.N/D stack and set emergency slips w/100k over.Cut 9 5/8"csg as per Vetco.N/U stack and test as per Vetco.C/O U.rams to VBR and prepare for BOPE testing. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. _ Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL G 4 P 'PJSA M/U 8 RIH w/9 5/8"casing f/9724'-13,320'(TD)@ 50 rpm,1l k tq,78k rotw. 06:00 07:00 1.00 7.00 DRILL G '20 P PJSA R/D Tesco CRT and equipment.install casing bails and 150 ton elevators.M/U Cmt.head and fill up/bleed off lines. • 0700 '12:00 5.00 12.00 DRILL G '7 P PJSA Fill 9 5f'casing as per well plan @ 4 bpm,50 psi bleeding off air.Totals;500/750/902 bbls. 7 bbls Tourly fluid losses. 12:00 13:30 1.50 13.50 DRILL G -.7 P 'PJSA Cont.filling 9 5/8"casing @ 4 bpm until full @ 1008 bbls.R/D filling equipment and R/U circulating/cementing equipment. 13:30 '23:00 9.50' 23.00 DRILL G 7 P PJSA Establish circulation @.5 bpm,420 psi and stage pumps to 7 bpm,560 psi. 23:00 '00:00 1.00 24.00 DRILL H 20 P "PJSA Load cement plugs in head,hold PJSA meeting for cementing.blow down cement line. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv .SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.cum 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Can.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 13.320.0 1/17/2015 Last Leakoff Test Depth(ftKB) TVD(11KB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,663.0 2,421.86 LSND 9.30 466.0 13.00 1,636.0 ` If* Eni E&P DivisionWell Name:Sr, -W7 ENI Petroleum Co.Inc. Daily RepoWell Code:28998 Field Name:NIKAITCHUO • API/UWI:50-629-23532-00-00 2^ Date:1/18/2015 - Report#: 22 'f (I page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(it) Ground Level(ft) Water Depth(ft) RKB-Base Flange(it) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22.951.0 22,413.32 193.72 115.7 17.83 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13,335.0 3.506.2 0.00 118.0 -10.4 Overcast WC-28` E @ 11 MPH Daily summary operation 24h Summary PT Cmt.lines and pump lead and tail cmt and displace w/rig pumps.Did not bump plug,floats held,CIP @ 0500 hrs.Perform injectivity test w/20 bbls mud.N/D and raise stack and set emergency slip w/100k over pull. Cut 9 5/8"csg.install pack off and m/u multi-bowl and N/U BOPE.FP IA w/160 bbls of diesel.N/U BOPE and testing as per AOGCC specs.Jeff Jones waived witness. Operation at 07.00 Picking up 4 1/2"DP 24h Forecast Complete BOPE testing and clenup area.P/U 8 M/U 4.5"DP and rack back in derrick. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.35 Time Log Start End Cum -2`" Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. _ 00:00 05:00 5.00 5.00 DRILL H 7 P PJSA Meeting held with all personnel.SLB pump 10 bbls of FW 8 PT to 1500/3500 psi.Rig pumped 100 bbls 10.5 ppg r MudPush @ 5 bpm,400 psi,drop Btm Plug and SLB pump 172.4 bbls 12.5 ppg Lead Cmt.@ 4 bpm,240 psi followed w/ 49.4 bbls 15.8 ppg Tail Cmt.@ 36 bpm,drop Top Plug and kick out w/10 bbls FW.Rig displace Cmt,w/996.8 bbls of Treated LSND @ 7 bpm/200 psi to 2 bpm/440 psi.Pumped calculated volume plus 1/2 shoe track and di¢not bump plug. Held psi for 5 mins.Floats held.CIP @ 0500 hrs. 05:00 05:30 0.50 5.50 DRILL H 9 P PJSA Perform injectivity test on IA w/20 bbls of diesel @ 1.5 bpm,620 psi. 05:30 06:30 1.00 6.50 DRILL H 20 P PJSA B/D&R/D Cmt.head and assy.C/O bails and install 5"elevators. 06:30 07:30 1.00 7.50 DRILL C 20 P PJSA M/U stand of 5"DP w1 pup and FOSV.RI casing to purge fluid for casing cut. 0770 09:00 1.50 9.00 DRILL C 20 P PJSA N/D stack components and raise/position stack for casing cut. 09:00 14:30 5.50 14.50 DRILL C 19 P PJSA Vetco install emergency slips on 9 5/8"casing and set slips w/100k over pull.Vetco cut 9 5/8"casing and prepto set packoff. 14:30 16:00 1.50 16.00 DRILL C 12 P PJSA Lower BOP's and M/U Multi-bowl to casing spool.Test pack off to 2742 psi for 10 min. 16:00 18:30 2.50 18.50 DRILL C 19 P PJSA N/U BOPE.Sim Ops;Freeze protect IA w/160 bbls diesel @ 1/2 bpm'200 psi to 1.5 bpnV 1000 psi. 18:30 20:30 2.00 20.50 DRILL C 20 P PJSA C/O top rams to VBR. 20:30 21:00 0.50 21.00 DRILL C 19 P PJSA Set Vetco test plug. 21:00 22:00 1.00 22.00 DRILL C 20 P PJSA R/U to test BOPE. 22:00 00:00 2.00 24.00 DRILL C 12 P PJSA Testing BOPE as per AOGCC specs w%4.5"Test jt.Witness waived by Jeff Jones. Daily Contacts Position Contact Name Company Title _ Email Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 13,320.0 1/17/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2663.0 2,421.86 LSND 9.30 466.0 13.00 1,6360 Eni E&P Division Well Name:Si -W7 rifill* ENI Petroleum Co.Inc. Daily Report` Well Code:28998 Field Name:NIKAITCHUQ • APIIUWI:50-629-23532-00-00 2^ Date:1/1912015 - Report#: 23 'I I' page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N` Operator ENI Share(%) Well Configuration type ADL 214-182 _ ENI PETROLEUM 100.00 HORIZONTAL • Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 18.83 Daily Information End Depth(ftKB) End Depth(TVD)(f..tDepth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) POB Temperature('F) Weather Wind 13,335.0 3,506.2 0.00 118.0 -14.0 Clear WC-39` ENE @ 17 MPH Daily summary operation 24h Summary Complete BOPE testing,M/U and RIH w/4.5"DP.POOH rack 4.5"DP in derrick.Perform 9 5/8"csg test to 3000 psi.C/O saver sub and service rig.M/U BHA#5 and single in hole to 2170'.SHT @ 1501'. Operation at 07.00 Singling 4 1/2"DP in hole W/BHA#5 @ 5,280'MD 24h Forecast RIH to FC @ 13,235'.Displace LSND w/9.2 ppg FazePro.Cut&slip drill line while cleaning surface mud equipment.Drill shoe track and 20'of new hole.CBU and perform FIT/LOT.Drill ahead. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 02:30 2.50 2.50 DRILL C 12 P PJSA Complete BOPE testing w/5.5"test jt. 02.30 03:30 1.00 3.50 DRILL C 20 P PJSA B/D&R/D testing equipment,Vetco pull test plug and install 9"wear bushing. 03.30 04:00 0.50 4.00 DRILL E 20 P PJSA CIO handling equipment to 4.5",inspect saver sub and install bell guide on top-drive. 04:00 08:30 4.50 8.50 DRILL E 4 P PJSA M/U mule shoe and XO's and M/U 4.5"OP and RIH to 3795'.13Dk puw,110k sow.Sim Ops;Clean pits and bring on 400 bbls OBM,C/O augar bearing and pump#1 liners to 6". 08:30 10:30 2.00 10.50 DRILL E 4 P PJSA POOH w/4.5"DP and rack in derrick. C,4".' 10:30 12:00 1.50 12.00 DRILL E 12 P PJSA RIU and test 9 518"casing to 3000 psi f/30 charted min. 1 12:00 13.00 1.00 13.00 DRILL E 20 P PJSA B/D&R/D from test.Load BHA#5 to rig floor. ..Pr 13:00 16.00 3.00 16.00 DRILL E 25 P PJSA C/O saver sub and service ng. 1 16:00 20:00 4.00 20.00 DRILL E 4 P PJSA M/U BHA#5 as per SLB to 100'.Hold PJSA and load Nukes,RIH to 363'. 20:00 00.00 4.00 24.00 DRILL E 4 P PJSA Single in hole w/4.5"DP f/363'-1501'.Perform SHT @ 440 gpm,720 psi.Cont.In hole to 2170',128k puw 122k sow. Daily Contacts Position Contact Name Company Title E-mail Office Mobile En:representative Mike Ross -ENI Senior Drilling Supv IISIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Andrea Lazzan ENI Drilling Eng. Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jack Kvasnikoff ENI HOE 907-685-0721 907-398-8770 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(f1KB) Run Date CASING 95/8 8.835 L-80 0.0 13,320.0 1/17/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 13.355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2.376.2 Eni E&P Division Well Name:Sra i-W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ VI* • API/UWI:50-629-23532-00-00 2�, Date:1/20/2015 - Report#: 24 II II ii page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 ,LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 19.83 Daily Information End Depth(ftKB) End Depth(TVD((f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13,335.0 3,506.2 0.00 120.0 -4.0 Cloudy WC-22' NNE @ 13 MPH Daily summary operation 24h Summary RIH F/2,170'to 7,007'MD W/4.5"D.P.F/Pipe Shed.Filling D.P.every 2.000'.Wash down F/7,007'to 10,710'MD.50 RPM,TRQ 16K,220 GPM,800 PSI.HST 200K,ROT 132K.C/O Handling Equip. to 5"and M/U X/O.Cont.wash in hole W/5"D.P.F/Derrick F/10,710'to 13,046'MD 50 RPM.TRQ 16K.Wash down to top of cement @ 13.148'MD 350 GPM,1,400 PSI,50 RPM,TRQ 16K.Clean out Shoe Track F/13,148'to F.C.@ 13,234'MD 350 GPM,1,600 PSI,70 RPM,TRO 18K,WOB 10-12K.SIMOPS displace LSND to new 9.2 ppg Faze Pro.Pumped 50 bbl Hi Vis Spacer,35 bbl LVT Spacer and 928 bbl 9.2 ppg Faze Pro.Drill Shoe Track to 13.300'MD during displacement.Clean surface Equip.from displacement.SIMOPS Inspect and service TDS-8,Block and Hook. Cut and slip drilling line,service and inspect Drawworks and Crown.Drill out Shoe Track F/13,300'to Shoe @ 13,320'MD 465 GPM,2,450 PSI,70 RPM,TRQ 15K,WOB 3-8K.Drill 20'of new hole to 13,355'MD.BROOH to 13,320'MD HST 195K,ROT 140K,TRQ 10K.R/U test Equip.Perform FIT Press.up to 700 PSI @.5 bpm.3 bbl pumped and 3 bbl bleed back.FIT 13.0 ppg EMW.Blow down and R/D test Equip. Operation at 07.00 Drill 8.75"Production hole @ 13,560'MD. 24h Forecast Drill ahead 8.75"Production hole F/13,355'to 22,951'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 0530 5.50 5.50 DRILL E 4 -P PJSA RIH F/2,170'to 6,910'MD W/4.5"D.P.F/Pipe Shed.Filling D.P.every 2,000'. . 05:30 710.30 5.00 10.50 DRILL 'E 4 P PJSA Cont.RIH F/6,910'to 7,007'MD.Wash down F/7,007'to 10,710'MD.50 RPM,TRO 16K,220 GPM,800 PSI.HST - 200K,ROT 132K.C/O Handling Equip.to 5"and M/U X/O. -' 10:30 14.00 3.50 14.00 DRILL E 4 P PJSA Cont.wash in hole W/5"D.P.F/Derrick F/10,710'to 13,046'MD 50 RPM,TRQ 16K.Wash down to top of cement @ 13 148'MD 350 GPM 1.400 PSI,50 RPM,TRQ 16K. 14:00 718.00 4.00 18.00 DRILL E 9 P PJSM Clean out Shoe Track F/13,148'to F.C.@ 13,234'MD 350 GPM.1,600 PSI.70 RPM,TRQ 18K,WOB 10-12K. SIMOPS displace LSND to new 9.2 ppg Faze Pro.Pumped 50 bbl Hi Vis Spacer,35 bbl LVT Spacer and 928 bbl 9.2 ppg Faze Pro.Drill Shoe Track to 13,300'MD during displacement. 18:00 719.00 1.00 19.00 DRILL E 20 ''P PJSA Clean surface Equip.from displacement.SIMOPS Inspect and service TDS-8,Block and Hook. 1900 '20.30 1.50 20.50 DRILL E 25 -P PJSA Cut and slip drilling line,service and inspect Drawworks and Crown. 20:30 22.00 1.50 22.00 DRILL E 3 'P PJSA Drill out Shoe Track F/13,300'to Shoe @ 13,320'MD 465 GPM,2,450 PSI,70 RPM,TRO 15K,WOB 3-8K.Drill 20' of new hole to 13,355'MD.BROOH to 13,320'MD HST 195K,ROT 140K,TRQ 10K. 2200 '00.00 2.00 24.00 DRILL E 11 7P PJSM R/U test Equip.Perform FIT Press.up to 700 PSI @.5 bpm.3 bbl pumped and 3 bbl bleed back.FIT 13.0 ppg ` EMW.Blow down and R/D test Equip. --....° Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com '907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supe 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 13,320.0 1/17/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 13,355.0 3,507.18 FAZE PRO 9.20 7000 13.04 2.376.2 YIP* Eni E&P DivisionWell Name:Sri-W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ • APIIUWI:50-629-23532-00-00 anIIDate:1/21/2015 - Report#: 25 'f I' page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 5P31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 20.83 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 14,995.0 3,520.9 1.660.00 15.01 110.6 124.0 -7.0 Partly Cloudy WC- E @ 4 MPH 17" Daily summary operation 24h Summary Drill 8.75"Production F/13,355'to 14,995'MD(3,519'TVD)465 GPM,2,390 PSI,160-180 RPM,TON 17K,TQF 10K,WOB 2-14K,HST 190K,SLK 85K,ROT 140K,ECD 10.8 ppg W/9.25 ppg MW.Max Gas 1,098 units.ADT 15.01,Bit Hrs 15.01,Jar Hrs 15.01.Monitor well,static. Operation at 07.00 Drill 8.75"Production hole @ 15,096'MD. 24h Forecast Drill ahead 8.75"Production hole F/14,995'to 22,951'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time _ Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL IE 3 P PJSA Drill 8.75"Production F/13,355'to 13,698'MD(3,516'TVD)465 GPM,2,400 PSI,80-140 RPM,TON 14-15K,TQF 10K,WOB 6-10K,HST 190K,SLK 141K,ROT 141K,ECD 10.73 ppg W/9.2 ppg MW.Max Gas 341 units.ADT 3.53,Bit Hrs 3.53,Jar Hrs 3.53.Monitor well,static. 06:00 '12:00 6.00 12.00 DRILL E 3 P 'PJSA Drill 8.75"Production F/13,698'to 14,164'MD(3,515'TVD)465 GPM,2,480 PSI,140-170 RPM,TQN 15-18K,TQF 10K,WOB 2-10K,HST 190K,SLK 85K,ROT 139K.ECD 10.96 ppg W/9.25 ppg MW.Max Gas 931 units.ADT 4.14,Bit Hrs 7.67,Jar Hrs 7.67.Monitor well,static. SPR @ 14,164'MD(3,515'TVD)W/9.25 ppg MW MP#3 20-260,30-340 1200 18:00 6.00 18.00'DRILL I.E 3 I P PJSA Drill 8.75"Production F/14,164'to 14,492'MD(3,516'TVD)465 GPM,2,370 PSI,160-180 RPM,TON 16K,TQF 12K,WOB 2-12K,HST 192K,SLK 85K,ROT 140K,ECD 10.74 ppg W/9.25 ppg MW.Max Gas 1,098 units.ADT 3.84,Bit Hrs 11.51,Jar Hrs 11.51.Monitor well,static. 18:00 -00:00 6.00 24.00 DRILL E '3 P PJSA Drill 8.75"Production F/14,492'to 14,995'MD(3,519'TVD)465 GPM,2,390 PSI,160-180 RPM,TQN 17K,TQF 10K,WOB 2-14K,HST 190K,SLK 85K,ROT 140K,ECD 10.8 ppg W/9.25 ppg MW.Max Gas 1,039 units.ADT 3.5,Bit Hrs 15.01,Jar Hrs 15.01.Monitor well,static. SPR @ 14,910'MD(3,524'TVD)W/9.2 ppg MW MP#3 20-300,30-380 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 13,320.0 1/17/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 13,355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2,376.2 J Eni E&P Division Well Name: Sr.c1-W7 ENI Petroleum Co.Inc. Daily ReportWell Code:28998 Field Name: NIKAITCHUQ •2,�n �l, DIIate:1/22/2015 - Report#: 26 API/UWI 50 629-23532-00-00 page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13,10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 21.83 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 16,869.0 3,488.8 1,874.00 16.21 115.6 127.0 -17.0 Overcast WC-41° SW @ 13 MPH Daily summary operation 24h Summary Drill 8.75"Production F/14,995'to 16,869'MD(3,487'TVD)465 GPM,2,500 PSI,160 RPM,TON 18K.TOF 13K,WOB 2-10K,HST 205K,SLK 85K,ROT 139K,ECD 11.15 ppg W1 9.25 ppg MW.Max Gas 968 units.ADT 16.21,Bit Hrs 31.22,Jar Hrs 31.22.Monitor well,static. Operation at 07.00 Drill 8.75"Production hole @ 17,394'MD. 24h Forecast Drill ahead 8.75"Production hole F/16,869'to 22,951'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum ' Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 'P PJSA Drill 8.75"Production F/14,995'to 15,284'MD(3,508'TVD)465 GPM,2,400 PSI,160-180 RPM,TON 17K,TOF 12K,WOB 2-10K,HST 198K,SLK 85K,ROT 130K.ECD 10.96 ppg W/9.3 ppg MW.Max Gas 934 units.ADT 5.29,Bit Hrs 20.30,Jar Hrs 20.30.Monitor well,static. 06:00 '12:00 6.00 12.00'DRILL E 3 'P PJSA Drill 8.75"Production F/15,284'to 15,750'MD(3,510'TVD)465 GPM,2,430 PSI,160-180 RPM,TON 18K,TQF 12K,WOB 2-10K,HST 220K,SLK 85K,ROT 139K,ECD 11.07 ppg W/9.2 ppg MW.Max Gas 968 units.ADT 2.94,Bit Hrs 23.24,Jar Hrs 23.24.Monitor well,static. SPR @ 15,750'MD(3,510'TVD)W/9.25 ppg MW MP#3 20-350,30-440 12.00 18:00 6.00 18.00'DRILL E 3 .P PJSA Drill 8.75"Production F/15,750'to 16,214'MD(3,488'TVD)465 GPM,2,460 PSI,160-180 RPM,TON 18K,TOF 12K,WOB 1-15K,HST 200K,SLK 85K,ROT 140K,ECD 11.11 ppg W/9.2 ppg MW.Max Gas 792 units.ADT 4.61,Bit Hrs 27.85,Jar Hrs 27.85.Monitor well,static. "18:00 00:00 6.00 24.00'DRILL E 3 'P PJSA Drill 8.75"Production F/16,214'to 16,869'MD(3,487'TVD)465 GPM,2,500 PSI,160 RPM,TON 18K,TQF 13K, WOB 2-10K,HST 205K,SLK 85K,ROT 139K,ECD 11,15 ppg W/9.25 ppg MW.Max Gas 806 units.ADT 3.37,Bit Hrs 31.22,Jar Hrs 31.22.Monitor well,static. SPR @ 16,310'MD(3,481 TVD)W/9,3 ppg MW MP#3 20-360,30-440 Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Mails Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.0 13,320.0 1/17/2015 Last Leakoff Test bepth(RKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 13,355.0 3,507,18 FAZE PRO 9.20 700.0 13.04 2,376.2 1 Eni E&P Division Well Name:Sro-VJ7-- EN/Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ • API/UWI:50-629-23532-00-00 2^ Date:1/23/2015 - Report#: 27 ill II page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) •RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22.951.0 22,413.32 193.72 115.7 22.83 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POE Temperature(°F) Weather Wind 18,739.0 3,488.2 1.870.00 15.64 119.6 127.0 -19.0 Overcast WC-51` SW @ 25 MPH Daily summary operation 24h Summary Drill 8.75"Production F/16,869'to 18,739'MD(3.486'TVD)465 GPM,2,600 PSI,160 RPM,TON 18-20K,TQF 12-14K.WOB 6-10K,HST 205K,SLK 85K,ROT 140K,ECD 11.28 ppg W/9.25 ppg MW. Max Gas 810 units.ADT 15.64,Bit Hrs 46.86,Jar Hrs 46.86.Monitor well,static. Operation at 07.00 Drill 8.75"Production hole @ 19,117'MD. 24h Forecast Drill ahead 8.75"Production hole F/18,739'to 22,951'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.25 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06.00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"Production F/16,869'to 17,469'MD(3,496'TVD)465 GPM,2,570 PSI,160-180 RPM,TON 16-20K,TOP 12K,WOB 2-14K,HST 215K,SLK 85K,ROT 138K.ECD 11.10 ppg W/9.25 ppg MW.Max Gas 436 units.ADT 4.19,Bit Hrs 35.41.Jar Hrs 35.41.Monitor well,static. SPR @ 17,431'MD(3,494'TVD)W/9.3 ppg MW MP#3 20-360,30-440 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production F/17,469'to 17,879'MD(3,482'TVD)465 GPM,2,570 PSI,160-180 RPM,TON 19K,TOF 12K,WOB 2-14K,HST 230K,SLK 85K,ROT 138K,ECD 11.39 ppg W/9.25 ppg MW.Max Gas 230 units.ADT 3.47,Bit Hrs 38.88,Jar Hrs 38.88.Monitor well,static. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"Production F/17,879'to 18,413'MD(3,479'TVD)465 GPM,2,500 PSI,160-180 RPM,TON 18-20K,TQF 13K,WOB 2-14K,HST 208K,SLK 85K,ROT 138K.ECD 11.38 ppg W/9.25 ppg MW.Max Gas 642 units.ADT 4.13,Bit Hrs 43.01,Jar Hrs 43.01.Monitor well,static. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"Production F/18,413'to 18,739'MD(3,486'TVD)465 GPM,2,600 PSI,160 RPM,TON 18-20K,TOE 12- 14K,WOB 6-10K,HST 205K,SLK 85K,ROT 140K,ECD 11.28 ppg W/9.25 ppg MW.Max Gas 810 units.ADT 3.85,Bit Hrs 46.86.Jar Hrs 46.86.Monitor well,static. SPR @ 18,458'MD(3,479'TVD)W/9.25 ppg MW MP#3 20-410,30-500 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dulling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.corn 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Mails Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 13,320.0 1/17/2015 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 13.355.0 3.507.18 FAZE PRO 9.20 700.0 13.04 2.376.2 f� Eni E&P DivisionWell Name:Sri-W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ • APIIlJWI:50-629-23532-00-00 2^ Date:1/24/2015 - Report#: 28 (I I' page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 23.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(f/hr) POB Temperature(CF) Weather Wind 20,795.0 3,507.2 2.056.00 15.64 131.5 121.0 -27.0 Overcast WC-57` SW @ 20 MPH Daily summary operation 24h Summary Drill 8.75"Production FI 18,739'to 20,795'MD(3,507'TVD)475 GPM,2,940 PSI,160-190 RPM,TQN 21K,TQF 15K,WOB 2-17K,HST 210K,SLK 85K,ROT 135K,ECD 11.67 ppg W/9.25 ppg MW. Max Gas 859 units.ADT 15.64,Bit Hrs 62.50,Jar Hrs 62.50.Monitor well,static. Operation at 07.00 Drill 8.75"Production hole @ 21,325'MD. 24h Forecast Drill ahead 8.75"Production hole F/20,795'to 22,951'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"Production F/18,739'to 19,392'MD(3,485'TVD)500 GPM,3,150 PSI,160 RPM,TQN 19-20K,TQF 13- 14K,WOB 4-6K,HST 211K.SLK 85K,ROT 139K,ECD 11.70 ppg WI 9.25 ppg MW.Max Gas 619 units.ADT 3.6,Bit Hrs 50.46,Jar Hrs 50.46.Monitor well,static. 06.00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production F/19,392to 19,655'MD(3,493'TVD)475 GPM,2,900 PSI,160-180 RPM,TQN 20-23K,TQF 14-15K,WOB 6-12K,HST 220K,SLK 85K,ROT 138K,ECD 11.30 ppg WI 9.25 ppg MW.Max Gas 608 units.ADT 4.06,Bit Hrs 54.52,Jar Hrs 54.52.Monitor well,static. SPR @ 19,392'MD(3,485'TVD)W/9.25 ppg MW MP#1 20-360,30-450 MP#3 20-360,30-450 12.00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"Production F/19,655'to 20,440'MD(3,511'TVD)475 GPM,2,980 PSI,160-180 RPM,TON 19-23K,TQF 15K,WOB 2-14K,HST 210K,SLK 85K,ROT 135K,ECD 11.72 ppg W/9.25 ppg MW.Max Gas 775 units.ADT 3.77,Bit Hrs 58.29.Jar Hrs 58.29.Monitor well,static. SPR @ 20,324'MD(3,511'TVD)W/9.3 ppg MW MP#1 20-400,30-490 MP#3 20-380,30480 18.00 00:00 6.00- 24.00 DRILL E 3 P PJSA Drill 8.75"Production F/20,440'10 20,795'MD(3,507'TVD)475 GPM,2,940 PSI,160-190 RPM,TON 21K,TQF 15K,WOB 2-17K,HST 210K,SLK 85K,ROT 135K.ECD 11.67 ppg W/9.25 ppg MW.Max Gas 859 units.ADT 4.21,Bit Hrs 62.50,Jar Hrs 62.50.Mondor well,static. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dolling Supv SIDDnlling@enipelroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Dolling Supv 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 • Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondnlling.cow 907-685-0716 Tool Push Pete Maninusen Doyon Dolling Tour Pusher ng15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 13,320.0 1/17/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 13,355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2,376.2 Eni E&P Division �� Well Name:Sr3l-W7 ENI Petroleum Co.Inc. Da I Iy Report Well Code:28998 Field Name:NIKAITCHUQ • API/UWI:50-629-23532-00-00 2 Date:1/25/2015 - Report#: 29 'i I' page 1 of 1 Wellbore name: SP31-W7 Well Header PermitlConcession N° Operator ENI Share)%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYONRIG 15 LAND RIG -- _ Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22.951.0 22,413.32 193.72 115.7 24.83 Daily Information End Depth(ftKB) End Depth(TVD)(L.1 Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22.454.0 3,432.1 1,659.00 8.68 191.1 121.0 -20.0 Overcast WC-52° SW @ 25 MPH Daily summary operation 24h Summary 4 Drill 8.75"Production F/20,795'to 22,454'MD(3,438'ND)475 GPM,3,090 PSI,160 RPM,TON 20K,TOF 15K,WOB 2-12K,HST 250K,SLK 85K,ROT 130K,ECD 11.64 ppg W/9.25 ppg MW.Max Gas 1,141 units.ADT 8.68,Bit Hrs 71.18,Jar Hrs 71.18.Encountered 15 bph dynamic losses around 21,815'MD due to fault.Lost 100 bbl to formation white drilling.Circ.hole clean as per K&M BROOH schedule.465 GPM,3,030 PSI,140 RPM,TRO 16K.Reciprocate F/22,450'to 22,354'MD.After Circ.550 bbl dynamic loss rate increased to 80 bph.Reduced pump rate to 350 GPM,1,980 PSI, dynamic loss slowed to 6 bph.Lost 183 bbl while pumping.Shut down and perform wet bore exhale test for 30 Min.Observed down trend and 49 bbl seen at surface.BROOH as per K&M schedule F 22,454'to 21,700'MD 360 GPM,1,920 PSI,140 RPM,TRO 17K,ROT 130K.ECD 11.03 ppg W/9.25 ppg MW.Dynamic losses around 10 bph.Lost 60 during back reaming.Total lost for today 342 bbl to formation. Operation at 07.00 BROOH as per K&M schedule 02)20,027'MD. 24h Forecast Cont.to BROOH 8.75"Bt as per K&M schedule W/5"D.P.F/21,700'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"Production F/20,795'to 21,715'MD(3,493'TVD)475 GPM,3,070 PSI,160 RPM,TON 22-23K,TOF 14- 15K,WOB 6-10K,HST 220K,SLK 85K,ROT 138K,ECD 11.84 ppg W/9.25 ppg MW.Max Gas 1,117 units.ADT 3.90,Bit Hrs 66.40,Jar Hrs 66.40.Monitor well,static. SPR @ 21,446'MD(3,488'ND)W/9.25 ppg MW MP#1 20-440,30-530 MP#3 20-440,30-530 05 00 12 00 6 CO 12.00 DRILL E 3 P -PJSA Drill 8.75"Production F/21,715'to 22,193'MD(3,461'ND)475 GPM,3,110 PSI,160 RPM,TON 22-24K,TOF 14- 15K,WOB 8-12K,HST 235K,SLK 85K,ROT 130K,ECD 11.90 ppg W/9.25 ppg MW.Max Gas 1,141 units.ADT 3.27,Bit Hrs 69.67,Jar Hrs 69.67.Encountered 15 bph dynamic losses around 21,815'MD due to fault.Lost 50 bbl for tour.Well breathing being seen. 1200 15 00 3.00 15.00 DRILL E 3 P PJSA Drill 8.75"Production F/22,193'to 22,454'MD(3,438'ND)475 GPM,3,090 PSI,160 RPM.TON 20K.TOF 15K, WOB 2-12K,HST 250K,SLK 85K,ROT 130K,ECD 11.64 ppg W/9.25 ppg MW.Max Gas 312 units.ADT 1.51,Bit Hrs 71.18,Jar Hrs 71.18.Encountered 15 bph dynamic losses.Lost 50 bbl while dolling.Well breathing. SPR @ 22,454'MD(3,438'ND)W/9.3 ppg MW MP#1 20-580,30-640 MP#3 20-570,30-600 15.00 17 30 2.50 17.50 DRILL E 7 P PJSA Circ.hole clean as per K&M BROOH schedule.465 GPM,3,030 PSI,140 RPM,TRO 16K Reciprocate F/22,450'to 22,354'MD.After Circ.550 bbl dynamic loss rate increased to 80 bph.Reduced pump rate to 350 GPM,1,980 PSI, dynamic loss slowed to 6 bph.Lost 183 bbl while pumping. 17.30 18.00 0.50 18.00 DRILL E 11 P Shut down and perform well bore exhale test for 30 Min.Observed down trend and 49 bbl seen at surface. 18.00 00.00 6.00— 24.00 DRILL E 6 P PJSA BROOH as per K&M schedule F 22,454'to 21,700'MD 360 GPM,1,920 PSI,140 RPM,TRO 17K,ROT 130K.ECD 11.03 ppg W/9.25 ppg MW.Dynamic losses around 10 bph.Lost 60 during back reaming. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative -Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akngclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher rig15@doyondrilling.cern 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 13,320.0 1/17/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 13,355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2,376.2 0191* Eni E&P Division well Name:Sr, -W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ • APIIUWI:50-629-23532-00-00 2�II II,ii Date:1/26/2015 - Report#: 30 page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13,10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 25.83 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 22,454.0 3,432,1 0.00 120.0 -23.0 Overcast WC-55° SW @ 30 MPH Daily summary operation 24h Summary BROOH as per K&M schedule F 21,700'to 15,620'MD 400 GPM,1,990 PSI,140 RPM,TRQ 13K,ROT 135K.ECD 10.67 ppg W/9.25 ppg MW.Dynamic losses around 2 bph.Slight well bore breathing. Encountered fault @ shale F 15,620'to 15,377'MD Reduced Pump rate F/400 GPM to 370 GPM,1,800 PSI,140 RPM,TRQ 14-18K.Slight packing off and increased dynamic loss 50-60 bph.Lost about 183 bbl to formation.Slight breathing seen at well.BROOH as per K&M schedule F 15,377 to 14,939'MD 400 GPM,1,880 PSI,120-140 RPM.TRQ 14K,ROT 135K,ECD 10.69 ppg W/9.25 ppg MW.Dynamic losses around 2 bph.Slight well bore breathing.Total for today 200 bbl to formation. Operation at 07.00 BROOH as per K&M schedule @ 13,240'MD. 24h Forecast Cont,to BROOH 8.75"Bit as per K&M schedule W/5"D.P.F/14,939'MD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 Time Log r Start End Cum Time Time Dur(Er) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00-DRILL E 6 P PJSA BROOH as per K&M schedule F 21,700'to 19,022'MD 405 GPM,2,200 PSI,140 RPM,TRQ 18K,ROT 140K.ECD 11.03 ppg W/9.25 ppg MW.Dynamic losses around 2 bph.Slight well bore breathing. 06:00 12:00 ' 6.00 12,00 DRILL E 6 P PJSA BROOH as per K&M schedule F 19,022'to 16689'MD 401 GPM,2,050 PSI,140 RPM.TRQ 16K,ROT 138K.ECD 11.03 ppg W/9.25 ppg MW.Dynamic losses around 2 bph.Slight well bore breathing.Lost 24 bbl for tour. 12:00 18:00 6.00 18.00 DRILL E 6 P PJSA BROOH as per K&M schedule F 16,689'to 15,620'MD 400 GPM,1,990 PSI,140 RPM.TRO 13K,ROT 135K,ECD 10,67 ppg WI 9.25 ppg MW.Dynamic losses around 2 bph.Slight well bore breathing. 18:00 21:30 3.50 21.50 DRILL E 6 P PJSA BROOH as per K&M schedule,Encountered fault @ shale F 15620'to 15,377 MD Reduced Pump rate F/400 GPM to 370 GPM,1,800 PSI,140 RPM,TRQ 14-18K.Slight packing off and increased dynamic loss 50-60 bph.Lost about 183 bbl to formation.Slight breathing seen at well. 21 30 00.00 2.50 24.00 DRILL E 6 P PJSA BROOH as per K&M schedule F 15,377'to 14,939'MD 400 GPM,1,880 PSI,120-140 RPM,TRO 14K,ROT 135K. ECD 10.69 ppg W/9.25 ppg MW.Dynamic losses around 2 bph.Slight well bore breathing.Total of 200 bbl lost for tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative -Mike Ross -ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.cow 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat _ r Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0.0 13,320,0 1/17/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(113/gal) Leak Off Pressure(psi) 13,355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2,376.2 ` Eni E&P Division Well Name:Sr-a -w7' I EN!Petroleum Co.Inc. Daily Repor..t} Well Code:28998 Field Name:NIKAITCHUQ • APIIUWI:50-629-23532-00-00 2^ii - Date:1/27/2015 - Report#: 31 If �I page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 26.83 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22,454.0 3,432.1 0.00 123.0 -15.0 Partly Cloudy WC- SW @ 10 MPH • 35° Daily summary operation 24h Summary BROOH as per K&M schedule F 14,939'to 10,806'MD 400 GPM,1,750 PSI,140 RPM.TRQ 11K,HST 158K,SLK 95K,ROT 130K.ECD 10.43 ppg W/9.4 ppg MW.Dynamic losses around 2 bph.Slight well bore breathing.Lost 14 bbl during BROOH.Circ.and reciprocate F/10,806'to 10,713'MD.Circ.hole clean as Per K&M and weight up mud to 9.45 ppg 465 GPM,2,250 PSI,120 RPM.TRQ 12K. Lost 22 bbl while Circ.Monitor well bore.Establish down trend over 35 Min.Well went static.Rack back last stand of 5"D.P.to 10,713'MD.C/O Saver Sub to NC-46 for 4.5"D.P.Monitor well on Trip Tank.5 bbl static loss.Service Rig.BROOH as per K&M schedule F 10,713'to 8,800'MD 400 GPM,1,980 PSI,120 RPM,TRO 14K,HST 150K,SLK 97K,ROT 125K.Dynamic losses around 6-7 bph. Slight well bore breathing.Lost 20 bbl during BROOH.Total lost for today 71 bbl. Operation at 07.00 BROOH as per K&M schedule @ 7,180'MD. 24h Forecast Cont.to BROOH 8.75"Bit as per K&M schedule W/4.5"D.P.FI 8,800'MD.Lay down BHA#5.R/U GBR Equip.and RIH 5.5"Liiner as per tally. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03.30 3.50 3.50 DRILL E 6 P PJSA BROOH as per K&M schedule F 14,939'to 13,320'MD 400 GPM,1,900 PSI,140 RPM,TRQ 14K.ROT 140K.ECD 10.51 ppg W/9.3 ppg MW.Dynamic losses around 2 bph.Slight well bore breathing. 03.30 09:30 6.00 9.50 DRILL E 6 P PJSA BROOH as per K&M schedule F 13,320'to 10,806'MD 400 GPM,1,750 PSI,140 RPM.TRQ 11K.HST 158K.SLK 95K,ROT 130K.ECD 10.43 ppg W/9.4 ppg MW.Dynamic losses around 2 bph.Slight well bore breathing.Lost 14 bbl during BROOH. 09.30 1530 6.00 15.50 DRILL E 7 'P PJSA Circ.and reciprocate F/10,806'to 10,713'MD.Circ.hole clean as Per K&M and weight up mud to 9.45 ppg 465 GPM,2,250 PSI,120 RPM,TRO 12K.Lost 22 bbl while Circ. 15:30 16:30 1.00 16.50 DRILL E 11 P Monitor well bore.Establish down trend over 35 Min.Well went static.Rack back last stand of 5"D.P.to 10,713'MD. 16.30 18:30 2.00 18.50 DRILL E 20 P PJSM C/O Saver Sub to NC-46 for 4.5"D.P.Monitor well on Trip Tank.5 bbl static loss. 18.30 19:00 0.50 19.00 DRILL E 25 P PJSA Service Rig. 1900 00:00 5.00 24.00 DRILL E 6 P PJSA BROOH as per K&M schedule F 10,713'to 8,800'MD 400 GPM,1,980 PSI,120 RPM,TRQ 14K,HST 150K,SLK 97K,ROT 125K.Dynamic losses around 6-7 bph.Slight well bore breathing.Lost 20 bbl during BROOH. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Dulling Supv 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker EM Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 ' Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 00 13,320.0 1/17/2015 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 13,355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2,376.2 fill* ,* Eni E&P DivisionWell Name:Sr,-W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name: NIKAITCHUQ • APIIUWI:50-629-23532-00-00 2^ Date:1/28/2015 - Report#: 32 nil I' page 1 of 1 Wellbore name: SP31-W7 • Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 27.83 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22454.0 3,432.1 0.00 122.0 -24.0 Partly Cloudy WC- SW @ 12 MPH 48' Daily summary operation 24h Summary BROOH as per K&M schedule F 8.800'to 2,071'MD 465 GPM,1,030 PSI,120 RPM.TRQ 2K.HST 125K.SLK 120K.ROT 125K.ECD 10.31 ppg W/9.45 ppg.Lost 14 bbl while BROOH.Circ.BU 2X @ 456 GPM,1,030 PSI.120 RPM,TRQ 2K,reciprocate F/2,071'to 1,986'MD.No increase at Shakers.Monitor wet for 10 Min.,static.Pull 1 stand 4.5"D.P.and rack back to 1.976'MD.Pump Dry Job, clean rig floor.Set up rig floor to L/D 4.5"D.P.POOH on Elevators laying down 4.5"D.P.to Pipe Shed F/1,976'to 364'MD.Lost 4 bbl during trip.PJSM W/all essential personnel for laying down BHA and Nuclear source.UD BHA#5 and Nuclear source as per Schlumberger DD and MWD Rep onsite.Co Rep onsite.8.75"MDSi616 BPX Bit Grade 0-1-CT-S-X-IN-NO-TD.There was minimal wear on all tools except for the top stabilizer on the Xceed was half removed down to the collar and the other half was down to 8"OD.All other stabilizers were in gauge and looked very good.While breaking 8.75" Bit with bit tong,the tong slipped 180 degree off of tong slot and became wedged on the radius of the Xceed bit box.Due to down hole wear on tong slot.Took extra time to remove tong from Xceed bit box.Clear rig floor of BHA components.Clean rig floor. Operation at 07.00 R/U GBR Volant Tools And Equipment 24h Forecast Change out Saver Sub F/4.5"to 5".R/U GBR Volant tools and Equip.P/U M/U 5.5"Liner shoe and RIH as per tally. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 6 P PJSA BROOH as per K&M schedule F 8,800'to 6,000'MD 465 GPM,1,600 PSI,120 RPM,TRO 4-6K,HST 138K,SLK 111K.ROT 125K.Dynamic losses around 1 bph.ECD 10.41 ppg W/9.45 ppg MW.Monitor well for 10 Min.,static. 06.00 12:00 6.00 12.00 DRILL E 6 P PJSA BROOH as per K&M schedule F 6,000'to 3,875'MD 465 GPM,1,500 PSI,120 RPM,TRQ 4-5K,HST 130K,SLK 119K,ROT 125K.ECD 10.31 ppg W/9.45 ppg.Dynamic losses around 1 bph.Monitor well for 10 Min.,static.Lost 13 bbl for tour. 12.00 15'.00 3.00 15.00 DRILL E 6 P PJSA BROOH as per K&M schedule F 3,875'to 2,071'MD 465 GPM,1,030 PSI,120 RPM.TRQ 2K,HST 125K,SLK 120K,ROT 125K.ECD 10.31 ppg W/9.45 ppg. 15:00 15.30 0.50 15.50 DRILL E 7 P PJSA Circ.BU 2X @ 456 GPM,1,030 PSI,120 RPM,TRQ 2K,reciprocate F/2,071'to 1,986'MD.No increase at Shakers. 15:30 16.30 1.00 16.50 DRILL E 4 P PJSA Monitor well for 10 Min.,static.Pull 1 stand 4.5"D.P.and rack back to 1,976'MD.Pump Dry Job,clean rig floor.Set up rig floor to UD 4.5"D.P. 16:30 18:30 2.00 18.50 DRILL E 4 P PJSA POOH on Elevators laying down 4.5"D.P.to Pipe Shed F/1,976'to 364'MD.Lost 4 bbl during trip. 18:30 22:30 4.00 22.50 DRILL E 4 P PJSM W/all essential personnel for laying down BHA and Nuclear source.UD BHA#5 and Nuclear source as per Schlumberger DD and MWD Rep onsite.Co Rep onsite.8.75"MDSi616 BPX Bit Grade 0-1-CT-S-X-IN-NO-TD.There was minimal wear on all tools except for the top stabilizer on the Xceed was half removed down to the collar and the other half was down to 8"OD.All other stabilizers were in gauge and looked very good. 22:30 23:30 1.00 23.50 DRILL E 20 U PJSM While breaking 8.75"Bit with bit tong,the tong slipped 180 degree off of tong slot and became wedged on the radius of the Xceed bit box.Due to down hole wear on tong slot.Took extra time to remove tong from Xceed bit box. 23:30 00:00 0.50 24.00 DRILL E 20 P PJSA Clear rig floor of BHA components.Clean rig floor. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Dulling Supv 907-685-0715 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.0 13,320.0 1/17/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 13.355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2,376.2 .., Eni E&P Division ..} Well Name:Srsi-W7 pa* ENI Petroleum Co.Inc. Daily Re M O 1 1 Well Code:28998 Field Name:NIKAITCHUO • API/UW1:50-629-23532-00-00 2�If i,r,ii Date:1/29/2015 - Report#: 33 page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig information Contractor Rig Name Rig Type _DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22,413.32 193.72 115.7 28.83 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22 454.0 3,432.1 0.00 124.0 -19.0 Partly Cloudy WC- SE @ 14 MPH 44` Daily summary operation 24h Summary C/O Saver Sub to TT525.P/U M/U GBR Volant CRT W/GBR Rep onsite.SIMOPS Reposition&stage slotted liner components for liner run.Service Drawv vrks,TDS-8 and traveling Equip.C/O short bails to Csg.bails for liner run.RIH 5.5"Liner 15.58,L-80,HYD 521 as per tally F/0'to 8,684'MD.HST 125K,SLK 100K.R/D GBR Volant tools.Clear rig floor.P/U Csg.Tongs and Baker handling tools. R/U Csg.Tongs.PJSM W/all essential personnel.M/U Seal Bore Extension to 5.5"Liner W/Baker Rep onsite.R/U False rotary table.M/U Slim Hole MWD assembly as per Schlumberger DD and MWD onsite.M/U MLZXP Packer to Seal Bore Ext.and scribe,check orientation as per Schlumberger DD and MWD,Baker and CO Rep onsite.Pour in PAL mix into MLZXP Packer.Total lost for today 10 bbl. Operation at 07.00 RIH 5.5"Liner and MLZXP Packer on 5"D.P.©9,229'MD. 24h Forecast Wait on PAL Mix to set up.CIO Csg.bails to short bails.RIH 5.5"Liner and MLZXP Packer on 5"D.P.to 21,893'MD.Set Packer. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E '20 P PJSM CIO Saver Sub to TT525. 02:00 03:30 1.50 3.50 DRILL G 1 'P 'PJSM P/U M/U GBR Volant CRT W/GBR Rep onsite.SIMOPS Reposition&stage slotted liner components for liner run. 0330 04:00 0.50 4.00 DRILL G 25 P PJSA Service Drawworks,TDS-8 and traveling Equip. -- s � 04:00 '05:00 1.00 5.00 DRILL G 1 P PJSM CIO short bails to Csg.bails for liner run. r 6� 05:00 12:00 7.00 12.00 DRILL G 4 P PJSA P/U M/U 5.5"Shoe and RIH WI 5.5"Liner F/0'to 3,714'MD.HST 111K,SLK 113K.Lost 5 bbl for tour. ,..io 12:00 20:00 8.00 20.00 DRILL G 4 -P 'PJSA RIH 5.5"Liner 15.58,L-80,HYD 521 as per tally F/3,714'to 8,684'MD.HST 125K,SLK 100K. 1.-- r'� 20:00 21:00 1.00 21.00 DRILL G 20 P PJSM R/D GBR Volant tools.Clear rig floor.P/U Csg.Tongs and Baker handling tools.R/U Csg.Tongs. t'yb 21:00 00:00 3.00 24.00 DRILL E 4 •P PJSM W/all essential personnel.M/U Seal Bore Extension to 5.5"Liner W/Baker Rep onsite.R/U False rotary table.M/U Slim Hole MWD assembly as per Schlumberger DD and MWD onsite.M/U MLZXP Packer to Seal Bore Ext.and scribe, check orientation as per Schlumberger DD and MWD,Baker and CO Rep onsite.Pour in PAL mix into MLZXP Packer.Lost 5 bbl for tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Amjad Chaudhry ENI Sr.Drilling Eng. Eni representative Andrea Lazzari ENI Drilling Eng. Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.0 13,320.0 1/17/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 13,355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2,376.2 111* Eni E&P DivisionWell Name:Si-J1-W7 Petroleum Co.Inc. Daily ReportWell Code:28998 Field Name:NIKAITCHUQ • APIIUWI:50-629-23532-00-00 2^ Date:1130/2015 - Report#: 34 l II page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22,951.0 22413.32 193.72 115.7 29.83 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22 454.0 3,432.1 0.00 123.0 16.0 Blowing Snow WC- SW @ 30 MPH 5" Gusts To 36 MPH Daily summary operation 24h Summary C/O Csg.bails back to short drilling bails.RIH 5.5"Liner.Rabbit in hole 5"D.P. F/8,684'to 8,924'MD.HST 130K,SLK 105K.Perform shallow hole test as per Schlumberger MWD.122 GPM,500 PSI. Blow down TDS-8.RIH WI 5.5"Liner on 5"D.P.F/8,924'to 18,260'MD.Adjusted Rabbit Hanger on bails.Fill D.P.and obtain data for KW prior to exit of 9 5/8"Shoe @ 13.311'MD.HST 157K,SLK 105K,ROT 139K.TRQ 8K.Cont.RIH WI 5"D.P.F/18,260'to 21,152'MD.Due to loss of string weight,started rotating in hole @ 30 RPM FI 21,152'to 21,889'MD.Odentate MLZXP Packer as per Baker,Schlumberger DD and MWD and CO Rep onsite.Drop 1.75"ball and pump down for setting packer at 4 bpm,1,000 PSI,slow pumps to 2 bpm,450 PSI and 1 bpm,200 PSI.Calculated strokes to bump ball 2,323 strokes,actual strokes to bump 2,992 strokes.Press.up to 1,900 PSI to set Hanger.SLK off to 90K to insure Hanger is set.Press.up to 2,600 PSI to set liner top packer and hold for 10 Min.Stage up F/2.600 PSI to 3,200 PSI to verify packer is set.Increase Press.up to 4,000 PSI to release running tool.Bleed off Press.and P/U to confirm release.Shut in Annular Preventer and test IA and packer to 1,500 PSI for 15 Min.All operations charted.Liner top @ 13,165'MD and 5.5"Liner shoe @ 21,889'MD.Baker and CO Rep onsite.POOH 3 stands 5"D.P.and rack back in Derrick F/ 13,165'to 12,979'MD.HST 180K,SLK 112K.Blow down TDS-8.Slip and cut drilling line,inspect brakes and adjust brakes.No losses for tour. Operation at 07.00 POOH 5"D.P.and liner running Assy @ 6,654'MD. 24h Forecast POOH 5"D.P.and packer running Assy.F/12,979'MD.L/D Liner running Assy.P/U M/U Whipstock and RIH W/5"D.P. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00-DRILL -G 20 P PJSM C/O Csg.bails back to short drilling bails. 01:00 02:30 1.50 2.50'DRILL G 4 P PJSM RIH 5.5"Liner Rabbit in hole 5"D.P.F/8,684'to 8,924'MD.HST 130K,SLK 105K.Perform shallow hole test as per Schlumberger MWD,122 GPM,500 PSI.Blow down TDS-8. 02.30 12:00 9.50 12.00 DRILL •G '4 P PJSA RIH W/5.5"Liner on 5"D.P.F/8,924'to 18,260'MD.Adjusted Rabbit Hanger on bails.Fill D.P.and obtain data for K&M prior to exit of 9 5/8"Shoe @ 13,311'MD.HST 157K,SLK 105K,ROT 139K.TRO 8K. 12:00 15.30 3.50 15.50 DRILL •G 4 P PJSA Cont.RIH 5.5"Liner on 5"D.P.F/18,260'to 21.152'MD.HST 210K,SLK 85K 15:30 16.30 1.00 16.50 DRILL "G 4 P PJSA Due to loss of string weight,started rotating in hole @ 30 RPM Fl 21.152'to 21,889'MD.HST 210K,ROT 148K, TRQ 15-16K 16:30 18.00 1.50 18.00 DRILL "G '19 P PJSA Orientate MLZXP Packer as per Baker,Schlumberger DD and MWD and CO Rep onsite. 18:00 20.00 2.00 20.00 DRILL ..G 19 P PJSA Drop 1.75"ball and pump down for setting packer at 4 bpm,1,000 PSI,slow pumps to 2 bpm,450 PSI and 1 bpm. 200 PSI.Calculated strokes to bump ball 2,323 strokes.actual strokes to bump 2,992 strokes. 20:00 21 30 1.50 21.50 DRILL -G 19 P PJSA Press.up to 1,900 PSI to set Hanger,SLK off to 90K to insure Hanger is set.Press.up to 2,600 PSI to set liner top packer and hold for 10 Min.Stage up F/2,600 PSI to 3,200 PSI to verify packer is set.Increase Press.up to 4,00 PSI to release running tool.Bleed off Press.and P/U to confirm release.Shut in Annular Preventer and test IA and packer to 1.500 PSI for 15 Min.All operations charted.Liner top @ 13,165'MD and 5.5"Liner shoe @ 21.889'MD.Baker and CO Rep onsite. 21 30 22.00 0.50 22.00 DRILL •G '4 P PJSA POOH 3 stands 5"D.P.and rack back in Derrick F/13,165'to 12,979'MD.HST 180K.SLK 112K.Blow down TDS-8. 22:00 00.00 2.00 24.00'DRILL •G °25 P PJSM Slip and cut drilling line,inspect brakes and adjust brakes.No losses for tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Dulling Supv 907-685-0715 Eni representative Andrea Lazzan ENI Drilling Eng. Eni representative Bemie Leas ENI Rig Clerk akngclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Troy England ENI HOE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dolling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 4.280 -5.0 21,889.0 1/30/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 13.355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2.376.2 Eni E&P DivisionWell Name:Sr,i-W7 VI* ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ • API/UWI:50-629-23532-00-00 2^ Date:1/3112015 - Report#: 35 II II page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(it) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 DRILLING 1/1/2015 22.951.0 22,413.32 193.72 115.7 30.33 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22,454.0 3,432.1 0.00 122.0 3.0 Partly Cloudy WC- SW @ 27 MPH 18" Daily summary operation 24h Summary PJSA&POOH 1/12,979'MD to 96'MD.HST=91K SLK=98K.PJSM&L/D liner running tool and slimhole MWD 1/96'MD to 0'MD w/Baker and Schlumberger reps onsite.PJSA.Clean and clear ng floor. PJSM.Mob whipstock and milling components to rig floor and stage.PJSA.P/U and M/U telescope,bumper sub,5"HWDP(4 1/2 IF).Upper Mill,Flex Jt.,Lower Mill&Window Mill.Orient with Baker& MWD Reps onsite.Witnessed By Eni Drilling Engineer&Company Rep onsite. Stand back in derrick.P/U and M/U Anchor,seal sub,safety shear disconnect,unloader,blank sub,drain sub,stnng magnet&Gen II whipstock slide 00'MD to 56'MD.SLK=81K. Operation at 07.00 Begin whipstock operations on well SP31-W7 L1. FINAL DAILY DRILLING REPORT. 24h Forecast Start operations on well SP21-W7 Lt. _ Lithology Showa MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 07:00 7.00 7.00 DRILL E 4 P PJSA&POOH 1/12,979'MD to 96'MD.HST=91 K SLK=98K. 07:00 08:00 1.00 8.00'DRILL E 20 P PJSM&UD liner running tool and slimhole MWD f/96'MD to 0'MD w/Baker and Schlumberger reps onsite. 08:00 09:00 1.00 9.00 DRILL E 20 P PJSA.Clean and clear rig floor.PJSM.Mob whipstock and milling components to ng floor and stage. 09:00 12:00 3.00 12.00 DRILL E 20 P PJSA.P/U and M/U telescope,bumper sub,5"HWDP(4 1/2 IF).Upper Mill,Flex Jt.,Lower Mill&Window Mill.Orient with Baker&MWD Reps onsite.Witnessed By Eni Drilling Engineer&Company Rep onsite. Stand back in derrick.P/U and M/U Anchor,seal sub,safety shear disconnect,unloader,blank sub,drain sub,string magnet&Gen II whipstock slide f/o' MD to 56'MD.SLK=81K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Em representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dnlling Supv. 907-685-0715 Eni representative Ben Perry ENI Senior Dulling Supv 907-685-0715 Eni representative Andrea Lazzari ENI Dniflng Eng. Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Troy England ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondnIling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 4.280 -5.0 21,889.0 1/30/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 13.355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2,376.2 ' 1111* Eni E&P Division Report Well Name:Sr, -W7 ! ENI Petroleum Co.Inc. Daily Well Code:28998 Field Name:NIKAITCHUO • APIIUWI:50-629-23532-00-00 2 Date:2/15/2015 - Report#: 1 1 I' page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(it) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 COMPLETION 45.83 Daily Information End Depth(RKB) End Depth(TVD)(1.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 110.0 -13.0 Clear WC-40` WNW @ 26 MPH Daily summary operation 24h Summary COMPLETE BOPE TESTING.RU AND MU LOWER COMPLETION AS PER TALLY Operation at 07.00 SPLICING MLE ESP 24h Forecast COMPLETE LOWER COMPLETION MAKE UP GBR CRT TOOLS RIH AND MAKE MLE ESP SPLICE MU AND RIH WITH COMPLETION STRING Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 09:30 9.50 9.50 COMP C 12 P PJSA Rig on Completion AFE#6931.Complete Testing BOPE. 09:30 10:30 1.00 10.50 COMP C 19 P PJSA Blow down all lines,pull test plug and R/D testing equipment. 10:30 13:30 3.00 13.50 COMP K 20 P PJSA Cear and clean rig floor.Load floor w/Baker Centrilift Completion equipment. 13:30 15:00 1.50 15.00 COMP K 20 P PJSA Hang ESP 8 Cap Tube sheaves in derrick and string up cables. /n� 15:00 18:00 3.00 18.00 COMP K 4 P PJSA M/U Lower completion,3.5"Dispersion tube,7 Shroud assy.,motor centralizer,MGU,MSP Motor and service Ci ,,w/ motor. 18:00 00:00 6.00 24.00 COMP K 4 P Cont.to M/U and service Tandem Motor and Seal assemblies,Intake.Terminate Tech wire to down hole gauge and motor /i lead. �/ Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Dulling Supv. '907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 4.280 -5.0 21,889.0 1/30/2015 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 13,355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2,376.2 .. 1 ft* Eni E&P Division Well Name:Sro:-W7 ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUQ • API/UWI:50-629-23532-00-00 2^ Date:2/16/2015 - Report#: 2 I) II II page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) SP31-W7 COMPLETION 46.83 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 111.0 -5.8 Clear WC-28' NNW @ 18 MPH Daily summary operation 24h Summary M/U Lower Baker completion and perform splices.M/U and RIH wl 4.5"12.6#L80 Hyd 563 ESP completion as per tally//7738',testing cable every 1000'.0/0 ESP spools. Operation at 07.00 Running 4.5"ESP completion @ 8,724'MD 24h Forecast Cont.to Run 4.5"ESP completion as per tally.M/U hanger and land string on Vetco tubing hanger. Lithology Shows - MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 COMP K 4 P PJSA RIH w/lower completion.Terminate TEC wire on DGU. 02:00 02:30 0.50 2.50 COMP K 20 P PJSA M/U GBR CRT and handling equipment.RIH w/Jt.#1. 02:30 05:30 3.00 5.50 COMP K 12 P PJSA Splice MLE/ESP and Cap line.Test good on both. 05:30 12:00 6.50 12.00 COMP K 4 P PJSA M/U&RIH W 4.5"12.64 L80 Hyd 563 completion as per tally fl 132'-2627',110k puw/sow.Test ESP every 1000'.5 bbls Toady fluid losses. 12:00 23:00 11.00 23.00 COMP K 4 P 'PJSA Run 4.5"ESP completion f/2672'-7738'. 23:00 00:00 1.00 24.00 COMP K 20 P PJSA C/O ESP Spools. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type [ OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 4.280 -5.0 21,889.0 1/30/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 13,355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2,376.2 Eni E&P Division Name:Sra I-W7 fig* ENI Petroleum Co.Inc. Daily Report Well Code:28998 Field Name:NIKAITCHUO • API/UW:50-629-23532-00-00 2,II II�nIi Date:2/17/2015 - Report#: 3 page 1 of 1 Wellbore name: SP31-W7 Well Header Permit/Concession N` Operator ENI Share(%) Well Configuration type ADL 214-182 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.77 13.10 36.80 33.99 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) SP31-W7 COMPLETION 47.83 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 0.0 120.0 9.0 Light Snow WC 1` ESE @ 7 MPH Daily summary operation 24h Summary RIH 4.5"Completion F/7,738'to 8,094'MD.As per Centredift Reps onsite.Install Gator splice on ESP Cable and test.witnessed by ENI Electrician.RIH 4.5"Completion F/8,094'to 11,285'MD.HST 140K,SLK 85K.Test ESP Cable every 1,000'.Total 281 Jnts run.Lost 3 bbl.M/U 0/0 Pup Jnt.R/D Volant CRT and Bail Extensions.Install YC Elevators.M/U Landing Jnt and Hanger as per Vetco Grey Rep onsite.As per Centedift Rep onsite,Install Penetrator in Hanger.Splice ESP Cable and CAP Line.Test ESP Cable.Land Hanger W/BPV installed. Landed at 11,328'MD.SLK 80K.RILDS and test Upper and Lower Hanger Seals to 5,000 PSI for 10 Min.L/D Landing Joint.String down and R/D ESP Sheaves.Clear rig floor of Centedift and GBR Tools and Equip.N/D BOPE Stack.Prep and N/U Tree as per Vetco Grey Rep onsite.Test Tree void to 5,000 PSI for 10 Min.witnessed by CO Rep onsite.Centerlift perform ESP commissioning tests.Test Tree to 5,000 PSI for 10 Min.charted.Pull Two Way Check valve as per Vetco Grey Rep onsite.Prep for rig move.Freeze Protect well with Little Red.Rig released @ 24:00. Operation at 07.00 Demob rig. 24h Forecast Demob rig. LAST COMPLETION REPORT Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 COMP K 4 P PJSA RIH 4.5"Completion F/7,738'to 8,094'MD.HST 135K,SLK 90K. 00:30 02:30 2.00 2.50 COMP K 5 P As per Centredift Reps onsite.Install Gator splice on ESP Cable and test,witnessed by ENI Electrician. 02:30 09:00 6.50 9.00 COMP K 4 P PJSA RIH 4.5"Completion F/8,094'to 11,285'MD.HST 140K,SLK 85K.Test ESP Cable every 1,000'.Total 281 Jnts run. Lost 3 bbl.Clamps in hole:Cannon 283,Splice 2,Singles 2,Pump Clamps 5,Protectolizer 2. 09:00 09:30 0.50 9.50 COMP K 20 P PJSAM/U X/O Pup Jnt.R/D Volant CRT and Bail Extensions.Install YC Elevators.M/U Landing Jnt and Hanger as per Vetco Grey Rep onsite. 09:30 12:00 2.50 12.00 COMP K 20 P PJSA As per Centerlift Rep onsite,Install Penetrator in Hanger.Splice ESP Cable and CAP Line.Test ESP Cable. 12:00 13:30 1.50 13.50 COMP C 20 P PJSA Land Hanger W/BPV installed.Landed at 11,328'MD SLK 80K.RILDS and test Upper and Lower Hanger Seals to 5.000 PSI for 10 Min.L/D Landing Joint. 13:30 15:00 1.50 15.00 COMP K 20 P PJSM String down and R/D ESP Sheaves.Clear ng floor of Centedift and GBR Tools and Equip. 15:00 17:30 2.50 17.50 COMP C 20 P PJSM WD BOPE Stack. 17.30 2130 4.00 21.50 COMP C 20 P PJSA Prep and N/U Tree as per Vetco Grey Rep onsite.Test Tree void to 5.000 PSI for 10 Min.witnessed by CO Rep onsite.Centedift perform ESP commissioning tests. 21:30 22:30 1.00 22.50 COMP C 12 P PJSA Test Tree to 5,000 PSI for 10 Min.charted. 22:30 23:00 0.50 23.00 COMP C 20 P PJSA Pull Two Way Check valve as per Vetco Grey Rep onsite. 23:00 00:00 1.00 24.00 COMP A 20 P PJSA Prep for rig move.Freeze Protect well with Little Red.Rig released @ 24:00. Daily Contacts Position Contact Name Company Title E-mail Office Mobile En:representative Bruce Simonson ENI Dolling Supv. 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 4.280 -5.0 21,889.0 1/30/2015 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 13,355.0 3,507.18 FAZE PRO 9.20 700.0 13.04 2,376.2 N AV1nn1A7m O O E="2" hagWHW30 'OAR 2ppWHY rOWN EMI E OWW !!!!! !!!;! !! ! !!!!! i !!!!! sms4444 444! 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S88 3 lap8§.9 sA • ZWW0OGme MAN 6OIGVV ACOe.iIn N O .R b B4B MB4B 774MM BB4BNAAP, LL OMn G �AA_�_ NS NI-f O 2 JAS m �gtV Ip y 3 C P.--TOMt7 17'14. 4 OIrl ONO GApO,= tOmtopi Ig{pp��App mrIp O i '0-10 m 8$SB NABS SR 22888 AON+O T0. AOf A ' -p- n Q dIy LL e ct C 8N N N v<N Iy 4 U iCryAr Qm040 <WRM 08 Y 90°i' 92 .. 01r � N, 7 °g !DYUS. N � 0N N ; j o NNNN NNNN NN G N N N n 3 N f im " 0-go Ism rt C oz t ,E- . ,t','7; • Eni Petroleum CASING&CEMENTING REPORT Lease&Well No. SP31-W7 Date 4-Jan-14 County GPB State Alaska Supv. Chant CASING RECORD-Surface casing TD 2677.00 Shoe Depth: 2663.00 PBTD: MD/ TVD Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 13-3/8 BTC WTF 2.75 2,663.00 2,660.25 2 13-3/8 68 L-80 BTC Tenaris 80.37 2,660.25 2,579.88 Float Collar 13-3/8 BTC WTF 1.40 2,579.88 2,578.48 65 13-3/8 68 L-80 BTC Tenaris 2,537.58 2,578.48 40.90 PJ&Hanger 13-3/8 68 L-80 BTC Tenaris 4.55 40.90 36.35 Totals 2,626.65 2,663.00 36.35 Csg Wt.On Hook: Type Float Collar: Float No.Hrs to Run: Csg Wt.On Slips: Type of Shoe: Guide Casing Crew: GBR Fluid Description: Liner hanger Info(Make/Model): Liner top Packer?: _Yes _No Liner hanger test pressure: Centralizer Placement: 1 centralizer 5'&8'above shoe,10'above FC,1 each joint up to 2143'MD,2 centralizer inside CP. CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10.1 Volume pumped(BBLs) 100 Lead Slurry Type: ASL Yield(Ft3/sack): 2.77 Density(ppg) 10.7 Volume (BBLs/sacks): 4041819 Mixing/Pumping Rate(bpm): 5 Tail Slurry , I Type: 12.5 crete Yield(Ft3/sack): 1.57 0 Density(ppg) 12.5 Volume (BBLs/sacks): 73/261 Mixing/Pumping Rate(bpm): 3 N Post Flush(Spacer) Type: H2O Density(ppg) 8.4 Rate(bpm): 5 Volume: 10 Displacement: Type: Mud Density(ppg) 9.3 Rate(bpm): 6 Volume(actual/calculated): 376/376 FCP(psi): 550 Pump used for disp: Rig pumps Plug Bumped? x Yes No Bump press 980 Casing Rotated? Yes x No Reciprocated? _Yes x No 100 %Returns during job Yes Cement returns to surface? x Yes _No Spacer returns? x Yes _No Vol to Surf: 93 bbls Cement In Place At: 12:00 Date: 1/4/2014 Estimated TOC: Surface Method Used To Determine TOC: Visual and weight taken to verify Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry u, Type: Yield(Ft3/sack): o Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): ch Post Flush(Spacer) z Type: Density(ppg) Rate(bpm): Volume: 0 w Displacement: e Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes _No %Returns during job Cement returns to surface? Yes _No Spacer returns?_Yes _No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Remarks: r I r Eni Petroleum CASING&CEMENTING REPORT Lease&Well No. SP31-W7 Date 19-Jan-15 County GPB State Alaska Supv. Chant CASING RECORD-Intermediate casing TD 13335.00 Shoe Depth: 13320.00 PBTD: MD/ TVD Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 9-5/8 Hydril 563 Davis-Lynch 501 2.89 13,320.00 13,317.11 2 _ 9-5/8 40 L-80 _ Hydril 563 Tenaris 79.64 13,317.11 13,237.47 Float Collar _ 9-5/8 Hydril 563 Davis-Lynch 700 2.94 13,237.47 13,234.53 326 9-5/8 40 1-80 Hydril 563 Tenaris 13,204.41 13,234.53 30.12 Totals 13,289.88 13,320.00 30.12 Csg Wt.On Hook: Type Float Collar: Float No.Hrs to Run: Csg Wt.On Slips: Type of Shoe: Guide Casing Crew: GBR Fluid Description: Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 1 centralizer 5'above shoe,10'above FC,1 each joint up to 11,276'MD CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10.5 Volume pumped(BBLs) 100 Lead Slurry Type: 12.5 #Crete Yield(Ft3/sack):/ 1.56 Density(ppg) 12.5 Volume (BBLs/sacks): 172.4/620 V Mixing/Pumping Rate(bpm): 4 Tail Slurry Type: G Blend Yield(Ft3/sack): 1.16 0 Density(ppg) 15.8 Volume (BBLs/sacks): 49.4/239 ✓ Mixing/Pumping Rate(bpm): 3.6 co Post Flush(Spacer) 0 Type: H2O Density(ppg) 8.4 Rate(bpm): 5 Volume: 10 cl Displacement: Type: Mud Density(ppg) 9.5 Rate(bpm): 7 Volume(actual/calculated): 996.8/993.5 FCP(psi): 440 Pump used for disp: Rig pumps Plug Bumped? _Yes x No Bump press 440 Casing Rotated? Yes x No Reciprocated? Yes x No 100 %Returns during job Cement returns to surface? Yes x No Spacer returns? Yes x No Vol to Surf: N/A Cement In Place At: 5:00 Date: 1/18/2015 Estimated TOC: 10,820 Method Used To Determine TOC: Volume pumped/Calculated Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry / Type: Yield(Ft3/sack): i/ Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry w Type: Yield(Ft3/sack): a Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Post Flush(Spacer) oType: Density(ppg) Rate(bpm): Volume: w Displacement: cn Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? _Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No %Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: _ Method Used To Determine TOC: Visual Remarks: Floats holding 214182 25 , 55 SchlumbergerTransmittal#: 26FEB15-SPO1 PetroTechnical Services DATA LOGGED /2015 PTS Answer Products M..KK..BENDER R Customer: ENI Operating Co. Inc.Alaska Dispatched To: Makana Bender Well No: SP31-W7 Date Dispatched: 26-Feb-15 Job#: 14AKA0155 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Product 5 Contents on CD N/A VISION*Resistivity 2"MD x x VISION*Resistivity 2"TVD �+ x x VISION*Resistivity 5"MD RECEIVED x x VISION*Resistivity 5"TVD x x VISION*Resistivity 5"MD IMAGE FEB 2 6 2015 x x AOGCC Digital Data N/A Contents on CD N/A ASCII/DLIS Survey 1 Contents on CD ASP Final Survey x x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:PDF x Survey: PDF x • Please sign and email a copy to: Please sign and email a copy to: andrew.buchanan(a�enipetroleum.com AlaskaPTSPrintCenter(a�slb.com Attention:Andrew Buchanan 6..ei.teeve AttentionSteepphanie Pacillo Received By: !✓ 2ot, N CO In CI v- un Uil n > O m-o o Mr e w MM M.n Ngp�ppo N d qoq d� d N�� ....4. 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Oo LL ON,,-03, N N'h m COFE mom. mMM7n + m mvsnn a1) O .- tmd zz C 2 NC.'N N 7)1.=1.= a 0LL N N m 0 2 W m 0 "`O NNN NNr.ON NN�app OO. Na0 NmaO u m 'WW O � O.dnM d�OaO dMOf NO O.On.- 02140 O h W 01 2'222 22222 amoamomoamom 22228 288 10 r 107 m N...- ma d00 c U o =N m N c a N N U gCamDNNr -'2d',.2sa mW�aZO 10(20 amONb NdO 0.10 aD N" V"" M n N N N N m .-2 N O. e V m p aa V m N 'OO d N.O n 1000010 M N O EWAN N N NNN N NNNNN N NNN N N N O` N N C - In O W co 6 v u ) N f EE u w U_ `O 0 8 c W`0 rn T T Et t o .. U MN 0 V/7, � THE STATE Alaska Oil and Gas °fALASI�CA F�= M Conservation Commission -� . GOVERNOR BILL WALKER 333 West Seventh Avenue ppm--,m:- Anchorage,Alaska 99501-3572 ALAS Main:907.279.1433 Fax:907.276.7542 Davide Simeone Well Ops Project Manager Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP31-W7 Eni US Operating Co. Inc. Permit No: 214-182 Surface Location: 4434' FSL, 1460' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 2699' FSL, 1493' FEL, SEC. 22, T14N, R8E, UM Dear Mr. Simeone: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce is contingent upon issuance of a conservation order approving a spacing exception. Eni US Operating Co. Inc. assumes the liability of any protest to the spacing exception that may occur. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, CA7 Cathy P. Foerster Chair DATED this D day of December, 2014. STATE OF ALASKA A :A OIL AND GAS CONSERVATION COMMi IN RECEI W ED PERMIT TO DRILL 20 AAC 25.005 ....rusL ji_ I,la.Type of Work: lb.Proposed Well Class: Development-Oil 01 Service- Winj ❑ Single Zone 0. c.Specify'f I' r for: Drill 0, Lateral ❑ Stratigraphic Test ❑ Development-Gas E Service-Supply ❑ Multiple Zone ❑ Coalbed Aates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number. ENI US Operating Co.Inc.• Bond No. RLB0008627• SP31-W7' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 22951 • TVD: 3476- 5 Nikaitchuq/Schrader Bluff' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease N ber• 3%sm Surface. 4434 FSL,1460 FEL,S19 T14N R9E UM ADL 0391283,0388583,0388574, 18X*03885-2 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2456 FSL,5080 FEL,S25 T14N R8E UM ADL 417493 12/27/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2699 FSL,1493 FEL,S22 T14N R8E UM 8260 4844'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL• 54.1 15.Distance to Nearest Well Open Surface:x- 511450 y- 6053615 Zone- 4 GL Elevation above MSL: 13.1 to Same Pool: 77'to 0113-03 16.Deviated wells: Kickoff depth. 400 feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle:73 7-92,34 degrees Downhole: 1587 psig Surface: 1199 psig 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 160 36 36 160 160 Pre-Installed 16" 13-3/8" 68 L-80 BTC 2686 35 35 2721 2454 Surface Lead 424bb1s 12.5ppg DeepCrete Tail 63 bbls 12.25" 9-5/8" 40 L-80 Hydril 563 13288 33 33 13321 3495 DeepCrete Lead 182bbls 15.8ppg Tail 48 bbls 8-3/4" 4-1/2" 11.6 L-80 Hydril 521 9830 13121 3481 22951 3476 Liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis0 Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 MC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 11/17/2014 22. I hereby certify that the foregoing is true and correct. Contact Andrea Lazzan 907-230 7511 Email andrea.lazzari@enipetroleum.com Printed Name D.videSimeone Title Well Ops Project Manager Signature -(734,UIJ� I I Phone (907)865-3320 Date 11/17/2014 Commission Use Only Permit to Drill -� API I�u •er: Permit Ap royal See cover letter for other Number: a I L( Ig ., 50-�n 29-02 353 a,-O -O 'Date: 1 - - t r"E requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales:av Other: 'l 3 5O0 p s:. db/C) 1;5f--- Samples req'd• Yes❑ No[f Mud log req'd:Yes No�7 / HZS measures: Yes❑ No El Directional svy req'd:Yes f No❑ Spacing exception req'd: Yes •Z No Inclination-only svy req'd:Yes NoR'" CO 'jet is,--,..L ILI,/t9 0 , APPROVED APPROVED BY • Approved by: - &of / All' COMMISSIONER THE COMMISSION Dat>.Zub 0.r nd RECEIVED STATE OF ALASKA NOV 13 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL A CC 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Development-Oil 0 Service- Winj ❑ Single Zone [7] lc.Specify if well is roposed for: Drill ❑✓ Redd! ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas Gas Hydrates ❑ Re-entry El Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Na and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 SP31-W7 3.Address: 6.Proposed Depth. 12.Fieltool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 22951 • ND: 3476 Nikaitchuq/Schrader Bluff 4a. Location of Well(Governmental Section): 7.Property Designation(Lease N� ?5 38g5 /. Surface: 4434 FSL,1460 FEL,S19 T14N R9E UM ADL 0391283,9388588,0388574, d388572 Top of Productive Horizon: 8.Land Use Permit: 43.Approximate Spud Date: 2456 FSL,5080 FEL,S25 T14N R8E UM ADL 417493 - 12/27/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2699 FSL,1493 FEL,S22 T14N R8E UM 8260' ' 4844'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: _,'5J4.1 15.Distance to Nearest Well Open Surface:x- 511450 y- 6053615 Zone- 4 - GL Elevation above MSL• ' -13.1 to Same Pool: 7710 0113-03 16.Deviated wells: Kickoff depth: 400 feet. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle:g3,c 92:84 degrees Downhole: 1587 psig• , Surface: 1199 psig , 18.Casing Program: Specifications Top - Setting Depth:, Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND ;TAD ND (including stage data) Driven 20" 178.89 X-65 Welded 160 36 36 / 160 160 Pre-Installed 16" 13-3/8" 68 L-80 BTC 2686 35 35 2721 2454 Surface Lead 424bb1s 12.5ppg DeepCrete Tail 63 bbls /' 12.25" 9-5/8" 40 L-80 Hydril 563 13288 33 �,33 13321 3495 DeepCrete Lead 182bbls (l 15.8ppg Tail 48 bbls 8-3/4" 5-1/2" 15.5 L-80 Hydril 521 9830 / 13 ' 3481 22951 3476 Liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be mp to r edrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): /Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural \ Surface AV Intermediate ` Production Liner \(� Perforation Depth MD(ft)' - Perforation Depth ND(ft): 20. Attachments: Property Plat 0 BO� k h \Q Drilling Program Q Time v.Depth Plot El Shallow Hazard Analysis Diverter etch Q Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements❑✓ 21. Verbal Approval: Commission Representative: Date 11/12/2014 22. I hereby certify that the foregoing is true and correct. Contact Andrea Lazzari 907-230 7511 Printed Name /�l' U avideMimeone Title Well Ops Project Manager Signature OL V ti 1 ( Phone (907)865-3320 Date 11/12/2014 ` Commission Use Only Permit to D ill APV'Nu 1:r:=r: Permit Approval See cover letter for other Number: - /8t 0 z9-,2,5.3 z -00 'Q 0Date: requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: li Other: / Samples req'd: Yes❑ No❑ Mud log req'd: Yes El No❑ H2S measures: Yes❑ No❑ Directional svy req'd: Yes ❑ No❑ / APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401(Revised 7/2009) T s rift is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate GINAL RECEIVED NOV 132014 AOGCC EnhiPktiroHeum pin_ 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Davide Simeone Phone(907)865-3320 Email: Davide.Simeone@enipetroleum.com November 12,2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer SP31-W7 Dear Commissioners, Eni US Operating Co. Inc.hereby applies for a Permit to Drill for the Offshore Producer well SP31-W7. This well will be drilled and completed using Doyon 15. The planned spud date could be as early as 12/27/2014. Please find attached for the review of the Commission forms 10-401 as well as the information required by 20 ACC 25.005. If you have any questions or require further information,please contact Andrea Lazzari 907 230 7511 Sincerely, D vide Sime,ne II Oper tie s Project Manager c_,, U 'ILI 1:) _iiofr i • En Petirolleum 2n 0 Application for Permit to Drill SP31-W7 Saved: 12-Nov-14 Application for Permit to Drill Document Producer Well sP31-w7 Table of Contents 1. Well Name 3 Requirements of 20 MC 25.005(0 3 2. Location Summary 3 Requirements of 20 MC 25.005(c)(2) 3 Please see Attachment 7:Surface Platt 3 Requirements of 20 MC 25.050(b) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 MC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 MC 25.005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 MC 25.005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 MC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 MC 25.005(c)(7) 5 Requirements of 20 MC 25.005(c)(8) 6 Surface Hole Mud Program(extended bentonite) 6 Intermediate Hole Mud Program 6 (LSND) 6 Lateral Mud Program 6 (MI FazePro Mineral Oil Base) 6 8. Abnormally Pressured Formation Information 6 Requirements of 20 MC 25.005(c)(9) 6 9. Seismic Analysis 7 Requirements of 20 MC 25.005(c)(10) 7 03 AOGCC PERMIT Document Page 1 of 10 Printed: 12-Nov-14 volt • ' ChM PetiroIkuim enff Application for Permit to Drill SP31-W7 Saved: 12-Nov-14 10. Seabed Condition Analysis 7 Requirements of 20 MC 25.005(c)(11) 7 11. Evidence of Bonding 7 Requirements of 20 MC 25.005(c)(12) 7 12. Proposed Drilling Program 7 Requirements of 20 MC 25.005(c)(13) 7 13. Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 MC 25.005(c)(14) 8 14. Area of Review 9 15. Attachments 10 Attachment 1 Drilling Procedure 10 Attachment 2 Directional Plan 10 Attachment 3 Drilling Hazards Summary 10 Attachment 4 BOP and Diverter Configuration 10 Attachment 5 Cement Loads and CemCADE Summary 10 Attachment 6 Formation Integrity And Leak Off Test Procedure 10 Attachment 7 Surface Platt 10 Attachment 8 % Mile Scan Report 10 Attachment 9 Casing Design Program 10 mimimimmmmimmommmommmiiisiiimmmimimmimimmim 03 AOGCC PERMIT Document Page 2 of 10 Printed:12-Nov-14 rio • Einiii PetroIkum en Application for Permit to Drill SP31-W7 Saved: 12-Nov-14 1. Well Name Requirements of 20 MC 25.005(0 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: SP31-W7 2. Location Summary Requirements of 20 MC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation, and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objec6Ve formation and at total depth; Location at Surface 4434 FSL, 1460 FEL, S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 54.1 ft'AMSL Northing: 6,053,615' Easting:511,450' Pad Elevation 13.1 ft'AMSL Location at Top of Productive Interval 2456 FSL, 5080 FEL, S25 T14N R8E UM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 13,377' Northing: 6,046,349' Easting: 502,756' Total Vertical Depth, RKB: 3,499' Total Vertical Depth, SS: 3,445' Location at Total Depth 3698 FSL, 5207 FEL, S10 T14N R8E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 22,951' Northing: 6,051,872' Easting: 495,779' Total Vertical Depth, RKB: 3,476' Total Vertical Depth, SS:- 3,422' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(b); Requirements of 20 MC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan 03_AOGCC PERMIT Document Page 3 of 10 Printed: 12-Nov-14 / L Pi*• Einii P❑ JLr I It�roll�l��nn1 Application for Permit to Drill SP31-W7 Saved: 12-Nov-14 (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (13)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 MC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036, or 20 MC 25.037, as applicable; Please see Attachment 4: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 MC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards, including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is: MPSP = (3,527'TVDss)(0.45 - 0.11 psi/ft) = 1199 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo pressured strata,lost circulation zones, and zones that have a propensity for diferential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 MC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (S)a description of the procedure for conducting formation integrity tests as required under 20 AAC 25.030(f); Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 03_AOGCC PERMIT Document Page 4 of 10 Printed: 12-Nov-14 tri* f • Eiriiii P en Application for Permit to Drill SP31-W7 Saved: 12-Nov-14 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre- perforated liner,or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/7bg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (R) (R) (R) Cement Program 20 Driven 178.89 X-65 Welded 160 36 / 36 160'/ 160' Pre-Installed 13-3/8 16 68 L-80 BTC 2686' 35/ 35 2721'/ 2454' Surface Lead: 424 bbls 12.5ppg DeepCrete 63 bbls 9-5/8 12-1/4 40 L-80 Hydril 563 13288' 33 / 33 13321'/ 3495' DeepCrete Lead: 182 bbls 15.8ppg Tail 48 bbls 5-1/2 8-3/4" 15.5 L-80 Hydril 521 9830' 13121'/ 3481' 22951'/ 3476' Liner in Open Hole-no cement 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified/n the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2),• Please see Attachment 4: BOP Configuration. 03_AOGCC PERMIT Document Page 5 of 10 Printed: 12-Nov-14 Ci PetirolleLuimEn ens Application for Permit to Drill SP31-W7 Saved 12-Nov-14 Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An appl/cation for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost _ Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 sf) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (LSND) (MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point • , Value Density(ppg) 8.7-9.4 Density(ppg) 8.8 - 9.5 Plastic Viscosti - 5 Funnel Viscosity (CP) (seconds) 45 60 Yield Point Plastic Viscosti (lb/100 sf) 14 20 Viscostiy 12 - 18 (CP) HTHP Fluid loss Yield Point (ml/30 min <5.0 (lb/100 sf) 18 24 200psi& 100°F API Filtrate Oil/Water (cc/30 min)) 4 6 Ratio 60 / 40 Chlorides(mg/I) <500 Electrical >600 pH 9.0 - 10.0 Stability MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 MC 25.005(c)(9) All application for a Permit ro Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the appl/cation: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.033(0; Not applicable: Application is not for an exploratory or stratigraphic test well. 03_AOGCC PERMIT Document Page 6 of 10 Printed: 12-Nov-14 en 11 11191101• En PtiroIIeum Application for Permit to Drill SP31-W7 Saved: 12-Nov-14 9. Seismic Analysis Requirements of 20 MC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: /10)fnr an ernlnratnry or stratioraphir test Weil a seismic refraction or refectinn analvcic ac reonired by 20AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 MC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an of'chore platform mobile bottom-founded structure,jack-up ng, or floating drilling vessel,an analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 MC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showina that the requirements of 20 AAC 25 025(Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 MC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Please refer also to Attachment 1— Drilling Procedure 1) Move in / rig up Doyon 15. 2) RU Diverter and test as per AOGCC requirements. • 3) Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4) Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 5) Install and test wellhead to 5000 PSI. 6) Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. - 7) Pressure test casing to 2500 psi per AOGCC regulations. Record results. 8) PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. , 9) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording- results. Min LOT= 11 ppg. 10) Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. • 11) Install 9-5/8"casing rams in the BOP and test to 3500 PSI. 12) RU casing drive system. 03 AOGCC PERMIT Document Page 7 of 10 Printed: 12-Nov-14 • Einii PtIr©IkLuIuTr11 en 11 Application for Permit to Drill SP31-W7 Saved- 12-Nov-14 13) Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 14) Install 9-5/8"Emergency Slips. 15) Install 9-5/8" packoff and test to 5000 psi. 16) Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. tc- 17) Pressure test casing to 3000 psi per AOGCC regulations. Record results. 18) PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 19) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. Min FIT= 12 ppg. 20) Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming. 21) RU to run 5-1/2"slotted liner ' 22) PU and run 5-1/2"slotted liner to TD. 23) Land liner, set liner hanger with 200' Liner lap inside the 9-5/8"intermediate casing. POOH laying down DP as required. 24) RU tubing running equipment and run 4-1/2"tubing. Land tubing. Set BPV • 25) Nipple down BOP, nipple up tree and test void to 5000 psi for 10 min. • ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). (1). O • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the ?A-Z�K tree as there is no vertical tree on this wellhead. o-- j2' • Wellhead schematics should be on file with the AOGCC. 26) Pull BPV and set TWCV. 27) Fill tree with diesel and function valves. Test and chart tree to 500 psi for 5 min. Test and chart tree to 5000 psi for 15 min. 28) Pull TWCV. 29) Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 30) Set BPV and secure tree and wellhead. 31) RDMO 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point or Spy Island Class I disposal well. Alternative disposal method will include hauling the fluids to the Prudhoe Bay Grind and Inject Facility. 03 AOGCC PERMIT Document Page 8 of 10 Printed: 12-Nov-14 wok • Eini PetiroIkuim eno Application for Permit to Drill SP31-W7 Saved: 12-Nov-14 14. Area of Review Requirements of 20 MC 25 To the knowledge of Eni US Operating Co. Inc. there are no other wells completed in the Schrader Bluff formation other then those stated in the attached 1/4 mile scan report. The Nikaitchuq Unit also includes the following wells drilled by Kerr McGee Oil &Gas Corporation: Nikaitchuq #1: Plugged and Abandoned 04/01/04 Nikaitchuq #2: Plugged and Abandoned 04/01/04 (East of Nikaitchuq Unit) Nikaitchuq #3: Plugged and Abandoned 04/26/05 Nikaitchuq #4: Plugged and Abandoned 04/21/05 Kigun #1: Plugged and Abandoned 03/30/05 Tuvaaq State #1: Plugged and Abandoned 03/09/05 To Eni US Operating Co. Inc.'s knowledge all wells have been cemented across the Schrader Bluff formation as per AOGCC regulations and plugged and abandoned. All wells that fall into the 1/4 mile radius said herein have been drilled and completed in the Schrader Bluff formation in accordance with 20 MC 25 AOGCC regulations. Please See attachment 8— 1/4 Mile Scan Report 03 AOGCC PERMIT Document Page 9 of 10 Printed: 12-Nov-14 • Enfl Petirolleum env Application for Permit to Drill SP3 1-W7 Saved: 12-Nov-14 15. Attachments Attachment 1 Drilling Procedure Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 BOP and Diverter Configuration Attachment 5 Cement Loads and CemCADE Summary Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt Attachment 8 % Mile Scan Report Attachment 9 Casing Design Program 03 AOGCC PERMIT Document Page 10 of 10 Printed:12-Nov-14 Attachment 1 Drilling Procedure ennil us op rratt ng WELL SP31-W7 Drilling Procedure SP31-W7 Spy Island Conductor slot #31 Reservoir location #W7 Producer (Schrader Bluff) Nikaitchuq Project SP21-NWI. Drilling Wellplan Page 1 of 39 11/12/14 fi fif* 2nd us opCr 1Ciing WELL SP31-W7 Spy Island Nikaitchuq Field eno petroleum North Slope - Alaska SP31-W7 DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD TVD SIZE SPECS INFO Cement to Surface 20" 0 Hole Angle ° X-65 0° 20"Conductor Shoe 160' 150' Driven Welded N/A Y 0 GR/Res .. Surface Csq Dir/PWD a0 13-3/8" 0 y 68# MW(ppg) Wellbore Stability Mud Motor B/Pernefrost 1,811' 1,752. 'A L-80,BTC 8.8-9.5 Lost Circulation W Hole Cleaning r^ Casing Sections KOP:400' ° Casing Wear DLS: Surface TI Tail Cement 2,216' 2,104' 0-3.8°/100' Hole Angle 55.35 Deg 13 3/8"Csg 2,721' 2,454' 16" 50°F WBM GR/RES/PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40# MW(p)9) Hole Cleaning L-80,Hydril 563 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: Casing Wear 86.00 Deg �, BHA Expense Intermediate TOC 10,713' 3,132 ' Pick-up Top of Sand N In O O N Top 11,713' 3,332' m ro 9 Q R m Hole Angle TOL 13,121' 3,481' 110 1!. 86.00 Deg 9 5/8"Csg 13,321' 3,495' 12.25" 85°F WBM GR/RES I I ADN/PeriSCOPE El El Wellbore Stability S- I I Lost Circulation E.E. I I ¢iott°d I in.., Hole Cleaning 1 I 11`x(115-1/2" Torque&Drag 15.5# MW(ppg) Casing Sections Xceed 6751 L-80,Hydril 521 8.7-9.4 Casing Wear F. I 1 BHA Expense 1 1 2 I 1 Liner shoe TD 22,951' 3,476' __El IV Hole Angle 92.34 Deg 8-3/4" 85°F MOBM SP31-W7 Drilling Wellplan Page 2 of 39 11/12/14 eni us operrCrnns WELL SP31-W7 Table of Contents WELL PLAN SUMMARY 4 MIRU SECTION 6 SURFACE SECTION 7 Surface Drilling 8 Surface Casing 11 Surface Cementing 14 Pick Up Intermediate Drilling Assembly 16 INTERMEDIATE SECTION 17 Intermediate Drilling 19 Intermediate Casing 20 Intermediate Cementing 23 Pick Up Production Drilling Assembly 25 PRODUCTION SECTION 26 Production Drilling 28 Production Liner 29 ATTACHMENTS 32 Recommended Drilling Practices 33 Health, Safety & Environment 34 Safety Meeting Topics 35 Well Shut In Procedure While Running Production Tubing 37 Conductor Broach—Contingency Cementing Plan 38 TAM PORT COLLAR Utilization Decision Tree 39 SP31-W7 Drilling Wellplan Page 3 of 39 11/12/14 119* 2no us operraCOng WELL SP31-W7 WELL PLAN SUMMARY Rig: Doyon 15 Type of Well: Producer Well Design: 13-3/8"Surface x 9-5/8"Intermediate x 5-1/2"Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survey Program& Procedures Take MWD surveys as frequently as needed,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-go lines. If a no-go or hard line has been or will be crossed,stop drilling immediately,and contact the Drilling Superintendent to discuss options. Mud Logging Program Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. SP31-W7 Drilling Wellplan Page 4 of 39 11/12/14 no us opereong WELL SP31-W7 OBJECTIVES: 1. Drill the well at or under AFE cost and time. Perform work in a safe and professional manner meeting all ENI Petroleum Health, Safety, and Environmental requirements. 2.Land Intermediate casing point within 100' radius of the planned directional target. 3.. Land the Intermediate hole section with the targeted inclination of 86° - 87° within the OA sand. Maximum dogleg severity shall be no greater than 3.5°/100' DLS in the lateral section. 4. Target Greater than 90% within the OA sand Reservoir. 5.. 8-3/4" hole LWD Failure Requirements: GR/Res/Dir/PWD—Require GR/Res/Dir to achieve TD. SP31-W7 Drilling Wellplan Page 5 of 39 11/12/14 eno us Op&rrahng WELL SP31-W7 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (ppfl Type (psi) (psi) (kips) 20 178.89 X-65 Welded 18.25 3240 4980 3417 1. Confirm that the identification markings on the conductor match the planned surface location with the "as-built survey." If identification markings are not present on the conductor, contact the Drilling Supt. prior to moving the rig onto the well. ➢ Each conductor is to be marked with a common pad elevation survey mark by the surveyors ➢ Surveyors to also mark each conductor with a degree of angle to set each horizontal wing valve 2. Move in and rig up. Record move distance and rig floor distance to pad and sea level in WellView and on IADC reports. Initiate a Rig Elevation Record and place it on the N drive. • Ensure all concerned parties(Directional Drillers,MWD Operators,and Geologists)are using the same rig floor elevation. 3. Post drilling permit in the rig office and company office. 4. Nipple up the Vetco Gray landing ring,Vetco starter head,the diverter spool,and the annular preventer. Function test the system. ➢ Notify AOGCC prior to spudding well and 24 hours prior to performing diverter function test ➢ Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. ➢ Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access to diverter line area ➢ Place drip berm under the end of diverter line 5. Verify that two 3"threaded nipples have been welded on the conductor on opposite sides. Include ball valves and Cam-Lock male fittings on each nipple. Ensure threaded ball valves can be installed without running into the OD of the diverter head. Nipples are to be used as follows: ➢ Assist in washing out surface casing hanger on cement jobs ➢ Take returns to Vac trucks while cementing ➢ Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Refer to the detailed MI-Swaco Mud Program(attached). SP31-W7 Drilling Wellplan Page 6 of 39 11/12/14 41W, eni us operating WELL SP31-W7 SURFACE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan P8) True Measured Formation Tops Vertical Comments Depth,ft Depth,ft SV-4 760 760 SV-3 1130 1122 SV-2 1396 1373 B/Permafrost 1811 1752 SV-1 1999 1922 Ugnu Top(UG4) 2372 2225 13-3/8" Csg 2721 2454 SCP UG-2 Coal Bed Marker 3541 2722 Lower Ugnu 10330 3079 Schrader BluffTop 11326 3255 N Sequence Top 11544 3299 N Top 11713 3332 ReCalc Intermediate Cement w/Actual N Bottom 11838 3354 N Sequence Base 12038 3386 OA Top 12889 3466 F-A20 12894 3466 Fault 13042 3476 9-5/8" Csg 13321 3495 ICP OA Top 13363 3499 OA-2 Top 13421 3502 Fault 14988 3532 Fault 17733 3576 Fault 21700 3522 5 1/2" Liner 22951 3476 Total Depth SP31-W7 Drilling Wellplan Page 7 of 39 11/12/14 ....w enn us operrafing rill WELL SP31-W7 Surface Close Approach Wells NOTE: It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. Surface Mud Program: NOTE: Maintain Weight up Schedule as listed below to casing point API Fluid Density 6 RPM Chlorides Interval Depth (PPO Reading Loss (mg/1) PH (ml/30min) 110'— 1800' 8.8-9.2 20—24 <8 <2000 9.0—9.5 Surface: 1800'—C.P. 9.2—9.5 20—24 <6 <2000 9.0—9.5 Surface Logging/Formation Evaluation Program: Surface: MWD Directional LWD GR/Resistivity Surface Drill Pipe Pipe WT Grade Conn. Tool Tool Body Make Up Joint Body DP Tensile (ppJ) type Joint Joint ID(in) Torque Torsion Torsional capacity Capacity OD ID(in) (ft.lbs) al Yield Yield w/conn. (kips) (in) (fi lbs) (ft.lbs) (gal/ft) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 _ 82,700 74,100 .731 712 5"HWDP 49.5 S-135 TT525 6.625 3.250 3.250 83,200 118,900 126,000 .43 990 Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Efforts should be made to minimize high doglegs in surface hole. ESP equipment will be damaged running through high doglegs. Inform the Drilling Engineer of any doglegs over 6 degrees per hundred. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures • Flow rates and hole cleaning • Ported float valves are required in all hole sections • Ensure lecithin is added to the mud system. SP31-W7 Drilling Wellplan Page 8 of 39 11/12/14 2n0 Ms (o)p raiing WELL SP31-W7 Surface Hole Procedure: 1. Pick up and drift all DP,HWDP,and DC's for surface section to confirm free of debris. 2. PU BHA(Include GWD if MWD surveys are not clean initially)for directionally drilling to Surface Casing point with one BHA 3. Directionally drill surface hole: ➢ Drilling Parameters: • 650-800 GPM • Lower flow rates of 450-600 GPM will help avoid anti-collision boundaries by minimizing hole washout and optimize dog leg capability in the build section • RPM:40-80 RPM > Avoid anti-collision boundaries > Take MWD surveys as frequently as needed. Carefully review the anticipated close crossings with existing wellbores. Make sure that directional drillers are aware of all drilling close crossing issues,hardlines and no-go lines. If a no-go or hardline has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. 4. Hole conditions will always determine final mud properties. ➢ Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas-cut mud before continuing to drill. • Due to expected gas hydrates,keep mud as cool as possible(cold lake water). • Control drill at 100 to 120 fph through any troublesome zone so the hole does not load-up with gas cut mud. • Check and report trip gas. • Have 2 ppb Lecithin on location prior to drilling below the permafrost to minimize the effects of hydrates on the mud if hydrates are encountered. ➢ Consider adding 0.5%Drilzone for screen blinding in shallow intervals right below the conductor. 5. Surface casing point: ➢ Landed in good shale found in this area between 2454'TVD ➢ Below the sand at the base of the Sagavanirktok Formation(SV-1). ➢ Inside the upper Ugnu(UG-4). > Drill the footage necessary to leave the appropriate amount of rathole below the casing shoe. 6. Backream out of the hole at surface casing point: ➢ Circulate until shakers are clean(+/-3 to 5 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 800 GPM or higher • 80 RPM or higher > Backream to the HWDP • 800 GPM or higher • 80 RPM or higher • Pull 5-10 feet per minute • Decrease backreaming speed as torque and pump pressure dictate. SP31-W7 Drilling Wellplan Page 9 of 39 11/12/14 2(n11 us op rraCong WELL SP31-W7 • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the HWDP. Do not attempt to pull out on elevators once backreaming has started. • Expect+/-100%increase in cuttings from 2400'-600'. • Lesson Learned from OP09-S 1:While backreaming out of the hole in the transition from horizontal to vertical,have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate ➢ Once the HWDP is reached,circulate until hole is clean(shakers clean) 7. Pull and lay down BHA. 8. Perform a dummy hanger run before running casing. SP31-W7 Drilling Wellplan Page 10 of 39 11/12/14 rn10 us operr Hng WELL SP31-W7 Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (ppf) Type (in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Surface Casing Connection Make Up Torque(ft.lbs) OD WT Opt. (in) (PPf) Grade Conn.Type Make Up Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casing Running Notes a. Surface casing will be landed on hanger and emergency casing slips will be the contingency plan. b. Rig up and utilize a Fill Up tool for the casing job. c. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. d. Any packing off while running casing,and especially while above the base permafrost,should be treated as a very serious problem if major returns are lost. Run 4"lines from side outlets on conductor to a Vac Truck to help reduce pack off problems and minimize chance of spill. It is preferable to pull casing out until circulation can be re-established rather than risk not getting cement to surface. Contact the Drilling Superintendent if the casing packs off high for discussion of the options. e. Have Vetco representative verify the correct casing hanger is on location prior to the point at which it is needed. f. Torque values for the BTC casing are determined at the rig by making up the connection to the make-up mark (base of triangle). Record torque values for the first 10 connections made up in this manner and average. This average will be used as the make up torque for the remainder of the string. 1. Inspect and drift all surface casing to 12.259". 2. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. 3. While RIH with the the Casing: D obtain SO Weights every 10 ioints D obtain PU Weights every 10 joints SP31-W7 Drilling Wellplan Page 11 of 39 11/12/14 ono us operating WELL SP31-W7 4. Run the surface casing as follows: Surface Casing Running Order I Float shoe Bakerlock 2 2 joints 13-3/8"68#L-80 BTC casing Bakerlock 3 Float Collar Bakerlock 4 13-3/8"68#L-80 BTC casing ** TAM BTC port collar+/-500 ft Only run if losses are expected 6 13-3/8"68#L-80 BTC casing to hanger 7 Vetco Gray 13-3/8"mandrel hanger 13-3/8"landing joint Slick landing joint if not 8 running the TAM port collar **If TAM port collar is run: • A landing joint,which has a connection that can be broken below the rotary table,will need to be run to allow for running the drill pipe inside the 13-3/8"without needing a false rotary table. Also,the drill pipe running tool needs to be on location and stood back in the derrick ready to run in case the TAM port collar needs to be opened to circulate cement to surface. • If decision to run is at the last minute,ensure the additional footage of the port collar plus handling pup will allow for sufficient rathole below the surface casing shoe. Surface Centralizers + - 15 I 3-3/8"Tandem Rise Weatherford SP31-W7 Drilling Wellplan Page 12 of 39 11/12/14 2 fn1 B M s Co)p C'r�o i n g IWELL SP31-W7 Surface Centralizer Placement 10' oa 13-3/8"x 16"Tandem Rise Centralizers Collar • 2 at 5'&8' above Float shoe on stop collars,using stop buttons or stop1111/11. collars. • No centralization on collar of 1' joint. • 1 at 10'above Float Collar,using stop buttons or stop collars. • From 3rd joint through tail slurry(500'tail slurry),1 centralizer per joint run on collars. Do not allow centralizer to float between collars. • 2 on 13-3/8"casing collars,inside conductor @ TD so csg can be reciprocated. Alm 8' 5' A SP31-W7 Drilling Wellplan Page 13 of 39 11/12/14 1%1 en!' us operrahnng WELL SP31-W7 Surface Cementing Program Section Casing Size Type of Fluid /Cmt Volume Properties Mudpush II 100 bbls Density10.1 ppg Lead Slurry 424hhls Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) Yield 2.33 ft3/sk Tail Slurry (DeepCRETE) I,,hhla Density 12.5 ppg Top of Tail @ 2,216' MD Yield 1.50 ft/sk Surface Cementing Casing Cementing Notes a. Obtain and review the Test Report from the cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. b. Use split landing joint if TAM port collar is utilized and needs to be opened by running tool on drill pipe. 1. After reaching bottom, rig up and circulate with casing on bottom at 5 bpm, if possible, without losing returns. Reduce mud viscosity prior to pumping cement if necessary. ➢ To help ensure good cement to surface after running the casing, and if practical for existing hole conditions, condition mud to YP < 20 Ib/100ft2 prior to cementing the casing but after the casing is on bottom. Have adequate supply of cold lake water on hand to ensure the desired rheologies can be achieved. 2. Rig up to cement and pressure test cement lines. 3. Pump cement job per the attached Schlumberger cementing plan. Cement volumes are based on 35%excess below the Permafrost and 190%excess in the Permafrost. ➢ If necessary,verify that the TAM Tech has located the proper crossovers to his combo running tool ➢ If necessary,rack TAM running tool in derrick and ready to run ➢ Hook up or install a water inlet below the landing ring(to the 3"threaded nipples)and the mandrel hanger to add water to clabbered mud returns when necessary. ➢ Run 4"lines x-over from 3"side outlets to a vacuum truck. • Include a tee to allow for cement sampling 4. Report the number of bbls of cement returned to surface: ➢ Task one person to be in charge of monitoring for cement returns and volume of cement returns ➢ Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement at 6 bpm maximum. 8. Drop circulation rate to 2 BPM for last 10 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. ➢ Do not over displace the cement(no more than 1/2 the shoe joint volume). SP31-W7 Drilling Wellplan Page 14 of 39 11/12/14 ena us operating WELL SP31-W7 ➢ Watch for signs of packing-off during pumping operations and closely monitor the cellar area for mud or cement returns around the conductor. ■ The pack off problem has occurred on some offset wells when the hanger by-pass area was restricted. ➢ In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. ➢ AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indicated on the conductor markings. ➢ If there is any doubt about the proper orientation,call the Drilling Superintendent. ➢ Ensure that the seal between the casing hanger and well head is tested to 5,000 psi for 10 minutes. ➢ Measure the distance from the rig floor to the top flange of the well head and record on the IADC report and in WellView. Complete the Rig Elevation Record and place it in the electronic well folder. 12. Nipple up the 13-5/8"5M BOP stack and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing freauencv every 14 days unless notified otherwise by AOGCC SP31-W7 Drilling Wellplan Page 15 of39 11/12/14 • en0 us operating WELL SP31-W7 Pick Up Intermediate Drilling Assembly 1. Install wear bushing. Pick up: ➢ 12-1/4"bit • Rotary Steerable • PWD • GR/RES ➢ Flow rate of 900 GPM ➢ 120— 140 RPM 2. RIH to top of float equipment and pressure test surface casing to 2500 psi for 30 min and record on chart. ➢ Plot Casing Pressure Test on LOT form on N drive. Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. ➢ Note:All BHA trips thru the TAM port collar(if applicable)should be done slowly with slow rotation to avoid accidentally opening port collar. If set-down weight is noted,stop immediately,PU,resume slow rotation and try slacking off through port collar area. 3. Drill out the float collar&shoe. ➢ See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 4. Drill 20'-50' of new hole using spud mud. 5. Displace hole to new LSND mud system. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 11.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Plot on LOT form on N drive. SP31-W7 Drilling Wellplan Page 16 of 39 11/12/14 2nd us operrafi nng WELL SP31-W7 INTERMEDIATE SECTION Surface Formation Markers: (all depths Dovonl5: Schlumberger Plan (P8) True Measured Formation Tops Depth,ft Vertical Comments Depth,ft SV-4 760 760 SV-3 1130 1122 SV-2 1396 1373 B/Permafrost 1811 1752 SV-1 1999 1922 Ugnu Top(UG4) 2372 2225 13-3/8"Csg 2721 2454 SCP UG-2 Coal Bed Marker 3541 2722 Lower Ugnu 10330 3079 Schrader Bluff Top 11326 3255 N Sequence Top 11544 3299 N Top 11713 3332 ReCalc Intermediate Cement w/Actual N Bottom 11838 3354 N Sequence Base 12038 3386 OA Top 12889 3466 F-A20 12894 3466 Fault 13042 3476 9-5/8"Csg 13321 3495 ICP OA Top 13363 3499 OA-2 Top 13421 3502 Fault 14988 3532 Fault 17733 3576 Fault 21700 3522 5 1/2" Liner 22951 3476 Total Depth SP31-W7 Drilling Wellplan Page 17 of 39 11!12/14 rem us operafing WELL SP31-W7 Intermediate Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the "N" sand Interval Density PV 6 RPM API FL pH DrillSolidsMBT (PR) Reading (mU3Omin) (%) Intermediate: 9.2—9.4 12-18 12-18 <6.0 9-10 6.0 18 Intermediate Logging/Formation Evaluation Program: Intermediate: MWD—Directional/PWD(Pressure While Drilling) LWD—GR/Res Intermediate Drill Pipe Tool Joint Body DP Tool Make Up Tensile Pipe WT Grade Conn. Joint Joint Body Torque Torsion Torsional capacity Capacity (ppj) Type OD ID(in) al Yield Yield w/conn. (in) ID(in) (Albs) (ft lbs) _ (ft.lbs) (gal/ft) (APs) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 S-135 TT525 6.625 3.250 3.250 83,200 118,900 126,000 .43 990 Intermediate Section Notes: a. If the well is to be an ESP producer,a pump tangent must be placed in the intermediate hole section as per the planned directional profile. The pump tangent must be within 300'TVD from the top of the uppermost OA sand and at least 200'MD in length. b. Efforts should be made to minimize high doglegs above the pump tangent(if applicable). The ESP equipment will be damaged running through high dog legs(>6 degrees per hundred). c. Shallow test MWD tools. d. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. e. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. f. Keep shut down times to a minimum during connections. g. Swab/Surge: Make"easy on,easy off"slips a standard practice h. Control the ROP if necessary to maintain good hole cleaning i. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. SP31-W7 Drilling W ellplan Page 18 of 39 11/12/14 eno us ®perrfing WELL SP31-W7 Intermediate Drilling I. Directionally Drill 12-1/4" hole D. Use the following Parameters: • Flow rate of 900 GPM • 120— 140 RPM 2. Casing Point:Land Intermediate casing at 13,321'MD into OA Sand Reservoir. 3. LOW ROP:Consult with Town as ROP drops to<1-2 fl/hr for one(1)full hour. This usually occurs in the Lower Ugnu at high tangent angles(+80 degrees). Goal is to avoid excessive BHA and DP wear. Decision should be made to trip BHA out of the hole before excessive wear begins. 4. Backream at Intermediate Casing point: ➢ Circulate until shakers are clean(+/-5 to 7 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 900 GPM • 120-140 RPM ➢ Backream into the surface casing shoe. • 900 GPM • 120 RPM • Slow backreaming speed when pulling into the surface casing shoe/rathole. Hold parameters steady at 900 GPM and 120 RPM. Large chunks of coal can be deposited in the 16"rathole near the shoe. • Lesson Learned from OP09-S 1:While backreaming out of the hole in the transition from horizontal to vertical,have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. Check drilling nipple for overflow at BOP's. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the surface casing shoe. Do not attempt to pull out on elevators once backreaming has started. ➢ Circulate until shakers are clean(+/-3 to 7 bottoms up per K&M model)in the surface casing shoe • 900 GPM • 120 RPM 5. Pull and lay down BHA. SP31-W7 Drilling Wellplan Page 19 of 39 11/12/14 IV* enQ us operating WELL SP31-W7 Intermediate Casing Program: OD 14'T Conn. Cplg OD Collapse Burst Tensile Yield (in) (ppJ) Grade Type (in) ID(in) Driftt(in) (psi) (psi) (kips) Hydril **Special 9-5/8 40 1.-811 563 10.625 8.835 Drift 3090 5750 916 8.75 Intermediate Connection Make Up Torque (ft.lbs) Min. Target Max OD li'T Grade Conn. Type Make Up Make Up Make Up Yield Torque (in) (PMTorque, ft- Torque Torque lbs 9-5/8 40 L-80 H563i1 10,800 13.000 N/A 75,000 **Special Drift casing to 8.75 Intermediate Casing Interval Notes: a. Ensure proper sized rams are installed and tested prior to running intermediate casing. b. Rig up and utilize a casing fill up tool for the casing job. Shoe Track: 1. Have a spare float shoe and collar made up with centralizers and on location ready to go D Shoe joint misalignment has caused cross threading with Hydril 563 connection and requires make up by hand for first 10-15 joints • Make-up Shoe track(and first 10-15 joints)by hand using chain tongs until enough weight is in the slips to prevent cross threading • The shoe track joints should be Bakerlocked. • Inspect the float valves as the shoe track is picked up. • Run the shoe track into the well to test and confirm the floats are holding negative differential pressure. Connection Make Un: 1. Refer to the TenarisHydril"Running Manual General Guidelines"attachment for make up,pipe dope,etc....(Also available on Tenaris website) 2. Make up the first joint to the specified target torque and relax the tongs. D Draw a longitudinal line across the pin and box and reapply the published target torque. D If the drawn line does not move more than V2"after the second torque application,continue running the rest of the string normally using the published target torque. D If the drawn line moves more than'h"after the second torque application,this indicates that a portion of the torque was absorbed by other variables in the make-up system.If this occurs,follow these steps: • Increase the target torque by 15%and reapply the torque. • Draw a second line and apply the original,specified target torque. • If the second drawn line does not move more than%2",continue running the rest of the string normally using the 15%higher target torque. • If the second drawn line moves more than'/2",recheck the alignment,dope application and tong function, then continue to repeat this procedure from above until the drawn line does not move more than'h". SP31-W7 Drilling Wellplan Page 20 of 39 11/12/14 • en us op rr tang WELL SP31-W7 ■ It is best practice to repeat this procedure in the event the tongs are changed out during the running of the pipe. 3. Ensure that the joint about to be made up is hanging along the same axis as the joint in the slips. Due to the fact that sometimes the rig is a few inches off center the slips and bell nipple may have to be adjusted. Casing Running Order Float shoe—Davis-Lynch Model501-DV-PVTS Baker-Lock down-jet float shoe(double valve)**** 2 2 joints 9-5/8"casing Baker-Lock Float Collar—Davis-Lynch Model Type 700 DVSB- 3 LAPN double-valve float collar w/anti-rotation Baker-Lock baffle**** 4 9-5/8"Casing 5 9-5/8"Casing 6 Vetco Gray 9-5/8"mandrel hanger 7 9-5/8"landing joint Slick landing joint for reciprocation purposes Centralizers +/-54 9-5/8"x 11-3/4"Rigid Hydroforms(Crimped) Volant 1. Inspect and drift intermediate casing(drift 8.75"). 2. Centralizers(See Diagram Below) 3. Pull wear bushing. Install 9-5/8"rams and test. Pick up and run casing. 4. Monitor running speeds to minimize surge and swab pressures while running in or picking up off slips. ➢ K&M Engineer will provide a trip speed schedule for each intermediate casing run based on individual well mud properties,hole angle,and depth. ➢ Circulate casing capacity at surface casing shoe,then break circulation every+/-2,000' MD and check flow through floats. Circulate bottoms up each time. ➢ Monitor trip tank while running in hole. Reduce speed if decrease or loss of flow is noted. 5. While running in open hole with Casing: ➢ obtain SO Weights every 10 joints 6. Once on bottom with the casing: ➢ obtain PU and SO Weight 7. Run the casing string on bottom. Establish circulation rate and pressure while pumping at least 1-2 bottoms up to condition hole. Reciprocate casing while circulating and cementing. 8. If needed,circulate and thin mud to properties slightly as outlined in CemCADE and Mud plan summary after running casing to bottom and prior to pumping cement. SP31-W7 Drilling Wellplan Page 21 of 39 11/12/14 en us operating WELL SP31-W7 Intermediate Centralizer Placement Y ! M1119-518"x 11-3/4" Hydroform Centralizers Collar Run 1 INdroform: • 5'above Float shoe • No centralizernest joint • 10'abuseboseFloat t'ollar • From 4 th.joint to +/-1000 above the shot& 1 centralizer erimpul between collars • 1 centralizer crimped between collars from N sand oil bearing zone tet-/- 500' above \ sand oil hearing zone L SP31-W7 Drilling Wellplan Page 22 of 39 11/12/14 en Ls operating WELL SP31-W7 Intermediate Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Mudpush II 100 bbls Density 10.5 ppg Intermediate 9-5/8" DeepCrete 182 bbls Density 12.5 ppg Top of Cement @10,642' MD Yield 1.5 ft3/sk Tail 48 bbls Density 15.8 ppg Top of Cement@12,821' MD Intermediate Cementing Intermediate Cementing Notes: a. Obtain and review the Test Report from cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. If need be,confer with Drilling Superintendent. b. Do not over displace the cement(no more than V2 the shoe joint volume). c. For injectors,a cement bond log is required. Prefer to run sonic LWD in production hole BHA and log intermediate casing on trip in hole to drill out intermediate shoe. I. Perform Rig pump efficiency check and confirm+96%efficiency before pumping and displacing cement. 2. Ensure Schlumberger re-calculates cement volume based on"N"sand actual depth! ➢ Cement volume is based on 50%excess and at least 1000'of annular fill above top of the N sand(highest known hydrocarbon bearing zone). Refer to attached cement detail sheet for volumes. 3. Batch mix cement. Test cement lines and pump cement job as per the attached Schlumberger program. 4. Displace cement with rig pumps and LSND water-based drilling mud. ➢ Ensure that the cement unit and rig pumps are manifolded so there will be redundancy in case of any pump failure during displacement. ➢ Pump cement at 5 bpm and displace with 7.0 bpm if possible without losing returns. Slow rate to 3 bpm during last+/-30 bbls prior to bumping plug. 5. When the plug bumps,pressure the casing to 500 psi over the final displacement pressure and ensure that the string is holding pressure. Notify the Drilling Superintendent if the string will not hold pressure. Bleed off pressure and ensure the floats are holding. If the floats leak,pressure back up to final displacement pressure and shut in cementing head. 6. Land casing on mandrel hanger ➢ Maintain reciprocation as long as possible 7. Install Vetco 9-5/8"packoff assembly. 8. Pressure test packoff per Vetco Gray. ➢ Do not exceed 80%of intermediate casing collapse ➢ Record test on IADC report and in WellView SP31-W7 Drilling Wellplan Page 23 of 39 11/12/14 eno us operr ink WELL SP31-W7 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. D Cement Consistency of 50 Bc(Bingham consistency)is not pumpable. 50 Bc is achieved roughly 4 hrs after mixing cement and starting downhole. D Pressure limitations are as follows:80%of surface burst or 80%of intermediate collapse,whichever is less. ■ 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) D Freeze protect the surface by intermediate annulus with diesel at 1-1/2 to 3 BPM. Pump enough diesel to flush and freeze protect to the surface casing shoe. 10. Install rams and test per the AOGCC Permit to Drill(attached) D Test rams and choke manifold components to 3500 psi high/250 psi low D. Test annular preventer to 2500 psi high/250 psi low D Do not test BOPE against casing. D Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC 11. Install wear bushing. 12. Clean mud pits in preparation to receive OBM • Pits must be clean and free of all Barite SP31-W7 Drilling Wellplan Page 24 of 39 11/12/14 en us operfing WELL SP31-W7 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly as per the attached BHA diagram. ➢ 8-3/4"PDC > Rotary Steerable > Flow rate: 550 GPM ➢ 120—140 RPM 2. RIH to the float equipment. ➢ Pressure test the casing to 3000 psi for 30 min and record on chart(AOGCC required casing integrity test). ➢ Plot Casing Pressure Test on the Pressure LOT form in N drive Oil Based Mud Fluid Displacement 3. Displace casing to new Oil Based Reservoir Drilling Fluid ➢ Do not contaminate new OBM in rig pits ➢ Displace old water based fluid to trucks or exterior tanks for disposal 4. Drill out the float collar&shoe. ➢ See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 5. Drill 20'-50'of new hole using the Oil Based Reservoir Drill-ln fluid. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 12.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Do not pump more than 1/2 bbl after leak off is determined. There is no need to pump more than 1/2 bbl into the leak off and extend the fracture. ➢ Plot on LOT form in N drive SP31-W7 Drilling Wellplan Page 25 of 39 11/12/14 ena us Oo er 1COn WELL SP31-W7 PRODUCTION SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan (P8)) True Formation Tops Measured Vertical Comments Depth,ft Depth,ft SV-4 760 760 SV-3 1130 1122 SV-2 1396 1373 B/Permafrost 1811 1752 SV-1 1999 1922 Ugnu Top(UG4) 2372 2225 13-3/8" Csg 2721 2454 SCP UG-2 Coal Bed Marker 3541 2722 Lower Ugnu 10330 3079 Schrader Bluff Top 11326 3255 N Sequence Top 11544 3299 N Top 11713 3332 ReCalc Intermediate Cement w/Actual N Bottom 11838 3354 N Sequence Base 12038 3386 OA Top 12889 3466 F-A20 12894 3466 Fault 13042 3476 9-5/8"Csg 13321 3495 ICP OA Top 13363 3499 OA-2 Top 13421 3502 Fault 14988 3532 Fault 17733 3576 Fault 21700 3522 5 1/2" Liner 22951 3476 Total Depth SP31-W7 Drilling Wellplan Page 26 of 39 1 1/12/14 a ' em us op!rr in9 WELL SP31-W7 Production Mud Program: FazePro Density HTHP FL Electrical Interval (1)Pg) VP (m1/30min) Oil:water Stability mlVolts Production 9.2 14-20 <5.0 65:35 >600 Production Logging/Formation Evaluation Program: Production: MWD Directional/PWD(Pressure While Drilling) LWD GR/Res/ADN/PeriSCOPE Production Drill Pipe Tool Tool Make Up Joint Body DP Tensile WT Conn. Joint Body Torsion Torsional capacity Pipe (ppb Grade type OD Joint ID(in) Torque al Yield Yield w/conn. Capacity (in) ID(in) (ft.lbs) (ft lbs) (ft.lbs) (gal/ft) (laps) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 Production Section Notes: a. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow test MWD tools. c. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. d. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. e. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Onenhole Sidetrackine Practices: f. Lowside in a fast drilling interval where the wellbore is heading up and where the ABI's show a good build rate. g. Orient within 15 degrees either side of lowside and trough with high rotary RPM's while reciprocating from the kickoff point back to the first stabilizer. Trough for approximately 30 minutes. h. Time drill at 4 to 6 feet per hour with high flow rates and rotary RPM's for the first 5 feet. Gradually increase the penetration rate as the openhole sidetrack is achieved. i. If any openhole sidetracks are drilled,confer with Drilling Supt.and consider tripping without circulating or without rotating past the sidetrack point. SP31-W7 Drilling Wellplan Page 27 of 39 11/12/14 n� us opereornng WELL SP31-W7 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. ➢ Geosteering will be required to remain in the target boundary 100%of the time ➢ Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. > Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: ➢ At TD circulate 50%of calculated TAD cleanup cycle pulling I stand per bottoms up. Once the first 50% cleanup cycle is completed circulate the remaining 50%of the calculated cleanup cycle pulling 2 stands per bottoms up. Decrease backreaming speed as torque and pump pressure dictate. • 550 GPM • 120-140 RPM ➢ Backream into the intermediate casing shoe. • 550 GPM • 120-140 RPM • Slow backreaming speed when pulling BHA into the Intermediate casing shoe/rathole. Hold parameters steady at 550 GPM and 120 RPM. • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming. Do not attempt to pull out on elevators once backreaming has started. 3. Drop rabbit down drill string once bit is above the intermediate shoe:the SLM of landing string portion of the tapered DP • Drift OD dependent on Completion • COMPLETION DP RABBIT SIZE:2-3/8"OD • All drifting tools will be accounted for and held in one place at all times. 4. Continue backreamin¢until depth at which it is possible to null out on elevators at>9.1 swab EMW at 2.5 min/stand • 550 GPM • 120-140 RPM • Determine depth at which swab can be kept>9.1 EMW at 2.5 min/stand as per K&M TAD Model. 5. Circulate until shakers are clean as per k&M. • 550 GPM • 120-140 RPM 6. Slug DP and trip out of hole on elevators. SP31-W7 Drilling Wellplan lan Page 28 of 39 11/12/14 env us operating WELL SP31-W7 > Utilize K&M's swab model to control trip speed and avoid swabbing the open hole below 9.1 ppg EMW. 7. Lay down BHA ➢ When out of hole,down load the recorded tool data and send to the Geologist in town Production Liner Completion DP RABBIT SIZE Will BE: 2-3/8" OD Production Liner OD Conn. Cplg OD Collapse Burst Tensile Yield (in) WT(ppb Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) 5-1/2 15.5 L-80 H521il 5.713 4.950 4.825 4990 7000 242 Production Liner Connection Make Up Torque (ft-lbs) Min. Target Max. OD Grade Conn. Type Make Up Make Up Make Up Yield (in) (ppb Torque, ft- Torque Torque* Torque lbs 5-1/2 15.5 L-80 Hydril 521 4600 8100 N/A 24,000 * See attached TenarisHydril Guidelines for make-up torque recommendations Production Liner Centralization From To Quantity/Joint Fixed/Floating Type Shoe Liner 1/joint Fixed 5-1/2"x 7" top -Mid joint -Crimped on -Hydroform,Volant(Crimp on) Liner Running Procedure Notes: • Ensure proper crossover from DP to slotted liner is on the rig floor in case of a well control situation. • Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. • Ensure accurate torque and drag data is gathered. Record pick up and slack off weights every stand and free rotating torque every five stands. Data gathered will assist in future liner running operations throughout the project. • Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well and recorded in WellView. • Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. • Review all setting operations and shear pressures with Baker Oil Tools service hand. • Ensure that all workstring components have been rabbited as ball will be dropped to actuate downhole tools.Rabbit DP on last trip out of prior to running liner. • If any openhole sidetracks have been drilled,monitor sidetrack depths during run in and ensure shoe enters the correct hole. SP31-W7 Drilling Wellplan Page 29 of 39 11/12/14 2nd us operafing WELL SP31-W7 • DO NOT run E-CD subs on drill pipe while running liner string. • Torque ratings for string components: String Components Yield Torque(ft-lb) 5" 19.5#TT525 Drill Pipe 74,100 HRD Running Tool 40,000 7"29#Hydril 563 39,000 5-1/2" 15.5#Hydril 521 24,000 • Shear pressures for liner hanger assembly: Item Description Shear Value Shear Range HRD Running Tool,7" Nominal- 3192 psi 15%+ 3671 psi 6795 mch rel,3 pins 15%- 2713 psi Pusher Tool Activation Nominal - 1986 psi 15%+ 2284 psi 15%- 1688 psi Pusher Tool Neutrlz. Nominal- 3588 psi 15%+ 4126 psi 15%- 3050 psi Ball Seat SOLID --"Make-up torque for liner hanger sub-assembly,including running tool connections,should be torqued to 14,000 ft-lbs prior to deliver to rig. Procedure: 1. Hold Pre job safety meeting to ensure all parties understand operation 2. PU the Liner Assembly and Running/Inner String as outlined above. 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. Fill Liner Tieback Sleeve with"pal mix"and ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 minutes for mixture to set up. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. Record ROTATE,PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIH with Liner Assembly as hole conditions allow,but do not exceed running speed of one stand per minute. Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. Circulate minimum of one DP volume and record ROTATE,PU and SO weights. 8. Record PU, SO,and Rotating torque in open hole every 500' to ensure friction factors are sufficient to run the liner to bottom successfully. If friction trend indicates liner will not go to bottom then call Drilling Supt.immediately. 9. Rotating liner 20-60 RPM will be necessary to run to bottom. 10. Continue RIH with Liner Assembly to proper setting depth. Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8"casing shoe. 11. Trip slightly deeper than desired liner top location with liner top. Last motion of the liner should be up to ensure it is set in tension. Ensure Liner Hanger assembly does not exit 9-5/8"casing shoe. 12. Prior to setting the hanger&packer,double check all pipe tallies and record amount of drill pipe on location. SP31-W7 Drilling Wellplan Page 30 of 39 11/12/14 eni us operating WELL SP31-W7 13. Rig up to pump down workstring with rig pumps. Pressure test lines. Bleed off test pressure. 14. Drop setting ball down the workstring and pump slowly(1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 15. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 minutes each up to 4000 psi. 16. Packer can now be pressure tested. Bleed DP pressure to zero,close annular preventer and test annulus to 1,500 psi for 10 minutes and chart. 17. Bleed off pressure and pickup to verify that the HRD running tool has released. If packer did not test,rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, 6,795 ft-lbs of left hand torque can mechanically release the tool. 18. Once running tool is free and packer is tested, Displace mud from liner top to surface with 9.0 ppg KCl brine per MI recommended program. 19. POOH and LD and inspect the liner running tools. SP31-W7 Drilling Wellplan Page 31 of 39 11/12/14 e nno us operrfi nng WELL SP31-W7 ATTACHMENTS 1. Recommended Drilling Practices 2. Health,Safety,and Environment 3. Safety Meeting Topics 4. Well Shut In Procedure While Running Tubing 5. Conductor Broaching Contingency Plan 6. Port Collar Decision Tree SP31-W7 Drilling Wellplan Page 32 of 39 11/12/14 em us operraCing WELL SP31-W7 Recommended Drilling Practices Hole Cleaning With a deviated well path and potential for losses,hole cleaning will require special practices. Pipe rotation is critical for effective hole cleaning. The maximum string RPM,as determined by the BHA,is specified for each hole section in the detailed procedures. The shakers should be monitored as an indicator of adequate circulating time. If circulation is of long duration,then pipe movement to prevent casing wear is critical and a stand should be laid down occasionally to prevent excess hole erosion over the length of pipe reciprocation. In addition the following practices should be employed at all times: a) Use all available solids control equipment to keep mud as clean as possible. b) Emphasize proper hole cleaning after slides by rotating at maximum allowable RPM c) As the hole angle increases,hole cleaning practices must be altered. Maximum pipe rotating speeds along with maximum achievable flow rates will increase hole cleaning efficiencies. Circulating times prior to trips should be increased accordingly to account for longer times required to remove cuttings from higher angle wells. d) Use good connection practices while drilling. After reaching the bottom of a stand,allow a small amount of circulating time to allow cuttings to get above the BHA prior to picking up off bottom. Be sure to pick up slowly to prevent packing off the cuttings bed around the top of the drill collars. Slower Trip/Connection Speeds High POOH and RIH speeds can aggravate fragile shales/formations due to the pressure variations between surge/swab. PWD data shows that excessive tripping and reaming speeds can exert pressure spikes in excess of 2 ppg equivalent. Effective ROP Strive to find the maximum effective rate of penetration.That is,the maximum rate at which a clean hole can be produced. While on bottom ROPs in excess of 400 fph may be possible,but such ROPs may load a high angle hole with cuttings that are not being removed fast enough. Using torque and drag trends,ECD and the shakers,establish a base line clean hole ROP,and then try to improve it by altering the hole cleaning practices. Slower Initial Pump Rates PWD data has shown that the most significant period for increased ECD occurs when the pumps are brought on at drilling rate while washing a connection to bottom. The study also concluded the least damaging procedure is if pump rates are held at 40%or less of drilling rate while reaming connections. SP31-W7 Drilling Wellplan Page 33 of 39 11/12/14 orisTok, 2no us operating WELL SP31-W7 Health, Safety & Environment The following are part of the mitigation&contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. H2S Contingency Measures Assume all locations have the potential for H2S. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H,S encounter,drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures,full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,daily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. SP31-W7 Drilling Wellplan Page 34 of 39 11/12/14 en us operrfinng WELL SP31-W7 Safety Meeting Topics Move In, Rig Up > Prior to spud,a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads-use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with various sizes of pipe and tubing, - Well control procedures, - Flow rates and hole cleaning,and - Diverter operation and crew responsibilities. ➢ A Diverting Shallow Gas'drill should be held with rig crews prior to spud,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ An'Accumulator'drill should be held with rig crews prior to spud. Document drill and record on morning report. ➢ Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. ➢ Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. > Perform and document all drills. ➢ Designate crew member to control access at the pad entrance in case of diverter operation. Surface ➢ A'Stripping'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A'Well Kill'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss production hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. SP31-W7 Drilling Wellplan Page 35 of 39 11/12/14 ..„,w enn ass operrafing WELL SP31-W7 ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Completion ➢ Operation of the control line spooler. ➢ Pinch points associated with tongs and slips. ➢ Proper tripping practices and hole fill calculations with tubing and control line. ➢ Well control practices while running production tubing with control line. ➢ Pressure testing and minimizing personnel exposure to pressurized lines. SP31-W7 Drilling Wellplan Page 36 of 39 11/12/14 4„,„w. • eno us ©perraHng WELL SP31-W7 Well Shut In Procedure While Running Production Tubing If well is suspected to be flowing: 1. Install TIW valve and pull back to the first banding point below the BOP stack. 2. Shut off air to control line spool and bleed off line pressure while checking well for flow. 3. If well is confirmed to be flowing,cut control line with bolt cutters directly above a banding point. 4. Slack off until full joint of pipe with no control line attached is spaced out across BOP stack. 5. Close annular and monitor pressure. If well is coming in rapidly and time is not permitted to complete above operations: 1. Install TIW and close annular around pipe and control line. 2. Shut off air to control line spool and bleed off line pressure while picking up a joint of drill pipe and making it up to TIW and top drive. 3. Close IBOP on top drive and open TIW valve. 4. Cut control line and strip the joint of drill pipe across stack for ram closure if needed. 5. If annular does not seal off around tubing and control line and the joint of drill pipe cannot be safely picked up, close blind/shear rams on production tubing. Notes: • Specify location of bolt cutters required to cut control line. • Need to have access to a joint of drill pipe and the appropriately sized elevators at all times. SP31-W7 Drilling Wellplan Page 37 of 39 11/12/14 2rr110 us operrahng WELL SP31-W7 Conductor Broach — Contingency Cementing Plan In the event of a broach to surface of drilling fluids during the drilling of the surface interval,the following contingency plan is recommended to remediate the situation. Conductor Hole Diameter Conductor Casing Size 20" Conductor Setting Depth +/- 120'MD DP/Conductor Annular Volume 5"DP x 18.25"ID:(36 bbls) Conductor Pipe Volume 39 bbls 16"Open Hole Capacity 0.2487 bbls/ft 1. Upon establishing that a broach of the conductor casing has occurred,POOH and stand back BHA. 2. RIH with open-ended drill pipe to 20'below the base of the conductor pipe. 3. Establish circulation with mud at normal drilling rate. Begin circulating and establish rate of flow through broach with drilling fluid. 4. Circulate up to 120 bbls of water or until water returns are seen from the broach. 5. RIH to 200'below the base of the conductor. If mud viscosity is<300sec/qt.,spot a 150'pill of 150K cp polymer (Biozan)to 50'below the conductor. POOH to 20'inside the conductor. 6. Mix and displace+/-80 bbls of Artic Set 1 cement at 15.8 ppg. Cement may U-tube with no ability to obtain squeeze. Do not over displace DP. Monitor and gauge all returns. 7. POOH and WOC for 8 hours. 8. PU 16"bit and BHA and RIH to clean out cement to 40'below conductor. Establish normal circulating rate and evaluate broaching. If no broaching is seen,continue with planned operations. If additional broaching occurs, repeat steps 6,7 and 8. SP31-W7 Drilling Wellplan Page 38 of 39 11/12/14 eno• us operating WELL SP31-W7 TAM PORT COLLAR Utilization Decision Tree TAM Port Collar Utilization Decision Tree Begin Primary One Stage Cement Job No Cement ement to to Surface Surface • V Drilling Foreman and ipple Up and Engineer determine the est BOP's Top of Cement • Top of Top of Cement Cement tontinue with above Port below Port omplefion Collar Collar (1000'TVD) (1000'TVD) • ♦ Indicators of Cement Top Perform Top Job as per ► Open Port Coll 1. Observation of Tracers in Spacer ahead of lead cement requirements of j If Top Job is ineffective or using drillpipe p AOGCC unacceptable to AOGCC 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface ♦ -_ ♦ Nipple Up and Circulate Cemen Test BOP's to Surface and close Port Collar ♦ — - • Continue with Nipple Up and Completion Test BOP's I -- V Continue with Completion SP31-W7 Drilling Wellplan Page 39 of 39 11/12/14 Attachment 2 Directional Plan *ii°"* Schlumberger en SP31-W7(P8)Proposal Geodetic Report (Del Plan) Report Date: June 05,2014.12:32 PM Survey/DL5 Computation: Minimum Curvature/Ludneb Client: En!Petroleum Vertical Section Axlmuth: 305.000•(True NOT) Field: NIMIMuq �� Vertical SeNbn Origin: 000011.00006 Table Well:Structure lSlat: Spy 1-Wb/5P31 B6BO[IV(y°(}R)g011t/ TVOGroRee4vee EHvetion:TVO Relerence Datum: �00B Wove MSL Well: SP31-W] �f iSW`�'U 11 above MSL nd B orehole: 5P31-W7 API#: 50829immd)0 Magnetic Declination: 18.977• Survey Name: SP31.W 7(P8) Total Gravity Field Strength: 1001 9929mgn(9.80665 Bae) Survey Date: May 20,2014 Gravity Model: GARM Tort/AHD/251/BBS Retb: 254.486•/21030.18711/7.535/5.873 Total Magnetic Field Strength: 57615 921 nT Coordlnele Reference System: NAD27 Alaska State Plane,Zone 04,US Feel Magnetic Dip Angle: 81.058• Location Let/Long: N 70.33'2769815,W 149.54.21 91285• Declination Date: December 31,2014 L ocation Grid N/E 5/X: N 8053614 950 BUS,E 511450.170 BUS Magnetic Declination Model: BGGM 2013 CRS Grid Convergence Angle: 0.0886• North Reference: True North Grid Scale Factor: 0.98980015 Grid Convergence Used: 0.0000° Version/Patch: 27.1043.0 Total Corr Mag North->Trce North: 18.9768• Local Coord Referenced To: Weil Head YO Incl eats,True 7VDS5 TVO VSEC NS EW h COLS Dkaglbnl Exclusion Zone n Eon. Ertlnp NorthingComments (0 (1 (1 (8) (II) pt) (B) (It) (1 (Twin Difficulty Yt 8ggltylndANN Arpin (BUS) (CUD) 21 RTE 0.00 0.00 170.00 54.10 000 0.00 000 0.00 170M N/A 0.00 894 511450.17 605381495 100.00 0.00 170.00 45.90 10000 0.00 0.00 0.00 170M 0.00 0.00 894 511450.17 6053614.95 200.00 0.00 170.00 145.90 20000 0.00 0.00 0.00 170M 0.00 0.00 894 511450.17 6053614 95 300.00 0.00 170.00 245.90 30000 000 000 0.00 170M 000 0.00 894 511450.17 605301495 KOP Cry 1.5100 400.00 0.00 170.00 345.90 40000 000 000 0.00 17004 0.00 0.00 884 511450.17 605361495 500.00 1.50 170.00 445.69 49999 0.93 -129 0.23 170M 1.50 0.29 1028 511450.40 6053613.66 Cm 2.75/100 600.00 3.00 170.00 545.81 59991 -3.70 -5.18 091 202.4904 1.50 1.20 1166 511451.09 6053609.80 700.00 4.78 202.49 645.59 69989 -645 1137 6.22 215,504 2.75 1.83 13.70 511449.96 6053803.38 800.00 7.17 215.50 745.04 79014 -7.30 -2049 .5.44 221.83M 2.75 2.28 1595 511444.77 6053594.46 900.00 9.78 221.83 843.95 89805 -6.23 31.89 -14.72 16.66R 2.75 2.82 18.33 511435.50 6053583.04 100000 12.42 225.49 94207 998.17 3.27 -4575 -28.05 13.08R 2.75 2.90 20.80 511422.20 6053569.16 Crv2.75/100 1058.71 14.00 227.00 999.22 05332 .0.64 -5502 -37.74 HS 2.75 3.04 2228 511412.52 6053559.88 1100.00 15.14 22700 1039.19 09329 1.52 62.10 -45.34 HS 2.75 313 23.40 511404 93 605355278 1200.00 17.89 227.00 1135.05 18915 7.43 -81.48 -68.12 HS 2.75 3.33 26.11 51138418 6053533.37 1300.00 20.84 227.00 1229.45 28355 14.28 -103.98 -9024 HS 2.75 3.50 28.62 511360.10 8053510.84 Cr03.5/100 1375.71 22.72 227.00 1299.80 35390 20.10 -123.05 -11068 HS 2.75 3.62 3088 51133958 605.3491.74 Cry0.5/100 1375.93 22.73 227.00 1300.00 354.10 20.12 -123.10 -110.78 HS 3.50 3.62 3089 51133962 605349189 140000 22.85 227.00 1322.19 376.29 22.05 .129.46 -11757 HS 050 365 31.01 51133291 605348532 150000 23.35 227.00 1414.18 468.28 3021 -15622 -14826 HS 0.50 374 3150 51130416 6053458.52 1800.00 23.85 227.00 1505.82 559.92 38.53 -163.51 -175.54 HS 0.50 3.83 32.00 511274.93 8053431.18 170000 24.35 227.00 1597.10 651.20 4702 -21136 -205.40 HS 050 3.90 3249 511245.12 6053403.30 180000 2485 227.00 168003 742.13 5567 239.74 235.83 HS 050 397 32.99 511214.73 6053374.87 190000 2535 227.00 1778.59 832.69 84.49 -288.67 -268.85 HS 050 403 33.49 511183.76 6053945.90 Crv375/100 192370 25.46 22700 1800.00 854.10 66.61 -27580 -274.29 HS 0.50 4.04 3360 51117833 6053338.95 200000 28.33 227.00 1868.04 922.14 73.78 -299.14 -299.53 HS 375 4.12 36.44 511151.13 6053315.38 2100.00 32.08 22700 1954.45 2008.55 8424 333.44 -336.31 HS 3.75 423 4017 511114.41 8053281.03 220000 35.83 227.00 2037.39 209149 95-85 -371.52 -377.15 HS 3.75 432 4389 511073.63 6053242.89 Cry 3.75h00 2223.70 36.71 227.00 2056.50 2110.60 98.76 -381.08 -38740 HS 3.75 434 44.78 511063.40 6053233.31 230000 39.58 227.00 211650 217000 108.56 -41322 -421.86 HS 3.75 4.41 4762 51102899 6053201.12 2400.00 4333 227.00 2191.44 224554 122-32 458.36 -470.27 HS 3.75 450 5136 510980.66 605.3155.91 2500.00 4708 227.00 2261.89 2315.99 137.07 -506.74 -522.18 HS 3.75 489 55.09 51092085 805310745 2800.00 80.83 22700 232755 2381.85 152.75 558.16 -577.30 HS 3.75 488 58.83 51087379 6053055.95 2700.00 54.58 227.00 2388.13 244223 169.28 61241 635.47 HS 3.75 474 62.56 510815.71 605300162 /3381Ce9 2720.67 5035 227.06 2400.00 2454.10 172.80 623.95 64784 NS 375 4.76 63.34 510803.36 6062980.07 2800.00 53.33 227.00 244339 2497.49 18661 66923 698.41 HS 3.75 4.81 6630 51075487 6052944.71 290000 62.08 227.00 2493.05 2547.18 204.65 72841 759.86 HS 3.75 4.88 70.04 510891.51 805288545 3000.00 6583 227.00 2536.99 259109 22332 -78987 825.55 HS 3.75 495 73.78 510625.92 6052824.09 3100.00 6958 227.00 2574.92 2629.02 242.55 -85275 893.21 HS 375 5.02 77.52 510558.37 8052760.90 320000 7333 227.00 2606.73 268083 262.26 -91740 962.53 HS 3.75 5.06 8126 510489.16 6052696.16 3300.00 77.08 227.00 2632.27 2686.37 282.36 -98332 .1033.23 HS 3.75 5.14 85.00 51041057 6052630.13 • 3400.00 80.83 227.00 265143 270553 30276 -105025 1105.09 HS 3.75 520 88.74 51034691 0052563/0 350000 84.58 227.00 2664.14 271824 323.38 -111788 -1177.52 HS 3.75 5.26 87.52 510274.49 605249536 1 End Cry 356468 87.00 22700 266089 272299 336.79 116188 -122488 HS 3.75 5.29 85.10 510227.41 6052451.32 380000 87.00 227.00 2670.74 2724.84 344.12 -118593 -125049 HS 0.00 5.31 85.10 510201.84 605242721 I 370000 87.00 227.00 2675.97 2730.07 364.89 -1254.03 -1323.53 HS 0.00 5.34 85.10 510128.72 605235900 • 3800.00 87.00 227.00 2681.20 273530 38565 1322.14 -1398.58 HS 0.00 5.38 8510 510055 79 6052290.79 390000 87.00 227.00 2688.44 2740.54 408.41 -139025 -146910 HS 0.00 5.41 85.10 50998287 605222258 400000 87.00 227.00 2691.67 2745.77 42717 -1458.35 -1542.63 HS 0.00 544 85.10 509909.95 605215436 410000 87.00 227.00 2696.90 2751.00 447.94 -1528.48 -1615.87 HS 0.00 5.47 0510 50983703 6052086.15 • 420000 87.00 227.00 2702.14 2758.24 468.70 -1594.57 -1888.70 HS 0.00 5.50 85.10 509764.10 605201794 • 430000 87.00 227.00 2707.37 276147 48946 -1862.67 1761.74 68 0.00 552 8510 50989118 8051949.73 4400.00 87.00 227.00 2712.80 278670 51023 -1730.78 -1334.77 HS 0.00 555 85.10 50961826 605188151 4500,00 87.00 227.00 2717.84 277194 53099 1798.88 -1907.81 HS 0.00 5.58 85.10 50954534 6051813.30 4800.00 87.00 227.00 2723.07 277717 551.75 1888.99 -1980.84 HS 000 5.80 85.10 50947241 8051745.09 • 4700.00 87.00 227.00 272030 278240 572.51 -1835.10 -2053.88 HS 0.00 5.83 85.10 50939949 6051676.88 4800.00 87.00 227.00 273154 2787.84 59328 -200320 -2126.92 HS 0.00 5.85 85.10 509328.57 8051808.87 490000 8700 227.00 2738.77 279287 614.04 -2071.31 -2109.95 HS 0.00 5.67 85.10 50925365 605154045 5000,00 87.00 227.00 2744.01 2]98.11 834.80 .213942 -2272.99 HS 0.00 589 85.10 50918073 605147224 5100.00 87.00 227.00 2749.24 2803.34 655.56 -2207.52 -2348.02 H8 000 572 85.10 509107.80 8051404.03 5200.00 87.00 227.00 275447 2808.57 676.33 -2275.83 -2419.06 H8 0.00 5.74 85.10 50803488 6051335.82 5300.00 8700 22700 2759.71 281301 69709 234174 -2492.09 HS 000 5.76 85.10 50896196 6051267.60 540000 8700 227.00 276494 2819.04 717.85 2411.84 25655.13 HS 000 5.78 8010 50888904 6051199.39 i 550000 8700 22700 2770.17 282427 738.81 -247995 2838.16 HS 0.00 580 85.10 508816.11 8051131.18 580000 87.00 227.00 277541 2829.51 759.38 2548.08 .2711.20 HS 0.00 582 85.10 50874319 8051082.97 5700.00 87.00 227.00 278084 2834.74 78014 -2618.18 .2784.23 HS 0.00 583 85.10 50867027 6050994.76 580000 87.00 227.00 278587 2839.97 300.90 -268427 285727 HS 0.00 5.85 85.10 50859735 6050926.54 5900.00 87.00 22700 279111 284521 82187 -275237 2930.30 HS 0.00 5.87 8510 50852442 6050858.33 8000.00 87.00 227.00 279834 2850.44 842.43 282048 3003.34 HS 0.00 589 85.10 50845150 6050790.12 0100.00 37.00 227.00 2801.58 2855.68 863.19 -2888_59 3076.37 HS 0.00 5.90 8510 50837858 6050721 91 • 620000 87.00 227.00 2806.81 286091 883.95 295869 314941 HS 0.00 5.92 85.10 50830586 605085389 630000 87.00 227.00 2812.04 2868.14 904.72 302480 -3222.44 HS 0.00 5.94 85.10 508232.73 6050585.48 6400.00 87.00 227.00 2817.28 287138 925.48 -309291 3295.48 NS 000 5.95 85.10 50815981 6050517 27 850900 87.00 227.00 282251 287661 94624 -316101 3368.51 HS 000 597 85.10 50808639 8050449.06 860000 87.00 227.00 2827.74 288184 96700 3229.12 3441.55 HS 0.00 598 8510 50801397 6050380.85 670000 8700 22700 2832.98 288708 987.77 329723 351458 HS 000 800 85-10 507941.05 605031283 880000 8700 227.00 2838.21 2892.31 1006.53 3365.33 -3587.62 HS 0.00 601 8510 50786812 6050244.42 690000 87.00 22700 284344 289754 1029.29 -3433.44 3860.65 HS 0.00 6.03 85-10 50779520 6050176.21 7009.00 8700 227.00 284868 290278 105006 350154 373389 HS 0.00 6.04 85.10 50772228 8050106.00 7100.00 87.00 22700 2853.91 2908.01 1070.82 3569.65 3808.72 HS 0.00 6.05 85.10 507649.36 6050039.78 720000 8700 22700 2859.14 291324 109158 363776 387976 HS 000 607 85.10 50757643 6049971.57 730000 87.00 22700 2864.38 291048 1112.34 370586 3852.79 HS 0.00 006 85.10 507503.51 6049903.36 7400.00 3700 22700 2869.61 292371 1133.11 -377387 -4025.83 HS 000 609 85.10 50743059 6049835.15 7500.00 8700 22700 2974.95 292895 1153.87 -384268 -4098.86 HS 009 6.11 85.10 50735767 604976694 780000 87.00 227.00 2680.08 2934.18 1174.63 -391018 -4171.90 HS 0.00 8.12 8510 50728474 604969872 7700.00 87.00 22700 2885.31 2939.41 119539 -397829 -4244.93 HS 0.00 6.13 85.10 507211.82 604963051 7800.00 87.00 227.00 2890.55 294465 121616 -404840 -4317.97 HS 0.00 6.14 8510 50713890 6049562.30 790000 8700 227.00 2895.78 294988 1236.92 -4114.50 4391.00 HS 0.00 616 85.10 507065 98 6049494.09 800000 87.00 227.00 290101 2955.11 125786 4182.61 4464.04 HS 000 817 8510 50899305 6049425.87 8100.09 87.00 22700 2906.25 2960.35 1278.44 -4250.71 -4537.07 HS 0.00 6.18 65.10 506920.13 6049357.66 820000 87.00 227.00 2911.49 2965.58 129921 -4318.82 -4610.11 HS 0.00 6.19 85.10 50884721 6049289.45 830000 87.00 22700 2916.71 2970.81 131097 -438093 -46133.15 HS 0.00 620 85.10 50877429 6049221 24 8400.00 87.00 22700 292195 2976.05 134073 415503 -4758.18 HS 0.00 621 85.10 50670136 6049153.03 850000 8700 22700 2927.18 298128 1361.50 -4523.14 -4829.22 HS 0.00 6.22 85.10 50662844 6049084.81 860000 87.00 22700 293242 2988.52 1382.28 459125 -4902.25 HS 0.00 623 85.10 506555.52 8049016.60 870000 8700 22700 293765 2991.75 140302 -465935 -497529 HS 0.00 624 85.10 508482.60 6048948.39 880000 67.00 22700 2942.88 2996.98 1423.76 -472746 504832 HS 0.00 826 85.10 508409.68 6048860.18 890000 87.00 22700 2948.12 3002.22 1444.55 -479557 6121.36 HS 0.00 627 85.10 50633675 604801196 9000.00 87.00 227.00 2953.35 3007.45 1465.31 -486367 5194.39 HS 0.00 8.28 85.10 50628183 6048743.75 910000 87.00 227.00 2958.58 3012.68 1488.07 -493178 5267,43 HS 0.00 6.29 85.10 506190.91 6048675.54 9200.00 87.00 227.00 2963.82 301792 150883 -499988 5340.48 HS 0.00 6.30 85.10 50611799 604860733 9300.00 87.00 227.00 2880.05 3023.15 1527.60 -506799 5413.50 HS 0.00 6.31 05.10 50604506 6048539.12 940000 87.00 227.00 2974.28 3028.38 1548.36 -5136.10 5488.53 HS 0.00 632 85.10 505972.14 6048470.90 950000 87.00 227.00 2978.52 3033.62 1569.12 -5204.20 -5559.57 HS 0.00 6.33 85.10 505899 22 6048402.69 980000 87.00 227.00 298475 303885 158888 -527231 -5632.60 HS 0.00 833 85.10 50582630 8048334.48 9700.00 8700 227.00 2989.98 3044.08 161085 -534042 5705.64 HS 000 6.34 85.10 50575337 6048266.27 Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SP34-W7\SP34-W7\SP34-W7(P4) 11/12/2014 11:20 AM Page 1 of 3 MD IInd /xlm Trow MOSS ND VSEC NS EW TF DLS DlrMbnal E.cluabEx050.12aw n Zone Emoting Northing CO....mn4 m) (1 15 M) (n) 91) (IB (1Q q (1100(t) D81cuily IM.. 9508 /7791. 11 (1105) (nus) 9800.00 87.00 22700 2995.22 3049.32 183141 5408.52 -5778.87 HS 000 635 8509 505680.45 6048198.05 980000 8700 227.00 3000.45 305455 1652.17 -5476.63 -5851.71 HS 000 6.36 85.09 505607.53 6048129.84 000000 8700 227.00 3005.69 3059.79 1672.94 -5544/4 -5924.74 HS 000 637 8509 505534 61 6048061 63 0100.00 87.00 227.00 301092 306502 1693.70 -5612.84 -5997.78 HS 080 638 8509 50546168 6047993.42 020000 87.00 22700 301615 3070.25 171448 588095 80780.81 HS 0.00 839 85.09 50538816 6047925.21 Cry2/100 028488 87.00 22700 301954 3073.64 1727.89 572498 8118.04 170.898 0.00 8.39 85.09 50534161 604788110 0306.00 86.29 227.04 302180 307570 1735.23 -574904 -6143.85 178.990 2.00 8.40 8580 50531584 604785701 040000 8430 227.14 3029.80 308.3.90 1756.10 -581689 8218.84 176.980 2.00 8.42 87.80 50524296 6047789.05 050000 8230 22725 304147 3095.57 1777.08 -588437 8289.70 176.976 2.00 8.44 8980 505170.21 8047721.46 080000 8030 22736 305660 3110.70 1798.15 -595140 8362.35 178959 2.00 6.45 8820 50509768 604765433 End Cry 0694.02 78.42 22746 307395 3128.05 1e16.00 801393 -6430.37 HS 2.00 6.47 8632 50502976 8047591.70 0700.00 78.12 22746 3075.15 3129.25 181926 801790 -643469 HS 0.00 6.47 8632 50502545 604758773 0800.00 78.42 227.46 3095.22 3149.32 184040 808413 -6506.87 HS 0.00 6.47 8632 50495338 6047521.39 090000 78.42 22746 311528 316938 186153 -615037 -8579.05 HS 0.00 6.48 8632 50488131 8047455.04 1000.00 7842 227.46 3135.35 318945 1882.67 -821681 865123 HS 000 6.48 8632 50480924 6047388.70 1100.00 78.42 22746 315541 3209.51 1903.80 828285 87223.41 HS 000 8.49 8632 504737.17 6047322.36 1200.00 7842 22746 3175.48 3229.58 1924.93 -634909 -6795.59 HS 0.00 8.80 8632 50466510 604725602 1300.00 78.42 22746 3195.54 3249.84 1946.07 -641532 8867.77 HS 080 6.50 8632 50459303 604718907 1400.00 78.42 22748 3215.61 3269.71 1967.20 -6481.56 -8939.95 HS 000 651 8632 50452095 6047123.33 1500.00 78.42 227.48 323567 3269.77 198834 -654780 7012.13 HS 000 651 8632 50444888 6047056.99 Cry3/100 1588.72 78.42 22748 325348 3307.58 2007.09 6606.57 -7076.17 77.294 0.00 652 8632 50438494 8046998.13 1800.00 78.50 227.80 325573 3309.83 2009.50 661401 -7084.33 77.224 300 652 8637 50437679 6046990.6] 1700.00 79.18 230.77 327509 3329.19 2033.71 .667800 -7158.88 76454 300 654 86.82 50430254 6046926.56 1800.00 7988 233.74 329327 334737 2062.88 -6738.18 -7238.44 76.114 3.00 656 8727 50422489 6046866.28 1900.00 8062 23889 3310.20 3364.30 209693 679440 -7317.37 75.814 3.00 6.58 87.73 50414405 8046809.94 2000.00 8138 239.83 332585 337995 2135.77 8846.50 -7401.27 75.15R 3.00 6.59 88.20 50406025 6046757.72 2100.00 82.16 242.58 3340.18 339428 217930 689433 -7487.90 74,734 3.00 8.81 88.68 503973.70 604670976 2200.00 8296 24547 335314 340724 2227.39 6937.77 -7577.02 74.354 3.00 6.83 89.15 50388485 6006666.19 2300.00 83.77 24838 3364.70 341880 2279.91 8976.69 -7868.39 74.01R 3.00 685 89.63 50379335 6048627.13 240000 84.61 25128 3374.82 342892 2336.72 701100 -7761.77 73.724 3.00 688 89.89 50370004 604659268 2500.00 85.45 254.16 3383.49 343759 239767 -704058 -7856.88 73.474 3.00 8.88 89.41 503804.98 604656295 End Cry 2563.89 88.00 25600 3388.23 3442.33 2438.56 7058.93 791825 HS 3.00 6.69 89.11 50354364 604654651 2600.00 06.00 25600 339077 3444.87 2462.32 .7065.70 7953.40 HS 0.00 6.89 89.11 503508.51 6048537.69 2700.00 88.00 25600 3397.74 3451.84 2527.77 708983 8050.19 HS 0.00 8.70 89.11 503411.77 6046513.41 2800.00 86.00 25800 3404.72 3458.82 2593.22 -711396 -814696 HS 0.00 6.71 89.11 503315.02 6006489.13 2900.00 88.00 25600 3411.69 3465.79 285088 -7138.10 8243.78 HS 000 8.71 89.11 50321827 8046464.85 3000.00 8600 25600 3418.67 3472.77 2724.11 -716223 834057 HS 0.00 6.72 89.11 503121.53 604644057 3100.00 8600 25800 3425.65 3479.75 2789.56 -718636 -843736 145 0.00 673 69.11 50302478 604641629 3200.00 86.00 25600 3432.62 3486.72 2855.00 -7210.50 -8534.16 945 000 6.73 69.11 50292804 6046392.01 330000 8600 25600 3439.60 349070 292045 723483 8630.95 HS 0.00 674 89.11 502831 29 6048387.73 95'8'COO 3320.83 86.00 256.00 3441.05 3495.15 2934.08 -7239.66 8651.11 NS 0.00 8.74 89.11 502811.14 6046302.67 SI-W7 T910 Heel 1338389 8600 25600 344404 3498.14 2962.13 -725000 869260 HS 0.00 6.74 69.11 50276987 604635226 Cm 4/100 337389 86.00 25600 344474 3498.84 2968.68 -7252.41 8702 28 66.669 0.00 6.74 8011 502760 00 6046349.83 340000 8842 25697 3446.48 350056 2980.06 -725805 8722780 66.8R 4.00 6.75 8802 502734.49 6046343.66 3500.00 8801 260.84 3451.34 3505.44 3055.19 -727793 8825766 66.42R 4.00 8.77 87.73 50263656 6046324.13 3600.00 89.62 264.31 3453.41 3507.51 312086 -729103 -8924.86 66 359 4.00 879 86.66 502537.50 8046310.88 370000 91.22 287.97 345268 3506.78 3206.71 -729776 9024 61 88379 4,00 6.81 85.60 502437.77 6046304.00 End Cm 375554 92.11 27001 345107 3505.17 325161 -7298.74 9080.12 HS 4.00 8.82 85.02 50238227 6046302.93 C552400 379321 92.11 210.01 3449.68 350070 3252.45 -729873 9117.76 13841. 000 8.82 8502 502344.63 6046302.88 3800.00 91.91 269.82 3449.44 3503.54 328000 -7298.74 -912455 138.4L 4.00 8.82 85.18 50233785 6046302.86 SI-W7 T911 3886.00 90.00 268.00 344034 3502.44 3341.32 -730000 -9190.52 129.478 4.00 683 8681 502271.88 6046301.50 390000 89.14 26905 3448.60 3502.70 3368.86 7300.88 922451 129.474 4.00 8.84 8782 50223790 6046300.57 End Cry 3928.80 88.40 26994 3449.21 3503.31 339210 -730113 9253.29 HS 4.00 8.85 88.87 50220911 6046300.27 400000 88.40 269.94 3451.20 3505.30 3450.38 -730120 -9324/7 HS 0.00 485 8867 50213795 6046300.09 4100.00 88.40 269.94 3453.98 3508.08 6932.18 -730131 -9424.43 HS 0.00 8.88 88.67 502037.99 6046299.83 Cry 2400 4187.98 88.40 288.94 3458.44 351054 380415 730140 951236 92574 0.00 8.88 8807 50195008 6046299.60 420000 88.38 27042 345677 351087 3614.00 -730137 -9524.39 92.558 4.00 8.87 88.76 501938.04 6046299.62 430000 8821 27442 345975 351385 3698.24 -7297.15 -9624.24 92.434 4.00 8.88 6953 50183820 8046303.68 SI-W72912 4364.56 88.10 27700 3461.83 3515.93 3754.51 -7290.73 .9688.44 91598 4.00 8.69 69.97 501774.00 8046310.00 440000 88.06 278.42 3463.02 3517.12 3785.98 -728598 -9723.54 91548 4.00 6.90 6971 501738 89 6046314.70 4500.00 87.96 282.42 3466.49 352059 3878.85 -7267.91 982181 91/8 4.00 8.92 8900 50164060 6046332.81 End Cry 4524.50 8794 283.40 346737 3521/7 389954 -7262.44 984567 HS 4.00 8.92 8882 50161673 6046338.04 460000 87.94 283.40 3470.09 352419 398989 -724495 9919.07 H5 000 8.93 8882 501543 32 6048355.41 4700.00 87.94 283.40 3473.69 3527.79 4082.81 -7221.79 -1001629 HS 000 8.93 8882 501446.08 8046378.42 Cry 2000 4763.39 8794 283.40 3475.98 3530.08 4121.51 -7207.11 -10077.91 13.61 000 6.94 8882 50138444 8046393.00 4800.00 8805 28323 347707 3531.17 4155.51 -7198.89 -10113.52 13.591 2.00 6.94 89.55 50134882 8046401.37 SI-W7 T013 4888.61 9200 28290 347709 3531.99 4220.08 -7182.96 -1018132 18814 2.00 8.95 89.06 501281.00 6046417.00 End Cry 489988 9057 283.10 347774 3531.84 4248.14 -717015 -10210.82 HS 2.00 6.95 8852 50125150 6046423.76 490000 9057 283.10 347774 3531.84 4248.25 -7178.12 -1021093 HS 0.00 695 8852 501251.38 6046423.79 5000.00 9057 283.10 3478.74 353084 434103 -7153.46 -10308.33 HS 000 6.98 8852 50115396 8046446.29 510000 9057 283.10 3475.74 3529.84 443381 -713081 .10405.72 HS 000 896 8852 501056.54 6046468.80 5200.00 9057 283.10 3474.74 352804 4526.58 -7108.15 -10503.12 HS 0.00 8.97 88.53 500959.12 6046491.30 5300.00 9057 283.10 3473.74 352784 461936 7085.50 -10600.51 HS 000 698 88.53 500861.70 6046513.80 CIV WOO 5325.79 90.57 283.10 3473.48 3527.58 464329 .7079.85 -10825.63 133.488 0.00 898 88.53 500836.57 6046519.61 SI-W7 1914 5387.45 9000 283.70 347327 352737 468202 -707000 -10868.16 135.878 2.00 6.98 89.19 50079604 6046529.19 5400.00 6953 284.15 347340 352750 4712.39 -7062.17 -10697.75 135.678 2.00 8.99 89.72 500764.44 6046536.98 5500.00 88.10 285.55 347546 352956 480625 -7038.54 -10794.38 135,044 2.00 7.00 88.85 500667.78 6046562.46 End Cm 558850 8684 286.79 347937 3533.47 4889.92 -7011.91 -10879.29 110 2.00 701 8721 500582.84 6046586.95 580000 8684 286.79 3480.00 3534.10 4900.84 .7008.59 -10890.29 HS 0.00 7.01 8721 500571.84 6046590.25 570000 8684 286.79 346552 353962 499568 -697975 -10985.88 HS 0.00 7.01 8721 50047621 6046618.94 Cr/2.5/133 576738 8604 28639 348923 3543.33 5059.58 8960.32 -11050.27 72.418 000 7.02 8721 50041180 6048638.27 5800.00 8709 287.57 309096 3545.06 5090.60 -695089 .11081.40 72378 2.50 7.02 8723 500380.65 8046647.85 SI-W7 TO 5 5880.90 87.70 289.50 349464 3548.74 5168.10 8925.00 11168.02 75.5R 2.50 7.03 8764 500304.00 804667342 5900.00 8782 26996 349539 3549.49 518601 .6918.58 -11175.99 75488 2.50 7.03 87.69 500286.02 6046679.83 6000.00 8845 292.38 349884 3552.74 528056 -688248 -11269.18 75.44 2.50 7.04 8793 500192.79 8046715.78 End Cry 801127 8852 292.68 349894 3553.04 529456 -6878.14 -11279.59 HS 2.50 7.05 8796 50018227 6046720.08 8100.00 8852 292.66 350123 3555.33 538121 8843.98 -11981.44 HS 000 7.05 87.96 500100.47 604675412 8200.00 8852 29266 350382 3557.92 547888 -6805.47 -11453.70 HS 000 7.06 8796 500008.17 8046792.48 Crv2.5/100 8229.42 8852 29286 350450 3558.68 550759 -8794.14 -11480.84 97.758 000 7.0E 87.96 499981.01 8046803.77 6300.00 8828 294.41 3508.55 356065 5578.73 -676597 -11545.52 97.78 2.50 7.07 87/5 499916.30 6046831.83 0I.067 1918 6384.49 88.00 296.50 3509.29 3563.39 5660.01 -672968 -11621.77 9522R 2.50 7.07 8685 49984000 6046868.00 8400.00 87.98 29889 3509.64 3563.94 5675.34 -8722.72 11835.61 9521R 2.50 7.08 8675 499826.14 6046874.94 8500.00 87.74 299.38 3513.58 356768 577455 -667581 -11723.73 95,124 2.50 7.09 88.15 49973796 6046921.91 660000 87.52 301.87 351772 3571.82 5874.16 -662471 -11809.70 95,0144 2.50 7.10 8555 499651.92 6046972.67 End Cm 6654.51 8740 30323 3520.14 3574.24 5928.57 -859501 -11858.81 HS 2.50 710 8523 499605 98 6047001.89 8700.00 87.40 30323 352220 3576.30 5973.99 -6570.51 -11693.82 HS 0.00 7.11 8523 49956793 6047026.73 CIV 2.5/100 872182 8740 30323 3523.19 3577.29 5995.77 -655857 -1191185 50898 0.00 7.11 8523 499549.69 8047038.65 6800.00 88.84 304.74 3525.89 3579.99 6073.69 -651490 -1197063 50845 2.50 7.12 8622 499484 84 604708222 SI-W7 1917 8885.79 90.00 306.40 3526.91 3581.01 8159.66 -6485.00 -1204640 50988 2.50 7.13 8732 49941500 6047132.00 End Cry 8898.68 9020 30665 3526.89 3580.99 8112.55 -045732 12058.78 HS 2.50 7.19 8748 499404 63 8047139.66 8900.00 9020 306.65 3526.88 3580.98 6173.87 -645651 12057.82 85 000 7.13 87.48 49900357 6047140.44 7000.00 90.20 306.85 3526.53 358063 6273.83 -839684 -12138.05 85 0.00 7.13 87.48 49932325 6047200.01 7100.00 9020 306.65 3526.17 3580.27 8373.79 -633715 -1221828 HS 060 7.14 8748 499242.94 0647259.57 7200.00 9020 306.65 3525.82 357992 647075 -627718 1229861 HS 000 7.14 87.48 49916283 6047319.13 7300.00 9020 30665 3525.46 3579.56 6573.71 -6217.77 -12378.74 HS 0.00 715 8748 499082.32 6047378.69 7400.00 90.20 30685 3525.11 357921 8673.66 -8158.07 -1245897 HS 000 7.15 87.48 499002.00 604743026 Cry25/100 7410.20 9020 30665 352507 357917 668386 -615198 .1246715 60.856 0.00 7.16 8748 498993.81 6047444.33 SI-W7 1018 7428.25 9040 30700 3524.99 3579.09 6699.90 -814238 12480.00 6136R 2.50 7.16 87.63 498980.95 6047453.93 End Civ 7449.85 9088 30751 3524.77 357087 8723.28 -812820 1249882 119 2.50 716 87.83 496962.31 6047488.07 7500.00 90.88 30751 3524.17 357827 6773.58 -609754 -12538.56 HS 0.00 716 8783 496922.33 6047498.66 7600.00 9068 30751 3522.98 3577.08 887348 603865 1281787 HS 080 7.17 87.83 49884293 6047559.42 770000 9068 30751 3521.81 3575.90 487337 597576 1289719 HS 0.00 717 87.83 498763.53 6047620.18 7800.00 90.68 30751 352061 3574.71 7073.27 591487 12776.50 HS 0.00 718 8783 498684.12 6047680.94 7900.00 90.88 30751 351942 357352 7173.17 -585398 12855.82 HS 0.00 7.113 87.83 498604.72 6047741.71 Cm3/100 793598 9088 30751 851899 3573.09 7209.09 583208 1288434 28.87R 0.00 7.18 8783 498576.17 0647763.56 SI-W7 1919 7955.74 9120 30780 851867 3572.77 722085 -582000 -1290000 32.978 3.00 7.19 88 30 498560.49 W47775.61 End Cm 797886 9178 308.17 351807 3572.17 7251.72 -5805.90 .12918.05 HS 3.00 719 8881 49854242 604778968 800000 91.78 308.17 3517.41 357151 727302 .5792.72 1293482 HS 0.00 7.19 88.81 49852563 6047802.84 810000 91/8 308.17 351431 3568.41 7372.82 -573094 13013.40 HS 0.00 720 8881 49844697 6047864.49 820000 91.78 308.17 351121 356531 7472.62 -566918 13091.98 HS 0.00 720 88.81 49836830 604792614 Cry3/100 821340 91.78 30817 351080 356490 748599 -566089 -13102.50 06.528 000 720 8881 498357.76 6047934.40 830000 9227 31117 3507.74 3561.84 757224 -560564 -13169.11 80.824 3.50 721 08.87 49529108 604798953 8400.00 9204 314.82 350327 355737 7671.18 -553766 .1324229 80.788 3.50 723 88.94 49821780 6048057.40 61-W7 12110 841088 9200 31500 3502.73 355683 7681.89 -553000 .13250.00 85380 3.50 723 8895 49821008 604806504 850000 93.15 318.11 349802 355212 776907 -5465.39 13311.19 85446 3.50 724 88.77 49814080 6048129.55 860000 9342 321.81 3492.29 354639 786555 538908 13375,54 856413 3.50 725 88.57 49808434 604820575 End Cm 869509 9367 32493 3486.40 3540.50 795566 531303 -13432.29 HS 3.50 726 88.39 49802748 6048281.71 870000 9387 324.93 348808 3540.18 796027 -5309.02 -13435.10 HS 000 726 8839 498024.66 6048285.72 8800.00 9367 32493 347988 3533.78 805408 822734 -13492.44 HS 0.00 727 8839 49796720 6048367.30 Cm 3/100 8838.94 9387 324.93 347719 353129 809081 -5195.53 -13514.78 122.11R 0.00 727 8839 497944.83 6048399.07 890000 92.53 324.75 347388 3527.98 814759 -5145.08 -13549.00 12221R 3.50 728 8703 49791052 6048449.46 SI-W7 T9111 890183 92.50 328.80 347380 3527.90 814929 5143.55 -13550.06 12444 3.50 7.28 8699 49790952 6048450.99 900000 90.56 32983 3471.18 3525.28 823946 506014 1360168 124.489 3.50 7.29 8472 497857.71 6048534.31 End Cry 900424 90.47 32916 347114 3525.24 824331 5056.49 -13803.82 HS 3.50 7.29 0462 497855.57 6048537.96 Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SP34-W7\SP34-W7\SP34-W7(P4) 11/12/2014 11:20 AM Page 2 of 3 NO Incl •71m T4ue TV085 /VD VSEC N8 EW TF OLS Directions! Zone Exclusion Zone Sorting Northing Comments 1 „l) (1 (1 (6) (N) (N) (It) (II) (1 (T100(0) Difficulty es 0181 (110S) (SUS) 9100.00 90.47 329.76 347035 352445 8330.27 -4973.76 -13652.05 HS 000 729 84.62 49780722 6048620.60 920000 90.47 329.76 3469.53 3523.63 8421.08 -4887.37 -13702.41 HS 000 730 84.62 497756.72 6048708.90 Cry3/100 9283.14 9047 329.78 346901 3523.11 8478.41 4832.83 -13734.21 90.966 0.00 730 8482 49772484 6048761.39 9300.00 9045 33088 3468.71 352281 851173 -480081 -13752.47 90.978 3.00 731 8448 497706.54 604879338 940000 9040 333.86 3467.96 3522.06 8800.53 -471223 -13798.85 B1R 3.00 7.32 8408 497660.02 604888188 SI-W77p112 9404.59 9040 334.00 3467.93 352203 8804.55 -4708.11 -13800.87 93.376 300 732 8407 49765800 604888600 950000 9023 336.88 346740 3521.50 8686.81 482135 13840.54 93.396 3.00 7.33 83.59 497618.20 6048972.69 End Cm 953057 90.18 337.77 346730 352140 8712.84 4593.14 -13852.33 HS 3.00 733 8344 49760637 604900087 960000 90.18 33777 346708 3521.18 8771.02 452887 -1387859 HS 0.00 733 8344 49758001 604906509 9700.00 90.18 337.77 3466.77 3520.87 8855.10 4438.31 1391642 MS 0.00 7.34 83 44 497542.04 604915759 9800.00 90.18 33777 346646 3520.56 8939.18 434374 -13954.25 MS 0.00 734 8344 497504.08 6049250.10 9900.00 90.18 337.77 3468.15 3520.25 9023.27 -4251.17 -13992.07 NS 0.00 7.35 8344 49746611 604934260 Cm 3/100 9813.75 90.18 337.77 3466.11 352021 9034.83 4238.44 -13997.27 14524L 0.00 735 8344 497460.89 604935532 81-W7 T0113 992094 9000 33765 346610 352020 9040.87 4231.79 14000.00 149281 3.00 735 8328 497458.15 6049361.96 20000.00 87.96 336.44 3467.51 3521.61 910788 4159.00 -14030.83 14924L 3.00 7.36 8138 49742721 604943469 End Cry 2008041 8589 335.20 3471.82 352592 9178.82 -4085.76 -14063.72 HS 3.00 737 7945 49739422 604950787 20100.00 85.89 335.20 347322 352732 9193.71 -4068.02 -14071.91 HS 000 737 7945 497385.99 604952560 Cm 3/100 2014228 85.89 335.20 347625 353035 9230.18 4029.74 14089.60 60.261 0.00 737 7905 49736825 604956385 20200.00 88.75 33369 347996 353406 9280.32 -397778 -14114.45 60.16L 3.00 737 8047 49734333 6049615.77 20300.00 8825 33109 348433 353843 936901 388926 -14180.74 60.05L 300 738 8228 49729690 604970421 2040000 8974 32849 348608 354018 9459.77 380286 1421104 SOL 300 739 84.05 497246.47 604979052 0I-W7T9114 20417.04 90.00 328.05 3486.12 3540.22 947543 -3788.36 -1422000 62.17L 3.00 740 8436 49723749 804980500 End CN 20423.54 90.09 32788 3486.11 354021 948141 -378286 -14223.45 HS 3.00 7.40 84.47 49723404 6049810.50 2050000 9009 327.88 3485.99 354009 955185 -3718.10 14264.10 NS 0.00 7.40 84.47 49719328 6049875.19 2060000 9009 327.88 3485.83 3539.93 9643.99 383341 .14317.28 HS 0.00 7.40 8447 49713999 6049959.79 2070000 90.09 32788 3485.68 353978 9736.12 -354872 -14370.45 HS 0.00 7.41 8447 497086 69 6050044.39 Cry 2/100 2072974 90.09 32798 3485.63 3539.73 9763.53 352353 -1438826 88881 0.00 7.41 8447 497070.83 6050069.55 20800.00 90.12 32647 3485.50 3539.80 982858 3484.49 1442435 88881 2.00 7.42 8468 49703266 8050128.52 20900.00 90.17 32447 3485.24 3539.34 992228 -338211 -14481.02 88091 2.00 7.42 84.97 49897587 605021081 SI-W7 19115 20923.68 90.18 32400 3485.17 353927 994462 338290 -1449466 88341. 2.00 7.43 85.04 49696200 6050230.00 End Cry 20992.62 9022 32262 3484.93 3539.03 1001006 -330761 -1453605 HS 2.00 7.43 8526 49692073 605028521 21000.00 9022 32262 3484.90 3539.00 1001710 3301.75 -1454053 MS 000 7.43 8526 49891624 8050291.07 2110000 9022 32262 3484.52 353862 10112.41 -322228 14801.24 HS 0.00 7.44 85 26 496855 42 6050370.43 2120000 9022 32262 348413 353823 10207.71 314282 -14661.94 HS 0.00 7.41 8526 49679459 605044979 21300.00 9022 32262 3433.75 3537.85 10303.92 -3063.36 -14722.85 HS 0.00 7.41 8526 496733.77 6050529.16 Cm 2/100 21331.10 9022 32262 3483.63 3537.73 10332.66 -3038.85 -1474153 28.081 0.00 745 8526 496714.86 605055383 2140000 91.46 32202 348262 3536.72 10398.13 -298412 -14783.64 26091 2.00 745 8657 49667266 6050608.29 51-617Tp116 21430.19 9200 32115 3481.71 3535.81 1042731 -2960.38 -1480227 28561 2.00 7.45 87.14 49665400 6050632.00 2150000 9323 321.08 347853 353263 1049420 290587 -1484576 28591 2.00 7.46 8844 49661043 6050686.44 End Cry 2150418 9330 321.04 3478.29 3532.39 10498.21 2902.62 -14848.38 HS 200 7.18 8852 498807.80 6050689.68 2160000 9330 321.04 3472.77 3526.87 10590.14 -282824 -1490853 HS 000 7.46 8852 498547.55 605076396 21700.00 9330 321.04 3467.02 352112 10688.08 -2750.61 -14971.30 HS 0.00 7.47 8852 49648486 605084149 0rv2/100 2172925 9330 321.04 3485.33 351943 10714.16 272789 -14989.67 108.096 000 7.47 8852 49646626 6050864.17 21800.00 92.86 322.39 3461.53 3515.63 10781.62 267245 -15033.43 108176 2.00 7.47 8791 49642242 605091955 21900.00 9223 32429 345709 3511.19 10878.90 -259231 -15093.08 108256 2.00 7.48 8705 49838285 605099958 61.007 T0117 2193737 9200 32500 3455.71 350981 10911.81 2581.85 -15114.69 101.186 2.00 7.48 88.72 49634100 605103000 22000.00 91.76 328.23 3453.66 3507.76 10970.40 -2510.20 -15150.04 101226 2.00 749 8833 496305.57 6051081.80 End Cry 22078.95 9145 327.78 345145 3505.55 11043.57 -2444.00 -1519302 HS 2.00 7.50 8583 49626249 605114772 22100.00 9145 32778 345092 350502 11062.97 -242620 -15204.24 HS 0.00 7.50 8583 496251.25 605116550 22200.00 91.45 327.78 3448.39 350249 11155.14 2341.83 15257.54 HS 0.00 750 85 83 49819782 605124998 22300.00 9145 32778 344586 349996 11247.31 2257.06 15310.84 HS 0.00 750 8583 49614440 605133446 Cry 2/101) 2239128 9145 327.78 344355 349765 11331.45 -2179.86 -15359.49 67.691 0.00 751 8583 49609563 6051411.58 2240000 9151 32762 344333 349743 11339.08 -2172.49 -15361.15 67691 2.00 7.51 85.92 49609096 605141894 SI-W7 78118 2244416 9185 32880 344203 349613 11380.35 -2135.39 -15388.06 72.16L 2.00 7.51 8635 49606700 605145600 958"C4g 22473.13 92.03 326.25 3441.05 346515 71107.28 -2111.24 -15401.02 72.171 200 7.51 8655 496051-00 60151480.12 2250000 92.19 32574 344006 3494.16 11432.35 -208898 -15419.05 72.191. 2.00 752 8682 49603594 605150236 End Cry 2252433 92.34 32527 343910 3493.20 11455.12 -208894 -15432.81 H8 2.00 7.52 87.03 49602214 6051522.37 22600.00 9234 32527 3438.01 3490.11 1152605 2006.80 -1547588 HS 0.00 7.52 87.03 49597898 6051584.44 2270000 9234 32527 343192 3488.02 11819.78 1924.86 -15532.60 140 0.00 7.53 8703 49592194 6051666.48 2280000 9234 325.27 3427.84 3481.94 11713.50 -184257 -15589/2 HS 0.00 753 67.03 49586490 6051748.48 2290000 9234 32527 342376 3477.86 11807.23 176045 -15646.61 MS 0.00 753 87.03 49580786 6051830.50 TD 2295059 92.34 32527 3421.69 347579 1185485 171890 -15675.44 0.00 7.54 87.03 49577900 605187200 Survey Type: Del Plan Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SP34-W7\SP34-W7\SP34-W7(P4) 11/12/2014 11:20 AM Page 3 of 3 oo 0 0 0 0 0 0 O O oo 0 0 0 0 0 0 0 _ N M 'T Q1,1 rn 00 r °0 0n '11(0,4 e, / I Q1/ / p"/ o '27( , lo- QV*, cilt z%o c&Q bcs'e- 8 L '�, ° Q4 gyp/ s 4*F ° g£ CO ca 1 ¢,e 1 °,14 ase ° _ s �y t E o `0 °s6o° 0 o �(st0b -- a_ NS, _ QAY 'kt o41. O • v Q ° I �S,; • Ql` ,�:I- e90ro 9 �., ., e oC/.1 ui o Q1< °e '744(�sem ao o O - _.-... - Q�Bt '-F.. Q�e - o 8 00 �I ° tt °g1.t�` kr `9Ie 00 in F e q �e Qi< ° v° `+h� ° fit. Qt., ' N S o Q egg li `�° TVD . . 0 y ^ �/y, g4 NO CO I 8 A w w th N. / 2 p glee, .9602 TVD O ° .. V) 4 j ° a (N 7 Q 6�'l"� t n o m ,, / ° 41:(4 0 ZLLQ` ° z l : _ . o - °°° , i l l Q1t o_ o r o 0 _V ` N iI;LL III co o '41, goo° -.1-1------4.-.1.--t...1.-- $ 441°4114e oVa - ON °� 2`r T� r O Q4 Q q��,� w . co z 3 � +F ee° M ,o t. 8 00` .27eejs•y, 4. o 0 • • . o N J O , E tl CO u o o o D_ o a . - o Lo CO c u • C a o a - o o m co aA v t,'. n M ikitilII a i', O o Ilk o - d ni I o ID m d 03 O 0 o O o 0 0 0 0 O O O O O O O O O N fh V Lc, a? N.- of m (4)009L:l=ale3S(4)SN Attachment 3 Drilling Hazards Summary Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill,Reduced pump rates,Reduced drilling fluid temperatures,Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets), pumping out 12-1/4" Open Hole/ 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill,reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology,LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out 8-1/2" Open Hole/ 5-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning,PWD tools, hole opener runs,decreased mud weight Lost Circulation Low Reduced pump rates,mud rheology,LCM Hole Swabbing on Trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out, backreaming Attachment 4 BOP & Diverter Configuration b gn g^ •5 0 1 ! '' 6 ,,,,o �Z b O � � U � � � I � i YO �O =O b � �zF }a} J = o z ao Zz01 Z ..c.:. r) O' cEi 11 e g m 7.4-' U m m H Q N M Y iA W N I ii ;41 01 E g ., r: . , i 1 o Rl E U, b W UcoN, 41 E :''. c 3,3. :rs g o o 1a L� wT` c/ ii" < y 1 ells 'Sal 1: q C r 1 g g ., 1 l pv. I !log 1 fz I's 111111 MI -- ill=.3. fiaL A L ` i ---._ II n r' 1-f-w-1 .v,•1a------b---- -------. - - i `-,r v n tu- g IF .1 s • i �. 0 1 1 0i i i ii 1 n i 1 — 00=1--- - i u .V99.. 1 i gg E 5E NNNNNN NNNhNh�-(D� cD,-(o�(O.(O� O - Oif)OIfO 04040000Of- ;y MCdlnlq(O�NNGDOD�OIOO7_NNMM�d'1nO°Dahh000Om6�OO""VNNMM"Y�t1()If) g n iEj jaa w o66666(oro(�c 66r.hhi:r,NNNN.NNNNnhnNNa 6m6m6666666 1 8 q Lola/ g o lig t u a._ ri S .c iplt M ,-NMet [101,006) ,-01M4WhO3M ,-NMet (ONMM •-NMet COh000) •-NM 33 0 m F (VMMMN]M7M M7 t7MM ttteFat tettNV7 LL')U711] • Ig6•6•66,_6•66•6•m6•6•(O•6• Nh•h €, G h 5 d; m m mm iliE U 5 1 12 ONO 4OdOdOeh 1,0eoOO80"�'-cUlMW OMDMWMhMO 0WM-.-NN g .�O _ eceeeea eeeeeseeev et 6766 n 6If)n n N N o A n N N A A unDcc;f0 00(O D 0. o E 7 E 8 .4-0M,,Mm ,-NMetln(Oh000) NMef In(OhOOO) �NMt-. Oh00 ) "-NMet'"NaJ 5 m, Odmm0500m��O�O)��0)O)9 QQQOQQ000��,-...... 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II II EIII II! y ii 3g 2 g 114111/6 hii1!1111 1111g gggil 11111111111111111111111 j'E 6,6 sa111 '11111 �� iii .i i . t 4 11111111111111111111111111111111111111111 ii� gl 16 4, WAil� `o I. o th\ \ ig - V j V I: r Cr b ._]c \ '�1�iS iS i�'b`c c :� m W oc! 00 . Ula Ula — ggi�gi�oo.g; cr O o or. sa Qw SIi$ I; 0 za 5 / 2 $ � $ qa 1256 -h a °i, A-AOB----/--- - -1- ---� ---- - -- ----, t r A-009 kt \ A y�IV �/yII pj: 1 ;: >4, j) 1 ? 1 r'ij / /\\% I i 3 a 1I - mil r-- - F ,1 i 1 1 Egsgssgn Ogggng .. il :' .-1,FIE 010 :... III '? g >; 1 i 0' •I• !r 3 I • ArA • • F SZ.ZooZk'p E .0- 0--1-- 4 i a �— !'-t��Q•�•1- - * .o-.oM o r n Y u>u Le4‘,,, 1 1: i5 O i GI , r®L®, 1 \ . W 5RR --10 41-111 W I c ."at \ 12 F ' F umea All I .o-ooz--i-- - 0,- 111 -r- . '<j- < •1 n .on-.uz ./ �� rS 0: I\ E"2\/\lwesr NI , I Imo,�i /NIT / I i = „_ a Y": d `� - --1 MI 1>m hi�� m•�^-- - �.+1•��/' "asiedu°°vrn : \ , IGIfi JJI/AMIV�Vtl• a. / illOtl)nn. IL 1 rr MID 1-3 Ti I ! Ioai JI I < O 1J '.-A k F i J ♦ 1 1 i ivy I xinu�mem an m r e imcnan a ie-uru-ww.0-1i\mem xuxuwurer mu+nue 9u-.• \nL�y OU JU„h f A'A0 Attachment 5 Cement Loads & CemCADE Summary Schlumberger CemCADE*well cementing recommendation for Surface casing Operator : ENI Well : SP31-W7 Country : USA State : Alaska Prepared for : Andrea Lazzari Location : Spy Island Proposal No. : Initiall Service Point : Prudhoe Bay Date Prepared : 11-11-2014 Business Phone : +1 907 659 2434 Prepared by : Angele Diboue Phone : +1 907 306 8949 E-Mail Address : aedimo©slb.com C -9lURTE Oisclaimer Notice Schlumberger submits this document with the beret it of its judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements,assumptions and inferences that are not Infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES.RECOMMENDATIONS MADE.OR RESULTS OF THE SERVICES RENDERED. Freedom tram infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. Mark of Schlumberger Page 1 SP31-W7.cfw;11-11-2014; LoadCase 133/8 Surface casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlumbergcr String District : Prudhoe Bay Country : USA Loadcase : 13 3/8 Surface casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2721.0 ft BHST : 50degF Bit Size : 16 in ft ft OD 20.in 0 200 400 600 800 1000 o- isoft 1 ■ Hori.Depart. I ` � N O O O $ 0013.4 In v Q 2721 O ft y `N— o —O r I— O X 141 LC 02641 ft N \ n T C (V O c� In— cv Well Hod. Departure Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 160.0 20 169.0 18.250 Landing Collar MD : 2641.0 ft Casing/liner Shoe MD : 2721.0 ft Page 2 5831-W7.cfw;11-11-2014; LoadCase 133/8 Surface casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlbergcr String District : Prudhoe Bay Country : USA Loadcase : 133/8 Surface casing Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2721.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 134.9 % Mean OH Equivalent Diameter: 18.975 in Total OH Volume :895.7 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 1811.0 16.000 190.0 20.063 2721.0 16.000 35.0 16.822 Max. Deviation Angle : 55 deg Max. DLS : 4.544 deg/100ft Refer to appendix 1 for complete directional surveys Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 970.0 11.50 8.40 SV4 Siltstone 1250.0 11.50 8.40 SV3 Sandstone 1800.0 11.50 8.40 SV2 Siltstone 1811.0 11.50 8.40 SV1 Sandstone 2275.0 12.00 8.40 Base Permafrost Shale 2721.0 12.50 8.40 UG4 Sandstone Page 3 SP31-W7.crw;11-11-2014; LoadCase 13 3/8 Surface casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 13 3/8 Surface casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 15 0.0 1811.0 1752.1 32 1.0 2721.0 2454.2 50 1.4 ft degF ft C- 0� 7n 40 _ 60 0 I i 1000 C,eoth.Profie I —Hod.Depart. a CV O .. _ O U? O o– \ or.! I 0 0 eo T- 00 x r . O N C~ O ICJ CN CNC O O C—i_ N Temperature Hori. Depairture Page 4 SP31-W7.cfw;11-11-2014; LoadCase 133/8 Surface casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 13 3/8 Surface casing Section 2: fluid sequence Job Objectives: Bring cement to surface. Original fluid Mud 9.50 lb/gal k : 8.28E-2 Ibf.s^n/ft2 n :0.262 Tr :0.48 Ibf/100ft2 Displacement Volume 395.4 bbl Total Volume 982.0 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:3.23E-2 Ibf.s^n/ft2 n:0.369 Ty:9.47 Ibf/100ft2 Lead Slurry 423.6 2216.0 0.0 10.70 k:1.52E-1 lbf.s^n/ft2 n:0.315 Ty:1.35 Ibf/100ft2 Tail Slurry 63.0 505.0 2216.0 12.50 k:1.56E-2 Ibf.s^n/ft2 n:0.811 Ty:3.01 Ibf/100ft2 Mud 395.4 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48 lbf/100ft2 Static Security Checks: Frac 7 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2007 psi at 2641.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 59 ton Check Valve Diff Press 178 psi ft (x 1000) psi 0—Hydrostat,_. -Frac -Pone c• Fluid Sequence Static Well Security Page 5 SP31-W7.cfw;11-11-2014; LoadCase 13 3/8 Surface casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 133/8 Surface casing Section 3: pumping schedule - Spacer/Cement Max Rate is 7-BPM - (No significant amount of time to be spent outside of+/-0.2ppg Density Range) - Maintain returns during cement job if possible( note returns,losses in Job report). - Max displacement Rate is 6-BPM - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be thinned back prior to cementing - Do not overdisplace more than 1/2 shoe track volume if plug bump not observed. - Attempt to follow highlighted flow rates as close as possible and within ranges specified o Please note variance from noted Rates in Job Report Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj.Temp. Comments (bbl/min) (bbl) (min) (bbl). (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Mix and pump Spacer ahead Pause 0.0 0.0 5.0 0.080 Drop bottom plug Lead Slurry 5.0 423.6 84.7 423.6 ` 80 Mix and Pump Lead slurry(3-6 bpm) Tail Slurry 4.0 63.0 15.8 63.0 80 Mix and pump Tal slurry(3-5 bpm) Pause 0.0 0.0 5.0 0.0 80 Drop top plug Mud 6.0 385.0 64.2 385.0 80 _ Displacement Mud 2.0 10.4 5.2 395.4 80 Slow rate to bump the plug Total 03:19 982.0 bbl hr:mn Dynamic Security Checks : Frac 3 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2007 psi at 2641.0 ft Burst4767 psi at 0.0 ft Temperature Results BHCT 65 degF Simulated Max HCT 69 degF Simulated BHCT 69 degF Max HCT Depth 2721.0 ft CT at TOC 58 degF Max HCT Time 03:19:51 hr:mn:sc Static temperatures: At Time (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 15 degF Bottom Hole (degF) (degF) 50 degF Page 6 SP31-W7.cfw,11-11-2014. LoadCase 133/8 Surface casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlokergcr String District : Prudhoe Bay Country : USA Loadcase : 133/8 Surface casing Contingencies Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Anytime a stoppage in the job occurs it must be noted how much time can be allotted to fix any issue and calculate time remaining based off of Field Blend Testing. 1) If Losses prior to cementing a) Utilize CemNET(1-2 lb/bbl; 2 lb MAX) b) Attempt to establish Max Rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue: time<20 min c) If issue with mixing system—switch to back-up mixing system d) If issue with tri-plex pump—Cont.job with secondary tri-plex pump on unit. 3) Mud Pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue: time<10 min c) Note displacement volume pumped by mud pumps:verify with Co. Rep/WSL d) Subtract pumped volume from total volume=volume pumped by Cement Unit e) Rig up hoses to get mud to Cement Unit i) Begin displacement with Cement Unit:volume verified by Co. Rep/WSL Simulated ECD at shoe 2721 ft o Depth= 2721 ft C' Frac ----- ' Pore ZNIw Hydrostatic Dynamic of N ' T r O V OI '^ U g l O co 0 30 60 90 120 150 180 210 Time(min) Page 7 SP31-W7 cfw,11-11-2014; LoadCase 13 3/8 Surface casing:Version wcs-cem412_05 Client : EM Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 13 3/8 Surface casing Simulated ECD at Previous shoe 160 ft Depth= 160 ft Frac - Pore N -- Hydrostatic ,-- Dynamic C3- 1/( I 16 GOli O t0_ al I (V_ 3 O cd O 30 60 90 120 150 180 210 Time (min) Simulated rate and pressure during placement r� rCalc-CemHP Calc-Pump Press. Acquired Pressure ----:----<---"----../.--------<1.1. , g -ice O O 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1 Pumped Volume (bbl) (x 1000) Fluids at 2721 ft n0h A- cquired 0 h OOut 1 - rS I i _ i. 0 O 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1 Pumped Volume (bbl) (x 1000) Page 8 SP31-W7.clw;11-11-2014; LoadCase 13 3/8 Surface casing;Version was-cem472_05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 13 3/8 Surface casing Calc.CemHP 1 Calc.Pimp Press. Acquired Pressure i § L '"---- --%' '''-----'. - .--A--- - .-.. - _____ 0 . i r------____ 0 30 60 90 120 150 180 210 Time (min) Fluids at 2721 ft Ln ri 0 i Acquired Q h — -Q Out a) IN Q p . - 0 30 60 90 120 150 180 210 Time (min) Simulated temperature during placement Last Sack Terrp. 1 0 First Sack Temp. le API B1-1C1 - IIN 1 1 • 4 v C i1 E (0 k M CD '. -co O 0 30 60 90 120 150 180 210 Time (min) Page 9 SP31-W7.dm/;11-11-2014; LoadCase 133/8 Surface casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 133/8 Surface casing Simulated temperature throuciht 24 hours after placement at Shoe 2721ft Depth= 2721 ft API BHCT Geothi.R'oflie -} .}Annulus T • Fluids IO- 8-, 2 I 0 250 500 750 1000 1250 1500 1750 Time (min) Page 10 SP31-W7.cfw;11-11-2014; LoadCase 133/8 Surface casing;Versionwcs-cem472_05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 133/8 Surface casing Section 4: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2711.0 ft Casing Shoe :2721.0 ft NB of Cent. Used :15 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 81.0 0 0/0 100.0 50.5 161.0 2 1/1 NW-ST-13 3/8-8-ST A3B W131 0.0 153.8 2241.0 0 0/0 0.0 161.0 2681.0 11 1/1 NW-ST-13 3/8-8-ST A3B W131 0.0 2250.6 2721.0 2 2/1 NW-ST-13 3/8-8-ST A3B W131 89.6 2691.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-ST-13 3/8-8-ST W131 13 3/8 18.386 14.685 No Hannover 16.000 1225.21 2996.70 A3B (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications 0 ft _ 0 21) 0 60 80 100 =et.: Cert I + rJ .=. Pipe Standoff Page 11 SP31-W7.cfw;11-11-2014; LoadCase 13 3/8 Surface casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Seidel!" String - District : Prudhoe Bay Country : USA Loadcase : 133/8 Surface casing Section 5: WELLCLEAN II Simulator ft % % 0 25 50 75 100 0 25 50 75 100 0 - Std Betw.Cent. 1 - Wtid Contanination -Cement Coverage - Uncontaminated Slurry _l_ 1 Fluid Sequence Cement Coverage Uncontaminated Slurry aro,... w , .4. z 3 3 z 0 I 0 00 500 -500 500 500 1000- I -1000 „ 1000 1000 .c s t L o- 1500- -1 500 0_ o- 1500 1 500 0_ a, at a, 0 o O O 0 2000- 2000 2000 2000 2500 2500 2500 2500 i r a, 3 a) a) ; m - o v v o a 3 3 3 0 0 Z Z ."wsw Q ueOw,n. •«"b.— IIS Page 12 SP31-W7.cfw;11-11-2014; LoadCase 133/8 Surface casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlmlirgcr String District : Prudhoe Bay Country : USA Loadcase : 133/8 Surface casing Section 2: operator summary MIXING PREPARATION MUDPUSH 11 Volume: 100.0 bbl Density: 10.10 lb/gal Code Quantity Design 0.200 gal/bbl of spacer 6.000 lb/bbl of base fluid 95.37 lb/bbl of spacer Lead Slurry Volume :423.6 bbl Density : 10.70 lb/gal Yield :2.76 ft3/sk Dry Phase Liquid Phase Blend: 0.0 sk Design Mix Water 0.0 bbl 10.0 bbl LAS Design 0.400%BWOB 9.000%BWOW 0.500%BWOB 0.500%BWOB 0.900%BWOB Tail Slurry Volume :63.0 bbl Density : 12.50 lb/gal Yield : 1.57 ft3/sk Dry Phase Liquid Phase Blend: 0.0 sk Design Mix Water 0.0 bbl 10.0 bbl LAS Design 0.200%BWOB 0.100 gal/sk blend 0.250%BWOB 0.250%BWOB Page 13 SP31-W7.cfw;11-11-2014; LoadCase 133/8 Surface casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 SelIlikliger String District : Prudhoe Bay Country : USA Loadcase : 13 3/8 Surface casing Appendix 1: Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 170.0 0.000 100.0 100.0 0.0 170.0 0.000 200.0 200.0 0.0 170.0 0.000 300.0 300.0 0.0 170.0 0.000 400.0 400.0 0.0 170.0 0.000 500.0 500.0 1.5 170.0 1.500 600.0 599.9 3.0 170.0 1.500 700.0 699.7 4.8 202.5 2.750 800.0 799.1 7.2 215.5 2.748 900.0 898.0 9.8 221.8 2.749 1000.0 996.2 12.4 225.5 2.750 1058.7 1053.3 14.0 227.0 2.754 1100.0 1093.3 15.1 227.0 2.761 1200.0 1189.1 17.9 227.0 2.750 1300.0 1283.5 20.6 227.0 2.750 1375.7 1353.9 22.7 227.0 2.747 1375.9 1354.1 22.7 227.0 4.544 1400.0 1376.3 22.9 227.0 0.499 1500.0 1468.3 23.4 227.0 0.500 1600.0 1559.9 23.9 227.0 0.500 1700.0 1651.2 24.4 227.0 0.500 1800.0 1742.1 24.9 227.0 0.500 1900.0 1832.7 25.4 227.0 0.500 1923.7 1854.1 25.5 227.0 0.464 2000.0 1922.1 28.3 227.0 3.761 2100.0 2008.5 32.1 227.0 3.750 2200.0 2091.4 35.8 227.0 3.750 2223.7 2110.5 36.7 227.0 3.713 2300.0 2170.5 39.6 227.0 3.761 2400.0 2245.5 43.3 227.0 3.750 2500.0 2315.9 47.1 227.0 3.750 2600.0 2381.6 50.8 227.0 3.750 2700.0 2442.2 54.6 227.0 3.750 2720.7 2454.0 55.3 227.0 3.725 2721.0 2454.2 55.3 227.0 0.000 Page 14 SP31-W7.cfw;11-11-2014, LaadCase 13 3/8 Surface casing;Version wcs-cem472_05 Schlumberger Cem CAD E*well cementing recommendation for Intermediate casing Operator : ENI Well : SP31-W7 Country : USA State : Alaska Prepared for : Andrea Lazzari Location : Spy Island Proposal No. : Initiall Service Point : Prudhoe Bay Date Prepared : 11-11-2014 Business Phone : +1 907 659 2434 Prepared by : Angele Diboue Phone : +1 907 306 8949 E-Mail Address : aedimo@slb.com CP 01, Disclaimer Notice: • Schlumberger submits this document with the benefit of its judgment.experience.and good oilfield practices. This intormation is provided in accordance with generally accepted industry practice,relying on facts or intonation provided by others,limitations.computer models,measurements,assumptions and inferences that are not infallible. Calculations are estimates bawd on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE.OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. .Mark of Schlumberger Page 1 SP31-W7.ctw;11-11-2014; LoadCase 95/8 Intermediate Casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlamberger String District : Prudhoe Bay Country : USA Loadcase : 9 5/8 Intermediate Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 13321.0 ft BHST : 85 degF Bit Size : 12 1/4 in ft (x 1000)ft OD 20.in ---- _ 0 2 4 6 8 10 12 O- @ 160ft �-� i 1-bri.Depart. Ch 2 o O OD 13.4 In q CA - @2721ft 0 1_ N __ = in // 0 r OD 9.62 in @ 13321ft Q `- T � X CV LC@13241ft N. C\I O_ Ch Ch_ I tY) (C) CY)— Well Hori. Departure Page 2 SP31-W7.cfw;11-11-2014; LoadCase 95/8 Intermediate Casing;Version wcs-cem472 05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 9 5/8 Intermediate Casing Previous String MD OD Weight ID _, (ft) (in) (lb/ft) (in) 2721.0 13 3/8 68.0 12.415 Landing Collar MD : 13241.0 ft Casing/liner Shoe MD : 13321.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 13321.0 9 5/8 40.0 40.0 8.835 L-80 2780 4920 IFJ Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 1840.9 bbl (including excess) Max. Deviation Angle : 87 deg Max. DLS : 4.544 deg/100ft Refer to appendix 1 for complete directional surveys Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 970.0 11.50 8.40 SV4 Siltstone 1250.0 11.50 8.40 SV3 Sandstone 1800.0 11.50 8.40 SV2 Siltstone 1811.0 11.50 8.40 SV1 Sandstone 2275.0 12.00 8.40 Base Permafrost Shale 2721.0 12.50 8.40 Ugnu Sandstone 11642.0 12.50 8.40 Ugnu Sandstone 13321.0 12.50 8.40 N-sand Sandstone Page 3 SP31-W7.cfw;11-11-2014; LoadCase 95/8 Intermediate Casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 9 5/8 Intermediate Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 15 0.0 1811.0 1752.1 32 1.0 2721.0 2454.2 50 1.4 13321.0 3495.1 85 2.0 ft degF (x 1000)ft o_ 0l 60 90 n 6 9 12 —Ge_v Profile I I I I O I . -1 \--‘\''`)' 00 f o_ css i - T r - Ili O i 1 __ OO O N G .- , N G 1 . t CO N N. o Temperature Hon. Departure Page 4 SP31-W7 cfw 11-11-2014, LaadCase95/B lntermedlate Casing Version wcs-cern472_05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 9 5/8 Intermediate Casing Section 2: fluid sequence Job Objectives: Bring cement 1000ft MD above N-top sand formation. Original fluid LSND Mud 9.50 lb/gal k : 5.99E-3 Ibf.s^n/ft2 n :0.616 Tv :8.84 lbf/100ft2 Displacement Volume 1004.0 bbl Total Volume 1334.2 bbl TOC 10642.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 1195.1 9446.9 10.50 k:2.70E-2 lbf.s^n/ft2 n:0.394 Ty:13.19 Ibf/100ft2 Lead Slurry 182.3 2179.0 10642.0 12.50 k:4.89E-3 lbf.s^n/ft2 n:0.960 Ty:15.95 Ibf/100ft2 Tail Slurry 47.9 500.0 12821.0 15.80 k:1.19E-2 lbf.s^n/ft2 n:0.789 Ty:0.02 Ibf/100ft2 Fresh water 5.0 13175.1 8.40 viscosity:5.000 cP LSND Mud 999.0 0.0 9.50 k:5.99E-3 lbf.s^n/ft2 n:0.616 Ty:8.84 Ibf/100ft2 Static Security Checks: Frac 382 psi at 2721.0 ft Pore 140 psi at 2721.0 ft Collapse 2571 psi at 13241.0 ft Burst 4920 psi at 0.0 ft Csg.Pump out 58 ton Check Valve Diff Press 68 psi ft (x 1000)psi 0 2.5 -Hydrostatic -Frac -Pore 141\t C, r. I C Fluid Sequence Static Well Security Page 5 SP31-W7.cfw:11-11-2014; LoadCase95/8Intermediate Casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 95/8 Intermediate Casing Section 3: pumping schedule - Spacer/Cement Max Rate is 7-BPM - (No significant amount of time to be spent outside of+/-0.2ppg Density Range) - Maintain returns during cement job if possible(note returns,losses in Job report). - Max displacement Rate is 7-BPM - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be thinned back prior to cementing - Do not overdisplace more than 1/2 shoe track volume if plug bump not observed. - Attempt to follow highlighted flow rates as close as possible and within ranges specified a Please note variance from noted Rates in Job Report Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj.Temp. Comments (bbl/min) (bbl) (min) (bbl). (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Mix and pump Spacer ahead Pause 0.0 0.0 5.0 0.0 80 _ Drop bottom plug Lead Slurry 5.0 182.3 36.5 182.3 80 Mix and pump lead slurry(3-6 bpm) Tail Slurry 5.0 47.9 9.6 47.9 80 Mix and pump tail slurry(3-5 bpm) Pause 0.0 0.0 5.0 0.0 80 Drop top plug Fresh water 5.0 5.0 1.0 5.0 80 Displacement/wash line with H2O LSND Mud _ 7.0 96.013.7 96.0 80 Displacement LSND Mud _ 5.0 893.0 1 178.6 _ 989.0 _ 80 Slow rate as soon as WHP increases LSND Mud 2.0 10.0 5.0 999.0 80 Slow rate to bump plug Total 04:34 1334.2 bbl hr:mn Dynamic Security Checks : Frac 190 psi at 13321.0 ft Pore 140 psi at 2721.0 ft Collapse 2322 psi at 297.5 ft Burst 4503 psi at 0.0 ft Temperature Results BHCT 83 degF Simulated Max HCT 85 degF Simulated BHCT 72 degF Max HCT Depth 13321.0 ft CT at TOC 72 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures: At Time 1 (hr:mn) 1 (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 72 degF Bottom Hole (degF) (degF) 85 degF Page 6 SP31-W7.dm,,11-11-2014: LoadCase 9 5/8 Intermediate Casing.Version wcs-cem472 05 Client : ENI Well : SP31-W7 Scioto" oto" String District : Prudhoe Bay Country : USA Loadcase : 9 5/8 Intermediate Casing Contingencies Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Anytime a stoppage in the job occurs it must be noted how much time can be allotted to fix any issue and calculate time remaining based off of Field Blend Testing. 1) If Losses prior to cementing a) Utilize CemNET(1-2 lb/bbl; 2 lb MAX) b) Attempt to establish Max Rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue: time<20 min c) If issue with mixing system—switch to back-up mixing system d) If issue with tri-plex pump—Cont.job with secondary tri-plex pump on unit. 3) Mud Pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue: time<10 min c) Note displacement volume pumped by mud pumps: verify with Co. Rep/WSL d) Subtract pumped volume from total volume=volume pumped by Cement Unit e) Rig up hoses to get mud to Cement Unit i) Begin displacement with Cement Unit: volume verified by Co. Rep/WSL Simulated ECD at shoe 13321 ft o Depths 13321 ft_ FFrac bre • N I, 'r '- Dynamic QQ 1 O d O as2 8 - 0 30 60 90 120 150 180 210 240 270 300 Time (min) Page 7 SP31-W7.cfw,11-11-2814oadCase 85/8 Intermediate Casing Version wcs-cem472_t15 Client : ENI Well : SP31-W7 Ulerger String District : Prudhoe Bay Country : USA Loadcase : 9 5/8 Intermediate Casing Simulated ECD at Previous shoe 2721 ft M _ _ Frac Depth= 2721 ft T Pae nHydrostatic T Dynamic 0 N T 1 T T 1I- T T cq 5 J --\ L— .5 g c. O 30 60 90 120 150 180 210 240 270 300 Time(min) Simulated rate and pressure during placement Calc.CemHP Pump Preen. ._ A tred Pressure —\ O -- T O 30 60 90 120 150 180 210 240 270 300 Time (min) Fluids at 13321 ft LQ Oh Acquired 0 hz - i nv...._ g 1 _ — — • 0 30 60 90 120 150 180 210 240 270 300 Time (min) Page 8 SP31-W7.cfw;11-11-2014; LoadCase 95/8 Intermediate Casing;Version wcs-cem472-05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Load case : 95/8 Intermediate Casing -Cab.Cerr1HP Calc.Pump Press. Acquired Pressure 1 § ........N. / ' O 0 0.25 0.50 0.75 1.00 1.25 1.50 Pumped Volume (bbl) (x 1000) Fluids at 13321 ft is: Oh C Acquired O 0 O Out v ( L O 0 0.25 0.50 0.75 1.00 1.25 1.50 Pumped Volume (bbl) (x 1000) Simulated temperature during placement 8 Last Sack Te •. - T O Rrst Sack Terrp. API BI-CT 8 , t 1 t -N I �� 6 6 4 \'KN----.....-----""."7-77-V" - v § i P 1 ..,,,----- x X41!( t co A_`-' i E co t t?I — O 0 30 60 90 120 150 180 210 240 270 300 Time (min) Page 9 SP31-W7.ciw;11-11-2014; LoadCase 9 5/8 Intermediate Casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 9 5/8 Intermediate Casing Simulated temperature throuaht 24 hours after placement at Shoe 13321ft Depth= 13321 ft co API BHCT -Geoth.Prof Ile #Annulus ,-Tubular Fluids co I L.LW C) oLr)_ 2 Q cD C>7_ co ch co 0 200 400 600 800 1000 1200 1400 1600 1800 2000 Time (min) Page 10 SP31-W7.cfw;11-11-2014; LoadCase 95/8 Intermediate Casing.Version wcs-cem412_05 Client : ENI Well : SP31-W7 Schlumberger String District : Prudhoe Bay Country : USA Loadcase : 95/8 Intermediate Casing Section 4: centralizer placement Top of centralization :10642.0 ft Bottom Cent. MD :13301.0 ft Casing Shoe :13321.0 ft NB of Cent. Used :54 NB of Floating Cent. :54 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 11161.0 0 0/0 0.0 11178.8 13321.0 54 1/1 HYDROFORM HFD 50.0 13321.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) HYDROFORM HFD 9 5/8 12.250 12.250 Yes Weatherford(1) N.A. N.A. N.A. (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft 0 1 '0 60 80 100 i 9erneer Cc-t I-77— _+_...__ - + 1 � - -+At Cert i - Ir.. _ ---- MI a O in I 11111 II I 111 _ „ ,III III la I , It_ 11- ' r. ' . ■. . 111 ■ ...�.I. i IN 11111111111111111 111 1111• :r Pipe Standoff Page 11 SP31-W7.cfw,11-11-2014, LoadCase 95/8 Intermediate Casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schilergcr String District : Prudhoe Bay Country : USA Loadcase : 95/8 Intermediate Casing Section 5: WELLCLEAN II Simulator ft 0 25 50 75 100 0 25 50 75 100 i— - _ I i - --i i , i Std Betw.Cent. - Mid Contamination —Cement Coverage — Uncontaminated Slurry ---A :111P--...._w........... *"""-- '--Ar .----...' SI i 1 i I 1 Fluid Sequence Cement Coverage Uncontaminated Slurry 3 z 3 3 z 11000 111111 11000 11000 11000 11500 11500 11500 11500 -c 12000 - 12000 -c -c12000 12000 c a a a a- m as m as 0 0 0 0 12500 12500 12500 12500 13000 13000 13000 13000 m ; m m ; m `o 0 3 3 3 z z Page 12 SP31-W7.ctw:11-11-2014; LoadCase 9 5/8 Intermediate Casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlmnkergcr String District : Prudhoe Bay Country : USA Loadcase : 95/8 Intermediate Casing Section 2: operator summary MIXING PREPARATION MUDPUSH 11 Volume : 100.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 90.625 bbl D047 20.000 gal 0.200 gal/bbl of spacer D182 543.750 lb 6.000 lb/bbl of base fluid D031 11722.021 lb 117.22 lb/bbl of spacer Lead Slurry Volume:423.6 bbl Density : 12.50 lb/gal Yield : 1.56 f13/sk Dry Phase Liquid Phase Blend: 1629.7 sk Design Mix Water 198.0 bbl 10.0 bbl LAS Design 12.5-0.82-53 151977.266 Fresh water 197.961 bbl 10.001 bbl lb 0046 303.955 lb 0.200%BWOB D065 379.943 lb 0.250%BWOB D167 379.943 lb 0.250%BWOB D153 151.977 lb 0.100%BWOB Tail Slurry Volume:63.0 bbl Density : 15.80 lb/gal Yield : 1.16 ft3/sk Dry Phase Liquid Phase • Blend : 304.9 sk Design Mix Water 37.5 bbl 10.0 bbl LAS Design G 28657.824 lb Fresh water 33.265 bbl 8.873 bbl D047 57.316 gal 15.288 gal 0.188 gal/sk blend D185 17.195 gal 4.586 gal 0.056 gal/sk blend D168 100.302 gal 26.754 gal 0.329 gal/sk blend D177 2.866 gal 0.764 gal 0.009 gal/sk blend Page 13 SP31-W7.cfw;11-11-2014; LoadCase 95/8 Intermediate Casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 Schlimkrgcr String District : Prudhoe Bay Country : USA Loadcase : 9 5/8 Intermediate Casing Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 170.0 0.000 100.0 100.0 0.0 170.0 0.000 200.0 200.0 0.0 170.0 0.000 300.0 300.0 0.0 170.0 0.000 400.0 400.0 0.0 170.0 0.000 500.0 500.0 1.5 170.0 1.500 600.0 599.9 3.0 170.0 1.500 700.0 699.7 4.8 202.5 2.750 800.0 799.1 7.2 215.5 2.748 900.0 898.0 9.8 221.8 2.749 1000.0 996.2 12.4 225.5 2.750 1058.7 1053.3 14.0 227.0 2.754 1100.0 1093.3 15.1 227.0 2.761 1200.0 1189.1 17.9 227.0 2.750 1300.0 1283.5 20.6 227.0 2.750 1375.7 1353.9 22.7 227.0 2.747 1375.9 1354.1 22.7 227.0 4.544 1400.0 1376.3 22.9 227.0 0.499 1500.0 1468.3 23.4 227.0 0.500 1600.0 1559.9 23.9 227.0 0.500 1700.0 1651.2 24.4 227.0 0.500 1800.0 1742.1 24.9 227.0 0.500 1900.0 1832.7 25.4 227.0 0.500 1923.7 1854.1 25.5 227.0 0.464 2000.0 1922.1 28.3 227.0 3.761 2100.0 2008.5 32.1 227.0 3.750 2200.0 2091.4 35.8 227.0 3.750 2223.7 2110.5 36.7 227.0 3.713 2300.0 2170.5 39.6 227.0 3.761 2400.0 2245.5 43.3 227.0 3.750 2500.0 2315.9 47.1 227.0 3.750 2600.0 2381.6 50.8 227.0 3.750 2700.0 2442.2 54.6 227.0 3.750 2720.7 2454.0 55.3 227.0 3.725 2800.0 2497.4 58.3 227.0 3.756 2900.0 2547.1 62.1 227.0 3.750 3000.0 2591.0 65.8 227.0 3.750 3100.0 2628.9 69.6 227.0 3.750 3200.0 2660.7 73.3 227.0 3.750 3300.0 2686.3 77.1 227.0 3.750 3400.0 2705.4 80.8 227.0 3.750 3500.0 2718.1 84.6 227.0 3.750 3564.7 2722.9 87.0 227.0 3.743 3600.0 2724.7 87.0 227.0 0.000 3700.0 2729.9 87.0 227.0 0.000 3800.0 2735.2 87.0 227.0 0.000 3900.0 2740.4 87.0 227.0 0.000 4000.0 2745.6 87.0 227.0 0.000 4100.0 2750.9 87.0 227.0 0.000 4200.0 2756.1 87.0 227.0 0.000 4300.0 2761.3 87.0 227.0 0.000 4400.0 2766.6 87.0 227.0 0.000 4500.0 2771.8 87.0 227.0 0.000 4600.0 2777.0 87.0 227.0 0.000 4700.0 2782.3 87.0 227.0 0.000 4800.0 2787.5 87.0 227.0 0.000 4900.0 2792.7 87.0 227.0 0.000 Page 14 SP31-W7.cfw,11-11-2014; LoadCase 9 5/8 Intermediate Casing,Version wcs-cem472_05 Client : EM Well : SP31-W7 Srthi berger String District : Prudhoe Bay ��(( �j Country : USA Loadcase : 9 5/8 Intermediate Casing Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 5000.0 2798.0 87.0 227.0 0.000 5100.0 2803.2 87.0 227.0 0.000 5200.0 2808.4 87.0 227.0 0.000 5300.0 2813.7 87.0 227.0 0.000 5400.0 2818.9 87.0 227.0 0.000 5500.0 2824.1 87.0 227.0 0.000 5600.0 2829.4 87.0 227.0 0.000 5700.0 2834.6 87.0 227.0 0.000 5800.0 2839.8 87.0 227.0 0.000 5900.0 2845.1 87.0 227.0 0.000 6000.0 2850.3 87.0 227.0 0.000 6100.0 2855.5 87.0 227.0 0.000 6200.0 2860.8 87.0 227.0 0.000 6300.0 2866.0 87.0 227.0 0.000 6400.0 2871.2 87.0 227.0 0.000 6500.0 2876.5 87.0 227.0 0.000 6600.0 2881.7 87.0 227.0 0.000 6700.0 2886.9 87.0 227.0 0.000 6800.0 2892.2 87.0 227.0 0.000 6900.0 2897.4 87.0 227.0 0.000 7000.0 2902.6 87.0 227.0 0.000 7100.0 2907.9 87.0 227.0 0.000 7200.0 2913.1 87.0 227.0 0.000 7300.0 2918.3 87.0 227.0 0.000 7400.0 2923.6 87.0 227.0 0.000 7500.0 2928.8 87.0 227.0 0.000 7600.0 2934.0 87.0 227.0 0.000 7700.0 2939.3 87.0 227.0 0.000 7800.0 2944.5 87.0 227.0 0.000 7900.0 2949.7 87.0 227.0 0.000 8000.0 2955.0 87.0 227.0 0.000 8100.0 2960.2 87.0 227.0 0.000 8200.0 2965.4 87.0 227.0 0.000 8300.0 2970.7 87.0 227.0 0.000 8400.0 2975.9 87.0 227.0 0.000 8500.0 2981.2 87.0 227.0 0.000 8600.0 2986.4 87.0 227.0 0.000 8700.0 2991.6 87.0 227.0 0.000 8800.0 2996.9 87.0 227.0 0.000 8900.0 3002.1 87.0 227.0 0.000 9000.0 3007.3 87.0 227.0 0.000 9100.0 3012.6 87.0 227.0 0.000 9200.0 3017.8 87.0 227.0 0.000 9300.0 3023.0 87.0 227.0 0.000 9400.0 3028.3 87.0 227.0 0.000 9500.0 3033.5 87.0 227.0 0.000 9600.0 3038.7 87.0 227.0 0.000 9700.0 3044.0 87.0 227.0 0.000 9800.0 3049.2 87.0 227.0 0.000 9900.0 3054.4 87.0 227.0 0.000 10000.0 3059.7 87.0 227.0 0.000 10100.0 3064.9 87.0 227.0 0.000 10200.0 3070.1 87.0 227.0 0.000 10264.7 3073.5 87.0 227.0 0.000 10300.0 3075.6 86.3 227.0 -2.012 10400.0 3083.8 84.3 227.1 -1.992 10500.0 3095.4 82.3 227.3 -2.003 Page 15 SP31-W7.cfw,11-11-2014; LoadCase 9 5/8 Intermediate Casing;Version wcs-cem472_05 Client : ENI Well : SP31-W7 S Schlimilrger String District : Prudhoe Bay Country : USA Loadcase : 95/8 Intermediate Casing Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 10600.0 3110.6 80.3 227.4 -2.003 10694.0 3127.9 78.4 227.5 -2.002 10700.0 3129.1 78.4 227.5 0.000 10800.0 3149.2 78.4 227.5 0.000 10900.0 3169.3 78.4 227.5 0.000 11000.0 3189.3 78.4 227.5 0.000 11100.0 3209.4 78.4 227.5 0.000 11200.0 3229.5 78.4 227.5 0.000 11300.0 3249.6 78.4 227.5 0.000 11400.0 3269.6 78.4 227.5 0.000 11500.0 3289.7 78.4 227.5 0.000 11588.7 3307.5 78.4 227.5 0.000 11600.0 3309.8 78.5 227.8 3.037 11700.0 3329.1 79.2 230.8 2.992 11800.0 3347.3 79.9 233.7 3.003 11900.0 3364.2 80.6 236.7 3.000 12000.0 3379.9 81.4 239.6 3.002 12100.0 3394.2 82.2 242.6 3.003 12200.0 3407.1 83.0 245.5 2.994 12300.0 3418.7 83.8 248.4 3.002 12400.0 3428.8 84.6 251.3 3.005 12500.0 3437.5 85.4 254.2 2.990 12563.7 3442.2 86.0 256.0 3.008 12600.0 3444.8 86.0 256.0 0.000 12700.0 3451.7 86.0 256.0 0.000 12800.0 3458.7 86.0 256.0 0.000 12900.0 3465.7 86.0 256.0 0.000 13000.0 3472.7 86.0 256.0 0.000 13100.0 3479.6 86.0 256.0 0.000 13200.0 3486.6 86.0 256.0 0.000 13300.0 3493.6 86.0 256.0 0.000 13320.8 3495.1 86.0 256.0 0.000 13321.0 3495.1 86.0 256.0 0.000 Page 16 SP31-W7.ctw.11-11-2014, LoadCase 95/8 Intermediate Casing;Version wcs-cem472_05 Attachment 6 FIT & LOT Procedure 111041 ENI S.p.A. SPEO IDENTIFICATION CODE PAG 206 OF 338 Eno E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW = +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight (PPG) Metric units EMW = P x 10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Enti E&P Division REVISION STAP-P-1-M-6140 0 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4° and smaller holes) or 0.50 bbl (171/2° hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 208 OF 338 EnII E&P Division REVISION STAP-P-1-M-6140 (-7-771 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent dlevice, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of `Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. 1401 ENI S.p.A. SPEO IDENTIFICATION CODE PAG 209 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 LEAK-OFF TEST REPORT Report N' Date: WELL NAME: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 MudT}pe: FWGELS Rig type: J.UPs Hole Dameter(in): 121/4 Weight(KgA): 1.3 R.K.B.eletenon(m): 26 Last Csg.Shoe(m): 797 -Marsh Uscosity(sec/Ot): 44 Water Depth(m): 24 Csg.diameter(in): 13'3/E P.V.(cps): 19 Pumps: 12-P-160 Grade: .155 Y.P.(1bf1001F): 5 Liners(in): 6.5" -Weight Obit): 61 Gels(1bf100 t'): ' „ 2/S Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 118.L(ccsS min): 10.5 Litholog y Shale Expected EMW 1.68 Kg/cm2/1 0 m Time Volume Pressure Time Volume Pressure Time Volume Pressure (min) (bbl) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 480 16 2 435 2 050 100 95 2 480 3 0.75 200 10 2 470 4 1 D0 300 10.5 2 - 463 5 125 400 11 2 455 6 150 500 11.5 2 460 7 1.75 570 12 2 445 8 200 600 13 2 440 8 200 550 14 2 437 8.5 200 505 15 2 435 Note: Pumped with a constant tow rate of(bbl): Vblume pumped(bbl): \.blume retjm ed(bbl): (pus) 1000 • 900 — .. - — 800 stop pump F 700 - e 600 �r - shut in curve S 500 / -,•��_. U 400 r I8 minutes e 300 200 100 0 , 0 0,25 0,5 0,75 1 1,25 1,5 1,75 i1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbt) 41 11 Time mins RESULTS (Press.,, +Press.Lo,)x10/Depth=[(1.3x797/10)+(430x0.07)]x101797=1.68(Kgfcm2/10 m) Note: I Company Representatiie Figure 15-1 - Leak-Off Test Report Attachment 7 Surface Platt REV DATE , BY CK APP DESCRIPTIOO REV, DATE BY CK APP DESCRIPTION D 10/01/10 DHS CC CC "1.0 -)rowing VICINITY MAP SCALE: 1" 7-- 2 1,11es 1b' IIT ,� I1 �8 1' _— or ) ______ ----- _____ _ _ I ._ ,, H___ _ __- THIS I _ SURVEY --t_. ____ __. „ _.. ______, ,. 0— — ,si. 2, 1 _... , _,.: , ',,a 19 21.; 21 „, , 26 25 30 2 �F! 25 30 29 2S 2 i A.S.P. NAp83, Za. 35 38 C4 ir 31 3,2 -`3 3 55 58 &F, 31 5:: 31, ya T14N I T14N T13NTRK I T13N 4 3 2 1 KTTK Pa T PAD", oo�rc -V ! 1 . 4 —'3 DSR 1G 1I `IJ 1 •• ? , 1c „ , {, r t .6 1 Q le 15 DS'r3�0E {,t,....w>� PAD., 1 4 }� i '' " i i 0 1 �-' c 7G 7 1G 7 J ' 7 � 1, 21 i l l3 ' w tf .> Mine SI v xCi o �I r, �" 3 D ni TH0 e, 05 3M 0, VO' 3,4 I + 4L, 9 PAD (DO ' t (ryADT 1�r NEST SNile, .n • '� ('F+U i �� • —tom 4�. l> DRAWING NOTES: 1. GRID COORDINATES SHOWN ARE ALAKA STATE PLANE, ZONE 4, NAD83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD83. 3. BASIS OF LOCATION DERIVED FROM CPS STATIC OBS. PROCESSED INTO OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TOWNSHIP 14 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. ALL SECTIONS SHOWN AND/OR REFERENCED IN THIS DRAWING ARE 'PROTRACTED SECTIONS'. 7. REFERENCE LOUNSBURY DOCUMENT E-087 FOR COORDINATE VALUES IN NAD27. .46,41,, ,- --..,.............. SURVEYOR'S CERTIFICATE • 49th �\ t* #4 M I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND • 0 -- . 4 't It LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF >% I �i:Kr"" ,::t�.r�a. ... ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY I♦c�G,`;•FRANCIS J. CORNING s DONTHAT ALL DIMENSIONS AND OTHER BY ME OR UNDER MY DETAILS DETAIILS ARENAND CO CORRECT �i,s.A LS-10695 ,�i AS OF OCTOBER 01, 2010 • �pl! �7o�.# - '. , ,y, ? o i11�tS ►I ' �A� Aliiiiiiill, &gssoc SPY ISLAND DRILL SITE s`t y WELL CONDUCTORS AS-BUILT LOCATIONS 2n 11 CAD FILE:EN13543D9 MS operating DAT[ /01/2010 DRAWING NO: Ent-3543--d9 PART: REV: 3 RE I 0 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 0 'C/:_ /",: ,' S CC CC "..,:c ,Drcww,-g N 9r9- P()N4. ".,.-...t 1 _....!' A 2.„ 1—___1 \ Sec. •9 V, 0 tA T. Ser, 2E) A S P NANO, 74. t; 7ri -J.. -1 000000 .... :4' 0004V"" N) td+ '2. 4) 00700° , s 000000 .., -. 1, t') GI LA i "1 t..) GO CP lrl trr n pa 1,1 0 •-.1 00 . t8 (.,, LA .D. ra L.3 cn Co DETAIL A. SCALE: 1"-..80' soloBAG Ia. ‘,,t G940ut_DER iu,'“- ., e.o t ,,•-:0;;0'0.1.1.4r7 c,0‘. DETAIL A L . '‘ SPY ISLAND DRILL SITE (SID) GRoo. 5vAckat- ----- ArlDBAG WE LEGEND SCALE 200 0 '00 200 0 = WELL CONDUCTOR AS-BUILT THIS SURVEY Illi J111_11111 JIM. 1" = 200' i SPY ISLAND DRILL SITE 4t. ft sit, .., ,, WELL CONDUCTORS • J\ , AS—BUILT LOCATIONS CAD FILE EN 354309 us operating DAlt: DRAWING NO: PART: REV: 10/01/2010 Eni-3543—d9 2 OF 3 0 REV DATE BY CK APP . DESCRIPTION REV DATE BY CK APP DESCRIPTION 0 .o/i./'v :i'...s CC CC rr.;.+C ' 'Cwr g Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian Alaska State Plane, NAD83 GRID NAD83 Geographic Section Line Offset Pad Well No. - 'Y' 'X' Latitude (N) Longitude (W) F.N.L F.E.L Elev. (US ft.) (US ft.) 1 6053423.20 1651769.82 70033127.209" 149054124.765" 797 1171 12.4 2 6053421.65 1651761.87 70033127.194" 149054'25.000" 798 1179 12.4 3 6053420.07 1651754.10 70033127.179" 149054'25.229" 800 1186 12.4 4 605341836 1651746.17 70033'27.164" 149054'25.463" 801 1194 12.4 5 6053417.03 1651738.44 70033'27.149" 149054125.692" 803 1202 12.4 6 6053415.54 1651730.54 70033'27.134" 149054'25.925" 804 1210 12.4 7 6053412.44 1651714.77 70033'27.104" 149054126.391" 807 1226 12.4 8 6053410.91 1651706.96 70033127.089" 149054126.622" 809 1234 12.4 9 6053409.39 1651699.11 70033'27.074" 149054'26.853" 810 1241 12.4 10 6053407.94 1651691.31 70033'27.060" 149054127.084" 812 1249 12.4 11 6053406.32 1651683.39 70033127.044" 149054'27.318" 813 1257 12.4 12 6053404.80 1651675.51 70033'27.029" 149054127.551" 815 1265 12.4 13 6053400.38 1651652.80 70033126.986" 149054'28.221" 819 1288 12.4 14 6053398.83 1651644.95 70033126.971" 149054128.453" 821 1296 12.4 15 6053397.31 1651637.12 70033126.956" 149054'28.685" 822 1304 12.4 16 6053395.82 1651629.26 70033'26.942" 149054128.917" 824 1311 12.4 17 6053394.32 1651621.47 70°33'26.927" 149054129.147" 825 1319 12.4 18 6053392.78 1651613.58 70033'26.912" 149054129.380" 827 1327 12.4 19 6053389.63 1651597.90 70°33'26.881" 149054129.843" 830 1343 12.4 20 6053388.17 1651590.00 70033'26.867" 149054130.076" 831 1351 12.4 21 6053386.60 1651582.24 7003326.852" 149054130.306" 833 1358 12.4 22 6053385.19 1651574.35 70033'26.838" 149054'30.538" 834 1366 12.4 23 6053383.64 1651566.41 70033126.823" 149054130.773" 836 1374 12.4 24 6053382.12 1651558.61 70033'26.808" 149054131.003" 837 1382 12.4 25 6053377.65 1651535.94 70033'26.764" 149054131.673" 842 1405 12.4 26 6053376.14 1651528.13 7003326.750" 1491'54'31.904" 843 1413 12.4 27 6053374.53 1651520.23 70033'26.734" 149054'32.137" 845 1421 12.4 28 6053373.11 1651512.46 70033126.720" 149054132.366" 846 1428 12.4 29 6053371.56 1651504,49 70033'26.705" 149054'32.602" 848 1436 12.4 30 6053370.06 1651496.66 70033126.690" 149054'32.833" 849 1444 12.4 31 6053367.05 1651480.97 70033'26.661" 149054'33.296" 852 1460 12.4 32 6053365.47 1651473.16 70033126.646" 149054'33.527" 854 1468 12.4 33 6053363.93 1651465.22 70033'26.631" 149054133.762" 855 1476 12.4 34 6053362.44 1651457.37 70033'26.616" 149054'33.993" 857 1483 12.4 35 6053360.91 1651449.52 70033126.601" 149054'34.225" 858 1491 12.4 36 6053359.33 1651441.62 70033126.586" 149054'34.459" 860 1499 12.4 37 6053356.19 1651425.30 70033126.555" 149054'34.941" 863 1516 12.4 38 6053354.74 1651417.32 70033'26.541" 149054'35.177" 864 1524 12.4 > i ' il .0•1�ge, SPY ISLAND DRILL SITE .: ?4 WELL CONDUCTORS • AS-BUILT LOCATIONS @ 11II i.v ,. 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U a) U o CO c o O U 0 CJ 0 C Attachment 8 1/4 Mile Scan Report SP31-W7(P8)Anti-Collision Detailed Report Analysis Method: 3D Least Distance Distance Unit ft Depth Interval: Every 50.00(ft)Measured Depth Azimuth Unit deg Step-down Trajectory: Reference Trajectory TC Azimuth Refereno: North Analysis Date-24hr Time: November 00,2014-14:01 North Reference: Tn/e Analysis Machine: AKA-DEC-9010 Client Eni Petroleum Database 1 Project: IocalhostldrillingNikaitdro 2.8572 Version I Patch: 2.8.5720 NOTE:Measured Depth is referenced to individual borehole elevation. TVD,NS,EW are referenced to the reference trajectory's wellhead location and borehole elevation. A minimum of 0.300 or is always included for borehole diameters. Alt local minima indicated. Results filtered:Depth 13300.00 It o.MD<=22950.59 ft,Ct-Ct separation<.1500.00 ft Results highlighted:EOU-EOU NparatIon 0.1320.00 ft Anti-Collision Rules Used Rule Set Name DAM AnlCollision Standard 5002 v5.1/5.2 Exemption Risk Level: Minor RulEName )tisk Level Buie Type Jauk L.psd NnDtBW9 SLB Alert Zone Threshold OSF=5.0 S00205.115.2 Alen Ratio OSF=5.00 SLB Minor Risk Threshold OSF=1.5 S002 05.115.2 Minor Ratio OSF=1.50 X SLB Major Risk Threshold OSF=1.05002 v5.1/5.2 Major Ratio OSF=1.00 SLB Surface Rule 5002 v5.15.2 Major CT_CT MAS=32.81(ft) SLB Alert Zone Threshold CtCt<=15m S002 v5.15.2 Alert CT_CT MAS=49.21(ft) Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-W7\SP31-W7(P8) 11/6/2014 2:01 PM Page 1 of 18 Reference Trajectory Summary Field: Nikaddmg Well: SP31-W7 585010re: Spy Island Borehole: SP31-W7 Slot SP31 Trajectory: SP31-W7(P8) Client: Eni Petroleum Type: Del Plan Coordinate System: NAD27 Alaska Stets Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08855791° Grid Scale Factor: 0.999900149 Magnetic Declination: 18.977° Magnetic Declination Date: December 31,2014 Magnetic Model: BGGM 2013 Reference Point 114Mae Eestin. Elevation Structure Unc. Slot Une 6053614950(RUS) 511450.170(OUS) 54.100(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 e.gena) Traleotoru Error Model 1SCWSAO 3-0 95.000%Confidence 2.7955 signs. Surveying Pro.'While Drilling Description Part MD From(ft) MD Ton EOU Fraq(ft) Survey Tool Type Hole fila(n) Casing Diameter)1) Borehole/Survey 1 0.000 41.000 11700.000 SLB_NSG+SSHOT-Depth Only-No Globe 16.000 13.375 SP31-W//SP31-WI(PB) 1 41.000 1100.000 1/100.000 SLB NSG+SSHOT-No Globs 16.000 13.375 SP31-W7/SP31-W7(P8) 1 1100.000 2850.132 11100.000 SLB MWD+SAG-No Globe 16.000 13.375 SP31-W7/SP31-W7(P8) 2 1100.000 2850.132 1/100.000 SLB MWD+GMAG-No Globe 16.000 13.375 SP31-W7/SP31-W7(P8) 2 2850.132 4350.000 1/100.000 SLB MWD+SAG-No Globe 12250 9.625 SP31-W7/SP31-W7(P8) 3 2850.132 13207.309 1/100.000 SLB MWD+GMAG-No Globe 12.250 8.625 SP31-W7/SP31-W7(P8) 3 13207.309 14700.000 11100.000 SLB MWD+SAG-No Globe 6.750 5.500 SP31-W7/SP31-W7(P8) 4 13207.308 22950.592 1/100.000 SLB MWD+GMAG-No Globe 8.750 5.500 SP31-W7/SP31-W7(P8) • • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-VV7\SP31-W7\SP31-W7(P8) 11/6/2014 2:01 PM Page 2 of 18 Offset Trajectory Summary Offset Selection Criteria; Offset Selection Criteria:Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Selection Summary Nblls Selected:4 Boreholes Selected:6 Definitive Surveys Selected 4 Non-Def Surveys Selected:0 Definitive Plans Selected:2 Non-De(Plans Selected0 Total Trajectories:6 OSF filler in detailed report None •Excluded:The trajectory was analyzed end fully passed all criteria so the detailed results have been excluded front this report for clarity. TraJeetery Borehole Well Type Passing Exeluded" 0113-03 0113.03 0113-03 Def Survey 5131-1A6L1(P2) S1341A6L1 S134-N6 Def Plan 5134-1.45(P6) S134N6 SI341/V6 Def Plan 0P17-02PB1 OP17-02P81 OP17-02 Def Survey 00408 0124-08 0124-08 Def Survey OP17-02 OP17-02 OP17-02 Def Survey Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-W7\SP31-W7(P8) 11/6/2014 2:01 PM Page 3 of 18 Field: NikedMuq Well: 0113-03 Structure: Oliktok Point Borehole: 0113-03 Slot: OP13 Trajectory: 0113-03 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Corrvergen8.Angle: 0.12847606° Grid Scale Factor: 0.999900315 Magnetic Declination: 20.862° Magnele Deelinagen Date: October 25,2011 Magnetic Model: BOOM 2011 Reference Point Nom .E.62110g EWOW Structure Uno. IOS tUnc. 6036524 380(SUS) 516654 550(IIUS) 53.200(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Trajectory Error Model:ISCWSAO 3-0 95.000%Congdenee 2.7966 sigma Surveying Pro%As Drilled Description MD From(ft) MD To(to EOU Freq Survey Tool Type Hole Sloe(In) Casing Diameter On) Borehole l Survey 0.000 41.000 158.425 SLB GYRO-MNA-Depth Only-No Globe 16.000 13.375 0113-03/0113-03 41.000 41.000 Act-Stns SLB GYRO-MWD-Depth Only-No Globe 16.000 13.375 0113-03/0113-03 41.000 1013.510 ActSinc SLB GYRO-MIND-No Globe 16.000 13.375 0113-03/0113-03 1013.510 2577.280 Act-Sins SLB MW0+GMAG-No Globe 16.000 13.375 011303/0113-03 2577.280 2659.260 Act-Stns SLB MWD-INC ONLY>10-No Globe 12.250 9.625 0113-0310113-03 2659.260 21262.440 Act-Sins SLB_MW9+GMAG-No Globe 12.250 9.625 0113-03/0113-03 21262.440 21327.000 Act-Stns SLB BLIND+TREND-No Globe 12250 9.625 011303/0113-03 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (0) (ft) (1t) (6) (6) (0) (0) _ (°) (0) (0) (0) All local minima indicated. • Results filtered:Depth 13300.00 ft<-MD<=22950.59 6 Results filtered:Ct-Cf separation 00 1500.00 ft Results higNighted:Ct-Ct separation<=1320.006 3300.00 3493.70 -7234.63 -8630.95 8704.85 3488.02 6428.80 -8070.38 35006 981.64 436.80 690.09 3.38 OSF150 Warning 3350.00 3497.18 -724670 -867935 872367 348735 -6417.96 -8085.75 349.84 101944 43702 72773 3.50 05F1.50 Waning 340000 3500.58 -725855 -8727.80 8758.66 3485.78 6397.65 -8114.20 34981 105729 438.07 764.89 363 OSF150 Nardng 3450.00 3503.35 -7269.02 -8776.61 8795.39 3483.64 -637644 -8144.11 350.24 1094.15 439.19 801.00 374 OSF1.50 Warrdng 3500.00 350544 -727793 -8825.76 8834.87 3480.84 -6353.77 -8176.30 35094 1129.82 440.39 835.87 385 OSF150 Naming 3550.00 3506.82 -728527 5875.20 8879.39 3477.80 -6328.42 -8212.77 351.62 1184.14 441.82 889.24 398 OSF150 Warning 3600.00 3507.51 -729103 -8924.86 8928.63 3474.86 -6300.67 -8253.35 352.59 1197.00 443.40 90105 406 OSF150 Warning 3650.00 3507.49 -7295.19 -8974.68 9008.07 347278 -625725 -8319.82 35383 1227.76 448.13 92998 4.13 OSF150 Warning 3700.00 3506.78 -7297.76 -9024.61 9048.44 3472.97 -6235.77 -8354.01 35527 1256.45 447.31 957.89 4.22 OSF150 Warning 3750.00 350537 -7298.73 -9074.58 9082.51 3473.04 -6217.50 -8382.76 356.79 1284.03 44829 984.81 430 OSF1.50 Naming 3800.00 350354 -7298.74 -9124.55 9116.75 3472.93 -6198.96 -841154 356.98 131104 449.27 1011.17 4.38 OSF1.50 Warning 3850.00 3502.50 -7289.50 -9174.53 9157.38 3472.79 -6176.84 -8445.63 356.58 1338.88 450.52 1038.15 4.48 OSF1.50 Warning 3900.00 3002.70 -7300.88 -9224.51 9198.08 3472.47 6154.68 -8479.76 358.10 1387.23 451.79 1065.68 4.55 OSF1.50 Warning 3950.00 3503.91 -7301.15 -9274.49 9234.24 3472.09 -6134.96 -8510.07 359.42 1394.76 452.93 1092.46 4.63 OSF1.50 Warning 4000.00 3505.30 -7301.20 -9324.47 9265.88 3471.61 -6117.53 -8538.47 359.37 1422.38 453.89 111943 4.71 OSF1.50 Warning 4050.00 3506.50 -7301.26 -9374,45 9297.20 3471.01 6100.09 -8562.49 359.32 1450.29 454.87 1146.69 4.79 OSF1.50 Warning 4100.00 3508.08 -7301.31 9424.43 9335.99 3470.15 6078.31 -8594.57 35925 1478.45 456.14 1174.00 4.87 OSF1.50 Warning 4150.00 3509.48 -7301.36 -9474.41 938497 3489.43 6050.94 6635.18 359.18 1506.48 457.86 1230.50 4.94 OSF1.50 Warning 4200.00 3510.87 -7301.37 -9524.39 9448.35 3489.06 6015.92 6888. 359.80 1534.17 460.13 1227.06 5.01 OSF1.50 Pass 4250.00 3512.32 -7300.13 -9574.35 9521.19 346855 6976.89 -8748.50 1.54 1559.89 462.72 1251.05 5.06 OSF1.50 Pass 4300.00 3513.85 -7297.15 -962424 9564.63 346839 -5953.91 -8786.37 3.50 1583.79 464.24 1273.94 5.13 OSF1.50 Pass 4350.00 3515.45 -7292.43 -9673.99 9808.92 346848 -593046 -882393 5.48 1606.18 45.84 1295.24 5.18 OSF1.50 Pass 4400.00 3517.12 -7285.98 9723.54 9670.59 3468.91 6898013 -8876.41 7.40 1626.73 46804 1314.35 5.22 OSF1.50 Peso 4450.00 3518.83 -7277.80 -9772.83 9719.57 3469.41 -587266 -8918.29 9.34 1645.33 463.86 1331.73 5.26 OSF1.50 Pass 4500.00 520.59 -7267,91 -9821.81 9749.60 3469.66 -5856.92 -8943.86 11.28 1662.61 471.05 1348.22 5.30 OSF1.50 Pass 4550.00 522.39 -7256.53 9870.48 9779.74 3489.83 684087 -896936 12.22 1878.95 472.25 1363.76 5.34 OSF1.50 Pass 4600.00 524.19 -7244.95 -9819.07 9810.61 346993 -5824.15 -8995.32 1219 1695.57 473,45 1379.57 5.38 OSF1.50 Pass 4630.00 525.89 -7233.37 9987.88 9848.05 3470.53 -5804.72 9024.95 12.18 1712.56 474.84 1395.64 5.42 OSF1.50 Pass 4700.00 3627.79 -7221.79 -10016.29 9881.32 3471.93 -5785.17 9054.27 12.19 1729.88 476.21 1412.05 5.46 OSF1.50 Pass 4750.00 529.59 -721021 -10064.89 9920.34 3474.40 -5763.34 -8086.52 12.24 1747.49 474.50 1430.80 5.53 OSF1.50 Pass 4800.00 3531.17 -7198.69 -1011352 9966.45 3478.29 -5737.49 -9124.51 1191 1765.23 47592 1447.59 557 OSF1.50 Pass 4850.00 3531.92 -7187.5 -10162.21 20008.86 3482.72 -5713.73 -9159.5 11.44 1783.17 477.18 1464.70 5.61 OSF1.50 Pass 4900.00 531.84 -7176.12 -10210.93 0037.84 3486.01 -569734 -9183.02 11.30 1801.52 477,77 1482.65 5.67 OSF1.50 Pass 4950.00 3531.34 -7164.79 -10259.63 006657 3489.35 -588088 9206.33 11.43 1820.22 478.33 1500.98 5,72 OSF1.50 Pass 5910.00 530.84 -7153.46 -10308.33 0095.06 349274 -5664.33 -9229.27 11.57 1839.38 478.85 1519.79 5.77 OSF1.50 Pass 5050.00 3530.34 -7142.14 -1057.03 20121.12 3495.87 -5648.99 9250.10 11.89 185802 479.22 155.18 5.83 OSF1.50 Pass 5100.00 529.84 -7130.81 -10405.72 20146.35 3498.85 -5633.92 9270.12 11.80 1879.16 479.51 1559.13 5.89 OSF1.50 Pass 5150.00 3529.34 -7119.48 -10454.42 20171.36 3501.73 6818.76 9289.80 11.91 1899.81 479.76 1579.61 5.95 OSF1.50 Pass 5200.00 528.84 -7108.15 -10503.12 20196.14 3504.52 -5603.53 9309.14 12.02 1920.95 47996 1603.62 6.01 OSF1.50 Pass 5250.00 3528.34 -7098.82 -10551.81 20218.89 3508.91 -5589.47 9326.61 12.11 1942.60 480.01 1622.24 6.08 OSF1.50 Pass 5300,00 527.84 -708550 -10600.51 20240.69 3508.95 -5575.54 9343.51 1219 1964.78 47999 1844.43 6.15 OSF7.50 Pass 5350.00 527.41 -7074.10 -10649.19 2026251 510.69 -5561.52 9360.14 1278 1987.42 47993 1667.11 6.22 OSF1.50 Pass 5450.00 3527.50 -7062.17 -10697.75 20284.26 512.12 6547.33 9376.57 13.90 2010.09 479.82 1689.86 6.29 OSF1.50 Pass 5450.03 3528.22 -7049.64 -10748.15 20305.71 513.26 6533.16 9392.63 14.98 2032.73 479.65 171261 6.37 OSF1.50 Pass 5500.03 529.56 -703654 -10794.38 2032657 514.15 -551918 940009 16.03 2055.33 479.41 175.37 6.44 OSF150 Pass 5550.00 3531.53 -7022.85 -1084243 20347.32 514.83 6505.11 -9423.31 17.06 2077.91 479.14 1758.13 6.52 OSF1.50 Pass 5600.50 534.10 -700859 -10890.29 20367.94 3515.32 -5490.94 -9438.29 17.82 2100.46 478.83 1780.88 6.59 OSF1.50 Pass 5850.03 3536.86 -6994.17 -10938.08 20388.34 515.61 -5476.75 9452.95 17.80 2123.36 478.51 1803.99 667 OSF1.50 Pass 5700.00 539.62 6979.75 -10985.88 20412.99 515.60 -5459.41 9470.47 17.76 2146.73 478.47 1827.40 6.74 OSF1.50 Pass 5750.00 3542.37 -696533 -11033.67 20440.46 515.39 -5439.95 -948986 17.70 2170.45 478.61 1851.02 6.81 OSF1.50 Peso 5800.01 3545.06 -6950.69 -11081.40 20487.72 514.68 -5420.50 9508.94 18.23 2194.32 478.72 1874.82 6.89 OSF1.50 Pass 585000 547.44 695.12 -11128.86 20494.98 513.55 -5400.92 9527.87 19.09 2217.67 478.80 1898.11 8.96 OSF1.50 Pass 5900.00 3549.49 -6918.56 -11175.99 20542.13 3510.94 -5386.97 9560.49 1994 224025 480.29 1919.70 7.01 OSF1.50 Pass 5950.00 3551.25 6901.00 -11222.77 20590.5 3507.63 -5332.34 -9593.88 20.82 2261.83 481.84 1940.25 7.05 OSF1.50 Pass 8000.00 355274 6882.46 -11269.18 20656.06 3502.42 525.43 -963959 21.67 2282.24 484.59 1958.82 7.08 OSF1.50 Pass 6050.25 3554.04 -6863.23 -11315.32 20719.82 3497.12 -5240.32 -9684.34 21.74 2301.56 487.17 1978.42 7.10 OSF1.50 Pass 6100.00 555.33 -6843.98 -11361.44 2077979 3493.31 5198.09 9726.75 21.61 2320.57 460.46 1993.90 7.12 OSF1.50 Pass 6150.25 556.63 6824.72 -11407.57 20824.28 3491.35 -5166.81 5758.33 2153 2339.43 490.69 2011.95 7.16 OSF1.50 Pass 6200.00 3557.92 -6805.47 -11453.70 20865.34 3490.11 -5137.88 -9787.41 21.48 235839 491.68 2030.25 7.21 OSF1.50 Pass 6250.00 559.22 6786.13 -11499.79 20907.84 3489.33 6107.81 -9817.46 21.97 237736 492.77 2048.49 7.25 OSF1.50 Pass Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-507\SP31-W7\SP31-W7(P8) 11/6/2014 2:01 PM Page 4 of 18 Trajectory:SP31-W7(P8)V.0113-03 Minimum Traveling Cylinder Allowable EOU-E00 Reference MD Referenoe TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Cr Distance Separation Clearance OSF Controlin9 Rule Status (8) (6) (8) (ft) (9) (tt) (9) (8) (') (ft) (n) (ft) 16300.00 3560.85 -676597 -11545.52 20952.45 3488.68 5076.23 -9848.97 23.21 2395.56 493.99 2065.87 729 OSF1.50 Pass 16350.00 356222 -6744.83 -11590.80 21000.E 3486.07 5042.07 5883.01 24.44 2412.77 495.44 208212 7.32 OSF1.50 Pass 16400.00 3563.94 -6722.72 -11635.61 2105994 3487.54 5000.22 -0924.98 25.65 2428.82 497.64 2096.71 733 OSF1.50 Pass 16450.00 3565.76 -6699.64 -11679.93 21119.47 3487.14 -4958.39 8867.31 26.84 2443.61 499.86 2110.02 7.35 OSF1.50 Pass 16500.00 3567.68 -667561 -11723.73 21179.25 3486.40 -4916.59 -10010.09 28.02 2457.13 50206 212205 7.35 OSF1.50 Pass 16550.00 3569.70 -6650.63 -11767.00 21264.79 3485.04 -4857.40 -10071.78 29.15 2469.13 506.77 130.92 7.32 OSF1.50 Pass 16600.00 3571.82 -6624.71 -11809.70 21313.60 3484.29 -4823.90 -10107.26 30.31 2479.70 524. 7.1 OSF1.50 Pass 16650.00 3674.03 5597.88 -11851.83 21327.00 3484.08 -4814.70 -10117.00 31.52 2489.47 528.16 2137.01 OSF1.50 Pass 1670000 3576.30 -6570.51 -11893.62 21327.00 3484.08 -481470 -1011700 31.63 2499.55 528.37 2148.29 7.13 OSF1.50 Pass 16750.00 3578.46 554303 -11935.33 21327.00 3484.08 -481470 -1011700 32.05 2510.45 524.45 2160.46 7.19 OSF1.50 Pass 18800.00 3579.99 5514.90 -11976.63 21327.00 3484.08 -4814.70 -10117.00 32.82 2521.53 522.41 2172.90 7.25 OSF1.50 Pass 16850.00 358083 5186.06 -12017.47 21327.00 3484.08 -4814.70 -10117.00 33.59 253271 520.23 2185.53 7.31 OSF1.50 Pass 16900.00 358098 -6456.54 -12057.82 21327.00 3484.08 -4814.70 -10117.00 34.36 254398 517.94 2198.33 7.38 OSF1.50 Pass 18950.00 3580.81 -6426.69 -12097.94 21327.00 3484.08 -4814.70 -10117.00 34.38 2555.78 515.55 2211.72 7.45 OSF1.50 Pass 17000.00 358063 -6396.84 -12138.05 21327.00 3484.08 -4814.70 -10117.00 3436 2588.49 513.06 2226.10 7.52 OSF1.50 Pass 17050.00 358045 5367.00 -12178.17 21327.00 348408 -4814.70 -10117.00 34.36 2582.12 510.48 2241.44 7.60 OSF1.50 Pass 17100.00 3580.27 -6337.15 -12218.28 21327.00 3484.08 -4814.70 -10117.00 34.36 2596.83 507.82 2257.73 7.68 OSF1.50 Pass 17150.03 3580.10 5307.31 -12258.40 21327.00 3484.08 -481470 -10117.00 34.36 2612.02 505.08 2274.95 7.77 0571.50 Pass 17200.00 3579.92 -6277.46 -12298.51 21327.00 3484.08 -4814.70 -10117.00 34.36 2628.28 502.27 2293.07 7.86 OSF1.50 Pass 17250.00 3579.74 -8247.61 -12338.62 21327.00 3484.08 -4814.70 -10117.00 34.36 2645.37 499.41 2312.08 7.96 OSF1.50 Pass 17300.00 3579.58 -6217.77 -12378.74 21327.00 3484.08 -4814.70 -10117.00 34.36 2663.30 496.48 2331.96 8.06 OSF1.50 Pass 17350.00 3579.39 5187.92 -12418.85 21327.00 3484.08 -4814.70 -10117.00 34.38 2682.04 493.51 2352.68 8.17 OSF1.50 Pass 17400.00 3579.21 5158.07 -12458.97 21327.00 348408 -4814.70 -10117.00 34.36 2701.58 49050 2374.22 828 OSF1.50 Pass 17450.00 3578.87 5127.99 -12498.90 21327.00 3484.08 -4814.70 -10117.00 35.04 2721.61 487.43 2398.30 8.39 OSF1.50 Pass 17500.00 3578.27 5097.54 -12538.58 21327.00 348408 -4814.70 -10117.00 35.04 2741.99 48432 2418.75 8.51 0071.50 Pass 17550.00 3577.68 5087.10 -12578.22 2132700 348408 -4814.70 -10117.00 35.04 2763.12 481.19 2441.97 8.83 OSF1.50 Pass 17800.00 3577.08 -6036.65 -12617.87 21327.00 3484.08 -481470 -10117.00 35.04 2784.99 478.04 2485.94 8.75 OSF1.50 Pass 17650.00 3576.49 -6006.21 -12657.53 21327.00 3484.08 -4814.70 -10117.00 35.04 2807.58 474.89 2490.64 8.88 OSF1.50 Pass 17700.00 3575.90 -5975.76 -12697.19 21327.00 3484.08 -4814.70 -10117.00 35.04 2830.88 471.72 2518.04 9.02 OSF1.50 Pass 17750.00 3575.30 -5845.32 -12736.85 21327.00 3484.08 -4814.70 -10117.00 35.04 2854.86 488.55 2542.13 9.16 OSF1.50 Pass 17800.00 3674.71 -5914.87 -12776.50 21327.00 3484.08 -4814.70 -10117.00 35.04 2879.50 465.38 2568.90 9.30 OSF1.50 Pass 17850.00 3574.12 -5884.42 -12818.16 21327.00 3484.08 -4814.70 -1011700 35.04 2904.80 462.22 2598.30 9.45 0071.50 Pass 17900.00 3573.52 -5853.98 -12855.82 21327.00 3484.08 -4814.70 -10117.00 35.04 2930.74 459.07 2624.34 9.00 OSF1.50 Pass 17950.00 3572.88 -5823.52 -12895.48 21327.00 3484.08 -4814.70 -10117.00 35.02 2957.27 455.93 2852.96 9.75 OSF1.50 Pass 16000.00 3571.51 -5792.72 -12934.82 21327.00 3484.08 -4814.70 -10117.00 35.04 2984.01 452.79 2681.79 9.91 OSF1.50 Pass 18050.00 3569.96 -5761.83 -12974.11 21327.00 3484.08 -4814.70 -10117.00 35.04 3011.23 449.67 2711.08 10.07 OSF1.50 Pass 18100.00 3568.41 5730.94 -13013.40 21327.00 3484.08 -4814.70 -10117.00 35.04 3039.04 446.58 2740.96 10.23 OSF1.50 Pass 18150.00 3566.86 5700.05 -13052.69 21327.00 3484.08 -481470 -10117.00 35.04 3067.40 443.51 2771.37 10.40 OSF1.50 Pass 18200.00 3565.31 -5869.18 -13091.98 21327.00 3464.08 -4814.70 -10117.00 35.04 3098.32 440.47 280231 10.57 OSF1.50 Pass 18250.00 3563.69 -5637.96 -13131.01 21327.00 3484.08 -4814.70 -10117.00 36.25 3125.44 437.42 2833.46 10.74 0571.50 Pass 18300.00 3561.84 5605.84 -13169.11 21327.00 3484.08 -4814.70 -10117.00 37.91 3153.89 434.33 2863.98 10.92 OSF1.50 Pass 18060.00 3559.73 -5572.20 -13208.22 21327.00 3484.08 -4814.70 -10117.00 39.59 3181.63 431.18 2893.83 11.09 OSF1.50 Pass 18400.00 3557.37 5537.86 -13242.29 21327.00 3484.08 -4814.70 -10117.00 41.28 3206.66 427.99 2922.97 11.27 0571.50 Pass 18450.00 3554.81 -5502.05 -13277.29 21327.00 3484.08 -481470 -10117.00 43.07 3234.95 424.77 2951.41 11.45 OSF1.50 Pass 18500.00 355212 -5465.39 -13311.19 21327.00 3484.08 -4814.70 -10117.00 44.89 3260.50 421.52 2979.13 11.83 0571.50 Pass 18550.00 3549.31 -5427.73 -13343.95 21327.00 3484.08 -4814.70 -10117.00 46.71 3285.31 41825 3006.12 11.81 OSF1.50 Pass 18600.00 3546.39 -5389.06 -13375.54 21327.00 3484.08 -4814.70 -10117.00 48.54 3309.36 414.94 363737 11.99 0571.50 Pass 18650.00 3543.34 -5349.50 -13405.93 21327.00 3484.08 -481470 -10117.00 50.37 3332.65 411.63 3057.88 12.17 OSF1.50 Pass 18700.00 354018 -5309.02 -13435.10 21327.00 3484.08 -4814.70 -10117.00 52.03 3355.19 408.31 308263 12.35 OSF1.50 Pass 18750.00 3536.98 -5268.18 -13483.77 21327.00 3484.08 481470 -10117.00 52.03 3377.77 405.20 3107.28 12.53 0571.50 Pass 18800.00 3533.78 -5227.34 -13492.44 21327.00 3484.08 -4814.70 -1011700 52.03 3400.93 402.13 313248 12.72 0671.50 Pass 18850.00 3530.80 5186.48 -13521.08 21327.00 3484.08 -4814.70 -10117.00 5250 3424.63 399.07 3158.23 12.90 OSF1.50 Pass 18900.00 352798 5145.08 -13549.00 21327.00 3484.08 -4814.70 -10117.00 54.59 3448.14 395.87 3183.87 13.10 0571.50 Pass 18950.00 3526.20 5102.95 -13575.87 21327.00 3484.06 -4814.70 -10117.00 56.62 3471.11 392.46 3208.12 13.30 0571.50 Pass 19000.00 3525.28 5060.14 -13801.68 21327.00 3484.08 -4814.70 -10117.00 58.61 3493.55 389.04 3233.83 13.50 OSF1.50 Pass 19050.00 3524.87 5018.95 -13628.86 21327.00 3484.06 -4814.70 -10117.00 58.77 3515.92 385.92 325827 13.70 0071.50 Pass 19100.00 3524.45 -4973.76 -13652.05 2132700 3484.08 -481470 -10117.00 58.77 3538.85 382.90 328318 13.90 OSF1.50 Pass 19150.00 3524.04 -4930.57 -13677.23 2132700 3484.08 -4814.70 -10117.00 58.77 356234 380.16 3308.45 14.10 OSF1.50 Pass 1920000 3523.63 -488737 -13702.41 2132700 3484.08 -4814.70 -10117.00 58.77 3586.36 37749 3334.23 14.30 OSF1.50 Pass 19250.00 3523.22 -4844.18 -13727.59 21327.00 3484.08 -4814.70 -10117.00 58.77 3610.92 374.87 3360.51 14.50 OSF1.50 Pass 19300.00 3522.81 4800.81 -13752.47 21327.00 3484.08 -4814.70 -10117.00 58.91 3635.70 372.20 3387.03 14.71 0571.50 Pass 19350.00 3522.42 -4758.82 -13778.24 21327.00 3484.08 481470 -10117.00 61.45 3659.90 36939 3413.08 14.92 0571.50 Pass 19400.00 3522.06 -4712.23 -13798.85 21327.00 3484.08 -4814.70 -10117.00 82.98 3883.47 368.58 3438.49 15.14 OSF1.50 Pass 19450.00 3521.74 -4867.06 -13820.29 21327.00 3484.08 -4814.70 -10117.00 64.54 3706.42 363.79 3463.27 15.35 OSF1.50 Pass 19500.00 3521.50 -4821.35 -13840.54 21327.00 3484.08 -4814.70 -10117.00 66.10 3728.74 361.03 3487.40 15.57 0571.50 Pass 19550.00 3521.34 -4575.16 -13859.68 21327.00 3484.08 -4814.70 -10117.00 6705 3750.52 358.36 351093 15.78 0571.50 Pass 19600.00 3521.18 -452897 -13878.59 21327.00 3484.08 -4814.70 -10117.00 67.05 3772.61 35587 3534.65 15.99 OSF1.50 Pass 19650.00 3521.03 -4482.59 -13897.50 21327.00 348408 -4814.70 -10117.00 87.05 3795.24 353.64 3558.74 18.19 OSF1.50 Pass 19700.00 3520.87 4436.31 -13916.42 21327.00 3484.08 -4814.70 -10117.00 67.05 3818.39 351.48 3583.30 16.39 OS71.50 Pass 19750.00 3520.72 -4390.02 -13935.33 21327.00 3484.08 -4814.70 -10117.00 87.05 3842.05 349.39 3608.32 1660 OSF1.50 Pass 19800.00 352056 -4343.74 -13954.25 21327.00 3484.08 -4814.70 -10117.00 87.05 3866.21 347.38 3833.80 16.80 OSF1.50 Pass 19850.00 3520.41 -4297.45 -13973.18 21327.00 3484.08 -481470 -10117.00 67.05 389086 345.44 3659.72 17.01 OSF1.50 Pass 19900.00 3520.25 -4251.17 -13992.07 21327.00 3484.08 4814.70 -10117.00 87.05 3916.00 343.57 3686.07 17.22 OSF1.50 Pass 19950.00 3520.39 -4204.95 -14011.16 21327.00 3484.08 4814.70 -10117.00 67.05 3941.77 341.20 371340 17.48 OSF1.50 Pass 20000.00 3521.61 -4159.00 -14030.83 21327.00 348408 -4814.70 -10117.00 87.12 3968.55 338.60 374189 1771 OSF1.50 Pass 20050.00 3523.95 -4113.38 -14051.10 21327.00 3484.08 -4814.70 -10117.00 67.26 3998.32 336.09 3771.32 17.98 OSF1.50 Pass 20100.00 3527.32 -4068.02 -14071.91 21327.00 348408 -4814.70 -10117.00 67.37 4025.01 333.82 3801.50 18.23 0571.50 Pass 20150.00 3530.90 -4022.78 -14092.84 21327.00 3484.08 -4814.70 -10117.00 67.11 4054.22 332.25 383172 18.45 OSF1.50 Pass 20200.00 3534.06 -3977.78 -14114.45 21327.00 3484.08 -481470 -10117.00 65.35 4084.42 330.61 3863.00 18.69 OSF1.50 Pass 20250.00 3536.57 -3933.27 -14137.08 21327.00 3484.08 -4814.70 -10117.00 63.54 4115.91 328.87 3895.64 18.94 OSF1.50 Pass 20300.00 3538.43 -3889.28 -14180.74 21327.00 3484.08 -4814.70 -10117.00 61.65 4148.64 327.22 3929.45 19.19 OSF1.50 Pass 20350.00 3539.63 -3845.78 -14185.39 21327.00 3484.08 -4814.70 -10117.00 59.70 4182.55 325.67 396438 19.44 OSF1.50 Pass 20400.00 3540.18 -3802.86 -14211.04 21327.00 3484.08 -4814.70 -10117.00 57.67 4217.59 324.20 400039 19.70 OSF1.50 Pass 20450.00 3540.17 -3780.45 -14237.52 21327.00 3484.08 -4814.70 -10117.00 56.68 4253.61 322.88 4037.27 19.95 OSF1.50 Pass 20500.00 3540.09 -3718.10 -14264.10 21327.00 3484.08 -4814.70 -10117.00 56.68 4290.00 321.69 4074.43 20.20 0671.50 Pass Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-007\SP31-VV7\SP31-VV7(P8) 11/6/2014 2:01 PM Page 5 of 18 Trajectory:SP31-W7(P8)Vs.0113-03 Minimum Traveling Cylinder 60004 0 EOU-EOU Reference MO Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (ft) (ft) (ft) (ft) (5) (ft) (5) (') (ft) (ft) (ft) 20550.00 3540.01 -3675.75 -14290.69 21327.00 3484.08 -481470 -10117.0 56.68 4328.68 320.70 411174 20.44 OSF1.50 Pass 2060.00 3539.93 -3633.1 -14317.28 21327.00 3484.08 -4814.70 -10117.00 56.68 4363.58 319.75 414928 20.67 OSF1.50 Pass 20850.0 3539.86 -3591.06 -14343.88 21327.00 3484.08 -4814.70 -10117.00 56.68 440076 318.85 418705 20.91 OSF1.50 Pass 2070.0 3539.78 3548.72 -14370.45 21327.0 3484.08 -4814.70 -10117.00 5668 443820 318.00 422504 21.15 OSF1.50 Pass 20750.0 3539.69 -3508.41 -14397.09 21327.00 3484.08 -4814.70 -10117.0 56.26 4475.92 317.11 4263.35 21.39 OSF1.50 Pass 20800.0 3539.0 -3464.49 -14424.35 21327.0 3484.08 -4814.70 -10117.0 55.20 4514.35 318.15 430240 21.64 OSF1.50 Pass 20850.0 3539.48 -3423.05 -14452.33 21327.00 3484.08 -4814.70 -10117.0 54.14 4553.54 315.05 4342.32 21.91 OSF1.50 Pass 20900.0 3539.34 -338211 -14481.02 21327.0 3484.08 -4814.70 -10117.0 53.08 4593.48 314.0 438294 22.18 OSF1.50 Pass 20950.0 3539.18 3341.67 -14510.43 21327.0 3484.08 -4814.70 -10117.0 5200 4834.12 313.03 442422 22.45 OSF1.50 Pass 2100.0 3539.0 -3301.75 -14540.53 21327.0 3484.08 -481470 -10117.0 51.08 467513 312.13 4466.12 22.72 OSF1.50 Pass 21050.0 3538.81 3262.02 -14570.88 21327.0 3484.08 -4814.70 -10117.0 51.08 471708 311.57 4508.14 22.96 OSF1.50 Pass 2110.0 3538.62 -3222.28 -1401.24 21327.00 3484.08 -4814.70 -10117.0 51.08 4758.90 311.04 4550.30 23.21 OSF1.50 Pass 21150.0 3538.43 4182.55 -14631.59 21327.0 3484.08 -4814.70 -10117.0 51.08 480.87 310.54 4592.60 23.45 OSF1.50 Pass 21200.00 3538.23 -3142.82 -14681.94 21327.0 3484.08 -4814.70 -10117.0 51.08 4842.99 310.07 4635.03 23.70 OSF1.50 Pass 21250.0 3538.04 3103.09 -14892.30 21327.00 3484.08 -4814.70 -10117.00 51.08 4885.27 308.82 4677.59 23.94 0591.50 Pass End of results • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-W7\SP31-W7(P8) 11/6/2014 2:01 PM Page 6 of 18 Field: Nike4chu9 Well: $134146 Structure: Spy Island Borehole: S134W6 Slot SP34 Trajectory. 5134-166(P6) Client: Eni Petroleum Type: Del Plan Coordinate System: 54027 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.088375407 Grid Seale Factor. 0 999900148 Magnetic Declination: 18.977° Magnetic Declination Date: December 31,2014 Magnetic Model: BGGM 2013 Reference Point Noml(59 fasting Elevation Structure Une. Slot Una 6053610330(kUS) 511428.580(ftUS) 54.100(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Tralectory Error Model:ISCWSA01-D 95.000%Confidence 2.7965 sigma Survevina Prow While Drilling Description Part MD From(ft) MD To(ft) EOU Fraq(ft) Survey Tool Type Hole Wu(In) Casing Diameter(In) Borehole/Survey 1 0.000 41.000 1/100.000 SLB NSG*SSHOT-Depth Only-No Globe 16.000 13.375 5134-606/S134-V76(P6) 1 41.000 1050.000 1/100.000 SLB_NSG+SSHOT-No Globs 16.000 13.375 S)34-W6)S)34W6(P6) 1 1050.000 2550.000 1/100.000 SLB MWD*SAG-No Globs 18.000 13.375 5134-V16/SI34916(P6) 2 1050.000 2900 598 1/100.000 SLB ANDD*GMAG-No Globe 16.000 13.375 0134488/0134156(P6) 2 2900.598 4400.000 1/100.000 SLB MWD*SAG-No Globe 12.250 9.625 S)34-W8/S13416(P6) 3 2900.598 13640.701 1/100.000 SLB_MW0*GMAG-N0Globs 12.250 9.825 5134-606/6134446(P6) 3 13640.701 15140.000 1/100.000 SLB_MWD*SAG-No Globs 8.750 5.500 SI3481/13/S)3446(P6) 4 13640.701 23968.221 1/100.000 SLB MWD*GMAG-No Globe 8.750 5.500 0134-N6/6134-96(P6) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset IVO Offset NS Offset EW Nona Azim Ct-Cl Distance Separation Clearance OSF Controlling Rule Statue (ft) (ft) (6) (ft) (R) (II) (ft) (ft) (`I (ft) (ft) (ft) al local minima indicated. Results dared:Depth 13300.00ft<=MD<=2295059 ft Results dared:CSCt separation<<1800.00 ft Results Nghighted:Ct-Ct separation<=1320.00ft 3300.00 3493.70 -7234.63 -8630.95 12472.94 3408.10 5450.96 9201.14 343.06 874.64 391.54 1613.21 7.20 OSF1.50 Pass 3350.00 3497.18 -7246.70 -8679.35 12498.72 3410.05 5458.38 -9225.51 343.13 871.89 390.29 161129 7.21 OSF1.50 Pass 3400.00 3500.58 -7258.55 -872780 12524.55 3413.87 5485.51 -9250.04 344.11 669.55 389.01 1609.81 7.23 OSF1.50 Pass 3450.00 3503.35 -7269.02 -877661 12550.37 3417.57 5472.33 -9274.66 34586 868,42 387.72 1607.53 7.24 OSF1.50 Pass 3500.00 350544 -7277.93 -882576 12576.16 3421.14 -5478.84 -9299.37 347.85 88230 388.37 1604.31 7.25 OSF1.50 Pass 3550.00 3508.82 -7285.27 -8875.20 12801.93 3424.57 -5485.03 -9324.14 349.79 857.20 385.03 1800.10 7.25 OSF1.50 Pass 3800.00 3507.51 -7291.03 -8924.88 12627.67 3427.88 5490.91 -9348.98 351.77 851.12 383.84 1594.96 7.26 OSF1.50 Pass 3850.00 350749 -7295.19 -897468 12653.37 3431.05 -5496.46 -9373.88 353.80 844.08 382.26 1588.83 7.25 OSF1.50 Pass 3700.00 3506.78 -7297.76 -9024.61 12679.04 3434.09 5501.70 -9398.82 355,88 838.07 380.83 158177 7.25 OSF1.50 Pass 3750.00 3505.37 -7298.73 -9074.58 12704.88 3437.00 5506.62 -9423.79 358.01 827.09 379.40 1573.75 7.24 OSF1.50 Pass 3800.00 3503.54 -7298.74 -9124.55 12730.31 3439.78 5511.24 -9448.87 358.12 817.81 377.95 1585.44 7.23 OSF1.50 Pass 3850.00 3502.50 -7299.50 -917453 12758.23 3442.48 5515.59 -9474.29 356.59 809.92 376.44 158.561 7231 OSF1.50 Pass 3900.00 3502.70 -7300.88 -9224.51 12782.40 3445.03 5519.85 -9500.00 35708 803.33 374.89 1552.99 723 OSF1.50 Pass 3950.00 3503.91 -7301.15 -9274.49 12808.84 3447.47 5523.40 -9525.86 357.90 796.32 373.35 154701 7.24 OSF1.50 Pass 4000.00 3505.30 -7301.20 -932447 12834.98 3449.79 -552683 -9551.88 35795 789.75 371.80 1541.47 724 OSF1.50 Pass 4050.00 3500.00 -7301.28 -937445 12861.42 3451.97 5529.95 -9578.04 357.99 783.81 37025 1536.57 725 OSF1.50 Pass 4100.00 3508.08 -7301.31 -942443 12887.95 3454.02 5532.73 -960435 358.03 778.53 368.68 1532.35 7.28 OSF1.50 Pass 4150.00 3509.48 -7301.36 -947441 12916.48 3456.07 5535.35 -9632.86 358.07 773.89 36733 1528.59 726 OSF1.50 Pass 4200.00 351087 -7301.37 -9524.39 12966.23 3459.54 5539.68 -9882.12 358.59 789.48 368.86 152316 721 OSF1.50 Pass 4250.00 3512.32 -7300.13 -957435 13015.87 3463.00 -5544.00 -9731.45 0.58 783.83 370.48 1516.44 7.16 OSF1.50 Pass 4300.00 813.85 -7297.15 -9624.24 13065.29 348645 5548.29 -9780.56 2.55 756.47 37215 1507.96 7.10 OSF1.50 Pass 4350.00 3515.45 -7292.43 -967309 13114.43 3409.88 555257 -9829.40 4.51 74738 373.87 1497.73 7.03 OSF1.50 Pass 4400.00 3517.12 -728.8 -9723.54 13163.23 3473.28 5556.81 -9877.89 6.47 73660 375.61 148578 695 OSF1.50 Pass 4450.00 3518.83 -7277.80 -9772.83 13211.63 3476.66 5561.02 -9975.99 8.41 724.12 377.39 147212 6.87 OSF1.50 Pass 4500.00 820.59 -7267.91 -9821.81 13259.56 3480.00 5565.18 -9973.82 10.35 709.96 379.15 1456.78 6.78 OSF1.50 Pass 4550.00 3522.39 -7256.53 -987046 13307.05 3483.32 5500.31 -10020.81 11.32 69436 380.96 148.98 6.69 OSF1.50 Pass 4600.00 352419 -7244.95 -9919.07 13354.47 3486.62 -5573.43 -10067.94 11.8 678.56 382.78 1422.96 6.59 OSF1.50 Pass 4650.00 825.99 -7233.37 -9967.68 13401.90 3489.93 -5577.56 -10115.07 11.40 682.75 384.65 1405.91 6.50 OSF1.50 Pass 4700.00 352779 -722179 -10016.29 13449.32 349324 5581.68 -10182.20 11.44 646.95 306.52 1388.86 6.41 OSF1.50 Pass 4750.00 352959 -7210.21 -10064.89 1349674 3496.55 5585.80 -10279.33 11.49 631.15 392.97 136877 6.24 OSF1.50 Pass 4800.00 3531.17 -7198.69 -10113.52 13544.17 3499.86 558.93 -10256.46 11.61 615.40 39460 1351.93 6.16 OSF1.50 Pass 4850.00 3531.92 -7187.35 -10162.21 13591.63 3503.17 5594.05 -10303.62 11.78 599.82 396.22 1335.26 6.07 OSF1.50 Pass 4900.00 3531.84 -7176.12 -1021093 1388.07 3506.48 -5598.18 -10350.76 12.32 584.33 39782 1318.70 5.99 OSF1.50 Pass 4950.00 3531.34 -7164.79 -10259.63 13686.44 3509.78 5602.30 -10397.84 12.45 568.74 398.98 130235 5.91 OSF1.50 Pass 5000.00 3530.84 -7153.46 -10308.33 13722.68 3512.31 -5605.41 -1043386 12.56 553.25 39832 1287.29 5.86 OSF1.50 Pass 5050.00 353034 -7142.14 -10357.03 1374562 3513.87 5607.06 -10456.69 12.63 538.40 39567 1274.21 5.85 OSF1.50 Pass 5100.00 829.84 -7130.81 -10405.72 13766.80 3515.42 5808.35 -10479.77 12.69 524.32 392.89 1261.98 5.83 OSF1.50 Pass 5150.00 3529.34 -7119.48 -1045442 13792.19 3518,94 5609.28 -10503.10 12.78 511.03 39000 1250.62_Ia OSF1.50 Pass 5200.00 3528.84 -7108.15 -10503.12 1815.79 3518.44 5609.84 -10526.64 12.83 498.54 87.00 1240.131 5821 OSF1.50 Pass 525000 3528.34 -7096.82 -10551.81 13839.59 3519.91 561000 -10550.40 1289 486.85 383.90 1230.51 562 OSF1.50 Pass 5300.00 3527.84 -708.50 -10620.51 13863.59 3521.8 5809.77 -10574.8 1296 475.97 380.67 122179 5.83 OSF1.50 Pass 5350.00 3527.41 -7074.10 -10649.19 13887.75 3522.78 5608.13 -10598.46 13.31 465.85 377.27 121392 5.84 OSF1.50 Pass 5400.00 3527.50 -708217 -10697.75 13912.05 3524.13 5808.09 -1062270 13.93 456.02 373.69 1276.48 5.86 OSF1.50 Pass 5450.00 3528.22 -7049.64 -10746.15 188.47 3525.47 5806.62 -10647.94 14.52 446.43 300.98 1199.36 5.88 OSF1.50 Pass 5500.00 829.56 -7036.54 -1079438 13961.01 3528.77 560473 -10671.47 15.08 437.08 366.19 119254 5.90 OSF1.50 Pass 5550.00 3531.53 -7022.85 -1084243 13985.66 3528.03 5602.41 -10695.98 15.63 427.97 382.28 1186.04 5.93 OSF1.50 Pass 5600.00 3534.10 -7008.59 -10890.29 14010.41 3529.25 559968 -10720.55 16.04 419.13 358.31 1179.85 5.96 OSF1.50 Pass 5650.00 3536.86 -699417 -10838.08 1403929 88.43 5596.47 -10745.19 18.03 410.96 354.39 1174.29 5.99 OSF1.50 Pass 5700.00 88.62 -697975 -10985.88 14060.31 3531.57 5592.83 -10769.92 16.02 403.85 350.36 1189.67 603 OSF1.50 Pass 5750.00 3542.37 -6965.8 -11033.67 14085.45 3532.67 5588.75 -10794.70 16.01 397.20 348.21 1165.98 6.07 OSF1.50 Pass 5800.00 3545.06 6950.69 -11061.40 14110.68 353372 5584.21 -10819.50 16.76 391.40 341.95 1163.02 6.12 OSF1.50 Pass 5850.00 3547.44 -6935.12 -11128.88 14135.96 3534.72 5579.23 -10844.28 17.93 385.49 337.55 1160.05 8.17 OSF1.50 Pass 5900.00 3549.49 6918.56 -11175.99 14161.28 358.87 5573.81 -1086897 19.11 379.42 333.06 1156.97 6.23 OSF1.50 Pass 5950.00 355125 6901.00 -1122277 14186.64 8858 5567.94 -10893.63 21.32 37317 328.46 1153.79 6.29 OSF1.50 Pass 6000.00 3552.74 6882.46 -11289.18 14212.05 3537.43 5581.62 -10918.23 21.53 368.75 323.79 1150.48 6.8 OSF1.50 Pass 6050.00 3554.04 -6863.23 -11315.32 14237.53 353824 5554.86 -10942.78 21.81 360.47 319.07 1147.34 641 OSF1.50 Pass 8100.00 3555.33 -6843.98 -11361.44 14283.12 358.99 5547.63 -10967.31 21.81 355.04 314.25 1145.13 649 OSF1.50 Pass 6150.00 3556.83 -682472 -11407.57 14288.79 3539.70 5539.94 -10991.80 21.81 350.49 309.37 1143.84 657 0011.50 Pass 6200.00 3557.92 -6805.47 -11453.70 14314.54 354035 5531.78 -11016.21 21.81 346.84 304.44 1143.49' 666 OSF1.50 Pass Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-W7\SP31-W7(P8) 11/6/2014 2:01 PM Page 7 of 18 Trajectory SP31-W7(P8)Vs.5134-896(P6) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Noah Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ff) (8) (ft) (ff) (6) (8) (6) (R) C) (R) (8) (6) 6250.00 3559.22 -6786.13 -11499.79 14340.35 3540.95 -552318 -11040.54 22.30 1343.98 299.40 114397 6.75 OSF1 50 Pass 6300.00 356065 -5765.97 -11545.52 1436818 3541.50 -551413 -11064.73 23.48 1341.14 294.31 1144.52 6.86 OSF1.50 Pass 6350.00 3562.22 -6744.83 -11590.80 1439204 3542.00 -550464 -11088.77 24.66 1338.11 289.13 114495 697 OSF1.50 Pass 6400.00 356394 -6722.72 -11835.81 1441791 354244 -5494.71 -11112.66 25.83 1334.90 283.92 1145.21 7.08 OSF1.50 Pass 5450.00 356576 -689964 -11679.93 14443.81 3542.82 -5484.34 -11136.38 26.99 133151 278.68 1145.33 7.19 OSF1.50 Pass 6500.00 3567.68 -6675.61 -11723.73 1448372 354315 -5473.55 -11159.94 28.15 1327.93 273.35 1145.30 7.31 OSF1.50 Pass 6550.00 3569.70 -6650.83 -11787.00 14495.66 3543.42 -5482.32 -11183.32 29.30 1324.18 287.97 1145.12 7.44 OSF1.50 Pass 8600.00 3571.82 -6624.71 -11809.70 14521.62 3543.64 5450.66 11206.52 30.44 132024 262.60 1144.77 7.57 OSF1.50 Pass 6650.00 357403 -659788 -1185183 14547.61 354380 -5435.57 -11229.52 31.58 1316.13 25718 7.71 OSF1 50 Pass 6700.(10 3578.30 -657051 -11893.82 1457364 354391 5426.05 -11252.34 31.63 1312.28 25171 7.85 05F1.50 Pass 6750.00 3578.46 -654303 -11935.33 14599.73 3543.96 541309 -11274.99 32.13 1309.20 246.18 1144. 8.01 OSF1.50 Pass 6600.00 357999 551490 -11976.63 1462586 354396 5399.70 -1129743 3308 130625 240.67 1145.39 8.18 OSF1.50 Pass 6850.00 3580.83 548606 -12017.47 14652.03 3543.89 5385.89 -1131965 34.05 1303.34 235.13 1146.18 835 OSF1.50 Pass 6900.00 3580.98 -645654 -1205782 14678.23 354377 -5371.66 -11341.65 35.02 1300.48 22958 1147.02 853 OSF1.50 Pass 6950.00 3580.81 -6428.69 -12097.94 14713.20 3543.54 5352.14 -1137066 3501 1298.06 22680 1146.45 8.62 OSF1.50 Pass 7000.00 3580.63 -639684 -1213805 14763.15 3543.19 -532416 -1141203 3500 1295.83 228.75 �(� 8 OSF1 50 Pass 7050.00 3580.45 -6367.00 -1217817 14813.10 3542.64 5296.17 -1145340 3499 1293.59 23071' 8 OSF1.50 Pass 7100.00 3580.27 -633715 -12218.28 1484257 84260 527957 -1147771 34.88 129170 226.36 1 8.60 OSF1.50 Pass 7150.00 3590.10 -630731 -12258.40 14888.96 3542.31 5284.18 -11498.27 3497 1 29 1 221.08 1142.91 8.80 OSF1.50 Pass 7200.00 3579.92 -627746 -12298.51 1489537 354194 5248.45 .11520.41 34. 215.84 114633 901 OSF1.50 Pass 7250.00 3579.74 -6247.61 -12338.62 14921.77 354149 5232.35 -11541.32 3495 1 1.4 210.71 7150.59 9.24 OSF1.50 Pass 7300.00 3579.56 521777 -12378.74 1494814 3540.96 -5215.89 -11561.92 34.93 1293.23 205.65 115572 9.48 OSF1.50 Pass 7350.00 3579.39 -6187.92 -1241885 1497447 3540.36 5199.09 -11582.18 3491 1295.89 200.68 116169 974 OSF1.50 Pass 7400.00 3579.21 -6158.07 -1245897 15000.73 353969 -5181.98 -11802.08 3489 1299.47 19582 1168.51 10.01 OSF1.50 Pass 7450.00 357887 512799 -12498.90 15026.94 3538.94 5164.52 -11621.62 8.69 1303.64 191.11 1175.82 10.29 OSF1.50 Pass 7500.00 357827 509754 -12538.56 15053.08 3538.11 -5146.78 -11640.80 3568 1308.26 188.54 1183.49 1058 OSF1.50 Paso 7550.00 3577.68 -606710 -12578.22 15079.09 3537.22 -5128.78 -1165956 3565 131378 18213 1191.95 10.88 OSF1.50 Pass 7e00.00 3577.08 5036.65 -12617.87 15101.93 3536.29 -5110.56 -11677.67 35.63 1320.19 177.90 120119 11.20 OSP1.50 P... 7650.06 3576.49 500621 -12857.53 15130.65 3535.33 -5092.12 -11695.76 35.61 1327.50 173.89 1211.17 11.52 OSF1.50 P... 7700.50 3575.90 -597576 -12897.19 15158.22 353433 5073.46 -11713.21 3558 138.69 158.19 1229.82 1275 OSF1.50 Pass 7750.00 3675.30 5945.32 -12738.85 15181.83 3533.31 -5054.62 -11730.23 35.56 134476 153.12 124227 13.27 05E1.50 Pass 7900.00 3574.71 -5814.87 -12776.50 15208.86 353227 5035.82 -11746.79 35.53 135469 11823 1255.46 13.81 05F1.50 Pass 780.00 87412 -5884.42 -12816.16 15231.91 3531.20 5016.47 -11782.80 8.51 1365.48 113.58 1269.35 14.37 OSF1.50 Pass 7900.00 3573.52 5853.98 -1285582 15256.75 3530.10 -4997.20 -11778.55 8.48 1377.13 139.17 1283.94 14.96 OSF1.50 Pass 7960.00 3572.88 -582352 -12895.48 15281.89 3528.99 -4977.82 -11793.73 35.57 1389.58 135.04 1299.15 15.56 OSF1.50 Pass 8000.00 3571.51 -5792.72 -12934.82 15307.43 3527.78 -4957.06 -11809.41 8.84 1402.41 131.53 131132_1ga OSF1.50 Pass 0050.00 3569.96 5761.83 -12974.11 15355.88 3525.51 -4918.42 -11838.20 3583 1415.49 133.17 1328 1601 OSF1.50 Pass 6100.00 3568.41 -5730.94 -13013.40 15387.88 352403 -4892.55 -11857.32 35.82 1428.77 131.33 1340.81 16.46 OSF1.50 Pass 8150.00 3566.86 5700.05 -1305269 1541500 352291 -4870.52 -11873.10 8.82 144274 128.89 1356.53 16.96 OSF1.50 Pass 8200.00 3565.31 -5669.16 -13091.98 15141.89 3521.92 -4848.45 -11888.42 35.83 1457.40 126.31 1372.78 17.46 OSF1.50 Pass 8250.00 3563.69 5637.96 -13131.01 15188.60 3521.06 -4826.30 -11903.32 37.09 1472.8 124.13 1389.19 17.95 OSF1.50 Pass 8300.00 3561.84 -5605.64 -13189.11 15495.31 3520.32 -4893.93 -11917.90 38.84 1486.61 122.16 1404.76 18.42 OSF1.50 Pass 8350.00 3559.73 5572.20 -13206.22 15522.02 3519.70 -4781.35 -11932.16 40.81 1500.09 121.37 1419.43 18.87 OSF1.50 Pass 8400.00 355737 -5537.66 -13242.29 15548.73 3519.20 -4758.57 -11948.10 42.41 1512.80 118.81 1433.18 18.28 OSF1.50 Pass 8450.00 3554.81 -5502.05 -13277.29 15575.44 3518.82 -4735.59 -11959.70 44.26 1524.73 117.53 1445.98 19.65 OSF1.50 Pass 8500.00 3552.12 -5485.39 -13311.19 15802.15 3518.56 -4712E1 -11972.97 46.13 158.89 116.50 1457.81 19.97 OSF1.50 Pass 8550.00 354931 5427.73 -13343.95 15628.85 3518.42 -4689.05 -11965.80 48.02 1546.26 115.77 1468.87 27.23 OSF1.50 Pass 8600.00 3546.39 5389.06 -13375.54 1565650 351840 -466555 -1199646 4992 1555.84 115.31 1478.55 20.44 05F1.50 Pass 8650.00 354334 5349.50 -1340593 15682.04 351848 -464197 -12010.63 51.82 156463 115.17 1487.44 21.58 OSF1.50 Pass 8700.00 3540.18 5309.02 -13435.10 15708.57 351868 -4618.22 -12022.46 53.56 1572.65 115.36 1495.34 21.06 OSF1.50 Pass 8750.00 8898 -5268.18 -13483.77 15735.01 3518.97 4594.8 -12)33.89 53.64 1580.78 118.32 1502.83 20.59 OSF1.50 Pass 8800.00 353378 -5227.34 -1349244 15781.30 351937 -457052 -1204493 53.72 1589.62 11760 1510.81 21.47 OSF1.50 Pass 9850.00 3530.60 -5186.48 -13521.08 15787.44 3519.86 -4546.64 -1255.55 54.19 159915 119.12 1519.33 20.33 OSF1.50 Pass 8900.00 3527.98 -5145.08 -13549.00 1581153 3520.46 -452286 -12185.81 56.00 1608.51 121.57 1527 OSF1.50 Pass 8950.00 3526.21 -5102.95 -1357587 15843.28 3521.26 -449515 -12077.11 57.75 1617.32 121.89 1535. OSF1.50 Pass 9000.00 3525.28 5080.14 -1360168 1589260 352264 -444946 -12195.63 59.46 1625.15 122.22 1543.26 20.13 OSF1.50 Pass 9050.00 3524.87 5016.95 -13626.86 1594206 3524.03 -4403.64 -12114.21 59.66 1632.26 123.26 1549.88 2005 OSF1.50 Pass 9100.00 3524.45 -4973.78 -1365205 15990.98 352539 -4358.33 -12132.58 59.72 1639.37 124.37 1558.05 18.95 OSF1.50 Pass 9150.00 3524.04 -4930.57 -13877.23 16035.70 3526.11 -4316.88 -12149.31 59.76 1846.57 126.13 156208 19.78 OSF1.50 Pass 9206.06 3523.63 -4887.37 -13702.41 16083.90 3526.21 -4272.12 -12167.24 59.78 1653.87 127.76 1568.29 19.59 OSF1.50 Pass 9250.00 3523.22 -4844.18 -13727.59 18133.36 3526.28 -4228.21 -12185.84 59.79 1681.18 129.37 1574.52 19.43 OSF1.50 Pass 9300.00 3522.81 -4800.81 -13752.47 16182.67 352635 -4180.25 -1224.06 6193 1686.13 130.78 1580.54 19.30 OSF1.50 Pass 9350.00 352242 -4756.82 -13776.24 16243.89 3526.43 -412382 -1222673 62.46 1673.82 131.59 1585.68 19.24 OSF1.50 Pass 9400.00 352206 -4712.23 -13798.85 16429.08 352692 -3955.22 -1230370 64.03 1675.88 135.47 1585.15 18.71 OSF1.50 Pass 9450.00 3521.74 -4667.06 -13820.29 18611.52 3527.91 -3795.90 -1239249 65.61 1872.59 150.27 157201 16.82 OSF1.50 Pass 9500.00 3521.50 -4821.8 -13840.54 16781.88 353076 -3651.43 -12488.20 67.23 166423 171.60 1549.42 14.64 OSF1.50 Pass 9550.00 3521.34 -4575.18 -13859.68 18951.74 3535.71 3519.51 -12590.19 68.35 1651.12 196.36 1519.90 12.68 OSF1.50 Pass 9600.00 3521.18 -4528.87 -13878.59 17004.92 353761 3478.78 -12624.30 68.43 163592 198.94 1502.89 12.40 OSF1.50 Pass 9650.00 3521.03 -4482.59 -13897.50 17053.61 353856 3441.30 -12855.70 68.48 1620.70 270.84 1486.53 1218 OSF1.50 Pass 9700.00 3520.87 -4436.31 -13916.42 17102.34 3538.48 -3404.12 -12686.90 68.49 1605.44 20227 1470.19 11.97 OSF1.50 Pass 9750.00 3520.72 -4380.02 -13935.33 17150.16 3537.62 3367.50 -12717.64 68.47 1590.16 203.76 145391 11.77 OSF1.50 Pass 9800.00 3527.56 -434374 -16954.25 17197.77 353672 3331.01 -12748.24 68.45 157488 205.20 1437.67 1157 OSF1.50 Pass 9850.00 3520.41 -4297.45 -13973.18 17245.37 3535.81 3294.59 -12776.84 68.42 1569.81 276.67 1421.42 11.38 OSF1.50 Pass 9900.00 3521.25 -425117 -1389207 17292.98 3531.91 3258.13 -12809.44 68.40 1544.33 25.13 1405.17 11.19 OSF1.50 Pass 9950.00 3520.39 -420495 -14011.16 17340.63 3534.00 3221.64 -1264007 6751 1528.23 20941 1369.21 11.01 OSF1.50 Pass 20000.00 3521.61 -4159.00 -1403083 17388.44 353309 3185.02 -1287080 66.29 151474 210.58 1373.95 10.64 OSF1.50 Pass 2050.00 3523.95 -1113.36 -14051.10 1748.38 3532.18 3145.31 -12901.62 65.06 1500.90 21179 1359.30 10.06 OSF1.50 Pass 27100.00 352732 -4068.02 -11071.91 1748442 353127 3111.53 -1293249 64.24 148767 213.07 1345.22 10.52 OSF1.50 Pass 21150.00 3530.90 -4022.76 -1409284 17534.10 3530.33 3073.48 -12984.44 63.90 1174.60 21495 1330.89 10.34 OSF1.50 Pass 27200.00 3534.06 3977.78 -14111.45 17808.03 352972 -301732 -13012.51 62.66 146176 22233 131313 9.91 OSF1.50 Pass 27250.00 88.57 -3933.27 -14137.08 17675.16 3530.29 -2967.08 -13057.03 61.50 1449.16 22626 1296.58 9.57 OSF1.50 Pass 20300.00 3538.43 3889.26 -14180.74 17723.75 353091 -2930.87 -13089.42 80.38 143746 229.76 1283.87 9.43 OSF1.50 Pass 2080.00 3539.63 3845.78 -14185.39 17772.61 3531.53 -2894.46 -13121.99 59.25 1428.85 231.8 1272.24 9.29 OSF1.50 Pass 20400.00 3540.18 -3802.86 -14211.04 17821.89 3532.15 -2857.87 -13154.71 58.12 1417.35 232.83 1281.72 9.17 OSF1.50 Pass 20450.00 3540.17 -3760.45 -14237.52 17870.95 353278 -2821.16 -13187.55 57.59 140881 231.42 1252.12 9.05 OSF1.50 Pass Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-067\SP31-067(P8) 11/6/2014 2:01 PM Page 8 of 18 Trajectory:5P31-W7(P8)V.5134-7 (P6) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference IVO Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separe8on Clearance OSF Controlling Rule Sbex (ft) ON (ft) (tt) (8) (8) (ft) (ft) (°) (ft) (ft) (ft) 20500.00 3540.09 -3718.10 -14264.10 17920.24 3533.40 -2784.43 -13220.40 57.62 1400.39 236.02 1242.63 8.94 OSF1.50 Pass 20550.00 354001 -3675.75 -14290.69 17989.52 353403 -2747.70 -13253.26 57.64 1391.97 237.67 1233.12 8.82 OSF1.50 Pass 20600.00 3539.93 -3633.41 -1431728 18018.80 3534.65 -2710.97 -13286.11 57.87 138355 239.31 1223.80 8.71 OSF1.50 Pass 20650.00 3539.86 -3591.06 -14343.86 1808809 353528 -2674.25 -13318.96 57.70 1375.13 240.98 1214.08 8.60 OSF1.50 Pass 20700.00 3539.78 -3548.72 -14370.45 18117.36 3535.91 -2637.52 -13351.81 57.73 1368.72 242.63 1204.56 8.48 OSF1.50 Pass 20750.00 3539.69 -3506.41 -14397.09 18166.86 353619 -2600.63 -13384.81 57.34 1358.37 244.32 1195.08 8.37 OSF1.50 Pass 20800.00 3539.60 -3464.49 -14424.35 1821627 3538.23 -2583.81 -13417.76 56.35 1350.72 245.94 1186.35 8.27 OSF1.50 Pass 20850.00 3539.48 -3423.05 -14452.33 18265.80 3536.28 -2526.89 -13450.79 55.35 1343.94 247.53 1178.51 8.18 OSF1.50 Pas 20900.00 3539.34 -3382.11 -14481.02 18315.45 3536.32 -2489.89 -13483.90 54.36 1338.02 249.11 1171.54 8.09 OSF1.50 Pass 20950.00 3539.18 3341.67 -14510.43 1836520 3536.36 -2452.82 -13517.07 53.37 1332.97 250.73 1185.41 8.01 OSF1.50 Pass 21000.00 3539.00 3301.75 -14540.53 18415.02 3536.41 -2415.70 -13550.29 52.53 1328.78 252.37 1160.13 7.93 OSF1.50 Pass 21050.00 3538.81 3262.02 -14570.88 18464.87 3536.45 -2378.55 -13583.53 52.54 1324.91 254.13 1155.09 7.85 OSF1.50 Pass 21100.00 3538.62 3722.28 -14601.24 18514.72 3536.49 -2341.40 -13616.77 52.56 1321.04 255.87 1150.05 7.77 OSF1.50 Pass 21150.00 3538.43 -3182.55 -1463159 18564.57 3536 54 2304.25 -13650.01 52.56 131716 257.64 1145.00 770 007150 Pass 21200.00 3538.23 -314282 -1466194 1881108 3535.59 -2269.58 -13881.02 52.57 131330 258.58 1140.5117 OSF1.50 Pass 21250.00 353804 -3103.09 -14692.30 18647.89 3536.84 -224196 -13705.36 5258 1309.80 257.19 1137.93 787 0541.50 Pass 21300.00 353785 -306336 -1472265 18854.06 3537.38 -2214.59 -13726.99 52.81 130681 255.66 1135.96 7.70 OSF1.50 Pass 21350.00 3537.60 -3023.64 -14753.03 18719.87 353813 -2187.24 -1375210 5250 1304.38 254.07 1134.59 773 0571.50 Pass 21400.00 3536.72 -298412 -14783.64 1876864 353934 -2149.80 -13783.33 5218 130258 255.56 1131.80 767 OSF1.50 Pass 21450.00 3535.06 -2944.85 -14814.55 18818.54 3540.58 -2111.50 -13815.28 51.88 1301.17 25732 1129.22 761 OSF1.50 Pass 21500.00 3532.63 -2905.87 -14845.76 18868.39 3541.81 -2073.23 -13847.21 51.54 130019 259.07 1127.06 7.56 0071.50 Pass 21550.00 3529.75 -2867.05 -14877.15 18918.22 3543.05 -2034.98 -13879.11 51.68 129946 260.82 1125.17 7.50 0571.50 Pass 21900.00 3526.87 -282824 -14908.53 18988.04 354428 -1996.73 -13911.02 51.86 1298.75 262.57 1123.29 745 OSF1.50 Pass 21650.00 3524.00 -278942 -14939.92 1901787 3545.52 -1958.48 -13942.92 52.04 1298.04 264.34 1121.41 739 OSF150 Pass . 21700.00 3521.12 -2750.61 -14971.30 19067.69 3546.75 -1920.23 -13974.83 52.22 129736 266.09 1119.55 007150 Pas 21729.25 351943 -272789 -14989.67 19095.92 354745 -1898.56 -13892.90 52.32 1298.96 268.91 1118.6 OSF1.50 Pas 21750.00 3518.26 -2711.74 -15002.63 19111.79 3547.80 -1886.34 -14003.04 52.79 1296.67 286.47 111861 OSF1.50 Pass 21890.00 3515.63 -2672.45 -15033.43 19150.11 3548.38 -1856.70 -14027.31 53.91 1295.68 265.44 1118.31 7.35 OSF1.50 Pass 21850.00 3513.28 -263263 -15063.59 1918848 354858 -1826.79 -14051.35 5498 129431 264.34 1117.68 7.37 0571.50 Pas 21900.00 3511.19 -2592.31 -1509308 19226.72 3548.41 -179676 -14075.03 56.03 1292.56 263.22 1118.67 7.39 OSF1.50 Pas 21950.00 350937 -2551.50 -15121.91 19264.99 354788 -1766.50 -14098.44 57.05 1290.42 262.12 1115.27 7.41 0571.50 Pas 22000.00 3507.76 -251020 -15150.04 1930327 3546.98 -1736.01 -14121.57 5807 1287.89 261.06 1113.44 743 OSF1.50 Pas 22050.00 3506.31 -2468.41 -1517746 19341.56 3545.72 -1705.31 -14144.41 59.07 128494 26003 1111.18 7.44 0571.50 Pass 22100.00 350502 -242620 -15204.24 1937984 3544.09 -167442 -14166.96 59.62 1281.66 259.07 110854 745 OSF1.50 Pas 22150.00 350375 -2383.92 -1523089 19429.81 3541.73 -163412 -14196.07 59.58 127847 260.87 110415 7.38 OSF1.50 Pas 22200.00 3502.49 -2341.63 -15257.54 1947950 3539.36 -159372 -1422525 5953 1275.28 262.68 1089.75 731 OSF1.50 Pas 22250.00 3501.22 -2299.35 -1528419 19529.39 3536.99 -155333 -14254.43 59.49 1272.09 26451 109534 7.24 OSF1.50 Pas 22300.00 349996 -225706 -1531084 1957928 353463 -151294 -14283.62 59.44 1288.90 266.33 1090.94 7.17 OSF1.50 Pas 2235000 3498.70 -221477 -15337.49 19629.16 353226 -147254 -14312.80 5939 1265.71 268.16 1088.53 OSF1.50 Pas 79. 22400.00 3497.43 -2172.49 -15364.15 19605 352969 -1432.15 -14341.98 59.19 1262.54 26998 10821 OSF1.50 Pas 2245000 349594 -2130.51 -15391.26 1971832 3528.17 -1400.26 -14364.84 58.22 1260.09 26927 108017 OSF1.50 Pas 22500.00 349416 -2088.98 -15419.05 19757.69 352685 -1368.08 -1438747 5725 1258.93 268.57 107948 7.06 OSF1.50 Pas 2255000 3492.15 -2047.86 -1544742 19807.89 3525.38 -1327.09 -1441607 56.79 1258.69 27023 1078.13 7.01 OSF1.50 Pas 22600.00 3490.11 -2006.80 -15475.88 19857.69 3523.92 -1266.11 -1444467 56.82 125855 272.01 1078.81 6.96 OSF1.50 Pas 22650.00 3488.07 -1965.74 -1550434 19907.68 352245 -1245.12 -1447326 56.85 1258.42 27388 107542 6.92 OSF1.50 Pas 2270000 3486.02 -192468 -1553280 19957.68 3520.98 -1204.14 -14501.86 56.87 1258.28 275.74 1074.05 6.87 OSF1.50 Pas 22750.00 3483.98 -1883.62 -1556126 20028.20 351877 -1146.56 -1454251 56.90 125791 28197 1069.52 6.71 OSF1.50 Pas 2280000 3481.94 -184257 -1558972 20113.92 351532 -1077.83 -14593.62 56.91 125624 29160 106144 8.48 OSF1.50 Pas 22600.00 347990 -1801.51 -15618.16 20193.40 351103 -101079 -1464648 56.88 1253.18 301.42 1051.81 6.26 0571.50 Pas 22900.00 3477.86 -1760.45 -15646.64 20285.06 350589 -945.17 -14701.29 56.81 1.97 350003 -881.00 -14758.10Z2g4886677 31149 104007.60 @6@003 OSF1.50 Pas 347581 -171039 -1587510 32179 OSF150 Pass 2295059 3475.79 -1718.90 -15675.44 20370.98 349996 -880.26 -14758.78 56.711 )4'1.b`ii 32192 1O). &811 OSF1.50 Pas End of results Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-W7\SP31-607(P8) 11/6/2014 2:01 PM Page 9 of 18 Field: Nikaechoq Weil: 5134-146 Structure: Spy/s/end Borehole: S(34-4611 Slot SP34 Trajectory: 5131-14SL1(P2) Client Eni Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08837540° Grid Seale Factor: 0999900148 Magnetic Declination: 18.97T Magnetic Declination Date: December 31,2014 Magnetic Model: BOOM 2013 Reference Point ymeiga Zulu limbs Struck.Una MILOS. 6053610.330(8US) 511426.580(SUS) 54.100(ft)MSL 0.000(ft)7 sigma) 0.000(ft)(1 sigma) TriWtav Error Madel:ISCWSAO 343 96.000%Confidence 2.7996 sigma J;a 0040.Woe Wh111 0.1119.9 Description Part MD From(It) MD To(R) EOU Freq(7T) Survey Tool Type Hole 910e(in) Casing Diameter(In) Borehole I Survey 1 0.000 41.000 1/100.000 SLB_NSG+SSHOT-Depen Only-No Global 16000 13.375 SI34-9.6/S1349.6(P4) 1 41.000 1250.000 1/100.000 SLB_NSG+SSHOT-No Globe 16000 13.375 5134-W6/51349.6(P4) 1 1250.000 2750.000 1/100.000 SLB_MWD+SAG-No Globe 16.000 13.375 5134-547/S13446(P4) 2 1250000 3093944 1/100.030 SLB_MW000MAG-No Globe 16.000 13.375 513486/5134006(P4) 2 3093.944 4500.000 1/100000 SLB MWD+SAG-No Globe 12.250 9625 S134-116/513486(P4) 3 3093944 15700.000 1/100.000 SLB_Mc4D+GMAG-No Globe 12.250 9.625 513486/513486(P4) 00 3 15700.000 16100. 0 1/100.000 SLB_MWD-INC_ONLY FILLER-No Globe 8.750 5.500 5134-W6L1/SI31-86L7(P2) 3 16100.000 17800.000 1/100.000 SLB_MVOD+SAG-No Globe 8.750 5.500 5134-8611/5131-86L1(P2) 4 16100.000 22357.489 1/100.000 SLB MWD+GMAC-No Globe 8.750 5.500 5134-W6L1/SI31-86L1(P2) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Acim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (9) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) All local minima indicated. Results filtered,Depth 13300.00 ft on MD<-22950.59 8 Results filtered'.Ct-Ct separation<c 1500.00 ft Results highlighted:Ct-Ct separation<e 1320.00ft 3300.00 3493.70 -7234.63 -863095 3210.37 3177.30 6822.11 -8772.25 309.78 538.74 32766 39x,'.76 241 OSF7.50 Warning 3350.00 349.18 -7246.70 -867935 325041 318562 6828.52 08810.89 310.45 537.82 326.90/ 3 8.�a 247 OSF1.50 Warning 3400.00 350058 -725855 -872780 329032 3193.87 6834.08 -8849.54 312.08 53765 326.06 3 99r 2.48 OSF1.50 Warning 3450.00 3503.35 -7269.02 -8776.61 3330.11 3202.07 4838.80 -8888.19 314.55 536.95 325.08 319.82 248 OSF1.50 Warning 3500.00 3505.44 -7277.93 -882576 3369.79 3210.20 6842.70 -8926.84 317.06 535.55 32391 31921 248 OSF1.50 Warning 3550.00 3506.82 -728527 -887520 3409.37 3218.26 6845.76 -8965.46 319.61 533.46 322.80 317.99 248 OSF1.50 Warning 3600.00 350751 -729103 -892486 3448.83 3226.25 6848.01 -9004.03 322.20 530.69 321.10 316.22 2.48 OSF1.50 Warning 3650.00 3507.49 -7295.19 -8974.68 3488.18 3234.18 4849.44 -904255 324.86 52726 31948 313.88 248 05F1.50 VWming 3700.00 3506.78 -729776 -9024.61 3527.42 324202 6850.06 -9081.00 327.56 523.17 31762 31102 247 OSF1.50 Naming 375000 3505.37 -7298.73 -907458 3568.56 3249.79 -6849.88 6119.35 330.32 518.45 315.63 30762 OSF1.50 Warning 380000 3503.54 -7298.74 -9124.55 3605.62 3257.49 6848.90 -9157.64 331.27 513.81 31345 OSF1.50 Warning 3850.00 3502.50 -728950 -9174.53 3644.76 3265.13 4847.12 -819588 330.78 311.011 OSF1.50 Warning 390000 3502.70 -7300.88 -8224.51 3683.96 327273 -684454 -923435 332.31 30828 249 OSF1.50 Warning 395000 3503.91 -7301.15 -9274.49 3723.26 3280.27 6841.15 -9272.77 334.03 305.18 30762 2.52 OSF1.50 Warning 400000 350530 -730120 -9324.47 376246 328772 6636.97 -9311.02 334.88 51287 30181 311.19 2.55 OSF1.50 Warning 405000 3506.69 -730126 -9374.45 3801.49 329607 683201 -9349 03 33575 51539 298.50 315.98 2.59 OSF1.50 Warning 4100.00 3508.08 -7301.31 -9424.43 384032 3302.30 6826.30 -9386.75 338.63 51905 294.90 32204 2.64 0511.50 Warning 4150.00 3509.48 -7301.36 -947441 3878.92 3309.40 4819.85 4424.14 33753 523.85 291.17 32932 270 OSF1.50 Warning 4200.00 3510.87 -7301.37 -9524.39 3917.28 331638 6812.68 -9481.15 338.92 529.75 28726 337.84 277 051150 Warning 4250.00 3512.32 -7300.13 -%74.35 395552 3323.26 -6804.78 -949795 34181 535.68 283.21 348.46 2.84 OSF1.50 Warning 4300.00 3513.85 -7297.15 -962424 3993.78 333005 6796.13 -9534.60 344.64 541.14 278.95 354.76 292 051150 Warning 4350.00 3515.45 -729243 -967399 403204 333676 6786.75 -957107 34741 546.11 274.59 362.84 299 051150 Warning 4400.00 3517.12 -72%98 -9723.54 4070.30 3343.37 6776.62 5607.37 350.12 550.57 27012 370.08 306 OSF1.50 Warning 4450.00 3518.83 -7277.80 -9772.83 4108.56 334989 -6765.76 5643.48 352.77 554.50 265.60 377.02 3.14 0517.50 Warning 4500.03 3520.59 -7267.91 -982181 4146.83 3356.31 6754.16 5679.38 355.36 557.87 20097 383.48 3.21 OSF1.50 Warning 4550.00 3522.39 -725653 -9670.46 4185.10 3362.63 -6741.84 -9715.05 35615 560.88 256.33 389.58 3.29 OSF1.50 Warning 4600.00 3524.19 -724495 -9919.07 4223.23 3368.83 6728.84 5750.36 357.55 584.78 25186 39659 3.38 OSF1.50 Warning 4650.00 3525.99 -723317 596788 426120 3374.90 4715.19 5785.27 358.15 569.75 24703 404.65 347 OSF1.50 Warning 4700.00 3527.79 -7221.79 -1001629 4298.97 3380.83 4700.93 -9819.73 358.75 57579 242.37 413.80 357 OSF1.50 Worming 4750.00 3529.59 -7210.21 -1006489 4336.52 3386.62 468606 -9853.72 359.35 58290 235.96 425.19 3.72 OSF1.50 Naming 4800.00 3531.17 -719889 -1011352 4373.78 339226 667064 5887.17 399.86 59107 230.11 43726 3.87 OSF1.50 Warning 4850.00 3631.92 -718736 -1016221 441065 339774 -6654.74 5919.98 359.90 600.29 224.17 450.44 4.03 OSF1.50 Warning 4900.00 3531.84 -7176.12 -10210.93 4447.11 3403.05 6638.39 5952.13 0.50 610.51 218.18 46495 4.21 OSF1.50 Warning 495000 3531.34 -716479 -15259.63 4483.22 340820 6621.59 -9983.67 1.20 62160 212.15 479.76 4.41 OSF1.50 Warning 5000.00 3530.84 -715346 -1030833 4518.98 3413.19 6604.35 -1001461 1.68 633.74 208.13 49692 4.63 OSF1.50 Warning 5050.00 3530.34 -7142.14 -1035703 4554.39 341804 6586.72 -1004493 2.53 646.92 200.13 513.09 4.87 OSF1.50 Warning 5100.00 3529.84 -7130.81 -10405.72 4589.42 3422.72 6568.72 -10074.61 3.16 861.10 194.18 531.24 5.13 OSF1.50 Pass 5150.00 3529.34 -7119.48 -10454.42 4624.05 342725 -6550.39 -1010364 3.76 676.26 188.29 550.33 5.41 OSF1.50 Pass 5200.00 3528.84 -7108.15 -10503.12 4658.26 343182 -653176 -1013200 4.33 692.39 182.49 570.33 5.72 OSF1.50 Pass 5250.00 %28.34 -708682 -10551.81 4892.05 343513 -651286 -1015969 488 70946 17678 591.20 6.05 OSF1.50 Pass 530000 3527.84 -7085.50 -10600.51 4725.40 3439.89 6493.73 -10186.70 5.39 72744 17118 612.91 6.41 OSF1.50 Pass 535000 352741 -7074.10 -10649.19 4756.33 341380 6474.37 -10213.05 6.39 74624 185.68 635.38 6.80 OSF1.50 Pass 5400.03 3527.50 -706217 -10897.75 4791.00 3447.58 4454.72 -10238.87 785 785.47 160.24 658.23 721 OSF1.50 Pass 5450.00 3528.22 -704984 -10746.15 4823.43 3451.23 6434.77 -10264.18 9.24 78504 154.95 681.33 7.85 OSF1.50 Pass 5500.00 3529.56 -703654 -10794.38 4855.62 345476 -6414.55 -10288.97 10.58 804.92 149.80 704.65 8.11 OSF1.50 Pass 555000 353153 -7022.85 -1064243 4887.55 3458.16 -6394.08 -10313.24 11.63 825.09 144.83 728.13 8.61 OSF1.50 Pass 5600.00 3534.10 -700859 -10890.29 4919.22 3461.44 6373.37 -10336.98 12.81 84553 140.03 751.77 9.12 0511.50 Pass 5850.00 3536.86 6994.17 -10938.08 4950.49 3464.58 -6352.55 -10360.09 1299 888.59 135.51 775.84 9.67 0511.50 Pass 570000 353962 -697975 -10985.88 498129 3467.58 6331.66 -1038253 13.16 888.39 131.17 800.53 10.24 OSF1.50 Pass 575000 3542.37 -696533 -11033.67 5011.61 347044 4310.75 -1040430 13.32 91091 127.02 825.82 10.85 0511.50 Pass 5800.00 354506 6950.69 -11061,40 5041.53 3473.18 -6289.78 -10425.46 14.11 933.93 123.06 851.49 11.48 OSF1.50 Pass 5850.00 3547.44 693512 -11128.86 5071.26 347580 -6268.61 -10446.17 15.23 958.78 11923 878.88 1215 OSF1.50 Pass 5900.00 3549.49 -691856 -11175.99 5100.85 347833 -6247.23 -10486.46 16.39 97937 115.58 90191 1263 OSF1.50 Pass 5950.00 3551.25 690100 -1122277 5130.29 348076 4225.64 -10486.34 17.59 1001.71 112.16 928.53 13.53 OSF1.50 Pass 6000.03 3552.74 -688246 -11269.18 5159.59 348309 6203.85 -10505.79 18.80 102378 10893 95075 1424 0511.50 Pass 6050.00 3554.04 6863.23 -11315.32 5188.88 348531 6181.93 -10524.78 19.18 1045.87 10599 974.80 1496 OSF150 Pass 6100.00 3555.33 684398 -11381.44 521735 3487.42 4160.04 -10543.18 19.32 1088.81 103.33 999.32 1588 OSFI.50 Pass 6150.00 3556.63 682472 -1140757 5249.54 3489.89 4135.17 -10563.47 19.48 109200 10193 1023.64 1625 OSF1.50 Pass Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-W7\SP31-W7(P8) 11/6/2014 2:01 PM Page 10 of 18 Trajectory SP31-W7(P8)Vs.5131-1A6L1(P2) • Minirnum Traveling Cylinder Allowable EOU-EOU Reference MD Reference ND Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azlm Ct-Ct Distance Separation Clearance OSF Controlling Rule Status Of) (11) lft) (fl) (8) (ft) (6) (5) () (ft) (ft) (B) 620000 3557.92 -680547 -1145370 15293.51 3492.75 -6101.08 -10591.08 1965 111558 103.45 1046.21 16.35 OSF1.50 Pass 8250.07 3559.22 -6786.13 -1149979 15337.53 3495.82 6066.95 -1061871 20.38 1139.09 104.98 1068.69 16.45 OSF1.50 Pass 6300.00 3560.65 -676597 -1154552 15381.97 349892 6032.50 -10848.61 21.86 1161.82 106.51 109041 16.54 OSF1.50 Pass 6350.00 356222 -6744.83 -1159080 15426.89 350206 -5997.67 -10674.81 23.31 1183.60 10805 1111.16 16.60 OSF1.50 Pass 6400.00 3563.94 -6722.72 -1163561 1547229 3505.22 -5962.48 -10703.31 24.73 120.41 10960 113093 16.65 OSF1.50 Pass 050.00 3565.76 -6699.0 -1167993 15518.13 3508.42 -55926.94 -10732.09 28.12 1224.24 111.20 1149.70 16.68 OSF1.50 Pass 6500.00 3567.68 -867561 -11723.73 1556439 3511.65 5891.07 -10781.13 27.49 1243.07 112.80 1167.46 16.69 OSF1.50 Pass 6550.00 3569.70 -6650.83 -11767.00 15611.06 3514.91 5354.50 -10780.43 2884 1260.90 11443 1184.21 OSF1.50 Pass 6605.05 3571.82 -6624.71 -11809.70 15658.11 3518.19 51997 818.42 -10830.18 1277.72 11608 1199 OSF1.50 Pass 9650.00 3574.03 -6597.88 -1185183 15702.20 352128 5754.24 -10847.64 31.50 1293.52 117.04 121509 16 4 OSF1.50 Pass 6700.00 357630 657051 -1189362 15726.71 352249 -576343 -10864.03 31.62 1309.32 114.28 1232.74 1736 OSF1.50 Pass 6750.00 3578.46 -654303 -1193533 15780.51 3523.93 3738.31 -10883.47 32.02 1325.50 112.66 1249.99 17.83 OSF1.50 Paw 8800.00 357999 -8514.90 -11976.63 15789.33 3525.74 5715.30 -10900.73 32.76 1341.60 110.83 1287.30 1834 OSF1.50 Pow 8360.03 3580.83 -648606 -1201747 1581797 3528.03 5692.21 -10917.52 33.55 136753 109.85 1284.02 18.76 OSF1.50 Paw 6900.00 3580.98 -645654 -1205782 1584638 3530.80 5669.11 -10937.82 3438 1373.30 106.98 1300.25 19.10 OSF1.50 Pass 6950.00 3580.81 -642669 -12097.91 1587270 3533.71 -564752 -10948.59 3452 1389.36 108.136 1316.37 19.34 OSF1.50 Paw 7000.00 3580.63 6396.84 -12138.05 15896.85 3536.23 -5627.49 -10961.61 3465 1406.19 109.42 1332.83 19.48 OSF1.50 Paw 7050.00 358045 -636700 -12178.17 15920.77 3538.48 560741 -1097465 3476 1423.79 112.82 1348.30 19.16 OSF1.50 Pass 7100.00 3580.27 6337.15 -12218.28 15944.44 3540.45 -558733 -10987.04 34.86 144214 116.40 1364.13 18.77 OSF1.50 Pass 7150.00 3580.10 6307.31 -12258.40 15967.86 3542.17 -5567.27 -10998.99 34.95 146123 120.42 1380.55 18.37 OSF1.50 Paw 7200.00 3579.92 -8277.46 -12298.51 15991.02 3543.63 5547.24 -1101051 35.03 1481.05 124.59 1397.58 17.99 OSF1.50 Pass 7250.00 3579.74 -624761 -12338.82 18013.89 354485 5527.27 -11021.59 35.09 1501.56 132.15 1413.05 17.19 OSF1.50 Pass 730000 3579.56 -621777 -12378.74 16036.48 3545.83 5507.38 -11032.25 35.15 1522.76 141.45 1428.06 16.28 OSF1.50 Paw 7350.00 3579.39 -818792 -12416.85 16058.77 3546.57 5487.59 -11042.49 35.19 1544.84 15038 1443.98 15.52 OSF1.50 Paw 7400.00 3579.21 -615807 -12458.97 16080.75 3547.10 -5467.92 -11052.30 35.23 1567.18 158.96 1169.79 14.89 OSF1.50 Pass 7450.00 378.87 -812799 -12498.90 16102.50 3547.40 -5448.34 -11061.73 35.89 1580.08 16708 1478.30 14.37 OSF1.50 Pass 7500.00 3578.27 -6097.51 -12538.56 1812403 3547.51 5428.80 -11070.80 35.91 161322 173.63 1497.06 14.02 OSF1.50 Pass 7550.00 3677.88 6067.10 -12578.22 16145.25 3547.41 5409.43 -11079.48 35.93 1838.98 18008 1516.51 19. OSF1.50 Pass 7600.00 357708 -6038.85 -12817.87 18166.16 3547.12 3690.23 -11087.74 35.0 188135 18638 1536OSF1.50 Paw 7690.00 3578.49 -8008.21 -12657.53 18202.78 3546.35 5356.46 -11101.87 35.94 1686.17 188.50 1560.09 1350 OSF1.50 Pass 7700.00 3575.90 -5975.76 -12687.19 16248.17 354543 -5316.43 -11118.61 35.95 1711.01 188.94 158465 1366 OSF1.50 Pass 7750.00 3575.30 -594532 -12736.85 18683.38 3534.90 -4937.13 -11333.32 35.91 1728.57 193.13 1599.411_1394 OSF1.50 Pass 7800.00 3574.71 591487 -1277850 16731.25 3533.56 -4898.28 -11381.27 35.90 1743.00 194.37 1613.01 13.53 OSF1.50 Pass 7850.0 3574.12 -588442 -1281616 16779.12 353222 -4859.44 -11389.21 36.88 175743 195655 1826.59 13.55 OSF1.50 Pass 7900.00 3573.52 -585398 -12855.82 16826.99 3505.88 -4820.59 -11417.15 36.87 1771.86 19699 1640.12 13.57 OSF1.50 Pass 7950.00 3572.88 -5823.52 -12895.16 16874.87 3529.54 -478174 -11445.10 36.95 1786.26 19838 1653.60 13.58 OSF1.50 Pass 8000.00 3571.51 -5792.72 -12934.82 16922.88 352820 -4742.78 -11473.12 36.23 1800.23 199.83 1666.60 13.59 OSF1.50 Pass 8050.00 3569.96 -576183 -12974.11 16970.92 3526.85 -4703.80 -11501.16 36.24 181408 201.34 1879.44 13.59 OSF1.50 Pass 8100.00 3568.41 -5730.94 -13013.40 17053.80 3524.26 -4638.89 -11550.02 36.26 1827.67 205.78 1690.08 13.39 OSF1.50 Pass 8150.00 38686 -5700.05 -13052.69 17139.93 3520.38 -456868 -11802.44 36.25 183995 210.95 1698.91 1315 OSF1.50 Pass 8200.00 3585.31 -5889.16 -13091.98 17188.48 3517.91 -4530.47 -11632.31 36.23 1851.89 212.72 1709.67 13.13 OSF1.50 Pass 8250.00 3563.69 -563796 -13131.01 17237.13 3515.44 -4492.21 -11682.24 37.47 1863.43 21452 1720.01 13.10 OSF1.50 Paw 8300.00 3561.84 -5605.64 -13169.11 17288.09 3512.94 -4453.69 -11692.37 39.21 1873.54 216.32 1728.93 13.08 OSF1.50 Pass 8350.00 3559.73 3572.20 -13208.22 17335.34 3510.43 -4414.95 -11722.87 40.96 188217 218.17 1736.32 13.01 OSF1.50 Paw 8400.00 3557.37 -553788 -13242.29 17384.83 3507.91 -4376.02 -11753.12 42.74 1889.30 220.04 1742.20 12.94 OSF1.50 Pass 8450.00 3554.81 -550205 -13277.29 17434.51 3505.38 -0336.94 -11783.69 44.57 1894.93 22196 1746.55 1287 OSF1.50 Paw 8500.00 3552.12 -5485.39 -13311.19 17493.99 350281 -4290.21 -11820.40 48.42 1698.93 22478 1748.68_1273 OSF1.50 Paw 855000 3549.31 -5427.73 -13343.95 1755523 350141 -4242.26 -11858.48 48.33 1901.12 227.66 1748.948 125: OSF1.50 Paw 8800.00 3546.39 -5389.08 -13375.54 17824.39 3501.31 -4188.39 -11901.84 50.30 1901.44 213.97 1758.39 13.40 OSF1.50 Paw 865000 3543.34 -5349.50 -13405.93 1768043 3502.05 -4145.03 -11937.34 52.28 1899.79 215.41 1755.77 13.30 OSF1.50 Paw 8700.00 3540.18 5309.02 -1343510 17730.19 3502.73 -4108.56 -11968.88 54.08 1896.61 21633 1751.98 13.22 OSF1.50 Paw 8750.00 3536.98 5268.18 -13483.77 17779.90 3503.41 -4068.11 -12000.38 54.19 1892.82 217.35 1747.51 13.13 OSF1.50 Paw 8900.00 363378 -522734 -1349244 17829.61 35009 -4029.67 -12031.90 54.31 188904 21837 1743.05 13.0 OSF1.50 Paw 8850.00 3530.60 -518648 -1352108 17879.32 350477 3991.23 -12063.41 54.76 188523 219.39 1738.56 1295 OSF1.50 Paw 8900.00 3627.98 5145.08 -13549.00 17928.99 3505.45 +3952.82 -12054.88 56.33 1880.54 220.36 1733.22 12.86 OSF1.50 Paw 895000 352620 -510295 -1357587 17978.57 3506.13 -391447 -12128.32 57.78 187459 22125 1726.88 12.77 OSF1.50 Paw 9030.05 362528 -5060.14 -13601.68 18028.03 350681 -387623 -12157.67 59.15 1887.39 222.14 1718.89 12.67 OSF1.50 Paw 9050.00 352487 -5016.95 -13626.86 18077.39 3507.48 3838.06 -12188.96 59.29 1368.48 223.11 1710.33 12.56 OSF1.50 Paw 9105.05 352445 -4973.76 -13362.05 16124.36 3508.15 -380173 -12218.72 59.32 1851.58 223.84 1701.94 12.47 OSF1.50 Paw 915500 352404 -4930.57 -13877.23 18172.29 3509.07 -3784.61 -12249.02 59.36 184376 224.69 1693.56 1237 OSF1.50 Paw 9200.05 362363 -488737 -13702.11 18221.88 351003 3726.36 -12360.23 59.40 1835.95 225.72 1685.06 1226 OSF1.50 Paw 9250.00 3523.22 -4844.18 -1372759 18271.03 3511.00 -3688.12 -1231144 59.44 1828.14 22681 1676.53 1215 OSF1.50 Paw 9305.03 322.81 -4800.81 -1375247 18320.34 351196 3849.93 -12342.61 60.80 1819.98 227.87 1667.66 12.0 OSF1.50 Paw 9350.00 3522.42 -4756.82 -1377624 1836943 3512.91 -3611.90 -12373.65 62.14 181058 228.88 1857.80 11.92 OSF1.50 Paw 9405.00 3522.06 -4712.23 -13798.85 18418.25 3513.88 3574.08 -12404.51 83.69 1799.90 229.85 1646.25 11.80 OSF1.50 Paw 9450.05 3521.74 -4867.06 -13820.29 18486.79 3514.81 -3536.49 -12435.19 69.21 1787.94 23083 1633.64 11.87 OSF1.50 Paw 9500.00 3521.50 -4621.35 -13840.54 18514.99 3515.74 -3499.15 -12465.67 66.73 1774.72 231.81 1619.77 11.54 OSF1.50 Paw 9550.05 3521.34 -4575.16 -13859.68 18582.87 3516.68 -348207 -12495.93 67.67 1780.34 232.80 1604.73 11.39 OSF1.50 Paw 9605.00 3521.18 -4528.87 -13878.59 18612.07 3517.64 3423.96 -12527.0 67.71 1745.72 233.93 1589.36 11.24 OSF1.50 Paw 9650.00 3521.03 482.59 -13897.50 18670.72 3519.50 -3378.69 -12564.28 6778 1730.92 235.97 1573.20 11.05 OSF1.50 Paw 9700.03 3520.87 -4436.31 -1391642 18728.26 3522.43 -3334.53 -12801.06 67.88 1715.82 237.87 1556.84 10.87 OSF1.50 Pass 9750.00 3520.72 -4390.02 -1393533 1877580 3525.24 3298.18 -12631.54 67.99 1700.81 23884 1540.97 10.73 OSF1.50 Paw 9800.00 3520.56 -4343.74 -1395425 18823.33 3528.05 3281.79 -12882.01 68.10 1685.39 238.85 1525.08 10.59 OSF1.50 Paw 9360.00 3520.41 -4297.45 -13973.16 18870.86 3530.86 -3225.41 -12692.48 6821 1670.19 240.92 1509.16 10.44 OSF1.50 Paw 9900.03 3520.25 -4251.17 -1399207 18918.40 3533.67 3189.04 -12722.85 68.32 1654.98 241.99 1493.25 10.30 OSF1.50 Paw 9950.00 3520.39 -420495 -1401116 18966.00 3536.49 -315261 -1275347 67.56 1639.96 24290 1477.62 10.17 OSF1.50 Paw 20003.03 3521.61 -415900 -14030.83 19013.85 3539.31 3116.00 -12784.14 66.49 1625.55 243.73 1462.66 10.05 OSF1.50 Paw 20050.00 3523.95 -4113.36 -14051.10 19061.91 3542.16 -3079.22 -12814.95 65.41 1611.79 24461 1448.30 9.93 OSF1.50 Paw 20100.00 3527.32 -4068.02 -14071.91 19118.28 354541 -3036.12 -12851.13 64.74 1598.58 246.47 1433.86 9.77 OSF1.50 Paw 20150.03 3530.90 -402276 -14052.84 19190.39 354846 -296148 -12898.08 6451 158493 250.38 1417.60 9.53 OSF1.50 Paw 20203.03 3534.06 X77.78 -14114.45 19258.04 3549.96 -2930.78 -12942.85 83.40 1571.33 253.36 1401.69 9.32 OSF1.50 Paw 20250.00 3536.57 -393327 -14137.08 19309.86 3550.41 -2892.22 -12977.46 62.28 1558.43 255.41 1387.75 9.19 OSF1.50 Paw 20300.03 3538.43 -3889.26 -14160.74 19358.42 3550.81 -285608 -13039.80 61.16 1546.62 256.55 1375.18 9.08 OSF1.50 Paw 20360.00 3539.63 -3845.78 -14185.39 19407.25 355122 -2819.75 -13042.52 60.02 1535.91 25774 1363.68 8.97 OSF1.50 Paw 20400.00 3540.18 -3802.86 -14211.04 19458.32 3551.62 -2783.24 -13075.31 58.88 1528.32 258.93 1353.29 8.88 OSF1.50 Paw Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-VV7\SP31-W7(P8) 11/6/2014 2:01 PM Page 11 of 18 Trajectory.SP31-W7(P8)Vs.5131-5,8L1(P2) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Nod Azim Ct-Ct Distance Separation Cleerence OSF Controling Rule Status (ft) (ft) (ft) (ft) (9) (8) (6) (ft) (-) (ft) (ft) (ft) 20450.00 354017 -3760.45 -14237.52 19505.57 3552.03 -2746.60 -13105.21 58.35 1517.69 260.17 1343.83 8.78 OSF1.50 Pass 20500.00 3540.09 -3718.10 -14264.10 19554.84 3552.44 -270994 -13141.12 58.37 1509.18 281.44 1334.48 8.69 OSF1.50 Pass 20550.00 3540.01 -3675.75 -14290.89 19604.11 3552.85 -2673.28 -13174.04 58.39 1500.68 262.74 1325.11 8.60 OSF1.50 Pens 20600.00 3539.93 -3633.41 -14317.28 19653.37 3553.25 -2636.62 -13208.95 58.41 1492.17 264.05 1315.73 8.51 OSF1.50 Pass 20650.00 3539.86 -3591.06 -14343.86 18702.61 3553.68 -2599.99 -13239.84 58.43 1483.67 265.36 1308.35 842 OSF1.50 Pass 20700.00 3539.78 -3548.72 -14370.45 19750.21 355306 -256494 •13271.81 58.45 1475.21 266.47 1297.16 8.34 OSF1.50 Pass 20750.00 3539.69 -3506.41 -14397.09 19799.50 3554.03 -2527.82 -1330450 58.06 1486.84 287.78 1267.91 8.25 OSF1.50 Paw 20800.00 3539.60 -3484.49 -14424.35 19846.91 3554.21 -2491.02 -13337.46 57.07 1459.17 269.08 1279.38 8.16 OSF1.50 Pass 20850.00 3539.48 -3423.05 -14452.33 19898.44 355438 -2454.12 -13370.51 56.08 1452.37 270.34 127173 8.09 OSF1.50 Pass 20900.00 353934 -338211 -14481.02 19946.09 3554.56 -2417.14 -1340363 55.10 1446.43 271.82 1264.94 8.02 OSF1.50 Pass 20950.00 3539.18 -3341.67 -14510.43 18997.83 3554.73 -2380.09 -13436.82 54.11 1441.36 272.92 1259.00 7.95 OSF1.50 Pass 21000.00 353990 -3301.75 -14540.53 20047.65 355491 -234298 -13470.08 53.28 1437.15 274.25 1253.91 7.89 05F1.50 Pass 21050.00 3538.81 -3282.02 -14570.88 20087.49 3555.08 -2305.86 -13503.31 53.29 1433.25 275.08 1249.06 7.83 OSF1.50 Pass 21100.00 3538.62 -3222.28 -14601.24 20147.34 3555.28 -226873 -13538.57 53.31 1429.38 277.12 1244.20 7.76 OSF1.50 Pass 21150.00 3538.43 -3182.55 -14631.59 20197.19 3555.43 -2231.80 -13569.83 53.32 1425.48 278.57 123934 7.70 OSF1.50 Pass 21200.00 3538.23 -3142.82 -14681.94 20243.55 3555.56 -2197.05 -1360075 53.34 1421.59 279.56 1234.81 7.65 OSF1.50 Pass 21250.00 353804 -3103.09 -1469230 20283.56 3555.27 -2167.09 -13627.26 53.33 141799 27975 1231.08 7.63 OSF1.50 Pew 21300.00 3537.85 -3063.36 -14722.85 2032380 3554.49 -2136.92 -13653.57 53.31 1414.74 279.96 1227.69 7.61 OSF1.50 Pass 21350.00 3537.80 -3023.64 -14753.03 20363.65 3563.24 -2108.58 -13879.68 5312 141186 280.19 1224.66 7.58 OSF1.50 Pass 21400.00 3536.72 -2984.12 -14783.84 20403.74 3551.50 -2076.01 -13705.57 52.67 1409.85 280.45 1222.28 7.57 OSF1.50 Pass 21450.00 3535.06 -2944.85 -14814.55 20443.85 3549.28 -2045.28 -13731.24 52.19 1408.19 28073 1220.83 7.55 OSF1.50 Pass 21500.00 3532.63 -2905.87 -14845.76 20485.94 3546.44 -2012.86 -1375794 51.67 1407.48 281.28 1219.57 7.53 OSF1.50 Pens 21550.00 3529.75 -2867.05 -14877.15 20535.94 354289 -1974.29 -13789.55 51.60 1407.14 282.78 121822 7.49 OSF1.50 Pass 21800.00 3528.87 -2828.24 -14908.53 20585.93 3539.34 -1935.73 -13821.17 51.57 140680 284.29 1216.86 7.45 OSF1.50 Paw 21850.00 3524.00 -2789.42 -14939.92 20635.92 3535.78 -1897.16 -13852.78 51.54 1406.46 285.83 1215.50 7.41 OSF1.50 Pass 21700.00 3521.12 -2750.81 -14971.30 20685.22 3532.28 -1859.13 -13883.95 51.52 140612 287.28 1214 7.37 OSF1.50 Pass 21729.25 3519.43 -2727.89 -14989.87 20706.33 3530.84 -1842.80 -13897.25 51.51 140602 287.11 1214.1 73 OSF1.50 Pass 21750.00 351828 -2711.74 -15002.83 20721.30 3529.87 -1831.17 -13906.63 51.92 1405.98 286.99 1214.24 7.37 OSF1.50 Pass 21800.00 3515.63 -2672.45 -15033.43 20757.39 3527.75 -1802.96 -13929.04 52.91 140565 288.64 121415 7.38 OSF1.50 Pass 21850.00 3513.28 -2832.83 -15083.59 20793.24 3525.92 -1774.71 -13951.03 53.90 1404.98 286.18 1213.79 7.39 OSF1.50 Pass 21900.00 3511.19 -2592.31 -15093.08 2082897 3524.35 -1746.32 -13972.67 54.88 140399 285.73 1213.09 7.40 OSF1.50 Pass 21950.00 350937 -2551.50 -15121.91 20864.70 3523.05 -1717.71 -13994.04 55.87 1402.67 285.30 121208 7.40 OSF1.50 Pass 22000.00 3507.76 -2510.20 -15150.04 20906.79 352180 -1683.77 •14018.89 58.88 1400.98 285.83 1210.13 738 OSF1.50 Pass 22050.00 3506.31 -2468.41 -15177.46 20858.73 352037 -1643.45 -14048.33 57.88 1398.47 286.98 1206.75 733 OSF1.50 Pass 22100.00 3505.02 -2428.20 -15204.24 21006.62 3518.94 -1803.17 •14077.74 58.45 1395.20 288.33 120257 7.28 OSF1.50 Pass 22150.00 3503.75 -2383.92 -15230.89 21056.50 3517.51 -1562.90 -14107.14 58.45 139178 289.88 1198.11 7.23 OSF1.50 Pass 22200.00 3502.49 -234183 -15257.54 21106.39 3516.08 -1522.83 -14136.54 58.44 1388.37 29145 1193.66 7.17 OSF1.50 Pass 22250.00 3501.22 -2299.35 -15284.19 21156.27 3514.65 -1482.36 -14185.95 58.43 1384.96 293.02 1169.20 7.11 OSF1.50 Pass 22300.00 3499.96 -2257.06 -15310.84 21206.15 351321 -1442.09 -14195.35 58.43 1381.54 294.59 1184.74 7.08 OSF1.50 Pass 2235000 3498.70 -2214.77 -15337.49 21243.03 3512.04 -1412.23 -14216.96 58.42 1378.35 29478 118143 7.04 OSF1.50 Pass 22400.00 3497.43 -2172.49 -15384.15 21279.10 3510.82 -1382.82 •14237.78 58.24 1375.67 294.87 1178.68 7.02 OSF1.50 Pass 22450.00 3495.94 -2130.51 -15391.26 21315.50 3508.91 -1352.93 -14258.49 57.27 11/77430 294.90 1177 7.0 OSF1.50 Pass 22500.00 3494.16 -2088.98 -15419.05 21352.26 3500.69 -1322.5!3 •14279.10 56.251 8 294.98 1176. 7.p1� OSF7.50 Pens 22550.00 349215 -2047.88 -15447.42 21394.95 3504.19 -1287.10 -14302.71 55.73 1374.51 29572 1116.96 6. OSF1.50 Pass 22000.00 3490.11 -2006.80 -15475.88 21451.28 350060 -1240.28 -14333.83 55.67 1375.49 297.83 1178.52 6.95 OSF1.50 Pass 22850.00 3488.07 -1985.74 -15504.34 21537.93 3495.88 -1189.07 -14382.97 55.62 1375.59 302.90 1173.24 6.83 OSF1.50 Pass 22700.00 3486.02 -1924.88 -15532.80 2182455 349238 -1099.18 44434.01 55.83 1374.35 308.08 1168.55 6.71 OSF1.50 Pens 22750.00 348398 -1883.62 -15561.28 21710.97 3490.11 -1030.80 -14488.81 55.68 1371.79 313.48 1182.39 8.58 OSF1.50 Pass 22600.00 3481.94 -184257 -15589.72 21797.04 3489.07 -964.10 -14541.20 55.79 1367.90 319.03 115481 6.45 OSF1.50 Pass 22690.00 3479.90 -1801.51 -15618.18 21885.49 3489.18 -897.11 -14598.94 55.95 1362.88 325.07 1145.56 8.31 OSF1.50 Pass 22900.00 3477.86 -1780.45 -15646.84 21956.92 3489.93 -844.19 -14648.91 56.11 135615 329.19 1136.28 6.20 OSF1.50 Pass 22950.00 3475.81 -1719.39 -15075.10 22006.39 3490.54 -807.73 -14680.33 56.22 134941 330.69 1128.54 6.14 OSF1.50 Pass 22960.59 3475.79 -1718.90 -15675.44 22006.97 3490.55 -807.30 -1468073 56.A misiliEragx 330.71�ib0 9 OSF1.50 Pass End of results • • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-W7\SP31-007(P8) 11/6/2014 2:01 PM Page 12 of 18 Field: Nikaitchug Well: OP17-02 Structure: O/iktok Point Borehole: OP17-02P51 Slot OP17 Trajectory: OP17-02P81 Client: PSI Type: Oaf Survey Coordinate System: NAD27 Alaska State Plane.Zone 04.US Feet North Reference: True Grid Convergence Angle: 0.12825768° Grid Seale Factor: 0999900314 Magnetic Declination: 21 399° Magnetic Decline on Date: November 01,2010 Magnetic Model: BGGM 2010 Reference Point 8000106 Eastlna Clevaeon Structure Unc. Slot Unc. 6036509 370(III1S) 516626 280(IfUS) 53.250(11)MSL 0.000(9)(1 sigma) 0.000(0)(1 agma) Tralectory Error Model'ISCWSAO 3-0 95.000:Confidence 2.7965 slgme 00urvevino Pro%As Drilled Description MD Front(H) MD To(fl( EOU Free Survey Tool Type Hole Sloe(In) Casing Diameter(n) Borehole/Survey 0.000 41.050 1/98.425 SLB GYRO-MWD-Depth Only-No Globe 16.000 13.375 0P17-02PB1/OP17-02P81 41.050 41.050 Act-Stns SLB GYRO-MVuD-Depth Only-No Globe 16.000 13.375 OP17-02PB1/OP17-02P81 41.050 1118.470 Act-Stns SLB GYRO-MWD-No Goba 16.000 13.375 OP17-02PB1/0P17-02P61 1118.470 2182.500 ActStns SLB_MWD+GMAG-No Globe 16.000 13.375 0P17-02PB7/OP17-02P61 2182.500 8441.850 Act-Ohms SLB_MVcD+GMAG-No Globa 12.250 9.625 0P17-02PB1/OP17-02PB1 8441.650 1&910.000 ActShs SLB MWO+GMAG-No Globe 8.500 8.500 OP17-02PB1/OP77-02PB7 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Aaim Ct-Ct Dlshna Separation Clearance OSF Controlling Rule Status (0) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (') (ft) (ft) (ft) All local minima indicated. Results hared:Depth 13300.00 ft<=MD e=22950.59 ft Results hared:CFCt separator no 150220 ft Results highlighted:Ct-Ct separation c=1320.00 ft 330000 3493.70 -7234.63 -863095 894000 349527 -806356 8504.42 88.26 83853 418. 3.05 OSF1.50 Warning 3350.00 3497.18 -724670 8879.35 8940.00 3495.27 -8063.56 -850442 68. 408.50 589. 3.10 OSF1.50 Warning 3373.69 3498.84 -725241 -8702.28 8940.00 349527 -806056 -850442 88. 831.9 404.45 582.18 113 OSF1.50 Warning 340000 3500.58 -7258.55 -8727.80 8940.00 349527 4063.56 -8504.42 67.18 835.44 399.83 58577 3.17 OSF1.50 Warning 345000 3603.35 -7289.02 -8776.61 8940.00 349527 -8063.56 -8501.42 88.98 839.90 390.78 57828 3.27 OSF1.50 Warming 350000 3505.41 -7277.93 -882576 8940.00 349527 -8063.56 -850442 70.89 848.88 38150 59143 3.38 OSF1.50 Wanting 355000 3506.82 -728527 8875.20 8940.00 349527 -8063.56 -850442 7290 86217 37235 610.88 3.52 OSF1.50 Warning 3800.00 3507.51 -7291.03 8924.86 8940.00 349527 43063.56 -850442 7501 879.61 383.47 634.26 3.88 OSF1.50 Warning 3650.00 3507.49 -7285.19 -897468 8940.00 349527 -806056 -850142 7723 900.93 355.12 661.18 3.87 OSF1.50 Warning 3700.00 3506.78 -7297.76 -902461 8940.00 349527 -8063.56 -850442 79.58 92583 34738 691.29 406 OSF1.50 Warning 3750.00 3505.37 -7298.73 -9074.58 8940.00 349527 -8063.56 -8504.42 8205 95401 340,37 724.19 4.28 OSF1.50 Warning 3800.00 3503.54 -7298.74 -912455 8940.00 3495.27 -8063.56 -850442 81.98 984.88 33403 758.11 4.50 OSF1.50 Warning 3850.00 350250 -7299.50 -917453 8940.00 349527 -8063.55 -850442 79.36 016.30 3213.15 790.72 4.73 OSF1.50 Warning 3900.00 3502.70 -7300.88 -9224.51 8940.00 349527 -806356 -850442 78.81 048.93 32278 831.00 496 OSF1.50 Warning 3950.00 3503.91 -730115 -9274.49 8940.00 3495.27 -8063.56 -850442 78.98 083.67 31802 888.95 521 OSF1.50 Pass 4000.00 3505.30 -7301.20 -932447 8940.00 349527 -8063.56 -8504.42 78.98 119.71 31381 907.85 545 OSF1.50 Pass 4050.00 3506.89 -7301.26 -937445 8940.00 3495.27 -8063.56 8504.42 78.98 15679 310.10 94746 570 OSF1.50 Paw 4100.00 3508.08 -730131 -9424.43 8940.00 349527 8063.56 8504.42 78.98 194.82 308.82 96773 595 OSF1.50 Pass 415000 3509.48 -730136 -947441 8940.00 3495.27 -8063.56 -850442 78.98 233.70 30395 1028.57 6.20 OSF1.50 Peso 4200.00 3510.87 -7301.37 -952439 8940.00 3495.27 -8063.56 8504.42 79.41 273.39 301.43 1069.98 646 OSF1.50 Pan 4250.00 3512.32 -730013 -9574.35 8940.00 319527 8063.56 4504.42 8116 31448 299.32 111254 6.71 OSF1.50 Pan 4300.00 3613.85 -7297.15 8E24.24 894000 3496.27 4063.56 8504.42 82.88 357.10 29757 1158.36 6.97 08F1.50 Pen 4350.00 351545 -7292.43 4873.99 894000 3495.27 -8083.56 4504.42 8455 401.04 298.13 1201.30 7.23 OSF1.50 Pan 440000 3517.12 -7235.98 -9723.54 8940.00 3495.27 -8063.56 -8504.42 86.21 448.15 294.97 1247.23 7.49 OSF1.50 Pass 445000 3518.83 -7277.80 -9772.83 894000 3495.27 0063.56 4504.42 87.81 492.28 294.01 1294.01 7.76 OSF1.50 Pass 4500.00 352059 -7287.91 -9821.81 8940.00 3495.27 -8063.56 -8504.42 89.33 53922 29324 1341.51 8.02 OSF1.50 Pass 4550.00 352239 -7258.53 -9870.48 8940.00 349527 8063.56 850442 90.04 588.85 292.82 1389.59 8.29 OSF1.50 Pass 4800.00 3524.19 -7244.95 891907 8940.00 349527 8063.56 850442 90.04 83468 292.08 1437.81 8.55 OSF1.50 Pass 4850.00 3525.99 -723337 3887.68 3540.00 3495.27 4063.56 4504.42 90.04 882.84 29157 1488.12 882 OSF1.50 Pass 4700.00 3527.79 -7221.79 -10018.29 8940.00 3495.27 -8063.56 -8504.42 90.04 730.71 291.13 1534.51 OSF1.50 Pass 4750.00 3529.59 -7210.21 -1008489 8940.00 3495.27 8063.56 -850442 90.04 77889 299.19 1577. OSF1.50 Pass 4800.00 3531.17 -7198.89 -10113.52 8940.00 349527 -8063.56 -8504.42 92.53 827.15 298.83 1825.87 33 OSF1.50 Pass 4350.00 3531.92 -7187.35 -10182.21 8940.00 3495.27 4053.56 -8504.42 95.92 87546 298.51 1874.42 9.59 OSF1.50 Pass 4900.00 3531.84 -7178.12 -1021093 8940.00 349527 -8063.56 -8504.42 99.69 923.81 298.22 172299 9.85 OSF1.50 Pass 4950.00 3531.34 -718479 -18259.63 8940.00 349527 8063.56 -8504.42 99.69 972.27 297.97 1771.63 10.15 OSF1.50 Pass 5930.00 3530.84 -7153.48 -10308.33 8940.00 3495.27 8063.56 8504.42 99.69 202079 29774 182032 10.38 OSF1.50 Pass 5050.00 353034 -7142.14 -10357.03 8940.00 3495.27 8063.56 -8504.42 9969 21769.39 297.54 186908 10.61 OSF1.50 Pass 5100.00 3529.84 -7130.81 -10405.72 8940.00 349527 8063.56 -8504.42 9969 2118.05 297.35 1917.88 10.87 OSF1.50 Pass 5150.00 3529.34 -7119.48 -10454.42 8940.00 3495.27 -8063.56 -8504.42 9969 2168.78 297.18 1968.74 11.12 OSF1.50 Pass 5200.00 3528.84 -7108.15 -10503.12 8940.00 349527 8063.56 -8504.42 99.69 2215.56 237.03 201564 11.38 OSF1.50 Pass 5250.00 3528.34 -7098.82 -1055181 8940.00 349527 -8083.58 -8504.42 99.69 2284.39 298.89 2064.58 11.63 06F1.50 Pass 5300.00 3527.84 -7085.50 -10800.51 8940.00 3495.27 8063.56 -8504.12 99.69 2313.28 298.77 2113.57 11.89 OSF1.50 Pass 5350.00 352741 -7074.10 -10&19.19 894000 3495.27 -8063.56 -8504.42 98.69 2362.22 298.84 2182.82 1214 OSF1.50 Pass 5400.00 3527.50 -7082.17 -10897.75 8940.00 3495.27 -8063.56 -8504.42 95.86 2411.33 298.50 2211.83 12.40 OSF1.50 Pass 5450.00 3528.22 -7049.81 -10748.15 8940.00 3495.27 -8063.56 -8504.42 9244 2480.58 298.38 2281.19 12.56 OSF1.50 Pass 5500.00 352956 -7038.54 -1079438 8940.00 3495.27 8063.56 -8504.42 8829 2509.95 298.23 2310.88 12.92 OSF1.50 Pass 5550.00 353153 -7022.85 -1084243 8940.00 3495.27 -8063.56 -8504.12 83.30 2559.43 298.11 2360.24 13.18 OSF1.50 Pass 5800.00 353410 -700859 -1089029 894000 3495.27 8063.56 -8504.42 78.83 2608.98 296.01 2409.88 13.43 OSF1.50 Pass 5850.00 3538.88 4994.17 -10938.08 8940.00 3495.27 4063.56 -8504.42 78.83 2858.57 295.94 2459.53 13.69 OSF1.50 Pass 5700.00 353962 8979.75 -1098588 894000 349527 4063.58 -8504.42 78.83 2708.17 295.87 2509.19 13.95 OSF1.50 Pass 5750.00 354237 8985.33 -11033.67 894000 3495.27 -8063.56 4504.42 7883 2757.79 295.90 2558.87 14.21 OSF1.50 Pan 5800.00 354506 -6950.69 -11081.40 894000 3495.27 -8083.56 -8504.42 79.51 2807.45 295.73 2808.59 14.46 OSF1.50 Pass 5850.00 354744 8935.12 -11128.86 894000 3495.27 -8063.56 -8504.42 80.54 285723 295.86 285843 14.72 OSF1.50 Pass 5900.00 3549.49 -6918.58 -11175.99 8940.00 3495.27 -8083.58 8504.42 81.05 2907.10 295.61 2708.34 14.98 OSF1.50 Peso 5950.00 3551.25 -690100 -11222.77 8940.00 349527 -8063.56 8504.42 79.68 2957.04 295.56 2758.33 15.24 OSF1.50 Pass 600000 3552.74 8882.48 -11269.18 8940.00 349527 -8063.56 8504.42 71.00 3007.02 295.53 2808.34 15.50 OSF1.50 Pass 8050.00 355404 4883.23 -11315.32 994000 349527 -8063.56 -8504.42 83.80 3057.02 295.50 2858.37 15.78 OSF1.50 Pass 610000 3555.33 8843.98 -11351.44 894000 3495.27 -8063.56 -8504.42 63.60 3107.02 29547 2908.39 18.02 OSF1.50 Pass 6150.00 3556.83 -6824.72 -11407.57 894000 349527 8063.56 -8504.42 63.80 315701 285.44 2958.42 18.27 OSF1.50 Pass 6200.00 3557.92 -6805.47 -11453.70 8940.00 3495.27 8063.56 -8504.42 63.80 3207.01 29542 3008.44 18.53 OSF1.50 Pass 6250.00 3559.22 -8788.13 -11499.79 8940.00 349527 406356 -8501.42 03.86 3257.01 29539 3058,47 16.79 OSF1.50 Pass Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-W7\SP31-W7(P8) 11/6/2014 2:01 PM Page 13 of 18 Trajectory:SP31-407(P8)Vs.OP17-02PB1 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (0) (8) (it) (5) ft) (6) (ft) (ft) (°) (8) (8) (ft) 630.0 350.85 -8785.97 -11545.52 8940.00 349527 4063.56 -8504.42 48.66 330700 295.37 3108.48 17.05 OSF1.50 Pass 8350.00 3562.22 4744.83 -11590.80 8940.00 3495.27 -8083.56 -8504.42 4210 335697 295.34 3158.47 17.31 OSF1.50 Pass 6400.00 3563.94 4722.72 -11835.81 8940.00 349527 -8063.56 -8504.42 40.20 3406.89 29534 3208.41 17.56 OSF1.50 Pass 6450.00 3565.76 -6699.64 -11679.83 894000 3495.27 -8063.58 -8504.42 39.39 345674 295.33 3258.27 17.82 OSF1.50 Pass 650.00 3567.88 6875.81 -11723.73 8940.00 349527 -8063.56 -8504.42 3937 3506.51 295.34 3308.04 18.08 OSF1.50 Pass 8550.00 3569.70 4650.63 -11767.00 8940.0 349527 -8083.56 -8504.42 39.74 3556.16 295.34 3357.70 18.33 OSF1.50 Pass 880.0 357182 6624.71 -11809.70 8940.0 3495.27 -8083.56 -8504.42 40.34 3605.69 295.38 3407.21 18.58 OSF1.50 Pass 840.0 3574.03 6597.88 -11851.83 8940.0 3495.27 -8063.56 -8504.42 41.09 385507 29539 3456.59 18.84 OSF1.50 Pass 670.0 3578.30 6570.51 -11893.82 8940.0 349527 -8063.56 -8504.42 41.16 3704.37 295.43 350586 1209 OSF1.50 Pass 8750.0 3578.46 454303 -11935.33 8940.0 3495.27 -8063.56 -8504.42 38.73 3753.67 29548 355513 19.34 OSF1.50 Pass 680.0 3579.99 -6514.90 -11976.63 8940.0 3495.27 -8063.56 -8504.42 35.07 3802.88 29555 3604.28 19.59 05F1.0 Pass 8850.0 350.83 6488.06 -12017.47 8940.00 349527 -8063.56 -8504.42 32.13 385192 295.63 3653.29 19.83 OSF1.50 Pass 690.0 3580.98 6456.54 -12057.82 8940.0 3495.27 -8063.56 -8504.42 29.85 3600.63 29574 370213 27.08 OSF1.50 Pass 6950.0 3580.81 6428.69 -12797.94 8940.0 3495.27 4063.56 -8504.42 29.85 3949.68 295.85 375090 20.32 OSF1.50 Pass 700.0 3580.63 -8396.84 -12138.05 8940.0 3495.27 4063.56 -8504.42 29.85 3998.56 295.98 3799.71 20.56 0571.50 Pass 7050.0 358045 -6367.0 -12178.17 894000 3495.27 -8063.56 -8504.42 29.85 404746 296.08 384854 20.81 OSF1.50 Pass 710.0 3580.27 6337.15 -1221828 8940.0 349527 -8063.56 450442 29.85 4098.39 298.19 389740 21.05 OSF1.50 Pass 7150.0 3580.10 4307.31 -12258.40 894000 3495.27 4063.56 -8504.42 29.85 4145.35 296.30 3946.28 21.29 OSF1.50 Pass 7200.0 3579.92 4277.46 -12298.51 8940.0 349527 -863.56 4504.42 29.85 4194.33 296.41 3995.19 21.54 OSF1.50 Pass 7250.0 3579.74 4247.61 -12338.62 8940.00 3495.27 -8063.56 -8504.42 29.85 4243.33 298.52 4044.12 21.78 OSF1.50 Pass 730.0 3579.56 4217.77 -12378.74 8940.0 349527 -8063.56 -8504.42 29.85 4292.36 298.63 403.08 22.02 OSF1.50 Pass 7350.0 3579.39 4187.92 -12418.85 8940.00 349527 -8063.56 -8504.42 29.85 4341.41 296.74 4142.0 22.27 OSF1.50 Pass 740.0 3579.21 4158.07 -12458.97 894000 349527 -8063.56 -8504.42 29.85 4390.48 296.84 4191.06 22.51 OSF1.50 Pass 7450.0 3578.87 -8127.99 -12498.90 8940.0 3495.27 -8063.56 -850442 28.94 4439.51 296.95 4240.02 22.75 OSF1.50 Pass 7500.0 3578.27 4097.54 -12538.56 894000 349527 -8063.58 4504.42 28.94 4488.47 297.08 4288.91 22.99 OSF1.50 Pass 7550.0 3577.68 407.10 -12578.22 8940.0 3495.27 -8063.56 -8504.42 28.94 453745 297.18 4337.81 23.23 OSF1.50 Pass 780.0 3577.08 4038.85 -12817.87 8940.0 3495.27 4063.56 -8504.42 28.94 4586.45 297.30 4388.73 23.48 OSF1.50 Pass 7650.0 3576.49 4006.21 -12857.53 8940.0 3495.27 -8063.56 -8504.42 28.94 4835.47 297.42 443568 23.72 OSF1.50 Pass 770.0 3575.90 -5975.76 -12897.19 8940.0 3495.27 -8063.56 4504.42 28.94 488451 297.54 448465 23.96 OSF1.50 Pass 7750.0 3575.30 -5945.32 -12736.85 8940.0 3495.27 -8063.56 -8504.42 28.94 4733.58 297.65 4533.84 24.20 OSF1.50 Pass 780.0 3574.71 -5914.87 -12778.50 8940.0 349527 -8063.56 -8504.42 28.94 478266 297.77 4582.65 24.44 OSF1.50 Pass 7850.0 3574.12 -5884.42 -12816.16 8940.00 349527 -8063.56 -8504.42 28.94 4831.76 297.88 4831.68 24.68 0571.50 Pass 790.0 3573.52 -5853.98 -12855.82 8940.00 349537 6063.56 -8504.42 2894 4880.88 297.99 4680.73 24.92 OSF1.50 Pass End of results Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-407\SP31-407\SP31-W7(P8) 11/6/2014 2:01 PM Page 14 of 18 Field: Nikeitchuq Well: OP17-02 Structure: Oliktok Pant Borehole: OP17-02 Slot OP17 Trajectory- OP17-02 Client ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12825768° Grid Scale Factor. 0.999900314 Magnetic Declination: 21.347° Magnetic Declination Date: December 07,2010 Magnetic Model: BGGM 2010 Reference Point N9. ii5a Egg gg Um= Structure Unc Slot line 6036509 370(ftUS) 516626.280(WS) 53.250(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Traleotory Error Model:ISCWSA03-D 95.000%Confidence 2.7995 sign Survevino Pro%As Drilled Description MD From(f9 MD To(ft) EOU Freq Survey Tool Type Hole Size(In) Casing Diameter On) Borehole 1 Survey 0.000 41.050 1/98.425 SLBGYRO-MWD-Depth Only-No Global 18.000 13.375 OP17-02PB1/0P17-02P81 41.050 41.050 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 13.375 0P17-02P6110P17-02P81 41.050 1116.470 ActStn. SLB GYRO-MVVD-No Global 16.000 13.375 0P17-02P61 10P17-02P91 1116.470 2182.500 Act-Stns SLB MVVD+GMAG-Na Global 16.000 13.375 0P17-02P61/0P17-02P61 2182.500 8441.850 Act-Stns SLB M110+GMAG-No Global 12.250 8.825 0P17-02P61/0P17-02P51 8441.650 9433.930 Act-Stns SLB MNO+GMAG-No Global 8.500 8.500 OP17-02P61/0P17-02PB1 9433.930 18200.000 Act-Stns SLB MWD+GMAG-No Global 8.750 5.500 0P17-02/OP17-02 Minimum Traveling Cylinder Albviable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (6) (ft) (ft) (0) (8) (5) (9) C) 16) (0) (1t) All local minima indicated. Results hired:Depth 13300.00 ft c MD sa 22950.59 ft Results hared:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation<e 1320.00 ft 330900 3493.70 -7234.63 5630.95 8200.00 352364 -0333.07 -7795.17 62.93 1380.58 333.07 1155.69 6.34 OSF1.50 Pass 3350.00 3497.18 -7246.70 -8679.35 8200.00 3523.64 -8333.07 -779517 6293 1400.95 328.36 117924 6.53 OSF1.50 Pass 3400.00 3500.58 -7258.55 5727.80 8200.00 352364 -8333.07 -7795.17 64.02 1423.00 323.92 1204.29 6.72 OSF/50 Pass 3450.03 3503.35 -728902 5776.61 8203.00 3523.64 -8333.07 -7795.17 66.16 1447.70 319.85 1231.75 6.93 OSF1.50 Pass 3500.00 3505.44 -7277.93 -882576 8200.00 352364 8333.07 -7795.17 68.69 1475.04 316.12 1261.63 714 OSF1.50 Pass 3550.00 3506.82 -7285.27 -8875.20 8210.00 3523.64 -8333.07 -7795.17 70.72 1504.87 31278 1293.71 7.36 OSF1.50 Pass 3800.00 3507.51 -7291.13 -892486 8200.00 3523.64 -5333.07 -7795.17 73.16 1536.98 309.79 1327.87 7.59 OSF1.50 Pass 3690.00 3507.49 -7295.19 -8974.68 8200.00 3523.64 -8333.07 -7795.17 75.72 1571.21 307.16 1363.69 7.83 OSF1.50 Pass 3700.00 3506.78 -7297.76 -9024.61 8200.00 3523.64 -8333.07 -7795.17 78.42 1607.38 304.83 1401.65 8.07 OSF1.50 Pass 3750.00 3505.37 -7298.73 -9074.58 8203.00 3523.64 -8333.07 -7795.17 81.28 1845.32 302.82 1440.97 8.32 OSF1.50 Pass 3800.00 3503.54 -7298.74 -9124.55 8200.00 3523.64 -8333.07 -7795.17 81.15 1684.48 301.03 1481.38 8.56 OSF1.50 Pass 3850.00 3502.50 -7299.50 -9174.53 820.00 3523.64 -8333.07 -7795.17 77.90 1723.75 299.37 1521.78 8.81 OSF1.50 Pass 3900.00 3502.70 -7300.88 -9224.51 8200.00 352364 -8333.07 -779517 76.76 1763.19 297.83 1562.29 9.06 OSF1.50 Pass 3950.03 3503.91 -7301.15 5274.49 8200.00 3523.84 4333.07 -7795.17 76.57 1803.78 296.49 1803.80 9.31 OSF1.50 Pass 4000.00 350530 -7301.20 -932447 8200.00 3523.64 -8333.07 -7795.17 76.57 184495 295.29 184.5.81 9.56 OSF1.50 Pass 4050.03 3506.69 -7301.26 -9374.45 8203.00 3523.84 -8333.07 -7795.17 78.57 1886.54 294.23 1688.14 9.81 OSF1.50 Pass 4100.00 3508.08 -7301.31 -9424.43 8200.00 3523.84 -8333.07 -7795.17 76.57 1928.54 293.27 1730.81 10.06 OSF1.50 Pass 4150.00 3509.48 -730136 -9474.41 8200.00 3523.64 -8333.07 -7795.17 76.57 1970.90 292.43 1773.77 10.31 OSF1.50 Pass 420000 3510.87 -7301.37 -9524.39 8203.00 352364 -8333.07 -7795.17 76.95 201365 291.69 1817.05 10.58 OSF1.50 Pass 4250.00 3512.32 -7300.13 -9574.35 5200.00 3523.64 -8333.07 -7795.17 78.50 2057.32 291.04 1881.19 10.81 OSF1.50 Pass 4300.00 3513.85 -7297.15 -0624.24 8203.00 3523.64 -8333.07 -7795.17 79.98 2102.07 290.51 1908.32 11.06 OSF1.50 Pass 4350.00 3515.45 -7292.43 -9673.99 8200.00 352364 -8333.07 -7795.17 81.35 2147.78 290.07 195234 11.32 OSF1.50 Pass 4400.00 3517.12 -7285.98 5723.54 8200.00 352364 -8333.07 -7795.17 82.64 2194.32 289.71 1999.15 11.57 OSF1.50 Pass 4450.00 3515.83 -7277.80 -977283 8200.00 3523.64 -8333.07 -7795.17 83.79 2241.60 289.40 2048.86 11.83 OSF1.50 Pass 4500.00 3520.59 -7267.91 -9821.81 8200.00 3523.64 -0333.07 -7795.17 84.72 2289.51 289.16 2094.75 12.00 OSF1.50 Pass 4550.00 3522.39 -7256.53 -8870.46 820.00 352364 -8333.07 -7795.17 85.06 2337.90 288.96 2143.29 12.36 OSF1.50 Pass 4800.00 3524.19 -7244.95 -9919.07 8200.00 352364 -8333.07 -7795.17 69.06 2386.41 288.78 2191.95 1262 OSF1.50 Pass 4650.00 3525.99 -7233.37 5867.68 8270.00 352364 -8333.07 •7795.17 85.06 2434.98 288.61 2240.85 12.88 OSF1.50 Pass 4700.00 3527.79 -7221.79 -1001629 827900 352364 -8333.07 -7795.17 85.06 2483.61 288.48 2269.39 1 OSF1.50 Pass 4750.00 3529.59 -7210.21 -10064.89 8270.00 3523.64 5333.07 -7795.17 85.06 2532.29 296.27 2332.881 1 OSF1.50 Pass 4800.00 3531.17 -719869 -10113.52 8200.00 352361 -8333.07 -7795.17 88.06 2581.01 296.16 238170 13.30 OSF1.50 Pass 4850.00 3531.92 -7187.35 -1016221 8200.00 352364 -8333.07 -7795.17 9213 2629.76 28806 2430.53 13.55 OSF1.50 Pass 4900.00 353184 -7178.12 -10210.93 8270.00 3523.64 -8333.07 -7795.17 96.49 2678.53 295.97 2479.38 13.80 OSF1.50 Pass 4950.00 3531.34 -716479 -10259.63 8270.00 3523.64 -8333.07 -7795.17 96.49 2727.36 295.89 2528.28 14.06 OSF1.50 Pass 5000.00 3530.84 -7153.46 -10308.33 8200.00 3523.64 -8333.07 -7795.17 96.49 2776.23 295.82 2577.22 14.31 03051.50 Pass 5050.00 3530.34 -7142.14 -10357.03 8270.00 3523.64 -8333.07 -7795.17 96.49 2825.15 295.75 2626.19 14.57 OSF1.50 Pass 5100.00 3529.84 -7130.81 -10405.72 8200.00 3523.64 -8333.07 -7795.17 96.49 2874.10 295.69 2875.20 14.82 OSF1.50 Pass 5150.00 3529.34 -7119.48 -10454.42 6900.00 3523.64 -8333.07 -7795.17 96.49 2923.09 29564 272424 15.07 OSF1.50 Pass 5200.00 3528.84 -7108.15 -1050112 8200.00 3523.64 -8333.07 -7795.17 96.49 2972.11 295.59 2773.31 15.33 OSF1.50 Pass 5250.00 3528.34 -7096.82 -10551.81 8200.00 3523.64 -8333.07 -7795.17 96.49 3021.15 295.54 2822.40 15.58 OSF1.50 Pass 5300.00 3527.84 -7065.50 -10600.51 8200.00 3523.64 -8333.07 -7795.17 96.49 307024 295.50 2871.53 15.83 OSF1.50 Pass 5350.00 3527.41 -7074.10 -10649.19 8200.00 3523.64 -8333.07 -7795.17 95.14 3119.37 295.45 2920.70 16.09 OSF1.50 Pass 5400.00 3527.50 -7062.17 -10697.75 8210.00 3523.64 -8333.07 -7795.17 91.79 3168.62 295.38 2970.02 16.35 OSF1.50 Pass 5450.00 3528.22 -7049.64 -10746.15 8200.00 3523.64 -8333.07 -7795.17 8767 3217.99 295.29 3019.48 16.60 OSF1.50 Pass 5500.00 3529.56 -7038.54 -1079438 8210.00 3523.64 -8333.07 -779517 82.74 3267.46 295.22 3088.99 16.86 OSF1.50 Pass 5550.00 3531.53 -7022.85 -10842.43 8200.00 3523.64 -8333.07 -7795.17 78.92 331701 295.15 3118.60 1712 OSF1.50 Pass 5800.00 3534.10 -7008.59 -1089029 8200.00 3523.64 -8333.07 -7795.17 71.83 3366.61 295.08 3168.28 17.38 OSF1.50 Pass 5650.00 3538.88 -6994.17 -10938.08 8200.00 3523.64 -8333.07 -7795.17 71.83 341824 295.04 3217.93 17.63 OSF1.50 Pass 5700.00 3539.82 -6979.75 -10985.88 8200.00 3523.64 -8333.07 -7795.17 71.83 3465.88 295.00 3287.61 17.89 OSF1.50 Pass 5750.00 3542.37 X65.33 -11033.67 8200.00 3523.64 -8333.07 -7795.17 71.83 3515.53 294.97 3317.29 18.15 OSF1.50 Pass 5800.00 3545.08 5950.69 -11081.40 8201.00 3523.84 -8333.07 -7795.17 71.54 358522 294.92 3387.02 18.40 OSF1.50 Pass 5850.00 3547.44 5935.12 -11128.86 8200.00 3523.64 -8333.07 -7795.17 70.39 361501 294.87 3416.88 18.66 OSF1.50 Pass 5900.00 3549.49 -6918.58 -11175.99 8200.00 3523.64 -8333.07 -7795.17 67.05 366489 294.84 3466.78 18.92 OSF1.50 Pass 5850.00 355125 -6901.00 -11222.77 8200.00 3523.64 -8333.07 -7795.17 5738 371484 294.79 3516.77 1918 OSF1.50 Pass 6000.00 355274 -6882.46 -11269.18 823.00 3523.64 8333.07 -7795.17 26.55 3764.82 29477 3586.77 1944 OSF1.50 Pass 6050.00 3554.04 -6863.23 -11315.32 8200.00 3523.64 -8333.07 -7795.17 13.03 381481 294.74 3616.79 1970 OSF1.50 Pass 6100.00 3555/3 -8843.98 -11361.44 8203.00 3523.64 -8333.07 -7795.17 13.03 386480 294.72 3666.81 19.96 OSF1.50 Pass 6150.00 3556.63 -6824.72 -11407.57 8200.00 3523.64 -8333.07 -7796.17 13.03 391480 294.69 3716.83 20.21 OSF1.50 Pass 6200.00 3557.92 5805.47 -11453.70 8200.00 3523.64 -8333.07 -7795.17 1103 3964.79 294.86 3766.85 20.47 OSF1.50 Pass 6250.00 3559.22 -6786.13 -11499.79 823.00 3523.64 -8333.07 -7795.17 87.43 401478 294.63 3816.87 20.73 OSF1.50 Pass Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-) 7\SP31-W7\SP31-W7(P8) 11/6/2014 2:01 PM Page 15 of 18 Trajectory:SP31-W7(P8)Vs.OP17-02 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference ND Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW North A2im Ct-Cf Distance Separation Clearance OSF Controlling Rule Status (7t) _ (5) (0) (ft) ft) (6) (ft) (6) (') (ft) (ft) (ft) 6300.00 3560.65 -6765.97 -11545.52 8200.00 3523.64 -8333.07 -7795.17 5909 4064.76 294.61 3868.87 20.99 OSF1.50 Pass 6350.00 356222 -6744.83 -11580.80 8200.00 3523.64 -833307 -7795.17 50.25 4114.71 294.58 3916.84 21.25 OSF1.50 Pass 6400.00 3563.94 -6722.72 -11635.61 8200.00 3523.64 -8333.07 -7795.17 4853 4164.59 29457 3966.75 21.51 OSF1.50 Pass 6450.00 3565.76 -680964 -11679.93 8200.00 3523.64 -8333.07 -7795.17 44.54 4214.41 294.55 4016.58 21.78 OSF1.50 Pass 6500.00 3567.68 -6675.61 -11723.73 8200.00 3523.64 -8333.07 -7795.17 43.88 4264.12 29454 4066.30 22.02 OSF1.50 Pass 6550.00 3569.70 -6650.63 -11767.00 8202.00 3523.64 -8333.07 -7795.17 43.43 4313.71 294.53 4115.92 22.28 OSF1.50 Pass 6600.00 3571.82 -6624.71 -11809.70 8200.00 3523.64 -8333.07 -7795.17 43.57 4363.17 294.53 4165.38 22.53 OSF1.50 Pecs 6650.00 3574.03 -6597.88 -11851.83 8200.00 3523.64 -8333.07 -7795.17 43.95 4412.47 294.53 4214.68 22.78 OSF1.50 Pass 6700.00 3576.30 -6570.51 -11893.62 8200.00 3523.84 -8333.07 -7795.17 43.99 4461.69 294.55 4283.89 23.04 OSF1.50 Pass 6750.00 3578.46 -654303 -11935.33 8200.00 3523.64 -8333.07 -7795.17 41.60 4510.89 294.57 4313.08 23.29 OSF1.50 Pass 6800.00 3579.99 -651490 -11976.63 8200.00 3523.64 -8333.07 -7795.17 37.95 4560.00 294.62 4382.18 23.54 OSF1.50 Pass 6850.00 3580.83 -6486.06 -12017.47 8200.00 3523.84 -8333.07 -7795.17 34.96 4608.96 294.67 4411.10 23.78 OSF1.50 Pecs 6900.00 358088 -6456.54 -12057.82 8200.00 3523.64 -8333.07 -7795.17 32.61 4657.77 294.74 4459.86 24.03 OSF1.50 Pass 6950.00 3580.81 -6428.69 -12097.94 8200.00 352364 -8333.07 -7795.17 32.61 4706.52 294.82 450858 24.27 OSF1.50 Pass 7000.00 358063 -6396.84 -12138.05 8200.00 3523.64 -8333.07 -7795.17 32.61 4755.29 294.90 4557.28 24.52 OSF1.50 Pass 7050.00 3680.45 -6367.00 -12178.17 8200.00 3523.64 -8333.07 -779517 32.61 4804.09 294.98 4608.03 24.76 OSF1.50 Pass 7100.00 3580.27 -6337.15 -12218.28 8200.00 3523.64 -8333.07 -7795.17 32.61 4852.92 295.06 4854.80 25.01 OSF1.50 Pecs 7150.00 3580.10 6307.31 -1225810 8200.00 3523.64 -8333.07 -779517 32.61 490176 295.14 470380 25.25 OSF1.50 Pass End of results Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-W7\SP31-007(P8) 11/6/2014 2:01 PM Page 16 of 18 Field: Nikeilchug Well: 0124-08 Structure: Oliktok Pont Borehole: 0124-08 Slot OP24 Trajectory: 0124-08 Client:: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane.Zone 04,US Fear North Reference: True Grid Convergence Angle: 0.12782172' Grid Scale Factor: 0 99990312 Magnetic Declination: 20.579° Magnetic Declination Date: April 24,2012 Magnetic Model: BGGM 2011 Reference Point 11.21191811 Ea Ins g Elevation Structure Lint Slot Unc. 6036479.380(%IS) 516569.890(ftUS) 52 20(ft)MSL 0.00(ft)(1 sigma) 0000(ft)(1 sign) Trajectory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Surveying Profs As Drilled Description MD From(ft) MO To(f0 EOU Freq Survey Tool Type Hate Sloe(In) Casing Diameter(In) Borehole l Survey 0000 40.000 1/98.425 SLB_GYRO-MWD-Dept Only-No Globe 18.000 13.375 0124-08/0124-08 40.000 40.000 AGSbts SLB GYRO-MWD-0epth Only-No Globe l 16.000 13.375 0124-08/0124-08 40000 718200 Act-Sins SLB GYRO-MWD-No Globe 16.000 13.375 0124-08/0124-08 718.200 2345.960 Act-Stns SLB MVID+GMAG-No Globe 18.000 13.375 012488/0124-08 2345.960 89500 ActStan SLB MWD+GMAC-No Globe 12.250 9.625 0124-08/0124-08 895090 18607260 Act-Stns SLB_MWD+GMAC-No Globe 8.750 5.500 0124-08/0124-08 18607.260 18670.000 AGSEll SLB BLIND+TREND-Nn Globe 8.750 5.500 0124-08/0124-08 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference N8 Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Stab. (5) (8) (9) (ft) (6) (8) (6) (6) (') (ft) (6) ON All 2.1 minima indicated. Results(bred.Depth 13300.00 ft 4=MD c 22950.59 ft Results(bred.Ct-Ct separation<e 1500.00 ft Results highlighted:Ct-Ct separation m 1320.006 3300.00 3493.70 -7234.63 -0630.95 18870.08 3431.64 5806.01 -8888.85 17062 1396.80 469.04 1081.41 4.52 OSF1.50 Warning 3350.00 3497.18 -7248.70 -8879.35 18670.00 3431.64 -8606.01 -8888.85 170.62 1376.92 466.98 1062.87 4.48 OSF1.50 Warning 3400.00 350058 -7258.55 -8727.80 18670.00 3431.64 -8606.01 -8888.85 171.34 135880 484.54 1046.33 4.44 OSF1.50 Warning 3450.00 3503.35 -7269.02 -8778.81 18670.00 3431.64 5806.01 5888.85 172.78 1343.60 461.72 1032.98 OSF1.50 Warning 3500.00 3505.44 -727793 -882576 1887000 3431.64 -8606.01 -8808.55 174.31 133162 458.48 10231 OSF1.50 Warning 3550.00 3506.82 -728527 -8875.20 1867000 3431.84 5806.01 588885 175.93 1322.94 454.84 1016.84 4.42 OSF1.50 Warning 380.0 350751 -729103 -892486 19670.00 343164 -8606.01 5888.85 177.64 131766 45084 1014.211 444 OSF1.50 Warning 3650.00 350749 -729519 -897468 18670.08 343164 5606.01 -888885 179.441 1315811 44649 101522 448 OSF1 50 Warning 3700.00 350.78 -729776 -9024.61 1867D.00 343164 -8006.01 -888865 18133 131742 44183 101991 4.53 05F1.50 Warning 3750.00 350.37 -7296.73 -9074.58 18670.00 3431.84 -8806.01 -8888.85 183.31 1322.46 438.96 1028.19 460 OSF1.50 Warning 3800.00 3503.54 -7298.74 5124.55 18670.00 3431.64 -8806.01 -8888.85 183.30 1330.28 431.87 103940 4.99 OSF1.50 Warning 3850.00 3502.50 -7299.50 -9174.53 18670.0 3431.64 -8806.01 -8888.85 181.62 1339.25 426.54 10191 4.78 OSF1.50 Warning 3900.0 3502.70 -7300.88 -9224.51 18670.00 343164 460.01 -8888.85 181.85 134947 421.00 106583 4.88 OSFI.50 Warning 3950.0 3503.91 -7301.15 -9274.49 18670.00 3431.64 -8606.01 -8888.85 182.64 1362.57 415.37 108268 5.0 OSF1.50 Warning 400.0 350.30 -7301.20 -9324.47 18670.00 3431.64 -806.01 -8888.85 18264 1377.57 408.99 1101.47 5.12 OSF1.50 Pass 4050.0 3506.69 -7301.26 -9374.45 18679.0 3431.64 -8606.01 -8888.85 182.64 139421 404.04 112189 5.26 OSFI.50 Pass 4100.00 3508.08 -7301.31 -942443 1867000 3431.84 -860601 -888885 182.64 1412.42 398.38 1143.89 5.40 OSF1.50 Pass 4150.0 3509.48 -7301.36 -9474.41 18670.0 343184 5906.01 -8888.85 182.84 1432.14 392.82 1167.34 5.56 OSF1.50 Pass 4200.00 3510.87 -7301.37 -9524.39 18670.00 343164 -8606.01 -888885 183.11 1453.37 387.33 1192.24 5.72 OSF1.50 Pass 420.0 3512.32 -730.13 -9574.35 186700 3431.64 5806.01 -8888.85 185.05 1477.07 382.0 1219.48 590 OSF1.50 Pass 430.0 3513.85 -7297.15 -862424 1867000 3431.64 -880601 -8888.85 186.99 1503.55 377.03 1249.34 6.0 OSF1.50 Pass 4350.0 3515.45 -7292.43 -9673.99 186700 3431.64 580.01 -8888.85 188.93 153263 372.31 1281.59 6.28 OSF1.50 Pass 440.0 3517.12 -7285.96 -9723.54 18670.00 3431.64 -860.01 -8888.85 19388 1564.13 387.90 1316.0 6.49 OSF1.50 Pass 4450.0 351883 -7277.80 -9772.83 18670.0 3431.64 -8806.01 -8888.85 19285 1597.86 363.82 135253 671 OSF1.50 Pass 450.0 3520.59 -7267.91 -8821.81 18670.0 3431.64 -8806.01 -8888.85 194.81 1633.66 360.07 1390.85 6.93 OSF1.50 Pass 4550.0 3522.39 -7256.53 -967046 188700 3431.64 -806.01 -888885 195.77 167119 356.64 1430.70 7.16 OSF1.50 Pass 4800.0 3524.19 -7244.95 5919.07 186700 3431.64 -880.01 588885 195.77 170.50 03.40 1471.20 7.39 OSF1.50 Pass 4850.0 3525.99 -723337 -9967.68 18670.0 3431.84 5806.01 -888885 195.77 1746.40 35035 151218 7.63 OSF1.50 Pass 470.0 352779 -7221.79 -1016.29 18670.0 3431.64 5806.01 -888885 195.77 1787.85 34746 155356 7.88 OSF1.50 Pass 4750.0 3529.59 -7210.21 -1004.89 186700 3431.64 506.01 -888885 195.77 1827.82 54.31 1568.99 7.88 OSF1.50 Pass 480.0 3531.17 -7198.99 -10113.52 186700 3431.64 -8606.01 4888.85 196.57 186823 51.82 1831.09 8.11 OSF1.50 Pass 4850.0 531.92 -718735 -10162.21 18670.0 343114 5806.01 -8888.85 197.68 190.95 349.45 1673.42 8.34 OSF1.50 Penn 490.0 531.84 -7176.12 -1021093 1867000 343184 4606.01 -8608.85 199.17 1950.01 34723 171598 8.58 OSF1.50 Pass 4950.0 531.34 -7164.79 -10259.63 18670.00 3431.64 406.01 -8888.85 199.17 1991.50 345.14 1758.90 881 OSF1.50 Pass 5000.0 353084 -7153.46 -1030833 18670.0 3431.64 -8806.01 5888.85 199.17 2033.38 343.17 180211 9.0 OSF1.50 Pass 5050.0 353034 -7142.14 -1035703 18670.0 3431.64 5806.01 -8888.85 199.17 2075.62 341.31 1845.82 9.29 OSF1.50 Pess 510.0 52984 -7130.81 -10405.72 18670.0 3431.64 5806.01 -8888.85 199.17 2118.20 339.55 1889.39 9.53 OSF1.50 Pass 5150.0 529.34 -7119.48 -10454.42 18670.00 3431.64 -860.01 -8888.85 199.17 2181.09 337.89 1933.42 9.77 OSF1.50 Pass 5200.0 3528.84 -710.15 -1050112 186700 3431.84 -806.01 -8888.85 199.17 2204.29 338.32 1977.88 10.01 OSF1.50 Pass 5250.00 528.34 -7098.82 -1051.81 18870.0 343164 480.01 -8888.85 199.17 2247.78 334.84 2022.17 10.26 OSF1.50 Pass 530.0 352784 -7085.50 -10600.51 1867000 3431.84 -8608.01 -8888.85 199.17 2291.50 33344 2066.87 10.50 OSF1.50 Pass 6350.00 527.41 -7074.10 -10649.19 18870.0 343184 -860.01 4888.85 198.97 2335.54 332.08 2111.83 10.74 OSF1.50 Pees 540.0 527.50 -7062.17 -10997.75 18870.0 3431.64 5806.01 -8888.85 196.41 238007 330.78 2157.27 1099 OSF1.50 Pass 5450.00 528.22 -704964 -10746.15 18870.0 3431.64 460.01 -8888.85 197.71 2425.11 329.48 2203.17 11.24 OSF1.50 Pass 5500.0 3529.56 -7036.54 -10794.5 18670.0 3431.64 -860.01 4888.85 196.88 2470.60 32833 224946 11.49 OSF1.50 Pass 5550.00 3531.53 -7022.85 -10842.43 18670.0 3431.64 -860.01 -8888.85 195.91 2518.51 327.23 229613 11.74 OSF1.50 Pass 560.0 534.10 -700859 -10080.29 18670.0 3431.64 -8606.01 -8888.85 195.06 2562.80 32623 2343.11 120 OSF1.50 Pess 5650.0 3536.86 -6994.17 -1038.08 18870.0 3431.64 460.01 -8888.85 195.06 2609.30 325.5 238021 1225 OSF1.50 Pass 57000 353962 -6979.75 -10985.88 18670.0 3431.64 -8026.01 -8888.85 195.06 2655.92 32452 243740 12.50 OSF1.50 Pass 575000 354237 5965.33 -11033.67 18670.0 3431.64 -80.01 -8880.85 195.06 2702.66 323.73 2484.99 12.75 OSF1.50 Pass 580.0 3545.06 -6950.99 -11081.40 19870.0 3431.64 460.01 -8888.85 196.42 2749.59 322.97 2532.15 13.0 OSF1.50 Pass 585000 3547.44 -693512 -11128.88 18870.0 3431.64 -880.01 -8888.85 198.64 279695 322.25 2580.01 13.25 OSF1.50 Pass 59000 549.49 -6918.56 -11175.99 18670.0 3431.84 460.01 -888885 20.96 284471 321.62 2028.21 13.50 OSF1.50 Pass 5950.0 3551.25 -60100 -11222.77 18670.0 3431.64 5608.01 -8888.85 20.37 2892.84 321.05 267674 13.75 OSF1.50 Pass 6000.0 355274 -6882.46 -11289.18 18870.0 3431.64 560.01 -8888.85 20602 294130 320.56 272555 14.0 OSF1.50 Pass 6050 DO 554.04 -686323 -1131532 18670.0 3431.64 5806.01 -8888.85 20.66 2989.98 320.11 277454 14.25 OSF1.50 Pass 610.0 555.33 -684398 -11361.44 1887000 343164 -8606.01 4888.85 206.66 3038.71 319.68 2823.57 14.51 OSF1.50 Pass 6150.0 556.63 582472 -11407.57 18670.0 3431.64 560.01 -8886.85 206.66 3087.48 319.27 2872.63 14.76 OSF1.50 Pass 820.0 557.92 -680547 -11453.70 18870.0 3431.64 -860.01 -8886.85 206.66 315.29 318.88 2921.71 15.01 OSF1.50 Pass 6250.0 3559.22 4786.13 -11499.79 18870.00 3431.64 -860.01 -8888.85 207.0 3185.18 318.50 2970.85 15.26 OSF1.50 Pess Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-997\SP31-997(P8) 11/6/2014 2:01 PM Page 17 of 18 Trajectory:SP31-W7(P8)Vs.0124-08 Minimum Traveling Cylinder Albxable EOU-EOU Reference MO Reference ND Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Asim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (n) (8) (8) (8) (R) (5) (8) (8) (°) (ft) (8) (8) 6300.00 3580.65 -6765.97 -11545.52 18870.00 3431.64 -8636.01 -8888,85 207.74 3234.23 318.16 3020.16 15.51 OSF1.50 Pass 6350.00 3562.22 -6744.83 -11590.80 18870.03 3431.64 6806.01 -8888.85 208.33 3283.53 317.86 3069.67 15.76 OSF1.50 Pass 8400.00 356394 -672272 -11635.61 1867000 3431.64 -8606.01 -8888.85 208.84 3333.01 317.81 3119.34 16.01 OSF1.50 Pass 6450.00 3565.76 6699.64 -11679.93 18870.00 343164 -8606.01 -8886.85 209.40 3382.65 317.39 3169.14 16.25 OSF1.50 Pass 6500.00 3567.68 -667561 -11723.73 18670.00 3431.64 -8608.01 -8888.85 209.61 3432.42 317.22 3219.03 16.50 OSF1.50 Pass 6550.00 3569.70 6650.63 -11767.00 1867000 343164 -8606.01 -8889.85 209.11 3482.28 317.07 3269.00 1675 OSF1.50 Pass 6800.00 3571.82 -662471 -11809.70 18670.00 343164 -8606.01 -8888.85 206.73 3532.22 318.98 3318.01 16.89 OSF1.50 Pass 6660.00 3574.03 6597.88 -11851.83 1867000 3431.64 -8606.01 -8888.85 195.98 3582.19 318.91 336905 1724 06F1.50 Pass 6700.00 3578.30 6570.51 -11893.82 1867000 3431.64 -8606.01 -8886.85 193.53 3632.19 316.85 3419.08 17.48 OSF1.50 Pass 6750.00 3578.46 -654303 -11935.33 18670.00 3431.64 -8606.01 6888.85 235.63 3682.18 316.80 3489.12 17.72 OSF1.50 Pass 6800.00 357999 6514.90 -11976.63 18670.00 3431.64 -860601 -8888.85 339.42 3732.18 31679 3519.14 17.96 OSF1.50 Pass 660.00 3580.83 -8488.06 -12017.47 18670.00 3431.64 6606.01 -8888.85 348.83 3782.18 318.80 3560.11 18.20 OSF1.50 Pass 6800.00 3580.98 6456.54 -12057.82 18670.00 3431.64 660601 -8888.85 352.39 3832.09 318.85 3619.02 18.44 OSF1.50 Pass 6950.00 3580.81 6426.69 -12087.94 18670.00 3431.64 660601 -8888.85 35239 3882.00 316.91 3688.90 18.67 OSF1.50 Pass 7000.00 3580.63 6396.84 -12138.05 18670.00 3431.84 6606.01 -8888.85 352.39 393191 316.97 3718.77 18.91 05F1.50 Pass 7050.00 3580.45 636700 -12178.17 16870.00 3431.64 -8606.01 -8888.85 35239 398162 317.03 3788.68 19.14 OSF1.50 Peso 7100.00 3680.27 6337.15 -1221828 18670.00 3431.64 -8606.01 -8888.85 352.39 4031.74 317.08 3818.54 19.38 OSF1.50 Pass 7150.00 3580.10 -6307.31 -12258.40 18870.00 3431.64 -8808.01 -8888.85 352.39 4081.65 317.14 3868.43 19.81 OSF1.50 Pass 7200.00 3579.92 -6277.48 -12298.51 18670.00 3431.64 -8606.01 -8888.65 352.39 4131.57 317.19 3918.32 1985 OSF1.50 Pass 7250.00 3579.74 6247.81 -12338.62 18870.00 3431.64 -8606.01 -8888.85 352.39 4181.49 317.24 3888.22 20.09 OSF1.50 Pass 7300.00 357956 6217.77 -12378.74 18870.00 3431.64 -8606.01 -8888.85 352.39 4231.42 317.29 4018.11 20.32 OSF1.50 Pass 7350.00 3579.39 -8187.92 -12418.65 18670.00 3431.64 -8606.01 -8888.85 352.39 4281.34 317.33 4088.01 20.56 OSF1.50 Pass 7400.00 3579.21 6158.07 -12458.97 18870.00 3431.64 -8806.01 -8888.85 352.39 4331.27 317.38 4117.92 20.79 OSF1.50 Pass 7450.00 3578.87 612799 -12498.90 18670.00 3431.64 -8606.01 6889.65 356.96 4381.18 317.43 4187.80 21.03 OSF1.50 Pass 7500.00 3578.27 -809754 -12538.56 18670.00 3431.64 -8606.01 -8888.85 358.96 4431.06 317.50 4217.64 21.26 OSF1.50 Pass 7550.00 3577.68 -606710 -12578.22 18670.00 3431.64 -8606.01 6888.85 356.96 4480.94 317.57 4267.48 21.50 OSF1.50 Pass 7600.00 3577.08 -603865 -12817.87 18670.00 3431.64 -8606.01 -8888.85 356.96 4530.82 317.63 4317.33 21.73 OSF1.50 Pass 7650.00 3576.49 6006.21 -12657.53 18670.00 3431.64 -8606.01 -8888.85 35696 4580.71 317.69 4367.18 21.96 OSF1.50 Pass 7700.00 3575.90 -597576 -12697.19 18670.00 3431.64 -860.01 -8888.85 356.96 4630.60 31775 4417.04 22.20 OSF1.50 Pass 7750.00 3575.30 -5945.32 -12736.85 18670.00 3431.64 6606.01 -8888.85 356.96 4680.49 317.81 4466.90 22.43 OSF1.50 Pass 7800.00 3574.71 -5914.87 -12776.50 18670.00 3431.64 -8606.01 -8888.85 356.96 4730.38 317.87 4516.76 22.66 OSF1.50 Pass 7850.00 3574.12 -5884.42 -12816.16 18670.00 3431.64 -8606.01 1888.85 356.96 4780.28 317.92 4586.62 22.90 OSF1.50 Pass 7900.00 3573.52 -585398 -12855.82 18870.00 3431.64 -860601 -8888.85 35696 4830.18 317.98 4616.49 23.13 OSF1.50 Pass 7950.00 3572.88 -5823.52 -1289546 18670.00 3431.64 660601 -8688.85 355.05 488008 318.03 4866.36 23.37 OSF1.50 Pass End of results • • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP31-W7\SP31-W7\SP31-W7(P8) 11/6/2014 2:01 PM Page 18 of 18 Attachment 9 Casing Design Program File: SP31-W7 (P8) ° Date: November 11, 2014 Page: 1 MINIMUM SAFETY FACTORS(13 3/8"Surface Casing) Depth(MD) Minimum Safety Factor(Abs) (usit) OD/Weight/Grade Connection Burst Collapse Axial Triaxial 1 0 13 3/8",68.000 ppf,L-80 N/A 2.50 B5 +100.00 Cl 8.08 B5 3.15 65 2 10 2.51 B5 +100.00 Cl 8.13 B5 3.1665 3 - 10 9.85811 +100.00Cl, 10.22 A5 6.34 A5 I 4 12 9.85 B11 +100.00 Cl' 10.23 A5 6.34 A5 5 30 9.84 B11 +100.00 Cl 10.31 A5 6.34 A5 6 330 9.78 B11 13.90 Cl 11.92 Al 7.04 A5 7 400 9.77811 11.48 C1 12.18 Al 7.22 A5 8 400 ' 9.77 B11 11.48 Cl 7.38 A5 6.54 A5 9 900 9.67 611 5.11 Cl 6.28 A5 6.30 Al- 10 1100 9.63 911 4.20 Cl 6.62 A5 6.44 Al 11 1100 9.63 611 4.20 C1 6.63 A5 6.44 Al 12 1255 9.60 611 3.70 Cl 6.93 Al 6.54 B11 13 1271 9.59611 3.66 C1 6.95 Al 6.55611 14 1300 9.59B11 3.58 C1 (6.43)C1 6.57811 15 1300 9.591311 3.58 C1 (6.43)Cl 6.58 B11 16 1309 9.59 B11 3.55 C1 7.00 Al 6.59 B11 17 1700 9.52 B11 2.78 C1 7.66 Al 7.11 Al 18 1862 9.49611 2.55 C1 (6.71)Cl 5.68 Cl 19 1980 9.47 611 2.41 Cl (5.04)Cl 4.96 Cl 20 2000 9.47 B11 2.39 Cl (4.84)Cl 4.85 Cl 21 2000 9.47 B11 2.39 Cl (4.85)Cl 4.86 Cl 22 2100 9.45 B11 2.29 Cl (4.80)Cl 4.72 Cl 23 2224 9.43 811 2.18 Cl (4.78)Cl 4.58 Cl 24 2224 9.43 B11 2.18 C1 (4.74)Cl 4.55 Cl 25 2300 9.42 B11 2.12 C1 (4.71)Cl 4.47 C1 26 2300 9.42 61 t 2.12 C1 (4.72)C1 i 4.47 Cl 27 2400 9.401311 2.04 Cl (4.68)Cl 4.36 Cl 28 2404 9.40 B11 2.04 Cl 1 (4.68)Cl 4.36 Cl 29 2446 9.40 1311 2.02 Cl ' (4.67)Cl 4.32 Cl 30 2500 9.39 B11 1.98 Cl (4.65)Cl 4.27 Cl 31 2600 9.38 611 1.93 C1 (4.62)Cl 4.18 C1 32 2720 9.36 611 1.87 Cl (4.60)C1 4.10 Cl 33 2721 9.36 611 1 1.87 Cl (6.63)A2 4.10 Cl 34 2721 9.36 611 1.87 Cl (6.58)A2 4.09 Cl 35 2721 9.36 B11 1.87 Cl (5.87)A2 4.09 Cl 36 37 B5 Pressure Test 38 1311 Fracture @ Shoe w/1/3 BHP at Surface _ 39 Cl Full/Partial Evacuation 40 Al Running in Hole-Avg.Speed 41 A2 Pre-Cement Static Load 42 A5 Green Cement Pressure Test(Axial) 43 O Compression 44 SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) * Date: November 11, 2014 Page: 2 BURST LOADS DATA(13 3/8" Surface Casing) Drilling Load: Pressure Test Test Pressure: 2000.00 psi Mud Weight: 9.50 ppg Plug Depth, MD: 10.0 usft Assigned External Pressure: Fluid Gradients (w/ Pore Pressure) Drilling Load: Fracture @ Shoe w/1/3 BHP at Surface Surface Pressure (1/3 ` BHP): 510.19 psi Shoe Depth, MD: 2721.0 usft Fracture Pressure at Shoe: 1598.51 psi Fracture Margin of Error: 0.00 ppg External Pressure: Fluid Gradients(w/ Pore Pressure) TOC, MD: 30.0 usft Prior Shoe. MD: 0.0 usft Mud Weight Above TOC: 8.33 ppg Fluid Gradient Below TOC: 8.33 ppg Pore Pressure In Open Hole: No SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) * Date: November 11, 2014 Page: 3 BURST DESIGN (13 3/8" Surface Casino) 0—Design Load Line Pipe Rating 200 r -r r r 1 400---+- 600 8001 J J L 1 J I I I I + I 1 1 1 1 I 1000— 1 J J L 1 J I 1 I + I I I 1 1 1200---- 1 a it I I I 1400 4 A I 1 I I 1600 + -1 -+ I- I -1 I I I 1 Q +a) I I I I 0 1800— r 1 r t 7 -0 I 1 I I IR I I NI I cN 2000--- +- i 1 r T 1 G 2200---+ r 1 r r 1 2400--- +' 2600—-- +. J L 1 J + 2800 J L J I I I I I I 30001 J J L 1 J I I I I I I 3200 1 a 1 a I I I I I I I I 3400 + 4 -I I- + 1 I I 3600 j I - I t j l 0 1500 3000 4500 6000 7500 9000 10500 12000 13500 Burst Rating (psi) SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) * Date: November 11, 2014 Page: 4 COLLAPSE LOADS DATA(13 3/8"Surface Casino) Drilling Load: Full/Partial Evacuation Mud Weight: 9.50 ppg Mud Level, MD: 2721.0 usft Assigned External Pressure: Fluid Gradients (w/Pore Pressure) External Pressure: Fluid Gradients(w/Pore Pressure) TOC, MD: 30.0 usft Prior Shoe, MD: 0.0 usft Fluid Gradient Above TOC: 9.50 ppg Fluid Gradient Below TOO: 9.50 ppg Pore Pressure In Open Hole Below TOC: No SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) * Date: November 11, 2014 Page: 5 COLLAPSE DESIGN (13 3/8"Surface Casing) Design Load Line Pipe Rating 200 T 1 r 400-- - 600— - 8001 J L 1 J L - I 1 I I I I I I I I I I I I 1000 1 J L 1 J L L - I I I I I I 1200 1 J L 1 J L L - I I I I I 1 I I 1400 - I I I I I I I I I E 1600 I - t ti r t r I I I L G. d I I 01800— 7 7 r i -1 r r - .p I I N � 7 g2000 T 1 r T -1 r - 2 1 I 1 I 1 I I I I 2200 T -1 r i 1 r - 2400— 2600 L + 2800 1 J L 1 J L L - I I I I I I I I I 30001 J L 1 J L L _ I I i I I I I I I I 3200 J - I I I I I I I I I I I I I 3400 E- + - 1 I I I 1 3600 i I , I 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Collapse Rating (psi) SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) * Date: November 11, 2014 Page: 6 AXIAL LOADS DATA(13 3/8"Surface Casing) Running in Hole-Avg. Speed: 0.0 ft/s Overpull Force: 0 lbf Pre-Cement Static Load: Yes Pickup Force: 0 Ibf Green Cement Pressure Test: 1000.00 psi Service Loads: Yes SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) * Date: November 11, 2014 Page: 7 AXIAL DESIGN (13 3/8" Surface Casing) 0 Design Load Line Pipe Rating 200 r r r 400----I 600 800 L L 1 J J J I I I + I I I I I I 1000 L 1 1 1 J J I I I I 1 I + I I I I I I 1 I 1200 Ij LL 1 J J + I I I I I I 1400 4 4 I I I I Z 1600 r + r -t 1 -I I I I I I Q. + I 1 I a) 0 1800r Y -p I 4) I I I I uI a`�i 2000 T + T T 1 C I I I G I I I I I 1 I I I 2200-- + r -Ir 1 �II 24001 2600 2800L L 1 1 J I I I I I I I I I I I 3000 L 1 1 1 J J I I I I I 1 I 1 3200— 1 1 1 J -1 I I I I I I I I I I 3400 + -, I I I 1 I I I I 3600 i r t t 0 400000 800000 1200000 1600000 2000000 2400000 2800000 3200000 3600000 Axial Force (lbf) SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) Date: November 11, 2014 Page: 1 MINIMUM SAFETY FACTORS (9 5/8" Intermediate Casing) Depth(MD) Minimum Safety Factor(Abs) (ustt) ODNVeighUGrade Connection Burst Collapse Axial Triaxial 1 0 9 5/8",40.000 ppt,L-80 N/A 2.86 B5 +100.00 Cl 5.02 B5 3.53 B5 2 12 2.87 B5 +100.00 Cl 5.05 B5 3.54 B5 3 15 2.87 B5 +100.00 Cl 5.05 B5 3.54 B5 4 15 11.32 B11 +100.00 Cl 5.42 A5 5.52 A5 5 400 11.21 B11 15.36 Cl 5.96 A5 5.81 A5 6 400 11.21 B11 15.36 Cl 4.83 A5 5.11 A5 7 900 11.07 B11 6.88 Cl 4.58 A5 4.90 A5 8 1100 11.02 B11 5.67 C1 4.76 A5 5.03 A5 9 1100 11.02 B11 5.67 Cl 4.77 A5 5.03 A5 10 1300 10.96 B11 4.84 C1 4.97 A5 5.16 A5 11 1508 10.91 B11 4.22 C1 6.16 Al 5.48 Al 12 1700 10.86 Bi 1 3.78 Cl 6.18 Al 5.81 Al 13 1843 10.83 1311 3.51 Cl 6.20 Al 5.20 Al 14 2000 10.79 B11 3.25 C1 5.00 A5 4.66 C1 15 2000 10.79 B11 3.25 Cl 5.01 A5 4.67 Cl 16 2100 10.77811 3.12 Ci 5.10 A5 4.60 Cl 17 2224 10.74811 2.97Cl 5.25 A5 4.53 Cl 18 2224 10.74 B11 , 2.97 Cl 5.21 A5 4.51 Cl 19 2300 10.73 B11 2.88 Cl 5.29 A5 4.46 Cl 20 2300 10.73 B11 2.88 C1 5.30 A5 4.46 C1 21 2400 10.71 811 2.79 Cl 5.39 A5 4.40 Cl 22 2500 10.69 B11 2.70 Cl 5.48 A5 4.35 Cl 23 2600 10.67 B11 2.63 Cl 5.57 A5 4.29 Cl 24 2721 10.65 811 2.55 Cl 5.69 A5 4.24 Cl 25 2721 10.65 811 2.55 Cl 5.68 A5 4.23 Cl 26 2721 10.65 B11 2.55 Cl 5.66 A5 4.23 C1 27 2790 10.64 B11 2.51 Cl 5.71 A5 4.20 C1 28 2800 10.64 B11 2.51 Cl 5.72 A5 4.20 C1 29 2800 10.64 B11 2.51 Cl 5.73 A5 420 C1 30 2900 10.62 B11 2.46 Cl 5.80 A5 4.16 C1 31 3000 10.61 B11 2.42 Cl 5.86 A5 4.12 Cl 32 3100 10.60 B11 2.38 C1 5.92 A5 4.09 Cl 33 3200 10.59 1311 2.35 Cl 5.97 A5 4.07 C1 34 3300 10.59 B11 2.33 Cl 6.01 A5 4.05 C1 35 3400 10.58 811 2.31 Cl 6.04 A5 4.03 Cl 36 3500 10.58 B11 2.30 Cl 6.06 A5 4.02 C1 37 3500 10.58 611 2.30 C1 6.07 A5 4.03 C1 38 , 3530 10.58 B11 2.30 Cl 6.65 Al 4.15 Cl 39 3700 10.57 B11 2.29 Cl 6.70 Al 4.99 Cl 40 9000 10.50 B11 1 2.08 C1 7.22 Al 4.60 Cl 41 9000 8.04 B11 2.08 Cl 7.22 Al 4.57 Cl 42 10300 7.99 811 2.03 Cl 7.36 Al 4.08 Cl 43 10400 7.98 811 2.03 Cl 7.37 Al 4.07 Cl 44 10500 7.97 1311 2.02 Cl 7.38 Al 4.06 Cl 45 10600 7.96 B11 2.01 Cl 7.39 Al 4.04 Cl 46 10800 7.93 B11 1.99 Cl 7.43 Al 4.37 Cl 47 11608 7.81 BI 1.89 Cl 8.20 Al 3.70 Cl 48 11700 7.80 811 1.88 Cl 7.70 B11 3.63 C1 49 11700 7.80 B11 1.88 Cl 7.68 611 3.63 Cl 50 11834 7.781311 1.87 Cl 7.68 611 3.61 Cl 51 11900 7.77 B11 1.86 Cl 7.68 B11 3.60 Cl 52 12100 7.75611 1.84 C1 7.67611 3.57Cl 53 12100 7.75 B11 1.84 Cl 7.68 B11 3.58 C1 54 12300 7.73 B11 1.83 Cl 7.67 811 3.55 Cl 55 12500 7.72 B11 1.82 Cl 7.69 B11 3.54 Cl 56 12500 7.72 811 1.82 Cl 7.66 B11 3.54 C1 57 12507 7.72 B11 1.82 Cl 7.99 B11 3.57 Cl 58 12528 7.72 1311 1.82 Cl 9.23 Al 3.66 Cl 59 12600 7.71 B11 1.82 Cl 9.35 Al 4.01 Cl 60 13320 7.68 B11 1.79 C1 11.50 Al 3.95 C1 61 13321 7.68811 1.79C1 11.50 Al 3.95Cl 62 63 B5 Pressure Test 64 B11 Fracture @ Shoe w/1/3 BHP at Surface 65 Cl Full/Partial Evacuation 66 Al Running in Hole-Avg.Speed 67 A5 Green Cement Pressure Tes((Axiom SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) Date: November 11, 2014 Page: 2 MINIMUM SAFETY FACTORS(9 5/8" Intermediate Casing) Depth(MD) 1 Minimum Safety Factor(Abs) (usft) OD/Weight/Grade Connection Burst Collapse Axial Triaxial 68 SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) Date: November 11, 2014 Page: 3 BURST LOADS DATA(9 5/8" Intermediate Casing) Drilling Load: Pressure Test Test Pressure: 2000.00 psi Mud Weight: 9.50 ppg Plug Depth, MD: 15.0 usft ', Assigned External Pressure: Fluid Gradients (w/Pore Pressure) Drilling Load: Fracture @ Shoe w/1/3 BHP at Surface Surface Pressure (1/3 * BHP): 507.37 psi Shoe Depth, MD: 13321.0 usft Fracture Pressure at Shoe: 2277.72 psi Fracture Margin of Error: 0.00 ppg External Pressure: Fluid Gradients(w/Pore Pressure) TOC, MD: 9000.0 usft Prior Shoe, MD: 2721.0 usft Mud Weight Above TOO: 9.50 ppg Fluid Gradient Below TOC: 8.33 ppg Pore Pressure In Open Hole: Yes SP31-W7 StressCheck 5000.1.10.0 Build 1934 File:SP31-W7 (P8) Date: November 11, 2014 Page:4 BURST DESIGN (9 5/8" Intermediate Casing) 0 -----.__ Design Load Line Pipe Rating 750— r r Lr 1 1 1500--J 2250 + 3000 + L 1 1 J J I I I 1 I 1 3750 L L 1 1 J I I 1 4500 LL I I 5250 + I I F. I 1 I 1 1 CO 6000— r r -t + -1 -I 1 I L 1 1 Q 1 1 N 0 6750— r r -r 1 1 2 I I 7CO I i N 7500 r r 7 7 1 M I I I I 8250 r r t z 1 1 9000—- + - 9750— 1 1 I I I + 10500 L 1 1 1 J I 1 L L -1 1 J J 11250 I I + I I 12000 — l- -' I I I I I I + I I 12750— + + I I I I I ! I + I I I I I 13500 I I 1 I I I I I 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 Burst Rating (psi) SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) Date: November 11, 2014 Page: 5 COLLAPSE LOADS DATA(9 5/8" Intermediate Casing) Drilling Load: Full/Partial Evacuation Mud Weight: 9.50 ppg Mud Level, MD: 13321.0 usft Assigned External Pressure: Fluid Gradients (w/ Pore Pressure) External Pressure: Fluid Gradients(w/Pore Pressure) TOO, MD: 9000.0 usft Prior Shoe, MD: 2721.0 usft Fluid Gradient Above TOC: 9.50 ppg Fluid Gradient Below TOC: 9.50 ppg Pore Pressure In Open Hole Below TOC: No I I SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) Date: November 11, 2014 Page:6 COLLAPSE DESIGN(9 5/8" Intermediate Casino) 0 r - + Design Load Line Pipe Rating 750 r r 1 1 1500— i- 2250— h 3000 L L 1 1 J I I I I I I I I 3750— L L 1 1 J I I I I I I 4500 1 _, I I I I I I I I 5250 I cn I I I I = 6000 r t 7 i -I -1 I = I I Q 4) I I 0 6750 r r 7 1 1 - 'D I I 2>• I I o) 2 7500— r r T 1 1 -I cI I G I I I I 8250 r r T 7 1 9000 9750 L i 1 I I 10500 L J J I I I I 11250 L L 1 1 J J L 1 I I I I I I I II 12000 -I I I I I I I I I 12750 -I I 13500 I —_"_ , _ I 1 I I I 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 Collapse Rating (psi) SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) Date: November 11, 2014 Page: 7 AXIAL LOADS DATA(9 5/8" Intermediate Casing) Running in Hole-Avg. Speed: 0.0 ft/s Overpull Force: 0 Ibf Pre-Cement Static Load: Yes Pickup Force: 0 Ibf Green Cement Pressure Test: 1000.00 psi Service Loads: Yes I i I I II SP31-W7 StressCheck 5000.1.10.0 Build 1934 File: SP31-W7 (P8) Date: November 11, 2014 Page: 8 AXIAL DESIGN(9 5/8" Intermediate Casino) 0 . Design Load Line] L+ Pipe Rating 750 tr r 1500 f 2250 - + 3000 + L 1 1 J J 1 + 3750 L 1 J J I 1 I I I I I I 4500 I I I I 5250 4- 6000 L CL N I 0 6750 D a> I >` I U) I ami 7500 r T 1 1 2 8250 r T 1 1 9000— -+ 9750 1 1 10500 L 1 1 J J I I I I I I I I I I 11250 + I 12000 12750 13500 I T j 1 0 300000 600000 900000 1200000 1500000 1800000 2100000 24000001 Axial Force (lbf) SP31-W7 StressCheck 5000.1.10.0 Build 1934 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday, November 14, 2014 2:20 PM To: andrea.lazzari@enipetroleum.com Subject: Nikaitchuq SP31-W7: Permit to Drill Application Good afternoon Andrea, The Form 10-401 submitted for the SP31-W7 application was the Form 10-401 (Revised 7/2009)which is outdated. Please resubmit the Form 10-401 for SP31-W7 on the current Form 10-401 (Revised 10/2012). The Form 10- 401 (Revised 10/2012) can be found on the AOGCC website at: http://doa.alaska.gov/ogc/forms/forms.html. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: ic.� c s? 3� — W4 PTD: .2/y - 1g� /Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: v fir(�I rCJ� POOL: I I1& T C.A Jo IWii+ U11)1 Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). 743(o The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are Well Loggingalso required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 T -a 0 I- v a x w 3 0 M 1 3 0 .< CD j r 3 m • _ '0 P. 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Z v° 3 a 0 X w �� :c o v m c c p ' m 5 '73 '2 a 'ro CO 3 3 • y fD O f0 W O a ,0 < CD 'n, N (O N CD (p j (� y CT C C �+ CD a. fi m ,� < a I_ lU F, co a ,� o , 7 y v °° n VD y m o ,v ° v m a .A :v ° m - ,m o 0 Sco O y 7 v ,m �'- .o 'z o : cl 0 ,N ,y 3 y r a v 3 O y -0 o rn ,3 0 b 0 o 3 y 0 T m c �O o '� a ,� o n0 �� V ,y ':O , : o Mo. o ma CO ac = a c a o V m 7CL ,c0. ;a .° d Z a d -* m o a) O. ,- 2 y N CD O. c 'CD 'N N o A 0 01 co _o V m moo) r+ w n ,� w a CD �• X (2 oD ae ° 3 30• a O 3 O _ c yN N (D a d a y Z .. O N RT D 4 V _ 5. ,-I0 c - 0 0❑ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: February 20, 2015 Surface Data Logging End of Well Report SP31-W7 SP31-W7 L1 SP31-W7 L1 PB1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 6. Mud Record 7. Bit Record 8. Morning Reports 9. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: Eni Petroleum Rig: Doyon 15 Well: SP31-W7, SP31-W7 L1, & SP31-W7 L1 PB1 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23532-00-00 (SP31-W7) 50-629-23532-60-00 (SP31-W7 L1) 50-629-23532-70-00 (SP31-W7 L1 PB1) Sperry Job Number: AK-XX-0901938178 Job Start Date: 29 December 2014 Spud Date: 1 January 2015 Total Depth: 22454’ MD, 3430’ TVD (SP31-W7) 22795’ MD, 3503’ TVD (SP31-W7 L1) 13600’ MD, 3508’ TVD (SP31-W7 L1 PB1) North Reference: True Declination: 19.029° Dip Angle: 81.059° Total Field Strength: 57589.998 nT Date Of Magnetic Data: 01 Jan 2015 Wellhead Coordinates N: North 70° 33' 27.69815" Wellhead Coordinates W: West 149° 54' 21.91285" Drill Floor Elevation 53.7’ Ground Elevation: 13.1’ Permanent Datum: Mean Sea Level SDL Engineers: Alexander Kalenuik, Kori Jo Plowman, Rebecca Mulkey, Gregory Dellner SDL Sample Catchers: Beverly Hur, Sonny Tiger, Sean Dowden, Chase Tomlinson Company Geologist: Josh Zuber Company Representatives: Jack Keener / Mike Ross SSDS Unit Number: 110 DAILY SUMMARY 12/29/2014 SDL continues on location from previous well. Skid rig floor into drilling position. Rig up operation in preparation for pre-spud acceptance 12/30/2014 Set SDL mud logging unit and continue rig up operations. Nipple up wellhead. Begin to pick up tools and BHA #1. Stand down issued due to high winds. 12/31/2014 Continue to wait on weather. Phase III conditions. Perform only “low risk” activities. 01/01/2015 Make up 16” bit, motor and heavy weight drill pipe. Clean out conductor casing to 160’ MD. Make up BHA #2 and run in hole to 160’ MD. Drill to 390’ MD and back ream out of hole to 110’ MD. Pick up remaining BHA and drill to 745’ MD. Gas: Max gas observed was 3 units at 737' MD with an average gas of 1 unit. Fluids: No fluid losses 01/02/2015 Drill from 745’ MD to 2600’ MD Gas: Max gas observed was 772 units at 1995' MD with an average gas of 123 units. Fluids: No fluid losses 01/03/2015 Drill from 2600’ MD to 2677’ MD for surface TD. Backream out of hole to 345’ MD and lay down BHA #2. Clean rig floor and rig up casing equipment. Run 13 3/8” casing and make up landing joint to 2663’ MD. Gas: Max gas observed was 159 units at 2643' MD with an average gas of 50 units. Fluids: No fluid losses 01/04/2015 Run cement job. Rig down equipment and nipple down stack. Clean pits. Load pipe shed with 5” drill pipe. Nipple up BOPE’s 01/05/2015 Complete nippleing up BOPE’s. Lay down 9 joints of heavy weight drill pipe. Pick up 348 joints of 5” drill pipe and rack in derrick. Rig up test equipment and test BOPE’s. Test 13 3/8” surface casing. Rig down equipment 01/06/2015 Clear rig floor and make up BHA #3. Run in hole to 1500’ MD. Shallow hole test tools. Run in hole to 2575’ MD and tag cement. Drill shoe track, cement and 20’ of new hole to 2697’ MD. Displace from spud mud to LSND. Slip and cut drill line. Perform formation integrity test. Drill from 2697’ MD to 2975’ MD Gas: Max gas observed was 200 units at 2880' MD with an average gas of 73 units. Fluids: No fluid losses Geology: Samples consist of mainly sandstone with occasional siltstone. 01/07/2015 Drill from 2975’ MD to 4963’ MD. Gas: Max gas observed was 135 units at 2985' MD with an average gas of 29 units. Fluids: No fluid losses Geology: Samples consist of mainly sandstone with occasional siltstone 01/08/2015 Drill from 4963’ MD to 7246’ MD. Gas: Max gas observed was 28 units at 5482' MD with an average gas of 7 units. Fluids: No fluid losses Geology: Samples consist of mainly sandstone with trace siltstone 01/09/2015 Drill from 7246’ MD to 9227’ MD. Gas: Max gas observed was 12 units at 8522' MD with an average gas of 4 units. Fluids: No fluid losses Geology: Samples consist of mainly sandstone with trace siltstone 01/10/2015 Drill ahead from 9227' MD to 9302' MD. The decision was made to back ream out of hole due to traces of metal shavings. Begin to back ream to around 3900’ MD Gas: Max gas observed was 9 units at 9174' MD with an average gas of 4 units. Fluids: Total of 15 barrels lost to formation Geology: Samples consist of mainly clean sandstone 01/11/2015 Continue to back ream out of hole to 350’ MD. Lay down BHA #3. Make up BHA #4. Run in hole and lay down bad joints of drill pipe. Shallow hole test at 1751’ MD. Continue to run in hole. Gas: Max gas observed was 66 units while back reaming out of the hole Fluids: Total of 19 barrels lost to formation 01/12/2015 Continue to run in the hole with BHA #4. Drill ahead from 9302’ MD to 11084’ MD Gas: Max gas observed was 123 units at 10786’ MD with an average gas of 12 units Fluids: No fluid losses Geology: Samples consist of mainly sandstone with occasional siltstone 01/13/2015 Continue to drill from 11084’ MD to 12404’ MD. Gas: Max gas observed was 550 units at 12260’ MD with an average gas of 55 units Fluids: Total of 13 barrels lost to formation Geology: Samples consist of mainly sandstone with occasional siltstone 01/14/2015 Continue to drill from 12404’ MD to 12404’ MD for intermediate TD. Begin to backream out of hole Gas: Max gas observed was 2581 units at 13289’ MD with an average gas of 277 units Fluids: No fluid losses Geology: Samples consist of mainly sandstone with occasional siltstone 01/15/2015 Continue to backream out of the hole. Pump dry job and begin to lay down BHA #4. Gas: Max gas observed while backreaming was 95 units Fluids: Total of 52 barrels lost to formation 01/16/2015 Continue to lay down BHA #4. Rig up casing equipment. Begin running in the hole with 9 5/8” casing. Gas: No significant gas data. Fluids: Total of 6 barrels lost to formation 01/17/2015 Continue to run in the hole with 9 5/8” casing. Land casing at 13320’ MD. Fill casing and condition mud for cementing Gas: No significant gas data. Fluids: Total of 7 barrels lost to formation 01/18/2015 Cementing 9 5/8” casing. Removed pump #2 from the pump room and fan a BOP test. Gas: No significant gas data. Fluids: No fluid losses. 01/19/2015 Complete BOP test and make up the mule shoe. Run in the hole with 4.5” drill pipe to 3795’ MD and pull out of the hole to rack back. Rig up and test casing. Make up BHA #5 and shallow hole test at 1501’ MD. Begin to trip in the hole. Gas: No significant gas data. Fluids: No fluid losses 01/20/2015 Continue to run in the hole with 4.5” drill pipe. Changeover to 5” drill pipe at 10710’ MD. Tag float collar at 13234’ MD. Displace hole from water based to oil based mud. Clean surface equipment, cut and slip the drill line then drill 20’ of new hole to 13355’ MD. Perform formation integrity test. Gas: No significant gas data. Fluids: No fluid losses 01/21/2015 Drill ahead from 13355’ MD to 14995’ MD to begin production section. Gas: Max gas observed was 1039 units at 14227’ MD with an average gas of 382 units Fluids: No fluid losses Geology: Samples consist of sandstone 01/22/2015 Continue to drill ahead from 14995’ MD to 16869’ MD. Gas: Max gas observed was 968 units at 15252’ MD with an average gas of 347 units Fluids: No fluid losses Geology: Samples consist of clean sandstone 01/23/2015 Continue to drill ahead from 16869’ MD to 18753’ MD. Gas: Max gas observed was 810 units at 17186’ MD with an average gas of 341 units Fluids: No fluid losses Geology: Samples consist of clean sandstone 01/24/2015 Continue to drill ahead from 18753’ MD to 20889’ MD. Gas: Max gas observed was 859 units at 24810’ MD with an average gas of 305 units Fluids: No fluid losses Geology: Samples consist of clean sandstone 01/25/2015 Continue to drill ahead from 20889’ MD to TD at 22454’ MD. Begin backreaming out of the hole Gas: Max gas observed was 1141 units at 21607’ MD with an average gas of 354 units Fluids: No fluid losses Geology: Samples consist of sandstone and siltstone 01/26/2015 Continue to backream out of the hole Gas: Max gas observed was 59 units at 22454’ MD with an average gas of 12 units Fluids: No fluid losses 01/27/2015 Continue to backream out of the hole Gas: Max gas observed was 15 units at 22454’ MD with an average gas of 3 units Fluids: Total of 71 barrels lost to formation 01/28/2015 Continue to backream out of the hole and lay down BHA #5 Gas: No significant gas data. Fluids: Total of 18 barrels lost to formation 01/29/2015 Perform rig maintenance. Run in hole with 5 ½” slotted liner and make up liner hanger Gas: No significant gas data. Fluids: Total of 13 barrels lost to formation 01/30/2015 Run in hole with 5” drill pipe. Orient liner top. Set the packer and test. Liner shoe at 21889’ MD Gas: No significant gas data. Fluids: No fluid losses 01/31/2015 Pull out of hole and lay down liner running tool. Clean rig floor. Mobilize and make up whipstock assembly. Run in hole with whipstock and mill assembly to 13150’ MD. Orient whipstock Gas: No significant gas data. Fluids: No fluid losses 02/01/2015 Mill 9 5/8” casing and 25’ of new rathole to 13165’ MD. Begin to pull out of hole Gas: Max gas observed was 19 units at 13152’ MD with an average gas of 9 units Fluids: No fluid losses 02/02/2015 Continue to pull out of hole. Lay down milling BHA #6. Rig up BOPE test equipment. Test BOPE. Service rig and make up BHA #7. Run in hole to 5585’ MD. Gas: No significant gas data. Fluids: No fluid losses 02/03/2015 Continue to run in hole. Conduct formation integrity test at 13106’ MD. Cut and slip drill line. Drill ahead and called TD PB1 at 13600’ MD after crossing fault. Begin to backream out of hole to sidetrack. Gas: Max gas observed was 347 units at 13287’ MD with an average gas of 120 units Fluids: No fluid losses Geology: Samples consist of siltstone and shale 02/04/2015 Continue to backream out of hole to 13324’ MD. Open hole sidetrack. Kick off point at 13350’ MD. Drill ahead to 15188’ MD Gas: Max gas observed was 1220 units at 14866’ MD with an average gas of 519 units Fluids: No fluid losses Geology: Samples consist of clean sandstone 02/05/2015 Continue to drill ahead from 15188’ MD to 17436’ MD Gas: Max gas observed was 971 units at 16240’ MD with an average gas of 461 units Fluids: No fluid losses Geology: Samples consist of clean sandstone 02/06/2015 Continue to drill ahead from 17436’ MD to 19378” MD Gas: Max gas observed was 800 units at 17752’ MD with an average gas of 320 units Fluids: No fluid losses Geology: Samples consist of clean sandstone 02/07/2015 Continue to drill ahead from 19378” MD to 21443’ MD Gas: Max gas observed was 1045 units at 21232’ MD with an average gas of 386 units Fluids: Total of 67 barrels lost to formation Geology: Samples consist of clean sandstone 02/08/2015 Continue to drill ahead from 21443’ MD to TD of 22795’ MD. Begin to backream out of hole Gas: Max gas observed was 936 units at 21511’ MD with an average gas of 419 units Fluids: Total of 97 barrels lost to formation Geology: Samples consist of clean sandstone 02/09/2015 Continue to backream out of hole Gas: Max gas observed was 101 units at 13892’ MD with an average gas of 17 units Fluids: Total of 196 barrels lost to formation 02/10/2015 Continue to backream out of hole. Pull BHA through window with no rotation. Cut and slip drill line. Pull out of hole and lay down BHA #7. Make up whipstock retrieval BHA Gas: No significant gas data. Fluids: No fluid losses 02/11/2015 Run in hole with whipstock retrieval hook. Latch on to whipstock and pull. Begin to pull out of hole with whipstock Gas: No significant gas data. Fluids: No fluid losses 02/12/2015 Continue to pull out of hole and lay down whipstock BHA. Clean rig floor. Bring liner tools to rig floor. Service top drive, blocks and drawworks. Run in hole with 5 ½” slotted liner. Gas: No significant gas data. Fluids: Total of 23 barrels lost to formation. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 22000 23000 24000 0 5 10 15 20 25 30 35 40 45 50 55 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: SP31-W7, SP31-W7 L1, & SP31-W7 L1 PB1 OPERATOR: ENI Petroleum MUD CO: MI Swaco RIG: Doyon 15 SPERRY JOB: AK-XX-0901938178 Days vs. Depth 29 Dec 2014 Sperry SDL Continue on Location LOCATION: Nikaitchuq AREA: North Slope Bourough STATE: Alaska SPUD: 1-Jan-2015 TD: 8-Feb-2015 Commenced 8.75" Production Hole Section On Bot: 23:55 20 Jan 2015 Commenced 16" Surface Hole Section On Bot: 04:37 01 Jan 2015 TD Surface Hole Section 2676' MD, 2431' TVD Off Bot: 01:05 03 Jan 2015 Landed 13.375" Casing 2663' MD, 2422' TVD 04 Jan 2015 Commenced 12.25" Intermediate Hole Section On Bot: 15:09 06 Jan 2015 POOH for Bit Change 10 Jan 2015 TD Intermediate Hole Section 13335' MD, 3505' TVD Off Bot: 13:38 14 Jan 2015 Landed 9.625" Casing 13320' MD, 3504' TVD 17 Jan 2015 TD Production Hole Section 22454' MD, 3430' TVD Off Bot: 15:10 25 Jan 2015 Mill Window through 9.625" Casing On Bot 09:30 31 Jan 2015 Commenced 8.75" L1 Production Hole Section On Bot: 07:39 03 Feb 2015 Commenced Open Hole Side Track @13350' MD On Bot: 00:15 04 Feb 2015 TD L1 Production Hole Section 22795' MD, 3503' TVD Off Bot: 14:00 08 Feb 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: Canrig was not set up to receive our gas data. It took approximately four hours on the phone to get them to correct the problem. The problem was not with us it was there inability to find the proper com port that the data was coming in on. Petrolink changed their IP address and so that took several hours trying to get the proper address to send data to. The Iris computer failed right as we finished running casing. Insite would not open so it had to be uninstalled and re-installed and then it was nessasry to go through each drilling parameter to assure that they were being mapped correctly. The ADI also failed but it was only nessary to restart it. The 9000 Gas Equipment failed and it was nessasry to send it to our facility in Deadhorse. We have ordered a replacement and are using the backup 8800. Recommendations: Take screen shots of all settings to minimize downtime when troubleshooting with Canrig and Petrolink. Innovations and/or cost savings: N/A Drilling proceeded according to plan. We logged to a depth of 2667'MD. SP31-W7 Nikaitchuq ENI Petroleum North Slope Bourogh AK-XX-0901938178 Alaska Doyon 15 Surface Paul Kalenuik 30-Jan-2015 What went as, or better than, planned: Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Difficulties experienced: The MADI crashed and when rebooted the plot manager would not open. ROC worked on the problem and resolved it. The Exporter will not work on the workstation, there has not been a resolution for this problem. Data is being exported on the ADI and transferred to a thumb drive. The Gas Chromatograph needed to be recalibrated toward the end of the section. It began to read C2 first. A failure report was filled out and the equipment sent to the shop after completion of the section. Recommendations: Always have back up gas gear warmed and ready to go in case of a failure to minimize downtime. Innovations and/or cost savings: N/A Doyon 15 Intermediate Kori Jo Plowman 30-Jan-2015 What went as, or better than, planned: The depth tracked very well during the intermediate section. Small adjustments were needed every few stands. It was very helpful to have the ROC available around the clock. SP31-W7 Nikaitchuq ENI Petroleum North Slope Bourogh AK-XX-0901938178 Alaska Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Difficulties experienced: The Iris was restarted during a rig power outage and the only hickup was the IP address that MWD uses to receive data from us had changed. The problem was fix as soon as they called. Recommendations: If WITS isn't working check the IP address and make sure it hasn't changed. Innovations and/or cost savings: N/A Doyon 15 Production Kori Jo Plowman 30-Jan-2015 What went as, or better than, planned: The chromatograph worked with no problems during production section. Logging overall seemed to go fairly smooth. SP31-W7 Nikaitchuq ENI Petroleum North Slope Bourogh AK-XX-0901938178 Alaska Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Difficulties experienced: We experienced a block height trace issue that was corrected by adjusting the smoothing of the trace. The gas trap in the upper possum belly cannot be adjusted to a correct height to handle the flow of mud necessitating that the lower trap be used. Recommendations: Manufacturing a adjustable clamp sytem on order to adjust the upper gas trap. Innovations and/or cost savings: N/A Production L1 SP31-W7 L1 ENI Petroleum AK-XX-0901938178 Doyon 15 A Paul Kalenuik 15-Feb-2015 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. Did not experience any networking problems with data. Nikaitchuq North Slope Bourogh Alaska Surface Data Logging After Action Review WELL NAME:SP31-W7, SP31-W7 L1, & SP31-W7 L1 PB1 LOCATION:Nikaitchuq OPERATOR:ENI Petroleum AREA:North Slope Bourough MUD CO:Mi Swaco STATE:Alaska RIG:Doyon 15 SPUD:1-Jan-2015 SPERRY JOB:AK-XX-0901938178 TD:8-Feb-2015 Marker MD INC AZ TVD TVDSS 16" Surface Borehole SV-4 756.5 6.4 196.3 755.9 -702.1 SV-3 1,129.0 14.8 230.3 1,121.4 -1,068.0 SV-2 1,397.0 23.8 229.5 1,374.8 -1,321.2 Permafrost Base 1,819.0 24.9 228.6 1,756.0 -1,702.2 SV-1 2,000.0 29.3 228.9 1,918.7 -1,865.3 Ugnu Top (UG4) 2,378.0 41.4 227.6 2,228.2 -2,174.8 12 1/4" Intermediate Borehole UG-2 Coal Bed Marker 3,580.0 84.7 227.6 2,718.2 -2,664.5 Fault 1 5,510.0 86.8 228.6 2,819.9 -2,766.4 Fault 2 6,647.0 87.1 229.2 2,880.4 -2,826.9 Fault 3 8,327.0 86.9 226.7 2,967.2 -2,913.8 Lower Ugnu 10,225.0 85.9 228.8 3,072.8 -3,019.5 Schrader Bluff 11,418.0 79.8 226.6 3,274.5 -3,221.0 N Sequence Top 11,664.0 79.4 231.2 3,318.5 -3,265.1 N Sand Top 11,820.0 79.2 236.9 3,348.3 -3,294.5 N Sand Bottom 11,932.8 80.7 239.1 3,367.8 -3,314.1 N Sequence Base 12,390.0 84.8 250.4 3,427.8 -3,374.2 Fault 4 12,420.0 85.0 250.9 3,430.5 -3,376.9 OA Sand Top 12,885.0 85.2 257.4 3,474.2 -3,420.5 OA-2 12,958.0 85.8 258.0 3,479.9 -3,426.2 Fault 5 12,978.0 86.0 258.2 3,481.3 -3,427.7 OA Sand Top 13,220.0 86.3 256.5 3,497.5 -3,443.9 OA-2 13,250.0 86.4 256.1 3,499.3 -3,445.8 8 3/4" Lateral OA-3 13,355.0 87.2 258.3 3,504.2 -3,450.6 Fault A 13,883.0 89.3 264.9 3,513.2 -3,459.6 Fault B 14,275.0 90.4 271.7 3,513.6 -3,460.1 OA-3 15,103.0 92.1 286.5 3,514.9 -3,461.4 OA-2 15,195.9 91.8 286.5 3,511.7 -3,458.2 Fault C 15,460.0 87.2 285.0 3,514.0 -3,460.7 OA Bottom 15,825.0 95.8 290.7 3,502.7 -3,449.2 OA-4 15,873.0 95.8 292.3 3,497.8 -3,444.4 OA-3 16,145.0 90.4 294.3 3,488.7 -3,435.2 OA-2 16,497.0 91.1 299.8 3,486.7 -3,432.9 OA Sand Top 17,281.4 89.7 308.5 3,489.5 -3,436.1 OA Sand Top 17,464.9 86.2 310.0 3,495.9 -3,442.4 Fault D 17,498.0 86.3 310.4 3,498.0 -3,444.5 OA Bottom 17,807.0 96.8 313.1 3,490.1 -3,436.5 OA-4 17,852.0 96.4 312.7 3,484.8 -3,431.7 Fault E 18,306.0 87.9 309.9 3,475.7 -3,422.1 OA--2 18,480.0 89.2 314.3 3,479.8 -3,426.2 OA--2 18,619.0 88.3 321.3 3,483.3 -3,429.7 OA--2 18,730.0 89.2 325.3 3,485.8 -3,432.1 OA-2 19,730.0 86.7 336.8 3,498.3 -3,444.7 OA-3 19,795.0 86.8 336.4 3,501.9 -3,448.4 OA-3 21,005.0 92.4 321.7 3,496.4 -3,442.8 OA-2 21,115.0 91.1 322.2 3,493.1 -3,439.6 Fault F 21,815.0 91.0 326.5 3,490.8 -3,437.3 Formation Tops WELL NAME:SP31-W7, SP31-W7 L1, & SP31-W7 L1 PB1 LOCATION:Nikaitchuq OPERATOR:ENI Petroleum AREA:North Slope Bourough MUD CO:Mi Swaco STATE:Alaska RIG:Doyon 15 SPUD:1-Jan-2015 SPERRY JOB:AK-XX-0901938178 TD:8-Feb-2015 Marker MD INC AZ TVD TVDSS SP31-W7 L1 Lateral TOW 13,122.0 86.2 257.6 3,491.0 -3,437.2 BOW 13,139.0 86.0 259.1 3,492.2 -3,438.4 OA Sand Top 13,220.0 87.0 263.8 3,497.6 -3,443.8 Fault A 13,230.0 87.3 265.4 3,498.1 -3,444.3 OA-2 13,250.0 87.8 265.5 3,498.9 -3,445.5 OA-2 13,377.0 89.5 271.8 3,500.4 -3.448.0 Fault B 13,445.0 87.2 270.6 3,502.4 -3.448.6 OA Sand Top 13,514.0 87.0 272.0 3,505.8 -3,453.1 Fault C 15,825.0 89.4 291.3 3,520.5 -3,466.8 OA-Sand Base 16,035.0 95.4 295.2 3,512.8 -3.459.1 OA-4 16,085.0 95.1 296.1 3,508.0 -3,454.2 Fault D 18,100.0 89.5 313.3 3,521.3 -3,467.5 OA-Sand Base 18,410.0 95.8 318.0 3,504.6 -3,450.8 OA-4 18,440.0 95.0 319.2 3,501.8 -3,448.0 OA-3 19,690.0 91.5 331.1 3,501.8 -3,445.8 OA-2 19,784.0 92.0 331.7 3,496.8 -3,443.0 OA Sand Top 20,550.0 90.8 327.7 3,485.5 -3,431.7 OA Sand Top 20,649.0 89.0 325.0 3,485.9 -3,432.2 OA-2 20,996.0 88.6 327.0 3,488.8 -3,435.0 OA-3 21,278.0 89.0 332.1 3,496.6 -3,442.8 OA-3 21,539.0 90.3 331.4 3,499.6 -3,445.8 OA-2 21,658.0 88.9 337.0 3,498.2 -3,444.5 SP31-W7 L1 PB1 Sidetrack Point 13,350.0 90.5 271.2 3,500.4 3,446.6 Fault B 13,446.0 91.3 272.2 3,498.8 -3,445.1 TD SP31-W7L1PB1 13,601.0 92.2 271.3 3,493.5 -3,439.8 Formation Tops SP31-W7, SP31-W7 L1, & SP31-W7 L1 PB1 ENI Petroleum MI Swaco Doyon 15 AK-XX-0901938178 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/R 6/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++ 1-Jan 505 8.90 90 28 32 18/43/55 5.3 88/60/49/37/18/16 3/-3.0 0/97 0.10 0.15 9.5 23.0 .08/.44 2500 100 Drilling ahead 2-Jan 2360 9.30 96 31 36 17/46/59 4.6 98//67/53/44/16/14 2.5/-4.0 0/96 0.10 0.20 9.6 23.0 .10/.60 2700 80 Drilling ahead 3-Jan 2677 9.30 72 27 28 16/43/58 5.2 82/55/43/30/15/13 3/-4.3 0/95.75 0.10 0.10 9.0 22.0 .07/.50 2600 100 Run in casing 4-Jan 2677 9.30 43 14 13 5/6/6 41/27/21/14/7/6 8.3 Rig up BOPE 5-Jan 2677 9.30 43 14 13 5/6/6 41/27/21/14/7/6 8.3 Picking up BHA 6-Jan 2697 9.25 47 10 19 9/12/14 5.2 39/29/25/19/10/8 1/-4.5 2/93.5 0.00 1.40 9.8 0.0 1.10/2.80 1900 80 Drilling ahead 7-Jan 4811 9.20 51 11 30 10/13/16 5.8 52/41/34/27/12/10 1/-4.8 3/92.25 0.10 1.00 9.8 8.0 .60/2.5 18000 140 Drilling ahead 8-Jan 6822 9.30 55 13 29 11/14/16 5.0 55/42/35/27/13/11 1/-4.9 3/92.1 0.10 1.20 9.8 8.5 1.0/2.8 17000 120 Drilling ahead 9-Jan 9124 9.30 58 13 33 10/13/15 4.8 59/46/38/28/12/10 1/-6.0 3/91 0.10 1.00 9.6 9.5 .80/3.60 17000 100 Drilling ahead 10-Jan 9301 9.35 60 16 29 11/13/15 4.6 61/45/38/28/13/11 1/-6.0 3.25/90.75 0.10 1.00 9.6 9.0 .80/2.60 15000 1220 TOOH 11-Jan 9301 9.35 53 15 23 10/11/13 4.6 53/38/33/24/12/9 1/-6.0 3.25 90.75 1.00 9.6 9.0 .70/2.80 15000 120 RIH BHA#4 12-Jan 10802 9.30 57 14 30 12/14/16 4.5 58/44/37/28/15/12 1/-6.0 3.25/90.75 0.10 0.90 9.5 9.5 .70/3.20 16500 100 Drilling ahead 13-Jan 12284 9.40 57 14 34 12/14/17 4.6 62/48/41/30/15/12 1/-6.0 3/91 0.10 1.10 9.6 10.0 .80/3.10 16000 100 Drilling ahead 14-Jan 13335 9.50 60 17 37 12/15/17 4.5 71/54/44/32/15/12 1/-6.0 4/91 0.10 1.10 9.7 10.0 .80/3.10 15500 100 BROOH 15-Jan 13335 9.40 57 13 33 11/14/16 4.5 59/46/38/29/14/11 1/-6.0 4/91 0.10 1.00 9.6 10.0 .70/3.00 15500 100 L/D BHA #4 16-Jan 13335 9.40 76 24 32 15/18/22 4.6 80/56/45/37/18/14 1/-6.0 4/91 0.10 1.00 9.6 10.0 .70/3.00 15500 100 Run 9 5/8" casing 17-Jan 13335 9.40 66 16 20 11/14/16 4.6 52/36/29/21/12/9 1/-6.0 4/91 0.10 1.00 9.5 10.0 .70/3.00 15500 100 Load cement plug 18-Jan 13335 9.40 53 16 20 11/14/16 4.6 52/36/29/21/12/9 1/-6.0 4/91 0.10 1.00 9.5 10.0 .7/3.00 15500 100 BOP testing 19-Jan 13335 9.40 53 16 20 11/14/16 4.6 52/36/29/21/12/9 1/-6.0 4/91 0.10 1.00 9.5 10.0 .7/3.00 15500 100 Single in hole Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/R 6/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-Jan 14830 9.3 43 14 14 7/8/8 3.9 42/28/23/17/8/6 -/1 6.37 67/33 2.75 3.58 711 31.22 -.4/6 2.8 Drilling 8.75" hole 22-Jan 16590 9.2 44 13 13 7/7/8 3.9 40/27/22/16/7/6 -/1 6.22 69/31 2.9 3.77 733 33.22 -.8/5.4 2.8 Drilling 8.75" hole 23-Jan 18600 9.25 44 14 13 7/7/8 3.9 41/27/21/16/7/6 -/1 6.52 67/33 3 3.9 777 30.47 -.9/5.6 2.8 Drilling 8.75" hole 24-Jan 20662 9.25 44 13 12 7/7/8 4.2 38/25/20/16/7/6 -/1 6.52 69/31 2.8 3.64 881 31.69 -1.2/5.3 2.8 Drilling 8.75" hole 25-Jan 22454 9.25 45 12 15 7/7/8 4.2 39/27/21/16/7/6 -/1 10 69/31 2.35 3.06 791 27.83 -1.9/5.3 2.7 BROOH 26-Jan 22454 9.25 45 12 13 7/7/8 4.4 37/25/20/15/7/9 -/1 10 69/31 2.2 2.86 772 27.24 -1.9/5.4 2.7 BROOH 27-Jan 22454 9.45 46 12 15 7/8/8 4.4 39/27/22/18/8/7 -/1 7.64 69/31 2.2 2.86 765 26.82 -1.9/5.4 2.7 BROOH 28-Jan 22454 9.45 46 12 14 6/7/7 NA 38/26/21/16/7/6 -/-7.64 69/31 2.2 2.86 750 26.82 -1.6/6 2.8 L/D BHA #5 29-Jan 22454 9.45 46 11 15 7/7/8 NA 37/26/21/16/7/6 -/-7.64 69/31 2.2 2.86 750 27.75 -1.6/6 2.8 M/U Pal Mix 30-Jan 22454 9.45 46 12 13 7/7/8 NA 36/25/19/14/7/6 -/-7.64 69/31 2.7 3.51 710 27.75 -1.6/6 2.8 Cut and Slip 31-Jan 22454 9.45 46 12 13 7/7/8 NA 37/25/19/14/7/6 -/-7.64 69/32 2.5 3.25 690 27.75 -1.6/6 2.8 Pump Dart 1-Feb 13165 9.30 46 12 12 7/7/8 NA 36/24/19/14/7/6 -/-7.59 69/31 2.60 3.38 640 27.8 -1.6/7 2.8 POH Mill Assy 2-Feb 13165 9.30 46 12 12 7/7/8 4.2 36/24/19/14 -/1 7.59 69/31 2.60 3.38 625 26.79 -1.5/6.1 2.8 POH 3-Feb 13508 9.30 46 12 12 6/7/7 4.2 36/24/18/24 -/1 7.6 69/31 2.40 3.12 635.0 27.1 -1.3/6.2 2.8 Drilling 8.75" hole 4-Feb 14717 9.30 44 11 13 6/6/7 4.2 35/24/18/14 -/1 7.7 69/31 2.00 2.60 630.0 26.1 -1.3/6.4 2.8 Drilling 8.75" hole 5-Feb 17148 9.30 45 12 13 6/6/7 4.3 37/25/18/13 -/1 7.9 70/30 2.10 2.73 630.0 26.0 -1.1/6.7 2.8 Drilling 8.75" hole 6-Feb 18948 9.30 48 13 14 6/6/7 4.4 40/27/20/14 -7.7 70/30 2.25 2.93 650.0 26.9 -1.3/6.4 2.8 Drilling 8.75" hole 7-Feb 21085 9.25 50 14 18 7/7/8 4.4 46/32/24/18/7/6 -7.64 69/31 2.40 3.12 625 26.82 -1.3/6.3 2.8 Drilling 8.75" hole 8-Feb 22795 9.25 52 14 17 7/7/8 4.4 45/31/25/19/7/6 -/1 7.17 68/32 2.70 3.51 620 27.59 -0.9/6.3 2.8 BROOH 9-Feb 22795 9.35 53 15 19 7/7/8 -49/34/27/19/7/6 -/-7.08 68/32 2.40 3.12 630 27.98 -0.8/6.3 2.8 BROOH 10-Feb 22795 9.4 53 16 16 7/7/8 -48/32/25/18/7/6 -7.56 68/32 2.40 3.12 685 28.55 -1.2/6.4 2.8 M/U Whipstock Retrieval Casing Record LOCATION: Remarks 20" Conductor @ 160' MD, 160'TVD 13.375" Casing @ 2663' MD, 2422'TVD 9.625" Casing @ 13320' MD, 3504'TVD WELL NAME:Nikaitchuq OPERATOR: MUD CO: AREA: North Slope Bourough STATE: Alaska RIG:SPUD:1-Jan-2015 SPERRY JOB:TD:8-Feb-2015 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 SP31-W7, SP31-W7 L1, & SP31-W7 L1 PB1 BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 2 100 1 Hughes MX-1 Mill Tooth 16"160 2677 2517 16.70 1.117 150.4 20 40 1650 700 1-1-WT-A-E-In-No-TD Surface TD 3 200 2 Hycalog SKHI716D-E10C PDC 12.25 2677 9302 6625 62.10 0.969 106.6 12 160 2150 900 5-2-WT-N-X-In-BT-PR POOH for Bit Change 4 300 3 Hycalog SKHI716D PDC 12.25 9302 13335 4033 43.30 0.969 93.2 12 180 3300 1030 2-3-CT-A-X-I-WT-TD Intermediate TD 5 400 4 Smith MDSi616 BPX PDC 8.75 13335 22454 9119 71.20 0.969 128.1 10 160 3100 550 0-1-CT-S-X-IN-NO-TD Production TD 7 700 5 Smith MDSi616 BPX PDC 8.75 13165 22795 9881 70.20 0.902 140.7 10 160 3400 500 1-0-CT-N-X-IN-NO-TD Production L1 8-Feb-2015 Alaska RIG:Doyon 15 SPUD:1-Jan-2015 WELL NAME:LOCATION:Nikaitchuq OPERATOR:ENI Petroleum AREA:North Slope Bourough MUD CO: SPERRY JOB:AK-XX-0901938178 TD: MI Swaco STATE: B i t R e c o r d . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (max) (current) Cly Set At Size Grade 907-685-0772 Unit Phone: Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Kori Plowman Units* Casing Summary Lithology (%) MBT pH Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth C-5n C-2 in Minimum Depth Time: 0' 0' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary (current) J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Rig move/Rig up PV 24 hr Max Weight Hours C-3 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB 100% Gas In Air =10,000 Units Connection No Gas to report in the last 24 hours SDL servives rigging up. Condition Bit # Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE ROP ROP (ft/hr) 4.23 @ Mud Data Depth 29-Dec-2014 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l Move sub, rock washer, and pit mod, transfer equip. to new well bay, stage diverter, Skid rig floor, put diverter in rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Continue Rigging up for spud, P/U tools, waiting on weather. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1700.00 30-Dec-2014 12:00 AM Current Pump & Flow Data: Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition Bit # 1 3.0 16 Mill Tooth 8.70 Size No Gas to report in the last 24 hours SDL servives rigged up. 100% Gas In Air =10,000 Units Connection Tools API FL Chromatograph (ppm) 160' WOB Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type Spud 6.0 160'47 Depth in / out YP (lb/100ft 2) 9.70 Cement Cht Silt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 wait on weather PV Footage J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 29 Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 0' 0' 0' Max @ ft Current Date: Time: in Minimum Depth C-5n C-2 SPP (psi) Gallons/stroke TFA Bit Type Depth 25.0 170 MBT pH 1.117 Siltst Units* Casing Summary Lithology (%) 907-685-0772 Unit Phone: Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Kori Plowman Set At Size Grade (max) (current) Cly Bottoms Up Time Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (max) (current) Cly Set At Size Grade 907-685-0772 Unit Phone: Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Kori Plowman Units* Casing Summary Lithology (%) MBT pH 1.117 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 25.0 170 C-5n C-2 in Minimum Depth Time: 0' 0' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary (current) J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 29 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 wait on weather PV 24 hr Max Weight Hours C-3 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.70 Spud 6.0 160'47 Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 160' WOB 100% Gas In Air =10,000 Units Connection No Gas to report in the last 24 hours Condition Bit # 1 3.0 16 Mill Tooth 8.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE ROP ROP (ft/hr) 4.23 @ Mud Data Depth 31-Dec-2014 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l 1700.00 waiting on weather. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (max) (current) Cly Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Paul Kalenuik 581 119 Units* Casing Summary Lithology (%) MBT pH 1.117 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 23.0 90 C-5n 737' 15.0 C-2 3 in 0 642'Minimum Depth Time: 0 160' 745' 585' Max @ ft Current 172'117.0 Date: Avg to 160' Yesterday's Depth: Current Depth: 24 Hour Progress: 2290.0 Flow In (gpm) Flow In (spm) Gas Summary (current) J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 28 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Drilling ahead PV 24 hr Max Weight Hours C-3 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.50 Spud Mud 5.3 505'32 Depth in / out Mud Type Lst Type Average 0Background (max) Trip 0.82 17.91 Avg Min Comments RPM ECD (ppg) ml/30min Tools SP Moter 1.83, GyroPulse, Telescope 825, ARC 825 API FL Chromatograph (ppm) 160' WOB Evermar 100% Gas In Air =10,000 Units Connection 160' Condition Bit # 1 3.0 16 Hughes MX1 Mill tooth 8.90 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 1154.07 DOYON15 Report For: Morning Report Report # 4 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE ROP ROP (ft/hr) 4.23 @ Mud Data Depth 1-Jan-2015 12:00 AM Current Pump & Flow Data: 1042 Max Chlorides mg/l 2500.00 RIH to 160' for a clean out run. Drill to 390' MD. BROOH to 110'. P/U remaining BHA #2. RIH to 343'. W ash down to rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Drill f/682' to 1,522' MD/1,488' TVD at 650 gpm, 1424 psi, 40 rpm, TQn:4-9k, TQf:2-4k, WOB:10-30k. ECD: 10.17 ppg. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2700.00 0 2-Jan-2015 12:00 AM Current Pump & Flow Data: 1566 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 5 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 735.13 DOYON15 Report For: Condition Bit # 1 4.0 16 Hughes MX1 Mill tooth 9.30 Size Max gas in last 24 hours 772 units. 160' 100% Gas In Air =10,000 Units 772 Connection 0 Tools SP Moter 1.83, GyroPulse, Telescope 825, ARC 825 API FL Chromatograph (ppm) 160' WOB Evermar 0.52 20.93 Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average 0 Mud Type Lst Type Spud Mud 4.6 2360'36 Depth in / out YP (lb/100ft 2) 9.60 000 00 Cement Cht Silt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Drilling ahead PV Footage J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 31 Gas Summary 0 0 0 (current) Avg to 160' Yesterday's Depth: Current Depth: 24 Hour Progress: 850.0 Flow In (gpm) Flow In (spm) 745' 2600' 1855' Max @ ft Current 2023'170.0 Date: Time: 123 in 2 2488'Minimum Depth C-5n 1995' 118.0 C-2 772 SPP (psi) Gallons/stroke TFA Bit Type Depth 23.0 96 MBT pH 1.117 0 0 0 Siltst 704 154 Units* Casing Summary Lithology (%) 019997 8167 907-685-0772 Unit Phone: 0 Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Paul Kalenuik Set At Size 178.9 X-65 Grade 20.00'' (max) (current) 0 0 Cly 111112 Bottoms Up Time Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (max) (current) 0 0 Cly 138 Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: 0 Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Paul Kalenuik 48 0 Units* Casing Summary Lithology (%) 0 MBT 2677' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 22.0 72 C-5n 2643' C-2 159 in 0Minimum Depth Time: 50 2600' 2677' 77' Max @ ft Current 2645'75.0 Date: Avg to 160' Yesterday's Depth: Current Depth: 24 Hour Progress: 605.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 27 2517' Footage 53.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Run 13 3/8" Csg PV 24 hr Max Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.00 000 40.0 Spud Mud 5.2 2677'28 Depth in / out Mud Type Lst Type Average 38 0Background (max) Trip 0.52 9.65 Avg Min Comments RPM ECD (ppg) ml/30min Tools SP Moter 1.83, GyroPulse, Telescope 825, ARC 825 API FL Chromatograph (ppm) 20.0 160' 2677' WOB Evermar 100% Gas In Air =10,000 Units 51 Connection 0 hours was 159 units. Run to 2,585'. Fill every jt & top off every 10 jts. Wash down to 2,622' at 1 bpm & 180 psi. M/U landing jt to 2,663'. Max gas in last 24 160' Condition Bit # 1 4.3 16 Hughes MX1 Mill tooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 9.65 DOYON15 Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 3-Jan-2015 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l 2600.00 Drill f/2,547' MD to TD at 2,677' MD/ 2,430' TVD Shoot MWD surveys. Monitor well. Static. BROOH to 345' at 850/700 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (max) (current) BTC 0 0 Cly 0 Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: 0 Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Paul Kalenuik 0 0 13 3/8" Units* Casing Summary Lithology (%) 0 L-80 MBT pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 22.0 72 C-5n C-2 in Minimum Depth Time: 2677' 2677' 0' Max @ ft Current 2645'75.0 Date: Avg to 2667' Yesterday's Depth: Current Depth: 24 Hour Progress: 605.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 27 2517' Footage 53.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 wait on cmt PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.00 000 40.0 Spud Mud 5.2 2677'28 Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 825/ARC 825/Telescope825/Gr/Res/DIR/PWD API FL Chromatograph (ppm) 20.0 160' 2677' WOB Evermar 100% Gas In Air =10,000 Units Connection 0 2663' 160' Condition 1-1-WT-A-E-In-No-TD Bit # 1 4.3 16 Hughes MX1 Mill tooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 7 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 4-Jan-2015 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l 2600.00 Cmt 13 3/8" surface csg. N/D diverter & stack. Install multibowl &test. N/U BOP & set test plug. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % * 24 hr Recap: Complete nippling up BOPE's. P/U 348 jts 5" DP & rack in derrick. Rig up test equip. Test BOPE's per regulations. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 0 5-Jan-2015 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-In-No-TD Bit # 1 16 Hughes MX1 Mill tooth 9.30 Size 2663' 160' 100% Gas In Air =10,000 Units Connection 0 Tools API FL Chromatograph (ppm) 20.0 160' 2677' WOB Evermar Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type 40.0 T-Spud Mud 2677'13 Depth in / out YP (lb/100ft 2) 8.30 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Pick up BHA PV 2517' Footage 53.00 J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 14 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2677' 2677' 0' Max @ ft Current Date: Time: in Minimum Depth C-5n C-2 SPP (psi) Gallons/stroke TFA Bit Type Depth 43 L-80 MBT pH 1.117 0 0 0 Siltst 13 3/8" Units* Casing Summary Lithology (%) 00 0 907-685-0772 Unit Phone: 0 Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Paul Kalenuik Set At Size 178.9 X-65 Grade 20.00'' (max) (current) BTC 0 0 Cly 0 Bottoms Up Time Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes * 24 hr Recap: M/U 12-1/4" bit & BHA. RIH to 1,500'. Shallow test MWD. OK.RIH to 2,575' & tag cmt. Drill shoe track to 2,579'. Drill rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 19000.00 0 6-Jan-2015 12:00 AM Current Pump & Flow Data: 1110 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 9 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 9.95 DOYON15 Report For: Condition Bit # 2 4.5 12.25 Hycalog 9.25 Size are mostly sandstone with occasional siltstone. rates & downlink per DD. Drill f/2,697' to 2,881' MD/2,544' TVD. Monitor well. Static. ECD: 9.93 ppg. Max gas 280 units. Samples 2663' 160' 100% Gas In Air =10,000 Units Connection 0 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 2677' WOB Evermar 9.47 9.75 Avg Min Comments Surface RPM ECD (ppg) ml/30min 52 Background (max) Trip Average Mud Type Lst 85% Type LSND 5.2 2697'19 Depth in / out YP (lb/100ft 2) 9.80 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Drilling ahead PV Footage J.Keener/O. Amend Sh Clyst Tuff Gvl Coal cP 10 Gas Summary 0 0 0 (current) Avg to 2677' Yesterday's Depth: Current Depth: 24 Hour Progress: 500.0 Flow In (gpm) Flow In (spm) 2677' 2975' 298' Max @ ft Current 92.0 Date: Time: 73 in 1 2678'Minimum Depth C-5n 2880' 352.0 C-2 280 SPP (psi) Gallons/stroke TFA Bit Type Depth 0.0 47 L-80 MBT pH 0.969 0 0 0 Siltst 13 3/8" 854 172 Units* Casing Summary Lithology (%) 010047 9 907-685-0772 Unit Phone: 0 Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Paul Kalenuik Set At Size 178.9 X-65 Grade 20.00'' (max) (current) BTC 0 0 Cly 34556 15% * 24 hr Recap: rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 18000.00 0 7-Jan-2015 12:00 AM Current Pump & Flow Data: 1649 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.36 DOYON15 Report For: Condition Bit # 2 4.8 12.25 Hycalog 9.20 Size Max gas 28 units at 5482'MD. Samples are sandstone with trace siltstone. 2663' 160' 100% Gas In Air =10,000 Units Connection 0 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 2677' WOB Evermar 8.09 10.01 Avg Min Comments Surface RPM ECD (ppg) ml/30min 1Background (max) Trip Average Mud Type Lst 100% Type LSND 4.8 4811'30 Depth in / out YP (lb/100ft 2) 9.80 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Drilling ahead PV Footage J.Keener/R. Wimmer Sh Clyst Tuff Gvl Coal cP 11 Gas Summary 0 0 0 (current) Avg to 2677' Yesterday's Depth: Current Depth: 24 Hour Progress: 601.0 Flow In (gpm) Flow In (spm) 4963' 7246' 2283' Max @ ft Current 6992'115.0 Date: Time: 7 in 0 6833'Minimum Depth C-5n 5482' 195.0 C-2 28 SPP (psi) Gallons/stroke TFA Bit Type Depth 8.0 51 L-80 MBT pH 0.969 0 0 0 Siltst 13 3/8" 910 184 Units* Casing Summary Lithology (%) 0249 94 907-685-0772 Unit Phone: 0 Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Paul Kalenuik Set At Size 178.9 X-65 Grade 20.00'' (max) (current) BTC 0 0 Cly 3350 * 24 hr Recap: Drill f/4,876' to 5,756' MD/2,834' TVD at 900 gpm, 1810 psi, 160-180 rpm, TQn:8-10k, TQf:4-5k, WOB:4-10k. ECD: rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 17000.00 0 8-Jan-2015 12:00 AM Current Pump & Flow Data: 2095 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.36 DOYON15 Report For: Condition Bit # 2 0.1 12.25 Hycalog 9.30 Size Max gas 28 units at 5482'MD. Samples are sandstone with trace siltstone. 2663' 160' 100% Gas In Air =10,000 Units Connection 0 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 2677' WOB Evermar 8.09 10.01 Avg Min Comments Surface RPM ECD (ppg) ml/30min 1Background (max) Trip Average Mud Type Lst 100% Type LSND 5.0 6882'29 Depth in / out YP (lb/100ft 2) 9.80 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Drilling ahead PV Footage J.Keener/R. Wimmer Sh Clyst Tuff Gvl Coal cP 13 Gas Summary 0 0 0 (current) Avg to 2677' Yesterday's Depth: Current Depth: 24 Hour Progress: 601.0 Flow In (gpm) Flow In (spm) 4963' 7246' 2283' Max @ ft Current 6992'115.0 Date: Time: 7 in 0 6833'Minimum Depth C-5n 5482' 101.0 C-2 28 SPP (psi) Gallons/stroke TFA Bit Type Depth 8.5 55 L-80 MBT pH 0.969 0 0 0 Siltst 13 3/8" 902 180 Units* Casing Summary Lithology (%) 0249 94 907-685-0772 Unit Phone: 0 Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Paul Kalenuik Set At Size 178.9 X-65 Grade 20.00'' (max) (current) BTC 0 0 Cly 3350 * 24 hr Recap: (max) (current) BTC 0 0 Cly 1383 Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: 0 Rebecca Mulkey Maximum Report By: Logging Engineers: Rebecca Mulkey/Paul Kalenuik 311 44 13 3/8" 904 182 Units* Casing Summary Lithology (%) 0 L-80 MBT pH 0.969 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 8.5 55 C-5n 8608' 101.0 C-2 12 in 1 9131'Minimum Depth Time: 4 7246' 9227' 1981' Max @ ft Current 7684'88.0 Date: Avg to 2677' Yesterday's Depth: Current Depth: 24 Hour Progress: 420.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J.Keener/R. Wimmer Sh Clyst Tuff Gvl Coal cP 13 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Drilling ahead PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.80 000 LSND 5.0 6882'29 Depth in / out Mud Type Lst 100% Type Average 2Background (max) Trip 10.10 10.38 Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 2677' WOB Evermar 100% Gas In Air =10,000 Units Connection 0 Max gas 12 units at 8608'MD. Samples are sandstone with trace siltstone. 2663' 160' Condition Bit # 2 0.1 12.25 Hycalog 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.61 DOYON15 Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 9-Jan-2015 12:00 AM Current Pump & Flow Data: 2161 Max 0 Chlorides mg/l 17000.00 Drill f/7,256' to 8,522' MD/2,977' TVD at 900 gpm, 2170 psi, 180 rpm, TQn:9-12k, TQf:7k, WOB:10-15k. ECD:10.45 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % * 24 hr Recap: Drill ahead from 9227' MD to 9302' MD. The decision was made to BROOH due to traces of metal shavings. Begin to rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 15000.00 0 10-Jan-2015 12:00 AM Current Pump & Flow Data: 1568 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 DOYON15 Report For: Condition Bit # 2 6.0 12.25 Hycalog 9.35 Size consisted of mainly clean sandstone. 2663' 160' 100% Gas In Air =10,000 Units Connection 0 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 2677' WOB Evermar 0.00 0.00 Avg Min Comments Surface RPM ECD (ppg) ml/30min 2Background (max) Trip Average Mud Type Lst 100% Type LSND 4.6 9302'29 Depth in / out YP (lb/100ft 2) 9.60 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 BROOH PV Footage J.Keener/R. Wimmer Sh Clyst Tuff Gvl Coal cP 16 Gas Summary 0 0 0 (current) Avg to 2677' Yesterday's Depth: Current Depth: 24 Hour Progress: 412.8 Flow In (gpm) Flow In (spm) 9227' 9302' 75' Max @ ft Current 9261'8.5 Date: Time: 4 in 1 9131'Minimum Depth C-5n 9174' 0.0 C-2 9 SPP (psi) Gallons/stroke TFA Bit Type Depth 9.0 60 L-80 MBT 9302' pH 0.969 0 0 0 Siltst 13 3/8" 898 181 Units* Casing Summary Lithology (%) 0366 44 907-685-0772 Unit Phone: 0 Kori Jo Plowman Maximum Report By: Logging Engineers: Kori Jo Plowman/Paul Kalenuik Set At Size 178.9 X-65 Grade 20.00'' (max) (current) BTC 0 0 Cly 1181 * 24 hr Recap: (max) (current) BTC 0 0 Cly Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: 0 Kori Jo Plowman Maximum Report By: Logging Engineers: Kori Jo Plowman/Paul Kalenuik 13 3/8" Units* Casing Summary Lithology (%) 0 L-80 MBT pH 0.969 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 9.0 53 C-5n C-2 in Minimum Depth Time: 9302' 9302' 0' Max @ ft Current Date: Avg to 9302' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J.Keener/R. Wimmer Sh Clyst Tuff Gvl Coal cP 15 6625' 12.25 0.969 Footage 62.10 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 RIH BHA#4 PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.60 000 160.0 Hycalog PDC LSND 4.6 9302' 9302'23 Depth in / out Mud Type Lst Type Average 66 Background (max) Trip 0.00 0.00 Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 12.0 2677' 9302' WOB Evermar 100% Gas In Air =10,000 Units Connection 0 3 2663' 160' Condition 5-2-WT-N-X-In-BT-PR Bit # 2 6.0 12.25 Hycalog PDC 9.35 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 DOYON15 Report For: Morning Report Report # 14 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 11-Jan-2015 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l 15000.00 Continue to BROOH to 350' MD. L/D BHA #3. M/U BHA #4. RIH and L/D bad joints. Shallow hole test at 1751' MD. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % * 24 hr Recap: Continue to RIH with BHA #4. Drill ahead from 9302' MD to 11084' MD. Samples consist of mainly sandstone with rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 16500.00 0 12-Jan-2015 12:00 AM Current Pump & Flow Data: 2878 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.54 DOYON15 Report For: Condition 5-2-WT-N-X-In-BT-PR Bit # 2 6.0 12.25 Hycalog PDC 9.30 Size 3 2663' 160' 100% Gas In Air =10,000 Units Connection 0 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 12.0 2677' 9302' WOB Evermar 9.98 10.27 Avg Min Comments Surface RPM ECD (ppg) ml/30min 9Background (max) Trip Average Mud Type Lst 90% Type 160.0 Hycalog PDC LSND 4.5 9302' 10802'30 Depth in / out YP (lb/100ft 2) 9.50 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Drill 12.25" hole PV 6625' 12.25 0.969 Footage 62.10 J.Keener/R. Wimmer Sh Clyst Tuff Gvl Coal cP 14 Gas Summary 0 0 0 (current) Avg to 9302' Yesterday's Depth: Current Depth: 24 Hour Progress: 475.0 Flow In (gpm) Flow In (spm) 9302' 11084' 1782' Max @ ft Current 10365'80.0 Date: Time: 12 in 1 10767'Minimum Depth C-5n 10786' 0.0 C-2 123 SPP (psi) Gallons/stroke TFA Bit Type Depth 9.5 57 L-80 MBT pH 0.969 0 0 0 Siltst 13 3/8" 1048 211 Units* Casing Summary Lithology (%) 0 10% 1298 351 907-685-0772 Unit Phone: 0 Kori Jo Plowman Maximum Report By: Logging Engineers: Kori Jo Plowman/Paul Kalenuik Set At Size 178.9 X-65 Grade 20.00'' (max) (current) BTC 0 0 Cly 17733 * 24 hr Recap: (max) (current) BTC 982 6 Cly 62219 Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: 10 Kori Jo Plowman Maximum Report By: Logging Engineers: Kori Jo Plowman/Paul Kalenuik 30% 7027 149 13 3/8" 1025 224 Units* Casing Summary Lithology (%) 41 L-80 MBT pH 0.969 3 440 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 10.0 57 C-5n 12260' 126.4 C-2 550 in 1 11716'Minimum Depth Time: 55 11084' 12404' 1320' Max @ ft Current 11403'58.2 Date: Avg to 9302' Yesterday's Depth: Current Depth: 24 Hour Progress: 429.5 Flow In (gpm) Flow In (spm) Gas Summary 0 224 429 (current) J.Keener/R. Wimmer Sh Clyst Tuff Gvl Coal cP 14 6625' 12.25 0.969 Footage 62.10 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Drill 12.25" hole PV 24 hr Max 68.0 Weight 85 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.60 017 32 160.0 Hycalog PDC LSND 4.6 9302' 12284'34 Depth in / out Mud Type Lst 70% Type Average 20 Background (max) Trip 9.98 10.27 Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 12.0 2677' 9302' WOB Evermar 100% Gas In Air =10,000 Units Connection 626 3 2663' 160' Condition 5-2-WT-N-X-In-BT-PR Bit # 2 6.0 12.25 Hycalog PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.54 DOYON15 Report For: Morning Report Report # 16 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 13-Jan-2015 12:00 AM Current Pump & Flow Data: 3019 Max 45 Chlorides mg/l 16000 Continue to drill from 11084' MD to 12404' MD. The max gas observed was 550u. Samples consist mainly of rig Density (ppg) out (sec/qt) Viscosity Cor Solids % * 24 hr Recap: Continue to drill ahead from 12404' MD to Intermediate TD of 13335' MD. BROOH per K&M. Max gas observed was rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 15500 250 14-Jan-2015 12:00 AM Current Pump & Flow Data: 2507 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 17 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.61 DOYON15 Report For: Condition 5-2-WT-N-X-In-BT-PR Bit # 2 6.0 12.25 Hycalog PDC 9.50 Size 3 2663' 160' 100% Gas In Air =10,000 Units Connection 5788 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 12.0 2677' 9302' WOB Evermar 10.34 10.61 Avg Min Comments Surface RPM ECD (ppg) ml/30min 93 Background (max) Trip Average Mud Type Lst 80% Type 160.0 Hycalog PDC LSND 4.6 9302' 13335'37 Depth in / out YP (lb/100ft 2) 9.70 593 186 00 Cement Cht Silt C-4i C-4n 24 hr Max 68.0 Weight 405 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 BROOH PV 6625' 12.25 0.969 Footage 62.10 M. Ross/R. Wimmer Sh Clyst Tuff Gvl Coal cP 17 Gas Summary 0 3750 1996 (current) Avg to 9302' Yesterday's Depth: Current Depth: 24 Hour Progress: 377.8 Flow In (gpm) Flow In (spm) 12404' 13335' 931' Max @ ft Current 13232'40.9 Date: Time: 277 in 2 12766'Minimum Depth C-5n 13289' 0.0 C-2 2581 SPP (psi) Gallons/stroke TFA Bit Type Depth 10.0 60 L-80 MBT pH 0.969 4 2857 0 Siltst 13 3/8" 901 197 Units* Casing Summary Lithology (%) 189 20% 25081 156 907-685-0772 Unit Phone: 1238 Kori Jo Plowman Maximum Report By: Logging Engineers: Kori Jo Plowman/Paul Kalenuik Set At Size 178.9 X-65 Grade 20.00'' (max) (current) BTC 4776 5 Cly 246639 * 24 hr Recap: (max) (current) BTC Cly Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: Kori Jo Plowman Maximum Report By: Logging Engineers: Kori Jo Plowman/Paul Kalenuik 13 3/8" Units* Casing Summary Lithology (%) L-80 MBT 13335' pH 0.969 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 10.0 57 C-5n 0.0 C-2 in Minimum Depth Time: 13335' 13335' 0' Max @ ft Current 0.0 Date: Avg to 9302' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary (current) M. Ross/R. Wimmer Sh Clyst Tuff Gvl Coal cP 13 6625' 12.25 0.969 Footage 62.10 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 L/D BHA #4 PV 24 hr Max 68.0 Weight Hours C-3 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.60 160.0 Hycalog PDC LSND 4.5 9302' 13335'33 Depth in / out Mud Type Lst Type Average 95 Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 12.0 2677' 9302' WOB Evermar 100% Gas In Air =10,000 Units Connection 3 2663' 160' Condition 5-2-WT-N-X-In-BT-PR Bit # 2 6.0 12.25 Hycalog PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 18 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 15-Jan-2015 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l 15500 Continue to BROOH per K&M. Pump 20 bbls dry job. Begin to L/D BHA. The max gas while BROOH was 95 units. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % * 24 hr Recap: Continue to L/D BHA #4. R/U casing equipment. RIH w/9 5/8" casing. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 15500 16-Jan-2015 12:00 AM Current Pump & Flow Data: Max 2-3-CT-A-X-I-WT-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 19 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 5-2-WT-N-X-In-BT-PR Bit # 2 6.0 12.25 Hycalog PDC 9.40 Size 3 2663' 160' 100% Gas In Air =10,000 Units Connection Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 12 12.0 2677' 9302' WOB Evermar Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type 180 160.0 Hycalog PDC LSND 4.6 9302' 13335'32 13335' Depth in / out YP (lb/100ft 2) 9.60 Cement Cht Silt C-4i C-4n 24 hr Max 68.0 Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 RIH 9 5/8" Csg PV 6625' 12.25 0.969 Footage 43.30 4033' 62.10 M. Ross/R. Wimmer Sh Clyst Tuff Gvl Coal cP 24 Gas Summary (current) Avg to 9302' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 13335' 13335' 0' Max @ ft Current 0.0 Date: Time: in Minimum Depth C-5n 0.0 C-2 SPP (psi) Gallons/stroke TFA Bit Type Depth 10.0 76 L-80 MBT 13335' pH 0.969 Siltst 13 3/8" Units* Casing Summary Lithology (%) 907-685-0772 Unit Phone: Kori Jo Plowman Maximum Report By: Logging Engineers: Kori Jo Plowman/Paul Kalenuik Set At Size 178.9 X-65 Grade 20.00'' (max) (current) BTC Cly * 24 hr Recap: (max) (current) BTC Cly Set At Size 178.9 X-65 Grade 20.00'' 907-685-0772 Unit Phone: Kori Jo Plowman Maximum Report By: Logging Engineers: Kori Jo Plowman/Paul Kalenuik 13 3/8" Units* Casing Summary Lithology (%) L-80 MBT 13335' pH 0.969 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 10.0 66 C-5n 0.0 C-2 in Minimum Depth Time: 13335' 13335' 0' Max @ ft Current 0.0 Date: Avg to 9302' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary (current) M. Ross/R. Wimmer Sh Clyst Tuff Gvl Coal cP 16 6625' 12.25 0.969 Footage 43.30 4033' 62.10 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 Load cement plugs PV 24 hr Max 68.0 Weight Hours C-3 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.50 180 160.0 Hycalog PDC LSND 4.6 9302' 13335'20 13335' Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 12 12.0 2677' 9302' WOB Evermar 100% Gas In Air =10,000 Units Connection 3 2663' 160' Condition 5-2-WT-N-X-In-BT-PR Bit # 2 6.0 12.25 Hycalog PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 20 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE 2-3-CT-A-X-I-WT-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 17-Jan-2015 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l 15500 Continue RIH 9 5/8" casing to 13320' MD. Fill casing, condition mud for cementing. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % * 24 hr Recap: Cemented 9 5/8" casing, remove pump #2 from pump room, freeze protect, BOP testing. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 15500 18-Jan-2015 12:00 AM Current Pump & Flow Data: Max 2-3-CT-A-X-I-WT-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 21 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 5-2-WT-N-X-In-BT-PR Bit # 2 6.0 12.25 Hycalog PDC 9.40 Size 3 2663' 160' 100% Gas In Air =10,000 Units Connection Tools API FL Chromatograph (ppm) 12 12.0 2677' 9302' WOB Evermar Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Hydrill Type 180 160.0 Hycalog PDC LSND 4.6 9302' 13335'20 13335' Depth in / out YP (lb/100ft 2) 9.50 Intermediate Cement Cht Silt C-4i C-4n 24 hr Max 68.0 Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 BOP Testing PV 6625' 12.25 0.969 Footage 43.30 4033' 62.10 M. Ross/R. Wimmer Sh Clyst Tuff Gvl Coal cP 16 40.0 Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 13335' 13335' 0' Max @ ft Current 0.0 Date: Time: in Minimum Depth C-5n 0.0 C-2 SPP (psi) Gallons/stroke TFA Bit Type Depth 10.0 53 L-80 MBT pH 0.969 Siltst 13 3/8" Units* Casing Summary Lithology (%) 907-685-0772 Unit Phone: Kori Jo Plowman Maximum Report By: Logging Engineers: Kori Jo Plowman/Paul Kalenuik Set At Size 178.9 X-65 Grade L-80 13320' 20.00'' 9 5/8" (max) (current) BTC Cly * 24 hr Recap: (max) (current) BTC Cly Set At Size 178.9 X-65 Grade L-80 13320' 20.00'' 9 5/8" 907-685-0772 Unit Phone: Kori Jo Plowman Maximum Report By: Logging Engineers: Kori Jo Plowman/Paul Kalenuik 13 3/8" Units* Casing Summary Lithology (%) L-80 MBT pH 0.969 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 10.0 53 C-5n 0.0 C-2 in Minimum Depth Time: 13335' 13335' 0' Max @ ft Current 0.0 Date: Avg to 13335' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 40.0 Gas Summary (current) M. Ross/R. Wimmer Sh Clyst Tuff Gvl Coal cP 16 6625' 12.25 0.969 Footage 43.30 4033' 62.10 Ss (ppb Eq) C-1 C-5i AK-AM-0901938178 TIH PV 24 hr Max 68.0 Weight Hours C-3 Intermediate Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.50 180 160.0 Hycalog PDC LSND 4.6 9302' 13335'20 13335' Depth in / out Mud Type Lst Hydrill Type Average Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 675, Periscope 675, Telescope 675 API FL Chromatograph (ppm) 12 12.0 2677' 9302' WOB Evermar 100% Gas In Air =10,000 Units Connection 3 2663' 160' Condition 5-2-WT-N-X-In-BT-PR Bit # 2 6.0 12.25 Hycalog PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 22 Customer: Well: Area: Location: Rig: SP31-W7 ENI PETROLEUM SPY ISLAND NORTH SLOPE 2-3-CT-A-X-I-WT-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 19-Jan-2015 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l 15500 Continue to test BOP. Make up mule shoe, RIH with 4.5" drill pipe to 3795' POOH and rack back. Rig up and test rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Continue TIH with 4.5" drill pipe, changed over to 5" drill pipe at 10,710' MD, tag float collar at 13234' MD, displaced Density (ppg) out (sec/qt) Viscosity 2331 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Morning Report Report # 23 Customer: Well: Area: Location: Rig: SP31-W7 21-Jan-2015 12:00 AM AK-AM-0901938178 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 165.0 Cor Solids Avg Min YP Max ECD (ppg) Tools Xceed 675, Periscope 675, Telescope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 13335'6.0 MWD Summary 96% %Mud Type fazepro NA Ratio Mud Data Depth 66/34 Size 160'Conductor Evermar 13335' WOB Hycalog PDC TFA Condition 3 12.25 9302' 4 13335' 43.30 2-3-CT-A-X-I-WT-TD test. No gas was observed, lag had not reached surface from the 20' drilled as of midnight. 2663' 100% Gas In Air =10,000 Units Connection Comments Surface Background Trip (max) 0Average Mud (lb/bbl) ml/30min 3.64 2.80 12.0 (lb/100ft 2) 9.25 Type 15 Smith PDC C-3 Bit # 0 Lst 00 C-4i C-4n Chromatograph (ppm) 0 0 0 Intermediate Cement C-1 C-5i Sh Siltst Perform FIT PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Oil / Water Casing Summary Lithology (%) 0.969 11 46 4033' 8.75 0.969 Footage 40.0 (current) Units* Clyst Ss Cht Silt API FL Depth Avg to 13335' Current 1.3 0.0 24 Hour Progress: 108 SPP (psi) Max @ ft 13341' Date: Time: 0 13335' 13355' 20' Lime Tuff Gvl C-5n Yesterday's Depth: Current Depth: 457 Alkal Coal Gallons/stroke L-80 0 0 0 Minimum Depth 13 3/8" Maximum in 0 0 0 0 0 0 0 00 C-2 Gas Summary 907-685-0772 Unit Phone: 0 Kori Jo Plowman Set At Size 178.9 X-65 Grade Depth in / out L-80 13320' Bit Type RPM 180.0 Hours Hydrill Report By: 20.00" 9 5/8" Logging Engineers: Kori Jo Plowman/ Paul Kalenuik (max) (current) BTC Cly . . * 24 hr Recap:Drilling f/13355' t/ 14164'MD, 3515'TVD, @465gpm, 80-170rpm, ECD's=10.73-10.96ppg, Drilling f/14164' t/ Density (ppg) out (sec/qt) Viscosity 2375 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Morning Report Report # 24 Customer: Well: Area: Location: Rig: SP31-W7 21-Jan-2015 12:00 AM AK-AM-0901938178ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 408.0 11.10 Cor Solids 10.73 Avg Min YP MaxECD (ppg)Tools Xceed 675, Periscope 675, Telescope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 13335'6.0 9.76MWD Summary 96% %Mud Type fazepro NA Ratio Mud Data Depth 66/34 Size 160'ConductorEvermar 13335' WOB Hycalog PDC TFA Condition 3 12.25 9302' 4 13335' 43.30 2-3-CT-A-X-I-WT-TD sandstone with trace shale. 2663' 100% Gas In Air=10,000 UnitsConnection Comments Surface Background Trip (max) 96Average Mud (lb/bbl)ml/30min 3.642.80 12.0 (lb/100ft2) 9.25 Type 15 Smith PDC C-3 Bit # 0 Lst 100 00 C-4i C-4n Chromatograph (ppm) 1198 899 77 Intermediate Cement C-1 C-5i ShSiltst Drill 8 3/4" Production PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Oil / Water Casing Summary Lithology (%) 0.969 1146 4033' 8.75 0.969 Footage 40.0 (current) Units* ClystSsChtSilt API FL Depth Avg to13335' Current 77.773.0 24 Hour Progress: 110 SPP (psi) Max @ ft 14993' Date: Time: 23 13355' 15005' 1650' Lime TuffGvl C-5n Yesterday's Depth: Current Depth: 461 Alkal Coal Gallons/stroke L-80 14995'MD, 3519'TVD, @465gpm, 140rpm, ECD's=10.74-10.80ppg, Max gas1039 units at 14227'MD. Cuttings consist of 100% 501 14227' 43 411 190 14584'Minimum Depth 13 3/8" Maximum in 5 80 184 0 381 54 0 12612 552443 C-2 Gas Summary 1098 907-685-0772Unit Phone: 102 Rebecca Mulkey Set AtSize 178.9 X-65 Grade Depth in / out L-8013320' Bit Type RPM 180.0 Hours Hydrill Report By: 20.00" 9 5/8" Logging Engineers:Kori Jo Plowman/ Rebecca Mulkey (max)(current) BTC Cly . . * 24 hr Recap: Cly Hydrill Report By: 20.00" 9 5/8" Logging Engineers:Kori Jo Plowman/ Rebecca Mulkey (max)(current) BTC Bit Type RPM 180.0 Hours 907-685-0772Unit Phone: 112 Rebecca Mulkey Set AtSize 178.9 X-65 Grade 130 C-2 Gas Summary 968 223 372 4 355 110225 5 6 4792 16512'Minimum Depth 13 3/8" Maximum in 5 15252' 0 382 215 16869'MD, 3487'TVD, @465gpm, 155rpm, ECD's=11.11-11.15ppg. Max gas: 968 units at 15252'MD. Cuttings consist of 100% 310 461 Alkal Coal Gallons/stroke L-80 0 15005' 16963' 1958' Lime TuffGvl C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 109 SPP (psi) Max @ ft 14993' Date: Time: API FL Depth Avg to13335' Current 98.6392.0 (current) Units* ClystSsChtSilt Lithology (%) 0.969 1344 4033' 8.75 0.969 Footage 40.0 Depth in / out Drill 8 3/4" Production PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Oil / Water 4 Intermediate Cement C-1 C-5i ShSiltst C-4n Chromatograph (ppm) 1124 756 69222 C-4iC-3 Bit # 138 Lst 100 12.0 (lb/100ft2) 9.20 Type 14 Smith PDC Casing Summary L-8013320' Mud (lb/bbl)ml/30min 3.772.90 (max) 560Average Comments Surface 410Background Trip sandstone with trace shale. 2663' 100% Gas In Air=10,000 UnitsConnection 3 12.25 9302' 4 13335' 43.30 2-3-CT-A-X-I-WT-TD Size 160'ConductorEvermar 13335' WOB Hycalog PDC TFA Condition MWD Summary 96% %Mud Type fazepro NA Ratio Mud Data Depth 2.2 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 16590'6.2 5.44 11.40 Cor Solids 6.06 Avg Min YP MaxECD (ppg) Tools Xceed 675, Periscope 675, Telescope 675 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 479.7 Morning Report Report # 25 Customer: Well: Area: Location: Rig: SP31-W7 22-Jan-2015 12:00 AM AK-AM-0901938178 2497 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Drilling f/14995' t/ 15750'MD, 3510'TVD, @465gpm, 160-180rpm, ECD's=10.96-11.07ppg, Drilling f/15750' t/ Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 2592 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Morning Report Report # 26 Customer: Well: Area: Location: Rig: SP31-W7 23-Jan-2015 12:00 AM AK-AM-0901938178ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 413.0 11.67 Cor Solids 11.01 Avg Min YP MaxECD (ppg) Tools Xceed 675, Periscope 675, Telescope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 18600'6.5 5.96 Mud Type fazepro NA Ratio Mud Data Depth 67/33 Size 160'ConductorEvermar 13335' WOB Hycalog PDC TFA Condition 4 13335' 43.30 2-3-CT-A-X-I-WT-TD Drilling f/16869' t/17879'MD, 3482'TVD, @465gpm, 160-180rpm, ECD's=11.10-11.39ppg, Drilling f/17879' t/ Trip sandstone with trace shale. 2663' 100% Gas In Air=10,000 UnitsConnection115Background(max) 395Average Mud (lb/bbl)ml/30min 3.903.009.25 Type 13 Smith PDC Casing Summary L-8013320' 3 12.25 9302' C-3 Bit # 133 Lst 100 66201 C-4i Chromatograph (ppm) 1167 752 11 Intermediate Cement C-1 C-5i ShSiltst Drill 8 3/4" Production PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Oil / Water Lithology (%) 0.969 1444 4033' 8.75 0.969 Footage 40.0 Depth in / out ClystSsChtSilt C-4n Depth Avg to13335' Current 86.6305.0 MWD Summary Max @ ft Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 109 SPP (psi) 12.0 (lb/100ft2) Comments 16963' 18753' 1790' Lime TuffGvl Surface 96% % 461 Alkal Coal Gallons/stroke L-80 18739'MD, 3486'TVD, @465gpm, 160-180rpm, ECD's=11.28-11.38ppg, Max gas: 810 units at 17186'MD. Cuttings consist of 100% 341 17186' 16 448 259 1017485'Minimum Depth 13 3/8" Maximum in 3 8 44004 191 458 10 263 98399 1043 C-2 Gas Summary 810 907-685-0772Unit Phone: 125 Rebecca Mulkey Set AtSize 178.9 X-65 Grade Bit Type RPM 180.0 Hours (current) Units* Cly Hydrill Report By: 20.00" 9 5/8" Logging Engineers:Kori Jo Plowman/ Rebecca Mulkey (max)(current) BTC . . * 24 hr Recap: Cly Hydrill Report By: 20.00" 9 5/8" Logging Engineers:Kori Jo Plowman/ Rebecca Mulkey (max)(current) BTC Bit Type RPM 180.0 Hours 907-685-0772Unit Phone: 82 Rebecca Mulkey Set AtSize 178.9 X-65 Grade Gas Summary 859 (current) Units* 103892 020 C-2 0 46577 196 019304'Minimum Depth 13 3/8" Maximum in 3 20481' 0 288 195 L-80 20795'MD, 3507'TVD, @475gpm, 160-180rpm, ECD's=11.67-11.72ppg, Cuttings consist of 100% sandstone with trace shale. 305 % 465 Alkal Coal Gallons/stroke Comments 18753' 20889' 2136' Lime TuffGvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 110 SPP (psi) Depth Avg to13335' Current 97.1243.0 MWD Summary ClystSsChtSilt C-4n Lithology (%) 0.969 1344 4033' 8.75 0.969 Footage 40.0 Depth in / out Drill 8 3/4" Production PV cP 68.0 Weight Flow In (gpm) Flow In (spm) 0 Intermediate Cement C-1 C-5i ShSiltst 168 C-4i 168 294 0 Lst 100 Chromatograph (ppm) 697 399 Type 12 Smith PDC Casing Summary L-8013320' 3 12.25 9302' Bit # Mud (lb/bbl)ml/30min 3.642.80 (max) 337Average 215Background 2663' 100% Gas In Air=10,000 UnitsConnection C-3 Drilling f/18739' t/19655'MD, 3493'TVD, @475gpm, 160-180rpm, ECD's=11.30-11.70ppg, Drilling f/19655' t/ Trip 4 13335' 43.30 2-3-CT-A-X-I-WT-TD12.0 Size 160'ConductorEvermar 13335' WOB Hycalog PDC TFA Condition Mud Type fazepro NA Ratio Mud Data Depth 69/319.25 Oil / Water (lb/100ft2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 20662'6.5 11.11 11.81 Cor Solids 11.44 Avg Min YP MaxECD (ppg) Tools Xceed 675, Periscope 675, Telescope 675 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 516.9 Morning Report Report # 27 Customer: Well: Area: Location: Rig: SP31-W7 24-Jan-2015 12:00 AM AK-AM-0901938178 2867 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Max @ ft 20711' 125 54 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 158 68 12:00 AM AK-AM-0901938178 1880 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Max @ ft 22393'518.3 Morning Report Report # 28 Customer: Well: Area: Location: Rig: SP31-W7 25-Jan-2015 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 11.81 Cor Solids 11.44 Avg Min YP MaxECD (ppg) Tools Xceed 675, Periscope 675, Telescope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22454'10.0 11.11 Mud Type fazepro NA Ratio Mud Data Depth 69/319.25 Oil / Water (lb/100ft2) 13335' WOB Hycalog PDC TFA Condition 2-3-CT-A-X-I-WT-TD 9119' 12.0 Size 160'ConductorEvermar Drilling f/20795' t/22193'MD, 3461'TVD, @475gpm, 160rpm, ECD's=11.84-11.90ppg, Max gas=1117-1141units. Trip t/21700' @360gpm, ECD=11.03ppg Cuttings consisted of 70% sandstone and 30% shale. 4 13335' 115.60 100% Gas In Air=10,000 UnitsConnection C-3 22Background (max) 283Average Mud (lb/bbl)ml/30min 3.062.3515 Smith PDC Casing Summary L-8013320' 3 12.25 9302' Bit # 2663' Chromatograph (ppm) 794 370 196 C-4i 197 328 0 0 Intermediate Cement C-1 C-5i ShSiltst Lst BROOH PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Lithology (%) 0.969 1245 4033' 8.75 0.969 Footage 40.0 Depth in / out ClystSsChtSilt 70 22454' Avg to13335' Current 70.1 MWD Summary Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 83 SPP (psi) Comments 20889' 22454' 1565' Lime TuffGvl Surface 96% % 351 Alkal Coal Gallons/stroke L-80 Drilling f/22193' t/ 22454'MD, 3438'TVD, @475gpm, 160rpm, ECD's=11.64ppg, Circ. and condition as per K&M BROOH f/22453' 354 21607' 0 299 219 22192'Minimum Depth 13 3/8" Maximum in 5 Depth 0 37896 192 131271 019 C-2 0 C-4n Gas Summary 1141 30(current) Units* 907-685-0772Unit Phone: 86 Rebecca Mulkey Set AtSize 178.9 X-65 Grade Bit Type RPM 22454' 180.0 Hours 43.30 Cly Hydrill Report By: 20.00" 9 5/8" Logging Engineers:Kori Jo Plowman/ Rebecca Mulkey (max)(current) BTC . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers:Kori Jo Plowman/ Rebecca Mulkey (max)(current) BTC 22454' 180.0 Hours 43.30 Cly Hydrill 907-685-0772Unit Phone:Rebecca Mulkey Set AtSize 178.9 X-65 Grade Gas Summary 59 (current) Units*C-2 C-4n Minimum Depth 13 3/8" Maximum in 0 Depth L-80 400gpm, 140rpm, ECD=10.67-11.23ppg max gas of 59 units. 6 % 410 Alkal Coal Gallons/stroke Comments 22454' 22454' 0' Lime TuffGvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 97 SPP (psi) 22454' Avg to13335' Current MWD Summary Ss Cht Silt Lithology (%) 0.969 1245 4033' 8.75 0.969 Footage 40.0 Depth in / out BROOH PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Intermediate Cement C-1 C-5i ShSiltst LstClyst C-4i Chromatograph (ppm) 13320' 3 12.25 9302' Bit # 2663' Bit Type Mud (lb/bbl)ml/30min 2.862.20 (max) Average 5Background 100% Gas In Air=10,000 UnitsConnection C-3 BROOH f/21700' t/16689' @400gpm, monitor well - light breathing observed. BROOH f/16689' t/14939' @370- Trip 4 13335' 115.60 9119' 12.0 Size 160'ConductorEvermar Smith PDC Casing Summary L-80 13335' WOB Hycalog PDC TFA Condition 2-3-CT-A-X-I-WT-TD 15 RPM Mud Type fazepro NA Ratio Mud Data Depth 69/319.25 Oil / Water (lb/100ft2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22454'7.3 11.11 11.81 Cor Solids 11.44 Avg Min YP MaxECD (ppg) Tools Xceed 675, Periscope 675, Telescope 675 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 29 Customer: Well: Area: Location: Rig: SP31-W7 26-Jan-2015 12:00 AM AK-AM-0901938178 2008 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Max @ ft Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 12:00 AM AK-AM-0901938178 2008 ROP ROP (ft/hr) M. Ross/O. Amend 24 hr Max Max @ ft Morning Report Report # 30 Customer: Well: Area: Location: Rig: SP31-W7 27-Jan-2015 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 11.81 Cor Solids 11.44 Avg Min YP MaxECD (ppg) Tools Xceed 675, Periscope 675, Telescope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22454'7.6 11.11 Mud Type fazepro NA Ratio Mud Data Depth 69/319.45 Oil / Water (lb/100ft2) 13335' WOB Hycalog PDC TFA Condition 2-3-CT-A-X-I-WT-TD 15 RPM 9119' 12.0 Size 160'ConductorEvermar Smith PDC Casing Summary L-80 Con't BROOH f/14,939' @ 400 gpm, 140 rpm, & 1900 psi to 13,320'. Observed very light breathing. BROOH inside 9- Trip while circ. 6 bph dynamic loss rate. C/O Saver sub for 4.5" DP. .5 bbl loss f/trip tank. Service rig. BROOH f/10,713' to 8,800' at 4 13335' 115.60 465 gpm, 120 rpm & 1980 psi. Max gas of 15 units. 100% Gas In Air=10,000 UnitsConnection Average 1Background Mud (lb/bbl)ml/30min 2.862.20 (max) C-3 2663' Bit Type Chromatograph (ppm) Cement C-1 C-5i ShSiltst LstClyst C-4i BROOH PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 46 4033' 8.75 0.969 Footage 40.0 Depth in / out 13320' 12.25 9302' Ss Cht Silt Avg to13335' Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 97 SPP (psi) 22454' 22454' 0' Lime TuffGvl Surface 96% Date: % 50 Alkal Coal Gallons/stroke 5/8" csg to 10,713'. Increase density f/9.3 ppg to 9.45 ppg per K & M while circ x 2 BU. Con't circ & wt up to 9.45 ppg. 22 bbl loss 4 Minimum Depth 13 3/8" Maximum in 0 Lithology (%) 3 Bit # Depth 22454' 0.969 12 C-2 C-4n Gas Summary 15 (current) Units* 907-685-0772Unit Phone:Rebecca Mulkey Set AtSize 178.9 X-65 Grade 22454' 180.0 Hours 43.30 Cly Hydrill L-80 Comments Intermediate Report By: 20.00" 9 5/8" Logging Engineers:Kori Jo Plowman/ Rebecca Mulkey (max)(current) BTC . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 12:00 AM AK-AM-0901938178 18 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Max @ ft Morning Report Report # 31 Customer: Well: Area: Location: Rig: SP31-W7 28-Jan-2015 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP MaxECD (ppg)Tools Xceed 675, Periscope 675, Telescope 675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22454'7.6 Mud Type fazepro NA Ratio Mud Data Depth 69/319.45 Oil / Water (lb/100ft2) 13335' WOB Hycalog PDC TFA Condition 2-3-CT-A-X-I-WT-TD 14 RPM 46 12.0 Size 160'ConductorEvermar Smith PDC Casing Summary L-80 Continue BROOH inside 9-5/8" csg f/8,800' to 3,875' at 465 gpm, 120 rpm & 1600 to 1500 psi. ECD: 10.13 ppg. AM Trip stds 4.5" DP to 364'. 4 bbl loss. L/D BHA #5. 4 13335' 115.60 100% Gas In Air=10,000 UnitsConnection Average 0Background Mud (lb/bbl)ml/30min 2.862.20 (max) C-3 Bit Type 9119' Chromatograph (ppm) Cement C-1 C-5i ShSiltst LstClyst C-4i L\D BHA PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.969 Footage 40.0 Depth in / out 13320' 12.25 9302' 22454' 2663' Ss Cht Silt Avg to13335' Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) 22454' 22454' 0' Lime TuffGvl Surface 96% Date: % 0 Alkal Coal Gallons/stroke BROOH loss: 13 bbls. BROOH f/3,875' to 2,071' at 465 gpm, 120 rpm & 1030 psi. 1 bbl loss. CBU x 2 same rate to 1,986'. L/D 17 0 Minimum Depth 13 3/8" Maximum in 0 Lithology (%) 3 Bit # Depth 22454' 0.969 12 C-2 C-4n Gas Summary 1 (current) Units* 907-685-0772Unit Phone:Rebecca Mulkey Set AtSize 178.9 X-65 Grade 180.0 Hours 43.30 Cly Hydrill L-80 Comments Intermediate 4033' Report By: 20.00" 9 5/8" Logging Engineers:Kori Jo Plowman/ Rebecca Mulkey (max)(current) BTC . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers:Kori Jo Plowman/ Rebecca Mulkey (max)(current) BTC 180.0 Hours 43.30 Cly Hydrill L-80 Comments Intermediate 4033' 907-685-0772Unit Phone:Rebecca Mulkey Set AtSize 178.9 X-65 Grade Gas Summary 1 (current) Units*C-2 C-4n Depth 0.969 11 Minimum Depth 13 3/8" Maximum in 0 Lithology (%) 3 Bit # equip. C/O bails. Monitor w/trip tank: 5 bbl loss. RIH 5.5" slotted liner to 3,714'. Continue RIH 5.5" liner to R/D Volant & GBR equip. 0 % 0 Alkal Coal Gallons/stroke 22454' 22454' 0' Lime TuffGvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) Avg to Current MWD Summary Ss Cht Silt 8.75 0.969 Footage 40.0 Depth in / out 13320' 12.25 9302' 22454' 2663' RIH 5.5" liner PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i ShSiltst LstClyst C-4i 9119' Chromatograph (ppm) Mud (lb/bbl)ml/30min 2.862.20 (max) C-3 Average 0Background 100% Gas In Air=10,000 UnitsConnection C/O Saver sub on top drive. Monitor well w/trip tank. M/U Volant tool. Lubricate drawworks, top drive & travelling Trip M/U Seal bore assy, MWD tool & liner hanger & allow Pal MIx to set f/30 min. 4 13335' 115.60 12.0 Size 160'ConductorEvermar Smith PDC Casing Summary L-80 Bit Type 13335' WOB Hycalog PDC TFA Condition 2-3-CT-A-X-I-WT-TD 15 RPM 46 Mud Type fazepro NA Ratio Mud Data Depth 69/319.45 Oil / Water (lb/100ft2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22454'7.6 Cor Solids Avg Min YP MaxECD (ppg)Tools ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 32 Customer: Well: Area: Location: Rig: SP31-W7 29-Jan-2015 12:00 AM AK-AM-0901938178 18 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Max @ ft Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 12:00 AM AK-AM-0901938178 18 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Max @ ft Morning Report Report # 33 Customer: Well: Area: Location: Rig: SP31-W7 30-Jan-2015 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP Max ECD (ppg) Tools 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22454'7.6 Mud Type fazepro NA Ratio Mud Data Depth 69/31 9.45 Oil / Water (lb/100ft 2) 13335' WOB Hycalog PDC TFA Condition 2-3-CT-A-X-I-WT-TD 13 RPM 47 12.0 Size 160'Conductor Evermar Smith PDC Casing Summary L-80 Bit Type C/O bails at 8,684'. Shallow test MWD tool at 8,924'. OK. RIH w/5" DP, rabbiting f/derrick f/8,924' to 9,391'. Fix rabbit Trip top. Drop setting ball. Pump at 4 bpm to 1 bpm. Ball seated at 2992 stks (Calc: 2323 stks). Set packer & test 1500 psi f/15 min. OK. 4 13335' 115.60 Liner shoe at 21,889'. TOL: 13,165'. POH 3 stds to 12,964'. PJSM. Cut & slip drill line. Adjust drawworks brakes. No PM tour loss. 100% Gas In Air =10,000 Units Connection Average 0Background Mud (lb/bbl) ml/30min 3.51 2.70 (max) C-3 9119' Chromatograph (ppm) Cement C-1 C-5i Sh Siltst Lst Clyst C-4i - - Cut & slip drill line PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.969 Footage 40.0 Depth in / out 13320' 12.25 9302' 22454' 2663' Ss Cht Silt Avg to Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) 22454' 22454' 0' Lime Tuff Gvl Surface 96% Date: % 0 Alkal Coal Gallons/stroke 0 Minimum Depth 13 3/8" Maximum in 0 Lithology (%) 3 Bit # Depth 0.969 12 C-2 C-4n Gas Summary 1 (current) Units* 907-685-0772 Unit Phone: Gregory Dellner Set At Size 178.9 X-65 Grade 180.0 Hours 43.30 Cly Hydrill L-80 Comments Intermediate 4033' Report By: 20.00" 9 5/8" Logging Engineers: Kori Jo Plowman/ Gregory Dellner (max) (current) BTC . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers:Kori Jo Plowman/ Gregory Dellner (max)(current) BTC 180.0 Hours 43.30 Cly Hydrill L-80 Comments Intermediate 4033' 907-685-0772Unit Phone:Gregory Dellner Set AtSize 178.9 X-65 Grade Gas Summary 1 (current) Units*C-2 C-4n Depth 0.969 12 Minimum Depth 13 3/8" Maximum in 0 Lithology (%) 3 Bit # 0 % 233 Alkal Coal Gallons/stroke 22454' 22454' 0' Lime TuffGvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 55 SPP (psi) Avg to Current MWD Summary Ss Cht Silt 8.75 0.969 Footage 40.0 Depth in / out 13320' 12.25 9302' 22454' 2663' - - Orient whipstock PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i ShSiltst LstClyst C-4i 9119' Chromatograph (ppm) Mud (lb/bbl)ml/30min 3.252.50 (max) C-3 Average 0Background 100% Gas In Air=10,000 UnitsConnection POH f/12,979'. L/D liner running tool & slimhole MWD. Clean rig floor. Mobilize & M/U Whipstock assembly to 56'. AM Trip PM trip loss. Orient whipstock 47 deg right at 350 gpm & 1050 psi. Drop dart for locking swivel, pump at 5.5 bpm & 400 psi. 4 13335' 115.60 12.0 Size 160'ConductorEvermar Smith PDC Casing Summary L-80 Bit Type 13335' WOB Hycalog PDC TFA Condition 2-3-CT-A-X-I-WT-TD 13 RPM 46 Mud Type fazepro NA Ratio Mud Data Depth 69/319.40 Oil / Water (lb/100ft2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22454'7.6 Cor Solids Avg Min YP MaxECD (ppg) Tools ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 34 Customer: Well: Area: Location: Rig: SP31-W7 31-Jan-2015 12:00 AM AK-AM-0901938178 400 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Max @ ft Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers: Paul Kalenuik/ Gregory Dellner (max) (current) BTC 2318 0 Hours Cly Hydrill L-80 Comments Intermediate 907-685-0772 Unit Phone: 0 Gregory Dellner Set At Size 178.9 X-65 Grade Gas Summary 19 (current) Units* C-2 0 C-4n 0 619 2 13124' Depth 0.969 12 49 Minimum Depth 13 3/8" Maximum in 5 Lithology (%) 4 Bit # 13152' 0 5 0 9 % 0 Alkal Coal Gallons/stroke 13122' 13161' 39' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) Avg to Current 11.7 N/A MWD Summary Ss Cht Silt 8.75 0.902 Footage 40.0 Depth in / out 13320' 8.75 13335' 2663' - - POH Mill Assembly PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 1 4 0 0 Chromatograph (ppm) 17 11 Mud (lb/bbl) ml/30min 3.38 2.60 (max) 3 C-3 Average 0Background 100% Gas In Air =10,000 Units Connection 11.1 ppg dry job. POH elevators to 2,545'. No PM tour loss. through window, no pump. Rack back 1 std. No AM tour loss. PumpOOH f/13,093' to 3,475' at 100 gpm & 60 psi. Pump 20 bbl Pump down dart. Seat at 2200 stks. PSI to 2700 to shear. Verify swivel locked. Mill 9 5/8" csg at 500 gpm & 2000 psi. Trip sweeps (101 FV) at 13,131', 13,137', & 13,157'. Rotate & reciprocate to 13,093'. No rotation through window, pump only. Work 5 13122' Size 160'Conductor Evermar Smith PDC Casing Summary L-80 Bit Type 22454' WOB Smith PDC TFA Condition 12 RPM 46 Mud Type fazepro NA Ratio Mud Data Depth 69/31 9.30 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 13165'7.6 Cor Solids Avg Min YP Max ECD (ppg) Tools ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 35.3 Morning Report Report # 35 Customer: Well: Area: Location: Rig: SP31-W7 1-Feb-2015 12:00 AM AK-AM-0901938178 0 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Max @ ft 13122' 0 01 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers: Paul Kalenuik/ Gregory Dellner (max) (current) BTC 160.0 Hours 71.20 Cly Hydrill L-80 Comments Intermediate 9119' 907-685-0772 Unit Phone: Gregory Dellner Set At Size 178.9 X-65 Grade Gas Summary 1 (current) Units* C-2 C-4n Depth 0.969 12 Minimum Depth 13 3/8" Maximum in 0 Lithology (%) 4 Bit # 0 % 0 Alkal Coal Gallons/stroke 13165' 13165' 0' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) Avg to Current MWD Summary Ss Cht Silt 8.75 0.902 Footage 40.0 Depth in / out 13122' 8.75 13335' 2663' - - RIH BHA #7 PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i Chromatograph (ppm) Mud (lb/bbl) ml/30min 3.38 2.60 (max) C-3 Average 0Background 100% Gas In Air =10,000 Units Connection Continue POH 2,545' to 119'. L/D milling BHA. Clean rig floor. Flush stack. Remove wear ring & install test plug. Trip equip. P/U 4.5" DP f/364" to 1,780' f/pipe shed. Test MWD at 460 gpm & 900 psi. OK. RIH to 5,585', fill pipe every 20 stds. 5 13165' 10.0 Size 160'Conductor Evermar Smith PDC Casing Summary L-80 Bit Type 22454' WOB Smith PDC TFA Condition 0-1-CT-S-X-IN-NO-TD 12 RPM 45 Mud Type fazepro NA Ratio Mud Data Depth 69/31 9.25 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 13165'7.6 Cor Solids Avg Min YP Max ECD (ppg) Tools ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 36 Customer: Well: Area: Location: Rig: SP31-W7 2-Feb-2015 12:00 AM AK-AM-0901938178 0 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Max @ ft Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers: Paul Kalenuik/ Gregory Dellner (max) (current) BTC 47027 0 Hours Cly Hydrill L-80 Comments Intermediate 907-685-0772 Unit Phone: 24 Gregory Dellner Set At Size 178.9 X-65 Grade Gas Summary 347 20 (current) Units* C-2 0 C-4n 0 14314 88 13165' Depth 13599' 0.969 12 55 Minimum Depth 13 3/8" Maximum in 3 Lithology (%) 4 Bit # 13287' 0 103 43 120 % 507 Alkal Coal Gallons/stroke 13165' 13599' 434' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 120 SPP (psi) Avg to 13165' Current 106.5 0.0 MWD Summary Ss Cht Silt 30 50 8.75 0.902 Footage 40.0 Depth in / out 13320' 8.75 13335' 2663' - - BROOH L1 PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 37 95 0 0 Chromatograph (ppm) 381 256 Mud (lb/bbl) ml/30min 3.12 2.40 (max) 115 C-3 Average 7Background 100% Gas In Air =10,000 Units Connection to 13,350'. RIH 4.5" DP f/5,585' to 10,426'. C/O to 5" equip. RIH 5" DP to 13,044". Fill pipe every 20 stds. Wash through window Trip Drill f/13,414' to 13,599' MD/3,495' TVD at 550 gpm, 2650 psi, 180-190 rpm. Monitor well. Static. Downlinkes per SLB DD. BROOH 5 13122' Size 160'Conductor Evermar Smith PDC Casing Summary L-80 Bit Type 22454' WOB Smith PDC TFA Condition 12 RPM 46 Mud Type fazepro NA Ratio Mud Data Depth 69/31 9.30 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 13508'7.6 10.06 11.17 Cor Solids 10.28 Avg Min YP Max ECD (ppg) Tools Xceed675 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 252.4 Morning Report Report # 37 Customer: Well: Area: Location: Rig: SP31-W7 3-Feb-2015 12:00 AM AK-AM-0901938178 2751 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Max @ ft 13485' 18 10 42 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 122 67 234 12:00 AM AK-AM-0901938178 3250 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Max @ ft 14924'443.0 Morning Report Report # 38 Customer: Well: Area: Location: Rig: SP31-W7 4-Feb-2015 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 11.34 Cor Solids 10.92 Avg Min YP Max ECD (ppg) Tools Xceed675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 14714'7.7 10.40 Mud Type fazepro NA Ratio Mud Data Depth 69/31 9.30 Oil / Water (lb/100ft 2) 22454' WOB Smith PDC TFA Condition 13 RPM 44 Size 160'Conductor Evermar Smith PDC Casing Summary L-80 Bit Type BROOH f/13,580' to 13,510'. PumpOOH to 13,324'. Open hole sidetrack. KOP: 13,350'. Drill to 13,755' MD/3,510' TVD Trip 5 13122' 100% Gas In Air =10,000 Units Connection Average 5Background Mud (lb/bbl) ml/30min 2.60 2.00 (max) 564 C-3 Chromatograph (ppm) 1280 937 212 441 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i - - Drill 8.75" Lateral PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13320' 8.75 13335' 2663' Ss Cht Silt 100 Avg to 13165' Current 285.0 91.0 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 130 SPP (psi) 13350' 15188' 1838' Lime Tuff Gvl Surface 96% Date: % 552 Alkal Coal Gallons/stroke 519 14866' 0 469 250 Minimum Depth 13 3/8" Maximum in 2 Lithology (%) 4 Bit # 51294 441 13527' Depth 13599' 0.969 11 45 C-2 0 C-4n 0 Gas Summary 1220 (current) Units* 907-685-0772 Unit Phone: 133 Gregory Dellner Set At Size 178.9 X-65 Grade Hours Cly Hydrill L-80 Comments Intermediate Report By: 20.00" 9 5/8" Logging Engineers: Paul Kalenuik/ Gregory Dellner (max) (current) BTC 137402 0 . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers: Paul Kalenuik/ Gregory Dellner (max) (current) BTC 15342 0 Hours Cly Hydrill L-80 Comments Intermediate 907-685-0772 Unit Phone: 145 Gregory Dellner Set At Size 178.9 X-65 Grade Gas Summary 971 (current) Units* C-2 0 C-4n 0 49498 402 17088' Depth Present 0.969 12 16 Minimum Depth 13 3/8" Maximum in 3 Lithology (%) 4 Bit # 16240' 0 472 280 461 % 549 Alkal Coal Gallons/stroke 15188' 17436' 2248' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 131 SPP (psi) Avg to 13165' Current 282.0 174.0 MWD Summary Ss Cht Silt 100 8.75 0.902 Footage 40.0 Depth in / out 13320' 8.75 13335' 2663' - - Drill 8.75" Lateral PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 259 461 0 3 Chromatograph (ppm) 1253 831 Mud (lb/bbl) ml/30min 2.73 2.10 (max) 581 C-3 Average 40 Background 100% Gas In Air =10,000 Units Connection Drill f/15,094' to 16,307' MD/3,495' TVD at 550 gpm, 3340 psi, 160 rpm. Monitor well. Static. Drill f/16,307' to 16,681 Trip 5 13122' Size 160'Conductor Evermar Smith PDC Casing Summary L-80 Bit Type 22454' WOB Smith PDC TFA Condition 13 RPM 45 Mud Type fazepro NA Ratio Mud Data Depth 69/31 9.30 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 17148'7.9 10.97 11.52 Cor Solids 11.26 Avg Min YP Max ECD (ppg) Tools Xceed675 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 417.0 Morning Report Report # 39 Customer: Well: Area: Location: Rig: SP31-W7 5-Feb-2015 12:00 AM AK-AM-0901938178 3500 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Max @ ft 16311' 181 96 269 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 149 77 204 12:00 AM AK-AM-0901938178 3600 ROP ROP (ft/hr) J. Keener/O. Amend 24 hr Max Max @ ft 17822'414.0 Morning Report Report # 40 Customer: Well: Area: Location: Rig: SP31-W7 6-Feb-2015 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 11.90 Cor Solids 11.81 Avg Min YP Max ECD (ppg) Tools Xceed675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 18948'7.7 11.04 Mud Type fazepro NA Ratio Mud Data Depth 70/30 9.30 Oil / Water (lb/100ft 2) 22454' WOB Smith PDC TFA Condition 14 RPM 48 Size 160'Conductor Evermar Smith PDC Casing Summary L-80 Bit Type Drill f/17,429' to 18,308' MD/3,519' TVD at 550 gpm, 3490 psi, 160 rpm. Monitor well. Static. Drill f/18,308' to 19,296' Trip 5 13122' 100% Gas In Air =10,000 Units Connection Average 5Background Mud (lb/bbl) ml/30min 2.93 2.25 (max) 379 C-3 Chromatograph (ppm) 1058 620 195 416 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i - - Drill 8.75" Lateral PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13320' 8.75 13335' 2663' Ss Cht Silt 100 Avg to 13165' Current 256.0 12.0 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 129 SPP (psi) 17436' 19378' 1942' Lime Tuff Gvl Surface 96% Date: % 541 Alkal Coal Gallons/stroke 320 17752' 0 403 256 Minimum Depth 13 3/8" Maximum in 5 Lithology (%) 4 Bit # 32350 264 18943' Depth Present 0.969 13 27 C-2 0 C-4n 0 Gas Summary 800 (current) Units* 907-685-0772 Unit Phone: 124 Gregory Dellner Set At Size 178.9 X-65 Grade Hours Cly Hydrill L-80 Comments Intermediate Report By: 20.00" 9 5/8" Logging Engineers: Paul Kalenuik/ Gregory Dellner (max) (current) BTC 91973 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 178 80 235 12:00 AM AK-AM-0901938178 3600 ROP ROP (ft/hr) J. Keener/R. Wimmer 24 hr Max Max @ ft 20521'422.5 Morning Report Report # 41 Customer: Well: Area: Location: Rig: SP31-W7 7-Feb-2015 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 12.28 Cor Solids 11.92 Avg Min YP Max ECD (ppg) Tools Xceed675 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 21085'7.6 11.62 Mud Type fazepro NA Ratio Mud Data Depth 69/31 9.25 Oil / Water (lb/100ft 2) 22454' WOB Smith PDC TFA Condition 18 RPM 50 Size 160'Conductor Evermar Smith PDC Casing Summary L-80 Bit Type Drill f/19,296' to 20,471' MD/3,488' TVD at 550 gpm, 3860 psi, 160 rpm. Monitor well. Static. Noticed losses at Trip Monitor well. Static. PM tour loss: 20 bbls. 5 13122' 100% Gas In Air =10,000 Units Connection Average 5Background Mud (lb/bbl) ml/30min 3.12 2.40 (max) 390 C-3 Chromatograph (ppm) 390 581 233 435 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i - - Drill 8.75" Lateral PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13320' 8.75 13335' 2663' Ss Cht Silt 100 Avg to 13165' Current 253.0 145.0 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 123 SPP (psi) 19378' 21443' 2065' Lime Tuff Gvl Surface 96% Date: % 516 Alkal Coal Gallons/stroke 386 21232' 0 426 299 Minimum Depth 13 3/8" Maximum in 3 Lithology (%) 4 Bit # 43045 263 19488' Depth Present 0.969 14 25 C-2 0 C-4n 0 Gas Summary 1045 (current) Units* 907-685-0772 Unit Phone: 128 Gregory Dellner Set At Size 178.9 X-65 Grade Hours Cly Hydrill L-80 Comments Intermediate Report By: 20.00" 9 5/8" Logging Engineers: Paul Kalenuik/ Gregory Dellner (max) (current) BTC 122746 0 . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers: Paul Kalenuik/ Gregory Dellner (max) (current) BTC 110911 0 Hours Cly Hydrill L-80 Comments Intermediate 907-685-0772 Unit Phone: 90 Gregory Dellner Set At Size 178.9 X-65 Grade Gas Summary 936 (current) Units* C-2 0 C-4n 0 52505 179 22709' Depth Present 0.969 14 20 Minimum Depth 13 3/8" Maximum in 6 Lithology (%) 4 Bit # 21511' 0 311 262 419 % 486 Alkal Coal Gallons/stroke 21443' 22795' 1352' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 118 SPP (psi) Avg to 13165' Current 277.6 0.0 MWD Summary Ss Cht Silt 100 8.75 0.902 Footage 40.0 Depth in / out 13320' 8.75 13335' 2663' - - BROOH 8.75" Lateral PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 222 358 0 0 Chromatograph (ppm) 822 329 Mud (lb/bbl) ml/30min 3.51 2.70 (max) 461 C-3 Average 5Background 100% Gas In Air =10,000 Units Connection Drill f/21,350' to 22,504' MD/3,502' TVD at 480 gpm, 3300 psi, 160 rpm. Monitor well. Static. Drill to TD at 22,795' MD/ Trip 500 gpm, 120 rpm & 3220 psi to 21,259'. 5 13122' Size 160'Conductor Evermar Smith PDC Casing Summary L-80 Bit Type 22454' WOB Smith PDC TFA Condition 17 RPM 52 Mud Type fazepro NA Ratio Mud Data Depth 68/32 9.25 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22795'7.2 11.93 12.42 Cor Solids 12.19 Avg Min YP Max ECD (ppg) Tools Xceed675 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: 467.1 Morning Report Report # 42 Customer: Well: Area: Location: Rig: SP31-W7 8-Feb-2015 12:00 AM AK-AM-0901938178 3400 ROP ROP (ft/hr) J. Keener/R. Wimmer 24 hr Max Max @ ft 22564' 176 61 193 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers: Paul Kalenuik/ Gregory Dellner (max) (current) BTC 13892 0 Hours Cly Hydrill L-80 Comments Intermediate 907-685-0772 Unit Phone: 29 Gregory Dellner Set At Size 178.9 X-65 Grade Gas Summary 101 (current) Units* C-2 0 C-4n 0 1382 11 Depth Present 0.969 15 0Minimum Depth 13 3/8" Maximum in 0 Lithology (%) 4 Bit # 0 56 84 17 % 541 Alkal Coal Gallons/stroke 22795' 22795' 0' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 130 SPP (psi) Avg to 13165' Current MWD Summary Ss Cht Silt 100 8.75 0.902 Footage 40.0 Depth in / out 13320' 8.75 13335' 2663' - - BROOH 8.75" Lateral PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 16 57 0 0 Chromatograph (ppm) 108 57 Mud (lb/bbl) ml/30min 3.12 2.40 (max) 14 C-3 Average 0Background 100% Gas In Air =10,000 Units Connection Continue BROOH f/20,895' to 18,739' at 550 gpm, 120 rpm & 3760 psi. ECD: 11.47 ppg . BROOH to 17,898' at Trip 5 13122' Size 160'Conductor Evermar Smith PDC Casing Summary L-80 Bit Type 22454' WOB Smith PDC TFA Condition 19 RPM 53 Mud Type fazepro NA Ratio Mud Data Depth 68/32 9.35 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22795'7.1 Cor Solids Avg Min YP Max ECD (ppg) Tools Xceed675 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 43 Customer: Well: Area: Location: Rig: SP31-W7 9-Feb-2015 12:00 AM AK-AM-0901938178 3200 ROP ROP (ft/hr) J. Keener/R. Wimmer 24 hr Max Max @ ft 29 11 17 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers:Paul Kalenuik/ Kori Plowman (max)(current) BTC 156 Hours Cly Hydrill L-80 Comments Intermediate 907-685-0772Unit Phone:Paul Kalenuik Set AtSize 178.9 X-65 Grade Gas Summary (current) Units*C-2 C-4n Depth 16 Minimum Depth 13 3/8" Maximum in Lithology (%) Bit # t/13150', no rotation. CBU x3.5 @575gpm. Cut/slip drill line, service equip. POOH as per K&M f/10425' t/9003', L/D 4.5" DP to shed, % Alkal Coal 22795' 22795' 0' Lime TuffGvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 130 SPP (psi) Avg to Current MWD Summary Ss Cht Silt 8.75 0.902 Footage 40.0 Depth in / out 13320' 22795' 2663' TIH for Whipstock PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i ShSiltst LstClyst C-4i 9673' Chromatograph (ppm) Mud (lb/bbl)ml/30min 3.122.40 (max) C-3 Average Background 100% Gas In Air=10,000 UnitsConnection BROOH f/13273' t/10425' at 550 gpm, 120 rpm & 3000 psi. ECD:11.47 ppg. Pull BHA through window f/13222' Trip M/U whipstock retrieval BHA 5 13122' 63.80 6 Size 160'ConductorEvermar Smith PDC Casing Summary L-80 Bit Type WOBTFA Condition 16 RPM 53 Mud Type fazepro NA Ratio Mud Data Depth 68/329.40 Oil / Water (lb/100ft2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22795'7.6 Cor Solids Avg Min YP MaxECD (ppg) Tools ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 44 Customer: Well: Area: Location: Rig: SP31-W7 10-Feb-2015 12:00 AM AK-AM-0901938178 ROP ROP (ft/hr) J. Keener/R. Wimmer 24 hr Max Max @ ft Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 12:00 AM AK-AM-0901938178 ROP ROP (ft/hr) J. Keener/R. Wimmer 24 hr Max Max @ ft Morning Report Report # 45 Customer: Well: Area: Location: Rig: SP31-W7 11-Feb-2015 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP MaxECD (ppg) Tools 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22795'7.6 Mud Type fazepro NA Ratio Mud Data Depth 68/329.40 Oil / Water (lb/100ft2) WOBTFA Condition 16 RPM 53 6 Size 160'ConductorEvermar Smith PDC Casing Summary L-80 Bit Type RIH w/whipstock retrieval hook t/1479'. SHT MWD @425gpm. RIH f/1479' t/13061', fill pipe every 2000'. Trip Continue to TOOH. Looking forward- pick up and begin to run liner. 5 13122' 63.80 Total losses 28 bbls 100% Gas In Air=10,000 UnitsConnection Average Background Mud (lb/bbl)ml/30min 3.122.40 (max) C-3 9673' Chromatograph (ppm) Cement C-1 C-5i ShSiltst LstClyst C-4i TOOH Whipstock PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13320' 22795' 2663' Ss Cht Silt Avg to Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 130 SPP (psi) 22795' 22795' 0' Lime TuffGvl Surface 96% Date: % Alkal Coal As per Baker, orient hook, wash whipstock slot, latch on to whipstock and pull. monitor well, slow t/1ft/min. Minimum Depth 13 3/8" Maximum in Lithology (%) Bit # Depth 16 C-2 C-4n Gas Summary (current) Units* 907-685-0772Unit Phone:Paul Kalenuik Set AtSize 178.9 X-65 Grade 156 Hours Cly Hydrill L-80 Comments Intermediate Report By: 20.00" 9 5/8" Logging Engineers:Paul Kalenuik/ Kori Plowman (max)(current) BTC . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers:Paul Kalenuik/ Kori Plowman (max)(current) BTC 156 Hours Cly Hydrill L-80 Comments Intermediate 907-685-0772Unit Phone:Paul Kalenuik Set AtSize 178.9 X-65 Grade Gas Summary (current) Units*C-2 C-4n Depth 16 Minimum Depth 13 3/8" Maximum in Lithology (%) Bit # liner. Adjust top drive to center line. Daily losses were 23bbls. No gas to report. No issues. % Alkal Coal 22795' 22795' 0' Lime TuffGvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 130 SPP (psi) Avg to Current MWD Summary Ss Cht Silt 8.75 0.902 Footage 40.0 Depth in / out 13320' 22795' 2663' RIH Liner PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i ShSiltst LstClyst C-4i 9673' Chromatograph (ppm) Mud (lb/bbl)ml/30min 3.122.40 (max) C-3 Average Background 100% Gas In Air=10,000 UnitsConnection POOH with Whipstock. L/D whipstock BHA as per Baker . Bring liner tools to rig floor and begin running in hole with Trip 5 13122' 63.80 6 Size 160'ConductorEvermar Smith PDC Casing Summary L-80 Bit Type WOBTFA Condition 16 RPM 53 Mud Type fazepro NA Ratio Mud Data Depth 68/329.40 Oil / Water (lb/100ft2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22795'7.6 Cor Solids Avg Min YP MaxECD (ppg) Tools ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 46 Customer: Well: Area: Location: Rig: SP31-W7 12-Feb-2015 12:00 AM AK-AM-0901938178 ROP ROP (ft/hr) J. Keener/R. Wimmer 24 hr Max Max @ ft Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Report By: 20.00" 9 5/8" Logging Engineers:Paul Kalenuik/ Kori Plowman (max)(current) BTC 156 Hours Cly Hydrill L-80 Comments Intermediate 907-685-0772Unit Phone:Paul Kalenuik Set AtSize 178.9 X-65 Grade Gas Summary (current) Units*C-2 C-4n Depth 16 Minimum Depth 13 3/8" Maximum in Lithology (%) Bit # ensure LTP clear. RIH f/ 9849' t/12182' w/ 5"DP. RIH w/ liner on 5" DP f/12182 to 21707'. Orient bent jt through window @13122 % Alkal Coal 22795' 22795' 0' Lime TuffGvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 130 SPP (psi) Avg to Current MWD Summary Ss Cht Silt 8.75 0.902 Footage 40.0 Depth in / out 13320' 22795' 2663' RIH Liner PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i ShSiltst LstClyst C-4i 9673' Chromatograph (ppm) Mud (lb/bbl)ml/30min 3.122.40 (max) C-3 Average Background 100% Gas In Air=10,000 UnitsConnection RIH f/3745 w 5.5"liner. R/D GBR Volant, C/O handlingequip. To 5". M/U liner packer. P/U 1 std 5" DP, circ @5 bpm to Trip and begin rotating. Total losses for day- 9bbls 5 13122' 63.80 6 Size 160'ConductorEvermar Smith PDC Casing Summary L-80 Bit Type WOBTFA Condition 16 RPM 54 Mud Type fazepro NA Ratio Mud Data Depth 68/329.40 Oil / Water (lb/100ft2) 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22795'7.6 Cor Solids Avg Min YP MaxECD (ppg) Tools ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 47 Customer: Well: Area: Location: Rig: SP31-W7 13-Feb-2015 12:00 AM AK-AM-0901938178 ROP ROP (ft/hr) J. Keener/R. Wimmer 24 hr Max Max @ ft Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 12:00 AM AK-AM-0901938178 ROP ROP (ft/hr) J. Keener/R. Wimmer 24 hr Max Max @ ft Morning Report Report # 48 Customer: Well: Area: Location: Rig: SP31-W7 13-Feb-2015 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP MaxECD (ppg)Tools 4.23 @ Current Pump & Flow Data: DOYON 15 Report For: 22795' Mud Type fazepro Ratio Mud Data Depth 9.30 Oil / Water (lb/100ft2) WOBTFA ConditionRPM 28 6 Size 160'ConductorEvermar Smith PDC Casing Summary L-80 Bit Type RIH f/21707' t/22795' w/5"DP @40rpm, tag bottom, pull up t/22775'. As per Baker, drop ball and set packer. Test Trip Pull wear bushing, set test plug. R/U to test BOP. Test BOP w/4.5" test jt. 5 13122' 63.80 Daily loss 18 bbls. 100% Gas In Air=10,000 UnitsConnection Average Background Mud (lb/bbl)ml/30min (max) C-3 9673' Chromatograph (ppm) Cement C-1 C-5i ShSiltst LstClyst C-4i Test BOP PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 13320' 22795' 2663' Ss Cht Silt Avg to Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 130 SPP (psi) 22795' 22795' 0' Lime TuffGvl Surface 96% Date: % Alkal Coal packer. Displace well t/9.3ppg. Clean surface equip. POOH f/12924' t/9378', w/5"DP, L/D to shed f/10872'. Minimum Depth 13 3/8" Maximum in Lithology (%) Bit # Depth C-2 C-4n Gas Summary (current) Units* 907-685-0772Unit Phone:Paul Kalenuik Set AtSize 178.9 X-65 Grade 156 Hours Cly Hydrill L-80 Comments Intermediate Report By: 20.00" 9 5/8" Logging Engineers:Paul Kalenuik/ Kori Plowman (max)(current) BTC WELL INFORMATION Created On : Mar 06 2015 Customer :ENI Petroleum Well Name :SP31-W7 Job Number :AK-XX-0901938178 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 0.00 170.00 0.00 0.00 N 0.00 E 0.00 0.00 40.67 0.00 170.00 40.67 0.00 N 0.00 E 0.00 0.00 117.12 0.49 295.23 117.12 0.14 N 0.30 W 0.28 0.64 160.25 0.52 307.70 160.25 0.34 N 0.62 W 0.58 0.26 252.75 0.11 208.40 252.75 0.52 N 0.99 W 0.93 0.59 345.55 0.24 156.28 345.55 0.26 N 0.96 W 0.92 0.21 404.26 0.85 175.20 404.25 0.29 S 0.87 W 0.90 1.07 453.58 1.44 176.46 453.56 1.27 S 0.80 W 0.93 1.20 546.38 2.37 181.61 546.31 4.35 S 0.78 W 1.25 1.02 639.23 3.13 187.53 639.05 8.78 S 1.17 W 2.12 0.87 732.55 5.72 194.31 732.09 15.82 S 2.65 W 4.36 2.83 825.89 8.43 200.27 824.71 26.74 S 6.17 W 9.05 3.00 919.14 9.93 209.80 916.77 40.13 S 12.54 W 16.84 2.29 1012.56 12.68 220.00 1,008.38 54.98 S 23.13 W 28.99 3.63 1070.31 13.98 224.79 1,064.57 64.79 S 32.12 W 39.00 2.95 1163.53 15.32 233.30 1,154.77 80.14 S 49.93 W 58.37 2.72 1256.93 17.83 233.41 1,244.28 96.04 S 71.31 W 81.36 2.69 1350.27 22.55 229.81 1,331.86 116.12 S 96.47 W 108.56 5.23 1443.61 24.98 229.24 1,417.28 140.54 S 125.08 W 139.66 2.61 1536.82 26.37 229.19 1,501.29 166.92 S 155.65 W 172.93 1.49 1630.04 25.79 227.95 1,585.02 194.04 S 186.38 W 206.43 0.85 1723.00 25.01 228.64 1,668.99 220.57 S 216.15 W 238.91 0.90 1816.32 24.93 228.64 1,753.59 246.60 S 245.72 W 271.14 0.09 1909.51 24.77 228.40 1,838.15 272.54 S 275.06 W 303.13 0.20 2002.84 29.45 228.92 1,921.20 300.61 S 306.99 W 337.94 5.02 2096.15 31.33 227.61 2,001.69 332.04 S 342.20 W 376.37 2.14 2189.56 35.22 227.81 2,079.77 366.52 S 380.11 W 417.81 4.17 2282.85 37.58 227.20 2,154.85 403.92 S 420.92 W 462.45 2.56 2375.83 41.35 227.58 2,226.62 443.91 S 464.41 W 510.05 4.06 2469.20 45.03 227.83 2,294.68 486.91 S 511.68 W 561.72 3.95 INSITE V8.1.10 Page 1Job No:AK-XX-0901938178 Well Name:SP31-W7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2562.51 48.81 225.62 2,358.41 533.64 S 561.25 W 616.10 4.40 2597.52 49.84 226.08 2,381.23 552.14 S 580.31 W 637.05 3.11 2697.41 53.60 226.71 2,443.10 606.20 S 637.08 W 699.38 3.80 2729.41 55.85 225.72 2,461.58 624.28 S 655.94 W 720.10 7.47 2822.79 60.45 225.71 2,510.84 679.64 S 712.71 W 782.57 4.93 2916.15 64.81 226.84 2,553.75 736.92 S 772.62 W 848.37 4.79 3009.44 68.29 228.86 2,590.88 794.33 S 836.07 W 917.70 4.23 3102.86 71.06 227.82 2,623.32 852.56 S 901.51 W 989.09 3.14 3196.24 74.32 227.56 2,651.10 912.56 S 967.42 W 1061.16 3.50 3289.95 77.39 227.39 2,674.00 973.98 S 1,034.38 W 1134.42 3.28 3383.06 80.04 228.06 2,692.22 1,035.39 S 1,101.94 W 1208.27 2.93 3476.38 82.35 227.92 2,706.50 1,097.11 S 1,170.46 W 1283.11 2.48 3569.70 84.40 227.64 2,717.27 1,159.40 S 1,239.10 W 1358.14 2.22 3663.01 86.84 226.95 2,724.39 1,222.49 S 1,307.47 W 1432.97 2.72 3756.31 86.93 226.64 2,729.46 1,286.27 S 1,375.37 W 1507.43 0.35 3849.63 87.10 226.64 2,734.32 1,350.26 S 1,443.13 W 1581.76 0.18 3943.01 87.30 226.71 2,738.89 1,414.25 S 1,510.98 W 1656.18 0.23 4036.42 86.42 226.81 2,744.00 1,478.14 S 1,578.92 W 1730.69 0.95 4129.68 86.98 226.40 2,749.37 1,542.11 S 1,646.58 W 1804.91 0.74 4222.99 87.82 226.65 2,753.60 1,606.24 S 1,714.22 W 1879.14 0.94 4316.35 87.49 227.18 2,757.42 1,669.96 S 1,782.35 W 1953.81 0.67 4409.77 86.29 226.52 2,762.49 1,733.76 S 1,850.40 W 2028.42 1.47 4503.03 86.87 226.07 2,768.06 1,798.08 S 1,917.70 W 2102.33 0.79 4596.39 87.35 226.83 2,772.76 1,862.32 S 1,985.28 W 2176.51 0.96 4689.79 87.17 226.42 2,777.23 1,926.39 S 2,053.09 W 2250.90 0.48 4782.94 87.46 227.29 2,781.59 1,990.02 S 2,120.98 W 2325.33 0.98 4876.34 87.19 227.41 2,785.95 2,053.23 S 2,189.60 W 2400.43 0.32 4969.59 86.51 227.34 2,791.07 2,116.29 S 2,258.11 W 2475.41 0.73 5062.91 87.13 228.10 2,796.25 2,178.97 S 2,327.05 W 2550.77 1.05 5156.23 86.83 228.09 2,801.17 2,241.21 S 2,396.40 W 2626.50 0.32 5249.61 86.70 228.25 2,806.44 2,303.39 S 2,465.87 W 2702.33 0.22 5342.96 87.39 228.82 2,811.25 2,365.12 S 2,535.73 W 2778.51 0.96 5436.29 86.88 228.58 2,815.91 2,426.64 S 2,605.76 W 2854.83 0.60 5530.33 86.84 228.56 2,821.07 2,488.77 S 2,676.16 W 2931.58 0.05 5623.05 86.86 227.80 2,826.16 2,550.51 S 2,745.15 W 3006.90 0.82 5716.19 87.05 226.92 2,831.11 2,613.51 S 2,813.57 W 3081.78 0.97 5809.55 86.92 226.57 2,836.02 2,677.39 S 2,881.47 W 3156.24 0.40 5902.94 87.02 226.10 2,840.96 2,741.78 S 2,948.94 W 3230.32 0.51 5996.33 86.89 225.64 2,845.92 2,806.72 S 3,015.87 W 3303.94 0.51 6089.67 87.11 225.72 2,850.80 2,871.84 S 3,082.56 W 3377.33 0.25 6183.11 87.08 225.52 2,855.54 2,937.11 S 3,149.26 W 3450.75 0.22 6276.29 86.80 226.77 2,860.51 3,001.58 S 3,216.35 W 3524.47 1.37 6369.64 86.87 228.16 2,865.67 3,064.59 S 3,285.03 W 3599.61 1.49 6463.09 86.93 229.34 2,870.72 3,126.11 S 3,355.19 W 3676.06 1.26 6556.51 86.95 229.72 2,875.71 3,186.66 S 3,426.16 W 3753.20 0.41 INSITE V8.1.10 Page 2Job No:AK-XX-0901938178 Well Name:SP31-W7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6649.91 87.07 229.20 2,880.58 3,247.29 S 3,497.04 W 3830.27 0.57 6743.31 87.05 228.56 2,885.37 3,308.63 S 3,567.31 W 3906.81 0.68 6836.69 86.61 228.16 2,890.53 3,370.58 S 3,636.99 W 3982.83 0.64 6930.16 87.04 228.24 2,895.71 3,432.78 S 3,706.56 W 4058.77 0.47 7023.49 87.41 228.30 2,900.23 3,494.83 S 3,776.13 W 4134.69 0.40 7116.88 86.87 227.81 2,904.89 3,557.18 S 3,845.50 W 4210.45 0.78 7210.14 87.08 227.06 2,909.81 3,620.17 S 3,914.09 W 4285.50 0.83 7303.61 86.85 226.16 2,914.76 3,684.29 S 3,981.92 W 4359.92 0.99 7396.97 87.21 226.42 2,919.60 3,748.72 S 4,049.32 W 4433.94 0.48 7490.50 86.64 226.14 2,924.61 3,813.27 S 4,116.82 W 4508.07 0.68 7583.90 87.00 226.37 2,929.79 3,877.75 S 4,184.19 W 4582.07 0.46 7677.37 86.76 226.15 2,934.88 3,942.28 S 4,251.62 W 4656.14 0.35 7770.79 87.16 225.48 2,939.84 4,007.30 S 4,318.51 W 4729.72 0.83 7864.12 87.31 225.37 2,944.34 4,072.72 S 4,384.92 W 4802.86 0.20 7957.42 87.03 225.32 2,948.95 4,138.22 S 4,451.20 W 4875.90 0.30 8050.82 86.98 225.50 2,953.83 4,203.70 S 4,517.63 W 4949.07 0.20 8144.17 86.86 226.07 2,958.84 4,268.70 S 4,584.44 W 5022.57 0.62 8237.55 87.84 226.53 2,963.16 4,333.15 S 4,651.88 W 5096.63 1.16 8330.86 86.88 226.70 2,967.46 4,397.17 S 4,719.62 W 5170.95 1.04 8424.25 87.47 227.22 2,972.06 4,460.83 S 4,787.79 W 5245.66 0.84 8517.69 87.16 227.56 2,976.44 4,524.02 S 4,856.48 W 5320.83 0.49 8611.18 86.71 227.80 2,981.44 4,586.88 S 4,925.51 W 5396.30 0.55 8704.60 86.66 226.93 2,986.84 4,650.05 S 4,994.12 W 5471.39 0.93 8798.01 86.97 227.08 2,992.03 4,713.65 S 5,062.34 W 5546.13 0.37 8891.40 86.89 226.52 2,997.03 4,777.48 S 5,130.32 W 5620.67 0.60 8984.84 87.11 226.49 3,001.92 4,841.71 S 5,198.01 W 5694.96 0.24 9078.23 86.95 226.77 3,006.76 4,905.76 S 5,265.81 W 5769.34 0.34 9171.60 86.99 226.33 3,011.69 4,969.88 S 5,333.50 W 5843.62 0.47 9266.04 86.75 226.68 3,016.85 5,034.78 S 5,401.90 W 5918.69 0.45 9359.53 86.56 225.76 3,022.31 5,099.36 S 5,469.29 W 5992.72 1.00 9452.90 87.09 226.30 3,027.48 5,164.08 S 5,536.38 W 6066.47 0.81 9546.09 86.89 225.59 3,032.37 5,228.79 S 5,603.26 W 6140.01 0.79 9639.49 86.89 226.43 3,037.44 5,293.57 S 5,670.36 W 6213.77 0.90 9732.89 87.22 226.40 3,042.24 5,357.87 S 5,737.93 W 6287.94 0.35 9826.29 86.41 226.11 3,047.43 5,422.35 S 5,805.30 W 6361.94 0.92 9919.69 86.50 226.63 3,053.20 5,486.68 S 5,872.77 W 6436.03 0.56 10013.12 86.32 226.96 3,059.05 5,550.51 S 5,940.74 W 6510.55 0.40 10106.39 86.29 227.83 3,065.06 5,613.52 S 6,009.25 W 6585.52 0.93 10199.79 86.34 228.73 3,071.06 5,675.55 S 6,078.81 W 6661.44 0.96 10293.18 84.82 228.99 3,078.26 5,736.81 S 6,148.94 W 6737.82 1.65 10386.54 83.44 229.27 3,087.81 5,797.57 S 6,219.16 W 6814.25 1.51 10479.71 82.15 230.27 3,099.50 5,857.27 S 6,289.73 W 6890.91 1.75 10573.11 82.08 229.09 3,112.31 5,917.13 S 6,360.27 W 6967.55 1.25 10666.37 82.06 227.89 3,125.18 5,978.35 S 6,429.43 W 7042.98 1.27 10759.72 78.76 227.32 3,140.73 6,040.40 S 6,497.40 W 7117.31 3.59 INSITE V8.1.10 Page 3Job No:AK-XX-0901938178 Well Name:SP31-W7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10853.46 77.20 225.57 3,160.25 6,103.57 S 6,563.85 W 7190.25 2.47 10946.45 78.16 225.27 3,180.09 6,167.33 S 6,628.55 W 7261.52 1.08 11039.85 78.09 225.15 3,199.31 6,231.73 S 6,693.42 W 7333.02 0.15 11133.12 78.21 224.63 3,218.46 6,296.40 S 6,757.84 W 7404.11 0.56 11225.91 78.45 225.40 3,237.23 6,360.64 S 6,822.11 W 7475.01 0.85 11319.78 78.44 225.67 3,256.03 6,425.06 S 6,887.75 W 7547.28 0.28 11413.03 79.84 226.64 3,273.60 6,488.49 S 6,953.80 W 7619.85 1.82 11506.45 79.73 226.64 3,290.17 6,551.62 S 7,020.64 W 7693.18 0.12 11599.62 79.69 228.99 3,306.82 6,613.17 S 7,088.56 W 7767.40 2.48 11692.84 79.21 232.26 3,323.89 6,671.30 S 7,159.39 W 7844.15 3.49 11786.24 78.68 236.20 3,341.80 6,724.88 S 7,233.75 W 7923.91 4.18 11880.09 80.16 238.06 3,359.04 6,774.94 S 7,311.23 W 8006.38 2.51 11972.92 81.06 239.95 3,374.18 6,822.10 S 7,389.74 W 8089.56 2.23 12066.13 81.40 242.09 3,388.40 6,866.73 S 7,470.32 W 8174.53 2.30 12159.35 82.19 244.71 3,401.70 6,908.03 S 7,552.81 W 8261.04 2.91 12252.31 83.07 246.74 3,413.63 6,945.93 S 7,636.85 W 8348.70 2.36 12345.63 84.53 249.55 3,423.71 6,980.46 S 7,722.94 W 8438.05 3.38 12438.82 85.06 251.30 3,432.16 7,011.55 S 7,810.38 W 8528.36 1.95 12532.15 84.84 252.41 3,440.38 7,040.50 S 7,898.73 W 8619.33 1.21 12625.46 84.33 253.00 3,449.19 7,068.12 S 7,987.42 W 8710.51 0.83 12718.87 84.19 255.62 3,458.53 7,093.25 S 8,076.89 W 8802.18 2.79 12812.16 84.57 256.52 3,467.67 7,115.60 S 8,167.00 W 8894.19 1.04 12905.14 85.36 257.65 3,475.83 7,136.30 S 8,257.27 W 8986.19 1.48 12998.51 86.18 258.34 3,482.71 7,155.67 S 8,348.35 W 9078.84 1.15 13091.82 86.12 258.08 3,488.98 7,174.69 S 8,439.49 W 9171.50 0.29 13185.21 86.24 256.89 3,495.20 7,194.89 S 8,530.45 W 9264.13 1.28 13278.57 86.50 255.75 3,501.11 7,216.92 S 8,620.98 W 9356.52 1.25 13349.62 87.37 257.57 3,504.91 7,233.29 S 8,690.01 W 9426.92 2.84 13443.04 86.77 258.38 3,509.69 7,252.73 S 8,781.26 W 9519.75 1.08 13536.42 89.15 260.40 3,513.01 7,269.91 S 8,872.98 W 9612.79 3.34 13629.82 91.50 264.13 3,512.48 7,282.47 S 8,965.50 W 9706.13 4.72 13723.24 89.32 264.44 3,511.81 7,291.78 S 9,058.45 W 9799.54 2.36 13816.56 89.20 263.69 3,513.02 7,301.42 S 9,151.26 W 9892.85 0.81 13909.88 89.84 265.75 3,513.80 7,310.01 S 9,244.18 W 9986.15 2.31 14003.19 89.46 266.59 3,514.37 7,316.24 S 9,337.28 W 10079.37 0.99 14096.49 89.81 266.71 3,514.96 7,321.70 S 9,430.41 W 10172.55 0.40 14189.81 90.76 268.06 3,514.50 7,325.95 S 9,523.63 W 10265.68 1.77 14283.19 90.42 270.91 3,513.54 7,326.79 S 9,616.99 W 10358.57 3.07 14376.60 88.78 273.36 3,514.19 7,323.31 S 9,710.33 W 10450.97 3.16 14469.86 88.97 276.56 3,516.02 7,315.25 S 9,803.21 W 10542.42 3.44 14563.17 88.63 280.07 3,517.98 7,301.76 S 9,895.50 W 10632.69 3.78 14656.53 88.94 283.65 3,519.96 7,282.58 S 9,986.83 W 10721.39 3.85 14749.95 88.97 286.38 3,521.66 7,258.39 S 10,077.04 W 10808.42 2.92 14843.21 90.19 286.44 3,522.34 7,232.04 S 10,166.50 W 10894.47 1.31 14936.57 91.54 286.42 3,520.94 7,205.64 S 10,256.03 W 10980.59 1.45 INSITE V8.1.10 Page 4Job No:AK-XX-0901938178 Well Name:SP31-W7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 15029.97 92.36 285.45 3,517.76 7,180.01 S 10,345.79 W 11067.02 1.36 15123.12 92.08 285.41 3,514.15 7,155.25 S 10,435.51 W 11153.51 0.30 15216.52 91.74 285.57 3,511.04 7,130.32 S 10,525.47 W 11240.21 0.40 15309.77 89.98 285.46 3,509.64 7,105.38 S 10,615.31 W 11326.79 1.89 15403.09 87.77 283.74 3,511.47 7,081.86 S 10,705.59 W 11413.97 3.00 15496.41 86.66 284.31 3,516.00 7,059.27 S 10,796.02 W 11501.40 1.34 15589.79 90.03 284.63 3,518.70 7,035.95 S 10,886.39 W 11588.68 3.63 15683.14 93.96 285.14 3,515.45 7,011.99 S 10,976.53 W 11675.68 4.25 15776.47 95.69 287.87 3,507.60 6,985.58 S 11,065.69 W 11761.42 3.45 15869.87 95.93 291.02 3,498.14 6,954.65 S 11,153.30 W 11845.14 3.37 15963.23 92.12 291.62 3,491.59 6,920.79 S 11,240.04 W 11927.67 4.13 16056.37 90.53 291.87 3,489.44 6,886.30 S 11,326.52 W 12009.88 1.73 16149.73 90.37 293.40 3,488.70 6,850.37 S 11,412.69 W 12091.61 1.65 16243.12 91.13 295.21 3,487.48 6,811.94 S 11,497.79 W 12172.01 2.10 16336.51 89.67 296.62 3,486.83 6,771.12 S 11,581.78 W 12251.05 2.17 16429.85 89.85 298.25 3,487.22 6,728.12 S 11,664.62 W 12328.71 1.76 16523.29 91.58 299.13 3,486.05 6,683.27 S 11,746.58 W 12405.29 2.08 16616.47 91.07 299.83 3,483.90 6,637.43 S 11,827.67 W 12480.90 0.93 16709.82 88.64 299.09 3,484.13 6,591.52 S 11,908.94 W 12556.68 2.72 16803.27 89.26 300.04 3,485.85 6,545.42 S 11,990.21 W 12632.44 1.21 16896.69 89.13 300.66 3,487.16 6,498.22 S 12,070.82 W 12707.42 0.68 16990.09 89.15 302.42 3,488.56 6,449.37 S 12,150.41 W 12781.21 1.88 17083.49 89.74 303.06 3,489.47 6,398.86 S 12,228.97 W 12853.79 0.93 17176.87 90.18 305.30 3,489.53 6,346.40 S 12,306.21 W 12924.85 2.44 17270.34 89.91 306.00 3,489.46 6,291.93 S 12,382.17 W 12994.41 0.80 17363.67 88.32 308.18 3,490.90 6,235.65 S 12,456.60 W 13062.27 2.89 17457.06 86.19 309.26 3,495.37 6,177.31 S 12,529.37 W 13128.25 2.56 17550.32 86.51 309.87 3,501.31 6,118.03 S 12,601.12 W 13193.10 0.74 17643.79 90.47 309.77 3,503.77 6,058.20 S 12,672.87 W 13257.90 4.24 17737.15 96.41 312.38 3,498.17 5,997.01 S 12,743.09 W 13321.03 6.95 17830.68 96.94 311.62 3,487.30 5,934.85 S 12,812.13 W 13382.88 0.99 17924.08 94.47 310.71 3,478.02 5,873.68 S 12,882.09 W 13445.75 2.82 18017.55 90.41 309.98 3,474.04 5,813.24 S 12,953.25 W 13509.89 4.41 18110.97 90.78 309.95 3,473.07 5,753.24 S 13,024.84 W 13574.52 0.40 18204.30 89.28 307.72 3,473.02 5,694.72 S 13,097.54 W 13640.40 2.88 18297.60 87.86 308.81 3,475.35 5,636.96 S 13,170.77 W 13706.89 1.92 18391.00 88.72 309.98 3,478.13 5,577.71 S 13,242.91 W 13772.15 1.55 18484.35 89.20 313.98 3,479.83 5,515.29 S 13,312.28 W 13834.30 4.31 18577.73 88.10 318.73 3,482.03 5,447.76 S 13,376.69 W 13890.96 5.22 18671.04 88.61 322.07 3,484.71 5,375.90 S 13,436.14 W 13942.22 3.62 18764.43 89.54 325.36 3,486.22 5,300.65 S 13,491.39 W 13988.93 3.66 18857.87 89.93 328.87 3,486.65 5,222.19 S 13,542.12 W 14030.80 3.78 18951.36 89.27 330.26 3,487.30 5,141.59 S 13,589.47 W 14069.08 1.65 19044.78 91.15 334.27 3,486.96 5,058.92 S 13,632.94 W 14103.28 4.74 19138.19 90.86 334.63 3,485.32 4,974.66 S 13,673.22 W 14134.13 0.49 INSITE V8.1.10 Page 5Job No:AK-XX-0901938178 Well Name:SP31-W7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 19231.58 90.05 335.17 3,484.58 4,890.09 S 13,712.83 W 14164.29 1.04 19325.02 89.09 334.73 3,485.28 4,805.45 S 13,752.39 W 14194.38 1.13 19418.41 89.03 334.58 3,486.81 4,721.06 S 13,792.37 W 14224.91 0.17 19511.78 88.70 335.30 3,488.66 4,636.49 S 13,831.91 W 14255.00 0.85 19605.08 87.50 335.97 3,491.76 4,551.55 S 13,870.37 W 14283.98 1.47 19698.57 86.71 336.99 3,496.48 4,465.94 S 13,907.64 W 14311.68 1.38 19791.94 86.82 336.34 3,501.75 4,380.34 S 13,944.56 W 14339.05 0.70 19885.13 86.64 336.07 3,507.06 4,295.21 S 13,982.10 W 14367.08 0.35 19978.53 88.25 334.94 3,511.23 4,210.31 S 14,020.78 W 14396.28 2.11 20071.93 90.21 335.99 3,512.48 4,125.36 S 14,059.56 W 14425.56 2.38 20165.33 90.19 335.37 3,512.16 4,040.25 S 14,098.03 W 14454.52 0.66 20258.73 90.10 333.24 3,511.92 3,956.09 S 14,138.52 W 14485.59 2.28 20352.16 90.31 333.19 3,511.59 3,872.68 S 14,180.62 W 14518.35 0.23 20445.43 90.26 330.92 3,511.12 3,790.29 S 14,224.33 W 14552.81 2.43 20538.83 90.90 329.31 3,510.18 3,709.32 S 14,270.86 W 14590.24 1.85 20632.22 90.45 326.82 3,509.08 3,630.08 S 14,320.26 W 14630.70 2.71 20725.58 91.72 324.50 3,507.31 3,553.01 S 14,372.91 W 14674.63 2.83 20818.75 92.35 322.31 3,504.00 3,478.26 S 14,428.41 W 14721.65 2.44 20912.15 92.30 319.82 3,500.21 3,405.67 S 14,487.05 W 14772.03 2.66 21005.41 92.45 320.09 3,496.34 3,334.34 S 14,547.00 W 14823.84 0.33 21098.76 91.17 320.44 3,493.40 3,262.59 S 14,606.65 W 14875.31 1.42 21192.07 91.05 322.55 3,491.59 3,189.59 S 14,664.73 W 14925.08 2.26 21285.49 90.82 323.12 3,490.06 3,115.15 S 14,721.15 W 14973.05 0.66 21378.89 89.42 323.53 3,489.87 3,040.24 S 14,776.94 W 15020.34 1.56 21472.16 89.32 324.53 3,490.89 2,964.76 S 14,831.72 W 15066.56 1.08 21565.48 89.96 325.02 3,491.48 2,888.53 S 14,885.54 W 15111.75 0.86 21658.82 89.20 325.29 3,492.16 2,811.93 S 14,938.87 W 15156.41 0.86 21752.07 91.09 326.14 3,491.93 2,734.89 S 14,991.40 W 15200.22 2.22 21845.49 90.95 326.70 3,490.27 2,657.07 S 15,043.06 W 15243.09 0.62 21938.66 93.08 326.65 3,486.99 2,579.27 S 15,094.21 W 15285.45 2.29 22031.88 95.72 326.86 3,479.84 2,501.55 S 15,145.16 W 15327.63 2.84 22125.28 97.13 328.12 3,469.39 2,423.28 S 15,195.04 W 15368.67 2.02 22218.62 96.98 328.40 3,457.92 2,344.50 S 15,243.77 W 15408.53 0.34 22311.96 96.93 328.90 3,446.62 2,265.38 S 15,291.98 W 15447.81 0.53 22387.41 96.75 327.50 3,437.63 2,201.71 S 15,331.45 W 15480.11 1.86 22454.00 96.75 327.50 3,429.81 2,145.94 S 15,366.98 W 15509.35 0.00 INSITE V8.1.10 Page 6Job No:AK-XX-0901938178 Well Name:SP31-W7 Survey Report 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 263.74 degrees (True) - A total correction of 19.03 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 22,454.00 feet is 15,516.10 feet along 262.05 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 7Job No:AK-XX-0901938178 Well Name:SP31-W7 Survey Report WELL INFORMATION Created On : Mar 06 2015 Customer :ENI Petroleum Well Name :SP31-W7 L1 Job Number :AK-XX-0901938178 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 0.00 170.00 0.00 0.00 N 0.00 E 0.00 0.00 40.67 0.00 170.00 40.67 0.00 N 0.00 E 0.00 0.00 117.12 0.49 295.23 117.12 0.14 N 0.30 W 0.28 0.64 160.25 0.52 307.70 160.25 0.34 N 0.62 W 0.58 0.26 252.75 0.11 208.40 252.75 0.52 N 0.99 W 0.93 0.59 345.55 0.24 156.28 345.55 0.26 N 0.96 W 0.92 0.21 404.26 0.85 175.20 404.25 0.29 S 0.87 W 0.90 1.07 453.58 1.44 176.46 453.56 1.27 S 0.80 W 0.93 1.20 546.38 2.37 181.61 546.31 4.35 S 0.78 W 1.25 1.02 639.23 3.13 187.53 639.05 8.78 S 1.17 W 2.12 0.87 732.55 5.72 194.31 732.09 15.82 S 2.65 W 4.36 2.83 825.89 8.43 200.27 824.71 26.74 S 6.17 W 9.05 3.00 919.14 9.93 209.80 916.77 40.13 S 12.54 W 16.84 2.29 1012.56 12.68 220.00 1,008.38 54.98 S 23.13 W 28.99 3.63 1070.31 13.98 224.79 1,064.57 64.79 S 32.12 W 39.00 2.95 1163.53 15.32 233.30 1,154.77 80.14 S 49.93 W 58.37 2.72 1256.93 17.83 233.41 1,244.28 96.04 S 71.31 W 81.36 2.69 1350.27 22.55 229.81 1,331.86 116.12 S 96.47 W 108.56 5.23 1443.61 24.98 229.24 1,417.28 140.54 S 125.08 W 139.66 2.61 1536.82 26.37 229.19 1,501.29 166.92 S 155.65 W 172.93 1.49 1630.04 25.79 227.95 1,585.02 194.04 S 186.38 W 206.43 0.85 1723.00 25.01 228.64 1,668.99 220.57 S 216.15 W 238.91 0.90 1816.32 24.93 228.64 1,753.59 246.60 S 245.72 W 271.14 0.09 1909.51 24.77 228.40 1,838.15 272.54 S 275.06 W 303.13 0.20 2002.84 29.45 228.92 1,921.20 300.61 S 306.99 W 337.94 5.02 2096.15 31.33 227.61 2,001.69 332.04 S 342.20 W 376.37 2.14 2189.56 35.22 227.81 2,079.77 366.52 S 380.11 W 417.81 4.17 2282.85 37.58 227.20 2,154.85 403.92 S 420.92 W 462.45 2.56 2375.83 41.35 227.58 2,226.62 443.91 S 464.41 W 510.05 4.06 2469.20 45.03 227.83 2,294.68 486.91 S 511.68 W 561.72 3.95 INSITE V8.1.10 Page 1Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2562.51 48.81 225.62 2,358.41 533.64 S 561.25 W 616.10 4.40 2597.52 49.84 226.08 2,381.23 552.14 S 580.31 W 637.05 3.11 2697.41 53.60 226.71 2,443.10 606.20 S 637.08 W 699.38 3.80 2729.41 55.85 225.72 2,461.58 624.28 S 655.94 W 720.10 7.47 2822.79 60.45 225.71 2,510.84 679.64 S 712.71 W 782.57 4.93 2916.15 64.81 226.84 2,553.75 736.92 S 772.62 W 848.37 4.79 3009.44 68.29 228.86 2,590.88 794.33 S 836.07 W 917.70 4.23 3102.86 71.06 227.82 2,623.32 852.56 S 901.51 W 989.09 3.14 3196.24 74.32 227.56 2,651.10 912.56 S 967.42 W 1061.16 3.50 3289.95 77.39 227.39 2,674.00 973.98 S 1,034.38 W 1134.42 3.28 3383.06 80.04 228.06 2,692.22 1,035.39 S 1,101.94 W 1208.27 2.93 3476.38 82.35 227.92 2,706.50 1,097.11 S 1,170.46 W 1283.11 2.48 3569.70 84.40 227.64 2,717.27 1,159.40 S 1,239.10 W 1358.14 2.22 3663.01 86.84 226.95 2,724.39 1,222.49 S 1,307.47 W 1432.97 2.72 3756.31 86.93 226.64 2,729.46 1,286.27 S 1,375.37 W 1507.43 0.35 3849.63 87.10 226.64 2,734.32 1,350.26 S 1,443.13 W 1581.76 0.18 3943.01 87.30 226.71 2,738.89 1,414.25 S 1,510.98 W 1656.18 0.23 4036.42 86.42 226.81 2,744.00 1,478.14 S 1,578.92 W 1730.69 0.95 4129.68 86.98 226.40 2,749.37 1,542.11 S 1,646.58 W 1804.91 0.74 4222.99 87.82 226.65 2,753.60 1,606.24 S 1,714.22 W 1879.14 0.94 4316.35 87.49 227.18 2,757.42 1,669.96 S 1,782.35 W 1953.81 0.67 4409.77 86.29 226.52 2,762.49 1,733.76 S 1,850.40 W 2028.42 1.47 4503.03 86.87 226.07 2,768.06 1,798.08 S 1,917.70 W 2102.33 0.79 4596.39 87.35 226.83 2,772.76 1,862.32 S 1,985.28 W 2176.51 0.96 4689.79 87.17 226.42 2,777.23 1,926.39 S 2,053.09 W 2250.90 0.48 4782.94 87.46 227.29 2,781.59 1,990.02 S 2,120.98 W 2325.33 0.98 4876.34 87.19 227.41 2,785.95 2,053.23 S 2,189.60 W 2400.43 0.32 4969.59 86.51 227.34 2,791.07 2,116.29 S 2,258.11 W 2475.41 0.73 5062.91 87.13 228.10 2,796.25 2,178.97 S 2,327.05 W 2550.77 1.05 5156.23 86.83 228.09 2,801.17 2,241.21 S 2,396.40 W 2626.50 0.32 5249.61 86.70 228.25 2,806.44 2,303.39 S 2,465.87 W 2702.33 0.22 5342.96 87.39 228.82 2,811.25 2,365.12 S 2,535.73 W 2778.51 0.96 5436.29 86.88 228.58 2,815.91 2,426.64 S 2,605.76 W 2854.83 0.60 5530.33 86.84 228.56 2,821.07 2,488.77 S 2,676.16 W 2931.58 0.05 5623.05 86.86 227.80 2,826.16 2,550.51 S 2,745.15 W 3006.90 0.82 5716.19 87.05 226.92 2,831.11 2,613.51 S 2,813.57 W 3081.78 0.97 5809.55 86.92 226.57 2,836.02 2,677.39 S 2,881.47 W 3156.24 0.40 5902.94 87.02 226.10 2,840.96 2,741.78 S 2,948.94 W 3230.32 0.51 5996.33 86.89 225.64 2,845.92 2,806.72 S 3,015.87 W 3303.94 0.51 6089.67 87.11 225.72 2,850.80 2,871.84 S 3,082.56 W 3377.33 0.25 6183.11 87.08 225.52 2,855.54 2,937.11 S 3,149.26 W 3450.75 0.22 6276.29 86.80 226.77 2,860.51 3,001.58 S 3,216.35 W 3524.47 1.37 6369.64 86.87 228.16 2,865.67 3,064.59 S 3,285.03 W 3599.61 1.49 6463.09 86.93 229.34 2,870.72 3,126.11 S 3,355.19 W 3676.06 1.26 6556.51 86.95 229.72 2,875.71 3,186.66 S 3,426.16 W 3753.20 0.41 INSITE V8.1.10 Page 2Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6649.91 87.07 229.20 2,880.58 3,247.29 S 3,497.04 W 3830.27 0.57 6743.31 87.05 228.56 2,885.37 3,308.63 S 3,567.31 W 3906.81 0.68 6836.69 86.61 228.16 2,890.53 3,370.58 S 3,636.99 W 3982.83 0.64 6930.16 87.04 228.24 2,895.71 3,432.78 S 3,706.56 W 4058.77 0.47 7023.49 87.41 228.30 2,900.23 3,494.83 S 3,776.13 W 4134.69 0.40 7116.88 86.87 227.81 2,904.89 3,557.18 S 3,845.50 W 4210.45 0.78 7210.14 87.08 227.06 2,909.81 3,620.17 S 3,914.09 W 4285.50 0.83 7303.61 86.85 226.16 2,914.76 3,684.29 S 3,981.92 W 4359.92 0.99 7396.97 87.21 226.42 2,919.60 3,748.72 S 4,049.32 W 4433.94 0.48 7490.50 86.64 226.14 2,924.61 3,813.27 S 4,116.82 W 4508.07 0.68 7583.90 87.00 226.37 2,929.79 3,877.75 S 4,184.19 W 4582.07 0.46 7677.37 86.76 226.15 2,934.88 3,942.28 S 4,251.62 W 4656.14 0.35 7770.79 87.16 225.48 2,939.84 4,007.30 S 4,318.51 W 4729.72 0.83 7864.12 87.31 225.37 2,944.34 4,072.72 S 4,384.92 W 4802.86 0.20 7957.42 87.03 225.32 2,948.95 4,138.22 S 4,451.20 W 4875.90 0.30 8050.82 86.98 225.50 2,953.83 4,203.70 S 4,517.63 W 4949.07 0.20 8144.17 86.86 226.07 2,958.84 4,268.70 S 4,584.44 W 5022.57 0.62 8237.55 87.84 226.53 2,963.16 4,333.15 S 4,651.88 W 5096.63 1.16 8330.86 86.88 226.70 2,967.46 4,397.17 S 4,719.62 W 5170.95 1.04 8424.25 87.47 227.22 2,972.06 4,460.83 S 4,787.79 W 5245.66 0.84 8517.69 87.16 227.56 2,976.44 4,524.02 S 4,856.48 W 5320.83 0.49 8611.18 86.71 227.80 2,981.44 4,586.88 S 4,925.51 W 5396.30 0.55 8704.60 86.66 226.93 2,986.84 4,650.05 S 4,994.12 W 5471.39 0.93 8798.01 86.97 227.08 2,992.03 4,713.65 S 5,062.34 W 5546.13 0.37 8891.40 86.89 226.52 2,997.03 4,777.48 S 5,130.32 W 5620.67 0.60 8984.84 87.11 226.49 3,001.92 4,841.71 S 5,198.01 W 5694.96 0.24 9078.23 86.95 226.77 3,006.76 4,905.76 S 5,265.81 W 5769.34 0.34 9171.60 86.99 226.33 3,011.69 4,969.88 S 5,333.50 W 5843.62 0.47 9266.04 86.75 226.68 3,016.85 5,034.78 S 5,401.90 W 5918.69 0.45 9359.53 86.56 225.76 3,022.31 5,099.36 S 5,469.29 W 5992.72 1.00 9452.90 87.09 226.30 3,027.48 5,164.08 S 5,536.38 W 6066.47 0.81 9546.09 86.89 225.59 3,032.37 5,228.79 S 5,603.26 W 6140.01 0.79 9639.49 86.89 226.43 3,037.44 5,293.57 S 5,670.36 W 6213.77 0.90 9732.89 87.22 226.40 3,042.24 5,357.87 S 5,737.93 W 6287.94 0.35 9826.29 86.41 226.11 3,047.43 5,422.35 S 5,805.30 W 6361.94 0.92 9919.69 86.50 226.63 3,053.20 5,486.68 S 5,872.77 W 6436.03 0.56 10013.12 86.32 226.96 3,059.05 5,550.51 S 5,940.74 W 6510.55 0.40 10106.39 86.29 227.83 3,065.06 5,613.52 S 6,009.25 W 6585.52 0.93 10199.79 86.34 228.73 3,071.06 5,675.55 S 6,078.81 W 6661.44 0.96 10293.18 84.82 228.99 3,078.26 5,736.81 S 6,148.94 W 6737.82 1.65 10386.54 83.44 229.27 3,087.81 5,797.57 S 6,219.16 W 6814.25 1.51 10479.71 82.15 230.27 3,099.50 5,857.27 S 6,289.73 W 6890.91 1.75 10573.11 82.08 229.09 3,112.31 5,917.13 S 6,360.27 W 6967.55 1.25 10666.37 82.06 227.89 3,125.18 5,978.35 S 6,429.43 W 7042.98 1.27 10759.72 78.76 227.32 3,140.73 6,040.40 S 6,497.40 W 7117.31 3.59 INSITE V8.1.10 Page 3Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10853.46 77.20 225.57 3,160.25 6,103.57 S 6,563.85 W 7190.25 2.47 10946.45 78.16 225.27 3,180.09 6,167.33 S 6,628.55 W 7261.52 1.08 11039.85 78.09 225.15 3,199.31 6,231.73 S 6,693.42 W 7333.02 0.15 11133.12 78.21 224.63 3,218.46 6,296.40 S 6,757.84 W 7404.11 0.56 11225.91 78.45 225.40 3,237.23 6,360.64 S 6,822.11 W 7475.01 0.85 11319.78 78.44 225.67 3,256.03 6,425.06 S 6,887.75 W 7547.28 0.28 11413.03 79.84 226.64 3,273.60 6,488.49 S 6,953.80 W 7619.85 1.82 11506.45 79.73 226.64 3,290.17 6,551.62 S 7,020.64 W 7693.18 0.12 11599.62 79.69 228.99 3,306.82 6,613.17 S 7,088.56 W 7767.40 2.48 11692.84 79.21 232.26 3,323.89 6,671.30 S 7,159.39 W 7844.15 3.49 11786.24 78.68 236.20 3,341.80 6,724.88 S 7,233.75 W 7923.91 4.18 11880.09 80.16 238.06 3,359.04 6,774.94 S 7,311.23 W 8006.38 2.51 11972.92 81.06 239.95 3,374.18 6,822.10 S 7,389.74 W 8089.56 2.23 12066.13 81.40 242.09 3,388.40 6,866.73 S 7,470.32 W 8174.53 2.30 12159.35 82.19 244.71 3,401.70 6,908.03 S 7,552.81 W 8261.04 2.91 12252.31 83.07 246.74 3,413.63 6,945.93 S 7,636.85 W 8348.70 2.36 12345.63 84.53 249.55 3,423.71 6,980.46 S 7,722.94 W 8438.05 3.38 12438.82 85.06 251.30 3,432.16 7,011.55 S 7,810.38 W 8528.36 1.95 12532.15 84.84 252.41 3,440.38 7,040.50 S 7,898.73 W 8619.33 1.21 12625.46 84.33 253.00 3,449.19 7,068.12 S 7,987.42 W 8710.51 0.83 12718.87 84.19 255.62 3,458.53 7,093.25 S 8,076.89 W 8802.18 2.79 12812.16 84.57 256.52 3,467.67 7,115.60 S 8,167.00 W 8894.19 1.04 12905.14 85.36 257.65 3,475.83 7,136.30 S 8,257.27 W 8986.19 1.48 12998.51 86.18 258.34 3,482.71 7,155.67 S 8,348.35 W 9078.84 1.15 13091.82 86.12 258.08 3,488.98 7,174.69 S 8,439.49 W 9171.50 0.29 13254.02 87.85 265.76 3,497.52 7,197.43 S 8,599.73 W 9333.27 4.85 13347.42 90.21 270.87 3,499.10 7,200.18 S 8,693.04 W 9426.32 6.03 13440.84 87.22 270.53 3,501.20 7,199.04 S 8,786.42 W 9519.02 3.22 13534.16 86.98 272.45 3,505.92 7,196.61 S 8,879.58 W 9611.36 2.07 13627.48 89.97 275.10 3,508.40 7,190.47 S 8,972.65 W 9703.20 4.28 13720.79 91.01 276.51 3,507.61 7,181.03 S 9,065.47 W 9794.45 1.88 13814.09 91.17 280.84 3,505.83 7,166.97 S 9,157.67 W 9884.56 4.64 13907.41 92.35 281.30 3,502.97 7,149.06 S 9,249.20 W 9973.60 1.36 14000.79 91.23 281.72 3,500.05 7,130.43 S 9,340.66 W 10062.47 1.28 14094.20 90.64 280.32 3,498.52 7,112.58 S 9,432.33 W 10151.65 1.63 14187.46 90.17 280.25 3,497.86 7,095.93 S 9,524.09 W 10241.05 0.51 14280.77 89.10 278.78 3,498.46 7,080.51 S 9,616.11 W 10330.84 1.95 14374.13 88.30 278.40 3,500.58 7,066.57 S 9,708.40 W 10421.06 0.95 14467.55 88.93 278.85 3,502.84 7,052.56 S 9,800.74 W 10511.32 0.83 14560.81 89.51 280.28 3,504.10 7,037.07 S 9,892.69 W 10601.03 1.65 14654.17 89.60 281.30 3,504.83 7,019.59 S 9,984.39 W 10690.28 1.10 14747.57 90.43 281.05 3,504.81 7,001.49 S 10,076.02 W 10779.39 0.93 14840.72 90.40 283.00 3,504.13 6,982.08 S 10,167.12 W 10867.83 2.09 14934.12 89.87 283.34 3,503.91 6,960.80 S 10,258.06 W 10955.91 0.67 15027.37 89.67 283.05 3,504.29 6,939.52 S 10,348.85 W 11043.84 0.38 INSITE V8.1.10 Page 4Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 15120.69 89.82 283.48 3,504.70 6,918.11 S 10,439.68 W 11131.79 0.49 15214.01 89.90 284.43 3,504.93 6,895.60 S 10,530.24 W 11219.36 1.02 15307.39 87.77 283.14 3,506.83 6,873.36 S 10,620.91 W 11307.06 2.67 15400.74 87.99 284.47 3,510.28 6,851.10 S 10,711.50 W 11394.68 1.44 15494.07 87.99 285.77 3,513.55 6,826.77 S 10,801.54 W 11481.53 1.39 15587.47 88.97 287.12 3,516.03 6,800.34 S 10,891.08 W 11567.66 1.79 15680.83 89.04 288.99 3,517.65 6,771.41 S 10,979.83 W 11652.72 2.00 15773.97 89.33 290.95 3,518.98 6,739.60 S 11,067.36 W 11736.26 2.13 15867.33 89.46 291.54 3,519.96 6,705.78 S 11,154.37 W 11819.06 0.65 15960.72 93.45 294.14 3,517.59 6,669.55 S 11,240.38 W 11900.61 5.10 16054.11 95.90 295.50 3,509.98 6,630.48 S 11,324.86 W 11980.32 3.00 16147.45 93.38 297.38 3,502.43 6,589.06 S 11,408.15 W 12058.60 3.36 16240.89 89.82 297.64 3,499.82 6,545.92 S 11,490.98 W 12136.23 3.82 16334.07 88.73 296.76 3,501.00 6,503.34 S 11,573.84 W 12213.96 1.50 16427.42 87.79 298.06 3,503.84 6,460.38 S 11,656.67 W 12291.61 1.72 16520.87 87.91 298.44 3,507.34 6,416.18 S 11,738.93 W 12368.57 0.43 16614.29 89.25 300.23 3,509.66 6,370.43 S 11,820.34 W 12444.50 2.39 16707.69 88.61 301.98 3,511.40 6,322.19 S 11,900.30 W 12518.72 1.99 16801.09 88.21 300.51 3,513.99 6,273.77 S 11,980.12 W 12592.78 1.63 16894.47 89.75 301.81 3,515.66 6,225.46 S 12,060.01 W 12666.93 2.16 16987.94 90.07 302.12 3,515.80 6,175.98 S 12,139.31 W 12740.36 0.48 17081.27 90.31 303.46 3,515.49 6,125.43 S 12,217.76 W 12812.83 1.46 17174.66 90.24 304.11 3,515.04 6,073.50 S 12,295.38 W 12884.33 0.70 17267.92 90.27 304.90 3,514.63 6,020.67 S 12,372.23 W 12954.96 0.85 17361.67 90.30 306.35 3,514.16 5,966.07 S 12,448.43 W 13024.75 1.55 17454.75 88.81 304.47 3,514.89 5,912.14 S 12,524.29 W 13094.28 2.58 17548.56 89.21 306.25 3,516.51 5,857.86 S 12,600.78 W 13164.39 1.94 17641.68 90.07 307.26 3,517.09 5,802.14 S 12,675.38 W 13232.48 1.42 17735.15 89.37 308.64 3,517.55 5,744.66 S 12,749.09 W 13299.47 1.66 17828.57 89.49 311.04 3,518.48 5,684.82 S 12,820.81 W 13364.24 2.57 17921.90 89.98 312.35 3,518.91 5,622.74 S 12,890.50 W 13426.74 1.50 18015.20 89.34 315.20 3,519.46 5,558.20 S 12,957.86 W 13486.66 3.13 18108.60 89.56 313.10 3,520.36 5,493.15 S 13,024.86 W 13546.18 2.26 18201.95 91.24 312.55 3,519.71 5,429.70 S 13,093.33 W 13607.32 1.89 18295.33 94.75 313.51 3,514.83 5,366.08 S 13,161.48 W 13668.13 3.90 18388.64 96.31 317.10 3,505.84 5,300.07 S 13,226.80 W 13725.85 4.18 18482.03 93.88 320.90 3,497.54 5,229.88 S 13,287.80 W 13778.84 4.82 18575.47 89.75 323.62 3,494.58 5,156.05 S 13,344.95 W 13827.60 5.29 18668.96 88.78 325.50 3,495.78 5,079.89 S 13,399.15 W 13873.17 2.26 18762.38 89.37 326.94 3,497.29 5,002.26 S 13,451.08 W 13916.33 1.67 18855.79 89.36 329.41 3,498.32 4,922.90 S 13,500.33 W 13956.63 2.64 18949.18 89.33 331.05 3,499.39 4,841.84 S 13,546.70 W 13993.88 1.76 19042.62 89.28 332.81 3,500.52 4,759.41 S 13,590.66 W 14028.60 1.88 19136.01 90.41 333.43 3,500.78 4,676.11 S 13,632.89 W 14061.48 1.38 19229.38 89.14 333.26 3,501.14 4,592.66 S 13,674.77 W 14094.02 1.37 INSITE V8.1.10 Page 5Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 19322.68 88.64 332.01 3,502.95 4,509.82 S 13,717.65 W 14127.61 1.44 19416.17 89.93 332.66 3,504.12 4,427.03 S 13,761.05 W 14161.73 1.55 19509.54 90.93 331.08 3,503.42 4,344.69 S 13,805.07 W 14196.50 2.00 19602.73 91.87 331.16 3,501.14 4,263.12 S 13,850.07 W 14232.34 1.01 19696.13 91.45 331.09 3,498.44 4,181.36 S 13,895.15 W 14268.24 0.46 19789.53 91.99 331.78 3,495.63 4,099.37 S 13,939.79 W 14303.67 0.94 19882.93 90.75 330.98 3,493.40 4,017.41 S 13,984.51 W 14339.19 1.58 19976.33 89.88 331.29 3,492.89 3,935.61 S 14,029.60 W 14375.09 0.99 20069.76 90.30 332.30 3,492.74 3,853.28 S 14,073.76 W 14410.00 1.17 20163.03 90.92 332.20 3,491.75 3,770.74 S 14,117.18 W 14444.17 0.67 20256.43 90.74 333.22 3,490.39 3,687.75 S 14,160.00 W 14477.68 1.11 20349.82 91.25 331.67 3,488.77 3,604.97 S 14,203.20 W 14511.59 1.75 20443.18 91.30 330.08 3,486.69 3,523.43 S 14,248.62 W 14547.86 1.70 20536.35 91.11 328.11 3,484.73 3,443.51 S 14,296.46 W 14586.70 2.12 20629.75 89.04 325.35 3,484.61 3,365.43 S 14,347.69 W 14629.11 3.69 20723.01 88.66 323.87 3,486.48 3,289.42 S 14,401.69 W 14674.50 1.64 20816.36 90.34 323.82 3,487.30 3,214.06 S 14,456.76 W 14721.02 1.80 20909.67 90.16 326.08 3,486.89 3,137.67 S 14,510.34 W 14765.96 2.43 21003.09 88.50 327.11 3,487.98 3,059.70 S 14,561.77 W 14808.58 2.09 21096.49 88.30 327.94 3,490.59 2,980.93 S 14,611.90 W 14849.82 0.91 21189.76 88.23 330.16 3,493.42 2,900.98 S 14,659.84 W 14888.76 2.38 21283.08 89.00 332.22 3,495.67 2,819.24 S 14,704.80 W 14924.53 2.36 21376.42 88.79 332.70 3,497.47 2,736.50 S 14,747.95 W 14958.40 0.56 21469.67 89.76 331.90 3,498.65 2,653.94 S 14,791.29 W 14992.48 1.35 21563.09 90.45 331.25 3,498.48 2,571.79 S 14,835.76 W 15027.73 1.01 21656.26 91.01 331.18 3,497.29 2,490.14 S 14,880.62 W 15063.42 0.61 21749.48 90.15 331.59 3,496.35 2,408.31 S 14,925.26 W 15098.87 1.02 21842.88 89.70 330.86 3,496.47 2,326.44 S 14,970.22 W 15134.63 0.92 21936.22 90.76 331.14 3,496.10 2,244.81 S 15,015.47 W 15170.71 1.17 22029.56 91.94 332.33 3,493.90 2,162.62 S 15,059.66 W 15205.68 1.80 22122.77 88.22 333.92 3,493.77 2,079.50 S 15,101.79 W 15238.49 4.34 22215.99 88.85 335.76 3,496.15 1,995.15 S 15,141.40 W 15268.67 2.09 22308.95 88.92 338.85 3,497.96 1,909.42 S 15,177.26 W 15294.96 3.32 22402.27 89.34 339.54 3,499.38 1,822.19 S 15,210.40 W 15318.40 0.87 22495.46 90.46 340.28 3,499.54 1,734.67 S 15,242.41 W 15340.67 1.44 22588.79 90.54 339.33 3,498.73 1,647.09 S 15,274.63 W 15363.15 1.02 22682.10 88.72 338.29 3,499.33 1,560.09 S 15,308.35 W 15387.19 2.25 22727.29 88.88 336.97 3,500.27 1,518.31 S 15,325.55 W 15399.72 2.94 INSITE V8.1.10 Page 6Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 Survey Report 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 263.74 degrees (True) - A total correction of 19.03 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 22,727.29 feet is 15,400.57 feet along 264.34 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 7Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 Survey Report WELL INFORMATION Created On : Mar 06 2015 Customer :ENI Petroleum Well Name :SP31-W7 L1 PB1 Job Number :AK-XX-0901938178 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 0.00 170.00 0.00 0.00 N 0.00 E 0.00 0.00 40.67 0.00 170.00 40.67 0.00 N 0.00 E 0.00 0.00 117.12 0.49 295.23 117.12 0.14 N 0.30 W 0.28 0.64 160.25 0.52 307.70 160.25 0.34 N 0.62 W 0.58 0.26 252.75 0.11 208.40 252.75 0.52 N 0.99 W 0.93 0.59 345.55 0.24 156.28 345.55 0.26 N 0.96 W 0.92 0.21 404.26 0.85 175.20 404.25 0.29 S 0.87 W 0.90 1.07 453.58 1.44 176.46 453.56 1.27 S 0.80 W 0.93 1.20 546.38 2.37 181.61 546.31 4.35 S 0.78 W 1.25 1.02 639.23 3.13 187.53 639.05 8.78 S 1.17 W 2.12 0.87 732.55 5.72 194.31 732.09 15.82 S 2.65 W 4.36 2.83 825.89 8.43 200.27 824.71 26.74 S 6.17 W 9.05 3.00 919.14 9.93 209.80 916.77 40.13 S 12.54 W 16.84 2.29 1012.56 12.68 220.00 1,008.38 54.98 S 23.13 W 28.99 3.63 1070.31 13.98 224.79 1,064.57 64.79 S 32.12 W 39.00 2.95 1163.53 15.32 233.30 1,154.77 80.14 S 49.93 W 58.37 2.72 1256.93 17.83 233.41 1,244.28 96.04 S 71.31 W 81.36 2.69 1350.27 22.55 229.81 1,331.86 116.12 S 96.47 W 108.56 5.23 1443.61 24.98 229.24 1,417.28 140.54 S 125.08 W 139.66 2.61 1536.82 26.37 229.19 1,501.29 166.92 S 155.65 W 172.93 1.49 1630.04 25.79 227.95 1,585.02 194.04 S 186.38 W 206.43 0.85 1723.00 25.01 228.64 1,668.99 220.57 S 216.15 W 238.91 0.90 1816.32 24.93 228.64 1,753.59 246.60 S 245.72 W 271.14 0.09 1909.51 24.77 228.40 1,838.15 272.54 S 275.06 W 303.13 0.20 2002.84 29.45 228.92 1,921.20 300.61 S 306.99 W 337.94 5.02 2096.15 31.33 227.61 2,001.69 332.04 S 342.20 W 376.37 2.14 2189.56 35.22 227.81 2,079.77 366.52 S 380.11 W 417.81 4.17 2282.85 37.58 227.20 2,154.85 403.92 S 420.92 W 462.45 2.56 2375.83 41.35 227.58 2,226.62 443.91 S 464.41 W 510.05 4.06 2469.20 45.03 227.83 2,294.68 486.91 S 511.68 W 561.72 3.95 INSITE V8.1.10 Page 1Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2562.51 48.81 225.62 2,358.41 533.64 S 561.25 W 616.10 4.40 2597.52 49.84 226.08 2,381.23 552.14 S 580.31 W 637.05 3.11 2697.41 53.60 226.71 2,443.10 606.20 S 637.08 W 699.38 3.80 2729.41 55.85 225.72 2,461.58 624.28 S 655.94 W 720.10 7.47 2822.79 60.45 225.71 2,510.84 679.64 S 712.71 W 782.57 4.93 2916.15 64.81 226.84 2,553.75 736.92 S 772.62 W 848.37 4.79 3009.44 68.29 228.86 2,590.88 794.33 S 836.07 W 917.70 4.23 3102.86 71.06 227.82 2,623.32 852.56 S 901.51 W 989.09 3.14 3196.24 74.32 227.56 2,651.10 912.56 S 967.42 W 1061.16 3.50 3289.95 77.39 227.39 2,674.00 973.98 S 1,034.38 W 1134.42 3.28 3383.06 80.04 228.06 2,692.22 1,035.39 S 1,101.94 W 1208.27 2.93 3476.38 82.35 227.92 2,706.50 1,097.11 S 1,170.46 W 1283.11 2.48 3569.70 84.40 227.64 2,717.27 1,159.40 S 1,239.10 W 1358.14 2.22 3663.01 86.84 226.95 2,724.39 1,222.49 S 1,307.47 W 1432.97 2.72 3756.31 86.93 226.64 2,729.46 1,286.27 S 1,375.37 W 1507.43 0.35 3849.63 87.10 226.64 2,734.32 1,350.26 S 1,443.13 W 1581.76 0.18 3943.01 87.30 226.71 2,738.89 1,414.25 S 1,510.98 W 1656.18 0.23 4036.42 86.42 226.81 2,744.00 1,478.14 S 1,578.92 W 1730.69 0.95 4129.68 86.98 226.40 2,749.37 1,542.11 S 1,646.58 W 1804.91 0.74 4222.99 87.82 226.65 2,753.60 1,606.24 S 1,714.22 W 1879.14 0.94 4316.35 87.49 227.18 2,757.42 1,669.96 S 1,782.35 W 1953.81 0.67 4409.77 86.29 226.52 2,762.49 1,733.76 S 1,850.40 W 2028.42 1.47 4503.03 86.87 226.07 2,768.06 1,798.08 S 1,917.70 W 2102.33 0.79 4596.39 87.35 226.83 2,772.76 1,862.32 S 1,985.28 W 2176.51 0.96 4689.79 87.17 226.42 2,777.23 1,926.39 S 2,053.09 W 2250.90 0.48 4782.94 87.46 227.29 2,781.59 1,990.02 S 2,120.98 W 2325.33 0.98 4876.34 87.19 227.41 2,785.95 2,053.23 S 2,189.60 W 2400.43 0.32 4969.59 86.51 227.34 2,791.07 2,116.29 S 2,258.11 W 2475.41 0.73 5062.91 87.13 228.10 2,796.25 2,178.97 S 2,327.05 W 2550.77 1.05 5156.23 86.83 228.09 2,801.17 2,241.21 S 2,396.40 W 2626.50 0.32 5249.61 86.70 228.25 2,806.44 2,303.39 S 2,465.87 W 2702.33 0.22 5342.96 87.39 228.82 2,811.25 2,365.12 S 2,535.73 W 2778.51 0.96 5436.29 86.88 228.58 2,815.91 2,426.64 S 2,605.76 W 2854.83 0.60 5530.33 86.84 228.56 2,821.07 2,488.77 S 2,676.16 W 2931.58 0.05 5623.05 86.86 227.80 2,826.16 2,550.51 S 2,745.15 W 3006.90 0.82 5716.19 87.05 226.92 2,831.11 2,613.51 S 2,813.57 W 3081.78 0.97 5809.55 86.92 226.57 2,836.02 2,677.39 S 2,881.47 W 3156.24 0.40 5902.94 87.02 226.10 2,840.96 2,741.78 S 2,948.94 W 3230.32 0.51 5996.33 86.89 225.64 2,845.92 2,806.72 S 3,015.87 W 3303.94 0.51 6089.67 87.11 225.72 2,850.80 2,871.84 S 3,082.56 W 3377.33 0.25 6183.11 87.08 225.52 2,855.54 2,937.11 S 3,149.26 W 3450.75 0.22 6276.29 86.80 226.77 2,860.51 3,001.58 S 3,216.35 W 3524.47 1.37 6369.64 86.87 228.16 2,865.67 3,064.59 S 3,285.03 W 3599.61 1.49 6463.09 86.93 229.34 2,870.72 3,126.11 S 3,355.19 W 3676.06 1.26 6556.51 86.95 229.72 2,875.71 3,186.66 S 3,426.16 W 3753.20 0.41 INSITE V8.1.10 Page 2Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6649.91 87.07 229.20 2,880.58 3,247.29 S 3,497.04 W 3830.27 0.57 6743.31 87.05 228.56 2,885.37 3,308.63 S 3,567.31 W 3906.81 0.68 6836.69 86.61 228.16 2,890.53 3,370.58 S 3,636.99 W 3982.83 0.64 6930.16 87.04 228.24 2,895.71 3,432.78 S 3,706.56 W 4058.77 0.47 7023.49 87.41 228.30 2,900.23 3,494.83 S 3,776.13 W 4134.69 0.40 7116.88 86.87 227.81 2,904.89 3,557.18 S 3,845.50 W 4210.45 0.78 7210.14 87.08 227.06 2,909.81 3,620.17 S 3,914.09 W 4285.50 0.83 7303.61 86.85 226.16 2,914.76 3,684.29 S 3,981.92 W 4359.92 0.99 7396.97 87.21 226.42 2,919.60 3,748.72 S 4,049.32 W 4433.94 0.48 7490.50 86.64 226.14 2,924.61 3,813.27 S 4,116.82 W 4508.07 0.68 7583.90 87.00 226.37 2,929.79 3,877.75 S 4,184.19 W 4582.07 0.46 7677.37 86.76 226.15 2,934.88 3,942.28 S 4,251.62 W 4656.14 0.35 7770.79 87.16 225.48 2,939.84 4,007.30 S 4,318.51 W 4729.72 0.83 7864.12 87.31 225.37 2,944.34 4,072.72 S 4,384.92 W 4802.86 0.20 7957.42 87.03 225.32 2,948.95 4,138.22 S 4,451.20 W 4875.90 0.30 8050.82 86.98 225.50 2,953.83 4,203.70 S 4,517.63 W 4949.07 0.20 8144.17 86.86 226.07 2,958.84 4,268.70 S 4,584.44 W 5022.57 0.62 8237.55 87.84 226.53 2,963.16 4,333.15 S 4,651.88 W 5096.63 1.16 8330.86 86.88 226.70 2,967.46 4,397.17 S 4,719.62 W 5170.95 1.04 8424.25 87.47 227.22 2,972.06 4,460.83 S 4,787.79 W 5245.66 0.84 8517.69 87.16 227.56 2,976.44 4,524.02 S 4,856.48 W 5320.83 0.49 8611.18 86.71 227.80 2,981.44 4,586.88 S 4,925.51 W 5396.30 0.55 8704.60 86.66 226.93 2,986.84 4,650.05 S 4,994.12 W 5471.39 0.93 8798.01 86.97 227.08 2,992.03 4,713.65 S 5,062.34 W 5546.13 0.37 8891.40 86.89 226.52 2,997.03 4,777.48 S 5,130.32 W 5620.67 0.60 8984.84 87.11 226.49 3,001.92 4,841.71 S 5,198.01 W 5694.96 0.24 9078.23 86.95 226.77 3,006.76 4,905.76 S 5,265.81 W 5769.34 0.34 9171.60 86.99 226.33 3,011.69 4,969.88 S 5,333.50 W 5843.62 0.47 9266.04 86.75 226.68 3,016.85 5,034.78 S 5,401.90 W 5918.69 0.45 9359.53 86.56 225.76 3,022.31 5,099.36 S 5,469.29 W 5992.72 1.00 9452.90 87.09 226.30 3,027.48 5,164.08 S 5,536.38 W 6066.47 0.81 9546.09 86.89 225.59 3,032.37 5,228.79 S 5,603.26 W 6140.01 0.79 9639.49 86.89 226.43 3,037.44 5,293.57 S 5,670.36 W 6213.77 0.90 9732.89 87.22 226.40 3,042.24 5,357.87 S 5,737.93 W 6287.94 0.35 9826.29 86.41 226.11 3,047.43 5,422.35 S 5,805.30 W 6361.94 0.92 9919.69 86.50 226.63 3,053.20 5,486.68 S 5,872.77 W 6436.03 0.56 10013.12 86.32 226.96 3,059.05 5,550.51 S 5,940.74 W 6510.55 0.40 10106.39 86.29 227.83 3,065.06 5,613.52 S 6,009.25 W 6585.52 0.93 10199.79 86.34 228.73 3,071.06 5,675.55 S 6,078.81 W 6661.44 0.96 10293.18 84.82 228.99 3,078.26 5,736.81 S 6,148.94 W 6737.82 1.65 10386.54 83.44 229.27 3,087.81 5,797.57 S 6,219.16 W 6814.25 1.51 10479.71 82.15 230.27 3,099.50 5,857.27 S 6,289.73 W 6890.91 1.75 10573.11 82.08 229.09 3,112.31 5,917.13 S 6,360.27 W 6967.55 1.25 10666.37 82.06 227.89 3,125.18 5,978.35 S 6,429.43 W 7042.98 1.27 10759.72 78.76 227.32 3,140.73 6,040.40 S 6,497.40 W 7117.31 3.59 INSITE V8.1.10 Page 3Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10853.46 77.20 225.57 3,160.25 6,103.57 S 6,563.85 W 7190.25 2.47 10946.45 78.16 225.27 3,180.09 6,167.33 S 6,628.55 W 7261.52 1.08 11039.85 78.09 225.15 3,199.31 6,231.73 S 6,693.42 W 7333.02 0.15 11133.12 78.21 224.63 3,218.46 6,296.40 S 6,757.84 W 7404.11 0.56 11225.91 78.45 225.40 3,237.23 6,360.64 S 6,822.11 W 7475.01 0.85 11319.78 78.44 225.67 3,256.03 6,425.06 S 6,887.75 W 7547.28 0.28 11413.03 79.84 226.64 3,273.60 6,488.49 S 6,953.80 W 7619.85 1.82 11506.45 79.73 226.64 3,290.17 6,551.62 S 7,020.64 W 7693.18 0.12 11599.62 79.69 228.99 3,306.82 6,613.17 S 7,088.56 W 7767.40 2.48 11692.84 79.21 232.26 3,323.89 6,671.30 S 7,159.39 W 7844.15 3.49 11786.24 78.68 236.20 3,341.80 6,724.88 S 7,233.75 W 7923.91 4.18 11880.09 80.16 238.06 3,359.04 6,774.94 S 7,311.23 W 8006.38 2.51 11972.92 81.06 239.95 3,374.18 6,822.10 S 7,389.74 W 8089.56 2.23 12066.13 81.40 242.09 3,388.40 6,866.73 S 7,470.32 W 8174.53 2.30 12159.35 82.19 244.71 3,401.70 6,908.03 S 7,552.81 W 8261.04 2.91 12252.31 83.07 246.74 3,413.63 6,945.93 S 7,636.85 W 8348.70 2.36 12345.63 84.53 249.55 3,423.71 6,980.46 S 7,722.94 W 8438.05 3.38 12438.82 85.06 251.30 3,432.16 7,011.55 S 7,810.38 W 8528.36 1.95 12532.15 84.84 252.41 3,440.38 7,040.50 S 7,898.73 W 8619.33 1.21 12625.46 84.33 253.00 3,449.19 7,068.12 S 7,987.42 W 8710.51 0.83 12718.87 84.19 255.62 3,458.53 7,093.25 S 8,076.89 W 8802.18 2.79 12812.16 84.57 256.52 3,467.67 7,115.60 S 8,167.00 W 8894.19 1.04 12905.14 85.36 257.65 3,475.83 7,136.30 S 8,257.27 W 8986.19 1.48 12998.51 86.18 258.34 3,482.71 7,155.67 S 8,348.35 W 9078.84 1.15 13091.82 86.12 258.08 3,488.98 7,174.69 S 8,439.49 W 9171.50 0.29 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 263.74 degrees (True) - A total correction of 19.03 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 13,091.82 feet is 11,077.06 feet along 229.63 degrees (True) INSITE V8.1.10 Page 4Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 PB1 Survey Report WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 5Job No:AK-XX-0901938178 Well Name:SP31-W7 L1 PB1 Survey Report