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Home My WebLink About214-100CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: SI07-SE4 (PTD# 214-100) TxIA Communication Date:Tuesday, February 22, 2022 2:51:04 PM Attachments:image001.png image002.png SI07-SE4 Schematic_Completed 02-14-2022.pdf From: Wallace, Chris D (OGC) Sent: Tuesday, February 22, 2022 2:13 PM To: Lopez Keith <Keith.Lopez@eni.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; Salazar, Grace (OGC) <grace.salazar@alaska.gov> Cc: Rupert Stephanie <Stephanie.Rupert@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Brown Timothy <Timothy.Brown@eni.com>; Hardy Scott <Scott.Hardy@eni.com> Subject: RE: SI07-SE4 (PTD# 214-100) TxIA Communication Keith, The plan below satisfies the well integrity requirements. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793- 1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793- 1250 or chris.wallace@alaska.gov. From: Lopez Keith <Keith.Lopez@eni.com> Sent: Tuesday, February 22, 2022 9:57 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Salazar, Grace (OGC) <grace.salazar@alaska.gov> Cc: Rupert Stephanie <Stephanie.Rupert@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Brown Timothy <Timothy.Brown@eni.com>; Hardy Scott <Scott.Hardy@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: RE: SI07-SE4 (PTD# 214-100) TxIA Communication Mr. Wallace, ENI has completed the tubing leak diagnostics on SI07 and successfully set a tubing patch over the one suspected leak. With further diagnostics we believe the TxIA communication has been corrected with this patch. ENI’s plan is to: 1. Thermally stabilize the well while on injection. As always, monitor trends for any indication of integrity concerns. 2. Conduct an initial MIT-IA to 1,500 psi. 3. Give the AOGCC 48 hour notice for a witnessed MIT and conduct the official MIT-IA to 1,500 psi. We had a state inspector at SID this weekend for SVS testing and there was some discussion as to whether the MIT-IA or a pressure test of the tubing should be conducted to prove integrity to the state. Can you please verify if the current plan will satisfy the state of the wells integrity or suggest alternate testing you may require? Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com From: Lopez Keith <Keith.Lopez@eni.com> Sent: Thursday, January 13, 2022 10:55 AM To: chris.wallace@alaska.gov; Regg, James B (CED) <jim.regg@alaska.gov>; grace.salazar@alaska.gov Cc: Hart David <David.Hart@eni.com>; Giraud Hector <Hector.Giraud@eni.com>; Rupert Stephanie <Stephanie.Rupert@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Atencio Lucas <Lucas.Atencio@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Lopez Keith <Keith.Lopez@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Betts Eric <Eric.Betts@external.eni.com> Subject: SI07-SE4 (PTD# 214-100) TxIA Communication Mr. Wallace, Yesterday (01-12-22), ENI noticed a concern with tubing by inner annulus communication on SI07-SE4. Overnight, we bled the pressure off of the IA and saw the pressure immediately return to the annulus. The injector has been shut in and freeze protected and will remain shut in until further diagnostics can be conducted with slickline/eline. SI07-SE4 last passed it’s 4-year MIT on 05/01/21. Please let me know of any concerns or further data the AOGCC requires. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com ----------------------------------------------------------------------------------------------------------------------------------------------------- ------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ 13-3/8" 68 ppf, Surf. Casing, 3,035' MD, 2,476' TVD44° Inc9-5/8" 40 ppf, H563,Intermediate Casing, 6,241' MD, 4,070' TVD, 82° Inc4-½”,12.6 ppf, H563, Production Tubing4-½” 11.6 ppf, H521Production LinerZonal Isolation PackersInjection Control DevicesHS Packer, 5,908' MD, 3,989' TVD, 69° IncConfidentialNikaitchuq Field – Spy IslandAs Completed Feb 14th, 20222,175' MD, 1,866' TVD, 45º Inc - 4-½” x 1" KBMG GLM, 2,000 psi A to T shear valve2,164' MD, 1,859' TVD- 3.81" X-nipple for possible injection valve5,945' MD - HAL Mirage Plug with Auto-fill valve 5,850' MD - 3.81" X-nipple SI07-SE4 Injector Monobore with Injection Control 6,066' MD – Top of SLZXP Liner Hanger/Packer 5,931' MD - 3.725" XN (inserted Nipple reducer 2-7/8" 6.4# XN Style Nipple with 2.205" NoGo XN Profile 2-7/8" 6.4# Hydril 511 Box x Full Mule Shoe down4-½” Ecc-Nose Guide Shoe, 16,110' MD, 4,075' TVD89° Inc6,068' MD – Bottom of entry guide 0TD 16,130' MD,4,076' TVD, 89° IncICD #1 15,629 ICD #10 10,645ICD #2 14,660 ICD #11 10,064ICD #3 14,134 ICD #12 9,574ICD #4 13,648 ICD #13 9,165ICD #5 13,121 ICD #14 8,624ICD #6 12,658 ICD #15 8,137ICD #7 12,166 ICD #16 7,645ICD #8 11,661 ICD #17 7,144ICD #9 11,135 ICD #18 6,654Swell Packer #1 15,182Swell Packer #2 12,987Swell Packer #3 12,030Swell Packer #4 10,196Swell Packer #5 8,991Swell Packer #6 7,47100Tubing patch TOPE= 5,666.3', BOPE=5,698' ELMD, Patch ID=2.992" CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: SI07-SE4 (PTD# 214-100) TxIA Communication Date:Thursday, January 13, 2022 11:39:33 AM Attachments:image001.png image002.png From: Lopez Keith <Keith.Lopez@eni.com> Sent: Thursday, January 13, 2022 10:55 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Salazar, Grace (OGC) <grace.salazar@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Giraud Hector <Hector.Giraud@eni.com>; Rupert Stephanie <Stephanie.Rupert@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Atencio Lucas <Lucas.Atencio@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Lopez Keith <Keith.Lopez@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Betts Eric <Eric.Betts@external.eni.com> Subject: SI07-SE4 (PTD# 214-100) TxIA Communication Mr. Wallace, Yesterday (01-12-22), ENI noticed a concern with tubing by inner annulus communication on SI07-SE4. Overnight, we bled the pressure off of the IA and saw the pressure immediately return to the annulus. The injector has been shut in and freeze protected and will remain shut in until further diagnostics can be conducted with slickline/eline. SI07-SE4 last passed it’s 4-year MIT on 05/01/21. Please let me know of any concerns or further data the AOGCC requires. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com ------------------------------------------------------------------------------------------------------------------------------------------------------ ------------------ Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 5, 2021 TO: Jim Regg P.I. Supervisor I`(.5/14 (u'u SUBJECT: Mechanical Integrity Tests Ent US Operating Company Ina 5107-SE4 FROM: Guy Cook NIKAITCHUQ S107-SE4 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Satre NON -CONFIDENTIAL Comm Well Name NIKAITCHUQ 5107-SE4 API Well Number 50-629-23519-00-00 Inspector Name: Guy Cook Permit Number: 214-100-0 Inspection Date: 5/1/2021 Insp Num: mitGDC210501111914 Rel Insp Num: ies d w be 4e- zozo Wednesday, May 5, 2021 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well - Type Inj N' -TVD 3oao u I 534 534 533 - 533 PTD 2141000 Type Test SPT iTest psi Iz00 IA I 827 nas 1721 - 1709 - — - BBL Pumped: IA - BBL Returned: i s - OA 240 310 { 260 - 250 - Interval 4vaTsr Notes: Testing done with a triplex pump, calibrated gauges and a bleed trailer. ies d w be 4e- zozo Wednesday, May 5, 2021 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,December 28,2016 P.I.Supervisor {l LZ SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC SI07-SE4 FROM: Jeff Jones NIKAITCHUQ SI07-SE4 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Jj2 NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ SI07-SE4 API Well Number 50-629-23519-00-00 Inspector Name: Jeff Jones Permit Number: 214-100-0 Inspection Date: 12/10/2016 Insp Num: mitJJ161213201433 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well SI07-SE4 - Type Inj W -TVD 3989 - Tubing 498 498 - 498 - 499 - PTD 2141000 Type Test SPT Test psi 1500 - IA 632 1670 - 1646 - 1639 . Interval 4'TST P/F P • OA 240 280 - 250 250 - Notes: 2.2 barrels diesel pumped. 1 well inspected,no exeptions noted. - SCANNED APP 0 5 201 Wednesday,December 28,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,September 10,2015 Jim Regg � / 'r�� SUBJECT: Mechanical Integrity Tests P.I.Supervisor r Z I ENI US OPERATING CO INC 5107-SE4 FROM: Jeff Jones NIICAITCHUQ 5107-5E4 Petroleum Inspector �y , ; '.h, Src: Inspector t�`�1`�� Reviewed By: P.I.Supry J6e---- NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ SI07-SE4 API Well Number 50-629-23519-00-00 Inspector Name: Jeff Jones Permit Number: 214-100-0 Inspection Date: 8/13/2015 Insp Num: mitJJ150906063211 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S107-5E4 Type Inj ; W 1TVD 7 3989 Tubing 1 389 � 389 389 - 389 - PTD rn1410 'Type Test, }Test psi 1500 • IA 759 1649 - 1626 -1_ 1622 - � r zlal000 SPT Interval l-- P/F 1 P � OA 240 260 - 250 245- Notes: 1.5 BBLS diesel pumped. 1 well inspected,no exceptions noted. - Thursday,September 10,2015 Page 1 of I • 0 o o o • 2I ~I 2I ~I 0 N o) N co co o 00 0) cC 0C 0C Q co } I \ 7 1 00 cI l cl c c pl :5NU I � NN � � (DI �I � I I I �I I m o I a a @ bm 0 Cl) oI in co iC) LL a O a) — ai CO ai m co I o 0 0 0 d "8 Z E �I N LL1 E w in 0 0 WI J <(/) D NSI N .T OI w WI T .� .1- < Q c m iL rn it > o > rn > > "> > co o 1 2 _ N 'N N(j I� in r- f0 r- w r- in N- iq h M r� -) ' I u� E 0. 0 0 o•y o f o1 oz o1 o1 o Z N I O N! c a) N (n LU to cn a) (n <n C co Ct 0_ cn W cn c „!!c0 03 4 p o c! fl ai ui I ui n ui I • ai I ai I ai ai ! 0 d0 co OU co 0O LLD -O LLL IlOO IO Ilpm LLQ U E U� U W U—- O— � U p C.) 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Q I I' III III i C.) H 0 c LL (.) N II I O " ` z LU W IX 0.0 0 LU N 7 , C) Z w II Z QN I a) 7 I J o w a � ' 2 � o I N NaI O M E C� a N O C w Cy U a) I o Q J EE 1 I— Co a v W N LoII oN 2 O M C7) N- W v6 I 7 M _ i 0 o Q 0III E ° Q ° 15 I EoI I, p d U I E11 ca Z I d LO V 0 0 N N N 0 N A- N 1 N 00 F W m T F N N I1 _ 6 > d W m X •L o V 0 w c D M• Z c N 0 inV o c0 0< OC a a. • J 'e a .2 al la C ) 0 a 2 0 O ct c 0 I c°. RECEIVED • STATE OF ALASKA • JUL. 0 9 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned P Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE WDSPL ❑ No. of Completions: _1 Service E Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ENI US Operating Co. Inc. Aband.: • 6/12/2015 214-100 3.Address: 7. Date$Spudded: M. 15.API Number: 3800 Centerpoint Drive, Ste. 300,Anchorage,AK 99503 • 5/19/2015 50-629-23519-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 4478.4 FSL 1225.7 FEL S19 T14N R9E UM •6/6/2015 S107-SE4 ' Top of Productive Interval: 9. KB(ft above MSL):".53.9 17. Field/Pool(s): 797 FSL 4733 FEL 17 T14N R9EUM GL(ft above MSL): .13.1 Nikaitchuq/Schrader Bluff Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 258 FSL 2042 FEL 21 T14N R9EUM N/A ADL 0391283, 0388583, 0388582 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 511683.97 y- 6053660.34 Zone- 4 .16130'MD/4076'TVD . ADL 417493 TPI: x- 513448.13 y- 6055261.80 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 521449.03 y- 6049461.86 Zone- 4 N/A 2045'MD/1775'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 13.1 (ft MSL) , N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary GR/RES/NEU/Den/SonicI idQ,b5S /`t'x 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20 178.89 X-65 37 160 37 160 Driven N/A N/A 13.375 68 L-80 36.95 3035 36.95 2476 16 10.7#Lead: 449 bbls;12.5#Tail:81 bbls N/A 9.625 40 L-80 35.63 6241 35.63 4070 12.25 12.5 ppg LiteCRETE:135 bbls N/A 4.5 11.6 L-80 6066 16110 4033 4075 8.75 Liner with ICD&Swelling Packer N/A 24.Open to production or injection? Yes ❑✓ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4.5 6,068 5,908'MD/3,989'TVD Liner with ICD iiii _J., � ki i, 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. i r___ L Was hydraulic fracturing used during completion? Yes❑ No 0 • Per 20 AAC 25.283(i)(2)attach electronic and printed information � ..' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period -p-N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. N/A N/A 24-Hour Rate - N/A N/A N/A N/A Form 10-407 Revised 5/2015 bJ Q 3ll$116 ,,,4 CON ILJE DQ rinS*UG 1 2015 Submit ORIGINIAL only 28. CORE DATA Conventional ) Yes ❑ No ❑ Sidewall Core es No 7 If Yes, list formations and intervals cored(MD/TV , From/To), and summarize lithology and presence of of,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� Permafrost-Top surf surf If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 2045 1775 Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Top Ugnu 2745 2268 Top Lower Ugnu 4976 3553 Top Schrader Bluff 5564 3844 Top N Sand 5720 3913 Top OA Sand 6230 4069 Formation at total depth: OA 16130 4076 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary, Cement reports Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Giuseppe Maugeri Email: giuseppe.maugeri@enipetroleum.com Printed Name: Marc Kuck Title: Drilling and Completion Engineering Manager Signature: Phone: (907)865-3328 Date: 6/24/2015 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: 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 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records 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. Pursuant to 20 AAC 25.071,submit detailed descriptions, core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. 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. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only c o C V • N Ci j •C d o ? m 0 c > c� W N p •C o ,� -` M C Eco w � o Zoo fa_ O '- 0 .. U) �' 00 . ... 00 0 V O \ d O (/' a ,F L Cl) m. A a r. =.w,! a),„1 = 0 a 4 r`i'! 2 a) xvolopetLO aD > CO C o CO o 11- 0 > V o a C O N = N " Qp 4r 0) > N - O CO N a-+ o C 0Q= d r T- - 0 - c 0) c ate." \ o O J min 4 d Cn — cn CO 0) . C 0 = Q 0- X '5 O L J o = / - "C) MIK L. V ° x 0) co E p 5 c� O = a) _N o co •� >o - L1 . . N > Ta v ♦O—,,, 2 - o Z o oo p = ca G) V c a X J � N v V c v m .� X U a - QI ca a a) C -c3 �' I . COr0 X ti ❑ 0 Am Tr � � � U as _ C6 0 Ex) N _ 2 to co 2 CO o °�° L. ti ' ❑ ; > M ❑ In �O co N > 1 2 d a) c CO (n L o) i 2 co L6 ) O co oo m 0) allo N- M CO rn i r 0op tri (4cNi O 00 ti C 0 I- L.0i cO 2 o \-/-' N M C d. Lf) +.`Q ,,'� *k # *k 4 w CO r O rP: �s Y Y Y Y Y Y o ,, ,,,,. c° u) cn u) U) U) U) To 0 ' O C o 0) o0 co" ti N- (0 o 0 Q (—j �¢." O 0 O N. N M 1- V) Co I` CO ❑ a) > v Tt Ft 4 t Ft Ft Ft Tt I CO" 0 y= LO H C ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ CI 35 N 2 Q a D) i - , 0 0 0 0 0 0 0 C) U = \ M to ca G 0 co co — co co cfl (.2 1 Cfl O LO COo ca M to v M M N N . I C d- T CO 4 a , , r- e-- r r r r r el co I 0 0 0 0 0 0 0 0 0 Eni E&P Divisio. Well N 07-SE4 OR EN/Petroleum Co.Inc. Daily Report Well Code:27981 Field Name: NIKIATCHUK • API/UW:50-629-23519-00-00 n Date:5/16/2015 - Report#: 1 e�I ("f page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F L) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S107-5E4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 -2.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 107.0 1.7 Clear WC 25° S @ 15 MPH Daily summary operation 24h Summary Move Rockwasher and remove Berming.Cont.to remove ODS suitcases and prep for rig move.Skid rig floor.Move Matt Boards and discard Herculite.Begin snow and ice removal. SIMOPS Prep Diverter section for removal.Prepare pad for moving Pits to west end.Cont.to set Matt Boards for pad.Move Pit complex and stage.Remove Diverter line section for rig move to SI07-SE4.Pull Sub complex off SP04-SE5 and stage.Move Matt Boards,pull Herculite and remove ice and prep pad under Sub Complex.SIMOPS Work on MP2's and housekeeping.Relocate Well Bay Equip.Remove hatch on Well Bay.Rebuild 4-way valve on Koomey.Remove wheel well door on Pit Complex. Operation at 07.00 Prep pad and work on MP2's. 24h Forecast Cont.removing ice and prepping pad.Lay down Herculite and Matt Boards.Move rig. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr)_Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00-MOB A 2 P PJSM Move Rockwasher and remove Berming.Cont.to remove ODS suitcases and prep for rig move.Skid rig floor.Move Matt Boards and discard Herculite.Begin snow and ice removal. SIMOPS Prep Diverter section for removal.Prepare pad for moving Pits to west end. 12:00 00:00 12.00 24.00-MOB A 2 P PJSM Cont.to set Matt Boards for pad.Move Pit complex and stage.Remove Diverter line section for ng move to SI07- SE4.Pull Sub complex off SP04-SE5 and stage.Move Matt Boards,pull Herculite and remove ice and prep pad under Sub Complex.SIMOPS Work on MP2's and housekeeping.Relocate Well Bay Equip.Remove hatch on Well Bay.Rebuild 4- way valve on Koomey.Remove wheel well door on Pit Complex. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Bruce Simonson ENI Drilling Supv. 907-685-0715 Oliver Amend ENI Drilling Supv. 907-685-0715 Wade Thomas ENI Rig Clerk Greg Parker ENI Matls Coordinator 907-980-7545 Ken Bogner ENI Expediter 907-980-7545 Troy England ENI HSE Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.cam 907-685-0716 Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 5/14/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) Eni E&P Divisio. well N 07-SE4 OR ENI Petroleum Co.Inc. Daily Report. Well Code:27981 Field Name:NIKIATCHUK 2^n Date:5/17/2015 - Report#: 2 APIIUWI:50-629-23519-00-00 II II IIpage 1 of 1 Wellbore name: SI07-SE4 Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 -1.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(SC) Weather Wind 0.00 108.0 0.6 Clear WC 24" NE @ 14 MPH Daily summary operation 24h Summary Prep pad for Herculite.Lay Down Herculite and lay Matt Boards on 5107-SE4.Move and spot Pit Complex.Prep pad and lay down Matt Boards for Pump#3.Weld seams on Herculite.Skid rig floor to drilling operations.Finish welding Herculite and set Matt Boards for Pump#3 and Rock Washer and spot in place.Spot driller side suitcases and R/U.R/U Steam,air,electrical and mud lines.Spot Rock Washer suitcases.Cont.general R/U operations.Spot Mud Logger and Mud Man shacks.Complete Berming around rig. Operation at 07.00 Cont.to rig up. 24h Forecast Finish R/U operations.Prep Well Head and Diverter Stack.Test Diverter stack. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 1200 12.00 12.00 MOB A 2 P PJSM Prep pad for Herculite.Lay Down Herculite and lay Matt Boards on SI07-SE4.Move and spot Pit Complex.Prep pad and lay down Matt Boards for Pump#3.Weld seams on Herculite.Skid rig floor to drilling operations. 12:00 00:00 12.00- 24.00 MOB A 2 P PJSMFinish skidding rig floor.Finish welding Herculite and set Matt Boards for Pump#3 and Rock Washer and spot in place.Spot driller side suitcases and R/U.R/U Steam,air,electrical and mud lines.Spot Rock Washer suitcases.Cont. general R/U operations.Spot Mud Logger and Mud Man shacks.Complete Berming around rig. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson EM Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative Troy England ENI HSE Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 5It4/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') iipoi* Eni E&P Divisio. Well N 07-SE4 OR I EN/Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK • II Date:5/18/2015 - Report#: 3 APIIUWI:50-629-23519-00-00 `�I� II page 1 of 1 Wellbore name: S(07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5I07-5E4 DRILLING 5/19/2015 492496 4,91642 124.58 39.5 0.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) PUB Temperature(°C) Weather Wind 0.00 107.0 1.1 Clear WC 27° W @ 9 MPH Daily summary operation 24h Summary Cont.R/U work on rig floor inner-connects.Test suitcase lines.Finish berming around rig.Prep Pipe Shed for tools.Clean and clear rig floor.Load Schlumberger tools to rig floor.Load Schlumberger BHA into Pipe Shed.Stage landing joint and 13 3/8"Hanger.SIMOPS replace Auger bearings.Perform Derrick inspection.Stage Multi Bowl and prep for Crane operations.PJSM N/U Speed Head and Riser,test seals to 500 PSI as per Vetco Grey Rep onsite verified by Driller.PJSM W/all essential personnel,Co Rep,ENI HSE and Doyon HSE for critical pick. Remove IDS I-Beam components from rig floor.Install surface Diverter Assy.and test seals to 500 PSI.Vetco Grey Rep onsite.N/U Diverter system,fabricate Diverter line Pup.SIMOPS Transfer 750 bbl Spud Mud to Pits.Dummy run 13 3/8" Csg.Hanger as per Vetco Grey Rep onsite.Perform Diverter test:Before function Manifold Press.1,500 PSI,System Press.3,000 PSI,Annular Press.1,000 PSI,after function Manifold Press.1,550 PSI, System Press.1,700 PSI,Annular Press.1,000 PSI.Knife Valve open in 23 Sec.Annular closed in 30 Sec.200 PSI increase in 46 Sec.Total system recharge 170 Sec.5 bottle Nitrogen average 2,400 PSI.Witness waived by AOGCC Bob Noble 5-18-15 @ 6:30 pm.Bring Diverter line Pup to Cellar and install.Remove Diverter line stand and realign.Re-test seals to 500 PSI for 10 Min as per Vetco Grey Rep onsite.Develop HRW for Mouse Hole Operations.P/U M/U 5"HWDP from Pipe Shed and rack back in Derrick.Clear tools from rig floor.P/U components to rig floor.Develop HRW for high Press. testing lines.Test Mud lines 300 PSI low and 4,250 PSI high for 10 Min.charted.Blow down and R/D testing Equip.Prep for flooding Diverter Stack. Operation at 07.00 BROOH @ 138'W/Conductor Drilling Assy. 24h Forecast PJSM Spud Meeting.Fill and test Diverter Stack and Equip.Clean out 20"Conductor to 160'MD.POOH and P/U M/U MWD and Gyro.Check survey to ensure anti-collision for SP08.Cont.to drill ahead to-400'MD.POOH and P/U M/U Collars and Jars and 5"HWDP.Drill ahead 16"Surface to 2,999'MD. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 MOB A 20 P PJSM Cont.R/U work on rig floor inner-connects.Test suitcase lines.Finish berming around rig.Prep Pipe Shed for tools. Clean and clear rig floor.Load Schlumberger tools to rig floor. 03:00 06:00 3.00 6.00 MOB A 20 P PJSA Load Schlumberger BHA into Pipe Shed.Stage landing joint and t3 3/8"Hanger.SIMOPS replace Auger bearings. Perform Derrick inspection.Stage Multi Bowl and prep for Crane operations. 06:00 '09:00 3.00 9.00 MOB C 5 P 'PJSM N/U Speed Head and Riser,test seals to 500 PSI as per Vetco Grey Rep onsite verified by Driller.PJSM W/all essential personnel,Co Rep,ENI HSE and Doyon HSE for critical pick. 09:00 12:00 3.00 12.00 MOB C 5 P PJSM Remove IDS I-Beam components from rig floor.Install surface Diverter Assy.and test seals to 500 PSI.Vetco Grey Rep onsite. 12:00 15:00 3.00 15.00-MOB C 2 P PJSMN/U Diverter system,fabricate Diverter line Pup.SIMOPS Transfer 750 bbl Spud Mud to Pits. 15:00 16:30 1.50 16.50'MOB C 20 P PJSM Dummy run 13 3/8"Csg.Hanger as per Vetco Grey Rep onsite. 16:30 17:30 1.00 17.50'MOB C 12 P PJSA.Perform Diverter test:Before function Manifold Press.1,500 PSI,System Press.3,000 PSI,Annular Press.1,000 PSI,after function Manifold Press.1,550 PSI,System Press.1,700 PSI,Annular Press.1,000 PSI.Knife Valve open in 23 Sec.Annular closed in 30 Sec.200 PSI increase in 46 Sec.Total system recharge 170 Sec.5 bottle Nitrogen average 2,400 PSI.Witness waived by AOGCC Bob Noble 5-18-15 @ 6:30 pm. 17:30 19:30 2.00' 19.50 MOB C 20 P PJSM Bring Diverter line Pup to Cellar and install.Remove Diverter line stand and realign.Re-test seals to 500 PSI for 10 Min as per Vetco Grey Rep onsite. 19:30 21:00 1.50 21.00'DRILL E 20 P PJSM Develop HRW for Mouse Hole Operations.P/U M/U 5"HWDP from Pipe Shed and rack back in Derrick. 21:00 21:30 0.50 21.50 DRILL E 20 P PJSA Clear tools from rig floor.P/U components to rig floor. 21:30 23:00 1.50 23.00 DRILL E 12 P PJSM Develop HRW for high Press.testing lines.Test Mud lines 300 PSI low and 4,250 PSI high for 10 Min.charted. 23:00 23:30 0.50 23.50'DRILL E 20 P PJSA Blow down and R/D testing Equip. 23:30 00:00 0.50' 24.00-DRILL E 20 P PJSA Prep for flooding Diverter Stack. Daily Contacts Position Contact Name Company i Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative Troy England ENI HSE Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 000 48.77 5/14/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') ",.-: Eni E&P D►v►sio. Well N I07-SE4 OR EN/Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK nDate:5/19/2015 - Report#: 4 API/UWI:50-629-23519-00-00 l�" "' page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DES(days) S107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 1.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 340.16 327.28 340.16 7.32 46.5 109.0 1.1 Overcast WC 31' NE @ 7 MPH Daily summary operation 24h Summary Pre Spud meeting with all service companies,talked about H2S,LEL,Emergency evacuation,broaching,communication and well control.Flood Diverter Stack and check for leaks.Clean out 20" Conductor W/16"BHA#1 to 160'MD.400 GPM,300 PSI,40 RPM,TRQ 2-3K,WOB 2-4K.BROOH to M/U MWD tools.P/U M/U NM STAB,X/O and GyroPulse.RIH and tagged up-55'MD.Worked BHA and was unable to RIH.Decision was made to L/D GyroPulse and M/U 1 stand 5"HWDP to clean out tagged spot.Rotate and wash F/40'to 130'MD.POOH.P/U M/U GyroPulse,Telescope,ARC and X/O.Orientate W/Schlumberger DD,MWD and Gyro Data,witnessed by Co Rep onsite.Drill 16"Surface F/160'to 394'MD(394 ND)600 GPM,800 PSI,40 RPM.BROOH F/394'to 115'MD.M/U BHA#2 8"NM FC,7"JARS and 5"HWDP to 385'MD.Rotate and slide 16"Surface F/394'to 1,116'MD(1,075'TVD)600 GPM,1,150 PSI,40 RPM,WOB 10-30K,TON 5K,TQF 3K,HST 125K,SLK 130K,ROT 130K.ECD 10.42 ppg W/9.2 ppg MW.Max Gas 31 units.ADT 7.22,AST 5.96,ART 1.26.Bit Hrs 7.22,Jar Hrs 5.32. Operation at 07.00 Slide and rotate 16"Surface @ 1,450'MD. 24h Forecast Cont.slide and rotate 16"Surface F/1,116'to 2,999'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1048.5 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 12 P Pre Spud meeting with all service companies,talked about H2S,LEL,Emergency evacuation,broaching,communication and well control.Flood Diverter Stack and check for leaks. 01:00 03:00 2.00 3.00 DRILL E 3 P PJSA Clean out 20"Conductor W/16"BHA#1 to 160'MD.400 GPM,300 PSI,40 RPM,TRO 2-3K,WOB 2-4K. 03:00 05:00 2.00 5.00 DRILL E 6 P PJSA BROOH to M/U MWD tools.P/U M/U NM STAB,X/O and GyroPulse.RIH and tagged up-55'MD.Worked BHA and was unable to RIH.Decision was made to LID GyroPulse and WU 1 stand 5"HWDP to clean out tagged spot.Rotate and wash F/40'to 130'MD.POOH. 05:00 06:00 1.00' 6.00 DRILL E 20 P PJSA P/U M/U GyroPulse,Telescope,ARC and X/O.Odentate W/Schlumberger DD,MWD and Gyro Data,witnessed by Co Rep onsite. 06:00 10:30 4.50 10.50 DRILL E 3 P PJSA Drill 16"Surface F/160'10 394'MD(394 TVD)600 GPM,800 PSI,40 RPM,TQN 3-5K,TQF 3K,WOB 10-20K,HST 100K,SLK 101 K,ROT 105K.Max Gas 6 units.ADT 1.90,ART 0.68,AST 1.22,Bit Hrs 1.90.Monitor well static. 10:30 12:30 2.00 12.50 DRILL E 6 P PJSA BROOH F/394'10 115'MD 600 GPM,550 PSI,40 RPM,TQF 2-3K,HST 92K,SLK 93K,ROT 92K. 12:30 14:00 1.50 14.00 DRILL E 20 P PJSM M/U BHA#2 8"NM FC,7"JARS and 5"HWDP to 385'MD. 14:00 18:00 4.00 18.00 DRILL E 3 P PJSA Rotate and slide 16"Surface F/394'to 685'MD(682 TVD)600 GPM,910 PSI,WOB 10-30K,HST 120K,SLK 120K, ROT 120K.ECD 10.22 ppg W/9.2 ppg MW.Max Gas 31 units.ADT 2.37,AST 2.33,ART 0.04.Bit Hrs 4.27,Jar Hrs 2.37. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Rotate and slide 16"Surface F/685'to 1,116'MD(1,075'ND)600 GPM,1,150 PSI,40 RPM,WOB 10-30K,TQN 5K,TQF 3K,HST 125K,SLK 130K,ROT 130K.ECD 10.42 ppg W/9.2 ppg MW.Max Gas 7 units.ADT 2.95,AST 2.41, ART 0.54.Bit Hrs 7.22,Jar Hrs 5.32. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative Troy England ENI HSE Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 5/14/2015 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') lirOliCS' Eni E&P Divisio. Wan N 07-SE4 OR ENI Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK n, Date:5/2012015 - Report#: 5 ApnUWI:50-629-23519-00-00 eIf II II page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00,HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S107-SE4 DRILLING 5119/2015 4,924.96 4,916.42 124.58 39.5 2.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 92964 758.15 589.48 11.56 51.0 113.0 0.0 Clear WC 25' NE @ 17 MPH Daily summary operation 24h Summary Rotate and slide 16"Surface F/1,116'to 3,050'MD(2,487 TVD)775 GPM,1,850 PSI,40 RPM,WOB 10-30K,TQN 8K,TQF 7K,HST 170K,SLK 130K,ROT 145K.ECD 10.15 ppg W/9.4 ppg MW.Max Gas 984 units.ADT 11.56,AST 6.08,ART 5.48.Bit Hrs 18.78,Jar Hrs 16.88.BROOH 16"Surface as per K&M schedule F/3,050'to 2,521'MD.CBU for 2 stands off bottom at 850 GPM,1,800 PSI.60 RPM,TRQ 10K.Cont.BROOH same parameters @ 5-10 FPM or as hole allows.ROT 140K,No losses.Monitor hole,static. Operation at 07.00 BROOH as per K&M schedule @ 1,450'MD. 24h Forecast Cont.to BROOH as per K&M schedule F/2,521'to BHA#2.UD BHA#2 as per Sclumberger DD,MWD and Gyro Data.R/U GBR and RIH W/13 3/8"Csg. Lithology Shows MAASP(kgf/cma) Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 3 P PJSA Rotate and slide 16"Surface F/1,116'to 1,619'MD(1,473'TVD)685 GPM,1,400 PSI,40 RPM,WOB 25-30K,TQN 5-7K,TQF 3-4K,HST 139K,SLK 125K,ROT 131K ECD 10.83 ppg W/9.25 ppg MW.Max Gas 104 units.ADT 3.76,AST 2.30,ART 1.46.Bit Hrs 10.98,Jar Hrs 9.08. 06:00 12.00 6.00 12.00 DRILL E 3 P PJSA Rotate and slide 16"Surface F/1,619'to 2,272'MD(1,934'TVD)747 GPM,1,760 PSI,40 RPM,WOB 20-30K,TQN 8-10K,TQF 4-7K,HST 165K,SLK 125K,ROT 138K.ECD 10.19 ppg W/9.35 ppg MW.Max Gas 984 units.ADT 3.42,AST 1.25,ART 2.17.Bit Hrs 14.40,Jar Hrs 12.5. 12:00 18.00 6.00' 18.00 DRILL E 3 P PJSA Rotate and slide 16"Surface F/2,272'to 2,900'MD(2,380'TVD)775 GPM,1,850 PSI,40 RPM,WOB 10-30K,TQN 5-10K,TQF 5-6K,HST 165K,SLK 130K,ROT 142K.ECD 10.5 ppg W/9.4 ppg MW.Max Gas 574 units.ADT 3.51,AST 1.97,ART 1.54.Bit Hrs 17.91,Jar Hrs 16.01. 18:00 20.00 2.00' 20.00 DRILL E 3 P PJSA Rotate and slide 16"Surface F/2,900'to 3,050'MD(2,487'ND)775 GPM,1,850 PSI,40 RPM,WOB 10-30K,TQN 8K,TQF 7K,HST 170K,SLK 130K,ROT 145K.ECD 10.15 ppg W/9.4 ppg MW.Max Gas 182 units.ADT 0.87,AST 0.56, ART 0.31.Bit Hrs 18.78,Jar Hrs 16.88. 20.00 '00:00 4.00 24.00 DRILL E 6 'P PJSA BROOH 16"Surface as per K&M schedule F/3,050'to 2,521'MD.CBU for2 stands off bottom at 850 GPM,1,800 PSI,60 RPM,TRQ 10K.Cont.BROOH same parameters @ 5-10 FPM or as hole allows.ROT 140K,No losses.Monitor hole,static. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative Troy England ENI HSE Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 5/14/2015 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcma) Eq.Mud Weight(g/L) P LeakOff(kgflcm') te46,..00 Eni E&P Divisio Well N 07-SE4 OR I EN/Petroleum Co.Inc. Daily Report Well Code:27981 Field Name: NIKIATCHUK e�,, Date:5/21/2015 - Report#: 6 APIIUWI:50-629-23519-00-00 lz i II�I page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 960 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5I07-5E4 DRILLING 5/19/2015 4,924.96 4.916.42 124.58 39.5 3.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 929.64 758.15 0.00 112.0 5.0 Cloudy WC 34' SW @ 11 MPH Daily summary operation 24h Summary BROOH 16"Surface as per K&M schedule F/2,521'to 218'MD.850 GPM,1,450 PSI,60 RPM,TRQ 2-3K.ROT 122K,At 1,500'to 1,100'reduce pulling speed for excessive cutting at Shaker of gravel and clay.No losses.Monitor hole,static.PJSM L/D 16"BHA#2 F/218'MD as per Sclumberger DD,MWD and Gyro Data Rep onsite.Bit Grade:1-1-WT-A-E-1-NO-TD.Clean and clear of floor of BHA components.PJSM W/all essential personnel.P/U GBR tools and Equip.to rig floor.R/U Volant and Csg.running Equip.M/U X/O for cementing on Volant tool.M/U and test 13 3/8"Shoe Track as per tally to 119'MD.RIH 13 3/8"Csg.as per tally F/119'to 1,334'MD.SLK 130K.Calculated displacement 28 bbl,actual 21.Lost 7 bbl during trip. Operation at 07.00 P/U M/U Hanger,Circ.and condition mud to<20 YP. 24h Forecast Cont.to RIH 13 3/8"Csg.on Volant CRT F/1,334'to 3,035'MD.P/U WU Hanger as per Vetco Grey Rep onsite.Circ.and condition mud to<20 YP.Perform cement job as per Schlumberger plan forward.R/D Csg.Equip.N/D Diverter Stack. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1126.4 Time Log Start End Cum ' Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12.00 12.00 12.00 DRILL E 6 P PJSA BROOH 16"Surface as per K&M schedule F/2,521'to 218'MD.850 GPM,1,450 PSI,60 RPM,TRQ 2-3K.ROT 122K,At 1,500'to 1,100'reduce pulling speed for excessive cutting at Shaker of gravel and clay.No losses.Monitor hole, static. 12:00 14:30 2.50 14.50 DRILL E 20 P PJSM L/D 16"BHA#2 F/218'MD as per Sclumberger DD,MWD and Gyro Data Rep onsite.Bit Grade:t-1-WT-A-E-1-NO- TD. 14:30 15:30 1.00 15.50 DRILL E 20 P PJSA Clean and clear of floor of BHA components. 15:30 18:00 2.50 18.00 DRILL G 1 P PJSM W/all essential personnel.P/U GBR tools and Equip.to rig floor.R/U Volant and Csg.running Equip.M/U X/O for cementing on Volant tool. 18:00 00:00 6.00 24.00 DRILL G 4 P PJSA M/U and test 13 3/8"Shoe Track as per tally to 119'MD.RIH 13 3/8"Csg.as per tally F/119'to 1,334'MD.SLK 130K.Calculated displacement 28 bbl,actual 21.Lost 7 bbl during trip. Daily Contacts Position Contact Name Company Title Entail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk Eni representative Greg Parker ,ENI Malls Coordinator 907-980-7545 Eni representative Jeremey Decker .ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Troy England ENI HSE Tool Push Chad Johnson .Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Dave Evans )Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.12 925.07 5/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm2) Eq.Mud Weight(gIL) P LeakOff(kgf/cm2) • Eni E&P Divisio. Well N 07-SE4 OR If* EN/Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK • 2 n ii Date:5/22/2015 - Report#: 7 API/UWI:50-629-23519-00-00 page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(10) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 4.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 929.64 758.15 0.00 108.0 0.0 Clear WC 21° NE @ 14 MPH Daily summary operation 24h Summary RIH 13 3/8"Csg.WI GBR CRT F/1,334'to 2,916'MD.HST 275K,SLK 180K.Wash down F/2,916'to 2,999'MD126 GPM,60 PSI.No losses.P/U M/U 13 3/8"Hanger as per Vetco Grey Rep onsite. Wash and land Hanger at 3,035'MD.Witnessed by Co Rep onsite.Break Circ.and condition mud as per MI Swaco plan.Stage up Circ.@ 3 bpm,60 PSI,4 bpm,80 PSI,5 bpm,110 PSI.No losses during conditioning.PJSM W/all essential personnel for cement job.Perform cement job as per Schlumberger plan.Press.test lines 650 PSI low and 3,600 PSI high.Rig pump 10.1 ppg 100 bbl Mud Push @ 5 bpm,160 PSI.Drop bottom plug,Schlumberger pump 449 bbl 10.7 ppg Lead @ 5.8 bpm 600 PSI,Pump 81 bbl 12.5 ppg Tail @ 3.7 bpm 440 PSI.Drop top plug and kick out W/10 bbl water. Rig pump 9.3 ppg mud @ 4.5 bpm,ICP 150 PSI,FCP 400 PSI.Top plug bumped 437 bbl away 400 PSI.Press.up to 930 PSI and hole for 5 Min.Check floats,good.CIP @ 14:18 pm.All charted.RID blow down lines and Equip.R/D GBR Volant CRT as per GBR Rep onsite.Pull landing joint as per Vetco Grey Rep onsite.Install Bell Guide and Elevators.Rig up stack washer and wash Diverter Stack. N/D Diverter Stack,riser and Diverter Pup.SIMOPS Load 117 joints 5"D.P.in Pipe Shed.Remove Starter Head.Prep Well Head.Install Multi Bowl.Test Hanger neck to 2,000 PSI for 10 Min.as per Vetco Grey Rep onsite.Test witnessed by Co Rep.Install High Press.Riser and BOPE stack. Operation at 07.00 Testing B.O.P.E. 24h Forecast Cont.to N/U BOPE.Test BOPE.P/U M/U BHA#3 clean out BHA.Single in hole W/5"D.P.F/Pipe Shed.Drill out Shoe Track. Lithology Shows MAASP(kgf/cm') Mud Weight(giL) 1114.4 Time Log Start End 1 Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 DRILL G 4 P PJSM RIH 13 3/8"Csg.W/GBR CRT F/1,334'to 2,916'MD.HST 275K,SLK 180K.Wash down F/2,916'to 2,999'MD126 GPM,60 PSI.No losses. 04:00 05:00 1.00 5.00 DRILL G 4 P PJSA P/U M/U 13 3/8"Hanger as per Vetco Grey Rep onsite.Wash and land Hanger at 3,035'MD.Witnessed by Co Rep onsite. 05:00 10:00 5.00 10.00 DRILL H 8 P PJSM Break Circ.and condition mud as per MI Swaco plan.Stage up Circ.@ 3 bpm,60 PSI,4 bpm,80 PSI,5 bpm,110 PSI.No losses during conditioning. 10:00 14:30 4.50 14.50 DRILL H 9 P PJSM W/all essential personnel for cement job.Perform cement job as per Schlumberger plan.Press.test lines 650 PSI low and 3,600 PSI high.Rig pump 10.1 ppg 100 bbl Mud Push @ 5 bpm,160 PSI.Drop bottom plug,Schlumberger pump 449 bbl 10.7 ppg Lead @ 5.8 bpm 600 PSI,Pump 81 bbl 12.5 ppg Tail @ 3.7 bpm 440 PSI.Drop top plug and kick out W/ 10 bbl water.Rig pump 9.3 ppg mud @ 4.5 bpm,ICP 150 PSI,FCP 400 PSI.Top plug bumped 437 bbl away 400 PSI. Press.up to 930 PSI and hole for 5 Min.Check floats,good.CIP @ 14:18 pm.All charted. 14:30 15:00 0.50 15.00 DRILL H 20 P PJSA R/D blow down lines and Equip. 1500 15:30 0.50 15.50 DRILL G 20 P PJSA R/D GBR Volant CRT as per GBR Rep onsite.Pull landing joint as per Vetco Grey Rep onsite. 15:30 17:00 ' 1.50 17.00 DRILL C 20 P PJSA Install Bell Guide and Elevators.Rig up stack washer and wash Diverter Stack. 17:00 '20:30 ' 3.50 20.50 DRILL C 5 P PJSM N/D Diverter Stack,riser and Diverter Pup.SIMOPS Load 117 joints 5"D.P.in Pipe Shed. 20:30 22:30 2.00 22.50 DRILL C 5 P PJSM Remove Starter Head.Prep Well Head.Install Multi Bowl.Test Hanger neck to 2,000 PSI for 10 Min.as per Vetco Grey Rep onsite.Test witnessed by Co Rep. 22:30 00:00 1.50 24.00 DRILL C 5 P PJSM Install High Press.Riser and BOPE stack. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Troy England ENI HSE Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.12 925.07 5/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') ir,0,01.* Eni E&P Divisio. Well Na 7-SE4 OR I EN!Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK • n Date:5/23/2015 - Report#: 8 AP 50-629-23519-00-00 lam'�' �I II page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information - Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB)'Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 5.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(SC) Weather Wind 929.64 758.15 0.00 106.0 0.0 Clear WC 15° NE @ 32 MPH Daily summary operation 24h Summary Cont.N/U BOPE,install Choke&Kill lines,Flow Nipple,Clamshell components and lines on Annular.SIMOPS Clean cement valves.RIO for BOPE test.M/U Floor valves,test manifold,chart recorder. Install test plug as per Vetco Grey Rep onsite.Fill and purge BOPE&Choke Manifold.Perform body test on BOPE.Test BOPE.R/D and blow down test Equip.Place floor valves back in service position. P/U M/U 5"D.P.F/Pipe Shed and rack back in Derrick.14 stands.Pull Mouse Hole and test plug.Install Wear Bushing as per Vetco Grey Rep onsite.ID 12.31". R/U and test 13 3/8"Csg.to 2,500 PSI for 10 Min.charted.Pumped 4.8 bbl @ 1 bpm,bleed back 4.8 bb.Witnessed by Co Rep onsite.P/U M/U 12.25"clean out BHA as per Schlumberger DD and MWD to 570'MD.Single in hole 5"D.P.F/ Pipe Shed F/570'to 2,904'MD.HST 162.Wash down F/2,904'to 2,953'MD tagged up at 2,953'MD 350 GPM,360 PSI.Drill out Shoe Track F/2,953'to 2,997 MD 500 GPM,640 PSI,80-100 RPM, TRQ 6-7K,WOB 4-10K.HST 160K,SLK 120K,ROT 139K. Operation at 07.00 Displacing,Perform Leak Off Test 24h Forecast Cont.drill out Shoe Track and 20'of new hole to 3,070'MD.Dispalace Spud Mud W/9.25 ppg LONG.Perform LOT/FIT.POOH and L/D BHA#3.P/U M/U 12.25"BHA#4 and RIH WI 5"D.P. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum 1 Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL C 5 P PJSM Cont.N/U BOPE,install Choke&Kill lines,Flow Nipple,Clamshell components and lines on Annular.SIMOPS Clean cement valves. 03:00 04:30 1.50 4.50 DRILL C 20 P PJSM R/U for BOPE test.M/U Floor valves,test manifold,chart recorder.Install test plug as per Vetco Grey Rep onsite. 04:30 '05:30 1.00 5.50 DRILL C 12 P PJSM Fill and purge BOPE&Choke Manifold.Perform body test on BOPE. 05:30 11:00 5.50' 11.00 DRILL C 12 P PJSM Test BOPE:Annular Preventer 250 PSI low and 2,500 PSI high.Choke Valves 1-14,Upper and Lower Rams,TT525 &NC 46 Dart&FOSV,Manual Choke&Kill,HCR Choke&Kill,Kill Line Demco,Upper and Lower IBOP W/5"&4,5"Test Joint to 250 PSI low and 3,500 PSI high for 5 Min.Test Manual and Super Choke to 1,500 PSI.All charted.Perform Koomey test:Start Press.Manifold 1,450 PSI,System 3,000 PSI,Annular 550 PSI,after function:Manifold 1,450 PSI, System 1,500 PSI,Annular 550 PSI.200 PSI increase in 40 Sec.Full charge 184 Sec.5 Nitrogen average 2,400 PSI. AOGCC witnessed waived by John Crisp 5-22-15 08:30. 11:00 12:30 1.50' 12.50'DRILL C 20 P PJSA R/D and blow down test Equip.Place floor valves back in service position. 12:30 14:00 1.50 14.00 DRILL E 20 P PJSA P/U M/U 5"D.P.F/Pipe Shed and rack back in Derrick.14 stands. 14:00 14:30 0.50 14.50'DRILL C 20 P PJSA Pull Mouse Hole and test plug.Install Wear Bushing as per Vetco Grey Rep onsite.ID 12.31" 14:30 '15:30 1.00 15.50 DRILL G 12 P PJSA R/U and test 13 3/8"Csg.to 2,500 PSI for 10 Min.charted.Pumped 4.8 bbl @ 1 bpm,bleed back 4.8 bb.Witnessed - by Co Rep onsite. 15:30 17:00 1.50 17.00 DRILL E 20 P PJSA P/U WU 12.25"clean out BHA as per Schlumberger DD and MWD to 570'MD. 17:00 20:00 3.00 20.00'DRILL E 4 P PJSM Single in hole 5"D.P.F/Pipe Shed F/570'to 2,904'MD.HST 162,SLK 120K. 20:00 21:00 1.00 21.00-DRILL E 6 P PJSA Wash down F/2,904'to 2,953'MD tagged up at 2,953'MD 350 GPM,360 PSI,20 RPM,TRQ 7-9K,ROT 139K. 21:00 00:00 3.00 24.00'DRILL E 3 P PJSA Drill out Shoe Track F/2,953'to 2,997'MD 500 GPM,640 PSI,80-100 RPM,TRO 6-7K,WOB 4-10K.HST 160K, SLK 120K,ROT 139K. SPR @ 2,950'MD(2,419'ND)W/9.4 ppg MW MP#1 30-120,40-140 MP#2 30-120,40-140 MP#3 30-120,40-140 1 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Troy England ENI HSE Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondnlling.cow 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.12 925.07 5/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 925.07 754.85 LSND 1108.4 34.4 1564.8 118.1 Eni E&P Divisio Well N o7-SE4 OR � � Daily Report � � ENI Petroleum Co.Inc. Well Code:27981 Field Name:NIKIATCHUK 2^ Date:5/24/2015 - Report#: 9 APIIUWI:50-629-23519-00-00 II II'In page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI07-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 6.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,022 91 821.26 93.27 3.26 28.6 106.0 0.0 Foggy WC 25' E @ 17 mph Daily summary operation 24h Summary Cont.drilling 13 3/8"Shoe Track F/2,997'to 3,050'MD Work thru Shoe @ 3,035'several times.Drill 12.25"Intermediate F/3,050'to 3,070'MD(2,487'TVD).PJSM W/all essential personnel for displacement.Displace Spud Mud,pump 50 bbl Hi Vis spacer and 443 bbl 9.25 ppg LSND as per MI Swaco plan.POOH F/3,070'to 2,997'MD.R/U test Equip.for FIT/LOT.SIMOPS Clean surface Equip.Perform FIT Press.up to 490 PSI,pumped 1.7 bbl and bleed back 1 bbl.EMW 13.0 ppg.Witnessed by Co Rep onsite.R/D and blow down test Equip.Monitor well,static.SIMOPS Cont.cleaning surface Equip.POOH 5"D.P.and BHA#3 F/2,997'to 570'MD.POOH L/D BHA#3 as per Schlumberger DD F/570'to 0'.Attempt to remove Stabilizer from Mud Motor for BHA#4 W/Rose Bud and change bend in Motor.Cont.to P/U M/U 12.25"BHA SP Motor 1.5°,Pony DC,NM STAB,ARC,TeleScope,NM Stab,NM Flex DC 7"Jar and 5"HWDP to 670'MD as per Schlumberger DD onsite.RIH 12.25"BHA#4 W/5"D.P.F/670'to 1,603'MD perform shallow hole test as per Schlumberger MWD 680 GPM,970 PSI.Cont.to RIH to 3,070'MD.Slide&Rotate 12.25"Intermediate hole F/3,070'to 3,356'MD(2,699'TVD)750 GPM,1,040 PSI,40 RPM,TQN 9-10K,TOF 6-7K,WOB 2-12K,HST 170K,SLK 130,ROT 149K,ECD 9.86 ppg W/9.3 ppg MW.Max Gas 35 units.ADT 3.26,AST 2.99,ART 027, Bit Hrs 3.26,Jar Hrs 21.14.Monitor well,static. Operation at 07.00 Rotate&slide 12.25"Intermediate @ 3,720'MD. 24h Forecast Rotate&slide 12.25"Intermediate F/3,356'to 6,231'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 3 -P PJSA Cont.drilling 13 3/8"Shoe Track F/2,997'to 3,050'MD Work thru Shoe @ 3,035'several times.520 GPM,700 PSI, 80 RPM,TRQ 8-10K,WOB,HST 165K,SLK 120K,ROT 135K. 00:30 02:00 1.50 2.00 DRILL E 3 P PJSA Drill 1225"Intermediate F/3,050'to 3,070'MD(2,487'TVD).750 GPM,1,250 PSI,TQN 8-10K,TQF 5-6K,WOB 15- 20,HST 165K,SLK 120K,ROT 135K. 02:00 03:00 1.00 3.00 DRILL E 9 P PJSM W/all essential personnel for displacement.Displace Spud Mud,pump 50 bbl Hi Vis spacer and 443 bbl 925 ppg LSND as per MI Swaco plan.POOH F/3,070'to 2,997'MD. 03:00 03:30 0.50 3.50 DRILL E 20 P PJSM R/U test Equip.for FIT/LOT.SIMOPS Clean surface Equip. 03:30 04:30 1.00 4.50 DRILL E 11 'P PJSA Perform FIT Press.up to 490 PSI,pumped 1.7 bbl and bleed back 1 bbl.EMW 13.0 ppg.Witnessed by Co Rep onsite. 04:30 05:00 0.50 5.00 DRILL E 20 'P PJSA R/D and blow down test Equip.Monitor well,static.SIMOPS Cont.cleaning surface Equip. 05:00 07:00 2.00 7.00 DRILL E 4 'P PJSA POOH 5"D.P.and BHA#3 F/2,997'to 570'MD.HST 78K,SLK 79K.12.25"Bit Grade 1-1-CT-G-X-In-No-BHA 07:00 09:30 2.50 9.50 DRILL E 4 -P PJSM POOH L/D BHA#3 as per Schlumberger DD F/570'to 0' 09:30 14:30 5.00 14.50 DRILL E 20 •P PJSM Attempt to remove Stabilizer from Mud Motor for BHA#4 W/Rose Bud and change bend in Motor.Cont.to P/U M/U 12.25"BHA SP Motor 1.5°,Pony DC,NM STAB,ARC,TeleScope,NM Stab,NM Flex DC 7"Jar and 5"HWDP to 670'MD as per Schlumberger DD onsite. 14:30 18:00 3.50 18.00 DRILL E 4 •P PJSA RIH 12.25"BHA#4 W/5"D.P.F/670'to 1,603'MD perform shallow hole test as per Schlumberger MWD 680 GPM, 970 PSI.Cont.to RIH to 3,070'MD. 18:00 00:00 6.00 24.00 DRILL E 3 'P PJSA Slide&Rotate 12.25"Intermediate hole F/3,070'to 3,356'MD(2,699'TVD)750 GPM,1,040 PSI,40 RPM,TQN 9- 10K,TGIF 6-7K,WOB 2-12K,HST 170K,SLK 130,ROT 149K,ECD 9.86 ppg W/9.3 ppg MW.Max Gas 35 units.ADT 3.26,AST 2.99,ART 0.27, Bit Hrs 3.26,Jar Hrs 21.14.Monitor well,static. SPR @ 3,070'MD(2,483'TVD)W/9.3 ppg MW MP#1 30-160,40-180 MP#2 30-160,40-180 MP#3 30-160,40-180 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.cow 907-980-7545 907-980-7545 Eni representative Troy England ENI HSE Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 • Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat - Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.12 925.07 5/22/2015 ' Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgftcm°) 925.07 754.85 LSND 1108.4 34.4 1564.8 118.1 <' Eni E&P Divisio. �. Well Na 07-SE4 OR EN!Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK e^n Date:5/25/2015 - Report#: 10 APIIIJWI:50-629-23519-00-00 II 'I II page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI07-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 7.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,540.76 1,095.25 517.86 13.93 37.2 107.0 0.0 Overcast WC 25' NE @ 6 MPH Daily summary operation 24h Summary Slide&Rotate 12.25"Intermediate hole F/3,356'to 5,055'MD(3,593'ND)800 GPM,1,600 PSI,40 RPM,TQN 7-10K,TQF 6-7K,WOB 2-20K,HST 190K,SLK 143,ROT 161K,ECD 9.97 ppg W/9.25 ppg MW.Max Gas 43 units.ADT 13.93,AST 8.77,ART 5.16, Bit Hrs 17.19,Jar Hrs 35.07.Monitor well,static. Operation at 07.00 Rotate&slide 12.25"Intermediate @ 5,120'MD. 24h Forecast Rotate&slide 1225"Intermediate F/3,356'to 6,231'MD.BROOH per K&M schedule. Lithotogy Shows MAASP(kgf/cm') Mud Weight(gIL) 11024 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 0 -3 P PJSA Slide&Rotate 12.25"Intermediate hole F/3,356'to 3,842'MD(2,948'ND)740 GPM,1,200 PSI,40 RPM,TON 9- 10K,TQF 8-9K,WOB 2-15K,HST 181 K,SLK 131,ROT 150K,ECD 9.72 ppg W/9.25 ppg MW.Max Gas 43 units.ADT 3.45,AST 1.96,ART 1.49, Bit Hrs 6.71,Jar Hrs 24.59.Monitor well,static. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Slide&Rotate 12.25"Intermediate hole F/3,842'to 4,258'MD(3,162'TVD)750 GPM,1,200 PSI,40 RPM,TON 8- 11K,TQF 7-8K,WOB 2-15K,HST 180K,SLK 137,ROT 152K,ECD 9.86 ppg W/9.2 ppg MW.Max Gas 14 units.ADT 3.52,AST 2.06,ART 1.46, Bit Hrs 10.23,Jar Hrs 28.11.Monitor well,static. SPR @ 4,029'MD(3,039'ND)W/9.2 ppg MW MP#1 30-220,40-240 MP#2 30-220,40-240 MP#3 30-220,40-240 12:00 18:00 6.00' 18.00 DRILL E 3 P PJSA Slide&Rotate 12.25"Intermediate hole F/4,258'to 4,686'MD(3,402'ND)750 GPM,1,290 PSI,40 RPM,TQN 7- 8K,TQF 7-9K,WOB 2-20K,HST 180K,SLK 140,ROT 159K,ECD 9.94 ppg W/9.2 ppg MW.Max Gas 12 units.ADT 3.58, AST 2.45,ART 1.13, Bit Hrs 13.81,Jar Hrs 31.69.Monitor well,static. 18.00 -0000 6.00 24.00 DRILL 'E 3 P PJSA Slide&Rotate 12.25"Intermediate hole F/4,686'to 5,055'MD(3,593'ND)800 GPM,1,600 PSI,40 RPM,TQN 7- 10K,TQF 6-7K,WOB 2-20K,HST 190K,SLK 143,ROT 161K,ECD 9.97 ppg W/925 ppg MW.Max Gas 17 units.ADT 3.38,AST 2.3,ART 1.08, Bt Hrs 17.19,Jar Hrs 35.07.Monitor well,static. SPR @ 5,055'MD(3,593'ND)W/9.25 ppg MW MP#1 30-230,40-260 MP#2 30-230,40-260 MP#3 30-230,40-260 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI 'Drilling Supv. 907-685-0715 Eni representative Wade Thomas ENI Rig Clerk Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Troy England ENI HSE Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.cow 907-685-0716 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.12 925.07 5/22/2015 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 925.07 754.85 LSND 1108.4 34.4 1564.8 118.1 0,06.000,tw Eni E&P Divisio. Well Na 07-SE4 OR EN/Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK n \�n Date:5/26/2015 - Report#: 11 API/UWI:50-629-23519-00-00 '� (�'� page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5107-5E4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 8.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,859.28 1,232.48 318.52 15.54 20.5 108.0 0.0 Foggy WC 23' NE @ I l MPH Daily summary operation 24h Summary Slide&Rotate 12.25"Intermediate hole f/5055'-6100'MD(4050'ND). Operation at 07.00 BROOH,Clean Up Cycle @ 6,175'MD 24h Forecast Slide&Rotate 12.25"Intermediate to 6246'MD Est TD.BROOH as per K&M. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1126.4 Time Log 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 3 P PJSA Ddg.f/5055'-5149'MD(3645'ND)@ 800 gpm,1500 psi,40 rpm,2-20k wob,8-9k tqn,8-10k tqf,200k puw, 140k sow,166k rotw,9.92 ECD,Max Gas 7,4.08 ADT,3.56 TST,.52 TRT,21.27 Bit,39.15 Jars. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Ddg.f/5149'-5336'MD(3743'ND)@ 800 gpm,1600 psi,40 rpm,2-20k wob,7-8k tqn,7-9k tqf,193k puw,143k sow,166k rotw,9.98 ECD,Max Gas 17,3.21 ADT,2.51 TST,.70 TRT,14.48 Bit,42.36 Jars.SPR @ 5335'MD(3743' ND)w/9.35 MW;#1/#2 @ 30-210,@ 40-230. 12:00 18:00 6.00 18.00 DRILL E •3 P PJSA Ddg.1/5336'-5709'MD(3922'ND)@ 800 gpm,1720 psi,40 rpm,2-12k wob,9k tqn,7-8k tqf,198k puw,145k sow,163k rotw,10.07 ECD,Max Gas xxx,4.61 ADT,2.68 TST,1.93 TRT,29.09 Bit,46.97 Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Ddg.f/5709'-6100'MD(4049'ND)@ 800 gpm,1880 psi,40 rpm,2-25k wob,8-9k tqn,7-8k tqf,200k puw,146k sow,165k rotw,10.19 ECD,Max Gas 1370,3.64 ADT,2.1 TST,1.54 TRT,32.73 Bit,50.61 Jars.SPR @ 6082'MD(4050 ND)w/9.4 MW;#1/92/83 @ 30-260,40-280. 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 Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Rig Clerk Eni representative Vance Dale ENI Malls Coordinator Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 -0.12 925.07 5/22/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 925.07 754.85 LSND 1108.4 34.4 1564.8 118.1 iircos. Eni E&P Divisiol Well N 7-SE4 OR I ENI Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK nDate:5/27/2015 - Report#: 12 ewuuwl:50629-23519-00-00 e�I I'rI page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.l.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 9.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 1,903.78 1,240.19 44.50 2.15 20.7 108.0 -2.2 Overcast/Fog WC ENE @ 15 MPH 19' Daily summary operation 24h Summary Slide&rotate to Geologists TD @ 6246'.Obtain SPR's and monitor well-static.CBU X 1.5 while BROOH 1 stand.BROOH as per K&M schedule to 3284'. CBU X 4 while rot.&recip.to 3097'.Pump BHA through casing shoe.CBU X 3 while rot.&recip.f/3004'-2910'.Monitor well and POOH to 2443'. Operation at 07.00 Laying down BHA#4 24h Forecast POOH and UD BHA.Clear and clean rig Floor.Install 9 5/8"test jt.and change rams to 9 5/8".Test Rams.P/U&R/U GBR CRT tools.Hold PJSA with all personnel and P/U casing and RIH.Test float equipment. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00'00 02:30 2.50 2.50 DRILL E 3 P PJSA Ddg.f/6100'-6246'MD(4077'TVD)@ 800 gpm,1880 psi,40 rpm,2-25k wob,9-10k tqn,8-9k tqf,198k puw, 145k sow,163k rotw,10.20 ECD,Max Gas 92,2.15 ADT,1.72 TST,.43 TRT,34.88 Bit,54.76 Jars.Downlink to MWD and obtain survey.Geologists TD. 02.30 03:00 0.50 3.00 DRILL E 11 P PJSA SPR @ 6246'MD(4072'TVD)w/9.45 MW;#1/#2/#3 @ 30-210,@ 40-230.Monitor well-static. 03:00 04:00 1.00 4.00 DRILL E 4 P PJSA CBU X 1.5 while BROOH 1 stand f/6246'-6175'@ 850 gpm,1900 psi,80 rpm,8-9k tq,198k puw,145k sow. 04:00 12:00 8.00 12.00'DRILL E 4 P PJSA BROOH 1/6175-4778'@ 850 gpm,1700 psi,80 rpm,9-11k tq,190k puw,140k sow,162k rotw,10.16 ECD. 12:00 18:00 6.00 18.00 DRILL E 4 P PJSA BROOH f/4778'-3284'@ 850 gpm,1400 psi,80 rpm,6-8k tq,152k puw,130k sow,145k rotw,10.11 ECD. 18:00 20:30 2.50 20.50 DRILL E 4 P PJSA Rotate and reciprocate fl 3284'-3097'CBU X 4 until shakers clean as per K&M,@ 850 gpm,1420 psi,80 rpm,6-Bk tq,145k rotw. 20:30 21:00 0.50 21.00 DRILL E 4 P PJSA Pull BHA through 13 3/8"shoe 3097'-3004'while pumping @ 850 gpm,1420 psi,152k paw. 21:00 22:00 1.00 22.00 DRILL E 4 P PJSA Rotate and reciprocate f/3004'-2910'while CBU X 3 @ 850 gpm,1400 psi,40 rpm,4-8k tq,145k rotw. 22:00 00:00 2.00 24.00 DRILL E 4 P PJSA Monitor well.POOH f/2910'-2443',148k puw,130k sow. 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. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -0.90 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflc m') 925.07 754.85 LSND 1108.4 34,4 1564.8 118.1 Eni E&P Divisio. Well N 07-SE4 OR EN/Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK • ,� ^II Date:5/28/2015 - Report#: 13 API/UWI:50-629-23519-00-00 �2I II IIpage 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(in) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(in) 16.43 399 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI07-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 10.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,903.78 1,240.19 0.00 103.0 -1.1 Mostly Cloudy WC NNE @ 15 MPH 19° Daily summary operation 24h Summary Complete POOH and L/D BHA#4.0/0 Upper rams to 9 5/8"and test to 250/3500 psi.R/U and run 9 5/8"40#L80 Hyd 563 casing to 6241'TD. Operation at 07.00 Filling Casing 24h Forecast M/U cement head and fill casing as per MI schedule.Install cement plugs and circulate well.Blow down cement line and PT.Perform cementing job as per SLB and bump plug and check floats.R/D cmt. equipment.Perform injectivity test on IA. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL 'E 4 P PJSA POOH f/2443'-200',80k puw,82k sow. 02:30 05:00 2.50 5.00 DRILL E 4 P PJSA L/D BHA as per SLB,f/200'. 05:00 07:30 2.50 7.50 DRILL C 20 P PJSA CIO upper rams to 9 5/8".Sim Ops;clear and clean rig floor and mobilize GBR CRT and equipment. 07:30 08:00 0.50 8.00 DRILL 'C 20 P PJSA Remove wear bushing and install test plug and test jt.w/Vetco. 08:00 08:30 0.50 8.50 DRILL C 12 P PJSA Test 9 5/8"rams @ 250/3500 psi. 08:30 09:00 0.50 9.00 DRILL 'C 20 P PJSA Remove test jt,test plug and install modified wear bushing for running 9 5/8"casing. 09:00 12:00 3.00 12.00 DRILL G 20 P PJSA Bring GBR CRT equipment to ng floor and R/U. 12:00 18:00 6.00 18.00 DRILL G 4 P PJSA w/all presonnel on running casing.P/U 8 M/U 9 5/8"shoe track and check floats.RIH w/9 5/8"405 L80 Hyd 563 casing to 3233',75k sow. 18.00 0000 6.00 24.00 DRILL i G 4 P PJSA RIH w/9 5/8"casing to 6241'TD.Start to rotate @ 3639',40 rpm,80k rotw,7-9k tq. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Em representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.cam 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.cam 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.cam 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.cam 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -0.90 1.902.26 5/2812015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm2) Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 925.07 754.85 LORD 1108.4 34.4 1564.8 118.1 Eni E&P Divisio Well N 07-SE4 OR ENI Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK • 2^�flifl* Date:5/29/2015 - Report#: 14 APULIWI:50-629-23519-00-00 II IIpage 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100,00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 11.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,903.78 1,240.19 0.00 101.0 0.4 Overcast WC 25' N @ 6 MPH Daily summary operation 24h Summary R/D Casing equip.Fill casing w/treated LSND mud.CBU X 3.5.Test cmt.line and pump 135 bbls of LiteCrete and displace w/454 bbls of LSND.Bump plug and floats held.CIP @ 13:55 hrs.Perform injectivity w/40 bbls of LSND.N/D Stack&Multibowl and pickup.Vetco set emergency slips w/100k over,and cut 9 5/8"csg.Install 9 5/8"pack off and N/U.Vetco test pack off to 2470 psi f/10 min. Complete R/U stack and set test plug and C/O upper rams to 3.5"X 6". Operation at 07.00 M/U stands of 4.5"DP and rack in derrick. 24h Forecast Freeze protect annulus w/181 bbls of diesel.R/U, P/U,M/U and rack back 105 stands of 4.5"DP.R/U and test BOPE to AOGCC specs.Witness waived by Lou Grimaldi. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1114 4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL G 20 P PJSA R/D Volant tool and casing running equipment.Install XO and cement head and R/U to fill casing. 00:30 04:30 4.00 4.50 DRILL G 19 P PJSA Fill casing wl treated LSND mud as per schedule @ 3 bpm,60 psi 13 bpm @ 60 psi/2 bpm/50 psi and top off w/ charge pump @ 30 psi. 04:30 10:30 6.00 10.50 DRILL G 7 P PJSA Circulate and condition mud w/3.5 X BU @ ICP 190 psi w/1.5 bpm staging up to 7 bpm,270 psi.Sim Ops;Load 315 jts.of 4.5"DP to pipe shed, 10:30 14:00 3.50 14.00 DRILL H 9 P PJSA vv/all personnel.Load wiper plugs in cement head and PT lines to 1600/3200 psi.Rig pump 100 bbls of 10.5 ppg MudPush @ 5 bpm,200 psi.Drop bosom plug and SLB pump 135 bbls of 12.5 ppg LiteCrete cement @ 5.3 bpm,30 psi. Drop top plug and kick out vd 10 bbls water.Rig pump 454 bbls of LSND @ 6 bpm,80 psi,then @ 2 bpm,430 psi.Bumped plug and pressure up to 930 psi f/5 min.Floats held.CIP @ 1355 hrs. 14:00 15:00 1.00 15.00 DRILL H 9 P PJSA Perform injectivity test down 13 3/8"X 9 5/8"annulus by pumping 40 bbls LSND mud @ 1 bpm,550 psi 15:00 16:00 ' 1.00 16.00 DRILL H 20 P PJSA Blow down and R/D all cementing lines and equipment. 16:00 16:30 0.50 16.50 DRILL E 20 P PJSA P/U 1 stand of HWDP wl pup and TIW valve and run in 9 5/8"casing displacing fluid for up coming casing cut. 16:30 18:00 1.50 18.00 DRILL C 20 P PJSA ND BOPE and Multibowl. 18:00 20:00 2.00 20.00 DRILL C 18 P PJSA Lift stack and Vetco set emergency slips w/100k over block weight.Set down @ 1/4".Vetco set up Wachs cutter and cut 9 5/8"casing.Cut piece was 3.21'. 20:00 22:00 2.00 22.00 DRILL C 12 P PJSA Pull wear bushing and install 9 5/8"pack off.Lower stack and N/U.Test pack off to 2470 psi f/10 min. 22:00 23:00 1.00 23.00 DRILL C 20 P •PJSA N/U choke,kill and flow lines. 23:00 00:00 1.00 24.00 DRILL C 20 P PJSA Vetco set test plug and C/O Upper rams to 3.5"X 6"Variables. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dulling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.cam 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -0.90 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 925.07 754.85 LSND 1108.4 34.4 1564.8 118.1 040.001/4 Eni E&P Divisio Well N 07-SE4 OR ENI Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK 2^n Date:5/30/2015 - Report#: 15 APuuwl:50-629-23519-00-00 �""' page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type SOUTH PASS 46(F 1) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 399 11.26 960 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date •Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI07-SE4 DRILLING 5/19/2015 4,924.96 4916.42 124.58 39.5 12.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,903.78 1,240.19 0.00 101.0 -1.9 Overcast WC 21° N @ 10 MPH Daily summary operation 24h Summary CIO upper rams and install mousehole in table.M/U 105 stands of 4.5"DP&rack in derrick.C/O saver sub.RAJ and test BOPE as per AOGCC specs w/4.5"&5"test jts.Witness waived by Lou Grimaldi.M/U BHA#5 and RIH to 118'. Operation at 07.00 RIH W/BHA#5 @ 4,154'MD 24h Forecast Load Nuclear source and complete M/U BHA#5.RIH w/4.5"DP and perform SHT.Cont to RIH to 3900'+/-and Mad Pass to Float Collar @ 6154'.Perform casing test to 3000 psi f/30 charted min. Displace LSND w/9.3 ppg FazePro OBM.Drill shoe track and 20'-50'of new hole and CBU until balanced.Perform LOT/FIT.Drill ahead as per SLB/Geologists. Lithology Shows MAASP(kgflcma) Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL C 20 'P 'PJSA Complete C/O of upper rams to 3.5"X 6"variables.Install mouse hole in rotary table. 01:00 '10:30 9.50 10.50 DRILL 'E 20 P PJSA M/U 105 stands of 4.5"DP and rack in derrick.Sim Ops;LiL Red freeze protect annulus w/181 bbls of diesel @ 1.75 bpm,350-975 psi.850 psi Shut in pressure.Load mud pits w/700 bbls of 9.25 ppg FazePro. 10:30 11:00 0.50 11.00 DRILL E 20 P PJSA C/O jars and L/D 3 stands of HWDP. 11:00 '11:30 0.50 11.50 DRILL E 20 P PJSA L/D mouse hole,clear and clean rig floor. 11:30 14:30 3.00 14.50'DRILL 'E 25 P PJSA C/O saver sub to 4.5"NC 46. 14:30 15:30 1.00 15.50 DRILL C 20 P PJSA R/U testing equipment,flood and purge all lines and equipment. 15:30 '20:00 4.50 20.00 DRILL C 12 P PJSA Test BOPE as per AOGCC specs w/4.5"&5"test jts.Witness waived by Lou Grimaldi.Blow down and R/D from testing. 20:00 '20:30 0.50 20.50 DRILL C 20 P PJSA Vetco pull test plug and install 9.0"wear bushing. 20:30 '21:30 1.00 21.50 DRILL E 20 P PJSA Bring BHA#5 tools and equipment to rig floor. 21 30 100.00 2.50) 24.00 DRILL E -4 P PJSA M/U BHA#5 as per SLB and RIH to 118'. Daily Contacts Position Contact Name 1 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@enipelroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Cleric AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -0.90 1,902 26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cma) Eq.Mud Weight(gIL) P LeakOtf(kgflcm') 925.07 754.85 LSND 1108.4 34.4 1564.8 118.1 Eni E&P Divisio. Well Na 07-SE4 OR ENI Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK • 2 s n Date:5/31/2015 - Report#: 16 APIIUWI:50-629-23519-00-00 (� II II page 1 of 1 Wellbore name: SI07-SE4 • Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 13.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 1,909.88 1,240.89 6.10 0.30 20.3 100.0 -1.8 Overcast WC 25" NNW @ 5 MPH Daily summary operation 24h Summary Complete M/U BHA#5 and RIH to 1511'and perform SHT.RIH to 4174'and Mad Pass to 6146'(Top of cement).P/U 1 stand and perform Casing Integrity Test to 3000 psi 0 30 charted min.Displace LSND w/429 bbls of 9.3 ppg FazePro while drilling shoe track 6162'.Cut 8 slip drill line and adjust brakes while cleaning surface mud equip.Drill out shoe track and 20'of new hole.CBU and balance mud @ 9.4 ppg.Perform FIT test to 13.0 ppg.Circulate well and load 5"DP in pipe shed.Pump dry job and POOH L/D 132 Its of 4.5"DP. Operation at 07.00 Picking up 5"drill pipe 24h Forecast P/U,M/U and single in hole w/126 jts of 5"DP.POOH and rack back 42 stand of 5"DP.RIH w/4.5"DP then 5"DP and drill ahead as per SLB/Geologists. Lithology Shows MAASP(kgflcm2) Mud Weight(g/L) 1126.4 Time Log • Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 4 P PJSA Load nuclear source and M/U BHA#5 and RIH to 377',98k puw/sow.CIO handling equipment to 4.5" 01:00 01:30 0.50 1.50 DRILL E 4 P PJSA RIH w/BHA#5 on 4.5"DP to 1511'. 01:30 02:00 0.50 2.00 DRILL E 12 P PJSA Perform shallow hole test @ 350 gpm,530 psi.Blow down top-drive. 02:00 03:30 1.50' 3.50 DRILL E 4 P PJSA RIH f/1511'-4174'filling pipe every 2000'. 03:30 08:30 5.00' 8.50 DRILL E 4 P PJSA Madd Pass @ 600'per hour f/4174'-6146'Top of cement,220k puw,120k sow. 08:30 10:00 1.50 10.00 DRILL E 12 P PJSA Rack back 1 stand to 6068'.Blow down top-drive and R/U to test casing.Test casing to 3000 psi f/30 charted min. R/D test equipment. 10:00 12:30 2.50 12.50 DRILL E 7 P PJSA Displace LSND mud w/30 bbls Hi-Vis spacer,25 bbls LVT followed w/429 bbls of 9.3 ppg FazePro @ 400 gpm, 1210 psi,while drilling shoe track 6 6146'-6161'@ 80 rpm,12-16k tq.Tag Top Plug @ 6160'. 12:30 14:00 1.50 14.00 DRILL E 25 P PJSA Cut and slip 100'of drill line,adjust brakes and clean surface mud equipment. 14:00 17:00 3.00 17.00 DRILL E 3 P PJSA Drill shoe track to 6241'and 20'of new hole to 6266'@ 400 gpm,1300 psi,4-6k wob,5-12k tq..3 ADT/Bit/Jars. 17:00 18:30 1.50 18.50 DRILL E 9 P PJSA CBU while pulling pipe f/6266'-6167'until 9.4 ppg all around.R/U and perform FIT to 13.0 ppg via closing rams and pressuring up to 762 psi @.5 bpm w/1.7 bbls pumped.Bleed of pressure w/1 bbl retums. 18:30 19:30 1.00 19.50 DRILL E 7 P PJSA Circulate @ 3 bpm,200 psi while loading 5"DP in pipe shed. 19:30 20:00 0.50' 20.00 DRILL E 25 P PJSA Service top-drive,blocks,draw works and Iron roughneck. 20:00 20:30 0.50 20.50 DRILL E 7 P PJSA Pump 16 bbl dry job @ 3 bpm,200 psi.Blow down top-drive. 20:30 00:00 3.50 24.00 DRILL E 4 P PJSA POOH L/D 4.5"DP f/6167-1990',total of 132 jts. 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 Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -0.90 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm2) Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 1,902.26 1,240.00 FazePro OBM 1126.4 53.6 1558.4 193.2 fpor,001/4 Eni E&P Divisio. Well Na 07-SE4 OR ENI Petroleum Co-Inc- Daily Report Well Code:27981 Field Name:NIKIATCHUK • 2^1111 n II Date:6/1/2015 - Report#: 17 API/UWI:50-629-23519-00-00 page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(in) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 14.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 2,248.51 1,243.68 338.63 6.58 51.5 101.0 -1.0 Overcast WC 25" W©5 MPH Daily summary operation 24h Summary Single in hole(/1990'-6004'w/5"DP and pump dry job.POOH and rack back 5"DP.RIH w/BHA#5 on 4.5"DP to 6163'.C/O handling equip.to 5".Wash down to 6266'and DrIg.f/6266-7377'MD (4081'TVD). Operation at 07.00 Dolling ahead @ 7,564'MD 24h Forecast Drill ahead f/7377'as per SLB/Geologists. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 11264 Time Log Start End I Cum 1 Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 DRILL E 4 P PJSA C/O handling equipment to 5"and single 5"DP in hole f/1990'-6004'(Total of 126 jts.),1856 puw,140k sow.Fill pipe every 2000'.Break circulation and pump dry job.Blow down top-drive. 04:00 06:00 2.00 6.00 DRILL E 4 P PJSA POOH f/6004'-1990'and rack 5"DP in derrick.C/O handling equipment to 4.5". 06:00 08:30 2.50' 8.50 DRILL E 4 P PJSA RIH f/1990'-6163'w/4.5"DP f/derrick,175k puw,142k sow.Fill Pipe. 08:30 11:00 2.50 11.00 DRILL E 20 P PJSA C/O saver sub f/4.5"NC46 to 5"TT525 and Saver sub wear guides.Wash and service top-drive. 11:00 12:00 1.00 12.00 DRILL E 4 P PJSA Wash down f/6163'-6266 @ 400 gpm,1490 psi,80 rpm,8k tq.Down link off bottom. 12:00 18:00 6.00' 18.00'DRILL E 3 P PJSA Drig.f/6266-6629'MD(4082'TVD)@ 540 gpm,2270 psi,140 rpm,6-8k wob,10k tqn,7k tqf,185k puw,125k sow,149k rotw,10.50 ECD,Max Gas 1074,3.58 ADT,3.88 Bit/Jars. 18:00 00:00 6.00 24.00 DRILL E 3 'P PJSA Ddg.f/6229'-7377'MD(4081 TVD)@ 517 gpm,2140 psi,140 rpm,6-8k nob,9-10k tqn,7k tqf,190k puw,120k sow,150k rotw,10.33 ECD,Max Gas 1717,3.0 ADT,6.88 Bit/Jars.SPR @ 7280'MD(4076'TVD)w/9.4 MW;#1/#2/#3 @ 20-220.@ 30-280. 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 Mitch Billington ENI Rig Clerk AKRi9ClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -0.90 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,902.26 1,240.00 FazePro OBM 1126.4 53.6 1558.4 193.2 04.05* Eni E&P Divisio. Well N 07-SE4 OR I ENI Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK 2 n Date:6/2/2015 - Report#: 18 API/UWI:50-629-23519-00-00 �� iipage 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) •RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 15.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,946.50 1,251 63 697.99 15.12 46.2 101.0 -3.3 Overcast WC 11° NNE @ 19 MPH Daily summary operation 24h Summary Drill 8.75"Production hole F/7,377'to 9,667'MD(4,107'TVD)520 GPM,2,330 PSI,140 RPM,TQN 11-12K,TQF 8-9K,WOB 6-10K,HST 205K,SLK 110,ROT 152K,ECD 10.82 ppg W/9.45 ppg MW. Max Gas 1,419 units.ADT 15.12,Bit Hrs 22.00,Jar Hrs 22.00.Monitor well,static.Lost 19 bbl to formation. Operation at 07.00 Drill 8.75"Production hole @ 10,103'MD. 24h Forecast Drill 8.75"Production hole F/9,667'to 16,158'MD as per well plan. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00'DRILL E 3 P PJSA Drill 8.75"Production hole F/7,377'to 7,750'MD(4,107'TVD)520 GPM,2,110 PSI,140-180 RPM,TQN 10K,TQF 7 -8K,WOB 6-14K,HST 190K,SLK 120,ROT 150K,ECD 10.29 ppg W/9.4 ppg MW.Max Gas 1,222 units.ADT 4.24,Bit Hrs 11.12,Jar Hrs 11.12.Monitor well,static. SPR @ 8,216'MD(4,110'TVD)W/9.4 ppg MW 06:00 12:00 ' 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/7,750'to 8,262'MD(4,107'TVD)520 GPM,2,170 PSI,140-180 RPM,TON 10K,TQF 6 -7K,WOB 6-14K,HST 190K,SLK 115,ROT 149K,ECD 10.48 ppg W/9.4 ppg MW.Max Gas 1,019 units.ADT 3.69,Bit Hrs 14.81,Jar Hrs 14.81.Monitor well,static.Lost 19 bbl for tour. SPR @ 8,216'MD(4,110'1VD)W/9.4 ppg MW MP#1 20-200,30-260 MP#2 20-200,30-260 MP#3 20-200,30-260 12:00 18:00 6.00 18.00 DRILL 'E 3 P PJSA Drill 8.75"Production hole F/8,262'to 8,870'MD(4,110'TVD)520 GPM,2,220 PSI,140 RPM,TQN 11K,TQF 7-9K, WOB 6-8K,HST 197K,SLK 115,ROT 151K,ECD 10.58 ppg W/9.4 ppg MW.Max Gas 965 units.ADT 4.7,Bit Hrs 19.51, Jar Hrs 19.51.Monitor well,static. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/8,870'to 9,667'MD(4,107'TVD)520 GPM,2,330 PSI,140 RPM,TQN 11-12K,TQF 8- 9K,WOB 6-10K,HST 205K,SLK 110,ROT 152K,ECD 10.82 ppg W/9.45 ppg MW.Max Gas 1,419 units.ADT 2.49,Bit Hrs 22.00,Jar Hrs 22.00.Monitor well,static.No losses. SPR @ 9,243'MD(4,099'TVD)W/9.4 ppg MW MP#1 20-260,30-320 MP#2 20-260,30-320 MP#3 20-260,30-320 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDD6lling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Jack Kvasnikoff EM HSE 907-685-0721 907-398-8770 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -0.90 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gtL) P LeakOff(kgf/cm') 1,902.26 1,240.00 FazePro OBM 1126.4 53.6 15584 193.2 Eni E&P Divisio. eu407-SE4 OR EN/Petroleum Co.Inc. Daily Report V1leII Code:27981 Field Name:NIKIATCHUK • enil Date:6/3/2015 - Report#: 19 APUUWI:50-629-23519-00-00 II (I page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0107-0E4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 16.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 3,614.01 1,250.89 667.51 16.46 40.6 102.0 -3.9 Overcast WC 13° NNE©15 MPH Daily summary operation 24h Summary Drill 8.75"Production hole F/9,667'to 11,857'MD(4,105'ND)520 GPM,2,440 PSI,140-180 RPM,TQN 13-14K,TQF 9-11K,WOB 4-16K,HST 208K,SLK N/A,ROT 154K,ECD 10.91 ppg W/9.4 ppg MW.Max Gas 1,462 units.ADT 16.46,Bit Hrs 38.46,Jar Hrs 38.46.Monitor well,static.Lost 89 bbl for today. Operation at 07.00 Drill 8.75"Production hole @ 12,418 MD. 24h Forecast Drill 8.75"Production hole F/11,857to 16,158'MD as per well plan. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 11264 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"Production hole Fl 9,667'to 10,270'MD(4,112'TVD)520 GPM,2,350 PSI,140-180 RPM,TON 12K,TQF 8-9K,WOB 8-14K,HST 205K,SLK 110K,ROT 151K,ECD 10.85 ppg W/9.4 ppg MW.Max Gas 916 units.ADT 4.2,Bit Hrs 2620,Jar Hrs 26.20.Monitor well,static. SPR @ 10,170'MD(4,114'ND)W/9.45 ppg MW MP#1 20-250,30-310 MP#2 20-250,30-310 MP#3 20-250,30-310 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/10,270'to 10,956'MD(4,122'ND)520 GPM,2,430 PSI,140-180 RPM,TQN 12K. TOE 9K,WOB 6-16K,HST 205K,SLK 110K,ROT 151K,ECD 10.98 ppg W/9.45 ppg MW.Max Gas 1,355 units.ADT 322,Bit Hrs 29.42,Jar Hrs 29.42.Monitor well,static.Lost 44 bbl for tour. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/10,956'to 11,484'MD(4,119'ND)520 GPM,2,420 PSI,140-180 RPM,TQN 13-14K, TQF 9-11K,WOB 4-14K,HST 208K,SLK N/A,ROT 152K,ECD 10.75 ppg W/9.35 ppg MW.Max Gas 1,300 units.ADT 4.65,Bit Hrs 34.07,Jar Hrs 34.07.Monitor well,static. SPR @ 11,204'MD(4,122'ND)W/9.45 ppg MW MP#1 20-300,30-380 MP#2 20-300,30-380 MP#3 20-300,30-380 1800 00:00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/11,484'10 11,857'MD(4,105'ND)520 GPM,2,440 PSI,140-180 RPM,TON 13-14K, TQF 9-11K,WOB 4-16K,HST 208K,SLK N/A,ROT 154K,ECD 10.91 ppg W/9.4 ppg MW.Max Gas 1,462 units.ADT 4.39,Bit Hrs 38.46,Jar Hrs 38.46.Monitor well,static. Daily Contacts Position Contact Name • Company Title E-mail Office Mobile Eni representative Davide Simeone ENI Project Manager 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 Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Drilling (Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -0.90 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1.902 26 1,240 00 FazePro OBM 1126.4 53.6 1558.4 193.2 1'< Eni E&P Divisio. Well N 07-SE4 OR EN/Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK • enf� Date:6/4/2015 - Report#: 20 APIIUWI:50-629-23519-00-00 �I "n page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5107-5E4 DRILLING 5/19/2015 4.924.96 4,916.42 124.58 39.5 17.00 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,371.75 1,253.53 757.73 14.80 51.2 102.0 -3.3 Overcast WC 9' NNE©26 MPH Daily summary operation 24h Summary Drill 8.75"Production hole F/11,857'to 14,343'MD(4,117'TVD)500 GPM,2,560 PSI,140 RPM,TQN 15K,TQF 12K,WOB 6-10K,HST 218K,SLK N/A,ROT 151K,ECD 11.03 ppg W/9.4 ppg MW. Max Gas 1,663 units.ADT 14.8,Bit Hrs 5326,Jar Hrs 53.26.Monitor well,static.Lost 69 bbl for today. Operation at 07.00 Drill 8.75"Production hole @ 14,482'MD. 24h Forecast Drill 8.75"Production hole F/14,343'to 16,158'MD as per well plan. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 11264 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/11,857'to 12,683'MD(4,099'TVD)520 GPM,2,560 PSI,140-180 RPM,TQN 14K, TQF 11K,WOB 6-14K,HST 220K,SLK N/A,ROT 150K,ECD 11.09 ppg W/9.4 ppg MW.Max Gas 1,502 units.ADT 3.3, Bit Hrs 41.76,Jar Hrs 41.76.Monitor well,static. 06:00 12:00 6.00 12.00 DRILL E -3 P PJSA Drill 8.75"Production hole F/12,683'to 13,419'MD(4,113'TVD)520 GPM,2,670 PSI,140 RPM,TON 14K,TQF 11- 14K,WOB 6-12K,HST 235K,SLK N/A,ROT 153K,ECD 11.24 ppg W/9.4 ppg MW.Max Gas 1,663 units.ADT 3.09,Bit Hrs 44.85,Jar Hrs 44.85.Monitor well,static.Lost 22 bbl for tour. SPR @ 13,258'MD(4,114'ND)W/9.4 ppg MW MP#2 20-300,30-370 MP#3 20-300,30-370 12:00 18.00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/13,419'to 13,926'MD(4,114'TVD)500 GPM,2,540 PSI,140-180 RPM,TQN 16K, TQF 12-14K,WOB 6-14K,HST 210K,SLK N/A,ROT 153K,ECD 10.98 ppg W/9.4 ppg MW.Max Gas 1,634 units.ADT 4.47,Bit Hrs 49.32,Jar Hrs 49.32.Monitor well,static. 18:00 000 6.00 24.00 DRILL E - 0. 3 P PJSA Drill 8.75"Production hole F/13,926'to 14,343'MD(4,117'TVD)500 GPM,2,560 PSI,140 RPM,TON 15K,TQF 12K,WOB 6-10K,HST 218K,SLK N/A,ROT 151K,ECD 11.03 ppg W/9.4 ppg MW.Max Gas 1,426 units.ADT 3.94,Bit Hrs 53.26,Jar Hrs 53.26.Monitor well,static.Lost 47 bbl for tour. SPR @ 14,192'MD(4,119'TVD)W/9.35 ppg MW MP#1 20-320,30-400 MP#3 20-320,30-400 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Davide Simeone ENI Project Manager Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-665-0715 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jeremey Decker EM Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondnlling.com 907-685-0716 Last Casing seat Can.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -090 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 1,902.26 1,240.00 FazePro OBM 1126.4 53.6 1558.4 193.2 to` Eni E&P Divisioe Well N 07-SE4 OR I ENI Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK eAPIIUWI:50-629-23519-00-00 n Date:6/5/2015 - Report#: 21 lam" II II page 1 of 1 Wellbore name: S!07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.L) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI07-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 18.00 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,895.09 1,241.47 523.34 17.27 30.3 101.0 0.0 Overcast WC 18° ENE @ 18 MPH Daily summary operation 24h Summary Drill 8.75"Production hole F/14,343'to 16,060'MD(4,075'ND)520 GPM,2,840 PSI,140-180 RPM,TQN 16K,TQF 12K,WOB 2-20K,HST 225K,SLK N/A,ROT 150K,ECD 11.8 ppg W/9.4 ppg MW. Max Gas 1,529 units.ADT 17.27,Bit Hrs 70.53,Jar Hrs 70.53.Monitor well,static.Lost 46 bbl for today. Operation at 07.00 Circulating Bottoms Up 24h Forecast Drill 8.75"Production hole F/16,060'to 16,130'MD as per Schlumberger DD and Gheology.BROOH as per KAM schedule. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11264 Time Log Start End Cum Time Time Dur(hr) Dar(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '06.00 6.00 6.00 DRILL •E 3 P PJSA Drill 8.75"Production hole F/14,343'to 14,566'MD(4,106'TVD)500 GPM,2,520 PSI,140-180 RPM,TQN 15K, TQF 12K,WOB 8-18K,HST 218K,SLK N/A,ROT 151K,ECD 11.04 ppg W/9.4 ppg MW.Max Gas 1,529 units.ADT 5.16, Bit Hrs 58.42,Jar Hrs 58.42.Monitor well,static. 06:00 12.00 6.00 12.00 DRILL •E 3 P PJSA Drill 8.75"Production hole F/14,566'to 14,931'MD(4,100'TVD)500 GPM,2,750 PSI,140-180 RPM,TON 15K, TQF 11-12K,WOB 8-18K,HST 215K,SLK N/A,ROT 150K,ECD 11.31 ppg W/9.4 ppg MW.Max Gas 1,182 units.ADT 4.63,Bit Hrs 63.05,Jar Hrs 63.05.Monitor well,static.Lost 32 bbl for tour. SPR @ 14,931'MD(4,100'ND)W/9.4 ppg MW MP#1 20-320,30-400 MP#2 20-320,30-400 MP#3 20-320,30-400 1200 18.00 6.00 18.00 DRILL •E 3 •P PJSA Drill 8.75"Production hole F/14,931'to 15,480'MD(4,086'ND)520 GPM,2,800 PSI,140-180 RPM,TQN 15K, TQF 12K,WOB 2-18K,HST 220K,SLK N/A,ROT 150K,ECD 11.21 ppg W/9.4 ppg MW.Max Gas 1,227 units.ADT 3.96, Bit Hrs 67.01,Jar Hrs 67.01. 18.00 .0000 6.00 24.00 DRILL E 3 -P PJSA Drill 8.75"Production hole F/15,480'to 16,060'MD(4,075'ND)520 GPM,2,840 PSI,140-180 RPM,TQN 16K, TOP 12K,WOB 2-20K,HST 225K,SLK N/A,ROT 150K,ECD 11.8 ppg W/9.4 ppg MW.Max Gas 1,391 units.ADT 3.52, Bit His 70.53,Jar Hrs 70.53.Monitor well,static.Lost 14 bbl for tour. SPR @ 15,778'MD(4,076'ND)W/9.4 ppg MW MP#1 20-360,30-420 MP#2 20-360,30-420 MP#3 20-360,30-420 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 Dulling 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 Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Tool Push ,Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -0.90 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 1,902.26 1,240.00 FazePro OBM 11264 53.6 1558.4 193.2 aro;iiiiis, Eni E&P Div►S10 Well N 07-SE4 OR EN/Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK 2,n"I Date:6/612015 - Report#: 22 I+Plluwl:50-629-23519-00-0000 '� Ipage 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 19.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,916.42 1,241 84 21.34 0.29 73.6 98.0 0.0 Overcast WC 22' E @ 8 MPH Daily summary operation 24h Summary Drill 8.75"Production hole F/16,060'to 16,130'MD(4,077'ND)520 GPM,2,910 PSI,140 RPM,TON 15K,TQF 12K,WOB 8-10K,HST 225K,SLK N/A,ROT 150K,ECD 11.35 ppg W/9.4 ppg MW. Max Gas 1,237 units.ADT 0.29,Bit Hrs 70.82,Jar Hrs 70.82.Monitor well,static.CBU 5X as per K&M schedule racking back one 5"stand per BU F/16,130'to 15,688'MD.BROOH as per K&M Schedule F/15,688'to 10,737'MD.500 GPM,2,200 PSI,140 RPM,TRQ 12K,HST 195K,SLK 120K,ROT 150K.ECD 10.56 W/9.4 ppg.Calculated displacement 44 bbl,actual displacement 124 bbl, lost 80 bbl to formation. Operation at 07.00 BROOH as per K&M schedule @ 9,046'MD. 24h Forecast BROOH as per K&M schedule F/10,737'MD. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 0030 0.50 0.50 DRILL E 3 P Drill 8.75"Production hole F/16,060'to 16,130'MD(4,077'ND)520 GPM,2,910 PSI,140 RPM,TQN 15K,TOE 12K, WOB 8-10K,HST 225K,SLK N/A,ROT 150K,ECD 11.35 ppg WI 9.4 ppg MW.Max Gas 1,237 units.ADT 0.29,Bit Hrs 70.82,Jar Hrs 70.82.Monitor well,static. C SPR @ 16,130'MD(4,077'ND)WI 9.4 ppg MW MP#1 20-370,30-450 MP#2 20-370,30-450 MP#3 20-370,30-450 00:30 01:00 0.50 1.00 DRILL E 11 P Perform down link and shoot survey as per Schlumberger MWD and DD.Monitor well,static. 01:00 07:00 6.00 7.00 DRILL E 6 P PJSA CBU 5X as per K&M schedule racking back 1 5"stand per BU F/16,130'to 15,688'MD.550 GPM,3,090 PSI,140 RPM,TRQ 14K,HST 215K,SLK 95K,ROT 152K.Calculated displacement 4 bbl,actual displacement 42 bbl,lost 38 bbl. 07:00 12:00 5.00 12.00 DRILL 'E 6 P PJSA BROOH as per K&M Schedule F/15,688'to 14,475'MD.500 GPM,2,530 PSI,140 RPM,TRQ 14K,HST 210K,SLK 105K,ROT 153K.ECD 11.0 W/9.4 ppg.Calculated displacement 9 bbl,actual displacement 19 bbl, lost 10 bbl to formation. 12:00 18:00 6.00 18.00 DRILL E 6 P PJSA BROOH as per K&M Schedule F/14,475'to 12,511'MD.500 GPM,2,350 PSI,140 RPM,TRQ 13K,HST 205K,SLK 105K,ROT 145K.ECD 10.71 W/9.4 ppg 18:00 00:00 6.00 24.00 DRILL E 6 P PJSA BROOH as per K&M Schedule F/12,511'to 10,737'MD.500 GPM,2,200 PSI,140 RPM,TRQ 12K,HST 195K,SLK 120K,ROT 150K.ECD 10.56 W/9.4 ppg.Calculated displacement 31 bbl,actual displacement 63 bbl, lost 32 bbl to formation. 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 Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Matls Coordinator Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Paul Holley ENI HSE Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -0.90 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,902.26 1,240.00 FazePro OBM 1126.4 53.6 1558.4 193.2 lot. Eni E&P Divisiola Well Na 07-SE4 OR I ENI Petroleum Co.Inc. Daily Repo)„t Well Code:27981 Field Name:NIKIATCHUK nDate:6/7/2015 - Report#: 23 APIIUWI:50-629-23519-00-00 — (� ��'ipage 1 of 1 Wellbore name: 5107-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI07-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 20.00 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,916.42 1,241.84 000 100.0 0.0 Partly Cloudy WC E @ 15 MPH 20- Daily summary operation 24h Summary BROOH as per K&M Schedule F/10,737'to 6,160'MD.500 GPM,1,830 PSI,120 RPM,TRQ 9K,HST 175K,SLK 138K,ROT 150K.ECD 10.07 W/9.4 ppg.Calculated displacement 40 bbl,actual displacement 94 bbl, lost 54 bbl to formation.Cont.CBU 4X as per K&M F/6,160'to 6,067' MD 550 GPM,2,200 PSI,120 RPM,TRQ 9K.Monitor well,static.POOH on Elevators F/6,160'to 5,690'MD. HST 176K.Pump dry job and Cont to POOH to 1,038'MD.Circ.hole clean as per K&M 550 GPM,1,220 PSI,60 RPM,TRQ 2K.POOH F/1,038'to 377'MD.PJSM W/all essential personnel for GD BHA and Nuclear Source as per Schlumberger DD and MWD.Co Rep onsite.L/D Nuclear source and BHA#5 as per Schlumberger DD and MWD.Calculated displacement 41 bbl,actual displacement 54,lost 13 bbl for trip.Bit Grade 1-2-CT-T-X-IN-WT-TD.String Stabilizer was 7 3/8”ILS was 8''/."everything else was good.Clean and clear rig floor of BHA#5 components.Service and inspect TDS-8. Blocks and Hook.P/U BHA#6 tools to rig floor. Operation at 07.00 RIH BHA#6 8 3/4"Hole Opener @ 6,054'MD. 24h Forecast P/U M/U BHA#6 as per Schlumberger DD.RIH W/4.5"and 5"D.P.to 16,130'MD.Circ.and build Faze Away Breaker.Spot Faze Away Breaker as per MI Swaco plan.POOH to 6,041'MD and displace to Brine.Cont.to POOH. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 11264 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 6 P PJSA BROOH as per K&M Schedule F/10,737'to 8,219'MD.500 GPM,2,000 PSI,140 RPM,TRQ 11K,HST 185K,SLK 130K,ROT 150K.ECD 10.19 W/9.4 ppg. 06:00 '11:30 5.50 11.50 DRILL E 6 P PJSA BROOH as per K&M Schedule F/8,219'to 6,160'MD.500 GPM,1,830 PSI,120 RPM,TRQ 9K,HST 175K,SLK 138K,ROT 150K.ECD 10.07 W/9.4 ppg.Calculated displacement 40 bbl,actual displacement 94 bbl, lost 54 bbl to formation. 11:30 12:00 0.50 12.00 DRILL E 7 P CBU as per K&M schedule 550 GPM,2,130 PSI,120 RPM,TRQ 9K. 12:00 13:30 1.50 13.50 DRILL E 7 P PJSM Cont.CBU 4X as per K&M F/6,160'to 6,067' MD 550 GPM,2,200 PSI,120 RPM,TRQ 9K.Monitor well,static. 13:30 17:00 3.50 17.00 DRILL E 4 P PJSA POOH on Elevators F/6,160'to 5,690'MD.HST 176K.Pump dry job and Cont.to POOH to 1,038'MD. 17:00 17:30 0.50 17.50 DRILL E 7 P PJSA Circ.hole clean as per K&M 550 GPM,1,220 PSI,60 RPM,TRQ 2K. 17:30 18:00 0.50 18.00 DRILL E 4 P PJSA POOH F/1,038'to 377'MD. 18:00 20:30 2.50 20.50 DRILL E 4 P PJSM W/all essential personnel for L/D BHA and Nuclear Source as per Schlumberger DD and MWD.Co Rep onsite.L/D Nuclear source and BHA#5 as per Schlumberger DD and MWD.Calculated displacement 41 bbl,actual displacement 54, lost 13 bbl for trip.Bit Grade 1-2-CT-T-X-IN-WT-TD.String Stabilizer was 7 3/8"ILS was 8'''A"everything else was good. 20:30 21:30 1.00 21.50 DRILL E 20 P PJSA Clean and clear rig floor of BHA#5 components. 21:30 23:00 1.50 23.00 DRILL E 25 P PJSA Service and inspect TDS-8,Blocks and Hook. 23:00 00:00 1.00 24.00 DRILL E 20 P PJSA P/U BHA#6 tools to rig floor. 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 Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Vance Dale ENI Malls Coordinator Eni representative Jeremey Decker ENI Expediter 'eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Paul Holley ENI HSE Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 -0.90 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm2) 1.902.26 1,240.00 FazePro OBM 1126.4 53.6 1558.4 193.2 16....iiis, Eni E&P Divisio. I Well NI110107-SE4 ORI EN!Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK �,n, Date:6/8/2015 - Report#: 24 API/UWI:50-629-23519-00-00 l�II i opage 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 399 11.26 960 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 21.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wnd 4,916.42 1,241.84 0.00 105.0 4.4 Mostly Cloudy WC WNW @ 7 MPH 34° Daily summary operation 24h Summary P/U M/U 8.75"BHA#6 Hole Opener as per Schlumberger DD.CIO handling Equip.to 4.5".RIH BHA#6 W/4.5"D.P.F/205'to 5,994'MD.HST 175K,SLK 135K.Fill D.P.every 2,000'MD.C/O Handling Equip.to 5",P/U M/U 6 joints of 5"D.P.to 6,181'MD.Drifted.Cont.RIH BHA#6 W/5"D.P.F/6,181'to 16,130'MD.HST 200K,SLK 110K.Filling every 2,000'.Calculated displacement 109 bbl,actual displacement 109,no losses.Reciprocate F/16,130'to 16,067'MD.Circ.@ 3 bpm,340 PSI,5 RPM,TRQ 12K,HST 200K,SLK 110K,ROT 150K.SIMOPS:Build Faze Away Breaker at Mud Plant.Prep mud pits for spotting Faze Away.PJSM W/all essential personnel for spotting Breaker. Pump Faze Away Breaker as per MI Swaco plan forward,Pump 750 bbl 9.5 ppg Faze Away @ 4 bpm,430 PSI,20 RPM,TRQ 10K,Pump 18 bbl 9.2 ppg Brine,30 bbl 9.4 ppg Faze Pro,39 bbl 11.4 ppg Dry Job,10 bbl 9.4 ppg Faze Pro to clear lines.POOH on Elevators as per K&M trip schedule F/16,130'to 15,703' MD.HST 235K,SLK 110K.Monitor well for 10 Min.,20 bph static loss.Cont.POOH on Elevators to 14,207'MD.Calculated displacement 11 bbl,actual displacement 65 bbl,lost 54 bbl for trip. Operation at 07.00 POOH on elevators F/10,200'MD. 24h Forecast Cont.to POOH on elevators F/14,20T to-5,994'MD.Displace 9.4 ppg Faze Pro to 9.2 ppg Brine.Cont.to POOH laying down 4.5"D.P.to Pipe Shed. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. • 00:00 00:30 0.50 0.50 DRILL E 20 P PJSAP/U M/U 8.75"BHA#6 Hole Opener as per Schlumberger DD.C/O handling Equip.to 4.5". 00:30 03:30 3.00 3.50 DRILL E 4 P PJSA RIH BHA#6 W/4.5"D.P.F/205'to 5,994'MD.HST 175K,SLK 135K.Fill D.P.every 2,000'MD. 03:30 04:00 0.50 4.00 DRILL E 20 P PJSA C/O Handling Equip.to 5",P/U M/U 6 joints of 5"D.P.to 6,181'MD.Drifted. 04:00 08:30 ' 4.50 8.50 DRILL E 4 P PJSA Cont.RIH BHA#6 W/5"D.P.F/6,181'to 16,130'MD.HST 200K,SLK 110K.Filling every 2,000'.Calculated displacement 109 bbl,actual displacement 109,no losses. 08:30 12:00 3.50 12.00 DRILL 'E 7 P PJSA Circ.@ 3 bpm,340 PSI,5 RPM,TRO 10K,ROT 150K.SIMOPS:Build Faze Away Breaker at Mud Plant Prep mud pits for spotting Faze Away. 12:00 15:00 3.00 15.00 DRILL E 7 P 'PJSA Reciprocate F/16,130'to 16,067'MD.Circ.@ 3 bpm,340 PSI,5 RPM,TRQ 12K,HST 200K,SLK 110K,ROT 150K. SIMOPS:Build Faze Away Breaker at Mud Plant.Prep mud pits for spotting Faze Away. 15:00 20:30 5.50 20.50 DRILL (E 9 P PJSM W/all essential personnel for spotting Breaker. Pump Faze Away Breaker as per MI Swaco plan forward,Pump 750 bbl 9.5 ppg Faze Away @ 4 bpm,430 PSI,20 RPM,TRQ 10K,Pump 18 bbl 92 ppg Brine,30 bbl 9.4 ppg Faze Pro,39 bbl 11.4 ppg Dry Job,10 bbl 9.4 ppg Faze Pro to clear lines. 20:30 00:00 3.50 24.00 DRILL E 4 P PJSA POOH on Elevators as per K&M trip schedule F/16,130'to 15,703'MD.HST 235K,SLK 110K.Monitor well for 10 Min.,20 bph static loss.Cont.POOH on Elevators to 14,207'MD.Calculated displacement 11 bbl,actual displacement 65 bbl,lost 54 bbl for trip. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dulling 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 Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Paul Holley ENI HSE Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -0.90 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1.902.26 1240.00 FazePro OBM 1126.4 53.6 1558.4 1932 Eni E&P Divisio. Well Na 07-SE4 OR ENI Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK nDate:6/9/2015 - Report#: 25 API/UWI:50-629-23519-00-00 I' (I IIpage 1 of 1 Wellbore name: SI07-SE4 Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 22.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 4,916.42 1,241 84 0.00 100.0 1.7 Mostly Cloudy WC E @ 25 MPH 23' • Daily summary operation 24h Summary POOH f/14,207'-6168'w/5"OP.Circulate well while lowering volume in mud pits.Cut&slip drill line and service rig.Displace FazePro OBM wd 9.2 ppg KCL brine and clean surface mud equipment. POOH VD 4.5"DP and BHA#6.R/U GBR casing running equipment and hold PJSM w/all personnel.M/U and RIH w/4.5"11.68 L80 H521 Injection liner as per tally to 882'. Operation at 07.00 M/U and RIH w/4.5"Injection liner to 2,898'and 24h Forecast Continue to M/U and run 4.5"Injection liner as per tally.M/U Baker SLZXP liner hanger/packer and service.Run 1 stand of 5"DP and circulate to ensure flow paths are free.RIH w/Injection liner to bottom w/5"DP.Circ.DP volume and record K&M parameters when needed. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:30 6.50 6.50 DRILL E 4 P PJSA POOH f/14,207'-6178',w/5"DP,170k puw,135k sow. 06:30 08:00 1.50 8.00 DRILL E 7 P PJSA Circulate staging up to 7 bpm,570 psi.Lower volume in mud pits. 08:00 09:30 1.50 9.50 DRILL E 25 P PJSA Cut and slip 119'drilling line,service draw works and crown. 09:30 11:30 2.00 11.50 DRILL E 7 P PJSA Displace FazePro w/47 bbls LVT,85 bbls Hi-Vis citric acid pill followed w/512 bbls 9.2 ppg KCL brine @ 7 bpm,360 -330 psi,w/50 rpm,6k tq,185k puw,125k sow. 11:30 12:00 0.50 12.00 DRILL E 20 P PJSA Blow down top-drive and clean surface equipment from FazePro/water interface.113 bbls Tourly fluid losses. 12:00 17:00 5.00 17.00 DRILL E 4 P PJSA POOH f/6178'-to BHA laying down 4.5"DP. 17:00 18:00 1.00 18.00 DRILL E 4 P PJSA Lay down BHA#6. 18:00 18:30 0.50 18.50 DRILL E 20 'P PJSA Clear and clean rig floor. 18:30 19:30 1.00 19.50 DRILL G 20 P PJSA P/U and R/U GBR casing running equipment. 19:30 00:00 4.50 24.00:DRILL G 4 P PJSA WI all personnel and M/U and RIH w14.5"11.6#L80 H521 Injection liner to 882'as per tally,90k puw/sow.53 bbls Tourly fluid losses. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Eni representative Paul Holley ENI HSE Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Can.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 -0.90 1,902.26 5/28/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 1,902.26 1,240.00 FazePro OBM 1126.4 53.6 1558.4 193.2 filo 1. Eni E&P Divisio. Well Na 07-SE4 OR I ENI Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK enII n Date:6/10/2015 - Report#: 26 APIIUWI:50-629-23519-00-00 I� �I page 1 of 1 Wellbore name: SI07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOSON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI07-5E4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 23.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather W nd 4,916.42 1,241.84 0.00 100.0 0.0 Mostly Cloudy WC W @ 15 MPH 21° Daily summary operation 24h Summary M/U and RIH wl 4.5"Injection liner f/882'-10,10,010'.R/D Volant tools and M/U GBR power tongs.M/U Baker SLZXP hanger assy.and service.RIH w/1 stand of 5"DP and perform K&M torq&drag parameters.While B/O f/liner the top-drive hung a thread and rotated the liner to the left.The Baker hanger was pulled to the floor and UD.During inspection,the shear pins were compromised and it was sent to Baker Tool shop f/inspection&repairs.POOH L/D 3 jts of liner and all three were crushed.A decision was made to reciprocate liner until the hanger was back on the island. Operation at 07.00 Reciprocate liner f/9894'-9844'. 24h Forecast Reciprocate liner until the Baker liner hanger is back to the Island. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL G 4 P PJSA M/U&RIH w/4.5"Injection liner f/882'-4283'as per tally,113k puw,105k sow,fill liner every 10 jts. 06:00 12:00 6.00 12.00 DRILL G 4 P PJSA WU&RIH wl 4.5"Injection liner f/4283'-7730'as per tally,147k puw,103k sow,fill liner every 10 jts.54 bbls Tourly fluid losses. 12:00 15:00 3.00 15.00 DRILL G 4 P PJSA M/U&RIH wl 4.5"Injection liner f/7730'-10,010',150k puw,100k sow. 15:00 16:30 1.50 16.50 DRILL G 4 P PJSA R/D Volant tools and R/U GBR power tongs.M/U Baker SLZXP liner hanger/packer and service as per Baker.RIH to 10,050'.M/U XO and 1 stand of 5"DP. 16:30 17:30 1.00 17.50 DRILL G 4 P PJSA RIH to 10,140'and take K&M parameters w/150k puw,105k sow,120k rotw,5k tq. 17:30 18:00 0.50 18.00 DRILL G 20 TR99 PJSA While breaking out the top-drive,the top-drive threads hung up and spun the liner string to the left.The Baker hanger was pulled from the hole and was UD to check the safety shear pins which had been compromised.It was sent to Baker Tool shop to be inspected and repaired. 18:00 21:00 3.00 21.00 DRILL G 4 TR99 PJSA A decision from town was to POOH UD 4.5"liner to inside the 9 5/8"casing shoe.POOH f/10,080'-9968'L/D liner. Breaking out of the first two joints with the Volant,these jts.were crushed with the backup rig tongs. 21:00 00:00 3.00 24.00 DRILL G 4 TR99 PJSA R/D Volant tools and R/U GBR casing equipment.Break out 1 jt.to 9894'and crushed liner jt.A decision f/town was to reciprocate liner f/6894'-9844'until Baker liner hanger is back on location.150k puw,100k sow.34 bbls Toady fluid losses. Daily Contacts Position I 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 Wade Thomas ENI Rig Clerk Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative Paul Holley ENI HSE Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Can.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 1.36 4,916.42 6/11/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 1,902.26 1,240.00 FazePro OEM 1126.4 53.6 1558.4 193.2 Eni E&P D►v►sio. Well N 107-SE4 OR ENI Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK • en II Date:6/11/2015 - Report#: 27 API/U W I:50-629-2 3519-00-00 I� �' page 1 of 1 Wellbore name: SI07-SE4 • Well Header Permit/Concession Ne Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.1.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DES(days) S107-SE4 DRILLING 5/19/2015 4,924.96 4,916.42 124.58 39.5 23.75 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 4,916 42 1,241 84 0.00 103.0 -1 1 Clear WC 25` SW @ 5 MPH Daily summary operation 24h Summary Reciprocate liner waiting on Baker SLZXP liner hanger assy to be repaired.R/U Volant equipment and M/U 3 jts.of 4.5"liner and liner hanger.P/U 1 std.and circulate tool.RIH w/liner on 5"DP to 16,130'and pick up to 16,110'and set Baker liner hanger/packer and test to 1500 psi f/10 charted min.POOH UD 5"DP and Baker running tool @ surface.Last drilling report. Operation at 07.00 24h Forecast On completion report @ 1800 hrs.AFE#6935. Lithology Shows MAASP(kgf/cm) Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04.00 4.00 4.00 DRILL G 20 TR99 PJSA Reciprocate liner f/9985'-9935',140k puw,100k sow while waiting on SLZXP liner hanger to be rebuilt. 04:00 05:30 1.50 5.50 DRILL G 4 TR99 PJSA R/U GBR Volant CRT and equipment.P/U&M/U 3 jts.of 4.5"11.6#L80 H521 liner and RIH to 10,010'.R/D Volant and equipment and C/O handling equipment to 5". 05:30 06:30 1.00 6.50 DRILL G 4 TR99 PJSA WU Baker SLZXP liner hanger assy.and service as per Baker.Clear and clean rig floor.P/U 1 stand of 5"DP and RIH to 10,151'.Break circulation @ 3 bpm,220 psi.Blow down Top-drive. 06:30 11:30 5.00 11.50 DRILL G 4 P PJSA RIH w/4.5"liner on 5"DP f/10,151'-16,130',223k puw,90k sow. 11:30 12:00 0.50 12.00 DRILL G 4 P PJSA Pull up to 16,110'setting depth and Baker drop 1.685"setting ball.38 bbls Toudy fluid losses. 12:00 13:00 1.00 13.00 DRILL G 12 P PJSA Liner set @ 16,110',TOL @ 6066'.Pump Baker ball down @ 3 bpm,400 psi then slow to 2 bpm,260 psi.Seat ball and pressure to 3500 psi and set hanger/packer and observe shears.0/0 to block weight and bleed pressure to 0 psi.Pull up to neutral @ 120k.Pressure up 5"X 9 5/8"annulus to 1500 psi f/10 charted min.to test hanger/packer.Bleed off all pressure,pull up and rack back 1 stand to 6015',175k puw. 13:00 18:00 5.00 18.00 DRILL G 4 P PJSA POOH Laying down 5"DP and Baker running tool @ surface.This the last drilling report. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.cow 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Rig Clerk Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative Paul Holley ENI HSE Tool Push Pete Marlinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 1.36 4,916.42 6/11/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,902.26 1240.00 FazePro 06M 1126.4 53.6 1558.4 193.2 If* Eni E&P Divisio. wag N 107-SE4 OR I ENI Petroleum Co.Inc. Daily Report well Code:27981 Field Name:NIKIATCHUK 2 n n II Date:6/11/2015 - Report#: 1 APIIUWI:50-629-23519-00-00 I' �� page 1 of 1 Wellbore name: SI07-SE4 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(F.I) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI07-SE4 COMPLETION 27.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 0.00 103.0 -1.1 Clear WC 25° SW @ 5 MPH Daily summary operation 24h Summary L/D Baker running tool.Set up and L/D 19 stands of 5"DP from derrick.Vetco pull wear bushing.PJSA w/all personnel and R/U GBR Volant eaquipment and power tongs.M/U and run 4.5"12.66 L80 H563 to 845'. Operation at 07.00 Running 4.5"completion as per tally @ 3,399' 24h Forecast Continue to run 4.5"completion as per tally to NO-GO and pull up and space out tubing.M/U Vetco hanger and land tubing.RILDS and test seals to 5000 psi f/10 min.Set Baker packer by closing Autofll and pressuring up to 2600 psi f/30 charted min.Tubing integrity test.Bleed tubing to 2000 psi and pressure IA to 2500 psi for 30 charted min.IA Integrity test. Bleed IA to 0 psi and pressure tubing to 4400 psi to shear Mirage plug.Pressure IA TO 2000+to shear GLM valve.Pull landing jt and set BPV.N/D stack and N/U Vetco tree. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 18:00 18:30 0.50 0.50 COMP 'K 20 P 'PJSA L/D Baker running tool. 18:30 20:30 2.00 2.50 COMP K 20 P PJSA Set mousehole and L/D 19 stands of 5"DP from derrick. 20:30 21:00 ' 0.50 3.00 COMP K 20 P PJSA L/D mousehole.P/U test jt and Vetco pull wear bushing. 21:00 22:00 1.00 4.00 COMP K 20 P PJSA vd all personnel.R/U GBR volant tool and equipment.R/U power tongs. 22:00 00:00 2.00 6.00 COMP K 4 P PJSA M/U and RIH w/4.5"12.6#L80 H563 completion tubing as per tally to 845',88k puw/sow.24 bbls Tourty fluid losses. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.cow 907-685-0716 Eni representative Paul Holley ENI HSE Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 1.36 4,916.42 6/11/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1.902.26 1,240.00 FazePro OBM 1126.4 53.6 1558.4 193.2 rillillik 1 Eni E&P Divisio. Well N 107-SE4 OR ENI Petroleum Co.Inc. Daily Report Well Code:27981 Field Name:NIKIATCHUK eni Date:6/12/2015 - Report#: 2 API/UNA:50-629-23519-00-00 page 1 of 1 Wellbore name: S)07-SE4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(FA) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.43 3.99 11.26 9.60 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SI07-SE4 COMPLETION 28.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 0.00 106.0 7.8 Clear WC 34' SE @ 12 MPH Daily summary operation 24h Summary Run 4.5"H563 tubing completion as per tally.NO-Go pins sheared and pull up and space out string.Land tubing on Vetco tbg.hanger,RILDS and test seals to 5000 psi f/10 min.TOL @ 6068',Btm of WLEG @ 6088'.20'Sting in Liner top.R/U and close Autofill,Set Baker HS packer and hold 3000 psi on tubing for Tubing Integrity Test.Pressure IA to 2500 psi for IA Integrity Test.Pressure up and shear Mirage plug.Pressure IA and shear GLM valve.Set BPV and N/D BOPE.Install Vetco tree and test to 5000 psi.Freeze protect IA w/120 bbls of diesel.R/U Halliburton slickline. Operation at 07.00 Pulling Sheared GLM Valve,Rigging Down,Cleaning Pit. 24h Forecast Rig released f/S107 @ 2400 hrs. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 07:00 7.00 7.00 COMP K 4 P PJSA M/U and RIH w/4.5"12.66 L80 H563 completion as per tally f/845'-5991',130k puw,105k sow. 07:00 10:30 3.50 10.50 COMP K 4 P PJSA Sting into liner hanger to NO-Go and shear pins.Pull up and space out tubing.M/U hanger and landing jt.and land Vetco tubing hanger.RILDS and test Hanger seals to 5000 psi f/10 min.6068'TOL,Bim of WLEG @ 6088'.20'sting in Liner top. 10:30 12:00 1.50 12.00 COMP K 20 P PJSA R/U to set and test Baker packer.20 bbls Toudy Fluid losses. 12:00 14:30 2.50 14.50 COMP K 12 P PJSA f/setting and testing Baker packer w/all personnel.Pressure up tubing to 1200 psi to close Autofill.Pressure up to 3000 psi to set packer.Observed shear @ 1800 psi.Hold 3000 psi f/30 min for Tubing Integrity Test.Bleed tubing pressure to 2000 psi and pressure IA to 2500 psi,chart f/30 min for IA Integrity Test.Bleed IA to 0 psi.Pressure up tubing to 4500 psi and shear Mirage plug.Pressure up IA to 2300 psi and sheared GLM valve. 14:30 15:30 1.00 15.50'COMP K 20 P PJSA Blow down and R/D testing equipment,UD landing jt and Vetco set BPV. 15:30 16:30 1.00 16.50 COMP K 20 P PJSA Clear casing tools f/ng floor. 16:30 18:30 2.00 18.50'COMP C 20 P PJSA N/D BOPE. 18:30 20:30 2.00 20.50 COMP C 12 P PJSA Install Vetco tree and test void to 5000 psi f/10 min. 20:30 21:00 0.50 21.00 COMP C 20 P PJSA Vetco pull BPV and install TWC. 21:00 22:30 1.50 22.50•COMP C 12 P PJSA R/U and test tree to 500 psi f/5 min and 5000 psi f/15 min.R/D f/testing. 22:30 00:00 1.50 24.00 COMP C 9 P PJSA w/Lil Red and freeze protect IA w/120 bls of diesel/1.4 BPM @ 1000 psi.Sim Ops;R/U Halliburton slickline equipment. Daily Contacts Position Contact Name Company ' Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Greg Parker ENI Malls Coordinator ' 907-980-7545 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Pete Martinusen Doyon Dolling Tour Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondnlling.corn 907-685-0716 Eni representative Paul Holley ENI 'HSE Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 1.36 4,916.42 6/11/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,902.26 1,240.00 FazePro OEM 1126.4 53.6 1558.4 193.2 111 4 0 m^4 4 w O, _v._ O O 6 4 m ^^W^U) !!H! d N 0 A O tO !! !4 w!i:0 m m U1 O U)N O U)O.-OO O O0 0 0 0 0 0 0 0 0 0 O O O O O 0 0 0 0 0 0 0,6,,, ,rrr, rrrrr rr,rr r r0^' 0 M, ^r a m^ O m.-w 0, w w N.-w O O 9 O M N N m N M A m N M m W 4 N N r O WN 0 O W O^ a O O W, a MOO 6 M O O r O W4 m NW O W W, d O C V<V V< a v v a a 0*a a a VV... 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T.Simson CASING RECORD- TD 6246.00 Shoe Depth: 6240.94 PBTD: Casing(Or Liner)Detail Setting Depths No.ofJts. Size Wt. Grade THD Make Length Bottom Top Shoe 9-5/8 Hydril 563 Davis-Lynch 501_ 2.75 6,240.94 6,238.19 2 9-5/8 40 L-80 Hydril 563 Tenaris 80.83 6,238.19 6,157.36 Float Collar 9-5/8 Hydril 563 Davis-Lynch 700 2.82 6,157.36 6,154.54 153 9-5/8 40 L-80 Hydril 563 Tenaris 6,121.54 6,154.54 33.00 Totals 6,207.94 6,240.94 33.00 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'above shoe,10'above FC,1 each joint up to 5,094'MD CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10.5 Volume pumped(BBLS) 100 Lead Slurry Type: N/A Yield(Ft3/sack): Density(ppg) Volume (BBLS/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: 12.5 LiteCRETE Yield(Ft3/sack): 1.56 Density(ppg) 12.5 Volume (BBLS/sacks): 135/486 Mixing/Pumping Rate(bpm): 5.3 average N Post Flush(Spacer) N Type: H2O Density(ppg) 8.4 Rate(bpm): 5 Volume: 10 Displacement: Type: LSND Density(ppg) 9.3 Rate(bpm): 6 Volume(actual/calculated): 454/456 FCP(psi): 430 Pump used for disp: Rig pumps Plug Bumped? x Yes No Bump press 930 Casing Rotated? Yes x No Reciprocated'? Yes x No %Returns during job 100 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: N/A Cement In Place At: 13:55 Date: 5/29/2015 Estimated TOC: 4,720 Method Used To Determine TOC: Calculated Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLS) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry wType: Yield(Ft3/sack): a Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): co Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: wDisplacement: Type: Density(ppg) Rate(bpm): variable Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes _No Reciprocated? Yes No %Returns during job Cement returns to surface? Yes _No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Remarks: • • XYZ Oil company CASING&CEMENTING REPORT Lease&Well No. ENI-SID SI07-SE4 Date 22-May-15 County GPB State Alaska Supv. R John Chant CASING RECORD- St-t..^C ,2}�h1 TD 3050.00 Shoe Depth: 3035.38 PBTD: cr� Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length _ Bottom Top Shoe 13-3/8 BTC WTF 2.50 3,035.38 3,032.88 2 13-3/8 68 L-80 BTC Tenaris 77.28 3,032.88 2,955.60 Float Collar 13-3/8 BTC WTF 1.50 2,955.60 2,954.10 74 13-3/8 68 L-80 BTC Tenaris 2,913.73 2,954.10 40.37 P1&Hanger 13-3/8 68 L-80 BTC Tenaris 3.42 40.37 36.95 Totals 2,998.43 3,035.38 36.95 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 2524'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): 449/910 Mixing/Pumping Rate(bpm): 5.8 Tail Slurry Type: 12.5 LiteCRETE Yield(Ft3/sack): 1.58 Density(ppg) 12.5 Volume (BBLs/sacks): 81/289 Mixing/Pumping Rate(bpm): 3.7 y Post Flush(Spacer) N Type: H2O Density(ppg) 8.4 Rate(bpm): 5 Volume: 10 o! E Displacement: Type: Spud Mud Density(ppg) 9.3 Rate(bpm): 4.5 Volume(actual/calculated): 437/443 FCP(psi): 400 Pump used for disp: Rig pumps Plug Bumped? x Yes No Bump press 930 Casing Rotated? Yes x No Reciprocated? Yes x No %Returns during job 100 Cement returns to surface? x Yes No Spacer returns? x Yes No Vol to Surf: 130 cmt/100 MP Cement In Place At: 14:18 Date: 5/22/2015 Estimated TOC: Surface Method Used To Determine TOC: Visual returns at surface Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: Yield(Ft3/sack): w a Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): N Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: icA Displacement: Type: Density(ppg) Rate(bpm): variable Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes _No Reciprocated? Yes_No %Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Remarks: III I IIIII711i1�III I IIII IIPRO 80659103SHIDDA VER . 'RECEIPT5 15 1800 E. 1st Avenue •Anchorage,AK 99501 ORIGIN: PRU TERM, AK DEST: ANC TERM, AK /1;;;14 Phone(907)276-7797• Fax(907)278-7301 907-659-2398 907-276-7797 CARLILE TRANSPORTATION SYSTEMS, INC. FOR CUSTOMER SERVICE, CALL 888-399-3290 OR VISIT www.carl i le.bi z SP • IAL INSTRUCTIONS: APPT DATE: TIME: e ENI PETROLEUM s ENI PETROLEUM o AOGCC 3800 CENTERPOINT DR H NOC WAREHOUSE OLIKTOK DOCK N 333 WEST 7TH AVE S300 P RD ANCHORAGE AK 99501 N G MEREDITH GUHL ANCHORAGE AK 99503 E 12 ACRE PAD N G 907-865-3300 R PRUDHOE BAY AK 99734 E 907-793-1235 907-670-8613 PCS UNIT HIM DESCRIPTION OF ARTICLES AND SPECIAL MARKS WEIGHT(LBS) RATE CHARGES 1 PLT WASH DRIED SAMPLES 30 161N X 111N X 11IN CUBE: 1FT3 **HIGH CLAIMS RISK, HANDLE WITH CARE** 1 30 Page 1 of 1 ALL hHEIGH I DESCRIBED ABOVE RECEIVED IN GOOD CONDII TON WITH SHRINK WRAP/BANDING IN TAG I EXCEL,rAS NOTED. ADDITIONAL SERVICES PERFORMED- SIGNATURE: DATE: /_�� !C� ADDITIONAL CHARGES MAY APPLY (P--- i J RES LTD ACCESS PRINTED NAME: TIME: j J LIFTGATE INSIDE PIECES DELIVERED: I INITIALS: DRIVER1I A/��_ .ti APPOINTMENT X EXCEPTIONS: fir OTHER: • • ,?64-'1oc). / 5-No fol HALLIBURTON 2nii EnO PtiroIIetuiirini Sperry Drilling PACKING LIST Spy Island Drillsite Nikaitchuq S107-SE4 Shipping Date: 6-Jun-2015 Spy Island,Alaska Ship From: Ship To: ENI Petroleum AOGCC C/O Sperry Drilling Alaska 333 West 7th Avenue; Suite 100 6900 Arctic Blvd. Anchorage,AK 99501 Anchorage,AK 99515 Attn: Meredith Guhl 907-793-1235 Item Descriptir Interval Packaging Box Description 11 S107-SE4 Washed and Dried Samples-50' 3050'-6246' Paper envelopes 1 of 5 Washed and Dried Samples-50' 6300'-9200' Paper envelopes 2 of 5 Washed and Dried Samples-50' 9250'-12000' Paper envelopes 3 of 5 Washed and Dried Samples-50' 12050'-14550' Paper envelopes 4 of 5 Washed and Dried Samples-50' 14600'-16130' Paper envelopes 5 of 5 NIOS .\-C3 Bundles vv 1.%(6.03 +.�e Contains G, Bundle 1-Five(5)Boxes Notes: Total Packages this Shipment: Please notify sender upon receipt of delivery; Josh Zuber 907-223-6659 9 .—j Received byExpediter: < Date: / Z�1 1 5— P I s • HALLIBURTON ell II II Enil PtiroIIeuiririi Sperry Drilling PACKING LIST Spy Island Drillsite Nikaitchuq SI07-SE4 Shipping Date: 6-Jun-2015 Spy Island,Alaska Ship From: Ship To: ENI Petroleum AOGCC C/O Sperry Drilling Alaska 333 West 7th Avenue; Suite 100 6900 Arctic Blvd. Anchorage,AK 99501 Anchorage,AK 99515 Attn: Meredith Guhl 907-793-1235 Item Description AIM Interval Packaging Box Description 5107-SE4 Washed and Dried Samples-50' 3050'-6246' Paper envelopes 1 of 5 Washed and Dried Samples-50' 6300'-9200' Paper envelopes 2 of 5 Washed and Dried Samples-50' 9250'-12000' Paper envelopes 3 of 5 Washed and Dried Samples-50' 12050'-14550' Paper envelopes 4 of 5 Washed and Dried Samples-50' 14600'-16130' Paper envelopes 5 of 5 One(1)Bundles Contains Bundle 1-Five(5)Boxes Notes: Total Packages this Shipment: Please notify sender upon receipt of delivery; Josh Zuber 907-223-6659 Received by Expediter: Date: • 214100 26 035 HALLIBURTON Drilling RECEIVED Sperry JUL 15 2015 DATA LOGGED To: Alaska Oil and Gas Conversation Commission AOGCC M.K.BENDER 333 W 7th Ave Suite 100 Anchorage, AK 99501 Attn: Meredith Guhl From: Sperry Drilling - Alaska Attn: Robert Haverfield 6900 Arctic Blvd. Anchorage, AK 99518 907-273-3559 Office 907-273-3535 Fax Robert.Haverfield@Halliburton.com Re: Eni Petroleum Well — SI07-SE4 AFE # 6934 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 4_ , ign Name Date Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. REVIVED • 2 0 / 1 a 259u5 Schlumberger JUN 18 , z0 Transmittal#: 18JUN15-SP01 Drilling& Measurements DATA LOGGED 5 '' MWD/LWD LogProduct Deliver (b/ZBE2DD5 y M.K.BENDER Customer: ENI Operating Co. Inc.Alaska Dispatched To: Makana Bender Well No: S107-SE4 Date Dispatched: 18-Jun-15 Job#: 15AKA0089 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"ND x x VISION*Resistivity 5"MD x x VISION*Resistivity 5"TVD x x VISION*Resistivity 5"MD IMAGE x _ x Digital DataN/A Contents on CD N/A -ASCII//DLIS x Survey 1 Contents on CD ASP Final Survey x x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:PDF x Survey:PDF/xls x Please sign and email a copy to: Please sign and email a copy to: joshua.zuber(a�enipetroleum.com AlaskaPTSPrintCenter(a�sib.com Attention:Joshua ZuberAttention:Stephanie Pacillo Received By: p-)ittga.4-uk.4) I5..e0,..c O I III O LD v' p eNdmor 4m oma ,,am N4' ° 01 _"to I Or rimngl ECM o m m m o m ;coin `m"m o i N � J N tp tD n (u s— Ln rrr�o n000o oo^rr r rrrr rrrrr ooO^r rrrrr r a C .J N rd� !!fl! HHE !! !! IIIIE V V;0 ! d m d O ..... htOMtOtO ..... ..... 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Qvs,.. oKWW U)OCCOOCOm' O, E' 'ECI ❑o y Y 0 % Su,W C '3272A88 2',,A88 0(00 r V 8714 g gW Oa2WDHH02WiT zoo NNN N N NNN N N NNN N N NNN N N NNN N N N N IL a W W 0 —...v, H K w f '22,724 W zz 26-,6;;;', y N d d wQ >yda to N0 m (WN ) 0 nJJ z YsNMN1 N2223 Gmin.eN AN.2rr m�NOm nes 0 o,NLL GW2N NWWNW 2NWWW WNMgY, 22m i JMr LL J J 3 V22 LL N O n n W - y C0°'4 o 2E138" ^MOW m O^0NImon W N4 N -;. ,74,%W 00NN Odd 2 0NE O -112-43' Kao <r288 2414r23 02042 Qr206OOo MMMO 4 4444 ddddd 2.-4N3 NNhN8 Nmm O(p 0 N a r- S L. 9 op N E 0 tO O E T T c E _ ci 00 411 • 2��4�1�0�0 REC � l SchiumbergerN 1 8 2013 Transmittal#: 18JUN15-SPO2 Drilling & Measurements DATA LOGGED �� MWD/LWD LogProduct Delivery �.K BENDER f JIE 1A *1 M.K. Customer: ENI Operating Co. Inc.Alaska Dispatched To: Makana Bender Well No: S107-SE4T.O.C. Date Dispatched: 18-Jun-15 Job#: 15AKA0089 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Product 1 Contents on CD N/A SonicVISION Top of Cement x x Digital Data N/A Contents on CD N/A ASCII/DLIS x Survey N/A Contents on CD CD 1 Contents on CD Data:DLIS/ASCII x Graphics:PDF x Please sign and email a copy to: Please sign and email a copy to: joshua.zuber(a�enipetroleum.com AlaskaPTSPrintCenter(a�slb.com Attention:Joshua Zuber Attention:Stephanie Pacillo Received By: iatida.-0,61/4„. Ai / , 4/ 214100 RECMVEI SehiumbergerUN 1 8 2015 Transmittal#: 18JUN15-SP03 Drilling & Measurements DATA LOGGED AOGC MWD/LWD Log Product Delivery G/19/2o15��..JJ��.J71I [ M.K.BENDER Customer: ENI Operating Co. Inc.Alaska Dispatched To: Makana Bender Well No: S107-SE4 BestDT Date Dispatched: 18-Jun-15 Job#: 15AKA0089 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Product 1 Contents on CD N/A SonicVISION BestDT x x 6110'-16030' MD Digital Data N/A Contents on CD N/A ASCII/DLIS x Survey N/A Contents on CD CD 1 Contents on CD Data:DLIS/ASCII x Graphics:PDF x Please sign and email a copy to: Please sign and email a copy to: ioshua.zuber(cr�enipetroleum.com AlaskaPTSPrintCenter@slb.com Attention:Joshua Zuber Attention:Stephanie Pacillo Received By: / ,,ai %a yrok, / ' 4/ • • Bettis, Patricia K (DOA) any-/00 From: Bettis, Patricia K (DOA) Sent: Thursday, May 07, 2015 3:05 PM To: 'Chaudhry Amjad' Cc: Schwartz, Guy L (DOA) Subject: RE: SI07-SE4 (P5) plan survey.xlsx Good afternoon Amjad, This minor revision in well depth will not trigger a revision of the approved 401. Thank you, Patricia From:Schwartz, Guy L(DOA) Sent:Thursday, May 07, 2015 2:30 PM To: Bettis, Patricia K(DOA) Subject: FW: S107-SE4 (P5) plan survey.xlsx Importance: High FYI.. Need to see if this triggers a revision on the approved 401 Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Chaudhry Amjad [mailto:Amjad.Chaudhry@@enipetroleum.com] Sent: Thursday, May 07, 2015 2:19 PM To: Schwartz, Guy L (DOA) Subject: FW: SI07-SE4 (P5) plan survey.xlsx Importance: High Hello Guy, As per our discussion this morning, please find new proposed well plan ( S107-SE4(P5)for your review, thanks Best regards 1 • • Amjad Chaudhry Sr. Drilling Engineer • eni us operating co. inc. 3800 Centerpoint Dr.Anchorage, AK W: 907-865-3379 D W: 907-346-0591 M Email: amjad.chaudhry(aenipetroleum.com operatingus This document and any files or e-mail messages attached to it contain data or information that is confidential,privileged or otherwise restricted from disclosure. Ifyou are not the intended recipient, be aware that any disclosure, copying, distribution or use of any of the data or information contained herein or in any of the attachments is strictly prohibited. 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Q m m m m m m m m T 0 0 ��pp pp pp pp O G 0 pp pp pp ppoaaa S w w O w a o O o. ..N .. .O O N S r w r a$A8 O0 N0 '..q ul • pTppC�SSOC ••66T(mp . 8 8880 8 (.lam.68(stn`88 .8Ve8gOQ<V Q<pOOOlIO�NN ��N NNwtNO tDm _ IC O = 2; o t S 0 W 6 g Z m O w0 v Z LSU �°r p >> 2 g s U s 0v ` C U r W F- 00 0 � 2 d C UI-W v Z Mp_.W UF-W W 0 IIIMIMISTIVIZOINNEI OF rkt, • • ��,.\ ,%sA THE STATE Alaska it air Gas �-„ , ,A of T � 7 C tret; _,_�,_ 333 West Seventh Avenue 04 � -, GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 ' Main: 907 279 1433 ®v. ALAS S fax: 907.276.7542 James Wright Drilling& Completion Engineering Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, S107-SE4 ENI US Operating Co. Inc. Permit No: 214-100 Surface Location: 4479' FSL, 1226' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 405' FSL, 2264' FEL, SEC. 21, T14N, R9E, UM Dear Mr. Wright: Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, / ;.6( L __ Cathy P Foerster Chair DATED this of July, 2014. V RECEIVED STATE OF ALASKA JUL 0 9 2014 AL KA OIL AND GAS CONSERVATION COMM' SION PERMIT TO DRILL j'��r��('� 20 AAC 25.005 AVti, C la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj 0, Single Zone ❑✓ , 1c.Specify if well is proposed for: Drill [.], Lateral ❑ Stratigraphic Test L Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril ❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑✓ , Single Well ❑ 11.Well Name and Number: ENI US Operating Co. Inc. Bond No. RLB0008627 , S107-SE4 3.Address: 6. Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 16129 " TVD: 4056 - Nikaitchuq/Schrader Bluff 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Surface: 4479 FSL, 1226 FEL,S19 T14N R9E UM ADL0391283,ADL0388583,ADL0388582 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1018 FSL,5129 FEL,S17 T14N R9E UM ADL 417493 8/10/2014 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 405 FSL,2264 FEL,S21 T14N R9E UM 6954• 2464'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 1o.KB Elevation above MSL: 54.1 feet ' 15.Distance to Nearest Well Open Surface:x- 511684 y- 6053660 Zone- 4 ' GL Elevation above MSL: 13.1 feet to Same Pool: 1100'to SP12-SE3 L1 16. Deviated wells: Kickoff depth: 200 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92.00 degrees ' Downhole: 1787 psig . Surface: 1350 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 3142 35 35 3177 2454 Surface Lead:570.7 bbls 12.5ppg DeepCrete 62.5 bbls 12.25" 9-5/8" 40 L-80 Hydril 563 6025 33 33 6058 4025 12.5 ppg DeepCRETE 155.5 bbls 8-3/4" 4-1/2" 11.6 L-80 Hydril 521 10271 5858 3970 16129 4056 Liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) ,j 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 Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 7/8/2014 22. I hereby certify that the foregoing is true and correct. Contact Andrea Lazzari 907 230 7511 Email andrea.lazzarudenipetroleum.corn Printed Name James Wright Title Drilling&Completion Engineering Manager Signature4- Phone (907)865-3321 Date 7/8/2014 Commission Use Only Permit to Drill API Number: Permit Approval1 See cover letter for other Number: (I I - !to 50-(0251, -02., 5-1�(-00-00 Date: a1 rt( 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: E Other: i: 5Cy) 15i �3C P r/ S f Samples req'd: Yes ❑ No© Mud log req'd: Yes ❑ No H2S measures: Yes ❑ No[ Directional svy req'd: Yes ❑ No ❑ X_ /111 T- CE L r e- 7-,--4,--t.)` Spacing exception req'd: Yes ❑ No Inclination-only svy req'd:Yes❑ Noer , t(( 1,, . C ' c---,_ ,..-, Ai 0 36 APPROVED BY Approved b . i) ' COMMISSIONER THE COMMISSION Date: 7--2_/ S. 7--/ 43'" iLt. /)/41. ‘7T-1°P" 5(g) V R G INr Submit Form and Form 10-401(Revised 10/2012) This r v li r frnthe date of approval(20 AAC 25.0 Attachments in Duplicate • RECEIVED JUL 0 9 2014 AOGCC • CIM PtiroIIeuim 2nll 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 James Wright Phone(907)865-3321 Email: James.Wright@enipetroleum.com July 8,2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Injector SI07-SE4 Dear Commissioners, Eni US Operating Co.)Enc.hereby applies for a Permit to Drill for the Offshore Injector well SI07-SE4. This well will be drilll and completed using Doyon 15. The planned spud date could be as early as 08/10/2014. J 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, if,:d-r-a7,21.40 ("A/ James Wright Drilling&Completion Engineering Manager • • rogitt. • Enil PetiroOeuim enn Application for Permit to Drill SI07-SE4 Saved:8-Jul-14 Application for Permit to Drill Document Injector Well SI07-SE4 Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(f) 3 2. Location Summary 3 Requirements of 20 MC 25005(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 AAC 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 AOGCC PERMIT Document Page 1 of 10 Printed:8-Jul-14 ire • • • Eno PetiroOeum eau Application for Permit to Drill SI07-SE4 Saved:8-Jul-14 10. Seabed Condition Analysis 7 Requirements of 20 AAC 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 9 Requirements of 20 MC 25.005(c)(14) 9 14. Area of Review 9 15. Attachments 10 Attachment 1 Drilling Procedure 10 Attachment 2 Directional Plan 10 Attachment 3 Drilling Hazards Summary 10 Attachment 4 BOP and Diverter Configuration 10 Attachment 5 Cement Loads and CemCADE Summary 10 Attachment 6 Formation Integrity And Leak Off Test Procedure 10 Attachment 7 Surface Platt 10 Attachment 8 % Mile Scan Report 10 Attachment 9 Casing Design Program 10 AOGCC PERMIT Document Page 2 of 10 Printed:8-Jul-14 • 019* Enil PtiroIIum e nn n Application for Permit to Drill SI07-SE4 Saved:8-Jul-14 1. Well Name Requirements of 20 MC 25.005(f) 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(b). For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: SI07-SE4 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 objective formation and at total depth; Location at Surface 4479 FSL, 1226 FEL, S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates ) RKB Elevation 54.1'feet'AMSL Northing: 6,053,660' Easting:511,684' 7, Pad Elevation 13.1'feet'AMSL Location at Top of Productive Interval 1018 FSL, 5129 FEL, S17 T14N R9E UM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 6,058' Northing: 6,055,480' Easting: 513,051' Total Vertical Depth, RKB: 4,025' Total Vertical Depth, SS: 3,971' Location at Total Depth 405 FSL, 2264 FEL, S21 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 16,128' Northing: 6,049,607' Easting: 521,226' Total Vertical Depth, RKB: 4,056' Total Vertical Depth, SS: 4,001' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(b); Requirements of 20 MC 25.050(6) It 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 AOGCC PERMIT Document Page 3 of 10 Printed.'8-Jul-14 • • Enli 05* • f enll Application for Permit to Drill SI07-SE4 Saved:8-Jul-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 (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 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 oradient; The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the planned vertical depth of the OA sand formation is: MPSP = (3,971'TVDss)(0.45 - 0.11 psi/ft) = 1350 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 differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 MC 25.0300; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document Page 4 of 10 Printed:8-Jul-14 1101 • Enfl P 2nn Application for Permit to Drill SI07-SE4 Saved:8-Jul-14 6. Casing and Cementing Program Requirements of 20 MC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted finer,pre- perforated finer, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 Driven 178.89 X-65 Welded 120 36 / 36 160'/ 160' Pre-Installed 13-3/8 16 68 L-80 BTC 3142' 35 / 35 3177'/ 2454' Surface Lead: 570.7 bbls 12.5ppg DeepCrete 62.5 bbls 9-5/8 12-1/4 40 L-80 Hydril 563 6025' 33 / 33 6058'/ 4020' 12.5 ppg DeepCRETE 155.5 bbls 8-3/4"OA 4-1/2 Sand 11.6 L-80 Hydril 521 10271' 5858'/ 3970' 16129'/ 4056' Liner in Open Hole-no cement Lateral 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 4: BOP Configuration. AOGCC PERMIT Document Page 5 of 10 Printed:8-Jul-14 i S • Enil PtiroIIuim 2no Application for Permit to Drill SI07-SE4 Saved:8-Jul-14 Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 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 st) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (LSND) (MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 8.7 - 9.4 Density(ppg) 8.8 - 9.5 Plastic Viscostiy 15 - 25 Funnel Viscosity (CP) 45 - 60 (seconds) Yield Point 15 - 20 Plastic Viscostiy 12 18 (lb/100 sf) (CP) HTHP Fluid loss Yield Point (ml/30 min <5.0 18-24 (lb/100 sf) 200psi& 100°F _ API Filtrate Oil/ Water (cc/30 min)) 4 6 Ratio 60/ 40 Chlorides(mg/0 <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 25005(c)(9) 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: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 MC 25.0330; Not applicable: Application is not for an exploratory or stratigraphic test well. AOGCC PERMIT Document Page 6 of 10 Printed:8-Jul-14 • iff* JL • Ell Petirolleum Application for Permit to Drill SI07-SE4 Saved:8-Jul-14 9. Seismic Analysis Requirements of 20 AAC 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)for an exploratory or stratigraphic test well a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 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 offshore platform,mobile bottom-founded structure,jack-up rig,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 AAC 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 showing that the requirements of 20AAC 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. FJrrr 2) RU Diverter and test as per AOGCC requirements ,/ 3) Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4) Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 5) Install and test wellhead to 5000 PSI. 6) Nipple up 13-5/8" 5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 7) Pressure test casing to 2500 psi per AOGCC regulations. Record results. 8) PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. 9) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. • Min LOT: 11.00 ppg 10) Directionally drill to 9-5/8" casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 11) Install 9-5/8"casing rams in the BOP and test to 3500 PSI. AOGCC PERMIT Document Page 7 of 10 Printed:8-Jul-14 • WI* • Enil P conn Application for Permit to Drill SI07-5E4 Saved:8-Jul-14 12) RU casing drive system. 13) Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 14) Install 9-5/8" Emergency Slips. 15) Install 9-5/8" packoff and test to 5000 psi. 16) Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 17) Pressure test casing to 3000 psi per AOGCC regulations. Record results. 18) PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. (Jet_ /i 17 19) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. • Min LOT: 12.00 ppg 20) Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 21) PU dumb iron assembly and TIH to TD 22) Displace well to 9.5 ppg FazeAway Delayed Breaker 23) POOH on elevators to intermediate casing shoe and displace to 9.0 ppg KCI brine. 24) POOH on elevators and LD BHA. RU to run 4-1/2" liner. 25) PU and run 4-1/2" liner to TD. Ensure cross over and FOSV is on the floor. 26) Land liner, set liner hanger with 200' Liner lap inside the 9-5/8" intermediate casing. 27) Bleed DP pressure to zero, close annular and test annulus to 1500 psi for 10 min on chart. 28) POOH laying down DP as required. 29) RU tubing running equipment and run 4-1/2"tubing. Land tubing. 30) Test upper and lower seals to 5000 psi for 10 min. 31) RU to set PHL Injection Packer. Test surface lines to 5000 psi and bleed to zero. 32) Pressure down tubing string to 1200 psi to close autofill valve and monitor for leaks. 33) Increase pressure down tubing to 3,500 psi to set packer and hold for 30 minutes. Record on chart as tubing integrity test. Ensure inner annulus is open and monitor for returns. 34) Reduce tubing pressure to 2,000 psi. Rig up and pressure inner annulus to 2,500 and hold for 30 \.<‘-, minutes. Record annulus pressure on chart as inner annulus integrity test. Bleed annulus pressure to zero. 35) Increase pressure down tubing to 4,400 psi to shear open Mirage Plug. Reduce tubing pressure to zero. 36) Pressure inner annulus to 2,500 to shear valve in GLM. If valve does not open, cycle annular pressure from 0 to 2,500 psi several times while allowing tubing to bleed pressure. 37) Pull landing joint and set BPV. AOGCC PERMIT Document Page 8 of 10 Printed:8-Jul-14 • • 111* Enil PtIroIIeLulm Application for Permit to Drill SI07-SE4 Saved:8-Jul-14 38) Nipple down BOP, nipple up tree and test void to 5000 psi for 10 min. • ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). (1). • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. 39) Pull BPV and set TWCV. 40) Fill tree with diesel and function valves. Test and chart tree to 500 psi for 5 min. Test and chart tree to 5000 psi for 15 min. 41) Pull TWCV. 42) Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 43) Set BPV and secure tree and wellhead. _ 44) RDMO �1 1<�2Q-.-+-.(� l l � � , � - —`"cj 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items,except for an item 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. 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: Nikaitchuq #3: Plugged and Abandoned 04/01/04 (East of Nikaitchuq Unit) 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 AOGCC PERMIT Document Page 9 of 10 Printed:8-Jul-14 • • P19* • 2n11 =mill PtiroIIuim Application for Permit to Drill SI07-SE4 Saved:8-Jul-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 AOGCC PERMIT Document Page 10 of 10 Printed:8-Jul-14 vos, • • ens us operating WELL SI07-SE4 Drilling Procedure SI07-SE4 Spy Island Conductor slot #7 Reservoir location #SE4 Injector (Schrader Bluff) Nikaitchuq Project SI07-SE4 Drilling Wellplan Page 1 of 40 07/08/14 4 • • 2rn1ll us operrah nns WELL S107-SE4 11* Spy Island Nikaitchuq Field c h p rokum North Slope - Alaska SI07-5E4 DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD NF MD TVD SIZE SPECS IO Cerrent to Surface 20" Hole Angle 2X-65 0' 20"Conductor Shoe 160' 160' Driven Welded N/A 0 GR/ResSurface Cog Dir/PWD a o 0 13-3/8" > 68#68# MW(ppg) Wellbore Stability Mud Motor B/Permafrost 2,000' 1,747' r L-80,BTC 8.8-9.5 Lost Circulation —0 Hole Cleaning Casing Sections KOP:200' lf. Casing Wear DLS: Surface/Tail Cement 3' .�..rr 0-4. 5/100' Jn b F C N Hole Angle1v S. 56.00 Deg 13 3/8" 3,177' 2,454' 16" 50°F W BM GR/RES/PWD Inter.Casing Weltore Stability 9-5/8" Lost Circulation Xceed 900 40# MW(p89) Hole Cleaning L-80,Hydril 563 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: Casing Wear 65.00 Deg BHA Expense Intermediate TOC 4,272' 3,171' Pick-up Top of Sand u N Top 5,272' 3,768' o Hole Angle TOL 5,858' 3,970' .I Cr 84.00 Deg 9 5/8" 6,058' 4,020' _l, ., 12.25" 85°F WBM GR/RES p � EcoSCOPE/PWD 1� El Wellbore Stability K ICD Lines Hole Cleaning �p p� 4-1/2" Torque&Drag ID SI 11.6# MW(ppg) Casing Sections Xceed 675 m L-80,Hydril 521 8 7-9.4 Casing Wear ICD BHA Expense °1 rkE SI � p ICD ID g Hole Angle 91.00 Deg TD 16,129' 4,056' 8-3/4" 85°F MOBM SI07-SE4 Drilling Wellplan Page 2 of 40 07/08/14 ViIrk • (eno us operraLt ng WELL SI07-SE4 Table of Contents WELL PLAN SUMMARY 4 MIRU SECTION 6 SURFACE SECTION 7 Surface Drilling 8 Surface Casing 11 Surface Cementing 14 Pick Up Intermediate Drilling Assembly 16 INTERMEDIATE SECTION 17 Intermediate Drilling 19 Intermediate Casing 20 Intermediate Cementing 23 Pick Up Production Drilling Assembly 25 PRODUCTION SECTION 26 Production Drilling 28 Production Liner 29 ATTACHMENTS 33 Recommended Drilling Practices 34 Health, Safety & Environment 35 Safety Meeting Topics 36 Well Shut In Procedure While Running Production Tubing 38 Conductor Broach—Contingency Cementing Plan 39 TAM PORT COLLAR Utilization Decision Tree 40 SI07-SE4 Drilling Wellplan Page 3 of 40 07/08/14 101#1 • • 2n11 us operating WELL SI07-SE4 WELL PLAN SUMMARY Rig: Doyon 15 Type of Well: Injector Well Design: 13-3/8"Surface x 9-5/8"Intermediate x 4-1/2"Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survey Program & Procedures Take MWD surveys as frequently as needed,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-go lines. If a no-go or hard line has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. SI07-SE4 Drilling Wellplan Page 4 of 40 07/08/14 • 2nn us operahng WELL S107-SE4 OBJECTIVES: 1. Drill the well at or under AFE cost and time. Perform work in a safe and professional manner meeting all ENI Petroleum Health, Safety, and Environmental requirements. 2. Land Intermediate casing point within 100' radius of the planned directional target. 3. Land the Intermediate hole section with the targeted inclination of 85° -87° above the OA sand. Maximum dogleg severity in the landing shall be no greater than 3.5°/100' DLS. 4. Target Greater than 90% within the OA sand Reservoir. 5. 8-3/4" hole LWD Failure Requirements: GR/Res/Dir/PWD— Require GR/Res/Dir to achieve TD. SI07-SE4 Drilling Wellplan Page 5 of 40 07/08/14 filit • eno us operating WELL SI07-SE4 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (ppt) 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). SI07-SE4 Drilling Wellplan Page 6 of 40 07/08/14 tc* • • ( rnn n us operating WELL SI07-SE4 SURFACE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (3) True Formation Tops Measured Vertical Comments Depth, ft Depth, ft SV-4 763 755 SV-3 1184 1135 SV-2 1542 1415 B /Permafrost 2000 1747 SV-1 2462 2061 Ugnu Top(UG4) 2985 2351 13-3/8" Csg 3177 2454 UG-2 Coal Bed Marker 3667 2757 Lower Ugnu 4632 3411 Schrader Bluff Top 5100 3684 N Sequence Top 5183 3726 N Top 5272 3768 ReCalc Intermediate Cement w/Actual N Bottom 5481 3858 N Sequence Base 5706 3948 9-5/8" Csg 6058 4025 ICP- Set ABOVE OA Sand Top OA Top 6127 4031 4 1/2" liner 16129 4056 Total Depth SI07-SE4 Drilling Wellplan Page 7 of 40 07/08/14 wok ill • env us operrafi nng WELL SI07-SE4 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 Reading Loss (mgn) 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) (ft lbs) (ft.lbs) (gal/ft) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 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 SI07-SE4 Drilling Wellplan Page 8 of 40 07/08/14 fiiik • • erm us operating rr in g WELL SI07-SE4 Surface Hole Procedure: 1. Pick up and drift all DP,HWDP,and DC's for surface section to confirm free of debris. 2. PU BHA(Include UBHO for Single shot E-line Gyro if MWD surveys are not clean initially)for directionally drilling to Surface Casing point with one BHA 3. Directionally drill surface hole: ➢ Drilling Parameters: • 650-800 GPM • Lower flow rates of 450-600 GPM will help avoid anti-collision boundaries by minimizing hole washout and optimize dog leg capability in the build section • RPM: 40-80 RPM ➢ Avoid anti-collision boundaries ➢ Take MWD surveys as frequently as needed. Carefully review the anticipated close crossings with existing wellbores. Make sure that directional drillers are aware of all drilling close crossing issues,hardlines and no-go lines. If a no-go or hardline has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. 4. Hole conditions will always determine final mud properties. ➢ 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 2000' SSTVD and 2150' SSTVD ➢ 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. SI07-5E4 Drilling Wellplan Page 9 of 40 07/08/14 vos. • eni us operating WELL SI07-SE4 • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the HWDP. Do not attempt to pull out on elevators once backreaming has started. • Expect+/-100%increase in cuttings from 1800'-600'. • Lesson Learned from: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. SI07-SE4 Drilling Wellplan Page 10 of 40 07/08/14 • • eno SIS operating WELL SI07-SE4 Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (ppl) Type (in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Surface Casing Connection Make Up Torque (ft.lbs) Opt. OD WT Grade Conn.Type Make Up (in) (Ppb Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casing Running Notes a. Surface casing will be landed on hanger and emergency casing slips will be the contingency plan. b. Rig up and utilize a Fill Up tool for the casing job. c. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. d. Any packing off while running casing,and especially while above the base permafrost,should be treated as a very serious problem if major returns are lost. Run 4"lines from side outlets on conductor to a Vac Truck to help reduce pack off problems and minimize chance of spill. It is preferable to pull casing out until circulation can be re-established rather than risk not getting cement to surface. Contact the Drilling Superintendent if the casing packs off high for discussion of the options. e. Have Vetco representative verify the correct casing hanger is on location prior to the point at which it is needed. f. Torque values for the BTC casing are determined at the rig by making up the connection to the make-up mark (base of triangle). Record torque values for the first 10 connections made up in this manner and average. This average will be used as the make up torque for the remainder of the string. 1. Inspect and drift all surface casing to 12.259". 2. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. 3. While RIH with the the Casing: D obtain SO Weights every 10 joints ➢ obtain PU Weights every 10 joints 5107-SE4 Drilling Wellplan Page 11 of 40 07/08/14 • us operrat ng WELL SI07-SE4 4. Run the surface casing as follows: Surface Casing Running Order 1 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 +/- 18 13-3/8"Tandem Rise Weatherford SI07-SE4 Drilling Wellplan Page 12 of 40 07/08/14 It* • • en 11 us operating WELL SI07-SE4 Surface Centralizer Placement 10' Pr.". oa 13-3/8"x 16" Tandem Rise Centralizers Collar • 2 at 5'&8' above Float shoe on stop collars,using stop buttons or stop collars. • No centralization on collar of 13`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. SI07-SE4 Drilling Wellplan Page 13 of 40 07/08/14 flOs 4111 • 2fI us operefi nns WELL SIO7-SE4 Surface Cementing Program Section Casing Size Type of Fluid/ Cmt Volume Properties Mudpush 11 100 bbls Density10.1 ppg Lead Slurry Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) 570 bbls Yield 2.40 ft3/sk Tail Slurry (DeepCRETE) 6.1 bls Density 12.5 ppg Top of Tail @ 2,723'MD Yield 1.56 ft3/sk Surface Cementing Casing Cementing Notes a. Obtain and review the Test Report from the cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. b. Use split landing joint if TAM port collar is utilized and needs to be opened by running tool on drill pipe. 1. After reaching bottom, rig up and circulate with casing on bottom at 5 bpm, if possible, without losing returns. Reduce mud viscosity prior to pumping cement if necessary. ➢ To help ensure good cement to surface after running the casing, and if practical for existing hole conditions, condition mud to YP < 20 lb/100ft2 prior to cementing'the casing but after the casing is on bottom. Have adequate supply of cold lake water on hand to ensure the desired rheologies can be achieved. 2. Rig up to cement and pressure test cement lines. 3. Pump cement job per the attached Schlumberger cementing plan. Cement volumes are based on 35%excess below the Permafrost and 190%excess in the Permafrost. > If necessary,verify that the TAM Tech has located the proper crossovers to his combo running tool > If necessary,rack TAM running tool in derrick and ready to run > 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: D Task one person to be in charge of monitoring for cement returns and volume of cement returns ➢ Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement at 8.5 bpm maximum. 8. Drop circulation rate to 3 BPM for last 20 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. ➢ Do not over displace the cement(no more than Y2 the shoe joint volume). SI07-SE4 Drilling Wellplan Page 14 of 40 07/08/14 Vi#41S CCn11 SISS operating crratin WELL SI07-SE4 ➢ Watch for signs of packing-off during pumping operations and closely monitor the cellar area for mud or cement returns around the conductor. ■ The pack off problem has occurred on some offset wells when the hanger by-pass area was restricted. ➢ In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. ➢ AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indicated on the conductor markings. ➢ If there is any doubt about the proper orientation,call the Drilling Superintendent. ➢ Ensure that the seal between the casing hanger and well head is tested to 5,000 psi for 10 minutes. ➢ Measure the distance from the rig floor to the top flange of the well head and record on the IADC report and in WellView. Complete the Rig Elevation Record and place it in the electronic well folder. 12. Nipple up the 13-5/8" 5M BOP stack and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC 5107-SE4 Drilling Wellplan Page 15 of 40 07/08/14 wittiet • enll us operating WELL SI07-SE4 Pick Up Intermediate Drilling Assembly 1. Install wear bushing. Pick up: ➢ 12-1/4"bit • Rotary Steerable • PWD • GR/RES ➢ Flow rate of 900 GPM ➢ 120— 140 RPM ➢ See BHA attachment for running order and specifications 2. RIH to top of float equipment and pressure test surface casing to 2500 psi for 30 min and record on chart. ➢ Plot Casing Pressure Test on LOT form on N drive. Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. ➢ Note: All BHA trips thru the TAM port collar(if applicable)should be done slowly with slow rotation to avoid accidentally opening port collar. If set-down weight is noted,stop immediately,PU,resume slow rotation and try slacking off through port collar area. 3. Drill out the float collar&shoe. ➢ See Float Equipment and 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. SI07-SE4 Drilling Wellplan Page 16 of 40 07/08/14 sity* ( i us op rafinng WELL SI07-SE4 INTERMEDIATE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan s:<; True Formation Tops Measured Vertical Comments Depth, ft Depth, ft SV-4 763 755 SV-3 1184 1135 SV-2 1542 1415 B /Permafrost 2000 1747 SV-1 2462 2061 Ugnu Top(UG4) 2985 2351 13-3/8" Csg 3177 2454 UG-2 Coal Bed Marker 3667 2757 Lower Ugnu 4632 3411 Schrader Bluff Top 5100 3684 N Sequence Top 5183 3726 N Top 5272 3768 ReCalc Intermediate Cement w/Actual N Bottom 5481 3858 N Sequence Base 5706 3948 9-5/8" Csg 6058 4025 ICP- Set ABOVE OA Sand Top OA Top 6127 4031 4 1/2" liner 16129 4056 Total Depth SI07-SE4 Drilling Wellplan Page 17 of 40 07/08/14 /rot • • eni us operating WELL SI07-SE4 Intermediate Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the "N" sand Interval Density PV 6 RPM API FL pH Drill Solids MBT (ppg) Reading (ml/30min) _ (%) Intermediate: 9.2—9.4 12-18 12-18 <6.0 9-10 <6.0 <18 Intermediate Logging/Formation Evaluation Program: Intermediate: MWD—Directional/PWD(Pressure While Drilling) LWD—GR/Res Intermediate Drill Pipe Tool Joint Body DP Tool Make Tensile Pipe WT Grade Conn. Joint Joint Body Torquep Torsion Torsional capacity Capacity (PPI) Type OD ID(in) al Yield Yield w/conn. (in) ID(in) (ft.lbs) (ft lbs) (ft.lbs) (gal/ft) (kips) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 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. SI07-SE4 Drilling Wellplan Page 18 of 40 07/08/14 • • us operafin9 WELL SI07-SE4 Intermediate Drilling 1. Directionally Drill 12-1/4" hole ➢ Use the following Parameters: • Flow rate of 900 GPM • 120- 140 RPM 2. Casing Point: Land Intermediate casing 50' into the 0A2 sand reservoir 3. LOW ROP: Consult with Town as ROP drops to< 1-2 ft/hr for one(1)full hour. This usually occurs in the Lower Ugnu at high tangent angles(+80 degrees). Goal is to avoid excessive BHA and DP wear. Decision should be made to trip BHA out of the hole before excessive wear begins. 4. Backream at Intermediate Casing point: ➢ 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. 5107-SE4 Drilling Wellplan Page 19 of 40 07/08/14 vois • eni ass operrang WELL SI07-SE4 Intermediate Casing Program: (all depths feet RKB) OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (ppb Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) Hydril **Special 9-5/8 40 L-80 563 10.625 8.835 Drift 3090 5750 916 8.75 Intermediate Connection Make Up Torque (ft.lbs) Min. Target Max OD WT Make (in) (ppb Grade Conn. Type Torque,Uft- Make Up Make Up Yield Torque lbs Torque Torque 9-5/8 40 L-80 5631 10,800 13,000 N/A 75,000 **Special Drift casing to 8.75 Intermediate Casing Interval Notes: a. Ensure proper sized rams are installed and tested prior to running intermediate casing. b. Rig up and utilize a casing fill up tool for the casing job. Shoe Track: 1. Have a spare float shoe and collar made up with centralizers and on location ready to go ➢ Shoe joint misalignment has caused cross threading with Hydril 563 connection and requires make up by hand for first 10-15 joints • Make-up Shoe track(and first 10-15 joints)by hand using chain tongs until enough weight is in the slips to prevent cross threading • The shoe track joints should be Bakerlocked. • Inspect the float valves as the shoe track is picked up. • Run the shoe track into the well to test and confirm the floats are holding negative differential pressure. Connection Make Up: 1. Refer to the TenarisHydril"Running Manual General Guidelines"attachment for make up,pipe dope,etc....(Also available on Tenaris website) 2. Make up the first joint to the specified target torque and relax the tongs. 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 %z"after the second torque application,continue running the rest of the string normally using the published target torque. ➢ If the drawn line moves more than 1/2"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'i/2",continue running the rest of the string normally using the 15%higher target torque. • If the second drawn line moves more than 1/2",recheck the alignment,dope application and tong function, then continue to repeat this procedure from above until the drawn line does not move more than 1/2". 5107-SE4 Drilling Wellplan Page 20 of 40 07/08/14 eA us operating WELL SI07-SE4 ■ 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 1 Float shoe—Davis-Lynch Model 501-DV-PVTS Baker Lock down jet float shoe(double valve)**** 2 2 joints 9-5/8"casing Baker-Lock Float Collar—Davis-Lynch Model Type 700 DVSB- 3 LAPN double-valve float collar w/anti-rotation Baker-Lock baffle**** 4 9-5/8"Casing 5 9-5/8"Casing 6 Vetco Gray 9-5/8"mandrel hanger 7 9-5/8"landing joint Slick landing joint for reciprocation purposes Centralizers +/-38 9-5/8"x 11-3/4"Rigid Hydroforms(Floating) 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. S107-SE4 Drilling Wellplan Page 21 of 40 07/08/14 14 • . 2rn1ll us operrah• n9 WELL SI07-SE4 Intermediate Centralizer Placement a C i 1 10' bloat 9-5/8" x 11-3/4" Hydroform Centralizers Collar Run 1 Hydroform: • On Stop collar 5'above Float shoe. _------ • No centralizer on next joint • On Stop collar 10'above Float Collar. • From 4th joint to+/-1000' above the shoe- 1 centralizer floated between collars • l centralizer floated between collars from N sand oil bearing zone to+/-500' above N sand oil bearing zone Cg C J 5' JL SI07-SE4 Drilling Wellplan Page 22 of 40 07/08/14 vois en o us operating WELL SI07-SE4 Intermediate Cementing Program Section Casing Size Type of Fluid /Cmt Volume Properties Intermediate 9-5/8" Mudpush II 100 bbls Density 10.5 ppg DeepCrete 155.5 bbls Density 12.5 ppg Top of Cement @ 4,325'MD Yield 1.56 ft3/sk Intermediate Cementing Intermediate Cementing Notes: a. Obtain and review the Test Report from cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. If need be,confer with Drilling Superintendent. b. Do not over displace the cement(no more than 1/2 the shoe joint volume). c. For injectors,a cement bond log is required. Prefer to run sonic LWD in production hole BHA and log intermediate casing on trip in hole to drill out intermediate shoe. 1. Perform Rig pump efficiency check and confirm+96%efficiency before pumping and displacing cement. 2. Ensure Schlumberger re-calculates cement volume based on"N"sand actual depth! D 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. D Ensure that the cement unit and rig pumps are manifolded so there will be redundancy in case of any pump failure during displacement. D Pump cement at 5 bpm and displace with 8.0 bpm if possible without losing returns. Slow rate to 3 bpm during last+/-30 bbls prior to bumping plug. 5. When the plug bumps,pressure the casing to 500 psi over the final displacement pressure and ensure that the string is holding pressure. Notify the Drilling Superintendent if the string will not hold pressure. Bleed off pressure and ensure the floats are holding. If the floats leak,pressure back up to final displacement pressure and shut in cementing head. 6. Land casing on mandrel hanger D. Maintain reciprocation as long as possible 7. Install Vetco 9-5/8"packoff assembly. 8. Pressure test packoff per Vetco Gray. D Do not exceed 80%of intermediate casing collapse D Record test on IADC report and in WellView 5107-5E4 Drilling Wellplan Page 23 of 40 07/08/14 1,5* • • enll ass operating WELL SI07-SE4 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 SI07-SE4 Drilling Wellplan Page 24 of 40 07/08/14 aro, 2n us operrahng WELL SI07-SE4 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly as per the attached BHA diagram. ➢ 8-3/4"PDC ➢ Rotary Steerable ➢ Flow rate: 550 GPM ➢ 120- 140 RPM 2. RIH to the float equipment. ➢ Pressure test the casing to 3000 psi for 30 min and record on chart(AOGCC required casing integrity test). ➢ Plot Casing Pressure Test on the Pressure LOT form in N drive Oil Based Mud Fluid Displacement 3. Displace casing to new Oil Based Reservoir Drilling Fluid ➢ Do not contaminate new OBM in rig pits ➢ Displace old water based fluid to trucks or exterior tanks for disposal 4. Drill out the float collar&shoe. ➢ See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 5. Drill 20'-50' of new hole using the Oil Based Reservoir Drill-In fluid. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 12.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Do not pump more than 1/2 bbl after leak off is determined. There is no need to pump more than 1/2 bbl into the leak off and extend the fracture. ➢ Plot on LOT form in N drive SI07-SE4 Drilling Wellplan Page 25 of 40 07/08/14 iirotil • • 2no• us operating WELL SI07-SE4 PRODUCTION SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan (3) True Formation Tops Measured Vertical Comments Depth, ft Depth, ft SV-4 763 755 SV-3 1184 1135 SV-2 1542 1415 N /Permafrost 2000 1747 SV-1 2462 2061 Ugnu Top(UG4) 2985 2351 13-3/8" Csg 3177 2454 UG-2 Coal Bed Marker 3667 2757 Lower Ugnu 4632 3411 Schrader Bluff Top 5100 3684 N Sequence Top 5183 3726 N Top 5272 3768 ReCalc Intermediate Cement w/Actual N Bottom 5481 3858 N Sequence Base 5706 3948 9-5/8" Csg 6058 4025 ICP- Set ABOVE OA Sand Top OA Top 6127 4031 4 1/2" liner 16129 4056 Total Depth SI07-SE4 Drilling Wellplan Page 26 of 40 07/08/14 tio* • 11, 2rnn • us opera t ng WELL SI07-SE4 Production Mud Program: FazePro Density HTHP FL Electrical Interval VP Oil:water Stability (ppg) (mU30min) 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/EcoSCO Production Drill Pipe Tool Tool Make Up Joint Body DP Tensile W7' 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. (ft lbs) (ft.lbs) (gal/ft) psi 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 Production Section Notes: a. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow test MWD tools. c. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. d. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. e. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Openhole Sidetracking Practices: f. Lowside in a fast drilling interval where the wellbore is heading up and where the ABI's show a good build rate. g. Orient within 15 degrees either side of lowside and trough with high rotary RPM's while reciprocating from the kickoff point back to the first stabilizer. Trough for approximately 30 minutes. h. Time drill at 4 to 6 feet per hour with high flow rates and rotary RPM's for the first 5 feet. Gradually increase the penetration rate as the openhole sidetrack is achieved. i. If any openhole sidetracks are drilled,confer with Drilling Supt.and consider tripping without circulating or without rotating past the sidetrack point. 5107-5E4 Drilling Wellplan Page 27 of 40 07/08/14 wok • us operrahng WELL SI07-SE4 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 D. Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. ➢ Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: ➢ At TD circulate 50%of calculated TAD cleanup cycle pulling 1 stand per bottoms up. Once the first 50% cleanup cycle is completed circulate the remaining 50%of the calculated cleanup cycle pulling 2 stands per bottoms up. Decrease backreaming speed as torque and pump pressure dictate. • 550 GPM • 120-140 RPM ➢ Backream into the intermediate casing shoe. • 550 GPM • 120-140 RPM • Slow backreaming speed when pulling BHA into the Intermediate casing shoe/rathole. Hold parameters steady at 550 GPM and 120 RPM. • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming. Do not attempt to pull out on elevators once backreaming has started. 3. Drop rabbit down drill string once bit is above the intermediate shoe:the SLM of landing string portion of the tapered DP • Drift OD dependent on Completion • COMPLETION DP RABBIT SIZE:2-3/8"OD • All drifting tools will be accounted for and held in one place at all times. 4. Continue backreaming until depth at which it is possible to pull out on elevators at>9.1 swab EMW at 2.5 min/stand • 550 GPM • 120-140 RPM • Determine depth at which swab can be kept>9.1 EMW at 2.5 min/stand as per K&M TAD Model. 5. Circulate until shakers are clean as per K&M. • 550 GPM • 120-140 RPM 6. Slug DP and trip out of hole on elevators. ➢ Utilize K&M's swab model to control trip speed and avoid swabbing the open hole below 9.1 ppg EMW. 7. Lay down BHA ➢ When out of hole,down load the recorded tool data and send to the Geologist in town SI07-SE4 Drilling Wellplan Page 28 of 40 07/08/14 1.0111701 us operahng WELL SI07-SE4 Production Liner Completion DP RABBIT SIZE Will BE: 2-3/8" OD Production Liner OD Conn. Cplg OD Collapse Burst Tensile Yield (in) WT(ppJ Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) 4-1/2 11.6 L-80 H5211 4.695 4.000 3.875 6360 7780 171 Production Liner Connection Make Up Torque (ft-lbs) Min. Target Max. OD WT Grade Conn. Type Make Up Make Up Make Up Yield (in) (ppb Torque, ftTorque* Torque Torque lbs 4-1/2 11.6 L-80 Hydril 521 3600 6300 N/A 16,000 * See attached TenarisHydril Guidelines for make-up torque recommendations Production Liner Centralization From To Quantity/Joint Fixed/Floating Type Shoe Liner 1/joint Fixed 4-1/2"x 7" top -Mid joint -Crimped on -Hydroform,Volant(Crimp on) Liner Running Procedure Notes: • Ensure proper crossover and FOSV is on the rig floor in case of a well control situation. • The liner will be run in FazeAway Delayed Breaker. Consult with completions engineer for liner detail. Liner string will be adjusted according to actual depths after drilling. Consult with completion engineer and ops geologist to determine exact placement and number of swell packers prior to installation. • Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. • Ensure accurate torque and drag data is gathered. Record pick up and slack off weights every stand and free rotating torque every five stands. Data gathered will assist in future liner running operations throughout the project. • Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well and recorded in WellView. • Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. • Review all setting operations and shear pressures with Baker Oil Tools service hand. • Ensure that all workstring components have been rabbited as ball will be dropped to actuate downhole tools.Rabbit DP on last trip out of prior to running liner. • If any openhole sidetracks have been drilled,monitor sidetrack depths during run in and ensure shoe enters the correct hole. • DO NOT run E-CD subs on drill pipe while running liner string. • Torque ratings for string components: SI07-SE4 Drilling Wellplan Page 29 of 40 07/08/14 wiis • • era•• us operating WELL SI07-SE4 String Components Yield Torque(ft-lb) 5" 19.5#TT525 Drill Pipe 74,100 HRD Running Tool 40,000 7"29#Hydril 563 39,000 4-1/2" 15.5#Hydril 521 16,000 • Shear pressures for liner hanger assembly: Item Description Shear Value Shear Range HRD Running Tool,7" Nominal- 3192 psi 15%+ 3671 psi 4650 mch rel,3 pins 15%- 2713 psi Pusher Tool Activation Nominal- 1986 psi 15%+ 2284 psi 15%- 1688 psi Pusher Tool Neutrlz. Nominal- 3588 psi 15%+ 4126 psi 15%- 3050 psi Ball Seat SOLID *****Make-up torque for liner hanger sub-assembly,including running tool connections,should be torqued to 14,000 ft-lbs prior to deliver to rig. Procedure: 1. Hold Pre job safety meeting to ensure all parties understand operation 2. PU the Liner Assembly and Running/Inner String as outlined above. 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. Fill Liner Tieback Sleeve with"pal mix" and ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 minutes for mixture to set up. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. Record ROTATE, PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIH with Liner Assembly as hole conditions allow,but do not exceed running speed of one stand per minute. Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. Circulate minimum of one DP volume and record ROTATE,PU and SO weights. 8. Record PU, SO, and Rotating torque in open hole every 500' to ensure friction factors are sufficient to run the liner to bottom successfully. If friction trend indicates liner will not go to bottom then call Drilling Supt. immediately. 9. Rotating liner 20-60 RPM will be necessary to run to bottom. 10. Continue RIH with Liner Assembly to proper setting depth. Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8"casing shoe. 11. Trip slightly deeper than desired liner top location with liner top. Last motion of the liner should be up to ensure it is set in tension. Ensure Liner Hanger assembly does not exit 9-5/8"casing shoe. 12. Prior to setting the hanger&packer,double check all pipe tallies and record amount of drill pipe on location. 13. Rig up to pump down workstring with rig pumps. Pressure test lines. Bleed off test pressure. 14. Drop setting ball down the workstring and pump slowly(1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. SI07-SE4 Drilling Wellplan Page 30 of 40 07/08/14 �• • • • ehin us op rra1t ng WELL SI07-SE4 15. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 minutes each up to 4000 psi. 16. Packer can now be pressure tested. Bleed DP pressure to zero, close annular preventer and test annulus to 1,500 psi for 10 minutes and chart. 17. Bleed off pressure and pickup to verify that the HRD running tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, 6,795 ft-lbs of left hand torque can mechanically release the tool. 18. Once running tool is free and packer is tested,Displace mud from liner top to surface with 9.0 ppg KC1 brine per MI recommended program. 19. POOH and LD and inspect the liner running tools. Run 4 1/2 Injetor Completion String 1. Hold pre job safety meeting prior to start of any operations including review of applicable notes listed above. 2. Pick up seal-stem no-go entry guide assembly and two full joints. 3. RIH 4 ''A Hydril 563 tubing joints until reaching Mirage Plug. 4. Make up Mirage Plug,Autofill valve,3.725 XN nipple,PHL Packer and 3.81 X nipple assemblies per HAL representative. 5. Continue RIH with 4-1/2"tubing. 6. Continue RIH until reaching GLM. Make up KBMG gas lift mandrel with DCK-2 annulus-to-tubing shear valve set for approximately 2,000 psi. 7. Continue RIH until the second 3.813"X nipple is reached. This second nipple should be placed at approximately 2200 feet MD. 8. Space out the landing of the seal stem entry guide and no-go sub in the liner tieback sleeve. Pick up additional joints of 4-1/2"tubing and land out no-go sub to obtain proper tubing hanger space out measurements. 9. Install correct pup joints to allow the tubing hanger to land properly while the seal stem is fully engaged in the liner tieback sleeve. Ensure entry guide will be engaged when tubing hanger is set. 10. Look at indicators to be sure the seal stem entry guide enters in the liner tieback sleeve. 11. Make up tubing hanger,pup joint and crossover. The upper most connection may be torque adjusted to allow for proper alignment of tubing hanger if necessary. 12. Drain and rinse BOP stack before landing tubing string and pick up landing joint. 13. Check hanger seal areas and grease hanger per Vetcogray recommendations. Ensure hanger is centered and land same. Run in Lock down screws. 14. Test upper and lower seals to 5,000 psi and hold for ten minutes. 15. Rig up pump to set packer. Test surface lines to 5,000 psi and then bleed pressure to zero. 16. Pressure down tubing string to 1200 psi to close Autofill Valve and monitor for leaks. SI07-SE4 Drilling Wellplan Page 31 of 40 07/08/14 _ �. . • ef�lli MSS Oo perafi nlg WELL SI07-SE4 17. Increase pressure down tubing to 3,500 psi to set packer and hold for 30 minutes. Record on chart as tubing integrity test. Ensure inner annulus is open and monitor for returns. 18. Reduce tubing pressure to 2,000 psi. Rig up and pressure inner annulus to 2,500 and hold for 30 minutes. Record annulus pressure on chart as inner annulus integrity test. Bleed annulus pressure to zero. 19. Increase pressure down tubing to 4,400 psi to shear open Mirage Plug. Reduce tubing pressure to zero. 20. Pressure inner annulus to 2,500 to shear valve in GLM. If valve does not open,cycle annular pressure from 0 to 2,500 psi several times while allowing tubing to bleed pressure. 21. Pull landing joint and set BPV. 22. Nipple down stack and nipple up tree. Test void to 5,000 psi for ten minutes. 23. Pull BPV and set TWCV. 24. Fill tree with diesel and function valves. Test tree using rig test pump and chart to 500 psi for 5 minutes and then 5,000 psi for 15 minutes. 25. Pull TWCV. 26. Rig up flow manifold to tree. Circulate diesel through GLM to fill annulus and tubing volume from GLM depth to surface. Diesel volume should be approximately 160 bbls. Allow annulus and tubing pressures to equalize. 27. Set BPV and secure tree and wellhead. 28. RDMO. SI07-SE4 Drilling Wellplan Page 32 of 40 07/08/14 tfo* • s rn1us operrfins WELL SI07-SE4 29. ATTACHMENTS 30. Recommended Drilling Practices 31. Health,Safety,and Environment 32. Safety Meeting Topics 33. Well Shut In Procedure While Running Tubing 34. Conductor Broaching Contingency Plan 35. Port Collar Decision Tree SI07-SE4 Drilling Wellplan Page 33 of 40 07/08/14 frIA • ! nn us operrafins WELL SI07-SE4 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. 5107-SE4 Drilling Wellplan Page 34 of 40 07/08/14 . • eno• us operreing WELL SI07-SE4 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 H25 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 H25 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. SI07-SE4 Drilling Wellplan Page 35 of 40 07/08/14 11,4* • • env us operr ins WELL SI07-SE4 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. SI07-SE4 Drilling Wellplan Page 36 of 40 07/08/14 • 2fn10 us operahns WELL SIO7-SE4 ➢ 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. SI07-SE4 Drilling Wellplan Page 37 of 40 07/08/14 • en8 us operating WELL SIO7-SE4 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. SI07-SE4 Drilling Wellplan Page 38 of 40 07/08/14 ., • • • 2no usoperrang WELL S107-SE4 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 Artie 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. SI07-SE4 Drilling Wellplan Page 39 of 40 07/08/14 IA • s • 2nd us operrahnc WELL SI07-SE4 TAM PORT COLLAR Utilization Decision Tree TAM Port Collar Utilization Decision Tree Begin Primary One Stage Cement Job • No Cement Cement to to Surface Surface T Drilling Foreman and Nipple Up an. Engineer determine the X Test BOP's Top of Cement Top of Cement / Cement Continue wit above Port / below Port Completion Collar Collar (1000'TVD) (1000'TVD) • • Indicators of Cement Top Perform Top Job as per ---- ► Open Port Collar If Top Job is ineffective or 1. Observation of Tracers in Spacer ahead of lead cement requirements of using drillpipe 2. Calculated Displacement AOGCC unacceptable to AOGCC P 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Circulate Cement Test BOP's to Surface and close Port Collar T T Continue with Nipple Up and Completion Test BOP's 7 Continue with Completion S107-SE4 Drilling Wellplan Page 40 of 40 07/08/14 • • mm p p�pp p(p �p pp C m 010 CO CO O10 OD(A��7mmm ON N CO 0O cmO V N�{0,CO N CpOO v.CI•<p 0 r CD c00 pmpt�co 0010..,-N n COO(cOO cD _� b'1 22 M m 00D r fm01017N S r St NNV 00.LL''N om N*10 CD m 0000N.-0000-,-010,v 01CAD W 010 N W 01 S 01 01 01 01 01 01 01 01 8 LLD Q Q Q Q th M N N N N N ' N N N NN N p) 17/ZZ 1n 1010 h h h h co m 1010 co 10101010 m 10 m 01 m m 010 m m 0101 m N h m H m m1010m1010 a 0 a Cm A A 4P3iAi8'• mn888vpn..:'282:24`1222.nm8:'-'28`28c`�nA819.48°'4222a42 01 t00t•00 (• O(pp 9�pp fOD,m-,.m00 W co, -m10- C) m 10 f O t D(0 f O Cn,�g O..m O O.-.-N N Q Q O m m n m m Q yy,O N N 1 O 2 1c 1110 uMittlr7ollcp�fnlv>ln ipn iiSv�i 233333333 pl�i8�i�i�i�i�i i[i�ori lii v'oihv� �� R_ COCCOO f0D 000 S 0101801 01 001 010101 01100 COOS CD 00 CO0101 0101 0101 01010101 01000(00 CD<0CD10D 01 O N W y pp p m p p p n Co'..NO ...NOM O CONv-ANN �100NppN�Np�00�pM:M.V.Sm M m 44 MS�O}n o. 444.660100mi0 cocn1 Qm N m°D CD CD1LilAA-', NNf717M171n7fAr;pg M M Q<Q V Q O R 01(1N,,,i10 V Q O V Q QOQM O b U O K W Nd c O c C o d w Q 'U 2 0 0 O 8 323.8N V 2 AA ONNMM<82882 g n 8828 O0001 0Q N 8284480 C O O O O 4 N N N CO CO CO CO M Q Q Q Q Q Q 0 0 0 Q Q Q Q Q Q Q6 1 n 1 n 1 n 1 n 1 n 1 n 1 f j 1 n 1 n 10 m 10 10 F. 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Z p N a .,zs al it oo° w N N g m m ✓n °,� .". 63f6—�co o 2. 740 Q ., fzOp a a .. Z. •°app ¢� .� 7 o�v_ % �fip w `�r` m •m C.) �, •Q z / °� I 'Zoe. M COtii i o 1 U p 'p' I '7'4 g�0 "K6 co o po 0 Z N U LL e ` Y a!°O •r �� . ° �n�(/ O co do 1 Z I lits y -.(' �Lyo� O y - O y (� N O ! f! f pp O 6, O�00 - O c m 0,�0lpp _ p tp ' �° N K '° °I ee. Y In 00•'app p ` 'fV`gg N e.n: Z Y BCOp o�ir .• �� r� 0 �yB U N c c3, ZS80pp. • "�1,�ie,p•8 co 0�5� m C m . fid' 0 E, ca. "'so:" l4 l fO O.. Lu • • R Bo' 1 . f8 � vm " C- v �6p - Q'i� rzffpW f, Z O,1l °, gyfs • .: 3 QY ` _I6,Op 4f. %;rsCu () O 2 0. I Qze, ---'• .‘-.,,:'''. °I,, . e •• pp „le ; 8 �pf • �r O 0 • 06 `je 06 °1t r. ®�f ffp <<fe, IIge • g M o u z e' .3. R �{r�lp. 0,49us sgf, __ •C 9.--. Ivo °ba v-f' ==.��Yyyf.♦c e • $k.. • ij�u o ▪ rn j ..j`,,,'",..--0"1"----ti ,`�� . ` _, piers!�. • LL is A . , o \" .+ ��j/' �/ .,, ° �,�oe �f �� SI c l f a; i9' "ai ..! z°1_ :: ,N '. , m a O ' oo LL I I m i f O r il 1P1 I O o'. O o I o \ 0 0 0 LL o 0 0 0 N N N V tD a 07 ¢ z z /J /II a a (8)05La=oleos(8)SN (1) LL Z 0 LL V Z z N Z a -- ‘,1 M z o Z LL Z Z LL > z Z � it (O O 0) (V J Z Z c° d o N c'' d -rn o_ c+' Z c° CL in . Z N a N .:6a. N co LL • e SI07-SE4(P3)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 Reference: North Analysis Date-24hr Time: July 08,2014-09:05 North Reference: True Analysis Machine: AKA-DEC-9010 Client EM Petroleum Database I Project: IocalhonUdrilling-Nikeitchuq 2.71043 Version I Patch: 27.1043.0 NOTE:Measured Depth is referenced to individual borehole elevation. TVD,NS,EW are referenced to the reference trajectories wellhead location and borehole elevation. A minimum 010.300 m is always included for borehole diameters. All local minima Indicated. Results filtered:Depth 0100.00 ft<•MD or 113128.01 ft,Ct-Ct separation 0=1500.00 ft Results highlighted:EOU-EOU separation v=1320.00 ft Anti-Collision Rules Used Rule Set Name DAM AnOCollision Standard 5002 v5.1/5.2 Exemption Risk Leval: Minor Rule Name jilsk Leos) Mira= .131112.1.11a1 RNe j SLB Alert Zone Threshold OSF=5.0 S002 05.1/5.2 Alert Rego OSF=5.00 "k'/ SLB Minor Risk Threshold OSF=1.55002 v5.1/5.2 Minor Ratio OSF=1.50 X SLB Major Risk Threshold OSF=1.0$00205.1/5.2 Major Ratio OSF=1.00 SLB Surface Rule S002 v5.1/5.2 Major CT_CT MAS=32.81(0) SLB Alert Zone Threshold CtCt<=15m S002 05.1/5.2 Alert CT_CT MAS=49 21(ft) Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\S107-SE4\SI07-SE4\S107-SE4(P3) 7/8/2014 9:06 AM Page 1 of 137 • 0 Reference Trajectory Summary Field: Nikeitchuq Well: S/07-SE4 Structure: Spy Wend Borehole: S107-SE4 Slot SF07 Trajectory. S107-0E4(P3) Client: Eni Petroleum Type: Der Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.09036679° Grid Scale Factor. 0999900155 Magnetic Declination: 19.119° Magnetic Declination Date: October 01,2014 Magnetic Model: BGGM 2013 Reference Point Lizthing Eating Endo Structure Unc Slot Unc. 6053660.340(ItUS) 511683.970(ftUS) 54.100(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Tralectory Error Model'ISCWSAO 343 95.000%Confidence 2.7955 sigma Survevina Prow While Drilling Description Part MD From(fl) MD To(R)EOU Freq(ft) Survey Tool Type Hole Slav tin) Casing Diameter On) Borehole/Survey 1 0.000 41.000 1/100.000 SLB NSG+SSHOT-Depth Only-No Globe 16.000 13.375 S 07-6E4/S107-SE4(P3) 1 41.000 1200.000 1/100.000 SLB_NSG+SSMOT-No Globe 16.000 13.375 S07SE4/SI07-SE4(P3) 1 1200.000 2700.000 1/100.000 SLB MWD+SAG-No Globe 16.000 13.375 S 07-5E4/S)07-SE4(P3) 2 1200.000 3177.389 1/100.000 SLB MWD+GMAG-NO Globe 16.000 13.375 S07SE4/SIS7-SE4(P3) 2 3177.389 4670.000 1/100.000 SLB_MWD+SAG-No Gleba 12.250 9.625 S 074E4/S107-SE4(P3) 3 3177.389 6058.363 1/100.000 SLB_MWD+GMAG-NO Globe 12.250 9.625 S07SE4/SI07-SE4(P3) 4 6015.240 7510.000 1/100.000 SLB_MWD+SAG-No Globe 8750 5.500 S 07SE4/S107-SE4(P3) 5 6058,363 18128.609 1/100.000 SLB MUVD+GMAG-No Globe 8.750 5.500 S07-8E4/SI07-SE4(P3) Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\S107-SE4\S107-SE4(P3) 7/8/2014 9:06 AM Page 2 of 137 • • Offset Trajectory Summary Offset Selection Criteria' Offset Selection Catena: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 Seleedon Summary Walls Selected:44 Boreholes Selected:74 Definitive Surveys Selected:53 Non-Def Surveys Selected:2 Definitive Plans Seleced:19 Non-Det Plans Selected:0 Total Trajectories:74 OSF filter in detailed report None •Excluded:The trajectory was analyzed and fully passed all exited°so the detailed results have been excluded horn this report for clarity. Trajectory Borehole Well Type Passing Excluded• 5114-N6 5114-N6 5114N6 Def Survey SP04SES(P2) SP045E5 SP04SE5 Def Plan SPIO-FN5 SPIOFN5 SP10-FN5 Def Survey SP08-N7 SP08-N7 SP08-N7 Def Survey SP08-N7L1 SPO8-N7L1 SP08-N7 Dat Survey SP09-N9L1(P1) SP09-N9L1 SP09-N9 Def Plan SP09-N9(P1) SPO9-N9 SP09-N9 Def Plan SI08-FN8(P1) S106-FN8 S106-FN8 Det Plan 511 t-FN6 SI11-FN6 5117-FN6 Def Survey SPOS-FN7PB1 SP05-FN7PB1 SP05-FN7 Det Survey SP05-FN7 SPO5-FN7 SP05FN7 Def Survey SP05FN7LI(Pt) Plan SPO5-FN7L1 SP05FN7 Def Plan SPO3FN9(Pt) SP03-FN9 SP03FN9 Def Plan SP03FN9LI(Pt) SP03-FN9L1 SP03FN9 Def Plan SP124E3LI current SP125E3LI SP12SE3 Non-Def Survey SPI2SE3 SP12-SE3 SP72SE3 Non-Def Survey 5102-SEN(P3) 5102-5E6 S102-5E6 Def Plan SI13-FN4 S113-FN4 SI13-FN4 Def Survey SP23-N3 SP23-N3 5P23-N3 Def Survey SP23-N3PB1 SP23-N3PB1 SP23-N3 Def Survey 5120-N4PB1 S120-N4PH 5120-N4 Def Survey S120-N4 5120-N4 S120-N4 Def Survey SP16FN3 SP16-FN3 SP16FN3 Def Survey SP21-NW1(P7) SP21-NWI SP21-NWI Def Plan SI25-N2 S125-N2 S(25-N2 Def Survey SP27-NIL1(P1) SP27-N1LI SP27-N1 Def Plan SP27-N1 SP27-N1 5P27-Nt Def Survey 5P30-WI 5P30-W1 SP30-WI Def Survey SP30-W1PBt SP3O-VVIPB1 SP30-W1 Def Survey 5126-NNO(P3) 5126-NW/ 5126-NW2 Del Plan 5132-W2 S132-V2 5132-WO Det Survey SD37-DSP1 SD37-DSP1 SD37-DSP1 Def Survey SP28-NW3(P2) SP28-NW3 SP28-NW3 Det Plan SP3I-W7(P8) SP31-W7 SP3I-W7 Def Plan SP31-W7L1(P3) SP31-WTL7 SP3t-W7 Def Plan SP33-W3 SP33-1/0 SP33-N3 Def Survey S135-W4 5135-W4 S135-W4 Def Survey 5(34-Vr6(Ph) 513444.6 5134-W6 Def Plan 5119-FN2 S119-FN2 S119-FN2 Def Survey SP36-V5 SP38-V5 SP38-W5 Def Survey SP36-V5L1 SP38-W5L1 SP36-W5 Def Survey SP22FN1 SP22FN1 SP22FN1 Def Survey SP22FN1PB4 SP22FN1PB4 5P22-FN1 Def Survey 5P22FN1 PB3 SP22FN1 PB3 SP22-FNi Def Survey SP22FNIPB2 SP22FNIPB2 SP22-FN1 Def Survey SP22FNIPB1 SP22FNIPB1 SP22FN1 Def Survey SP28-NW3LI(Pt) SP28-NW3LI 5P28-NWe Def Plan 5115-N8(Pt) SI15-N2 5115-N8 Def Plan SP18-N5PB1 SP18-N5PB1 SP18-N5 Def Survey SP18-N5 SP18-N5 SP18-N5 Def Survey OP0S-06L1 OPO5-06L1 OP05-06 Def Survey OP05-06 OPO5-06 OP05-06 Def Survey SI17SE2 SI17SE2 S117-SE2 Det Survey Oliktok Point I-1A-106(P5b)OP tat Ohktok Point I-1A-106 Olikbk Point 1-1 Def Plan 0108-05 0106-05 0106-05 Def Survey SP24SE7 L1 SP24SE1L1 SP24SE1 Det Survey Nikaitchuq 3 Nikaitchuq 3 Nikaitchuq 3 Def Survey Nikaitchuq 3PB3 Nikaitchuq 3PB3 Nikaitchuq 3 Def Survey Nikaitchuq 3PB2 Nikaitchuq 3PB2 Nikaitchuq 3 Del Survey Nikaitchuq 3PB1 Nikaitchuq 3PBt Nikaitahuq 3 Def Survey 0l06-0SPB1 0108-0SPBt 0108-05 Def Survey SP24SE1 SP245E1 SP24SE1 Def Survey SP015E7(P2) SP01SE7 SP01 SE7 Def Plan Nikaitchuq 4PB1 Nikaitchuq 4P81 Nikaitchuq 4 Def Survey Nikaitchuq 4 Nikaitchuq 4 Nikaitoh g 4 Del Survey OP05-06P82 0P05-06PB2 OPO5-06 Def Survey Nikaitchuq 1 Nikaitchuq 1 Nikaitchuq 1 Det Survey S129-S2 S129-S2 S129-52 Def Survey Nikailehuq 2 Nikaitchuq 2 Nikaitchuq 2 Def Survey Kigun 1 Kigun 1 Tuvaaq ST 1 Def Survey Kigun 1 PBI Kigun 1 FBI Twaaq ST 1 Def Survey Tuvaaq ST 1 Tweaq ST 1 Tuvaaq ST 1 Def Survey Oliktok Point 1-1 Oliktok Point I-1 Oliktok Point 1-1 Def Survey OPO5-06PB1 0P55-06PB1 OP05-06 Def Survey Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island Z107-6E4\8107-6E4\8107-8E4(P3) 7/8/2014 9:06 AM Page 3 of 137 • • Field: Nikertchuq Well: SP04SE5 Structure: Spy/sand Borehole: SP04SE5 Slot SPO4 Trajectory: SP04SES(P2) Client: Eni Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Plane.Zone 04.US Feet North Reference: True Grid Convergence Angle: 0.09060981° Grid Scale Factor: 0999900156 Magnetic Declination: 20.325° Magnetic Declination Date: September 30,2012 Magnetic Model: BGGM 2011 Reference Point: Northlna .0 ing gIeoe8on Structure Unc. Slot One. 6053666 440(SUS) 511715380(ttUS) 54100(ft)MSL 0.000 ON(1 sigma) 0.000(k)(1 sigma) Trajectory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Survevina Prorr While Drilling Description Part MD Front(f) MD To(ft) EOU Frog(II) Survey Tool Type Hole Sloe(in) Casing Diameter(in) Borehole/Survey 1 0.000 41.000 1/100.000 SLB NSGFMSHOT-Depth Only-No Global 16.000 13375 SP04-SE5/SP04SE5(P2) 1 41.000 1000.000 1/100.000 SLB NSGOMSHOT-NO Global 16.000 13.375 SPO4-SE5/SP04SE5(P2) 2 500.000 2565.427 1/100000 SLB MVVD0GMAG-No Global 16000 13.375 SP04SE5/SP04SE5(P2) 2 2565427 7198.950 1/100.000 SLB_MWD«GMAG-No Global 12250 9.825 SP04-SE5/SP04SE5(P2) 2 7196.950 17153.967 1/100.000 SLB MWD0GMAG-No Global 8750 5500 SP04-SE5/SP04SE5(P2) 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 Statue ((t) (ft) (ft) (4) (ft) (ft) (5) ((t) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 6100.00 ft<=MD cc 16128.61 ft Results altered:Ct-Ct separation<=1500.00ft Results highlighted:Ct-Ct separation 001320008 6100.00 4028.97 797.48 1405.89 6699.00 4026.14 277999 1763.75 2933 1045.66 112.70 970.1•MININBC196.7. OSF 1.50 Pass 6150.00 • 4031.82 772.50 1449.10 6748.22 4030.43 2763.23 1809.82 3004 1054.35 113.66 978.1:tititit(tie0t/v OSF 1.50 Pass 6200.00 403407 748.44 1491.71 6797.18 4034.70 2746.54 1855.66 31.87 1084.27 114.89 98740 14.... OSF 1.50 Pass 6250.00 4035.84 718.95 1533.44 6845.76 4038.93 2729.99 1901.13 3372 1075.83 11590 998.15 14.06 OSF 1.50 Pass 8300.00 4037.11 690.07 157423 689390 4043.13 2713.59 1946.20 35.58 1089.03 117.10 1010.55 14.08 OSF 1.50 Pass 6350.00 4037.89 65986 1614.06 8941.55 4047.28 2697.36 1990.80 37.11 1103.82 118.48 102444 14.11 OSF 1.50 Pess 6400.00 4038.51 629.18 18.53.54 698901 4051.41 2681.18 2035.23 36.93 1119.18 119.88 1038.85 14.13 OSF 1.50 Pass 6450.00 4039.13 59851 1693.02 703647 4056.55 266501 207966 36.75 1134.55 121.46 1053.17 1414 OSF 1.50 Pass 6500.00 4039.74 567.83 1732.50 7083.93 4059.69 2648.64 2124.09 36.58 1149.93 123.04 1087.49 14.14 OSF 1.50 Pass 6550.00 4040.36 537.15 177198 7131.40 406382 263267 2168.52 36.41 116531 124.80 1081.71 1413 OSF 1.50 Pass 6600.00 4040.97 506.48 1811.46 7178.86 406796 2616.50 221295 36.24 1180.71 126.57 1095.92 14.12 OSF 1.50 Pees 6650.00 4041.54 475.99 1851.08 723279 407265 2598.08 226342 35.13 1195.87 128.58 110974 14.07 OSF 1.50 Pass 6700.00 4041.70 448.54 189149 313.92 407928 2568.99 2338.88 33.95 1208.91 131.15 1121.06 13.94 OSF 1.50 Peru 6750.00 4041.78 41729 1932.04 7396.36 408537 2537.31 241473 33.69 122039 133.62 113077 13.79 OSF 1.50 Pass 6800.00 4041.86 38804 197259 7479.91 409086 2503.06 2490.3 ' 33.47 1230.51 136.44 1139.14 1364 OSF 1.50 Pass 6850.00 4041.93 35878 2013.13 756444 4095.72 246623 2566.66 33.27 1239.24 139.16 114606 13.46 OSF 1.50 Pass 690000 4042.01 329.53 2053.68 764981 409992 242684 2642.28 33.11 1246.56 141.83 1151.80 1329 OSF 1.50 Pass 6950.00 404209 300.28 2094.23 7735.90 4103.41 238494 271740 3298 1252.43 144.54 115566 13.10 OSF 1.50 Pass 700000 4042.16 271.02 213478 782255 4106.19 234058 279178 3287 125686 147.19 1158.32 12.90 OSF 150 Pass 7050.00 404224 24177 2175.33 7908.61 410822 2293.85 2865.20 32.80 1259.82 14987 1159.50 12.70 OSF 1.50 Pass 7100.00 4042.32 212.52 221588 7996.91 4109.50 2244.85 2937.44 32.75 1261.30 152.46 115925 1250 OSF 1.50 Pass 7150.00 4042.44 183.28 2256.43 8073.60 4110.00 220011 2999.72 3274 1261.38 155.06 1157.58 1229 OSF 1.50 Pass 7200.00 4043.24 15401 2296.97 8123.59 411020 2170.60 304007 3277 1261.00 157.77 1155.41 1207 OSF 1.50 Pass 725000 4044.68 12477 233751 8173.58 411040 2141.10 308042 32.83 1260.61 180.61 1153.14 11.85 OSF 1.50 Pass 7300.00 4046.15 095.54 2378.04 8223.56 4110.60 2111.59 3120.77 3289 1260.22 163.47 1150.83 11.64 OSF 1.50 Pass 735000 4047.63 066.30 2418.57 8273.54 4110.79 208209 3161.11 3294 125983 16648 1148.44 1142 OSF 1.50 Pass 7400.00 4049.10 037.06 2459.11 8323.53 4110.99 205258 3201.46 3300 125945 169.50 1146.04 11.22 OSF 1.50 Pass 7450.00 4050.58 007.82 2499.84 8373.51 4111.19 2023.08 3241.80 33.06 1259.08 172.58 1143.600) 1Q1,00Q1 OSF 1.50 Pass 7500.00 405205 978.58 2540.17 411139 99357 328215 33.11 1268.67 175.6fil Pass 755000 053.53 94934 258070 8473.47 411159 964.07 332249 33.17 1258.29 148.551160.18 12.98/ GOP 1.50 Pass 7800.00 405500 920.10 262124 8523.46 4111.79 934.57 336284 33.23 1257.91 148.01 1158.82 12.84 OSF 1.50 Pass 7650.00 4056.47 89086 2661.77 857344 4111.99 905.06 3403.18 3329 1257.52 149.50 1157.45 12.71 OSF 1.50 Pass 7700.00 ' 4057.80 861.62 2702.31 8623.43 4112.19 875.55 3443.53 33.33 1257.15 15100 1156.08 1258 OSF 150 Pass 7750.00 4058.33 832.37 274285 8673.42 411238 846.04 3483.89 3334 125681 152.49 1154.74 12.45 OSF 1.50 Pass 7800.00 4058.41 803.12 2783.40 8723.42 4112.58 81653 352424 33.33 1256.49 15389 1153.42 12.33 OSF 150 - Pass 7850.00 4058.48 773.87 2823.95 877342 4112.78 787.01 3564.60 33.33 1258.17 155.51 1152.09 12.20 OSF 150 Pass 7900.00 4058.56 74462 2864.50 8823.42 411298 757.50 3604.96 33.32 1255.85 15703 1150.76 12.08 OSF 1.50 Pass 7950.00 4058.63 71537 2905.06 887342 4113.18 727.99 364532 33.32 125553 15857 1149.41 11.98 OSF 150 Pass 8000.00 4058.71 686.11 2945.61 8923.42 4113.38 69847 3685.68 33.31 125521 183.12 1148.06 11.84 OSF 150 Pass 8050.00 4056.78 656.86 2986.16 8973.42 4113.58 668.96 372603 33.30 125489 16168 1146.70 11.72 OSF 1.50 Pass 8100.00 4058.86 627.61 3026.71 9023.41 4113.78 639.44 3766.39 33.30 1254.57 163.25 1145.33 11.60 OSF 1.50 Pass 8150.00 4058.93 59836 306728 907141 4113.97 609.93 3806.75 33.29 1254.26 164.84 1143.96 11.49 OSF 150 Pass 8200.00 405901 569.11 3107.81 9123.41 4114.17 58042 3847.11 33.28 125394 16642 114258 11.37 OSF 150 Pass 8250.00 4059.03 539.87 3148.37 9173.41 4114.37 550.90 3887.47 33.21 1253.60 168.02 1141.17 11.26 OSF 150 Pass 8300.00 4058.96 510.67 3188.95 9223.41 4114.57 521.39 3927.82 33.18 1253.23 169.63 1139.73 11.15 OSF 1.50 Pass 8350.00 4058.90 481.47 3229.54 9273.41 4114.77 491.88 3968.18 33.18 1252.85 171.25 1138.28 11.04 OSF 1.50 Pass 8400.00 4058.84 45226 3270.12 9323.40 411497 46236 4008.54 33.17 1252.48 17287 1136.83 10.93 OSF 1.50 Pass 845000 4058.77 42306 3310.71 937340 411517 43285 4048.89 33.16 1252.11 17451 1135.36 10.83 OSF 1.50 Pass 8500.00 4056.71 393.85 3351.29 9423.40 4115.37 403.34 4089.25 33.14 1251.74 178.15 1133.90 1072 OSF 1.50 Pass 855000 4058.64 38465 3381.88 947340 411557 373.82 4129.81 33.13 1251.37 17781 1132.42 10.62 OSF 1.50 Pass 8600.00 4058.58 335.45 3432.46 9523.39 4115.76 344.31 4169.97 33.12 1250.99 179.48 113095 1052 OSF 1.50 Pass 8650.00 4058.51 306.24 3473.05 9573.39 4115.96 314.80 4210.32 33.10 1250.62 181.13 1129.46 10.42 OSF 1.50 Pass 8700.00 4058.45 277.04 351383 9823.39 411616 28528 4250.88 33.09 1250.25 182.81 112797 10.32 OSF 1.50 Pass 8750.00 4058.13 247.82 3554.20 9673.39 4116.36 255.77 4291.04 33.13 1249.92 184.48 1128.52 10.22 OSF 1.50 Pass 880000 4056.98 218.54 3594.72 972337 4118.56 226.27 4331.38 33.16 1249.70 186.15 1125.19 1013 OSF 1.50 Pass 8850.00 4055.51 189.23 3635.20 977334 4116.76 198.77 437172 33.08 124954 18781 1123.92 10.04 OSF 1.50 Pass 8900.00 4054.05 15993 3675.69 9823.31 411696 16727 441205 33.01 1249.37 189.48 1122.64 9.94 OSF1.50 Pass 8950.00 4052.59 130.62 3716.17 9873.28 4117.16 13777 4452.39 32.93 124921 19116 112137 9.86 OSF 1.50 Peru 9000.00 4051.13 10132 3756.66 992325 4117.35 10828 4492.72 32.85 1249.06 192.84 1120.08 9.77 OSF 1.50 Pass 9050.00 404967 7201 3797.15 9973.23 4117.55 03.78 4533.06' 32.78 1248.90 194.54 1116.80 9.68 OSF 1.50 Pass 9100.00 4048.21 4271 3837.63 10023.20 4117.75 049.28 4573.40 3270 1248.75 196.23 1117.52 9.80 OSF 1.50 Pass 9150.00 4046.74 13.40 3878.12 10073.17 4117.95 01978 4613.73 3262 1248.60 197.93 1116.24 9.51 OSF 1.50 Pass • Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\S107-SE4(P3) 7/8/2014 9:06 AM Page 5 of 137 0 • Trajectory:0107-SE4(P3)Vs.SPO4-8E5(P2) 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 Statrn (ft) (R) (6) (ft) (8) (ft) (ft) (ft) (') (ft) (9) (ft) 920000 4045.28 -1590 391860 10123.14 411815 990.28 465407 32.55 24845 199.63 1114.95 9.43 OSF1.50 Pass 9250.00 4043.82 -45.21 3959.09 10173.11 4118.35 960.79 469441 3247 248.30 201.34 111367 9.35 057 1.50 Pax 930000 4042.78 -74.49 3999.60 10213.10 4118.55 931.28 473475 32.34 248.11 202.98 1112.38 9.27 OSF 150 Pass 935003 404242 -103.74 4040.15 10273.09 4118.75 901.77 477511 32.30 247.82 204.83 111099 9.19 OSF1.50 Pees 9400.00 404211 -133.00 4080.70 10323.09 411894 872.26 481546 32.27 24752 206.31 1109.58 9.12 0571.50 Pass 9450.00 4041.80 -162.25 4121.25 10373.08 4119,14 842.75 4855.82 3225 24723 208.07 1108.11 9.04 OSF 1.50 Pea 9500.00 4041.50 -191.50 4161.80 10423.08 411934 813.23 4896.17 32.22 24693 209.83 1106.84 8.96 OSF 1.50 Pass 9550.00 4041.19 -220.75 420235 10473,08 4119.54 78372 4936.53 32.20 24664 211.60 1105.17 8.88 OSF 1.50 Pass 9600.00 4040.89 -250.00 4242.90 10523.07 4119.74 754,21 4976.89 3217 24635 21337 1103.69 8.80 OSF 150 Pass 9650.00 4040.58 -279.25 428345 10573.07 411994 724.70 5017.24 3215 246.05 215.14 1102.22 8.73 OSF 1.50 Pass 9700.00 4040.27 -308.50 4324.00 10623.07 4120.14 695,18 5057,60 32.13 ' 24576 21692 1100.74 8.65 OSF 1.50 Pass 975000 4039.97 -33775 436455 10673.06 4120,34 66567 5097.95 32.10 245.47 218.71 1099.25 8.58 OSF 1,50 Pass 9800.00 4039.66 -387.00 4405.10 10723.06 4120.54 636.16 5138.31 32.08 245.17 22050 1097.77 851 OSF 1.50 Pass 9850.00 403947 -396.21 444568 10773.06 4120.73 606.64 5178.67 31.99 244.83 222.22 1096.27 8.44 OSF 150 Pass 9900.00 403932 -425.41 448626 10823.05 4120.93 577.13 5219.02 31.98 244.47 223.95 1094.76 8.37 OSF1.50 Pass 9950,00 4039.16 -454.62 452685 10873.05 4121.13 547.62 5259.38 31.96 244.11 225.75 109320 8,30 OSF 1.50 Pass 000000 4039.00 -483.82 456743 1092305 4121.33 518.11 529974 31.94 243.75 227.56 109164 8.23 OSF 1.50 Pass 005000 4038.84 -51303 4608.02 10973.05 4121.53 488.59 534009 31.92 243.39 229.37 109007 8.17 OSF1.50 Pax 0100.00 4038.68 -542.23 4648.60 11023.04 4121.73 455.08 538045 31.01 243.03 231.18 1088.50 8.10 OSF 1.50 Pass 0150.00 4038.52 -571.44 4689.18 11073.04 4121.93 429.57 5420.81 31.89 24287 233.00 1086.93 8.03 OSF 1.50 Pass 0200.00 4038.36 -600.64 4729.77 11123.04 4122.13 400.05 5461.17 31.87 242.31 234.82 1085,36 7.97 OSF 1.50 Pax 0250.00 4038.28 -62964 4770.35 11173.03 4122.32 37054 550152 31.87 24195 23662 1083.80 7.91 OSF 1.50 Pax 0300.00 4038.93 -659.06 4810.93 11223.03 4122.52 341.03 5541.68 31.91 241.55 238.39 1082.22 7.84 OSF 1.50 Pax 0350.00 4040.45 -688.27 4851.47 11273.01 4122.72 311.53 5582,22 32.02 241.11 240.13 1060.62 7.78 OSF 1.50 Pass 0400.00 404229 -71750 489200 11322,98 4122.92 282.03 5622.56 32.09 24068 241.94 1078.97 7.72 OSF1,50 Pax 0450.00 4044.13 -746.73 4932.52 11372.96 4123.12 25253 5662.89 32.17 24025 243.83 1077.28 7.66 OSF 1.50 Pass 0500.00 4045.97 -775.96 4973.05 11422.93 4123.32 223.03 5703.23 32.24 239.82 245.73 1075.59 7.60 OSF 1.50 Pax 0550.00 4047.81 -80519 5013.57 11472.90 4123.52 193.53 5743.57 32.32 239.39 247.62 1073.90 7.54 OSF 1.50 Pass 0600.00 4049.65 -83443 5054.09 11522.87 4123.72 164.04 5783.90 32.39 238,97 249.52 1072.21 7.48 OSF 1.50 Pass 0650.00 4051.49 -883.66 5094.62 11572.84 4123.91 13454 5824.24 3247 238.54 251.43 1070.52 7.42 OSF 1.50 Pass 0700.00 4053.33 -89289 513514 11622.82 4124.11 10504 5864.58 3254 238.12 253,33 1068.83 7.36 OSF1.50 Pax 0750.00 405517 -922.12 5175.66 1167279 4124.31 7554 590491 32.62 237.70 255.24 1067.13 7.30 OSF 1.50 Pax 0800,00 4057.01 -95135 5216.19 11722.76 4124.51 4604 5945.25 3269 237.29 25715 106544 7.24 OSF 1.50 Pass 0850.00 4058.80 98058 525671 11772,73 4124.71 16.54 598559 3279 236.88 25907 1063.76 7.19 OSF 1,50 Pax 090000 4959.94 -1009.87 5297.22 11822.72 4124,91 -1296 8025.94 3289 236.56 260.97 1062.18 7.13 OSF 1.50 Pass 095000 4060.83 -1039.18 5337.71 1187272 4125.11 -42.48 6066.29 32.92 236.28 282.86 106063 7.08 OSF 150 Pass 1000,00 4061.72 -1088.49 5378.21 11922.71 4125.31 -71.99 6106.65 3295 236.00 264.76 1059.08 7.03 OSF 150 Pass 1050.00 4062.61 -109781 5418.71 1197271 4125.50 -101.50 8147.00 32.98 23571 266.66 1057.53 8.98 OSF 1.50 Pax 1100.90 4063.50 -1127.12 5459.21 12022,70 4125.70 -131.01 818736 33.01 235.43 268.56 1055.98 6.92 OSF 1.50 Pass 1150,00 4064.38 -1156.43 5499.71 1207170 4125,90 -160.52 6227.71 33.05 235.15 270.47 105443 6.87 057 1.50 Pass 120000 406527 -1185.74 5540.21 12122.69 4126.10 -190.03 6268.07 3308 234.87 272.38 105288 6.82 OSF1.50 Pass 1250.00 4066.16 -1215.05 5580,70 1217269 4126.30 -219.54 6308.42 33.11 234.59 274.29 1051.33 6.78 OSF 150 Pass 1300.00 406705 -1244.36 5621.20 12222.68 4126.50 -249.06 6348.77 33.14 234.31 276.20 1049.77 6.73 OSF 1.50 Pass 1350.00 4067.94 -1273.87 5661.70 1227267 412670 -278.57 6389.13 33.17 234.03 278.11 1048.21 6.68 OSF 1.50 Pass 1400.00 4068.79 -1302.96 570221 1232267 4128.90 -30808 6429.48 33.05 233.73 28003 1046.64 663 OSF1.50 Pax 1450.00 406946 -1332.16 574279 1237267 4127.10 -337.59 646984 33.07 233.33 281.94 104496 658 OSF 1.50 Pass 1500.00 4070.14 -138137 5783.37 12422.66 412729 -367.10 651020 33.09 232.92 28388 1043.28 6.54 OSF 150 Pass 1550.00 4070.82 -1390.57 582395 1247266 4127.49 -396.62 6550.55 33.11 232.52 285.77 104159 8.49 057150 Pass 1600.00 4071.50 -141977 5864.53 12522.65 4127.69 -426.13 659091 33.13 232.11 287.69 1039.91 645 OSF 150 Pass 180.00 407218 -1448.97 590511 1257265 4127.89 -455.64 663126 33.15 23171 289.62 1038.22 640 OSF 1.50 Pass 1700.00 407286 -1478.18 5945.69 12622.65 4128.09 -485.15 667152 33.18 231.31 291.54 103654 636 OSF 1.50 Pass 1750.00 4073.54 -150738 5988.27 1267264 4128.29 -514.67 6711.98 33.20 230.90 29317 103485 631 0971.50 Pass 1800.00 407422 -1536.58 6026.85 12722.64 4128.49 -544.18 6752,33 33.22 23050 295.39 1033.16 6.27 OSF 1.50 Pass 1850.00 4074.90 -1565.79 8067.43 12772.64 4128.69 -573.69 6792.69 33.24 230.10 297.32 103147 6.23 OSF1.50 Pax 1900.00 4075.50 -159499 6108.01 12822.63 412888 503.20 683304 33.27 229.70 299.25 1029.79 6.18 057 150 Pax 1950.00 4075.36 -1824.22 6148.58. 12872.63 412908 -632.72 6873.40 33.28 229.36 301.16 1028.18 6.14 0571.50 Pass 2000.00 4074.37 -1653.46 6189.12'• 12922.61 4129.28 662.22 6913.75 33.24 229.09 30305 1026.85 6.10 OSF 1.50 Pax 2050.00 4073.06 -1682.70 6229.66`. 12972.59 4129.48 -69172 695409 33.17 228.83 30493 102514 6.06 OSF 1.50 Pax 2100.00 4071.76 -1711.95 6270.1 e` 13022.57 4129.68 -721.22 6994.43 33.10 228.58 306.81 102363 6,02 OSF 150 Pass 2150.00 4070.45 -1741.18 63107$ 13072.54 412988 -750.72 7034.77 33.03 228.33 308.69 1022.13 5.99 OSF 1.50 Pax 2200.00 4059.15 -1770.44 6351.26. 1312252 4130.08 -780,22 7075.11 32.96 228.08 31057 1020,63 5.95 OSF 1.50 Pax 2250.00 4067.84 -1799.68 6391.80 13172.50 4130,28 -808.72 711545 32.88 227.83 312.45 1019.13 5.91 OSF1.50 Pax 2300.00 4066.54 -1828.92 643233 1322247 4130.48 -839.23 7155.78 32.81 22759 314.33 1017.63 5.88 OSF 150 Pax 2350.00 4065.23 -185817 647287 13272.45 413087 -888.73 7196.13 32.74 227.35 316.22 1016.13 5.84 OSF1.50 Pax 2400.00 4063.92 -1887.41 651340 13322.42 4130.87 -898,23 7236.47 3267 227.10 318,10 101453 5.80 OSF 1.50 Pass 2450.00 4062.92 -1916.66 6553.95 13372.41 4131.07 927.73 7276.81 32.62 226.85 31997 1013.17 5.77 OSF 1.50 Pax 2500.00 406270 -194591 659449 13422,40 4131.27 -95724 7317.17 32.60 228.55 321.69 1011.68 5,74 OSF 1,50 Pass 2550.00 4062.66 -197516 663505 1347240 413147 -966.76 7357.53 32.59 226.24 323.62 1010.08 5.70 OSF 1.50 Pass 2600.00 4062.61 -2004.41 667560 13522.40 4131.67 -1018.27 7397.88 3258 225.92 32554 1008,49 5.86 OSF 1.50 Pax 2650.00 4062.56 -2033.66 6718.15 13572.40 4131.87 -1045.78 7438.24 32.56 22561 327.47 1008.89 5.83 OSF1.50 Pass 2700.00 4062.51 -206291 675870 13822.40 4132,07 -1075.30 7478.80 32.55 225.30 329.41 1005.29 5.59 OSF 1.50 Pass 2750.00 4062.46 -2082.17 679725 13672.40 4132.26 -110481 7518.96 32.54 224.99 331.34 1003,69 5.56 OSF 1.50 Pax 2800.00 4062.42 -2121.42 6837.80 13722.39 413246 -1134.33 7559.31 32.53 224.68 333.27 1002.09 5.53 OSF 1.50 Pax 2850.00 4062.37 -2150.67 6878.35 13772.39 413266 -1163.84 7599.67 3251 224.37 335,21 1000.49 5.49 OSF 1.50 Pax 2900.00 406232 -2179.92 6918.90 13822.39 413286 -1193.35 764003 32,50 224.06 337.14 998.89 5.46 OSF 1.50 Pax 2950.00 4062.27 -2209.17 5959.45 1387239 4133.06 -122287 7680.39 32.49 223.75 339.08 997.29 5.43 OSF 1.50 Pax 3000.00 4062.14 -2238.44 6999.99 13922.39 4133.26 -1252.38 7720.75 3250 223.46 341.01 995.71 5.40 OSF 1.50 Pax 3050.00 4061.97 -2287.70 7040.53 1397239 4133.46 -1281.89 7761.10 32.48 223.18 34295 994.14 5.36 OSF 1.50 Pax 3100.00 4061.79 -2296.97 708107 14022.38 4133.66 -1311.41 7801.46 3246 22290 344.88 992.57 5.33 OSF 1.50 Pass 3150.00 4061 61 -232624 7121.60 14072.38 413385 -1340.92 7841.82 32.44 222.61 346.82 990.99 5.30 OSF 1.50 Pax 3200.00 4061.43 -2355.51 716214 14122.38 4134.05 -137043 7882.17 32.42 222.33 348.76 989.42 527 OSF 1.50 Pax 3250.00 4061.26 -238478 720268 14172.38 4134.25 -1399.95 792253 32,40 222.05 350.69 98785 5.24 OSF 1.50 Pax 3300,00 4061.08 -2414.05 724322 14222.37 413445 -1428.46 7962.89 3239 221.77 352.63 986.28 5.21 OSF 1.50 Pax 330.00 4060.90 -2443.32 7283.75 14272,37 4134.65 -1458.97 8003.24 3237 221.49 35457 964.70 5.18 OSF 1.50 Pets 3400.00 4060.73 -247259 732429 14322.37 4134.85 -148849 804300 32.35 22121 356.51 98313 5.15 OSF 1.50 Pax Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 6 of 137 • • Trajectory.S107-SE4(P3)Vs.SPO4-5E5(P2) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Sate (8) (8) (8) (5) (ft) (8) (8) (8) C) (ft) (6) (8) 1345000 4060.55 -2501.86 7364.83 1437237 413505 -1518.00 8083.96 3233 122093 358.46 981.55 5.12 OSF 1.50 Pass 1350000 4060.40 -2531.12 740537 14422.36 413525 -1547.51 8124.32 3230 1220.65 36037 979.99 509 OSF 1.50 Pass 13550.00 406099 -2560.38 744591 14472.36 4135.45 -157703 816467 32.31 - 1220.31 362.16 97847 5.07 OSF 150 Pass 13600.00 406206 -2589.62 7486.45 14522.35 413584 -1606.53 8205.02 32.38 121993 36403 976.83 5.64 060 1.50 Pass 13650.00 4063.28 -2618.86 7526.99 1457234 413584 -1636.04 8245.37 3240 1219.54 36602 97512 501 OSF 1.50 Pass 13700.00 4064.50 -2648.11 7567.53 14622.33 413604 -1965.55 828572 3245 1219.16 38802 973.40 4.98 OSF 1.50 Warning 13750.00 406572 -267735 7608.07 1467232 4138.24 -1895.00 8326.07 32.50 121877 37002 971.89 4.95 OSF 1.50 Warning 13800.00 4066.94 -2706.59 7648.61 14722.31 413644 -172457 8366.42 3254 121839 37201 96997 492 OSF 150 Warning 13850.00 4068.15 -273583 7689.15 14772.29 4136.64 -1754.07 840677 3259 1218.00 37401 968.25 4.90 OSF 1.50 blaming 13900.00 4069.37 -2765.08 7729.68 1482228 4136.84 -1783.58 8447.12 32.64 121762 37601 966.54 4.87 OSF 1.50 Naming 13950.00 4070.59 -279432 7770.22 14872.27 413704 -1813.09 848747 3269 1217.24 37801 96482 4.84 OSF 150 Wemirg 14000.00 4071.81 -2823.56 7810.78 14922.26 4137.23 -1842.60 8527.82 3273 121686 38002 96311 481 OSF 1.50 Wamirg 14050.00 4072.64 -285281 7851.31 14972.25 4137.43 -1872.11 8568.18 3276 121650 382.01 96142 479 OSF 1.50 blaming 14100.00 4072.76 -288206 7891.86 15022.25 413783 -1901.62 860853 3275 1216.18 383.97 95979 4.76 OSF 1.50 Warning 14150.00 4072.80 -291131 793241 15072.25 413783 -1931.14 8648.89 32.74 121587 385.93 958.17 474 OSF150 Warning 14200.00 4072.84 -294056 797296 15122.25 4138.03 -1960.95 8689.25 3273 1215.55 387.90 958.54 471 OSF 1.50 Warning 14250.00 407288 -2969.82 8013.51 1517225 4138.23 -1990.16 8729.61 32.72 1215.23 389.86 954.92 469 OSF 1.50 Warning 14300.00 407292 -299907 8054.06 15222.25 413843 -2019.68 8769.97 3272 121492 39183 953.29 466 OSF 1.50 Warning 14350.00 4072.96 -302832 809461 15272.25 4138.63 -2049.19 8810.32 3271 1214.60 383.79 951.67 464 OSF 1.50 Warning 14400.00 4073.00 -305757 8135.16 15322.24 4138.83 -2078.70 8850.68 32.70 1214.29 395.76 950.04 4.81 OSF 1.50 Warning 14450.00 407304 -308682 8175.71 15372.24 4139.02 -2108.22 8891.04 32.69 1213.97 39773 946.41 4.59 OSF 150 blaming 14500.00 407308 -311608 8216.26 15422.24 4139.22 -213773 8931.40 3268 1213.65 39969 946.78 456 OSF 150 Warning 14550.00 4073.16 -3145.33 8256.81 15472.24 4139.42 -2167.25 8971.76 3264 1213.33 40163 945.17 454 OSF 150 blaming 14800.00 4073.53 -317453 8297.39 15522.24 4139.62 -2196.76 901211 32.62 121294 403.51 943.53 4.52 OSF 1.50 Warning 14850.00 4073.92 -320374 8337.97 15572.24 413982 -2226.27 9052.47 3263 1212.55 40549 841.82 449 OSF 1.50 Warning 1470000 4074.30 -323294 8378.56 15622.24 4140.02 -2255.79 9092.83 32.64 121216 407.48 940.10 4.47 OSF 1.50 Warning 14750.00 4074.68 -3262.15 8419.14 15872.23 4140.22 -2285.30 9133.19 3284 1211.77 409.46 938.39 4.45 OSF 1.50 Warning 14800.00 407507 -329135 8459.72 15722.23 4140.42 -2314.81 9173.54 3265 121138 411.45 936.67 4.43 OSF 1.50 Warning 14850.00 407545 -3320.56 8500.30 15772.23 4140.62 -2344.33 9213.90 3266 1210.99 413.43 93496 4.40 OSF 1.50 Warning 14900.00 4075.84 -3349.76 8540.89 15922.23 4140.81 -2373.84 9254.26 32.67 1210.60 41542 93325 438 OSF 1.50 Warning 14950.00 4076.22 -3378.97 8581.47 15872.23 4141.01 -2403.35 9294.82 3268 121021 41740 931.53 4.36 OSF 1.50 Warning 15000.00 407680 -3408.17 8622.05 15922.22 414121 -243287 933497 32.68 1209.82 419.39 929.81 4.34 OSF 150 Warning 15050.00 407699 -343738 866263 15972.22 4141.41 -2482.38 9375.33 32.69 120943 421.38 928.10 4.31 0901.50 Warning 15100.00 4077.00 -3466.60 8703.20 16022.22 414161 -2491.89 941599 3271 1209.08 423.35 926.43 4.29 0601.50 Warning 15150.00 407614 -349584 8743.75 16072.21 414181 -2521.40 945604 32.88 120880 425.29 924.88 4.27 OSF 1.50 Naming 15200.00 4074.70 -3525.08 8784.29 16122.18 4112.01 -2550.90 9496.37 32.61 1208.58 427.21 923.35 4.25 OSF 1.50 blaming 15250.00 4073.24 -355432 8824.82 16172.15 4142.21 -2580.40 9538.71 32.53 1208.33 429.12 921.84 4.23 OSF 1.50 Naming 1530000 1071.79 -3583.56 886535 16222.12 414240 -2609.90 957705 32.45 1208.11 431.04 92034 4.21 OSF 1.50 Warning 15350.00 407033 -3612.83 8905.88 16272.09 4142.60 -2639.39 9617.38 3237 1207.88 432.95 918.84 4.19 OSF 1.50 Wamirg 1540000 4068.88 -3642.04 894642 1632207 4142.80 -2868.89 9657.72 32.29 1207.68 434.86 917.34 417 0601.50 Naming 15450.00 406742 -367128 8986.95 1637201 4143.00 -2698.39 9699.05 32.21 1207.44 43618 915.85 4.15 0501.50 VVaming 1550000 4065.97 -3700.52 802748 1642201 4143.20 -2727.89 9738.39 32.13 1207.22 438.69 91435 414 OSF 1.50 Naming 15550.00 4064.51 -3729.76 906801 1647198 4143.40 -2757.38 9778.73 3205 1207.00 440.60 912.86 412 OSF 1.50 Warning 15800.00 4063.14 -375901 910854 16521.96 414380 -2788.88 981906 32.02 1208.79 44247 91140 4.10 OSF 1.50 Wamirg 15850.00 406235 -3788.31 914905 1657194 4143.80 -281639 985941 3201 1206.59 444.27 910.00 4.08 OSP 1.50 Warning 15700.00 4061.85 -381761 918956 1662194 4143.99 -2845.90 9899.77 31.96 1206.40 448.12 908.57 4.06 OSF1.50 Naming 15750.00 4060.94 -3846.91 9230.07 16671.93 4144.19 -2875.41 9940.12 31.92 1206.20 448.07 907.08 404 OSF 1.50 Warning 15000.00 4060.24 -3876.22 9270.57 16721.92 4144.39 -290492 998047 31.88 120601 450.01 905.59 403 0601.50 Naming 15850.00 405953 -380552 9311.08 1677191 4144.59 -293443 1002082 31.83 1205.81 45196 904.10 401 OSF 1.50 Naming 15900.00 4058.83 -3934.82 935159 18821.80 414479 -2963.94 10061.17 31.79 1205.62 453.90 90261 3.99 OSF 1.50 blaming 15950.00 4058.12 -396412 939210 16871.89 4144.99 -2993.45 1010153 31.75 1205.42 455.84 901.12 3.97 OSF 1.50 Warning 16000.00 405741 -3993.43 9432.60 16921.88 4145.19 -3022.96 10141.88 3170 1205.23 457.79 899.63 396 060150 Warning 16050.00 4056.71 -4022.73 9473.11 16971.87 4145.39 -3052.47 10182.23 3166 1205.04 45973 898.14 3.94 OSF 1.50 Warning 16100.00 4058.00 -4052.03 9513.62 17021.87 4145.58 -3081.98 10222.58 31.:1441.1 461.67 3.92 OSF 1.50 Warning 16128.61 4055.60 -406880 9536.80 17050.47 4145.70 -3098.86 10245.67 31. 46279M OSF 1.50 Naming End of mains Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 7 of 137 . Field: Nike&hug Well: SI14-N6 Structure: Spy Island Borehole: 5114-N6 Slot SP14 Trajectory: 5114-N6 Client: Eni Petroleum Type: Del Survey Coordinate System: NA027 Alaska State Plane,Zone 04,US Feel North Reference: True Grid Convergence Angle: 008982660' Grld Scale Factor: 0.999900153 Magnetic Declination: 15.561° Magnetic Declination Date: December 19,2013 Magnetic Model: BGGM 2013 Reference Point North�in Mao Eleva6an Structure One. Slot Une 6053646 720(OUST 511614.150(IIUS) 53.930(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Trajectory Error Model:ISCWSAO 343 95.000%Confidence 2.7955 sigma Survevina Proa'As Drilled Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Note Olee(9r) Casing Diameter(In) Borehole I Survey 0.000 40830 Act-Stns SLB NSG+SSHOT-Depth Only-No Globe 16.000 13.375 0114-N6/0114-N6 40.830 920,910 Act-Stns SLB_NSG+SSHOT-No Gioba 16.000 13.375 5114-N6/SI14-N6 920.910 2614360 ActStns SLB_MWD+GMAG-No Globe 16.000 13.375 6114-N6/S111-N6 2614.360 2711.740 Act-Stns SLB MWD-INC_ONLV_FILLER-No Globe 12.250 9.625 5114-N8 1 5114-N6 2711.740 6999930 Act-Stns SLB MWD+GMAG-No Globe 12,250 9825 5114-N6/5114-N6 6989.930 14701520 Act-Stns SLB_MWD+GMAG-No Globe 8.750 5.500 0114-N6/SI14-N6 14701.520 14770000 Act-Stns SLB BLIND+TREND-No Globe 8.750 5,500 5114-N6/S114-N6 Minimum • Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azlm Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (0) (a) (ft) (S) (a) (5) (ft) (ft) 1°) (5) (ft) (ft) NI local minima indicated. Results filtered:Depth 6100.00 ft vee MD ve 16128.61 ft Results filtered:Ct-Ct separation a 1500.00 ft Results highlighted:Ct-Ct seperehon<=1320.00 ft 6100.00 4028.97 1797.48 1405.89 6102.94 396301 1774.39 34708 157.95 9133 56.20 53.51 2.46 OSF 1.50 Warning 6150.00 4031.82 1772.50 1449.10 8063.67 3958.09 174001 36543 185.32 116.16 60.66 75.36 290 OSF 1.50 blaming 6200.00 4034.07 1746.44 1491.71 602524 3953.29 1705.82 382.29 172.45 14194 83.58 9920 338 OSF 1.50 W8rning 6250.00 4035.84 1718.95 1533.44 5987.08 3948.53 167137 39789 ' 17813 16803 65.58 123.95 3.88 OSF 110 Warning 6300.00 4037.11 169007 1574,23 594152 3943.67 1638.19 41302 182.88 19397 66.88 14902 4.40 OSF1.50 Warning I 6350.00 4037.89 1659.86 1614.06 5910.15 3938.75 1600.88 427.22 186.61 219.58 67.93 173.91 4.90 OSF 1.50 Warning 6400.00 4038.51 1829.18 1653.54 587298 3933.75 1568.45 440.28 188.09 24575 68.78 19954 5.42 OSF 1.50 Pass 6450.00 4039.13 1598.51 1693.02 5838.83 3928.41 153279 452.36 189.24 27294 8956 228.20 5.95 OSF 1.50 Pass 8500.00 4039.74 156183 1732.50 580196 3922.84 1500.20 46341 190.13 301.08 70.18 25393 6.51 OSF 1.50 Pass 6550.00 4040.36 1537.15 1771.98 5768.82 3917.38 1469.02 473.19 190.90 33021 70.88 282.60 707 OSF 1.50 Pass 8000.00 4040.97 1506.48 1811.46 5738.83 3912.03 1438.70 48191 191.57 36031 71.49 312.29 7.65 OSF 1.50 Pass 6650.00 4041.54 1475.99 1851.08 5704.91 3906.62 1408.28 489,93 190.87 391.43 72.17 34296 8.23 OSF 1.50 Pass 6700.00 4041.70 1448.54 1891.49 567317 3901.05 1377.95 49744 189.70 423.98 72.93 37500 883 OSF 1.50 Pass 6750.00 4041.78 1417.29 1932.04 5642.32 3895.47 1348.41 504.34 190.33 45725 7375 407.73 9.41 OSF 1.50 Pass 6800.00 4041.86 1388.04 197259 5613.82 389016 1321.06 51033 190.84 491.09 7448 441.10 10.01 OSF 150 Pass 6850.00 4041.93 1358.78 2013.13 5587.95 3885.22 1296.15 515.29 191.27 525.67 75.18 475.19 10.82 OSF 1.50 Pass 6900.00 4042.01 1329.53 2053.68 5563.05 3880.38 127210 519.59 191.65 560.96 75.84 510.05 11.23 OSF 1.50 Pass 6950.00 404209 1300.28 2094.23 5539.08 3875.62 1248.91 523.30 191.99 596.92 78.53 545.55 11.84 OSF 150 Pass 7000.00 4042.16 1271.02 213478 5514.43 3870.64 1225.01 526.69 192.32 633.49 7724 581.64 12.45 OSF 150 Pass 7050.00 4042.24 124177 217533 5490.04 3865.63 1201.33 529.72 192.62 67055 78,01 818.19 1305 OSF 1.50 Pass 7100.00 4042.32 121252 2215.88 5466.38 3860.70 1178.34 532.35 192.89 70808 78.74 655.23 13.65 OSF 150 Pass 7150.00 4042.44 118326 225643 5443.44 3855.84 1156.04 534.60 193.49 746.06 7947 692.73 14.25 OSF1.50 Pass 7200.00 404324 1154.01 229897 5423.21 3851.50 1136.34 536.31 191.77 784.65 8006 73092 14.88 OSF 1.50 Pass 7250.00 4044.63 1124.77 2337.51 5404.14 3847.37 1117.78 537.64 195.19 823.88 80.63 769.76 15.51 OSF 1.50 Pass 7300.00 4048.15 1095.54 2378.04 5385.78 3843.36 1089.89 538.65 195.28 863.55 8119 809.07 16.15 OSF 1.50 Pass 7350.00 4047.63 1066.30 2418.57 5388.10 3839.47 1082.66 539.37 195.38 903.65 81.80 848.77 16.77 OSF 1.50 Pass 7400.00 4049.10 103706 2459.11 5351.05 3835.68 1086.04 539.85 195.45 940.15 8237 888.89 17.40 OSF 150 Pass 7450.00 4050.58 1007.82 249964 5333.37 3831.74 1048.80 540.11 195.53 985.02 83.03 929.32 18.01 OSF 1.50 Pass 7500.00 4052.05 978.58 254017 5315.78 3827.83 1031.66 540.17 195.62 1026.20 8368 970.06 18.61 OSF 1.50 Pass 755000 4053.53 94934 258070 5298.74 382406 101504 540.04 195.70 1067.68 6543 1023.71 24.86 OSF 1.50 Pass 7660.00 4055.00 92010 262124 5282.22 3820.42 98693 539.74 195.78 110845 6546 1065.45 25.82 OSF 1.50 Pass 765000 4056.47 890.86 2661.77 5266.20 3816.89 983.31 539.29 195.87 1151.48 65.50 1107.46 26.78 OSF 1.50 Pass 770000 4057.80 861.62 2702.31 5250.73 3813.51 968.23 538.70 195.09 1193.75 65.53 1149.70 27.75 OSF 1.50 Pass 775000 4058.33 832.37 2742.85 5238.11 3810.31 953.98 537.99 193.72 123812 65.54 1192.07 28.73 OSF 1.50 Pass 7800.00 4058.41 80312 2783.40 5221.89 380721 940.12 537.16 193.82 1278.67 65.56 1234.60 29.71 OSF 1.50 Past 7850.00 405848 773.87 282395 5208,10 3804.20 926,70 536.23 19394 1321,46 6558 1277.38 30.70 OSF1.50 Pass 7900.00 4058.56 744.62 286450 519473 3801,29 913,69 535,20 19406 1364.49 8561 1320,39 31.68 OSF1.50 Pass 7950.00 4058.63 71537 290506 518176 3798.46 901.09 534.08 191.17 1407.75 6564 1383.63 3267 OSF 1.50 Pass 8000,00 405871 686.11 294561 5169.18 3795.73 88888 532,89 194.28 1451.22 6567 1407.08 33.67 OSF1.50 Pass 8050.00 4058.78 858,86 298616 5157.03 3793.09 87707 531.64 194.39 149489 6570 1450.73 3467 OSF 1.50 Pass 8100.00 4058.86 627.61 302671 5145.41 3790.55 865.80 530.35 194,49 1538.77 6573 1494.59 35.67 OSF 1.50 Pass 8150.00 405893 59836 3067.26 5134.12 378806 854.88 529.01 191.58 1582.84 6577 1538.63 36.67 OSF 1.50 Pass 8200,00 4059.01 569.11 3107.81 5123.16 378563 844.28 527,63 19466 1627.09 65.80 1582.86 37.68 OSF 1,50 Pass 625000 405903 539.87 3148,37 511252 3783.25 834.00 526.21 194.34 167112 85.84 162727 38.88 OSF 1.50 Pass 8300.00 4058.96 510.67 3188.95 5102.18 3780.92 824.03 524,76 194.42 1716.11 65.87 1671.84 39.70 OSF 1.50 Pass 8350.00 4058.90 481.47 3229.54 5092.12 3778.64 814.35 523.28 194.50 1760.87 6591 1716.57 40.71 OSF 1.50 Pass 8400.00 4058.84 452.26 3270.12 5082.34 3776.40 801.95 521.78 194.57 1805.78 65.95 1761.46 41.72 OSF 1.50 Pass 8450.00 4058.77 423.06 3310.71 5072.83 3774.22 795.82 520.26 194.64 1850.85 65.99 1806.49 42.74 OSF 1.50 Pass 8500.00 4058.71 393.85 3351.29 5063.66 3772.08 787.02 518.74 194.71 188605 6604 1851.67 43.75 OSF1.50 Pass 8550.00 4058.64 36465 3391,88 5054.89 3770.06 778.63 517.23 194.77 1941,39 66.11 1896.96 4475 OSF1.50 Pass 8600.00 4058.58 335.45 3432.46 5046.37 3768.09 770.48 515.70 190.83 1986.86 66.18 1942.39 45.75 OSF 1.50 Pass 8850,00 4058.51 30624 3473.05 5038.08 3766.17 762,56 514.17 194.89 203246 66.24 1987.94 46,75 OSF 1,50 Pass 8700.00 4058.45 27704 3513.83 5030.01 3764.31 75486 512.63 190.94 2078.19 66.31 2033.62 4776 OSF 1.50 Pass 8750.00 4058.13 247.82 3554.20 50.12.11 3762.48 74734 511.08 193.50 2123.98 68.38 2079.37 48.76 OSF 1.50 Pass 880000 4056.98 218.54 3594.72 5014.33 3760.68 739.93 509.50 192.01 2169.74 66.45 2125.08 49.76 OSF 1.50 Pass 8850.00 4055.51 18923 3635/0 5006.71 3758.92 73269 507.92 192.09 2215.54 66.52 2170.84 5075 OSF 1.50 Pass 8900.00 4054.05 159.93 367569 4999.28 375721 725.63 506.34 192.16 226117 66.59 2216,71 51,74 OSF 1,50 Pass 8950.00 4052.59 13062 3716.17 4992.03 3755.53 718.77 504.75 192.24 2307.49 66.67 2262.69 5274 OSF 1.50 Pass 9000.00 4051.13 101.32 3756.66 4984.97 3753.91 712.08 503.18 192.31 2353.63 66.74 2308.78. 53.74 OSF 1.50 Pass 9050.00 4049.67 72.01 3797.15 497809 3752,32 705.57 50160 192.38 2399.86 66.81 2354.97 54.73 OSF 1,50 Pass Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 8 of 137 0 0 Field: Nikeifchuq Wel: 5P08-147 Structure: Spy Island Borehole: SP084,17 Slot SPO8 Trajectory. SPOB-N7 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grld Convergence Angle: 0.09030636° Grid Seale Factor: 0.999900155 Magnetic Declination: 19.681° Magnetic Declination Date: October 03,2013 Magnetic Model: BGGM 2013 Reference Point Northing Eastino levati on Structure UD4. 11121 221. 6053658 800(SUS) 511676 160(SUS) 53 930(ft)MSL 0.000(ft)(1 sigma) 0.000(B)(1 t4grrla) Traiectory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Surveying Pros:As Drilled Description MD Front Ott MD To(ft) EOU Freq Survey Tool Type Hole Sloe(In) Casing Diameter en) Borehole/Survey 0.000 40.830 Act-Stns SLB_NSG+S SHOT-Depth Only-No Global 16.000 13.375 SP08-N7/SP08-N7 40.830 579.980 Act-Stns SLB NSG+SSHOT-No Globe 16.000 13.375 5P08-N7/SP08-N7 579.980 2609.640 AclSlot SLB_MWD+GMAG-No Globa 16.000 13.375 SPO8-N7/SP08-N7 2809.840 2703.480 Act-Stns SLB MWD-INC ONLY FILLER-NO Globa 12.250 9.625 SPO8-N7/SPO8-N7 2703.480 8000.950 Act-Sins SLB_MWD+GMAG-No Globe 12.250 9.625 SP08-N7/SP08-N7 8000.950 15804.570 Ace-Stns SLB_MWD+GMAG-No Globe 8.750 5.500 SP08-N7/SP08-N7 15804.570 15870.000 Act-Stns SLB BLIND+TREND-No Globe 8.750 5.500 SP08-1,17/5P08-N7 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference ND Reference NS Reference EW Offset MD Offset NO Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (6) (ft) (8) (0) (ft) (h) (9) (') (ft) (9) (0) Al local minima indicated. Resuls filtered:Depth 6100.00 fl cc MD c 16128.61 8 Resuls filtered:Ct-Ct separation e=1500.00 S Results highlighted:Ct-Ct separation eo 1320.00 ft 6100.00 4028.97 179748 1405.89 6619.68 3848.01 2167.80 236078 45.74 104005 80.35 986.13 19.66 OSF 1.50 Pass 6150.00 4031.82 1772.50 1449.10 6580.96 3841.53 2131.80 237348 46.31 100984 8034 955.92 19.09 OSF 1.50 Pass 6200.00 4034.07 1746.44 1491.71 6542.41 383487 2095.96 2386.01 4840 98082 80.27 928.76 18.55 OSF 1.50 Pass 6250.00 4035.84 1718.95 1533.44 650039 3827.48 2059.74 2398.51 50.57 952.84 80.37 898.90 18.00 OSF 1.50 Pass 630000 4037.11 1690.07 157423 6454.45 3817.41 2014.35 2413.79 53.10 926.43 80.14 872.66 1755 OSF 1.50 Pass 6350.00 4037.89 1659.86 1614.06 6396.32 3805.11 1960.16 2430.85 55.75 900.84 79.75 847.32 17.15 OSF 150 Pass 6400.00 4038.51 1629.18 1853.54 6333.13 379125 1900.88 244777 5767 875.07 79.27 821.87 16.76 OSF 1.50 Pass 6450.00 4039.13 1598.51 1613.02 6239.28 3769.87 1811.93 2488.65 6097 848.32 7777 796.121 (§ OSF 1.50 Pass 5000 65 . 4039.74 1567.83 173250 605915 3731.09 1637.68 2489.05 69.21 817.31 72.83 768.40 { OSF 1.50 Pass 6550.00 4040.36 1537.15 1771.98 5969.20 3711.86 1549.41 2482.38 74.81 782.77 7085 73518 16.80 OSF 150 Pass 6600.00 404097 150648 181146 5909.59 3700.22 1481.24 2476.48 79.10 747.39 6166 700.60 16.32 OSF 1.50 Pass 665000 4041.54 1475.99 185108 5887.87 3692.36 1450.75 2470.96 81.99 711.91 68.91 665.61 15.72 OSF 1.50 Pass 6700.00 404170 1448.54 1891.49 5831.68 3885.56 1415.56 2485.27 84.78 676.04 68.16 630.24 15.09 OSF 1.50 Pass 6750.00 4041.78 1417.29 193204 5798.64 3679.33 138368 2459.32 88.05 640.72 67.43 595.41 14.46 OSF 1.50 Pam 6800.00 4041.86 138804 197259 5768.95 3673.62 135516 2453.28 91.20 606.42 66.61 561.66 13.85 OSF 150 Pass 8850.00 4041.93 135878 2013.13 5742.17 3668.38 132960 2447.28 94.19 573.48 6574 529.29 13.28 OSF 1.50 Pass 69100 4042.01 1329.53 2053.68 5718.69 3663.76 1307.28 2441.65 96.92 54230 64.85 49871 12.73 OSF 1.50 Pass 695000 4042.08 130028 2094.23 5896.56 365947 1286.28 2436.13 99.58 513.31 63.80 47042 12.25 OSF1.50 Pass 7000.00 4042.16 1271.02 2134.78 5675.41 3655.45 1266.24 2430.68 102.19 486.96 6249 444.94 11.87 OSF 1.50 Pass 7050.00 4042.24 1241.77 2175.33 5855.18 3651.66 1247.11 2425.30 10474 463.75 6094 422.76 11.59 OSF 1.50 Pass 7100.00 4042.32 1212.52 2215.88 5836.36 3648.19 1229.34 2420.15 107.15 444.24 59.22 404.40 11.43 OSF 1.50 Pass 7133.58 4042.37 1192.87 224311 562444 364601 1218.10 2416.85 106.69 43350 58.50 394471 OSF 1.50 Pass 7150.00 404244 1183.28 2258.43 561868 3644.96 1212.67 2415.24 109.47 429.04 57.38 39043 OSF 1.50 Pass 7200.00 4043.24 115401 2296.97 560153 364186 1196.51 2410.41 111.76 419.26 55.42 381.95 11.54 OSF 1.50 Pass 7250.00 4044.68 1124.77 233751 556489 363888 1180.84 240585 113. 53.5 �'EY31 11.83 OSF 1.50 Pass 7300.00 4046.15 1095.54 2378.04 556861 363599 1165.53 2400.94 116.010 52.02 12.24 OSF 1.50 Pass 7350.00 4047.63 1066.30 2418.57 555268 363319 1150.56 239828 118.17 423.50 50.96 389.17 12.70 OSF 1.50 Pass 7400.00 4049.10 103706 2459.11 553836 383068 1137.12 239202 120.04 435.42 50.61 401.33 13.15 OSF 1.50 Pass 7450.00 4050.58 1007.82 2499.64 5524.64 362825 1124.27 2387.88 121.82 452.12 50.76 417.92 13.61 OSF 1.50 Pass 7500.00 4052.05 978.58 2540.17 5511.40 3625.90 1111.89 2383.80 123.54 473.11 51.30 438.55 14.09 OSF 1.50 Pass 7550.00 4053.53 949.34 2580.70 5498.61 3823.61 1089.96 2378.81 125.18 497.87 51 96 482.87 14.64 OSF 1.50 Pass 7600.00 4055.00 920.10 2621.24 5488.25 3621.38 1088.45 2375.89 128.75 52589 52.93 490.25 15.18 OSF 150 Pass 7650.01 4056.47 890.86 266177 547430 3619.22 1077.34 2372.05 128.25 556.69 53.88 520.42 1578 OSF 1.50 Pass 7700.00 4057.87 86162 2702.31 5462.71 3617.11 1066.59 2388.28 129.66 589.74 5475 562.89 16.45 OSF 1.50 Pass 7750.00 4058.33 83237 2742.85 5451.97 3615.14 1056.65 236473 130.89 624.25 55.59 586.83 17.14 OSF 1.50 Pass 7800.00 4058.41 803.12 2783.40 5442.04 3513.31 1047.47 2361.39 132.06 660.24 5638 62229 17.87 OSF 1.50 Pass 7850.50 4058.48 77387 282395 5432.55 3611.56 1038.73 235814 133.18 697.76 5709 659.35 18.65 OSF 1.50 Pass 7900.00 4058.56 744.62 2864.50 5423.49 3809.87 1030.41 2354.99 13423 736.61 5772 697.78 19.48 OSF 1.50 Pass 7950.00 4058.63 71537 290506 5414.83 3608.25 1022.46 2351.93 135.22 776.59 5827 737.39 20.34 OSF 1.50 Pass 8000.00 4058.71 68811 294561 5406.53 3606.70 101498 2348.96 136.16 817.55 58.76 778.03 21.23 OSF 1.50 Pass 8050.30 4058.78 656.86 298616 5398.58 360520 1007.63 2346.07 137.05 859.35 59.18 819.54 22.15 OSF 110 Pass 8100.00 4058.86 627.61 3026.71 5390.97 380376 1000.69 2343.27 137.90 90188 59.56 861.82 23.10 OSF 1.50 Pass 815000 4058.93 59836 306726 5383.65 3602.37 99405 2340.54 138.70 945.06 59.89 904.77 2407 OSF 1.50 Pass 8200.00 4059.01 569.11 310781 5376.63 3601.03 987.68 2337.90 139.46 988.79 60.19 948.31 25.06 OSF 1.50 Pass 8250.00 4059.03 539.87 3148.37 538989 3599.74 981.58 2335.33 13992 1033.00 60.45 99234 26.07 OSF 1.50 Pass 8300.00 4058.96 51067 3188.95 5363.32 359848 97565 2332.81 140.61 1077.61 60.68 103880 27.09 OSF 1.50 Pass 8350.00 4058.90 491.47 3229.54 5356.58 3597.18 969.57 2330.19 141.32 1122.62 60.88 108187 28.13 OSF 1.50 Pass 8400.00 4058.84 45226 3270.12 535004 359590 963.69 2327.84 141.99 1167.97 61.05 1126.91 29.18 OSF 1.50 Pass 8450.00 4058.77 423.06 3310.71 534369 3594.66 957.99 2325.14 142.64 1213.63 6121 1172.47 30.24 OSF 1.50 Pass 8500.00 4058.71 393.85 3351.29 5337.52 359345 95246 2322.70 143.26 125957 61.35 1218.32 31.32 OSF1.50 Pam 8550.00 4058.64 364.85 3391.88 5331.53 3592.26 947.09 2320.31 143.86 1305.76 61.47 126442 3240 OSF 1.50 Pam 860000 4058.58 335.45 3432.48 5325.71 3591.10 941.89 2317.97 144.43 1352.18 61.58 1310.77 33.49 OSF 1.50 Pam 8850.00 4058.51 308.24 3473.05 5320.05 3589.97 936.83 2315.89 144.96 1398.81 61.61 1357.33 34.59 OSF 1.50 Pam 8700.00 4058.45 277.04 3513.83 5314.54 3588.86 931.92 2313.45 145.51 1445.62 61.78 1404.08 35.61 OSF 1.50 Pam 8750.00 4058.13 247.82 3554.20 5309.15 3587.77 927.12 2311.25 145.66 1492.52 61.86 1450.93 36.80 OSF 1.50 Pam 8800.00 4058.98 218.54 3594.72 5303.75 3586.67 822.33 2309.04 145.62 1539.31 61.94 1497.68 3791 OSF1.50 Pam 8850.00 4055.51 189.23 3635.20 529845 3585.58 917.82 2308.85 148.08 1588.16 62.02 1544.46 39.01 OSF 1.50 Pam 8900.00 4054.05 159.93 3875.69 5293.28 3584.52 913.04 2304.71 146.53 1633.17 82.08 1591.42 40.12 OSF 1.50 Pam 8950.00 4052.59 130.62 3718.17 528825 3583.48 908.58 2302.81 146.96 1680.32 82.15 1838.53 41.24 OSF 1.50 Pam 9000.00 4051.13 101.32 3756.66 5283.34 3582.48 904.24 2300.55 147.38 1727.60 62.21 1685.77 42.38 059 1.50 Pass Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\S107-SE4\SI07-SE4\5107-SE4(P3) 7/8/2014 9:06 AM Page 10 of 137 • • Trajectory:SI07-S64(P3)W.SPO8-N7 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference ND Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (N) (ft) (6) (ft) (ft) (6) (5) (ft) (°) (ft) (6) (ft) 9050.00 4049.67 72.01 3797.15 5278.55 358146 900.02 2298.53 147.78 1775.01 62.26 1733.14 43.48 OSF 1.50 Pass 9100.00 4048.21 42.71 3837.63 5273.88 358049 895.90 229656 148.17 1822.53 62.31 1780.63 44.61 OSF 1.50 Pass 9150.00 4046.74 13.40 387812 5269.54 357957 89207 2294.71 148.53 1870.16 6237 1828.22 45.74 OSF1.50 Pass 9200.00 4045.28 -15.90 3918.60 5265.50 357875 88862 2293.03 148.86 1917.88 6243 1875.92 48.86 OSF 1.50 Pass 9250.00 4043.82 -45.21 3959.09 5261.78 3577.94 885.26 2291.39 149.17 1985.72 62.49 192370 4798 OSF 1.50 Pass 9300.03 4042.78 -74.49 3999.60 5258.12 3577.17 882.05 2289.81 150.55 2013.74 6253 1971.70 49.12 OSF 1.50 Pass 9350.00 4042.42 -103.74 4040.15 5254.64 3576.43 879.00 228829 151.28 2062.02 82.57 2019.95 50.26 OSF 1.50 Pass 9400.00 4042.11 -133.00 4080.70 5251.25 3575.71 876.04 2286.82 151.56 2110.37 62.81 2068.27 51.41 OSF 1.50 Pass 9450.00 4041.80 -182.25 4121.25 5247.96 3575.02 873.16 2285.38 151.84 2158.79 62.66 2116.66 52.55 OSF 1.50 Pass 9500.00 4041.50 -191.50 4161.80 5244.76 3574.34 870.37 228397 152.10 2207.27 6271 2155.11 53.69 OSF1.50 Pass 9550.00 4041.19 -220.75 4202.35 5241.64 3573.68 867.65 2282.60 152.36 2255.80 62.75 221361 54.83 OSF 1.50 Pass 9600.00 4040.89 -250.00 4242.90 5238.60 3573.03 885.00 2281.25 152.61 2304.38 62.79 2281.17 55.98 OSF 1.50 Pass 9650.00 4040.58 -279.25 428345 5235.64 357240 862.42 2279.93 152.85 2353.02 62.83 2310.77 57.12 OSF 1.50 Pass 970000 4040.27 -308.50 4324.00 5232.75 3571.79 859.91 2278.64 153.08 2401.70 62.87 2359.43 5827 OSF 1.50 Pass 9750.00 4039.97 -337.75 4364.55 5229.94 3571.19 857.47 2277.38 153.31 2450.42 62.91 2408.13 59.41 OSF 1.50 Pass 980000 4039.66 -367.00 4405.10 5227.19 3570.80 85509 2276.14 153.53 2499.19 62.94 2456.88 6056 OSF1.50 Pass 9850.00 403947 -396.21 4445.68 5224.54 357003 85279 2274.95 153.76 2548.03 62.97 2505.69 61.72 OSF 1.50 Pass 9900.00 4039.32 -425.41 4486.28 522195 3569.48 85055 2273.78 153.97 2596.91 83.00 255455 6287 OSF 1.50 Pass 9950.00 403916 -454.82 4528.85 5219.43 3568.94 848.37 2272.63 154.17 2645.82 63.03 260344 64.02 OSF 1.50 Pass 0000.00 4039.00 -483.62 4587.43 5216.97 3568.42 846.24 2271.51 154.36 2694.77 63.07 265237 65.17 OSF 1.50 Pass 0050.00 4038.84 -513.03 4608.02 5214.56 3567.90 844.17 2270.41 154.55 2743.75 63.10 270133 66.32 OSF 1.50 Pass 0100.0D 403868 -542.23 4848.80 5212.21 356740 842.14 2269.33 154.73 2792.76 63.13 2750.32 67.47 OSF1.50 Pass 0150.00 403852 -57144 4689.18 5209.91 3566.90 840.16 2268.28 154.91 2841.80 63.16 2799.34 68.63 OSF 1.50 Pass 0200.00 4038.38 -60064 4729.77 5207.67 3566.42 838.23 2267.24 155.08 2890.87 63.19 2848.39 6978 OSF1.50 Pass 0250.00 4038.28 -62984 4770.35 5205.48 356595 836.34 2266.23 156.43 2939.97 63.22 289747 70.93 OSF1.50 Pass 0300.0D 4038.93 -659.06 4810.93 5203.39 356550 834.54 2285.26 15971 2989.22 63.24 294670 72.09 OSF 1.50 Pass 0350.00 4040.45 -68827 4851.47 5201.40 3565.07 83284 2264.33 163.26 3038.59 63.26 2996.06 7328 OSF 1.50 Pass 0400.00 4042.29 -717.50 4892.00 5199.46 3564.66 831.18 2283.43 163.43 3088.02 63.29 3045.48 74.42 OSF 1.50 Pass 0450.00 4044.13 -746.73 4932.52 519757 3564.25 829.55 2262.55 163.58 3137.47 83.31 3094.91 7558 OSF1.50 Pass 5500.00 4045.97 -775.96 4973.05 519572 3563.85 827.97 2261.68 16372 3186.93 63.34 3144.35 76.74 OSF 1.50 Pass 0550.00 4047.81 -805.19 5013.57 5193.91 3563.46 826.42 2260.83 163.86 3236.40 63.37 3193.80 77.90 OSF 1.50 Pass 0600.00 4049.85 -83443 5054.09 5192.13 3583.08 824.90 2260.00 164.00 3285.89 83.39 3243.27 79.06 OSF 1,50 Pass 0850.00 405149 -863.86 5094.62 5190.40 3562.70 823.41 2259.18 184.13 3335.39 6342 3292.75 80.22 OSF 1.50 Pass 0700.00 405333 -892.89 5135.14 5188.69 3562.34 821.95 2258.37 164.26 3384.90 83.44 334225 81.38 OSF 1.50 Pass 0750.00 4055.17 -92212 5175.66 5187.02 3561.98 820.53 225758 16439 343442 63.47 3391.75 82.53 OSF 1.50 Pass 0900.00 405701 -95135 5216.19 5185.39 3561.62 819.13 2256.81 184.51 3483.95 83.49 3441.27 83.69 OSF 1.50 Pass 0850.00 4058.80 -980.58 5258.71 5183.78 3561.27 817.76 2256.05 163.32 3533.49 63.52 3490.79 8485 OSF 1.50 Pass 0900.00 4059.94 -1009.87 5297.22 5182.14 3560.92 816.36 225527 160.78 3582.96 63.54 3540.25 86.00 OSF 1.50 Pass 0950.00 4060.83 -1039.18 5337.71 0180.52 3560.57 814.98 2254.49 160.90 3632.41 63.57 3589.68 87.15 OSF 1.50 Pass 1000.00 4061.72 -1068.49 5378.21 5178.92 3560.22 813.62 2253.73 161.01 388188 63.59 3639.13 88.31 OSF 1.50 Pass 1050.00 4062.61 -1097.81 5418.71 5177.21 3559.85 812.16 2252.91 161.13 3731.36 63.62 3688.59 89.46 OSF 1.50 Pass 1100.00 4063.50 -1127.12 5459.21 517513 3559.40 810.40 2251.92 161.28 3780.85 6363 373807 90.62 OSF 1.50 Pass 1150.00 4064.38 -1156.43 5499.71 5173.09 3558.96 808.66 2250.94 161.43 383034 6365 378755 9178 OSF1.50 Pass 1200.00 4065.27 -1185.74 5540.21 5171.08 355852 806.95 2249.97 161.57 387985 83.67 3837.05 9294 OSF 1.50 Pass 1250.00 4066.16 -1215.05 5580.70 5169.10 3558.10 805.27 2249.02 161.71 3929.37 63.69 3886.56 94.10 OSF 1.50 Pass 1300.00 4067.05 -1244.38 5621.20 5167.15 3557.67 803.62 2248.08 16184 397890 63.70 3936.07 95.26 OSF 1.50 Pass 1350.00 4067.94 -1273.67 566170 5165.23 3557.26 801.99 2247.15 161.97 402844 6372 3985.60 9642 OSF 1.50 Pass 1400.00 4068.79 -1302.96 5702.21 5163.35 3556.85 800.39 2246.24 160.01 4077.98 63.74 4035.13 9758 OSF1.50 Pass 1450.00 4069.48 -1332.16 5742.79 5161.52 355645 798.85 2245.36 160.14 4127.52 63.76 4084.68 98.73 OSF 1.50 Pass 1500.00 4070.14 -1361.37 5783.37 5159.72 355606 797.32 2244.48 150.26 4177.07 63.78 4134.20 99.89 OSF 1.50 Pass 1550.00 4070.82 -1390.57 5823.95 5157.95 3555.68 795.82 2243.62 160.39 4228.63 63.80 4183.75 10104 OSF 1.50 Pass 1800.00 4071.50 -1419.77 5864.53 515620 3555.30 794.34 224277 160.51 4276.20 63.81 4233.30 102.20 OSF 1.50 Pass 1850.00 4072.18 -1448.97 5905.11 5154.48 355492 792.88 2241.94 180.62 432578 63.83 4282.87 103.35 OSF 1.50 Pass 1700.00 4072.86 -1478.18 5945.69 5152.79 355455 791.45 2241.11 180.74 4375.36 63.85 433244 104.51 OSF1.50 Pass 1750.00 4073.54 -1507.38 598627 5151.12 3554.19 790.04 2240.30 180.86 4424.95 63.87 4382.02 105.68 OSF 1.50 Pass 1800.00 4074.22 -1538.58 5026.85 514947 355383 788.65 2239.49 180.97 4474.55 63.89 4431.60 106.81 OSF 1.50 Pass 1850.03 407490 -1565.79 8067.43 5147.85 355348 787.28 2238.70 161.08 4524.16 63.91 4481.20 107.97 OSF 1.50 Pass 1900.00 4075.50 -1594.99 6108.01 5146.24 3553.13 78582 2237.91 159.40 4573.76 63.93 4530.79 109.12 OSF 1.50 Pecs 1950.00 4075.36 -1624.22 6148.58 5144.60 3552.77 784.53 2237.10 155.90 462329 63.94 4580.30 110.27 OSF 1.50 Pass 2000.00 4074.37 -1653.46 6189.12 5142.90 3552.40 78310 2236.27 153.46 4672.72 63.96 4629.72 11142 OSF 1.50 Pass 2050.00 407308 -168270 6229.66 5141.21 3552.03 781.87 2235.44 153.56 4722.12 63.98 4679.11 112.56 OSF1.50 Pass 2100.00 4071.76 -171195 6270.19 5139.53 3551.67 780.26 2234.62 153.66 4771.53 6400 4728.51 113.71 OSF 1.50 Pass 2150.00 4070.45 -1741.19 6310.73 5137.88 3551.31 778.87 2233.80 153.76 4820.95 64.02 4777.91 114.85 OSF 1.50 Pass 2200.00 4069.15 -177044 635128 5136.26 355096 777.50 2233.00 153.85 4870.38 64.04 4827.33 115.99 OSF1.50 Pass 2250.00 4067.84 -179968 639180 5134.65 3550.61 776.15 2232.21 153.95 4819.82 6406 4876.76 117.13 OSF1.50 Pass End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 11 of 137 • • Field: Nikadchuq Well: SPOB-N7 Structure: Spy Island Borehole: SPO8-N7L7 Slot: SP08 Trajectory: SP08-N7L7 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feel North Reference: True Grld Convergence Angle: 0.09030636` Grid Scale Factor: 0999900155 Magnetic Declination: 19.639° Magnetic Decllnaeon Date: October 30,2013 Magnetic Model: BGGM 2013 Reference Point: Nom Essen. Eleva ion Structure Una Slit 6053658.B00(ftUS) 511676.160(605) 53.930(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Trajectory Error Model'ISCWSAO 3-0 95.000%Con9dence 2.7955 sigma Survevina Pro.'As Drilled Description MD From(ft) MD To(It) EOU Freq Survey Tool Type Hole We(In) Casino Diameter(1m) Borehole I Survey 0.000 40.630 Act-Stns SLB_NSG*SSHOT-Depth Only-No Global 16.000 13.375 SP08-N7/SPO8-N7 40.830 579.980 Act-Stns SLB NSG+SSHOT-No Gleba 16.000 13.375 SPO8-N7/SPOB-N7 579.980 2609.640 ActSIns SLB MWD*GMAGNo Gleba 16.000 13.375 SP08-N7/SPO8-N7 2609.640 2703.480 Act-Stns SLB_MWD-INC ONLY FILLER-No Globa 12.250 9.625 SPOB-N7/SPO&N7 2703.480 7789.190 Act-Stns SLB_MWD*GMAGNo Goba 12.250 9.625 SP08-N7/SP08-N7 7789.190 7791.000 Act-Stns SLB_MWD*GMAGNo Globs 12.250 9.625 SP08-N7L1/SP08-N7L1 7791.000 7899.430 ActSIns SLB_MWD-INC_ONLY_FILLER-No Globs 8.750 5.500 SP08-N7LI/SPO8-N7L1 7899.430 15912.840 Ad-Stns SLB MN0*GMAGNo Globs 8750 5.500 SP08-N7LI/SPO8-N7L1 15912840 15977.000 Act-Stns SLBBLIND+TREND-No Globa 8.750 5500 SP08-117L1/SP08-N7L1 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 Consoling Rubs Status (II) (ft) (ft) (6) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 6100.00 ft on MD<=16128.61 ft Results filtered:Ct-Ct separation On 1500.00 ft Results highlighted:Ct-Ct separation<=1320.00ft 6100.00 4028.97 1797.48 1405.89 6619.68 384801 2167.80 236078 45.74 1040.05 80.35 986.13 19.66 OSF 1.50 Pass 6150.00 4031.82 177250 1449.10 658096 3841.53 2131.80 237348 48.31 100984 80.34 855.92 19.09 OSF 1.50 Pass 6200.00 403407 174644 149171 654241 3834.87 2095.96 238601 48.40 980.62 80.27 826.76 18.55 OSF 1.50 Pass 6250.00 4035.84 1718.95 1533.44 6503.39 3827.48 2059.74 239851 50.57 95284 80.37 898.90 18.00 OSF 1.50 Pass 6300.00 4037.11 1690.07 1574.23 6454.45 3817.41 201435 2413.79 53.10 926.43 80.14 872.65 17.55 OSF 1.50 Pass 6350.00 4037.89 1659.86 1614.06 6396.32 3805.11 1960.16 2430.85 55.75 900.84 79.75 847.32 17.15 OSF 150 Pass 6400.00 4038.51 1629.18 1853.54 6333.13 3791.25 1900.88 244777 57.87 875.07 79.27 821,8 OSF 1.50 Pass 6450.00 4039.13 1588.51 169302 623928 3700.87 1811.93 2468.65 60.97 848.32 77.77 796.1 OSF 1.50 Pass 6500.00 4039.74 1567.83 1732.50 6059.65 373109 1637.68 2486.05 69.21 817.31 72.83 76839 OSF 150 Pass 6550.00 404036 1537.15 1771.98 5969.20 3711.86 1549.41 2482.38 74.81 78277 7086 735.18 18.80 OSF 1.50 Paw 6600.00 4040.97 150648 181146 5909.59 370022 149124 247848 79.10 747.39 69.66 700.60 16.32 OSF 1.50 Pass 685000 4041.54 1475.99 1851.08 5867.97 3692.36 1450.75 2470.96 81.99 711.91 68.91 665.61 15.72 OSF 1.50 Pass 670500 4041 70 1446.54 1891 49 583168 368556 1415.56 246527 8478 676.04 68.17 630.24 15.09 OSF 1.50 Pass 6750.00 4041.78 141729 193204 5798.64 3679.33 138366 2459.32 88.05 64072 6743 59541 14.48 OSF 150 Pass 6800.60 4041.86 1388.04 197259 5768.95 3673.62 1355.16 2453.28 91.20 606.42 6662 561.65 13.85 OSF 1.50 Pass 6850.00 4041.93 1358.78 201313 574217 3668.38 1329.00 244728 9419 57348 65.75 529.29 13.27 OSF 1.50 Pass 690000 404201 1329.53 205388 5718.69 3663.76 1307.28 2441.65 9692 54230 6485 498.71 12.73 OSF 1.50 Pass 6950.00 4042.09 130028 2094.23 5696.56 365947 1288.28 2436.13 99.58 513.31 6380 470.42 12.25 OSF 150 Pass 7000.00 404216 127102 213478 567541 3655.45 126624 2430.68 102.19 486.96 62.49 444.94 11.87 OSF 150 Pass 7050.00 404224 124177 217533 5655.18 385186 1247.11 2425.30 104.74 46375 60.94 422.76 11.59 OSF 150 Pass 7100.00 404232 121252 221588 5636.36 3648.19 1229.34 242015 107.15 44424 59.22 404.40 1143 OSF 1.50 Pass 713358 4042.37 1182.87 2243.11 562444 364601 1218.10 2416.85 10069 43350 5800 39417tr �q OSF 1,50 Pass 7150.00 404244 1183.26 225643 561868 364496 121267 2415.24 10047 429.04 5738 390.43 11.40 OSF 150 Pass 7200.00 4043.24 115401 2296.97 5601.53 3641.86 1196.51 2410.41 1117641Q 55.42 381 11.54 OSF 1.50 Pass 7250.00 404468 112477 233751 5584.89 3638.88 1180.84 2405.85 113.91/ 41$. 53.5 11.83 OSF 1.50 Pass 7300.00 404615 109554 2378.04 5568.61 3635,99 118553 2400.94 116.08 4167 5202 381 12.24 OSF1.50 Pass 735000 4047.63 1068.30 241857 555268 3633.19 115056 2396.28 118.17 423.50 50.96 389.17 12.70 OSF 1.50 Pass 7400.00 4049.10 1037.08 2459.11 5538.36 3630.68 1137.12 239202 120.04 43542 5061 40133 13.15 OSF 150 Pass 7450.00 4050.58 103782 2499.64 5524.64 3628.25 112427 2387.88 121.82 452.12 50.77 417.92 13.61 OSF 1.50 Pass 7500.00 4052.05 978.58 2540.17 5511.40 3625.90 111189 2383.80 123.54 473.11 5131 438.55 14.09 OSF 1.50 Pass 7550.00 4053.53 949.34 2580.70 549861 362381 109996 2379.81 125.18 497.87 51.96 462.87 14.64 OSF 1.50 Pass 7600.00 4055.00 920.10 262124 5486.25 3621.38 1088.45 2375.89 126.75 52589 52.94 490.24 15.18 OSF 150 Pass 765000 4056.47 89086 2661.77 547430 3619.22 107734 2372.05 128.25 556.69 53.88 520.41 15.78 OSF 1.50 Pass 7700.00 4057.80 881.82 2702.31 5462.71 3617.11 1066.59 2388.28 129.86 589.74 54.76 552.88 16.45 OSF 1.50 Pass 775000 4058.33 83237 274285 5451.97 3615.14 105665 2364.73 130.89 62425 55.60 586.83 17.14 OSF 150 Pass 7800.00 4058.41 80312 278340 5442.04 3613.31 1047.47 236139 13206 660.24 56.39 622.28 17.87 OSF 1.50 Pass 7850.00 4058.48 773.87 252395 543255 3611 56 1038.73 2358.14 133.18 697.76 5710 65534 18.65 OSF 1.50 Pass 7900.00 4058.56 74462 2864.50 5423.49 3809.87 1000.41 2354.99 134.23 736.61 57.72 69777 19.47 OSF 1.50 Pass 795000 4058.63 71537 2905.06 541483 3608.25 102246 2351.93 13522 776.59 58.28 737.39 20.33 OSF1.50 Pass 8000.00 4058.71 686.11 294561 5406.53 3806.70 101488 2348.96 136.16 817.55 5876 778.02 21.23 OSF 1.50 Pass 8050.00 4058.78 656.86 2986.16 539858 360520 1007.63 2346.07 137.05 859.35 59.19 819.53 2215 OSF 1.50 Pass 8100.00 4058.86 627.61 3026.71 539097 3603.76 1000.69 2343.27 13790 901.88 59.57 861.81 23.10 OSF1.50 Pass 8150.00 4058.93 59836 3067.26 538365 3602.37 99405 2340.54 138.70 94506 5990 904.76 2407 OSF 100 Pass 8200.00 4059.01 569.11 3107.81 5376.63 3601.03 987.68 2337.90 139.46 988.79 60.20 948.30 25.06 OSF 1.50 Pass 8250.00 4059.03 539.87 3148.37 5389.89 3599.74 98158 2335.33 139.92 1033.00 60.46 99233 26.06 OSF 1.50 Pass 8300.00 4058.96 51067 3188.95 5363.32 3598.48 975.65 2332.81 140.61 107761 60.69 1036.79 27.08 OSF 1.50 Pass 835000 4058.90 48147 3229.54 5356.58 3597.18 969.57 2330.19 141.32 1122.62 6089 108167 28.12 OSF 1.50 Pass 8400.00 4058.84 45226 3270.12 535004 359590 963.69 232764 141.99 1167.97 61.06 112690 29.18 OSF1.50 Pass 8450.00 405877 42306 3310.71 5343.69 359466 957.99 232514 142.64 1213.63 61.22 1172.46 30.24 OSF1.50 Pass 8500.00 405871 393.85 3351.29 5337.52 359345 952.46 232270 143.26 125957 61.36 1218.31 31.31 OSF 1.50 Pass 8550.00 4058.64 36465 3391.88 5331.53 3592.26 94709 2320.31 14386 1305.76 61.48 126442 3239 OSF 1.50 Pas=_ 8600.00 4058.58 335.45 3432.46 5325.71 3591.10 94189 2317.97 144.43 1352.18 61.59 1310.76 33.48 OSF 1.50 Pass 8650.00 4058.51 306.24 3473.05 5320.05 358997 936.83 2315.69 144.98 1398.81 61.70 1357.32 34.58 OSF1.50 Pass 8700.00 4058.45 277.04 351363 5314.54 3588.86 931.92 2313.45 145.51 1445.62 61.79 140407 35.89 OSF 1.50 Pass 8750.00 405813 247.82 3554.20 5309.15 358777 927.12 2311.25 145.56 1492.52 61.87 1450.92 36.79 OSF 1.50 Pass 8800.00 4056.98 218.54 3594.72 5303.75 3586.67 922.33 2309.04 145.62 1539.31 61.95 1497.66 37.90 OSF 1.50 Pass 8850.00 4055.51 189.23 3635.25 5296.45 3585.58 917.62 2306.85 146.08 158616 62.03 1544.45 39.00 OSF 1.50 Pass 8900.00 4054.05 159.93 3675.69 5293.28 358452 913.04 2304.71 146.53 1633.17 62.09 159141 40.12 OSF1.50 Pass Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 12 of 137 • 0 Trajectory:SI07SE4(P3)Vs.SP08-N7L1 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 (1t) ON (6) (P) (ft) (6) _ (ft) (6) (°) (1t) (ft) (8) 8950.05 4052.59 130.82 3716.17 528825 3583.48 90858 2302.61 46.96 1680.32 62.16 1638.52 41.23 OSF 1.50 Pass 9050.05 4051.13 101.32 375666 5283.34 3582.46 90424 2300.55 47.38 1727.60 62.22 1685.77 42.35 OSF 1.50 Pass 9050.05 4049.87 72.01 3797.15 5278.55 3581.46 900.02 2298.53 4778 1775.01 62.27 1733.14 4348 OSF 1.50 Pass 9100.00 4048.21 42.71 3837.63 5273.88 3580.49 895.90 2296.56 48.17 1822.53 6232 1780.62 44.60 OSF 1.50 Pass 9150.00 4046.74 13.40 3878.12 5269.54 3579.57 892.07 229471 48.53 1870.16 62.38 182822 4573 OSF 1.50 Pass 9200.03 4045.28 -15.90 3918.60 5265.60 3578.75 888.62 2293.03 48.86 1917.89 62.44 1875.91 46.85 OSF 1.50 Pass 9250.00 4043.82 -4521 3959.09 5261.78 3577.94 88526 2291.39 49.17 1965.72 62.50 1923.70 4797 OSF1.50 Pass 9300.00 4042.78 -74.49 3999.60 5258.12 357717 882.05 2289.81 50.55 2013.74 62.54 1971.69 49.11 OSF 1.50 Pass 9350.05 4042.42 -103.74 4040.15 5254.64 3576.43 87900 2288.29 51.28 2062.02 62.58 2019.94 5025 OSF1.50 Pass 9400.00 4042.11 -133.00 4060.70 5251.25 357571 87604 2286.82 51.56 2110.37 62.83 2068.27 51.40 OSF 1.50 Pass 9450.05 4041.80 -162.25 412125 5247.96 3575.02 873.16 2285.38 51.84 2158.79 62.67 2116.65 52.54 OSF 1.50 Pass 9500.00 4041.50 -191.50 4161.80 5244.76 3574.34 870.37 2283.97 52.10 2207.27 62.72 216510 53.68 OSF 1.50 Pass 9550.00 4041.19 -220.75 4202.35 5241.64 3573.68 867.65 228260 52.36 2255.80 82.76 2213.60 54.82 OSF 1.50 Pass 9600.00 404089 -250.00 4242.90 5238.60 3573.03 885.00 2281.25 52.61 2304.38 6280 226216 55.97 OSF 1.50 Pass 9650.00 4040.58 -279.25 4283.45 5235.64 3572.40 882.42 2279.93 52.85 2353.02 62.84 2310.77 57.11 OSF 1.50 Pass 9700.00 404027 -308.50 4324.00 523275 357179 859.91 2278.64 53.08 2401.70 62.88 2359.42 58.26 OSF 1.50 Pass 9750.00 403997 -33775 436455 5229.94 3571.19 857.47 2277.38 53.31 2450.42 62.92 2408.12 59.40 OSF1.50 Pass 9800.00 403966 -367.05 4405.10 5227.19 3570.60 855.09 2276.14 53.53 2499.19 62.95 245687 60.55 OSF 1.50 Pass 9850.00 4039.47 -396.21 4445.68 5224.54 3570.03 852.79 2274.95 53.76 2548.03 62.98 250569 61.71 OSF 1.50 Pass 9900.00 403932 -42541 4486.28 5221.95 3569.48 850.55 2273.78 53.97 2598.91 63.01 255455 6286 OSF 1.50 Pass 9950.05 4039.16 -454.62 4526.85 5219.43 3568.94 848.37 2272.63 54.17 264582 63.04 280344 64.01 OSF 1.50 Pass 10050.05 403900 -483.82 4567.43 5216.97 3588.42 846.24 2271.51 54.36 2694.77 63.08 265236 65.16 OSF 1.50 Pass 10050.05 4038.84 -513.03 4808.02 5214.56 3567.90 844.17 2270.41 5455 274375 63.11 2701.32 66.31 OSF 1.50 Pass 10100.05 4038.68 -54223 4848.80 5212.21 3567.40 842.14 2269.33 54.73 2792.76 83.14 2750.31 67.46 OSF 1.50 Pass 10150.05 4038.52 37144 4689.18 5209.91 3566.90 840.16 2268.28 54.91 2841.80 63.17 2799.33 68.61 OSF 1.50 Pass 10200.08 4038.36 505.84 472977 5207.67 3566.42 83823 226724 55.08 2890.87 8320 2848.38 69.77 OSF 1.50 Pass 10250.05 4038.28 -629.84 477035 520548 3565.95 836.34 2266.23 56.43 293997 63.23 2897.47 70.92 OSF1.50 Pass 10300.00 4038.93 -659.06 4810.93 5203.39 3565.50 834.54 2265.26 59.71 298922 63.25 2946.69 7208 OSF 1.50 Pass 10350.05 4040.45 -68827 4851.47 5201.40 356507 83284 2264.33 63.28 3038.59 6327 2996.06 7325 OSF 1.50 Pass 10405.05 4042.29 -717.50 4892.05 5199.48 3564.66 831.18 2263.43 83.43 308802 63.30 304547 74.41 OSF 1.50 Pass 10450.00 4044.13 -746.73 4932.52 5197.57 3564.25 829.55 2282.55 63.58 3137.47 63.32 309490 75.57 OSF 1.50 Pass 10500.00 4045.97 -775.96 4973.05 519572 3563.85 827.97 2261.68 63.72 3186.93 63.35 314434 76.73 OSF 1.50 Pass 10550.05 4047.81 -805.19 5013.57 519191 3563.46 826.42 2280.83 63.86 3236.40 83.38 3193.80 77.89 OSF 1.50 Pass 10600.00 4049.65 -834.43 5054.09 5192.13 3563.08 824.90 2260.00 64.00 3285.89 63.40 3243.27 79.05 OSF 1.50 Pass 10650.00 4051.49 -863.86 5094.62 5190.40 3562.70 823.41 2259.18 84.13 3335.39 63.43 3292.75 80.20 OSF 1.50 Pass 10705.00 4053.33 -892.89 5135.14 5188.69 3582.34 821.95 2258.37 64.26 3384.90 63.45 3342.24 81.36 OSF 1.50 Pass 10750.00 4055.17 -922.12 5175.66 5187.02 3561.98 820.53 2257.58 64.39 3434.42 63.48 3391.74 8252 OSF 1.50 Pass 10800.00 4057.01 -951.35 5218.19 518539 3561.62 819.13 2256.81 64.51 348395 6350 3441.26 83.68 OSF 1.50 Pass 10850.00 4058.80 -980.58 5256.71 5183.78 3581.27 817.76 2256.05 63.32 353349 63.53 3490.78 84.83 OSF1.50 Pass 10900.05 4059.94 -1009.87 5297.22 5182.14 3565.92 816.36 2255.27 60.78 3582.96 63.56 3540.24 8599 OSF 1.50 Pass 10950.05 4060.83 -1039.18 5337.71 5180.52 356557 814.98 2254.49 60.90 3632.41 63.58 3589.67 87.14 OSF 1.50 Pass 11000.00 4061.72 -1069.49 537821 5178.92 3505.22 813.82 2253.73 61.01 3681.88 63.60 3639.12 88.29 OSF 1.50 Pass 11050.05 4082.61 -1097.81 5418.71 5177.21 3559.85 812.16 2252.91 61.13 3731.36 6363 368858 89.44 OSF1.50 Pass 11100.05 4063.50 -1127.12 545921 5175.13 3559.40 810.40 2251.92 61.28 3780.85 63.64 373806 9061 OSF1.50 Pass 11150.05 4064.38 -1156.43 5499.71 5173.08 3558.96 808.66 2250.94 81.43 383034 63.66 3787.55 91.76 OSF 1.50 Pass 11200.05 4065.27 -1185.74 5540.21 5171.08 3558.52 806.95 2249.97 61.57 3879.85 63.68 3837.04 9293 OSF 1.50 Pass 11250.05 4066.16 -1215.05 5580.70 5169.10 3558.10 805.27 2249.02 61.71 392937 63.70 3886.55 9408 OSF1.50 Pass 11300.05 4067.05 -1244.36 5621,20 5167.15 3557.67 803.62 2248.08 61.84 3978.90 63.72 3936.07 95.24 OSF 1.50 Pass 11350.00 4067.94 -1273.67 5661.70 5165.23 355726 801.99 2247.15 61.97 4028.44 63.73 398559 96.40 OSF 1.50 Pass 11400.05 4068.79 -1302.96 570221 5163.35 3556.85 800.39 2246.24 60.01 4077.98 63.75 403512 9756 OSF 1.50 Pass 11450.00 4069.46 -1332.18 5742.79 5161.52 3566.45 798.85 2245.36 60.14 4127.52 63.77 4084.65 98.71 OSF 1.50 Pass 11500.00 4070.14 -1361.37 5783.37 5159.72 355606 797.32 2244.48 60.26 4177.07 83.79 4134.19 98.87 OSF 1.50 Pass 11550.05 4070.82 -1390.57 5823.95 5157.95 355568 79582 2243.62 0039 4226.63 63.81 4183.74 101.03 OSF 1.50 Pass 11600.05 407150 -1419.77 586453 5158.20 3555.30 794.34 2242.77 60.51 4276.20 6382 4233.30 102.18 OSF 1.50 Pass 11650.05 4072.18 -1448.97 590511 515448 3554.92 79288 224194 60.82 4325.78 63.84 4282.86 103.34 OSF 1.50 Pass 11700.00 4072.86 -1478.18 5945.69 515279 3554.55 79145 2241.11 60.74 4375.36 63.86 4332.43 104.49 OSF 1.50 Pass 11750.00 4573.54 -1507.38 598627 5151.12 3554.19 790.04 2240.30 60.86 4424.95 6388 438201 105.64 OSF 1.50 Pass 11800.00 407422 -1536.58 602685 5149.47 3553.83 788.85 223949 60.97 4474.55 6390 4431.60 108.80 OSF 1.50 Pass 11690.00 4074.90 -1565.79 606743 5147.85 355348 787.28 2238.70 61.08 4524.16 63.92 4481.19 107.95 OSF 1.50 Pass 11905.05 4075.50 -159499 6108.01 5146.24 3553.13 785.92 2237.91 59.40 4573.76 63.94 4530.78 108.10 OSF 1.50 Pass 11950.05 4075.36 -1624.22 6148.58 5144.60 355277 784.53 2237,10 55.90 4623.29 63.95 4580.30 110.25 OSF 1.50 Pass 12000.05 407437 -165346 6189.12 5142.90 3552.40 783.10 2236.27 53.46 4672.72 6397 4629.72 111.40 OSF 1.50 Pass 12055.05 4073.06 -1682.70 6229.68 5141.21 355203 781.67 2235.44 53.56 4722.12 63.99 4679.10 11254 OSF 1.50 Pass 12105.00 407176 -1711.95 6270.19 5139.53 3551.67 780.26 2234.62 53.66 4771.53 64.01 4728.50 113.69 OSF 1.50 Pass 12150.05 4070.45 -174119 631073 5137.88 3551.31 778.87 2233.80 5376 4820.95 6403 477791 114.83 OSF 1.50 Pass 12200.00 4069.15 -1770.44 8351.28 5136.26 3550.96 777.50 2233.00 53.85 4870.38 64.05 4627.33 115.97 OSF 1.50 Pass 12250.05 4067.84 -1799.68 6391.80 5134.65 3550.61 776.15 2232.21 53.95 4919.82 64.07 4876.75 117.12 OSF 1.50 Pass End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\S107-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 13 of 137 ill 1111 Field: NikeNchuq Well: SP09-N9 Structure: Spy Island Borehole: SP09-N9 Slot: SP09 Trajectory SP09-N9(P7) Client: Eni Petroleum Type: De!Plan Coordinate System: NA027 Alaska Stole Plane,Zone 04,US Feel North Reference: True Grid Convergence Angle: 0.09024571' Grid Scale Factor: 0.999900155 Magnetic Declination: 19.490' Magnetic Declination Date: February 03,2014 Magnetle Model: BGGM 2013 Reference Point: NOV retina Easnna Elevation Structure Uno Slot Une. 6053657 280(ftUS) 511668 320(ftUS) 54.100(ft)MSL 0.000(ft)(1 sigma) 0000(ft)(1 sigma) Trajectory Error Model:ISCWSA03-D 95.000%Confidence 2.71166 sigma Survevina Proa:While Drilling Description Part MD From go MD To(ft)EOU Freq(ft) Survey Tool Type Hole Size(in) Casing Diameter 6n) Borehole/Burbly 1 0.000 41.000 1/100.000 SLB NSG+SSHOT-Dept[Only-No Global 30.000 30.000 SP09-N9/SP09-N9(P1) 1 41.000 1000.000 1/100.000 SLB NSG+SSHOT-No Global 30.000 30.000 SP09-N9/SP09-N9(P1) 1 1000.000 18363.223 1/100.000 SLB MVVD+GMAG-No Global 30.000 30.000 SP09-N9/SP09-N9(P1) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference WE Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Palm Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (5) (8) (ft) (ft) (ft) _ (9) (ft) (ft) (°) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 6100.00 ft r-MD<c 16128.61 ft Results filtered:Ct-Ct separation<01500.00 ft Results highlighted Ct-Ct separation<:1320.00 ft 6100.00 4028.97 1797.48 1405.89 5625.35 3576.97 802.78 2637.02 143.77 1646.03 87.20 1587.26 28.92 OSF 150 Pass 6150.00 4031.82 1772.50 144910 5635.11 3578.18 810.09 2643.37 143.39 1599.47 8724 1540.67 28.09 OSF 1.50 Pass 6200.00 4034.07 1746.44 1491.71 5643.59 3579.23 816.45 2618.89 140.21 1552.69 87.23 1493.89 27.27 OSF 1.50 Pass 6250.00 4035.84 1718.95 1533.44 5650.38 3580.07 621.53 2653.31 136.71 1505.72 87.17 1446.97 26.48 OSF 1.50 Pass 6300.00 4037.11 189007 1574.23 565545 3580.70 625.33 2656.61 132.99 1458.64 87.05 1399.97 25.67 OSF 1.50 Pass 6350.00 4037.89 1659.86 1614.06 5658.83 3581.12 827.86 2658.81 129.78 1411.51 86.88 1352.95 24.89 OSF 1.50 Pass 6400.00 4038.51 1629.18 1653.54 5861.62 3581.47 829.95 2660.62 129.45 1364.51 88.66 1306.09 24.12 OSF 1.50 Pass 6450.00 4039.13 159851 1893.02 5664.40 358181 83204 266244 129.11 1317.72 88.42 1259.47 23.36 OSF 1.50 Pass 6500.00 4039.74 1567.83 173250 5667.19 3582.16 83412 2864.25 128.78 1271.17 86.14 1213.11 2201 OSF 1.50 Pass 6550.00 4040.36 1537.15 1771.98 566998 358250 836.21 2866.06 128.44 1224.88 8582 1167.03 21.86 OSF 150 Pass 6600.00 404097 1506.48 181146 5872.77 3582.85 838.30 2867.88 12811 1178.90 85.46 1121.28 21.13 OSF 150 Pass 6650.00 4041.54 147599 1851.08 5675.78 3583.22 840.58 2689.84 129.03 1133.22 8506 1075.87 20.41 OSF 150 Pass 6700.00 4041.70 1446.54 189149 5680.04 358375 84375 2672.61 129.77 1087.77 84.65 1030.70 19.69 OSF 1.50 Pass 6750.00 4041.78 1417.29 193204 568452 358431 847.11 2875.53 129.23 104267 8418 985.91 18.98 OSF 1.50 Pass 880.00 4041.86 138804 197259 568901 3584.86 850.47 2678.45 128.68 99803 83.64 941.63 18.28 OSF 1.50 Pass 680.0 4041.93 135878 2013.13 5693.49 3585.42 853.82 2881.36 128.13 953.90 83.02 89791 17.61 OSF 1.0 Pass 890.0 4042.01 1329.53 2053.68 5697.97 358597 857.18 2684.28 127.58 910.35 82.29 854.85 18.95 OSF 1.50 Pass 690.0 404209 130028 2094.23 5702.46 358653 80.54 2687.20 127.02 86747 81.46 812.53 16.32 OSF 1.50 Pass 700.0 404216 127102 213478 5708.94 358709 863.90 2690.12 12647 82537 80.49 771.08 15.72 OSF 1.50 Pass 700.0 4042.24 124177 2175.33 5711.42 358764 867.26 2693.03 125.91 784.18 79.38 730.62 15.15 OSF 1.50 Pass 710.0 4042.32 1212.52 2215.88 5715.91 3588.20 870.62 2695.95 125.35 744.03 78.08 691.34 14.82 OSF 1.0 Pass 710.0 4042.44 1183.26 225643 572039 358875 873.98 2698.87 124.0 705.15 7658 653.46 1413 OSF 1.0 Pass 7200.00 4043.24 115401 2296.97 5724.97 3589.32 877.40 2701.85 124.26 668.19 7482 617.67 13.71 OSF 150 Pass 720.0 4044.88 112477 2337.51 5729.62 358990 88089 2704.87 123.71 633.46 7279 58429 13.37 OSF 1.50 Pass 730.0 4046.15 1095.54 2378.04 5734.27 3590.47 884.38 2707.90 123.14 60.87 70.51 553.22 13.10 OSF 150 Pass 735000 4047.63 1066.30 2418.57 5738.93 3591.05 887.86 2710.93 122.57 57077 68.02 524.78 1291 OSF 1.0 Pass 740.0 4049.10 103706 245911 5743.59 30163 891.35 2713.96 122.01 543.57 65.36 499.36 1 8 OSF 1.0 Pass 7450.00 4050.58 100782 2499.64 5748.24 3592.21 894.84 2716.99 121.44 519.72 6266 477. OSF 150 Pass 7500.00 4052.05 97858 254017 5752.90 30278 898.33 2720.03 12087 499.72 0.10 459.01 12. OSF 1.50 Pass 750.0 405353 949.34 2580.70 5757.56 3593.36 90182 2723.06 120.30 484.02 5703 44538 13.12 OSF 1.0 Pass 76000 4055.0 92010 262124 5762.21 359394 905.31 2726.09 119.73 473.07 55.37 435.51 13.22 OSF 150 Pass 780.0 405647 89086 266177 5766.87 3594.51 90879 2729.12 119.16 467.19 5476 43004 13.21 OSF 150 Pass 7670.0 4057.09 878.65 267870 5768.82 359475 910.25 2730.38 118.'. 5E1P7.. 54'86a 429.08 13.16 OSF 1.0 Pass 770000 4057.80 861.62 270231 5771.51 3595.09 91227 2732.13 118.59 r:•. 55,a3+eO 13.04 OSF 150 Pass 7750.03 4058.33 832.37 2742.85 5776.05 359565 91567 2735.09 118.05 470.18 5712 12.72 OSF 1.0 Pass 7800.00 4058.41 803.12 278340 5780.53 3596.21 919.03 2738.01 117.0 478.67 5980 438.16 12.36 OSF 1.50 Pass 780.0 4058.48 773.87 2823.95 5785.02 3596.76 92239 2740.93 116.95 492.07 63.05 44940 12.03 OSF 1.0 Pass 790.0 4058.56 744.62 286450 570.0 359732 92575 2743.84 118.41 510.01 6653 40.02 11.80 OSF 1.50 Pass 7950.0 4058.63 71537 290506 5793.99 359787 92911 2748.76 115.86 532.01 6997 484.1 OSF 1.0 Pass 0.0 80 4058.71 688.11 294561 5798.47 3598.43 932.47 2749.68 115.31 557.61 73.19 50818 11. OSF 1.50 Pass 80000 4058.78 656.86 2986.16 5802.96 3598.99 935.83 2752.60 114.77 586.33 76.13 534.94 11.81 OSF 1.50 Pass 810.0 4058.86 827.81 302671 580744 3599.54 939.19 2755.52 114.22 617.73 7874 564.60 1202 OSF 1.50 Pass 810.0 405893 598.36 3067.26 5811.93 360010 94255 2758.44 113.68 651.43 81.03 596.77 1232 OSF 1.0 Pass 8200.0 4059.01 50.11 3107.81 581641 360.65 94591 2761.36 113.13 687.09 83.02 631.10 12.67 OSF 1.50 Paw 825000 4059.03 53987 3148.37 5820.91 360121 94928 2764.28 112.49 724.38 84.75 66724 13.08 OSF 1.50 Paw 830000 4058.96 51067 3188.95 5825.44 301.77 952.67 2767.23 111.94 763.05 8626 704.90 13.54 OSF 150 Paw 83000 4058.0 48147 322954 5829.96 302.33 958.0 2770.17 111.40 02.94 8757 74392 14.03 OSF 150 Pae 840.0 4058.84 452.26 327012 5634.49 3602.89 95945 2773.12 110.86 84388 8871 78410 14.56 OSF 1.0 Paw 840.0 4058.77 42306 331071 5839.01 303.46 962.84 2776.06 11032 885.73 89.71 825.28 1510 OSF 1.50 Paw 8500.0 4058.71 39385 3351.29 5843.54 304.02 98623 2779.01 109.78 928.37 90.59 867.33 15.87 OSF 1.0 Paw 850.0 405864 38465 3391.88 5848.07 304.58 989.62 2781.95 109.24 97168 9138 91013 16.26 OSF 1.50 Paw 86000 4058.58 33545 3432.46 5852.59 305.14 97301 278490 108.70 1015.60 9207 953.58 16.87 OSF 1.0 Paw 8650.0 4058.51 30624 347305 5857.12 305.70 976.40 2787.84 108.17 1060.03 920 997.59 17.48 OSF 1.50 Pass 870.0 405845 27704 351363 5861.64 3606.26 979.79 2790.79 107.64 1104.92 93.25 104211 18.12 OSF 1.50 Pass 870.0 4058.13 24782 3554.20 5866.11 306.81 983.14 2793.70 107.83 1150.11 93.76 108897 18.75 OSF 1.50 Pass 880.0 4056.98 21854 359472 587040 360735 986.35 2796.49 108.17 1195.35 9422 113190 19.39 OSF 1.50 Paw 885000 4055.51 189.23 3635.20 5874.81 380787 989.50 279923 107.70 1240.84 94.65 1177.09 20.04 OSF 150 Pass 890.0 4054.05 15993 367569 5878.83 308.39 992.66 201.97 107.23 1286.64 9505 1222.64 2069 OSF 1.0 Pass 8950.0 4052.59 130.62 3716.17 5883.04 3608.91 995.82 2804.71 106.77 1332.73 9541 1268.48 21.35 OSF 1.50 Pae 9000.0 4051.13 101.32 3756.0 588725 308.43 996.97 2807.45 106.31 1379.08 95.75 1314.61 2202 OSF 1.50 Pae 9050.0 4049.67 7201 3797.15 5891.48 3609.98 102.13 2810.20 105.85 1425.67 96.06 1360.99 2268 OSF 1.0 Pars 9100.00 404821 42.71 3837.63 5895.68 3810.48 1005.28 2812.94 105.39 147247 96.35 1407.59 23.36 OSF 1.0 Paw 9150.00 4046.74 13.40 3878.12 5899.89 3811.0 1008.44 2815.68 104.93 1519.46 96.63 1454.40 24.03 OSF 1.50 Paw 9210.0 4045.28 -15.0 3918.0 5964.10 3611.52 1011.0 281842 104.47 1566.62 96.89 101.39 2471 OSF 150 Pass Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\S107-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 14 of 137 0 • Trejectory:5107-SE4(P3)Vs.SP09N9(P1) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVS Offset NS Offset EW North Azim Ct-Ct Distsnce Separation Clearance OSF Controlling Rule Status (rt) (9) (9) (8) (8) (9) IN (8) (`) (f) (8) (8) 9250.00 4043.82 -45.21 395909 5908.32 361204 1014.75 2821.16 104.02 1613.94 97.13 1548.55 25.40 OSF1.50 Pass 9300.07 4042.78 -74.49 3999.60 5912.61 3612.58 1017.97 2823.96 102.11 1681.53 97.36 1595.98 26.08 OSF 1.50 Pass 9350.00 4042.42 -103.74 4040.15 5917.04 3613.13 1021.29 2826.84 101.05 1709.42 97.57 164373 26.78 OSF 1.50 Pass 9400.00 4042.11 -133.00 4080.70 5921.48 3613.68 1024.61 2829.73 100.55 1757.42 9778 1691.80 2747 OSF 1.50 Pass 9450.00 4041.80 -182.25 4121.25 5925.92 3814.23 1027.94 2832.61 100.05 1805.53 97.98 1739.57 2816 OSF 1.50 Pass 9500.00 4041.50 -191.50 4161.80 5930.35 3614.78 1031.26 2835.50 99.56 1853.72 98.18 1787.63 28.85 OSF 1.50 Pass 9550.00 4041.19 -220.75 4202.35 593479 3615.33 1034.59 2838.39 99.07 1902.00 9837 1835.78 29.55 OSF 1.50 Pass 9601.00 4040.89 -250.00 4242.90 5939.23 3615.88 1037.91 2841.28 98.59 1950.35 98.56 1884.01 30.24 OSF 1.50 Pass 9650.00 4040.58 -279.25 4283.45 5943.67 3616.43 1041.24 2844.17 98.10 1998.78 98.74 1932.31 30.94 OSF 1.50 Pass 9700.00 404027 -308.50 432400 5948.11 3816.98 1044.56 2847.06 97.82 2047.27 98.92 1980.68 31.63 OSF1.50 Pass 9750.00 4039.97 -337.75 4364.55 5952.55 3617.53 1047.89 2849.94 9715 2095.82 99.09 2029.12 32.32 OSF 1.50 Pass 9800.00 4039.66 -367.00 4405.10 5956.98 3618.08 1051.21 2852.83 9667 2144.43 9926 2077.62 33.01 OSF1.50 Pass 9850.00 4039.47 -396.21 4445.68 5961.48 361863 1054.58 2855.76 95.53 2193.11 89.42 2126.19 33.71 OSF 1.50 Pass 9900.00 4039.32 425.41 4486.26 5966.00 3619.19 1057.96 285870 95.06 2241.85 98.58 2174.82 34.40 OSF 1.50 Pass 9950.00 4039.16 454.62 4526.65 5970.51 3619.75 106134 2861.64 94.58 2290.63 99.75 222349 35.09 OSF 1.50 Pass 0000.00 4039.00 483.82 4567.43 5975.03 362031 106472 2864.57 94.11 2339.45 99.91 227221 3578 OSF 1.50 Pass 0050.00 4038.84 -513.03 4808.02 5979.54 362087 1068.11 2867.51 9365 2388.31 100.07 2320.96 36.47 OSF 1.50 Pass 0100.00 4039.68 -542.23 4648.60 5984.05 362143 1071.49 287045 93.18 2437.21 100.22 236976 37.16 OSF1.50 Pass 0150.00 4038.52 -571.44 4689.18 5988.57 362199 1074.87 287338 92.72 2486.15 100.38 2418.59 37.85 OSF 1.50 Pass 0200.00 403836 -600.64 4729.77 5993.06 3622.55 1078.25 2876.32 9227 2535.12 100.53 246746 3853 OSF1.50 Pass 0250.00 403828 -629.84 4770.35 5997.60 3623.11 1081.64 2879.26 90.62 2584.13 100.68 2516.38 3922 OSF 1.50 Pass 030000 4038.83 -659.06 4810.93 8002.20 3823.68 1085.08 288226 86.99 2633.29 100.83 256543 39.91 OSF 1.50 Pass 0350.00 404045 -688.27 4851.47 6006.89 3624.28 1088.60 2885.31 83.45 2682.59 100.97 2814.63 40.59 OSF 1.50 Pass 0400.00 4042.29 -717.50 4892.00 6011.59 3624.85 1092.12 288837 82.94 2731.94 101.12 2863.89 41.28 OSF 1.50 Pass 0450.00 404413 -748.73 4932.52 6016.30 3625.43 1095.84 2891.43 8245 2781.31 101.27 2713.16 41.96 OSF 1.50 Pass 0500.00 4045.97 -775.96 4973.05 6021.00 362601 1099.16 289449 81.96 2830.70 101.42 2762.45 4284 OSF1.50 Pass 0550.00 4047.81 -605.19 501357 0325.70 3626.59 1102.68 289755 8147 2880.10 10157 281175 43.32 OSF 1.50 Pass 0600.00 4049.65 -834.43 5054.09 6030.40 3627.18 1108.21 2900.61 80.99 2929.51 101.71 2861.06 4400 OSF 1.50 Pass 0650.09 4051.49 -863.88 5094.62 6035.10 362776 1109.73 2903.67 80.52 297893 101.88 2910.39 44.68 OSF 1.50 Pass 0700.00 4053.33 -892.139 5135.14 6039.80 3628.34 1113.25 2906.73 80.05 3028.37 102.01 2959.73 4536 OSF 1.50 Pass 0750.00 4055.17 -92212 5175.88 0344.51 3628.92 1118.77 2909.79 79.59 3077.82 102.16 3009.07 48.03 OSF 1.50 Pass 0800.00 4057.01 -951.35 5216.19 604921 3829.51 1123.29 2912.85 79.14 312727 10230 3058.43 46.70 OSF 1.50 Pass 0850.03 4058.80 -980.58 5256.71 6053.90 3630.09 1123.81 2915.90 80.44 3176.74 102.45 3107.80 47.37 OSF 1.50 Pass 0900.00 4059.94 -1039.87 529722 6058.46 3630.65 1127.23 2918.87 8379 322615 102.59 3157.11 48.04 OSF 1.50 Pass 0950.00 4060.83 -1039.18 5337.71 6062.97 3631.21 1130.60 2921.80 83.38 3275.54 102.73 3206.42 4871 OSF 1.50 Pass 1003.00 406172 -1068.49 5378.21 606748 363177 1133.98 292473 82.96 332495 102.87 3255.73 49.37 OSF 150 Pass 105000 4062.61 -1097.81 5418.71 607198 3632.33 1137.38 2927.67 82.56 3374.37 103.01 3305.06 50.04 OSF 1.50 Pass 1100.03 4063.50 -1127.12 5459.21 607649 3632.89 1140.73 2930.60 8215 3423.80 103.16 3354.39 50.70 OSF 1.50 Pass 1150.00 4064.38 -1156.43 5499.71 6081.00 3633.45 1144.11 293353 81.75 3473.24 103.30 3403.74 51.36 OSF 1.50 Pass 1200.00 4065.27 -11135.74 5540.21 608551 3634.01 1147.49 2936.47 81.36 352269 103.44 3453.10 52.02 OSF 1.50 Pass 1250.00 4066.16 -1215.05 5580.70 609001 3634.56 1150.86 2939.40 8096 3572.15 10358 350246 52.68 OSF 1.50 Pass 130000 4067.05 -1244.36 562120 609452 3835.12 1154.24 294233 80.58 3821.62 10372 3551.84 53.33 OSF1.50 Pecs 135000 406794 -1273.67 5861.70 6099.03 363588 1157.62 2945.27 80.19 3671.10 103.88 3031.22 53.99 OSF 1.50 Pass 1400.00 406879 -1302.96 5702.21 610385 3636.24 1161.01 2948.21 80.10 3720.513 104.03 3650.81 54.64 OSF 1.50 Pass 1450.00 4069.46 -133216 5742.79 6108.17 363682 1164.46 295122 79.72 3770.04 104.14 3699.98 55.29 OSF1.50 Pass 1503.00 4070.14 -1361.37 5783.37 6112.79 3637.39 1167.92 295422 7935 3819.51 104.29 374935 5594 OSF 1.50 Pass 155000 4070.82 -1380.57 5823.95 6117.40 363796 1171.38 295722 7898 3868.99 104.43 3798.73 56.58 OSF 1.50 Pass 160000 4071.50 -1419.77 586453 6122.02 363853 1174.84 2960.23 7862 3918.47 104.57 3848.12 5723 OSF1.50 Pass 1650.00 4072.18 -1448.97 5905.11 6126.63 363910 1178.29 2863.23 78.26 3967.97 104.72 3897.52 57.87 OSF 1.50 Pass 1700.00 4072.86 -1478.18 5945.69 6131.25 363988 1181.75 2966.23 77.91 4017.47 104.88 3946.92 58.51 OSF 1.50 Pass 1750.00 4073.54 -150738 5986.27 6135.86 364025 1185.21 296924 7756 4066.97 105.00 3996.33 59.15 OSF 1.50 Pass 1800.00 4074.22 -1536.58 6028.85 614048 3640.82 1188.67 297224 77.21 411649 105.15 4045.75 5979 OSF 1.50 Pass 1850.00 4074.90 -1565.79 6067.43 614509 364139 1192.12 297525 76.86 4166.01 105.29 4635.17 60.42 OSF 1.50 Pass 1903.00 4075.50 -1594.99 8108.01 6149.70 364196 1195.57 2978.24 78.89 421553 105.43 4144.60 81.06 OSF 1.50 Pass 1950.00 4075.36 -1624.22 6148.58 6154.18 3642.52 1198.93 2981.16 83.48 4264.98 105.57 4193.96 61.69 OSF 1.50 Pass 2000.00 4074.37 -1653.46 618912 6158.54 3643.06 1202.20 2984.00 86.73 4314.35 105.71 4243.24 6232 OSF 1.50 Pass 2050.00 4073.06 -1682.70 6229.66 616285 3643. 1205.43 2986.80 86.43 4363.70 10685 4292.50 6295 OSF 1.50 Pass 2100.00 4071.78 -1711.95 6270.19 6167.16 3644.13 1208.65 2989.61 86.14 4413.05 105.98 4341.76 63.58 OSF 1.50 Pass 2150.00 4070.45 -1741.19 6310.73 6171.47 3644 1211.88 299241 8584 4462.42 106.12 4391.04 64.21 OSF 1.50 Pass 2263.00 4089.15 -1770.44 6351.26 6175.78 3645 1215.11 2995.21 85.55 4511.80 106.25 4440.32 64.84 OSF 150 Pass 2250.00 4067.84 -179968 6391.80 618009 3645.73 1218.34 2998.02 85.26 4561.18 106.39 4499.62 65.46 OSF1.50 Pass 2300.00 4086.54 -182892 6432.33 618440 3646. 1221.57 3000.82 84.97 4610.57 106.52 4538.92 66.09 OSF1.50 Pass 2350.00 4065.23 -1858.17 6472.87 6188.71 364680 1224.80 3003.83 84.68 4659.98 106.66 4588.23 6671 OSF1.50 Penn 2400.00 4063.92 -1887.41 6513.40 6193.02 3647.33 1228.03 3006.43 84.40 4709.39 106.80 4837.55 67.33 050 1.50 Pass 2450.00 4062.92 -1916.66 6553.95 6197.37 3647.87 1231.28 3009.26 80.27 4758.84 106.93 4686.92 67.95 OSF 1.50 Pass 2500.00 4062.70 -1945.91 659449 6201.82 364842 1234.82 301216 76.70 4808.38 107.06 4736.36 68.57 OSF 1.50 Pass 2550.00 4062.66 -1975.16 6635.05 6206.29 3648.98 123796 3015.07 76.40 485794 107.20 4785.83 69.18 OSF 1.50 Pass 2600.00 4062.61 -2004.41 667560 6210.76 3649.53 1241.31 3017.97 76.11 4907.50 107.34 4835.30 69.80 OSF 1.50 Pass End of restate Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 15 of 137 0 Field: Nikeitchuq Well: SP09-N9 Structure: Spy Wend Borehole: SP09-N9L1 Slot: SP09 Trajectory: SP09-N9L1(P1) Client: Eni Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grld Convergence Angle: 0.09024571° Grid Scale Factor: 0.999900155 Magnetic Declination: 19.484° Magneto Declination Date: February 07,2014 Magnetic Model: BGGM 2013 Reference Point Nom Ligiafi Elevation Structure Unc. Slot Una 6053657 280(ftUS) 511668.320(ftUS) 54 100(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Trajectory Error Model:ISCWSAO 3-D 95.000%Con8denee 2.7955 sigma Surveying Plots While Drilling Description Part MD From(8) MD To(B)EOU Freq(R) Survey Tool Type Hole Size(in) Casing Diameter in) Borehole I Survey 1 0.000 41.030 1/100.000 SLB NSG+SSHOT-Depth Only-No Global 30.000 30.000 SP09-N9/SP09-N9(P1) 1 41.000 1000.000 1/100.000 SLB_NSG+SSHOT-No Global 30.000 30.600 SP09-99/SP09-N9(P1) 1 1000.000 10400.000 1/100.000 SLB MWD+GMAG-No Global 30.000 30.000 SP09-N9/SP09-N9(P1) 1 10400000 18372.567 1/100.000 SLB_UNKNOWN-No Global 30.000 30.000 SP09-N9L1/SP09-N9L1(P1) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference ND 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) (fl) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) All local minima indiceted. Results filtered:Depth 6100.00 ft<-MD sa 18128.61 ft Results filtered:Ct-Ct separation es 1500.00 ft Results highlighted:Ct-Ct separation<_1320.00 ft 6100.00 4028.97 1797.48 140589 5625.35 357697 802.78 263702 143.77 1646.03 87.20 1587.26 28.92 OSF1.50 Pass 6150.00 4031.82 1772.50 1449.10 5835.11 3578.18 810.09 2643.37 143.39 1599.47 87.24 1540.67 28.09 OSF 1.50 Pass 6200.00 4034.07 1746.44 1491.71 5643.59 3579.23 816.45 2648.89 140.21 1552.69 87.23 1493.89 27.27 OSF 1.50 Pass 6250.00 4035.84 1718.95 1533.44 5850.38 358007 821.53 2653.31 138.71 1505.72 87.17 1446.97 26.46 OSF 1.50 Pass 6300.00 4037.11 1690.07 1574.23 5655.45 3580.70 825.33 2656.61 132.99 1458.64 87.05 1399.97 25.67 OSF 1.50 Pass 6350.00 4037.89 1659.86 1614.06 5658.83 3581.12 827.86 2658.81 129.78 1411.51 86.88 1352.95 24.89 OSF 1.50 Pas 8400.00 4038.51 1629.18 1853.54 5661.62 3581.47 829.95 2680.62 129.45 1364.51 86.66 1306.09 24.12 OSF 1.50 Paas 6450.00 403913 1598.51 169302 5664.10 3581.81 832.04 266244 129.11 131772 8642 1259.47 2336 OSF 1.50 Pass 6500.00 4039.74 156783 1732.50 5667.19 3582.16 83412 2664.25 128.78 127117 86.14 121311 2261 OSF 1.50 Pass 6550.00 4040.36 1537.15 177198 5689.98 3582.50 83621 266606 128.44 122488 85.83 1187.03 21.86 OSF 1.50 Pass 6600.00 4040.97 1506.48 1811.46 567277 358285 838.30 266788 128.11 117890 85.46 1121.28 21.13 OSF 1.50 Pass 6650.00 4041.54 1475.99 1851.08 5675.78 3583.22 840.56 2689.84 129.03 1133.22 8506 1075.87 20.41 OSF 1.50 Pass 6700.00 4041.70 144654 1891.49 5680.04 3583.75 84375 2672.61 129.77 108777 ' 84.65 1030.69 19.69 OSF 1.50 Pass 6750.00 404178 141729 1932.04 5684.52 3584.31 847.11 267553 12923 1042.67 8418 985.91 18.98 OSF 1.50 Pass 6800.00 4041.86 1388,04 197259 5689.01 3584.86 850.47 267845 12868 998.03 83.64 941.63 18.28 OSF 1.50 Pass 6850.00 4041.93 135878 2013.13 5693.49 358542 853.82 2681.36 128.13 953.90 83.02 897.91 17.61 OSF 1.50 Pass 6900.00 4042.01 132953 205368 569797 3585.97 857.18 2684.28 127.58 910.35 8229 854.85 18.95 OSF 1.50 Pass 6950.00 4042.09 130028 209423 5702.46 3586.53 860.54 2687.20 12702 867.47 81.46 812.53 16.32 OSF 1.50 Pass 7000.00 4042.16 1271.02 213478 5706.94 3587.09 863.90 2690.12 12647 825.37 80.48 771.08 15.72 OSF 1.50 Pass 7050.00 4042.24 124177 2175.33 5711.42 3587.64 867.26 2693.03 12591 78418 79.38 73062 15.15 OSF 1.50 Pass 7100.00 4042.32 1212.52 2215.88 5715.91 3588.20 87062 2695.95 125.35 744.03 78.08 651.34 14.82 OSF 1.50 Pass 7150.00 4042.44 1183.26 225643 5720.39 3588.75 873.98 2698.87 12480 705.15 76.58 653.48 14.13 OSF 1.50 Pass 7200.00 4043.24 1154.01 2296.97 5724.97 3589.32 87740 2701.85 12426 66819 74.82 617.67 13.71 OSF 1.50 Pass 7250.00 4044.68 1124.77 2337.51 5729.62 3589.90 880.89 270487 123.71 633.46 7280 584.29 13.37 OSF 1.50 Pass 7300.00 4046.15 1095.54 2378.04 5734.27 359047 884.38 2707.90 123.14 600.87 ' 7051 553.22 13.10 OSF 1.50 Pass 735000 404763 106630 2418.57 5738.93 359105 887.86 2710.93 12257 57077 68.02 52478 12.91 OSF 130 Pass 7400.00 4049.10 1037.06 2459.11 5743.59 359163 89135 2713.96 122.01 543.57 65.36 499.36 12.81 OSF 1.50 Pass 7450.00 4050.58 100782 2499.64 574824 3592.21 89484 2716.99 121.44 519.72 6266 477.3. OSF 150 Pass 7500.00 405205 978.58 2540.17 5752.90 359278 898.33 2720.03 120.87 49972 60.10 459.01 I OSF 1.50 Pass 7550.00 4053.53 949.34 258070 5757.56 3593.36 901.82 2723.06120.30 484.02 57.03 44536 13.12 OSF 1.50 Pass 65 70.00 4055.00 920.10 2621.24 5762.21 359394 905.31 2726.09 '1 119.73 473.07 55.37 43551 13.22 OSF 150 Pass 7650.00 4056.47 89086 2661.77 5766.87 3594.51 908.79 2729.12 119.16 487.19 54.76 430.00 13.21 OSF 1.50 Pass 7670.89 4057.09 878.65 2878.70 5768.82 3594.75 91025 2730.38 \ 118.E=,q��ii(p�� 5486 429.08 13.16 OSF 1.50 Pass 7700.00 4057.80 861.62 270231 5771.51 359509 912.27 2732.13 ! 118.59 466.43 5534 48.391 13.04 OSF 1.50 Pass 8.3 7750.00 4053 83237 2742.85 5776.05 3595.65 915.67 2735.09 118.05 470.18 57.12 431.47 12.72 OSF 1.50 Pass 7650.00 4058.41 803.12 278340 5780.53 359621 919.03 2738.01 117.50 478.67 59.80 438.16 12.36 OSF 1.50 Pass 7850.00 4058.48 773.87 2823.95 578502 3596.76 922,39 274093 116.95 492.07 6305 449.40 12.03 OSF 1.50 Pass 7900.00 4058.56 744.62 286450 578950 359732 92575 2743.84 116.41 510.01 6553 465.02 OSF 1.50 Pass 7950.00 4058.63 715.37 290506 579399 3597.87 929.11 2746.76 115.86 532.01 6997 484 OSF 1.50 Pass 8000.00 4058.71 686.11 2945.61 5798.47 3598.43 932.47 2749.68 115.31 55761 7319 50818 OSF 1.50 Pass 8050.00 4058.78 65686 2986.16 580296 3598.99 935.83 2752.60 114.77 586.33 7613 534.94 11.81 OSF 1.50 Pass 8100,00 4058.86 627.61 3026.71 580744 3599.54 939.19 2755.52 114.22 617.73 7874 564.60 12.02 OSF 1.50 Pass 815000 4058.93 598.36 306726 5811.93 3600.10 942.55 2758.44 113.68 651.43 81 03 598.77 12.32 OSF 1.50 Pass 8200.00 405901 569.11 310781 581641 3600.65 945.91 2761.36 113.13 68709 83.02 631.10 12.67 OSF 1.50 Pass 8250.00 405903 539.87 314837 5820.91 3601.21 949.28 2764.28 112.49 724.38 8475 667.24 13.08 OSF 1.50 Pass 8300.00 4058.96 510.67 3188.95 5825.44 3801.77 95267 276723 111.94 76305 86.26 704.90 13.54 OSF 1.50 Pass 8350.00 4058.90 481.47 3229.54 582996 3602.33 956.06 2770.17 111.40 80294 87.57 743.92 14.03 OSF 110 Pass 8400.00 4058.84 452.26 3270.12 5834.49 3602.89 95845 2773.12 110.66 843.88 88.71 784.10 14.55 OSF 150 Pass 845000 4058.77 423.06 331071 583901 360346 96284 2776.06 110.32 885.73 89.72 82528 15.10 OSF 150 Pass 8500.00 4058.71 39385 335129 5843.54 3604.02 968.23 2779.01 119.78 928.37 90.60 867.33 15.67 OSF 160 Pass 8550.00 4058.64 364.65 339188 5848.07 360458 96962 2781.95 109.24 97168 9138 91013 16.26 OSF 1.50 Pass 8600.00 4058.58 33545 343246 5852.59 3605.14 973.01 2784.90 108.70 015.60 92.07 953.58 16.87 OSF 160 Pass 8650.00 4058.51 308.24 347305 5857.12 360570 976.40 2787.84 108.17 060.03 9269 997.59 17.48 OSF 160 Pass 8700.00 4058.45 277.04 351363 586164 3806.26 979.79 2790.79 107.64 10492 93.25 104211 18.12 OSF 1.50 Pass 8750.00 4058.13 247.82 355420 5866.11 3606.81 983.14 2793.70 107.83 150.11 93.76 1086.97 18.75 OSF 1.50 Pass 880000 4056.98 218.54 3594.72 587040 3607.35 986.35 279649 106.17 195.35 94.22 113190 19.39 OSF 150 Pass 8850.00 4055.51 189.23 363520 587461 3607.87 989.50 279923 107.70 24084 94.66 1177.09 20.04 OSF 150 Pass 8900.00 4054.05 159.93 367569 5878.83 360839 992.66 2801.97 107.23 286.64 95.05 122263 2069 OSF 160 Pass 8950.00 4052.59 130.62 3716.17 5883.04 3608.91 995.82 2804.71 108.77 332.73 85.42 1268.48 21.35 OSF 1.50 Pass 9000.00 4051.13 101.32 3756.66 5887.25 3609.43 998.97 2807.45 106.31 379.08 95.75 1314.61 22.01 OSF 1.50 Pas 9050.00 4049.67 72.01 3797.15 5891.46 3609.96 100213 281020 105.85 425.67 9606 1380.99 2268 OSF 1.50 Pas 8100.00 4048.21 42.71 383763 5895.68 361049 1005.28 2812.94 105.39 472.47 96.36 1407.59 23.36 OSF1.50 Pass 9150.00 4046.74 13.40 387812 5899.89 3611.00 1008.44 2815.68 104.93 519.46. 9663 145440 2403 OSF1.50 Pass Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\S107-SE4\S107-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 16 of 137 4111 • Trajectory:5107-SE4(P3)Vs.SP09-N9L1(P1) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference ND Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (9) (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) (ft) 9200.00 4045.28 -15.90 3918.60 5904.10 3611.52 1011.60 2818.42 10447 1566.62 96.89 1501.39 24.71 OSF 1.50 Paso 9250.00 4043.82 -4521 3959.09 5908.32 3612.04 1014.75 2821.16 10402 1613.94 97.13 1548.55 25.39 OSF 150 Pass 9300.00 404278 -74.49 3999.60 5912.61 3612.58 1017.97 2823.96 10211 1661.53 97.36 1595.98 26.08 OSF 1.50 Pass 9350.00 4042.42 -103.74 4040.15 5917.04 3613.13 1021.29 282684 101.05 1709.42 9757 1643.73 2678 OSF 1.50 Pass 9400.00 404211 -133.00 4080.70 5921.48 3613.68 1024.61 2829.73 100.55 175742 9778 1691.60 27.47 OSF 150 Pass 945000 4041.80 -162.25 4121.25 5925.92 3614.23 1027.94 283261 10005 1805.53 97.99 1739.57 2816 OSF1.50 Pass 9500.00 4041.50 -191.50 4161.80 5930.35 361478 103126 2835.50 99.56 1853.72 98.18 1787.63 28.65 OSF 1.50 Pass 9550.00 4041.19 -220.75 4202.35 5934.79 3615.33 1034.59 2838.39 9907 1902.00 98.38 1835.78 29.55 OSF1.50 Pass 9600.00 4040.89 -250.00 4242.90 593923 3615.88 1037.91 2841.28 98.59 1950.35 9856 188401 3024 OSF 1.50 Pass 965000 4040.58 -279.25 4283.45 5943.67 3616.43 1041.24 2844.17 98.10 1998.78 98.74 1932.31 30.93 OSF 1.50 Pass 9700.00 4040.27 -30850 4324.00 594811 3616.98 1044.56 2847.06 97.62 2047.27 9892 1980.68 31.63 OSF 1.50 Pass 975000 403997 -33775 436455 595255 3617.53 1047.89 2849.94 97.15 2095.82 99.09 202912 32.32 OSF1.50 Pass 980000 4039.66 -367.00 4405.10 5956.98 361808 1051.21 2852.63 96.67 2144.43 9926 2077.62 33.01 OSF1.50 Pass 9850.00 403947 -396.21 4445.68 5961.48 3618.63 1054.58 285576 95.53 2193.11 93.42 2126.19 3371 OSF 1.50 Pass 9900.00 4039.32 -425.41 4486.26 5968.00 3619.19 1057.96 2858.70 95.06 224185 99.59 217482 3440 OSF 1.50 Pass 9950.00 4039.18 -454.62 4526.85 5970.51 3819.75 1061.34 2861.64 94.58 229063 99.75 2223.49 3509 OSF1.50 Pass 0000.00 4039.00 -483.82 456743 5975.03 362031 1064.72 286457 94.11 233945 9991 2272.21 35.78 OSF 1.50 Pass 005000 4038.84 -513.03 4808.02 5979.54 3820.87 1068.11 2867.51 93.65 238831 10007 232096 36.47 OSF1.50 Pass 0100.00 403868 -542.23 4648.60 598405 362143 1071.49 2870.45 9318 2437.21 100.22 236976 37.16 OSF 1.50 Pass 0150.00 403852 -571.44 4689.18 598857 3621.99 1074.87 2873.38 92.72 2486.15 100.38 2418.59 37.85 OSF 1.50 Pass 0200.00 403836 600.64 472977 5993.08 362255 1078.25 2876.32 82.27 2535.12 10053 2467.46 38.53 OSF 1.50 Pass 0250.00 4038.28 -629.84 4770.35 5997.60 362311 108164 2879.26 90.62 258413 100.68 2516.38 39.22 OSF 1.50 Pass 0300.00 4038.93 659.06 4810.93 6002.20 3623.68 1085.08 288226 86.99 2633.29 100.83 2565.43 39.91 OSF 1.50 Pass 0350.00 404045 -68827 4851.47 6006.89 362426 1088.00 2885.31 8345 268259 100.87 2614.63 40.59 OSF 1.50 Pass 0400.00 4042.29 -717.50 4892.00 6011.59 362485 109212 2888.37 8294 2731.94 101.12 2863.89 4128 OSF1.50 Pass 0450.00 404413 -748.73 493252 6016.30 362543 1095.64 2891.43 8245 2781.31 10127 2713.16 41.96 OSF1.50 Pass 0500.00 4045.97 -775.96 497305 6021.00 362601 1099.16 2894.49 8196 2830.70 101.42 2782.45 4264 • OSF 1.50 Pass 0550.00 4047.81 -805.19 501357 602570 362659 1102.88 2897.55 81.47 288010 101.57 2811.75 43.32 OSF 1.50 Pass 0600.00 404965 -834.43 5054.09 6030.40 3627.18 1106.21 2900.61 80.99 2929.51 101.71 2861.06 44.00 OSF 1.50 Pass 0650.00 4051.49 -863.66 5094.62 6035.10 3627.76 1109.73 290367 80.52 297893 101.86 291039 4468 OSF 1.50 Pass 0700.00 4053.33 -89289 5135.14 6039.80 362834 1113.25 2906.73 80.05 3028.37 102.01 2959.72 4535 OSF 1.50 Pass 0750.00 4055.17 -922.12 517566 8044.51 3628.92 1116.77 2909.79 7959 3077.82 102.16 3009.07 46.03 OSF1.50 Pass 0800.00 4057.01 -95135 521619 6049.21 3629.51 1120.29 291285 79.14 3127.27 10230 3058.43 46.70 OSF1.50 Pass 0850.00 4058.80 -980.58 525671 6053.90 3630.09 1123.81 291590 8044 3176.74 10245 3107.80 47.37 OSF1.50 Pass 0900.00 4059.94 -100987 5297.22 6058.46 363065 1127.23 291887 83.79 3226.15 102.59 3157.11 48.04 OSF 1.50 Pass 0950.00 406083 -1039.18 5337.71 6062.97 3631.21 1130.60 2921.80 83.38 3275.54 102.73 3206.42 48.71 OSF 1.50 Peso 1000.00 4061.72 -1068.49 537821 6067.48 3631.77 1133.98 2924.73 82.96 332495 102.87 325573 4937 OSF1.50 Pass 1050.00 406261 -1097.81 541871 6071.98 3632.33 1137.36 2927.67 82.56 337437 103.02 3305.05 5004 OSF 1.50 Pass 1100.00 4063.50 -1127.12 5459.21 6076.49 3632.89 1140.73 2930.60 82.15 342380 103.16 335439 50.70 0571.50 Pass 1150.00 4064.38 -1156.43 5499.71 6081.00 3633.45 1144.11 293353 81.75 347324 10330 3403.74 51.36 OSF 1.50 Pass 1200.00 4065.27 -118574 5540.21 6085.51 3634.01 1147.49 2936.47 81.36 3522.69 103.44 3453.10 52.02 OSF 1.50 Pass 1250.00 4066.16 -121505 5580.70 6090.01 3634.56 1150.86 2939.40 80.96 3572.15 103.58 350246 52.68 OSF1.50 Pass 1300.00 4067.05 -124436 5621.20 6084.52 3635.12 1154.24 2942.33 80.58 3621.62 103.72 3551.84 53.33 OSF 1.50 Pass 1350.00 4067.94 -127367 566170 6099.03 363.566 1157.62 294527 8019 3671.10 103.86 360122 53.99 OSF 1.50 Pass 1400.00 4068.79 -130296 5702.21 6103.55 3635.24 1161.01 294821 80.10 372058 104.00 365061 5464 OSF 1.50 Pass 1450.00 4069.46 -1332.16 5742.79 6108.17 3636.82 1164.46 2951.22 79.72 377004 104.14 3699.97 5529 OSF 1.50 Pass 1500.03 407014 -1361.37 5783.37 611279 3637.39 1167.92 295422 79.35 3819.51 104.29 3749.35 55.94 OSF 1.50 Pass 1550.00 4070.82 -139057 5823.95 6117.40 3637.96 1171.38 2957.22 78.98 3868.99 104.43 3798.73 56.58 OSF 1.50 Pass 1600.00 407150 -141977 586453 612202 3638.53 1174.84 2960.23 7862 391847 104.57 3848.12 5723 OSF 1.50 Pass 1600.00 4072.18 -1448.97 5935.11 6126.63 3639.10 1178.29 2963.23 7826 396797 104.72 3897.52 5787 OSF 1.50 Pass 1700.00 407286 -147818 5945.69 6131.25 363968 1181.75 2966.23 77.91 401747 104.86 3946.92 5851 OSF1.50 Pass 1750.00 407354 -150738 598827 6135.86 3640.25 1185.21 296924 77.56 406697 105.01 399633 59.15 OSF 1.50 Pass 1800.00 4074.22 -153658 6026.85 6140.48 3640.82 1186.67 2972.24 77.21 411649 105.15 404575 59.79 OSF 1.50 Pass 1850.00 4074.90 -156579 6067.43 6145.09 3641.39 1192.12 2975.25 76.86 416601 105.29 4085.17 6042 OSF 1.50 Pass 1900.00 407550 -159499 6108.01 6149.70 364196 1195.57 2978.24 78.89 421553 105.44 414460 61.06 OSF 1.50 Pass 1950.00 4075.36 -162422 614858 6154.18 3642.52 1198.93 2981.16 83.46 426498 105.58 4193.96 6169 OSF 1.50 Pass 2000.00 4074.37 -165346 6189.12 6158.54 364306 1202.20 2984.00 86.73 431435 105.71 424324 8232 OSF 1.50 Pass 2050.00 4073.06 -168270 622968 6162.85 3643.59 1205.43 2986.60 86.43 4383.70 105.85 429250 6295 OSF 1.50 Pass 2100.00 4071.76 -1711.95 6270.19 6167.16 3644.13 1208.65 2989.61 88.14 441305 105.98 4341.76 6358 OSF 1.50 Pass 2150.00 4070.45 -1741.19 631073 6171.47 364466 1211.88 2992.41 85.84 4462.42 106.12 4391.03 64.21 OSF 1.50 Pass 2200.00 4060.15 -177044 635126 6175.78 3645.19 121511 2995.21 85.55 4511.80 106.25 444032 6484 OSF 1.50 Pass 2250.00 4067.84 -179968 639180 6180.09 3645.73 1218.34 2998.02 8526 456118 106.39 4489.61 6546 OSF1.50 Pass 2300.00 4066.54 -1828.92 6432.33 6184.40 3646.26 1221.57 3000.82 8497 461057 10053 4538.92 6608 OSF 1.50 Pass 2350.00 4065.23 -1858.17 647287 6188.71 3646.80 1224.80 3003.63 84.68 4659.98 106.66 4588.23 66.71 OSF 1.50 Pass 2400.00 406392 -1887.41 6513.40 6193.02 364733 1228.03 300643 84.40 4709.39 106.80 463755 67.33 OSF 1.50 Pass 2450.03 406292 -1916.66 6553.95 6197.37 3647.87 1231.28 3009.28 80.27 4758.84 106.93 4686.91 6795 OSF 1.50 Pass 2500.00 4062.70 -194591 6594.49 6201.82 364842 1234.62 3012.16 76.70 4608.38 107.07 4736.36 68.57 OSF 1.50 Pass 2550.00 406266 -1975.16 6635.05 6206.29 3648.98 1237.96 3015.07 76.40 485794 107.21 4785.83 60.18 OSF 1.50 Pass 2600.03 406261 -2004.41 667560 6210.76 3649.53 124131 3017.97 76.11 4907.50 107.35 4835.30 69.79 OSF 1.50 Pass End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\S107-SE4\S107-SE4(P3) 7/8/2014 9:06 AM Page 17 of 137 0 • Field: Nikeftlwq Well: SP72SE3 Structure: Spy Island Borehole: SP12SE3L7 Slot SP72 Trajectory: SPI2SE3L1 currant Client: Eni Petroleum Type: Nun-Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04.US Feet North Reference: True Grid Convergence Angle: 0.09006289` Grid Scale Factor 0.999900154 Magnetic Declination: 19.313. Magnetic Declination Date: July 02.2014 Magnetic Model: BGGM 2014 Reference Point Nor Fasting Eleva5on Structure Unc. Slot Use. 6053652 820(ftUS) 511644 690(ftUS) 53930(ft)MSL 0.000(ft)(1 sigma) (m00(8)(1 sigma) Tralectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prow As Drilled Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Slat On) Casing Dlameser On) Borehole I Survey 0.000 40.830 Act-Stns SLB NSG.tSSHOT-Daptr Only-No Global 18.000 13.375 SP72-SE3/5P12-5E3 40.830 1290.720 Act-Stns SLB_NSG0SSHOT-No Globe 16.000 13.375 SP72-0E3/SP72SE3 1290.720 2801.150 Act-Stns SLB MWDFGMAG-No Globs 16.000 13.375 SP72-SE3/SP726E3 2801.150 2915540 Act-Stns SLB_MWD-INC ONLY FILLER-No Goba 12.250 9.625 SP12-0E3/SP72SE3 2915540 4970.140 Act-Stns SLB_MWO+GMAG-No Globe 12.250 9.025 SP72SE3/SP72SE3 4970.140 4982.000 ActSMs SLB_MWD+GMAC-No Goba 12.250 9.625 SP72-SE3L7/SP72-SE3L7 anent 4992.000 5184.890 Act-Stns SLB_MWO-INC_ONLY FILLER-No Globe 8.750 5.500 SP72-SE3L7/SP72-SE3L7 current 5184.890 15178.460 ActStns SLB MWD+GMAC-No Globe 8.750 5.500 SP72-SE3L7/SP72-SE3L7 anent 15178.460 15245.000 Act-Stns SLB BLINDOTREND-No Goba 8.750 5.500 SP72SE3L1/SP12-SE3L7 current Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (5) (9) (ft) (fn) (ft) (ft) (ft) (ft) (1 (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 6100.00 ft<=MD 0=16128.61 ft Results filtered:Ct-Cteeparabon<=1500E0 ft Results highlighted:Ct-Ct separation<=1320.00 ft 6100.00 4028.97 179748 1405.89 5589.39 401689 708.67 936.08 208.83 118591 06.33 1114.69 1687 OSF 1.50 Pass 6150.00 4031.82 1772.50 1449.10 5600.34 4018.44 696.18 96436 209.52 1180.51 06.59 1109.12 1675 OSF 1.50 Pass 6200.00 4034.07 1746.44 1491.71 5631.31 4020.09 68324 992.45 211.43 1174.67 06.94 1103.05 1662 OSF 1.50 Pass 6250.00 4035.84 1718.95 1533.44 5662.90 4021.67 66959 020.88 213.39 1167.94 07.48 1095.95 18.44 OSF 1.50 Pass 6300.00 4037.11 1690.07 1574.23 565.71 4023.90 654.99 050.19 215.40 1160.26 08.04 1087.91 16.24 OSF 1.50 Pass 6350.00 4037.89 165986 1614.06 5728.46 4026.09 639.99 079.23 217.13 1151.66 08.78 1078.81 16.01 OSF 1.50 Pass 8400.00 4038.51 1629.18 1653.54 5761.33 402842 62454 108.14 217.22 1143.18' 09.60 1069.79 1577 OSF 150 Pass 8450.00 4039.13 1598.51 1693.02 5794.41 4030.59 608.57 13703 217.31 1135.42 1060 1061.36 15.52 OSF 1.50 Pass 6500.00 4039.74 1567.83 1732.50 5827.66 4032.52 592.09 16584 217.38 1128.37 11.59 1053.84 15.29 OSF 1.50 Pass 6550.00 4040.36 1537.15 1771.98 5858.03 403403 576.65 191.95 217.44 1122.07 12.76 1046.57 15.04 OSF 1.50 Pass 6600.00 404097 150648 1811.46 5887.03 4035.13 561.43 218.61 217.48 1118.68. 1390 1040.42 1482 OSF 1.50 Pass 6650.00 404154 147599 1851.08 5916.16 4035.86 545.69 241.11 218.50 1112.45 1515 103535 14.60 OSF 100 Pass 670080 4041.70 1448.54 189149 5949.34 4036.32 527.25 288.69 215.53 1110.41 1855 1032.38 1440 OSF 1.50 Pass 6750.00 404178 1417.29 1932.04 5987.34 4036.74 505.76 300.03 215.55 11If11109.20 18.20 1030.07 14.18 OSF 1.50 Pass mono 404106 138804 1972.59 602536 4037.11 93 331.15 215.56 19.86 102030 1397 OSF 150 Pass 6850.00 201213 6064.60 403737 h 21.73 690900 404201 1329 3 2053.68 6103.81 4037.40 �.90 394..07 71 215.57' 71 2359 1 1026.91 .00 13.55 OSF 1.50 Pass 6950.00 404209 1000.28 2094.23 6144.19 4037.24 413.77 427.06 215.58 1109.52 2563 102544 13.34 OSF 1.50 Pass 7000.00 4042.16 1271.02 2134.78 6185.24 4037.06 388.96 459.75 215.55 1110.73 27.71 1025.27 1914 OSF 150 Pass 7050.00 404224 1241.77 217533 6249.46 4036.70 349.98 510.79 215.52 1112.17 30.41 102490 12.88 OSF1.50 Pass 7100.00 404232 1212.52 221588 6325.41 4035.93 305.64 572.44 215.48 1111.97 33.32 102277 12.59 OSF 1.50 Pass 7150.00 4042.44 1183.26 2256.43 6365.76 4035.89 282.14 805.25 215.4 35.61 1021.06 12.38 OSF 1.50 Pass 7200.00 4043.24 1154.01 229697 640585 4036.34 25864 63748 215.47 37.848 21548 1114.18 ,6 1019.488222 1218 OSF 1.50 Pass 7250.00 4044.69 .77 751 6443.26 4037.30 23E17 .62 215.46 1112.84 40.16 11.98 OSF 150 Pa. 11.80 OSF 1.50 Pass 7350.00 7300.00 4047.63 106630 15 54 24 857 .75 4041.18 1 .07&Isom 403085 21339 �28 215.54 1116.00 45.11 101893 11.60 OSF 1.50 Pass 7400.00 4049.10 1037.06 2459.11 6569.08 4043.64 15912 766.87 215.61 1118.03 47.80 1Q019.17 11.41 OSF 1.50 Pass 7450.00 .58 7.82 00 4046.95 2726 807.23 21569 5072 19.39 11i1 OSF 1.50 Pass 7500.00 4052.05 197858 2.1177 0575.81 4049.98 193.25 850.66 215.76 1122.15 5374 1619.33) 14.3 OSP 1.50 PPass ass 7550.00 405353 94934 2580.70 6726.93 4052.40 6192 890.94 215.81 1123.96 18.55 104466 7600.90 4055.00 920.10 262124 6776.81 405433 31.35 930.30 215.83 1125.74 1901 1045.73 14.23 OSF 1.50 Pass 7650.00 4056.47 89088 266177 6818.15 4055.85 5.86 962.02 215.84 1127.72 20.30 1047.19 1416 OSF 1.50 Pass 7700.00 4057.80 861.62 270231 6859.46 4056.78 -19.86 995.13 215.81 1130.09 21.19 1049.04 14.10 OSF 1.50 Pass 775000 4058.33 832.37 274285 689769 4057.0 -4392 202483 21577 1132.90 21.83 1051.35 14.05 OSF 1.50 Pass 7800.00 4058.41 80312 2783.40 693529 4058.12 -6791 2053.78 215.80 1138.24 2255 105421 1401 OSF 1.50 Pass 785000 4058.48 77387 2823.95 6980.34 4058.51 -96.99 2088.18 215.81 1140.07 23.52 1057.39 1394 OSF 1.50 Pass 7900.00 4058.56 74462 2864.50 7038.92 4059.82 -134.62 213306 215.87 1143.70 24.91 1060.11 13.83 OSF 1.50 Pass 7950.00 4058.63 71537 2905.06 7092.48 4061.77 -168.75 2174.28 215.97 1147.04 26.15 1082.62 13.73 OSF 1.50 Pass 8000.00 405871 68611 2945.61 714446 4063.69 -201.81 221435 218.06 1150.29 2734 1085.06 13.64 OSF 1.50 Pass 8050.00 4058.78 65686 2986.16 7266.39 4066.67 -276.03 231102 218.20 115551.579 30.47 1064.28 13.33 OSF 1.50 Pass 8100.00 627 61 71 26 4067.86 -31043 32.13 109215 13.16 OSF 1.50 Pass 2 11 820.00 4059.01 569.1136 3110886 73.25 4068.66 -357.22 239657 216ii(,0 3302 12.98 OSF 1.50 Pass 70 13.06 OSF 1.50 Pass 8200.00 4059.01 569.11 3107.81 7406.25 4068.69 -357.22 2424.87 216.29 11 xU 8250.00 4059.03 53987 3148.37 7457.88 4069.03 -387.99 246633 216.23 115181 35.20 6300.00 4058.96 510.67 3188.95 7528.08 4070.23 -428.99 252329 21630 115180 3700 1059.94 12.69 OSF 1.50 Pass 8350.00 4058.90 481.47 3229.54 7576.73 407125 -457.12 2562.98 216.35 1151.26 38.29 1058.75 12.57 OSF 1.50 Pass 840000 4058.84 452.26 3270.12 7624.53 407213 -484.81 2601.93 216.40 1150.99 3956 1057.02 12.45 OSF1.50 Pass 8450.00 4058.77 423.06 331071 7689.72 4072.81 -511.12 2638.66 218.44 4081 1056.68 12.34 OSP 1.50 Pass 8500.00 4058.71 393.85 3351.29 7719.70 4073.36 -540.37 267919 216.47 42.18 1055.84 12.22 OSF 1.50 Pass 8550.00 4058.64 364.65 339188 7791.36 407379 -581.66 273776 216.49 115048 4409 1054.10 1205 OSF 1.50 Pass 8600.00 4058.58 335.45 3432.46 7846.06 407377 -612.64 278284 216.50 1149.39 45.57 1052.02 11.91 OSF 1.50 Pass 6020.00 4058.51 308.24 3473.05 7898.63 407336 842.31 2826.23 216.48 1148.19 47.02 1049.85 11.78 OSF 1.50 Pass 870000 4058.45 277.04 351363 7953.48 407266 -67312 2871.60 216.45 1146.62 48.53 1047.47 11.85 OSF 150 Pass 8750.00 4058.13 247.82 3554.20 8010.41 407177 -794.88 2918.85 218.52 1145.20 50.10 1044.81 11.51 OSF 1.50 Pass 8800.00 4056.98 218.54 3594.72 8070.62 4071.00 -738.06 2969.08 216.68 1143.11 51.74 104162 11.36 OSF 150 Pass 8850.00 4055.51 189.23 3635.20 812308 4070.36 -76671 3013.02 216.73 1140.68 53.25 1038.19 11.23 OSF 1.50 Pass 8900.00 4054.05 159.93 3675.69 8174.02 4002.49 -794.48 3055.71 218.76 1138.20 54.74 103472 11.09 OSF 1.50 Pass 8950.00 4052.59 13062 3716.17 8217.16 4068.66 -81810 3091.81 218.78 113585 56.09 103146 10.87 OSF 1.50 Pass Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 28 of 137 I Trajectory.S107-SE4(P3)Vs.SP12-SE3L1 current Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (8) (6) (8) (8) (8) (8) (6) (6) (') (ft) (9) (R) 9000.00 4051.13 375686 8260.33 4067.80 -841.94 312778 216.81 113 .1 1028.51 10.86 OSF 1.50 Pass 905000 4049.67 3797.15 8304.14 406722 -866.35 3164.16 218.64 113_ 1025.83 1075 OSF 1.50 Pass 9100.00 4048.21 383783 834809 4086.73 -891.03 3200.52 216.88 113054 16119 1023.41 10.64 OSF 150 Pass 9150.00 4048.74 1340 3878.12 839173 4068.45 -915.73 3236.50 216.93 112931 161.57 1021.27 10.54 OSF 1.50 Pass 920000 4045.28 15.90 3918.60 8435.25 4066.42 -940.56 3272.24 217.00 1128.37 16295 101941 10.44 OSF 1.50 Pass 925000 4043.82 4521 3959.09 847672 4066.57 -964.43 3306.15 217,0 164.29 1017.89 10.35 OSF 1.50 Pass 9300.00 4042.78 -74.49 3999.60 851666 4066.68 -987.70 3338.61 217 16548 1016.93 10.27 OSF 1.50 Pass 9350.00 4042.42 -10374 4040.15 8559.11 4068.67 -101274 3372.89 21703 11 166.72 1016.40 10.20 OSF 1.50 Pass 9400.00 4042.11 -13300 4080.70 8809.84 4066.66 -1042.75 3413.79 21705 112828 16822 1015.81 10.11 OSF 150 Pass 9450.00 4041.80 -16225 4121.25 8666.33 406679 -1076.07 3459.40 217.07 112860 169.96 1014.97 10.01 25F1.50 Pass 9500.00 4041.50 -19150 4161.80 8731.80 406800 -1114.08 3512.70 217.15 112836 171.91 1013.43 9.89 OSF 150 Pass 9550.00 4041.19 -22075 4202.35 6782.49 4069.45 -1143.19 355418 217.24 112775 173.53 1011.74 880 OSF 1.50 Pass 9800.00 4040.89 -250.00 4242.90 8832.32 4070.76 -117180 3594.95 217.33 112714 175.13 1010.06 970 OSF 1.50 Pass 9650.00 4040.58 -279.25 428345 6879.35 4071.93 -119866 3833.40 217.40 1126.61 176.69 1008.49 961 OSF1.50 Pass 9700.00 4040.27 -30850 432400 8825.76 4073.04 -122567 3671.27 217.4711 178.23 1007.05 952 OSF1.50 Pass 9750.00 4039.97 -33775 4364.55 8987.37 4073.88 -124989 3705.06 217.5 as 179.68 1005.98 945 OSF 1.50 Pass 9800.00 4039.66 387.03 440510 9008.99 4074.48 -1274.38 3738.72 217.57 i 181 9.37 OSF 1.50 Pass 9850.00 4039.47 -396.21 4445.68 9050.67 4074.92 -1299.17 3772.24 217.54 1128.99 182 9.31 OSF 1.50 Pass 9900.00 4039.32 -425.41 4486.28 9092.36 4075.30 -1324.21 380557 217.56 1128.04 18376 9.25 OSF 1.50 Pass 9950.00 403916 -454.62 4526.85 9139.72 407563 -1352.87 3843.27 21759 1129.37 185.35 1005.47 9.18 OSF 1.50 Pass 0000.00 4039.00 -483.82 4567.43 9190.44 4075.73 -1383.57 3883.64 217.80 1130.69 187.03 1005.67 9.11 OSF 1.50 Pass 0050.00 4038.84 -513.03 4608.02 9240.76 4075.75 -1414.01 3923.71 217.60 113199 18870 1005.86 9.04 OSF 1.50 Pass 0100.00 403868 -542.23 4648.60 9290.98 4078.16 -1444.37 3963.71 217.63 1133.28 190.36 100604 8.97 OSF 1.50 Pass 0150.00 4038.52 -571.44 4689.18 934096 407682 -1474.57 4003.53 217.67 1134.57 192.02 1006.23 8.90 OSF 1.50 Pass 0200.00 4038.36 -800.64 4729.77 939056 4077.96 -1504.52 4043.05 217.73 1135.85 19388 1008.41 8.83 OSF1.50 Pass 0228.51 4038.27 -617.29 475291 941560 407813 -1519.69 4062.97 217.76 1136.64 194.52 1006.63 8.80 OSF 1.50 Pass 0250.00 4038.28 -829.84 4770.35 943448 4078.65 -1531.16 4077.98 217.79 1137.28 195.13 1008.87 8.78 OSF 1.50 Pass 0300.00 4038.93 -859.06 4810.93 9478.39 4078.72 -1558.01 411271 217.81 1138.94 198.53 100769 873 OSF 1.50 Pass 0350.00 404145 -68827 485117 955205 407874 -1002.61 4171.32 217.76 1140.22 198.75 1007.39 8.64 OSF 1.50 Pass 0400.00 4042.29 -71750 4692.00 9609.93 4079.68 -1636.87 4217.96 217.70 1140.60 20055 1006.57 8.57 OSF 1.50 Pass 0450.00 404413 -746.73 4832.52 966009 408173 -1666.45 4258.42 217.71 1140.92 202.24 100576 8.50 OSF 1.50 Pass 0500.00 4045.97 -77596 4973.05 970861 4084.13 -1695.05 4297.54 217.74 1141.26 203.90 1005.00 8.43 OSF1.50 Pass 0550.00 4047.81 4805.19 5013.57 9756.82 408555 -1723.58 4336.38 217.72 114169 205.56 1004.32 8.38 OSF 1.50 Pass 0600.00 4049.65 -834.43 505409 981165 4086.30 -1756.13 438074 217.65 114205 207.41 1003.46 8.29 OSF 1.50 Pass 0650.00 4051.49 -86366 5094.82 9868.10 4086.58 -178919 4426.25 217.56 1142.17 209.28 1002.32 8.22 OSF 1.50 Pass 0700.00 4053.33 -89289 5135.14 992601 408622 -1822.94 4473.31 21744 1141.97 211.19 1000.85 8.14 OSF1.50 Pass 0750.00 405517 -922.12 5175.68 9983.82 408546 -1656.19 4520.35 217.30 1141.42 213.08 999.04 8.07 OSF 1.50 Pass 0600.00 4057.01 -95135 5216.19 10041.13 4085.64 -188906 456754 217.20 1140.56 214.97 996.92 7.99 OSF 1.50 Pass 0850.00 4058.80 -98058 5256.71 10100.85 4086.14 -1922.81 461680 217.15 1139.31 216.90 994.38 7.91 OSF 1.50 Pass 0900.00 4059.94 -100987 5297.22 10157.77 4086.18 -1954.62 466401 217.18 1137.62 218.77 991.45 7.83 OSF1.50 Pass 0950.00 4060.83 -103918 5337.71 10210.89 4086.14 -198413 4708.17 217.13 113573 220.57 988.36 775 OSF 1.50 Pass 1000.00 4061.72 -106649 5378.21 10263.44 408615 -2013.21 4751.94 217.09 1133.72 222.38 985.15 7.68 OSF1.50 Pass 1050.00 4062.61 -1097.81 541871 1031571 4085.40 -2042.04 479553 21706 113159 224.15 981.83 7.60 OSF 1.50 Pass 1100.00 4063.50 -1127.12 5459.21 10364.24 4086.70 -2068.79 4836.04 217.03 112944 225.88 978.52 753 OSF 1.50 Pass 1150.00 4064.38 -1156.43 5499.71 10412.27 408678 -209533 487686 216.99 1127.37 22762 975.30 7.46 OSF 1.50 Pass 1200.00 4065.27 -118574 5540.21 10452.23 408673 -211757 490926 216.96 112556 229.20 972.43 7.39 OSF 1.50 Pass 1250.00 4066.16 -1215.05 5680.70 1049184 4086.61 -2139.83 4941.78 21692 1124.21 230.76 970.04 7.33 OSF1.50 Pass 1300.00 4067.05 -1244.36 5621.20 10533.19 4086.43 -2163.59 4975.87 216.87 1123.31 23235 968.08 7.28 OSF 1.50 Pass 1350.00 4067.94 -1273.67 5661.70 10576.41 4086.37 -2188.53 5011.18 218.83 1122.72 233.96 96642 722 OSF 1.50 Pass 1400.00 4068.79 -1302.96 5702.21 10644.20 408657 -2227.64 5066.54 216.63 1122.25 236.15 964.49 7.15 OSF 1.50 Pass 1450.00 4069.46 -1332.16 5742.78 1071075 408712 -2261.58 5121.88 216.62 1120.38 23826 96121 7.08 OSF 1.50 Pass 1500.00 4070.14 -1361.37 5783.37 10740.68 4087.19 -2281.38 5146.63 216.60 111900 239.64 958.91 7.03 OSF 1.50 Pecs 155000 4070.82 -1390.57 5823.95 10770.58 4067.04 -2298.63 5171.08 216. 240.96 95755 6.99 OSF 1.50 Pass 1600.00 4071.50 -141977 586453 10806.92 4086.54 -232010 520039 216.52 242.39 95696 6.95 OSF 1.50 Pass 1650.00 4072.18 -144897 5905.11 10853.55 4085.39 -2347.84 523769 216.43 1119.54 244.09 956.48 6.90 OSF1.50 Pass 1700.00 4072.86 -1478.18 5945.69 10901.07 4083.63 -2378.21 5275.94 216.30 1120.34 245.81 95614 688 OSF 1.50 Pass 1750.00 4073.54 -1507.38 5986.27 10950.12 4061.45 -2405.54 531519 216.16 112121 24757 95583 6.81 OSF 1.50 Pass 1800.00 4074.22 -1536.58 6026.85 11002.29 4078.88 -2436.73 535694 215.98 112209 249.41 955.46 677 OSF 1.50 Pass 1850.00 4074.90 -1565.79 6067.43 11058.03 4076.34 -248186 540168 21582 112276 251.34 954.87 672 OSF 1.50 Pass 1900.00 4075.50 -1594.99 6108.01 11114.44 4074.09 -2503.16 5447.16 21569 1123.18 253.28 95398 8.67 OSF 1.50 Pass 1950.00 4075.36 -162422 8148.58 11170.73 407200 -2536.12 5492.74 215.62 1123.25 255.22 952.78 6.62 OSF 1.50 Pass 2000.00 4074.37 -1653.46 6189.12 1122514 4070.69 -256779 553696 21563 1123.09 257.13 951.34 657 OSF 1.50 Pass 2050.00 4073.06 -1682.70 6229.68 11276.32 4070.32 -259745 557867 215.68 112275 25897 949.77 652 OSF 1.50 Pass 2100.00 4071.76 -1711.95 6270.19 11323.25 4070.30 -2624.72 5616.88 215.74 112249 260.73 948.34 648 OSF 1.50 Pass 2150.00 4070.45 -1741.19 6310.73 11371.03 4070.45 -2652.58 565569 215.81 1122.36 262.50 947.03 6.43 OSF 1.50 Pass 0.00 69. 2204015 -1770.44 6351.26 11419.88 407070 -2881.10 5695.34 215.891 11?2.0 I264.31 945.76 6.39 OSF 1.50 Pass 2250.00 4067.84 -179968 6391.80 11464.07 4070.98 -2706.98 5731.17 215.96 1122. 266.00 944.68 6.35 OSF 1.50 Pass 2300.00 4066.54 -1828.92 6432.33 11504.15 4071.13 -2730.71 5763.48 216.02 112278 26758 94407 6.31 OSF 1.50 Pass 2350.00 406523 -1858.17 6472.87 11546.77 4071.14 -2756.25 5797.58 216.08 1123.66 28922 943.85 6.28 OSF 1.50 Pass 2400.00 4083.92 -188741 651340 11599.70 4070.77 -2768.01 583992 216.13 112459 271.16 943.49 624 OSF 1.50 Pass 2450.00 4062.92 -191686 6953.95 11653.76 4069.91 -2820.32 5883.26 218.15 112538 273.02 943.04 6.20 OSF 1.50 Pass 2500.00 4062.70 -194591 659449 11709.25 406880 -285328 592789 216.11 1125.93 274.83 94239 6.16 OSF 1.50 Pass 2550.00 4062.66 -1975.16 8635.05 11760.74 406773 -288372 5969.41 216.06 112631 27669 941.53 8.12 OSF 1.50 Pecs 2600.00 4062.61 -2004.41 6675.60 11810.92 4067.01 -2913.37 6009.88 218.03 112688 27851 940.68 6.08 OSF 1.50 Pass 2690.00 4062.56 -2033.66 6716.15 11868.12 4066.59 -294589 6054.48 218.01 1128.94 280.48 939.62 604 OSF 1.50 Pass 2700.00 4062.51 -2062.91 8758.70 11921.24 406648 -2978.14 6088.17 216.01 1126.94 282.44 938.32 600 OSF 1.50 Pass 2750.00 4062.46 -2092.17 679725 11973.66 4068.51 -3008.69 6141.78 216.01 112679 28435 936.90 596 OSF 1.50 Pass 2800.00 4062.42 -212112 6937.80 12026.91 4066.59 -3039.61 6185.13 218.02 112852 28627 935.35 5.92 OSF 1.50 Pass 2850.00 4062.37 -2150.67 6878.35 1208126 4066.71 -3071.01 6229.49 216.03 1128.08 288.22 933.60 5.88 OSF 1.50 Pass 2900.00 4062.32 -2179.82 6918.90 12136.44 4067.05 -310270 627466 216.05 112543 290.19 931.64 583 OSF 1.50 Pass 2950.00 4062.27 -2209.17 6958.45 12191.75 4068.16 -3134.24 6320.08 216.11 1124.53 292.17 929.43 5.79 OSF 1.50 Pass 3000.00 4062.14 -2238.44 6999.99 12240.03 4069.67 -316170 6359.76 216.22 112355 294.01 927.22 5.75 OSF 1.50 Pass 3050.00 4061.97 -226770 7040.53 1228978 4071.66 -3180.05 640060 218.33 112264 295.88 92506 5.71 OSF 150 Pass 3100.00 4061.79 -229697 7061.07 12354.33 4074.77 -3226.43 6453.83 216.50 112138 298.05 922.35 5.66 OSF 1.50 Pass 3150.00 4061.61 -232624 7121.60 12405.23 4077.53 -3254.73 6498.05 21669 111967 299.97 919.36 5.61 OSF1.50 Pass Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 29 of 137 • • Trajectory:5107-SE4(P3)Va.SP125E3L1 current Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset N5 Offset EW North Azim CI-Ct Distance Separation Clearance OSF Controlling Rule Status (8) (t) (ff) (R) R) (it) (6) (ft) (') (5) (a) (R) 3200.00 -2355.51 7162.14 2448.65 4079.79 3279.03 6531.96 216.76 301.75 916.70 5.57 OSF 1.50 Pass 3250.00 4061 26 -2384.78 720268 2494.48 4081.97 -330489 656972 216.90 116.99 303.57 914.28 5.53 OSF 150 Pass 3300.00 4061.08 -2414.05 7243.22 2542.81 4083.49 -3332.28 6608.52 216.99 115.89 305.43 911.94 5.49 OSF 1.50 Pass 3350.00 4060.90 -2443.32 728375 2589.54 4084.13 -3358.85 8647.96 21703 114.89 30726 909.72 5.46 OSF 1.50 Pass 3400.00 4060.73 -2472.59 732429 2635.01 4083.97 -338487 668525 217.03 114.08 308.05 907.72 5.42 OSF 1.50 Pass 3450.00 4080.55 -2501.86 7364.83 268238 4083.14 -341212 6723.98 217.00 11345 310.86 905.88 5.38 OSF 1.50 Pass 3500.00 4060.40 -2531.12 7405.37 2731.61 408246 -344048 676422 21895 11287 312.88 904.09 5.35 OSF 150 Pass 3550.00 4060.89 -256038 744591 278361 4082.04 -347043 680673 218.88 112.30 314.38 902.38 5.32 OSF 1.50 Pass 3800.00 4062.06 -2589.62 748645 2837.37 4081.67 -3501.26 6850.77 216.79 111.58 316.18 900.44 5.29 OSF 1.50 Pass 3650.00 4063.28 -261886 752699 2891.87 408132 -353235 6895.53 216.71 110.64 318.14 898.22 5.25 OSF 1.50 Pass 3700.00 4064.50 -264811 756753 2944.76 408100 -3562.34 8939.08 216.63 109.52 320.05 89582 5.21 OSF 1.50 Pass 3750.00 4065.72 -2677.35 760807 298893 4080.61 -3587.46 6975.42 216.55 108.50 321.81 893.83 518 OSF 1.50 Pass 3800.00 4066.94 -2706.59 764881 303337 408002 -3612.93 7011.83 216.46 107.74 323.56 891.71 515 OSF 1.50 Pass 385000 4068.15 -273583 7689.15 3082.79 4079.31 -364135 705226 216.37 107.12 32542 889.85 5.11 OSF 1.50 Pass 390000 40699.37 -2765.08 7729.68 3132.39 4078.69 -3689.90 7092.81 216.27 106.52 32727 888.02 5.08 OSF1.50 Pass 395000 4070.59 -279432 7770.22 3182.88 4078.18 3698.94 7134.08 216.18 105.92 32914 886.17 5.05 OSF 1.50 Pass 4000.00 4071.81 -2823.56 7810.76 3233.37 4077.78 -372799 7175.41 218.10 105.30 331.02 88430 502 OSF1.50 Pass 4050.00 4072.64 -2852.81 7851.31 3283.98 4077.42 -375707 721682 21805 104.66 332.90 882.40 4.99 OSF1.50 Warning 4100.00 4072.76 -288206 7891.88 3334.13 4077.04 -3785.88 725788 218.03 104.00 334.79 88048 4.96 OSF 1.50 blaming 415000 4072.80 -2911.31 7932.41 3383.73 4076.39 -3814.36 7298.48 215.99 103.34 336.67 878.57 493 OSF 1.50 Warning 4200.00 4072.84 -2940.56 7972.96 3432.23 4075.57 -384224 733815 215.95 102.72 338.52 876.72 4.50 OSF 1.50 Warning 4250.00 4072.88 -2969.82 8013.51 3479.94 4075.05 3889.75 7377.13 215.92 102.20 34035 874.97 4.87 OSF 1.50 Warning 4300.00 4072.92 -299907 8054.06 3529.68 407482 -3898.48 7417.73 21590 101.75 342.23 87327 4.84 OSF 150 Warning 4350.00 4072.96 -302832 8094.61 358062 407464 -3927.88 7459.33 21589 10127 344.15 871.51 4.81 OSF 1.50 Warning 4400.00 4073.00 -305757 8135.16 3632.69 4074.54 -3957.88 7501.88 215.89 100.73 346.09 869.67 4.78 OSF 1.50 Warning 4450.00 4073.04 -3086.82 8175.71 388502 4074.61 -398795 7544.72 215.89 10008 34805 867.72 4.75 OSF 1.50 Warning 4500.00 407308 -311608 821826 373440 4074.85 -401628 7585.16 21590 099.39 34994 865.77 4.72 OSF 1.50 Warning 4550.00 407316 -3145.33 825681 3783.20 4075.28 -404430 7625.11 215.87 098.73 351.79 86388 4.69 OSF 1.50 Warning 4600.00 4073.53 -3174.53 829739 3827.71 4075.08 -4069.99 7861.46 215.82 098.29 353.44 862.34 467 OSF 1.50 Warning 4650.00 4073.92 -3203.74 833797 3872.26 407380 -4095.86 7697.70 215.73 098.11 355.18 860.99 4.65 OSF 150 Warning 4700.00 4074.30 -3232.94 8378.58 3955.50 4070.16 -4143.31 7765.98 215.51 097.29 35767 858.51 461 OSF 1.50 Warning 475000 4074.68 -3262.15 8419.14 4011.16 406765 -4174.17 7812.24 215.36 095.51 359.61 855.45 4.58 OSF 150 blaming 4800.00 4075.07 -3291.35 845972 406413 405560 -4203.44 785636 215.23 093.63 36151 852.30 455 OSF 1.50 Warning 4850.00 407545 -3320.56 8500.30 4124.19 4063.86 -4238.31 7906.59 215.11 091.44 363.50 84878 4.51 OSF 1.50 Warning 490000 4975.84 -3349.76 8540.89 4175.19 408287 -4263.94 7949.44 215.04 088.90 365.40 844.97 448 OSF 1.50 Warning 495000 4076.22 -3378.97 8581.47 4218.43 406196 -4287.52 7985.67 214.97 086.58 387.23 841.43 4.45 OSF 1.50 Warning 5000.00 4076.60 3406.17 862205 4260.58 4060.92 -4310.73 8020.83 214.90 084.58 369.02 838.24 442 OSF 1.50 Warning 5050.00 4076.99 -3437 38 8662.63 4301.04 4059.61 -4333.28 8064.41 214.81 083.00 370.76 835.49 4.39 OSF 1.50 Whming 5100.00 4077.00 -3466.60 8703.20 4342.76 4057.92 -4356.83 8088.81 214.78 081.83 372.50 833.16 436 OSF 1.50 Warning 5150.00 4076.14 -349584 874375 4397.83 4058.16 -4387.96 8134.19 214.78 08067 37449 83068 4.34 OSF 150 Warning 5210.00 407470 -3525.08 8784.29 4448.58 4055.53 -4418.51 8178.15 214.83 07928 37844 828.00 4.31 OSF 1.50 Warning 5250.00 4073.24 -355432 8824.82 4492.64 4055.42 -444144 8212.48 214.90 078.08 378.27 825.57 4.28 OSF 1.50 Warning 5300.00 4071.79 -3583.56 8865.35 4535.53 4055.60 -4465.90 8247.70 214.97 077.17 38008 823.45 4.26 OSF 1.50 Warning 5350.00 4070.33 -3612.80 8905.88 4575.26 4055.66 -448084 8280.14 215.03 076.67 381.80 821.81 424 OSF 1.50 Warning 5400.00' 4068.88 -3642.04 8946.42 4615.00 4055.48 -451210 8312.37 215.1-1.YL7 1 38348 820.67 4.22 OSF 1.50 Warning 5450.00 4067.42 3671.28 8988.95 4661.02 4055.03 -4539.27 8349.51 215.13 38532 819.78 420 OSF 1.50 Warning 550000 4085.97 -3700.52 9027.48 4707.59 4054.40 -4566.89 8387.00 215.17 077.47 38716 819.03 4.18 OSF 1.50 blaming 5550.00 406451 -372976 9068.01 4758.85 4053.65 -4596.18 842680 215.21 078.06 389.07 818.35 4.16 OSF 1.50 Warning 5600.00 4083.14 -375901 9108.54 4806.47 4052.96 -4825.70 8466.47 215.29 078.66 39094 817.71 4.15 OSF 1.50 Warning 5650.00 406235 -3788.31 9149.05 4960.00 405246 -4657.49 8508.53 215.35 079.15 392.81 816.95 4.13 OSF 1.50 Warning 5700.00 4061.65 -381761 9189.56 4913.57 4052.34 -4689.17 855274 215.38 078.46 394.73 815.98 4.11 OSF 1.50 Warning 5750.00 4060.94 -3846.91 9230.07 4967.25 4052.36 -472077 8596.14 215.43 079.61 396.76 814.77 4.09 OSF 1.50 Warning 5800.00 4060.24 -387622 9270.57 5021.57 4052.41 -4752.58 864017 215.47 07958 39881 813.38 407 OSF 1.50 Warning 5850.00 4059.53 -3935.52 9311.08 5071942 4052.38 -4784.51 868476 215.51 079.33 400.85 811.77 405 OSF 1.50 Warning 5900.00 4058.83 -393482 9351.59 5133.54 405230 -4817.51 8731.39 215.55 07881 402.94 809.86 402 OSF 1.50 Warning 5950.00 4058.12 -3964.12 939210 5189.42 4052.29 -4849.48 877721 215.59 077.95 409.57 80458 3.95 OSF 1.50 Warning 6000.00 405741 -3993.43 9432.60 5239.40 405230 -4878.00 8818.27 215.62 07699 43306 787.95 374 OSF 1.50 Warning 8050.00 4056.71 -4022.73 947311 5245.00 4052.30 -4881.19 882286 215. 436.21 785.8 3.711 OSF 1.50 Warning 6100.00 4056.00 -405203 9513.62 5245.00 4052.37 -4881.19 882288 215. 435.87 788.28 3.72 OSF1.50 Warning 6128.61 4055.60 -4068.80 9536.80 5245.00 405230 -4881.19 8822.86 215.63 1081.52 435.27 791.01 3.73 OSF 1.50 Warning End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 30 of 137 • Field: Nikadchuq Well: SP72SE3 Structure: Spy Island Borehole: SP72S03 Slot SP72 Trajectory. SP12S03 Client: Eni Petroleum Type: Non-De/Survey Coordinate System: NAD27 Alaska State Plane,Zone 04 US Feel North Reference: True Grid Convergence Angle: 0.09006289° Grld Scale Fetter: 0.999900154 Magnetic Declination: 19.261° Magnetic Declination Date: July 01,2014 Magnetic Model: BGGM 2013 Reference Point Northlna faa6na Li/nation Structure Uno. Blot U^e. 6053652 820(kUS) 511644.690(ftUS) 53.930(ft)MSL 0.000(ft)(1 sigma) 0000(11)(1 sigma) Trajectory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Survevina Proa:As Drilled Description MD Front(R) MD To(R) EOU Freq Survey Tool Type Hole Sloe(In) Casing Diameter(In) Borehole/Survey 0.000 40.830 Act-Stns SLB_NSG*SSHOT-Depth Only-No Global 16.000 13.375 - SP12-003/SP125E3 40.830 1290.720 Act-Sins SLB_NSG+SSMOT-No Globe 16.000 13.375 SP72-SE3/SP12SE3 1290.720 2801.150 Ace-Stns SLB MWD.GMAG-No Globe 16.000 13.375 SP12-SE3/SP72SE3 2801.150 2915540 Act-Stns SLB_MNO-INC_ONLV_FILLER-No Globe 12250 9.625 SP12-SE3ISP72SE3 2915.540 5124.670 Act-Stns SLB MWD+GMAG-No Globe 12.250 9.625 SP72-SE3/SP72SE3 5124870 15151.590 Act-Stns SLB_MWO+GMAG-No Globe 8.750 5.500 SP12-SE3/SP72SE3 15151.590 15216000 Act-Stns SLB BLIND+TREND-NO Globe 8750 5.500 SP72-SE3/SP72SE3 Minimum Traveling Cylinder Albwa8e EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset N5 Offset EW North/Vim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (5) (ft) (ft) (ft) (ft) (5) (5) (°) (ft) (9) (ft) All local minima indicated. Results filtered:Depth 6100.00 ft m MD<-16128.61 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation c 1320.00 ft 6100.00 4028.97 1797.48 1405.89 5432.39 4005.74 699.05 78368 208.8 100.76 1195.12 18.97 OSF 1.50 Pass 6127.27 4030.65 1783.89 1429.47 5446.91 4007.33 69185 79619 208. 100.94 1194.98 18.93 OSF 1.50 Pass 6150.00 4031.82 1772.50 1449.10 5459.00 4008.65 685.76 806.55 209.44 1262.7 101.13 1194.95 18.90 OSF 1.50 Pass 6200.00 403407 174644 149171 5480.03 401091 67489 824.41 211.34 1262.55 101.45 119459 16.84 OSF 150 Pass 6250.00 4035.84 171895 1533.44 5499.45 4012.81 66445 840.68 213.26 1261.91 101.90 1193.65 18.74 OSF 1.50 Pass 6300.00 4037.11 169007 157423 5518.89 4014.54 653.60 856.71 215.19 1260.81 102.31 1192.27 18.85 OSF 1.50 Pass 6350.00 4037.89 165986 1614.06 553835 4016.08 64234 872.51 216.83 1259.25 102.88 1190.34 18.52 OSF 1.50 Pass 6400.00 4038.51 1629.78 1853.54 5557.84 4017.43 630.68 888.07 216.88 1 10350 1189.00 18.40 OSF 1.50 Pass 6450.00 4039.13 159851 1693.02 5593.32 4019.79 608.95 916.00 216. 10467 1188.21 18.19 OSF 1.50 Pass 6500.00 4039.74 1567.83 1732.50 5629.29 402232 58680 94408 217.07 105.85 1187.97 17.99 OSF 1.50 Pass 6550.00 4040.36 153715 1771.98 5672.56 4025.47 559.38 977.56 217.19 1259.91 107.47 1187.93 1773 OSF 1.50 Pass 6800.00 4040.97 150648 1811.46 5728.20 4029.04 524.43 1020.71 217.32 1260.89 109.47 1187.58 17.42 OSP 150 Pass 8850.00- 404151 147599 1851.08 5795.37 403245 482.63 1073.18 216.42 126173 112.00 118674 17.04 OSF 1.50 Pass 8700.00 4041.70 1446.54 1891.49 5860.24 4034.87 443.02 1124.50 215.50 1263.08 114.54 1188.39 16.87 OSF 1.50 Pass 8750.00 4041.78 141729 1932.04 5914.01 4036.70 410.45 1167.24 215.58 1264.39 116.92 1186.11 16.35 OSF 1.50 Pass 8800.00 4041.86 1388.04 1972.59 5967.07 4038.50 378.42 1209.50 215.66 1265.55 119.27 1185.71 16.04 OSF 1.50 Pass 6850.00 4041.93 135878 2013.13 6019.77 4040.27 346.70 1251.55 215.73 1286.61 12177 1185.11 15.72 OSF 1.50 Pass 6900.00 4042.01 1329.53 2053.68. 0072.47 4042.08 315.08 1293.67 215.81 ' 1267.57 124.24 1184.41 15.41 OSF 1.50 Pass 8950.00 404209 1300.28 2094.23 6124.78 4043.98 283.78 133554 215.89 1268.42 12685 1183.52 15.10 OSF 1.50 Pass 7000.80 4042.16 127102 2134.78 8174.09 4045.40 254.29 1375.03 215.95 1269.24 12939 118265 1482 OSF 1.50 Pass 7050.00 4042.24 124177 2175.33 6228.52 4048.19 221.73 1418.64 21599 127007 132.20 1181.81 14.51 OSF 1.50 Pass 7100.00 4042.32 1212.52 2215.88 6300.38 4046.55 179.41 1476.73 216.00 1270.31 13547 1179.66 14.16 OSF 1.50 Pass 7150.00 404244 1183.26 2256.43 635227 4046.18 149.28 1518.96 215.97 1270.04 13831 117751 13.86 OSF1.50 Pass 7200.00 4043.24 1154.01 2296.97 6403.45 4044.88 119.57 1560.61 215.87 1269.76 141.08 1175.38 13.59 OSF 1.50 Pass 7250.00 4044.68 1124.77 2337.51 6487.26 4042.65 82.87 1612.77 215.68 1269.18 14419 1172.73 13.28 OSF 1.50 Pass 7300.00 404615 109554 237804 6532.14 4040.26 46.16 168621 215.49 1268.04 147.32 1169.50 12.99 OSF 1/0 Pass 7350.00 4047.63 1085.30 2418.57 659497 4038.23 1122 1718.38 215.31 1268.31 15053 1165.63 12.69 OSF 1.50 Pass 7400.00 4049.10 1037.06 2459.11 6645.30 4036.97 -16.59 1760.32 215.19 1264.36 15346 1161.73 1243 OSF 1.50 Pass 7450.00 4050.58 07.82 31.97 4036.18 -42.38 1799.21 21109 1262.43 7500.00 4052.05 1978.58 2540.17 6731. 08 4035.87 64.22 1831.65 215.02 1260.83 159.423 (154..5 1# OOSF 1.50 Pass SF 1.50 Pass 7550.00 4053.53 549.34 2580.70 6770.24 4035.93 86.36 1883.94 214.97 7259.66 12554 11/5666444 7600.09 4055.00 920.10 2621.24 6802.70 4036.03 -105.01 1890.51 214.9 126.28 1174.52 15.06 OSP 1.50 Pass 7650.00 4056.47 890.86 288177 6834.72 4035.87 -123.78 1916.45 21488 12714.97 OSF 1.50 Pass 7670.89 4057.09 87865 267870 6848.08 4035.72 -131.73 1927.20 214.86 1259.39 127321 7gil 14.94 OSF 1.50 Pass 7700.00 4057.80 861.62 270231 6867.97 4035.41 -143.65 1943.10 21481 1259.95 127.77 117444 14.89 OSF 1.50 Pass 7750.00 4058.33 832.37 2742.85 6952.29 4035.81 -193.55 2011.07 214.78 1260.37 130.00 1173.38 14.64 OSF 1.50 Pass 7800.00 405841 803.12 2783.40 7008.39 403777 -225.99 2056.79 214.87 125994 13149 117195 14.47 OSF 1.50 Pass 7690.00 4058.48 773.87 2823.95 7059.78 404025 -255.58 2098.74 214.98 1259.37 132.88 117046 14.31 OSF 1.50 Pass 7900.80 4058.56 744.62 2884.50 7101.04 4042.04 -279.45 2132.34 215.056r2 13402 1189.32 14.18 OSF 1.50 Pass 7950.00 4058.63 715.37 2905.06 7142.35 404321 -303.59 2165.84 215.1 13517 1168.51 14.06 OSF 1.50 Pass 8000.00 4058.71 686.11 2945.61 7187.10 4044.22 -329.96 2201.99 215.15 7 136.42 116793 13.94 OSF 1.50 Pass 8050.00 4058.78 656.88 2986.16 723219 4045.57 -356.68 223830 215.21 1259.64 137.69 116752 13.81 OSF 7.50 Pass 8100.00 4058.86 62761 3026.71 7297.99 4047.67 -395.45 229141 215.30 125993 13962 1166.52 13.62 OSF 110 Pass 8150.00 4058.93 598.36 3067.26 7353.98 4049.12 -427.90 2337.01 215.3 141.28 1165.08 13.46 OSF 1.50 Pass 8200.00 405901 59911 3107.81 7395.75 4050.48 -45222 2370.94 215.4 14253 118408 13.34 OSF 1.50 Pass 8250.00 4059.03 539.87 3148.37 7448.50 405252 -482.00 2411.99 215.44 14406 1163.21 13.20 OSF1.50 Pass 8300.00 4058.96 510.67 3188.95 7521.71 4055.58 -525.32 2473.38 215.59 1259.10 146.28 116125 1299 OSF 1.50 Pass 8350.00 405890 48147 3229.54 7587.13 4057.03 -562.16 2527.42 215.66 1257.83 148.29 1158.64 1280 OSF 1.50 Pass 8400.00 4058.84 452.26 3270.72 7636.35 4056.83 -590.64 2589.99 215.65 1256.12 14987 115588 12.65 OSF 1.50 Pass 8450.00 4058.77 42306 3310.71 7880.18 405657 -614.07 2004.65 215.64 1254.65 151.19 1153.53 12.52 OSF 1.50 Pass 8500.00 4058.71 393.85 335129 7724.55 4056 41 -639.15 2641.25 215.63 1253.50 15256 115146 12.39 OSF 1.50 Pass 8550.00 4058.64 364.65 339188 7773.21 4057.05 686.73 2881.33 215.67 1252.44 154.04 1149.42 1226 OSF 1.50 Pass 8690.00 4058.58 335.45 3432.46 7820.34 4058.59 -693.48 2720.10 215.74 1251.46 15549 114747 12.14 OSP 1.50 Pass 8690.00 4058.51 306.24 3473.05 7865.62 4069.67 -719.30 275724 215.84 1250.65 15692 114570 12.02 OSP 1.50 Pass 8700.00 4058.45 277.04 3513.63 7912.38 406335 -746.08 2795.48 215.96 1250.01 158.40 1144.08 11.90 OSF 1.50 Pass 8750.00 4058.13 247.82 3554.20 7961.52 4065.52 -774.25 2835.61 216.20 1249.42 159.96 114245 11.78 OSF 1.50 Pass 8800.00 4058.98 21854 3594.72 8006.40 4069.55 -800.03 2872.23 216.49 1248.84 181.43 1140.90 11.67 OSP 1.50 Pass 8850.00 4055.51 18923 3635.20 8046.94 4071.48 -823.56 290518 216. 162.78 1139.72 11.57 OSF 150 Pass 8900.00 405405 159.93 3675.69 8087.23 407245 -847.22 2937.77 21673 164.1314........4% 11.47 05F150 Pass 8950.00 4052.59 130.62 3716.17 8125.83 407295 -870.17 2988.81 216.81 1249.22 185 11.39 OSP 1.50 Pass Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI.07-SE4(P3) 7/8/2014 9:06 AM Page 31 of 137 • • Trajectory:5107-SE4(P3)Vs.SP12SE3 Minimum Towing Cylinder Allowable EOU-EOU Reference MD Reference WD Reference NS Reference EW Offset MD Offset TVD Offset NS O1feet EW North Asim Ct-Ct Dieting Separation Clearance OSF CoMaling RW Status (8) (8) (8) (8) (8) (10 (8) (8) (') (8) (R) (8) 9000.00 4051.13 10132 3756.66 8164.43 407329 -893.40 299964 216,87 1250.22 66.64 1138.79 1131 OSF 1.50 Pass 9050.00 404967 72.01 3797.15 820156 4073.46 -91603 3029.07 21693 1251.69 67.84 1139.47 11.24 OSF 1.50 Pass 9100.00 4048.21 42.71 3837.63 8238.21 407350 -938.68 3057.69 216.98 1253.70 6899 1140.71 11.18 OSF 1.50 Pass 9150.00 4046.74 13.40 3878.12 828915 407346 -970.53 3097.85 217.04 1256.17 70.84 1142.09 11.10 OSF 1.50 Pass 9200.00 4045.28 -15.90 391860 8381.73 407563 -1028.84 3171,23 217.26 1257.41 7385 1141.31 10.91 OSF 1.50 Pass 9250.00 4043.82 -45.21 395909 8449.88 4076,76 -106672 3226.31 217.41 1257.59 75.89 1140.00 10.78 OSF1.50 Pass 9300.00 4042.78 -74.49 3999.60 8504.25 4076.58 -1098.34 3270.57 217.37 125733 77.64 1138.58 10.67 OSF 1.50 Pass 9350.00 404242 -103.74 404015 8559.69 4075.51 -1130.44 3315.76 217.32 1256.95 79.40 1137.03 10.56 OSF 1.50 Pass 9400.00 4042.11 -133.00 4080.70 8622.77 4074.47 -1166.55 3367.47 217,29 125618 81.38 1134.94 10.44 OSF 150 Pass 9450,00 4041.80 -162.25 4121.25 8684.31 4074.01 -1201.27 3418,27 217.29 125491 83.35 1132.35 10.31 OSF 1.50 Pass 9500.00 4041.50 -191.50 4161.80 874378 4073.68 -1234.40 3467.68 217,29 1253.20 85.27 1129.36 10.19 OSF 1.50 Pass 9550.00 4041.19 -220.75 4202.35 8796.82 4073.56 -1263.73 3511.85 217.30 125126 87.05 1126.24 10.08 OSF 1.50 Pass 9600.00 4040.89 -250.00 4242.90 886292 4073.94 -1299.98 3567.12 217.34 1249.10 89.12 1122.69 995 OSF 1.50 Pass 9650.00 4040.58 -279.25 4283.45 8934.84 4076.11 -133816 3828.03 217.47 1245.65 91.30 1117.98 9,81 OSF 1.50 Pass 9700.00 4040.27 -308.50 432400 8979.82 407755 -1361.86 3886.23 217.55 124243 9294 1113.47 9.70 OSF 1.50 Pass 9750.00 4039.97 -33775 436455 9025.35 4078.57 -1388.02 3704.81 217.82 123920 94.59 1109.15 9.59 OSF 150 Pass 9800.00 4039.66 -367.00 440510 907251 407549 -1411.15 374470 217.68 123611 96.27 1104.94 9.49 OSF 150 Pass 9850.00 4039.47 -396.21 4445.68 9118.24 4080.39 -143562 3783.33 217.85 1233.18 9784 1100.96 9.39 OSF 130 Pass 9900,00 4039.32 -425.41 4488.28 9159.75 4081.20 -1458.01 381827 217.70 1230.54 99.30 1097.35 9.30 OSF 150 Pass 9950.00 4039.16 -45462 4526.85 9201.29 408202 -148067 385308 217.75 1228.24 200.84 1094.02 9.21 OSF 1.50 Pass 0000.00 4039.00 -483.82 456743 924583 408280 -1505.07 3890.10 217.78 1226.23 202.46 109093 9.12 OSF 1.50 Pass 005000 4038.84 -513.03 460802 929000 408281 -1529.68 3927.02 217.79 1224.44 20407 1088.07 9.04 OSF 1.50 Pass 0100.00 4038.68 -542.23 464860 9334.41 408197 -1554.50 3963.84 217.77 122289 205.69 108543 8.95 OSF 1.50 Pass 0150.00 4038.52 -571.44 4689.18 9378.80 4080.56 -1579.48 4000.50 21772 1221.56 20731 106302 8.87 OSF 1.50 Pass 0200.00 4038.36 30064 472977 9427.89 4078.46 -1607.24 4040.94 217.63 1220.38 209.03 1080.71 8.79 OSF 1.50 Pass 0250.00 4038.28 -629.84 4770.35 9478.18 4076.43 -1635.67 408237 217,53 1219.20 21074 1078.38 8.71 OSF 1,50 Pass 0300.00 4038.93 x.06 481093 9521.17 4074.94 -1660.05 4117.74 217.43 1218.11 212.19 1076.32 8.64 OSF 1.50 Pass 0350.00 4040.45 -68827 485147 9563.58 407388 -1684.31 4152.49 217.35 121729 213.55 1074.59 8.58 OSF 1.50 Pass 0400.00 404229 -71750 4892.00 9604.00 407321 -1707.87 4185.49 217.25 214.93 1073.16 8.52 OSF 1.50 Pass 0450,00 404413 -746.73 4932.52 9643.77 4072.75 -1730.91 4217.76 217.1 216.38 1072.12 8.47 OSF 1.50 Pass 0500.00 4045.97 -77596 4973.05 9685.33 4072.48 -1755.47 4251.28 217. 217.83 1071.45 6.41 OSF 1.50 Pass 0550.00 4047.81 -80519 5013.57 9729.96 4072.37 -1782.03 4287.15 216.99 217.58 219.40 1070,98 8.35 OSF 1.50 Pass 0800.00 4049.65 -834.43 5054.09 9773.82 407241 -1808.16 4322.13 218,82 218.38 220.94 1070.76 8.30 OSF 1.50 Pass 0650.00 4051.49 -86386 5094.62 981494 4072.30 -1833.11 4355.07 216.84 219.51 222.40 10/0.91 8.25 OSF 1.50 Pass 0700.00 4053.33 -89289 5135.14 9856.29 4071.92 -1858.31 4387.85 216.75 220.99 223.85 107143 8.21 OSF 1.50 Pass 0750.00 405517 -92212 5175.86 990306 4071.32 -1886.99 4424.79 216.64 22272 22549 1072.07 8.18 OSF 1.50 Pass 0800.00 4057.01 -95135 5218.19 9949.81 4070.63 -1915.75 4461.63 216.52 22458 227.12 1072.84 8.12 OSF 1.50 Pass 0850.00 4058.80 -980.58 5256.71 999755 4069.96 -194520 4499.20 216.42 226.55 228.79 107370 8.07 OSF 1.50 Pass 0800.00 4059.94 -1009.87 5297.22 10045.54 4069.44 -1974.88 4536.92 216.38 228.57 230.47 1074.60 8.02 OSF 1.50 Pass 0950.00 4060.83 -1039.18 5337.71 10096.21 4068.85 -2008.23 4578.72 216.31 230.59 232.28 1075.41 7.97 OSF 1.50 Pass 1000.00 406172 -1068.49 5378.21 10146.92 4068.09 -2037.57 4818.57 216.23 23258 234.10 1078.19 7.92 OSF 1.50 Pass 1050.00 4062.61 -1097.81 541871 10197.79 406726 -2068.99 4656.57 216.15 234.54 23595 1076.91 7.87 OSF 1.50 Pass 1100.00 4063.50 -1127.12 5459.21 10259.16 4066.43 -2108.78 470494 216.06 236.38 238.17 1077.27 7.81 OSF 1.50 Pass 1150.0D 4064.38 -1156.43 5499.71 10331.23 4067.26 -2150.14 476248 216.04 237.32 240.73 1076.51 7.74 OSF 1.50 Pass 1200.00 4065.27 -118574 5540.21 10380.33 4068.33 -2179.40 4801.89 216.05 237.93 24252 1075.92 7.68 OSF 1.50 Pass 1250.00 4066.16 -1215.05 5580.70 10429.93 4069.27 -2208.98 4841.69 216.05 238.57 244.33 1075,35 763 OSF 1.50 Pass 1300.00 4067.05 -124436 5621.20 1048078 4069.76 -2239.31 4882.51 216.03 239.19 246.20 1074.73 7.57 OSF 1.50 Pass 1350.00 4067.94 -1273.87 5861.70 10533.93 406970 -2270.95 4925.21 215.99 239.76 248.15 1074.00 7.52 OSF 1.50 Pass 1400.00 4068.79 -130296 5702.21 10569.88 4069.48 -2304.09 4970.29 215.78 240.14 250.18 1073.03 7.46 OSF 1.50 Pass 1450.00 4069.46 -1332.16 5742.79 10648.49 4069.12 -2338.52 5017.72 215.72 240.36 252.29 1071.83 740 OSF 1.50 Pass 1500.00 4070.14 -1361.37 578337 10708.55 4068.48 -2373.44 5066.58 215.86 240.20 254.43 1070.25 7.33 OSF 1.50 Pass 1550.00 4070.82 -1390.57 582395 10771.37 4068.21 -2409.48 5118.03 215.61 239.56 25881 1068.16 727 OSF 1.50 Pass 1600.00 407150 -1419.77 5864.53 10818.56 4068.49 -2438.33 5158.85 215.59 238.84 258.37 1066.08 7.21 OSF 1.50 Pass 1650.00 4072.18 -1448.97 5905.11 10859.74 406920 -2459.97 5190.55 215.60 23103 259.97 1084.39 7.16 OSF 1.50 Pass 1700.00 4072.86 -147818 5945.69 10903.39 4070.37 -2485.27 5226.10 215.82 23777 26163 1053.02 7.12 OSF 1.50 Pass 1750.00 4073.54 -150738 598627 10950.05 407189 -251244 5284.00 215.66 237.67 263.37 108176 707 OSF 1.50 Pass 1800.00 4074.22 -1536.58 6026.85 11006.51 4073.91 -2545.34 5309.85 215.72 237.61 265.42 1060.34 7.01 OSF 1.50 Pass 1050.00 407490 -156579 6067.43 11072.87 4075.86 -2583.43 5364.27 215.77 236.95 267.73 1058.13 695 OSF 1.50 Pass 1900.00 4075.50 -1594.99 6108.01 1111743 4076.56 -2808.78 5400.78 215.80 236.10 269.47 1056.12 8.90 OSF 1.50 Pass 1950.00 4075.36 -1624.22 614858 11181.90 4076.49 -2834.31 5437.20 215.85 235.45 27121 1054.32 6.85 OSF 1.50 Pass 2000.00 4074.37 -1653.46 6189.12 11210.16 4076.04 -2682.12 5478.64 215.90 234.93 27303 1052.58 6.80 OSF 1.50 Pass 2050,00 4073.06 -168270 6229.66 11258.57 407567 -2690.05 5516.15 215.94 234.46 274.85 1050.90 676 OSF 1.50 Pass 2100.00 4071.76 -1711.95 6270.19 11308.67 407533 -2719.04 555704 215.99 234.03 276.73 1049.22 8.71 OSF 1.50 Pass 2150.00 4070.45 -1741.19 6310.73 11360.13 4074.98 -2748.77 5598.04 216.03 233.59 27865 104749 6.66 OSF 1.50 Pass 2200.00 4068.15 -177044 6351.26 11417.38 4074.56 -2781.66 564559 216.08 232.94 280.74 1045.46 661 OSF 110 Pass 2250.00 4067.84 -179968 6391.80 11471.36 4074.14 -2812.45 5690.23 21613 232.05 28273 1043.23 8.55 OSF 1.50 Pass 2300.00 4066.54 -1828.92 6432.33 1152274 4073.62 -2841.68 573249 216.18 231.07 284.65 1040.97 8.50 OSF 1.50 Pass 2350.00 4065.23 -1858.17 647287 11576.16 407346 -2872.00 5776.47 21623 230.00 286.62 1038.59 6.45 OSF 1.50 Pass 2400.00 4063.92 -188741 0513.40 11630.49 4072.60 -290269 5821.29 216.26 228.77 28862 1036.03 6.40 OSF 1.50 Pass 2450.00 4062.92 -1916.66 0553.95 11697.80 4073.07 -2940.20 5877.18 218.31 227.10 290.81 1032.90 6.35 OSF 1.50 Pees 2500.00 4062.70 -1945.91 6594.49 11749.95 4074.75 -2968.80 5920.75 216.37 224.90 292.80 1029.51 6.30 OSF 1.50 Pass 2550.00 4062.66 -1975.16 6635.05 11792.97 407628 -299254 595659 216.45 22292 29434 1026.37 625 OSF 1.50 Pass 2600.00 4062.61 -200441 6675.60 11837.88 407774 -3017.52 599388 218.52 221.21 296.12 1023.47 6.20 OSF 1.50 Pass 2650.00 406256 -2033.66 6716.15 11885.04 4078.24 -3043.89 603298 216.54 219.64 297.95 1020.87 816 OSF 1.50 Pass 2700.00 4062.51 -206291 6758.70 1194536 4077.61 -3077.59 608301 216.52 218.05 300.06 1017.69 6.10 OSF 1.50 Pass 2750.00 4062.46 -2092.17 6797.25 12013.39 4077.63 -311470 6140.02 218.52 215.63 302.28 1013.78 605 OSF 1.50 Pass 2800.00 406242 -2121 A2 6837.80 1205714 4077.53 -313845 617676 216.52 213.08 304.06 1010.09 600 OSF 1.50 Pass 2850.00 4062.37 -215067 6878.35 12101.56 4076.91 -3162.76 621394 216.50 210.78 305.85 1006.55 5.85 OSF 1.50 Pass 2900.00 4062.32 -217992 6918.90 12152.30 4075.73 3190.59 6256.34 21644 208.56 30775 1003.06 5.90 OSF 1.50 Pass 2950.00 406227 -220917 6959.45 12201 28 4074.24 -3217.44 6297.28 218.38 208.32 309.62 96658 5.86 OSF 1.50 Pass 3000.00 4062.14 -2238.44 6999.99 12245.15 4073.25 -3241.62 633387 216.37 204.25 311.39 996.33 5.81 OSF 1.50 Pass 3050,00 4061.97 -226770 7040.53 12288.17 4072.86 -3285.51 636965 218.36 202.42 313.13 993.34 5.77 OSF 1.50 Pass 3100.00 406179 -2296.97 7081.07 12324.82 407247 -3286.18 640003 218.34 201.03 314.71 990.89 5.74 OSF 1.50 Pass 3150.00 4061.61 -232624 7121.80 12381.67 4071.65 3307.19 6430.17 216.31 200.18 316.25 989.02 5.71 OSF 1.50 Pass 3200,00 4061.43 -2355.51 718214 12406.00 4070.25 -333288 646628 216.25 199.80 31796 987.50 5.67 OSF 1.50 Pass Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 32 of 137 • • • • Trajectory:9107-0E4(P3)Vs.SP12-SE3 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference ND Reference NS Reference EW Offset MD Offset/VD Offset NS Offset EW North Azim Ct-Ct Defence Separation Clearance OSF Controlling Rule Status (ft) (9) (6) (n) ((t) (6) (8) (8) C) (ft) (9) (ft) 325000 406126 -238478 720268 2455.83 4068.83 -3361.77 650685 216 19 1199 41 31981 985 94 5.64 OSF 1.50 Pass 330.0 4061.08 -2414.05 7243.22 2503.16 4067.63 -3389.25 654536 216 14 1199.19 32160 984.46 5.61 OSF 1.50 Pass 3350.0 4060.90 -2443.32 7283.75 2549.43 4086.48 -3416.23 8582.93 21E1*INNIMEAM 32336 983 16 5.57 057 1.50 Pass 340.0 4060.73 -2472.59 732429 2588.67 4085.56 -3439.27 6614.69 216.06 11".1: 324.90 982.25 5.55 OSF 150 Pass 3450.0 4060.55 -250166 7364.83 2624.57 406491 -3460.68 664349 21803 1199.87 325.3[® 5.53 05F 1.50 Pass 3486.65 4080.42 -2523.31 739454 265087 4064.56 -3476.58 6664.44 216.02 120.75 32731 982.21 5.51 OSF 1.50 Pass 300.0 4060.40 -2531.12 7405.37 266029 406446 -348232 6671.0 21601 1201.15 327.63 982.40 5.51 05F 1.50 Pass 3550.0 4080.89 -2560.38 7445.91 269424 4063.92 -350323 6698.85 216.0 1203.07 328.66 983.64 5.50 OSF 1.50 Pass 3800.0 402.0 -2589.62 748645 2728.12 4063.0 -352444 6725.0 215.93 1205.66 32968 985.55 5.50 OSF1.50 Pass 3650.0 406328 -2618.86 752699 2768.89 4061.88 -3550.37 6756.49 215.82 1208.87 33109 987.82 5.49 OSF 1.50 Pass 370.0 406450 -2648.11 7567.53 2823.60 4060.32 -3585.14 6798.70 215.69 1212.08 33313 989.67 5.47 OSF 1.50 Pass 3750.0 4065.72 -2677.35 760807 2880.43 4059.62 -3621.07 6842.72 215.60 1215.07 335.28 991.22 5.45 OSF 1.50 Pass 380.0 4068.94 -270.59 764861 293841 4058.89 3657.43 6887.88 215.50 121773 33748 99242 5.42 05F1.0 Pass 3850.0 406815 -2735.83 7889.15 299173 4058.35 -3690.68 6929.56 21541 1220.16 . 339.48 993.52 5.40 OSF 1.50 Pass 390.0 4089.37 -2765.08 7729.68 3046.0 4058.07 -3724.40 6972.0 215.34 1222.45 341.52 994.44 5.38 OSF 1.50 Pass 3950.0 4070.58 -2794.32 7770.22 310299 40774 3759.59 701692 215.28 122450 343.67 995.05 536 OSF 1.50 Pass 400.0 4071.61 -2823.58 7810.76 3160.35 407.24 -379474 7062.23 215.17 1226.25 34564 5.33 OSF 1.50 Pass 0 4050. 407264 -285281 785131 3217.87 405656 -3829.70 7107.90 215.07 1227.69 348. 5.30 OSF1.50 Pass 41000 407276 -2682.0 789186 3267.04 405589 3859.48 7147.03 215.02 1228.99 34988 5.28 OSF1.50 Pass 4150.0 4072.80 -291131 793241 331657 4055.18 388950 7186.41 214.99 1230.31 351.76 995.48 5.26 OSF 1.50 Pass 420.0 4072.84 -2940.56 7972.96 3368.85 4054.47 -3921.16 722802 214.95 1231.60 35372 995.46 5.23 OSF 1.50 Pass 425000 4072.88 -2969.82 801351 3422.80 4053.82 -395361 7270.88 21492 123278 355.73 995.29 521 OSF 1.50 Pass 430.0 4072.92 -2999.07 8054.06 3479.38 405330 -398768 731627 21490 123373 357.85 994.83 5.18 OSF 1.50 Pass 430.0 4072.96 -302832 8094.61 354230 4053.03 -4025.09 738687 214.88 123432 383.16 99388 515 0571.50 Pass 440.0 4073.0 -3057.57 813516 360.80 4053.38 -40268 741903 214.89 1234.29 36248 992.30 5.12 OSF1.50 Pass 4450.0 4073.04 -308682 8175.71 3665.84 4053.78 -4096.88 746740 214.91 1233.81 364.66 990.37 508 OSF1.50 Pass 450.0 407308 -311608 8216.26 372498 4054.07 -413088 7515.95 21492 1232.95 36662 986.08 5.05 OSF1.50 Pass 4550.0 4073.16 -3145.33 8256.81 378249 4054.28 -4163.16 7563.39 214.88 123174 368.89 985.48 5.02 OSF 1.50 Pass 480.0 4073.53 -3174.53 8297.39 3826.60 4054.61 -416820 759995 214.85 1230.57 37058 983.19 4.99 OSF 1.50 Warning 4650.0 4073.92 -320374 8337.97 3871.12 4055.25 -4213.41 7636.39 214.86 122964 372.38 98105 4.98 OSF 1.50 Warning 470.0 4074.30 -323294 8378.56 3922.01 4056.47 -424244 7678.17 21490 1228.80 37432 978.92 4.93 OSF 1.50 Warning 47560 4074.68 -3262.15 6419.14 3973.31 405830 -4271.87 772029 21497 1227.92 376.28 976.74 4.90 OSF 1.50 blaming 480.0 4075.07 -329135 8459.72 402679 4060.82 -4302.04 7764.24 215.06 122694 378.31 97441 4.87 OSF 1.50 Warning 480.0 4075.45 -332056 850.30 4075.99 4062.92 -4329.89 780474 215.15 122586 380.25 972.0 4.84 OSF 1.50 Warning 490000 4075.84 -334976 8540.89 4119.26 406424 -4354.54 784027 215.19 1224.98 382.03 989.96 4.82 0671.50 Warning 4950.0 4076.22 -337897 8581.47 416786 4064.72 -4382.43 788007 215.20 1224.35 38393 968.06 4.79 OSF1.50 Warning 5000.0 4076.60 -340.17 8622.05 4231.17 4084.89 -4418.42 7932.16 215.19 1223.39 38617 965.62 4.78 OSF 1.50 Warning 5050.00 407699 -343738 866263 4293.64 406509 -4453.38 798393 215.17 122190 388.36 982.67 4.73 OSF 1.50 Warning 510.0 4077.0 -3486.60 8703.20 4353.43 4064.78 -4486.36 803380 215.23 1219.90 39046 95927 4.66 OSF 1.50 Warning 5150.0 407614 -349684 874375 440722 406500 -4515.81 8078.81 21535 1217.63 392.48 955.65 4.88 OSF 1.0 Weming 520.0 4074.70 -352508 8784.29 4454.24 406588 -454149 811820 21546 121525 39441 951.99 4.83 OSF 1.50 VJaming 5250.0 4073.24 -355432 8824.82 4495.93 4065.03 -456446 8152.99 215.52 1213.17 39624 948.69 4.80 OSF 1.50 Warning 530.0 407179 -358356 8865.35 454158 40538 -4589.85 819092 215.56 121141 398.12 945.67 4.57 OSF 1.50 Warning 5350.00 4070.33 -361280 890.88 4595.82 4064.63 -481996 823603 215.80 1209.59 40.15 942.49 4.54 OSF1.50 Weming 540.0 4068.88 -364204 894642 464284 4063.95 -464604 8275.26 21583 1207.68 40205 939.32 4.51 OSF1.50 Whoring 5450.0 4067.42 -3671.28 8986.95 4885.12 4063.48 -4689.59 831025 215.67 1208.05 40.67 936.48 4.49 OSF 1.50 Warning 550.0 4065.97 -370.52 902748 4725.47 406316 -4692.34 8343.57 215.71 1204.78 405.82 934.02 4.48 OSF 1.50 blaming 5550.0 4064.51 -372976 908.01 476277 4062.93 -4713.88 837417 215.75 120396 407.26 932.13 4.44 OSF 1.50 Warning 560000 4063.14 -3759.01 9108.54 480009 4062.72 -473535 840456 215.83 12067 408.81 930.81 442 OSF1.50 1Aaming 5801.85 4063.10 -376009 9110.04 4801.47 4062.72 -4736.15 840567 215.81 1203.6 40.66 930.77 4.42 OSF 1.50 \Naming 5650.0 4062.35 -378831 914905 484253 4062.51 -476029 8438.89 215.89 120377 41036 929.87 4.41 OSF 1.50 Warning 570.0 4061.65 -3817.61 9189.56 4885.71 406230 -4785.86 847369 21590 120415 411.96 929.19 4.39 OSF1.50 Warning 5750.00 4060.94 -3846.91 9230.07 494105 4062.12 -4818.72 8518.21 215.93 120463 41405 928.27 4.37 OSF 1.50 Warning 580.0 406024 -387622 9270.57 4999.82 4062.30 -485325 8565.76 21598 120473 416.25 926.90 4.35 OSF 100 %aming 5850.0 4059.53 -393552 9311.0 5050.50 406246 -488289 860.88 21602 1 .5 41823 92650 4.33 0571.50 Warning 590.0 4058.83 -393462 935159 509088 4062.45 -491175 8646.94 216. 420.16 92411 4.31 OSF 1.50 Warning 5950.0 405812 -396412 939210 514630 402.62 -4938.96 8684.55 21609422.01 822.89 4.29 0571.50 Weming 6000.00 4057.41 88 10 872466 216.15 120465 441.50 4.i OSF 1.50 Warning 6050.0 4056.71 -402273 947311 5216.00 4063.14 -4979.92 8740.94 216.17 1205.112 450.51Ei5 4.4. 007 1.60 VVaming 1.50 Wemirlg 610.0 4056.0 -4052.03 951362 5216.0 4083.14 -4979.92 8740.94 216.17 120750 450.18OSF 6128.81 4055.60 -4068.80 953680 521600 4063.14 -4979.92 874094 21617 120979 44961 909.71 404 OSF 1.50 Warning End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 33 of 137 • • Field: Nikeitchuq Well: 5/15-N8 Structure: Spy Island Borehole: S115-N2 Slot SP15 Tre)aetory. 5115-N8(P1) Client: En:Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Plane.Zone 04.US Feet North Reference: True Grid Convergence Angle: 0.08976602° Gnd Scale Factor 0999900153 Magnetic Declination: 19041` Magnetic Declination Date: November 20,2014 Magnetic Model: BGGM 2013 Reference Point Normhln .E iia Elevation Structure Dns. Io IUne. 6053645 200(SUS) 511606 320(SUS) 54.100(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Traiectory Error Model:ISCWSAO 3-D 99.000%Confidence 2.7999 sigma Survevioc Prod:While Drilling Description Part MD From(ft) MD To(ft)EOU Fred(ft) Survey Tool Type Hole Slee On) Casing Diameter(n) Borehole 1 Survey 1 0.00 10 0 41. 0 1/100.000 SLB NSG+SSHOT-Depni Only-No Global 16.000 13.375 SI15-N2/SI15-N8(P7) 1 41.000 1000.000 1/100.000 SLB NSG+SSHOT-No Globa 18.000 13.375 S115N2/S115-58(P1) 1 1000.000 2500.000 1/100.000 SLB MWD+GMAC-No Globe 16.000 13.375 S115N2/SI15-N8(P1) 2 1000.000 2686.673 1/100.000 SLB_MWD+GMAG-No Globe 18.000 13.375 S115N2/SI15N8(P1) 2 2666.673 4220.000 1/100.000 SLB_MWD+GMAG-No Globa 12.250 9.625 SI15N2/S115-58(P1) 3 2886.873 9238.523 1/100.000 SLB_MWD+GMAG-No Globe 12.250 9.625 S115N2/SI15N8(P1) 3 9236.523 10640.000 1/100.000 SLB_MWD+SAG-No Globa 8.750 5.500 0115N2/S115-58(P1) 4 9236.523 16941.768 1/100000 SLB_MWD+GMAG-NO Globs 8.750 5.500 S115N2/5115-N8(P1) Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference ND Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW North Azim Cl-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (1t) (ft) (ft) (5) (6) (ft) (ft) C) (II) (ft) (6) All local minima indicated. Results filtered:Depth 6100.00ft c=MD c=18128.81 ft Results Stared:Ct-Ct separation co 1500.00ft Results highlighted'.Ct-Ct separation c=1320.00ft 610000 4028.97 1797.48 1405.89 5148.25 3383.90 772.24 2485.15 145.74 1609.12 80.63 1554.96 30.37 OSF1.50 Pass 6150.00 4031.82 177250 144910 5162.18 3386.57 782.69 2476.89 145.40 156802 8061 1511.87 29.57 OSF 1.50 Pass 6200.00 403407 1748.44 149171 5176.86 338903 79231 2487.70 143.65 1522.64 80.53 1468.55 28.78 OSF 1.50 Pass 8250.00 4035.84 171895 153344 5189.88 339122 80084 249729 141.74 147901 80.38 1425.02 28.00 OSF 1.50 Pass 8300.00 4037.11 1690.07 1574.23 5201.21 3393.12 808.26 2505.64 139.71 1435.21 8018 1381.38 27.25 OSF 1.50 Pass 6350.00 4037.89 1659.88 1614.06 5210.88 339474 81460 251275 137.85 1391.31 79.88 1337.87 28.52 OSF 1.50 Pass 6400.00 4038.51 1629.16 1653.54 5219.95 3398.27 820.54 2519.44 137.12 1347.65 79.49 1294.25 25.81 OSF 1.50 Pass 6450.00 4039.13 1598.51 1693.02 5229.03 339779 826.49 2526.12 136.39 1304.37 79.07 1251.25 25.11 OSF 150 Pass 6500.00 403974 1567.83 1732.50 5238.11 339931 83244 2532.81 135.66 1261.52 78.59 1208.72 2444 OSF 1.50 Pass 6550.00 4040.36 1537.15 177198 5247.18 3400.84 838.39 2539.49 13491 1219.15 78.05 1166.71 23.78 OSF 1.50 Pass 6600.00 4040.97 1508.48 1811.48 5256.26 340236 844.34 2546.17 13417 1177.32 77.43 1125.29 23.15 OSF 150 Pass 6650.00 4041.54 1475.99 185108 5255.58 340392 85043 2553.02 133.90 1136.05 78.74 1084.48 22.54 OSF 1.50 Pass 6700.00 4041.70 1448.54 1891.49 5276.05 3405.68 857.30 2560.75 13352 1095.28 78.01 1044.20 21.95 OSF 150 Pass 6750.00 4041.78 1417.29 1932.04 5286.75 3407.48 864.32 2568.63 13283 1055.16 75.20 1004.62 21.37 OSF 150 Pass 6800.00 4041.86 1388.04 197259 5297.46 3409.28 871.33 2576.52 131.73 1015.81 7427 965.89 20.84 OSF 1.50 Pass 6850.00 4041.93 1358.78 2013.13 5308.17 3411.07 878.35 258440 130.82 97732 73,24 92808 20.33 OSF1.50 Pass 6900.00 404201 1329.53 205368 5318.87 341287 885.37 2592.29 129.90 93978 7207 891.33 19.87 OSF 150 Pass 6950.00 4042.09 1300.28 2094.23 5329.58 3414.67 892.38 2800.17 128.98 90333 7078 855.74 19,45 OSF 150 Pass 7000.00 404216 1271.02 213478 5340.29 3416.47 89940 2508.06 12805 868.10 6934 821.46 19.09 OSF 150 Pass 7050.00 404224 1241.77 217533 535099 3418.26 908.42 2615.94 127.11 83423 8778 788.64 18.78 OSF 1.50 Pass 7100.00 4042.32 1212.52 221588 5361.70 342006 91343 2623.83 126.18 80192 6607 757.46 18.52 OSF 1.50 Pass 7150.00 404244 118325 2256.43 5372.42 3421.86 92045 2631.72 125.22 77138 6426 728.13 18.33 OSF 1.50 Pass 7200.00 4043.24 115401 2296.97 5383.24 342368 927.55 2639.69 124.27 74337 6234 701.41 18.22 OSF 150 Pass 7250.00 4044.68 112477 2337.51 5394.17 3425.51 934.71 2647.74 123.32 718.15 60.40 677.48 18.17 OSF 1.50 Pass 7300.00 4046.15 1095.54 2378.04 5405.11 3427.35 941.88 2655.80 122.35 69647 58.55 658.03 18.17 OSF 1.50 Pass 7350.00 4047.63 106630 2418.57 5416.05 342918 949.05 2663.88 121.38 67556 58.98 837.18 18.15 OSF 1.50 Pass 7400.00 4049.10 103706 245911 5426.99 3431.02 956.22 2671.91 120.41 658.67 55.73 621.11 18.09 OSF 1.50 Pass 745000 405058 1007.82 2499.84 5437.93 3432.86 963.38 2679.97 119.44 845.04 55.06 807.92 17.94 OSF 150 Pass 7500.00 4052.05 97858 2540.17 5448.87 3434.69 97055 2688.02 118.48 63187 55.08 59774 . OSF 1.50 Pass 7550.00 4053.53 94934 2580.70 5459.80 3436.53 97772 2696.08 117.49 , 005369 592.13 �f�198 OSF 1.50 Pass 7800.00 4055.00 820.10 2621.24 547074 3438.36 984.89 2704.14 118.51 5468 588.69 17,52 OSF 1.50 Pass 7650.00 4056.47 8 .88 2861.77 5481.68 3440.20 992.06 271219 115.53 625. 56. 17.00 OSF 150 Pass 7700.00 4057.80 861.62 270231 5492.60 344203 99921 2720.23 114.57 63121 5870 18.44 OSF 1.50 Pass 7750.00 4058.33 832.37 2742.85 5503.38 3443.84 1006.28 2728.17 113.64 638.79 61.47 597.40 15.87 OSF 1.50 Pass 780200 4058.41 803.12 2783.40 5514.09 344584 1013.29 273608 112.69 649.53 6454 806.10 15.38 OSF 1.50 Pass 7850.00 4058.48 773.87 252395 552480 3447.44 1020.31 2743.95 111.74 663.71 67.78 818.13 14.94 OSF 1.50 Pass 7900.00 405856 74462 286450 5535.50 344924 1027.33 275163 110.79 881.10 70.98 63337 14.62 OSF 150 Pass 7950.00 4058.63 715.37 2905.06 5546.21 345103 1034.34 275972 109.84 701.46 74.11 65161 14.41 OSF 1.50 Pass 8000.00 4058.71 686.11 294561 5556.92 3452.83 1041.36 276760 106.90 724.55 77.09 672.75 14.30 OSF 150 Pass 8050.00 405878 656.86 2986.16 5567.63 3454.63 1948.36 277549 107.96 750.11 79.87 696.45 61 OSF 1.50 Pass 8100.00 4058.86 627.61 3026.71 557834 345643 1055.39 2783.38 107.03 777.90 8244 722.53 14.34 OSF 1.50 Pass 8150.00 4058.93 598.36 306726 5589.04 3458.22 1062.41 2791.26 106.10 80769 8480 750.75 14.47 OSF 1.50 Pass 8200.00 405901 569.11 3107.81 5599.75 3460.02 1069.43 2799.15 105.18 83927 88.94 78090 1466 OSF 150 Pass 8250.00 405903 539.87 3148.37 561047 346182 1078.45 2807.04 104.19 87240 8889 812.73 14.91 OSF 1.50 Pass 8300.00 4055.96 510.67 3188.95 562121 348362 1083.49 2814.95 103.27 90688 9066 84603 15.19 OSF 1.50 Pass 8350.00 4058.90 481.47 3229.54 5631.96 346543 1090.53 2822.87 102.37 942.63 92.27 88071 15.51 OSF 150 Pass 8400.00 4058.84 452.26 3270.12 564270 346723 1097.57 283078 101.47 97952 9373 91662 15.86 OSF 1.50 Pass 8450.00 4058.77 423.08 331071 5853.44 3468.03 1104.61 2838.69 10058 1017.40 9506 95362 16.24 OSF 1.50 Pass 6500.00 4058.71 39385 3351.29 566418 347083 1111.65 2846.60 9969 1056.19 9628 991.80 16.65 OSF 1.50 Pass 8550.00 4058.64 364.65 3391.88 567492 347264 111859 2854.51 9881 1085.78 97.39 1030.45 17.07 OSF1.50 Pass 860000 4058.58 33545 3432.46 5685.66 347444 1125.73 2862.42 9795 1138.09 98.41 1070.08 17.52 OSF 1.50 Pass 865000 4058.51 30624 347305 5696.40 3476.24 113276 2870.33 97.08 1177.05 99.36 1110.40 17.97 OSF 1.50 Pass 8700.00 4058.45 277.04 3513.63 5707.14 347805 1139.80 2878.24 96.23 121859 100.23 1151.36 18.44 OSF 150 Pass 875000 4058.13 247.82 3554.20 5717.82 3479.84 1146.80 2886.10 96.14 1260.54 101.05 1192.76 18.92 OSF 1.50 Pass 8800.00 4056.98 218.54 359472 5728.28 348159 1153.65 2893.80 96.21 1302.61 101.82 123432 1940 OSF 150 Pass 8850.00 4055.51 189.23 3635.20 5738.84 3483.33 1180.44 2801.44 95.43 1345.01 182.55 127824 19.89 OSF 1.50 Pass 8900.00 4054.05 159.93 3675.69 5749.01 348507 1187.24 2909.07 94.68 1387.84 103.23 1318.61 20.39 OSF1.50 Pass 8950.00 4052.59 130.62 3716.17 5759.38 3486.81 1174.03 2916.71 93.69 1431.07 103.88 1361.41 20.89 OSF 1.50 Pass 9000.00 4051.13 101.32 375686 5769.75 3488.56 1180.83 2924.35 93.14 1474.64 104.49 1404.58 21.40 OSF 1.50 Pass Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 45 of 137 • • Trajectory:5107-SE4(P3)Vs.5115-N8(P1) Minimum Treveling 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 (8) (ft) (8) (8) (8) (ft) (8) (fl) 7) (8) (8) (8) 9050.00 4049.67 72.01 3797.15 578012 3490.30 118762 2931.88 92.39 1518.55 05.07 1448.09 21.92 OSF 1.50 Pass 9100.00 404821 42.71 3837.63 5790.48 3492.04 119442 2939.62 91.65 1562.75 0562 149193 22.44 OSF 150 Pass 9150.00 4046.74 13.40 3878.12 5800.85 3493.78 1201.21 294725 90.92 1607.22 06.16 1536.04 22.96 OSF 1.50 Pass 9200.00 404528 -15.90 3918.60 5811.22 3495.52 1208.00 2954.89 90.20 1651.95 0667 158043 23.48 OSF 150 Pass 9250.00 404382 -45.21 395909 5821.59 3497.26 1214.80 2962.53 8948 1696.90 07.16 1625.06 24.01 OSF 1.50 Pass 9300.00 4042.78 -74.49 3999.60 5832.06 3499.01 1221.66 2970.24 87.30 1742.20 07.62 167005 24.55 OSF 1.50 Pew 9350.00 404242 -103.74 4040.15 5842.69 350080 1228.63 2978.07 88.03 1787.90 08.06 1715.45 25.09 OSF 1.50 Pass 9400.00 4042.11 -133.00 4080.70 585333 350259 1235.60 2985.91 85.31 1833.77 08.50 1761.03 25.62 OSF 1.50 Pass 9450.00 4041.80 -18225 4121.25 586398 3504.37 1242.58 2993.75 84.61 1879.79 08.94 1806.76 26.16 OSF 1.50 Pass 9500.00 4041.50 -191.50 4161.80 5869.26 3505.26 1246.04 2997.63 84.26 192597 09.03 185287 26.78 OSF 1.50 Pass 9550.00 4041.19 -220.75 420235 587423 3506.10 1249.32 3001.28 8394 1972.31 09.11 1899.18 27.40 OSF1.50 Pass 9600.00 4040.89 -250.00 424290 587907 350691 1252.52 3004.81 83.63 201879 0918 194560 2803 OSF1.50 Pass 9650.00 4040.58 -278.25 4283.45 5883.77 3507.71 1255.83 3008.24 83.32 2065.42 09.24 1992.18 28.67 OSF 1.50 Pass 9700.00 4040.27 -308.50 4324.00 5888.35 350848 1258.86 3011.57 83.03 2112.18 09.29 2038.91 2930 OSF1.50 Pass 9750.00 4039.97 -337.75 4364.55 5892.80 3509.24 1261.65 301461 82.75 2159.06 09.34 2085.76 2994 OSF 1.50 Pass 9800.00 4039.68 -367.00 4405.10 5897.14 3509.98 1264.55 3017.94 82.47 220606 0938 2132.73 30.58 OSF 1.90 Pass 9850.00 403947 -396.21 4445.68 5901.39 3510.70 1267.40 3021.01 81.68 2253.19 09.40 217985 31.23 OSF 1.50 Pass 9900.00 4039.32 -425.41 4486.26 5905.54 3511.41 1270.19 3024.00 81.42 2300.43 09.38 2227.10 31.89 OSF 1.50 Pass 9950.00 403916 -454.62 4526.85 5909.58 3512.10 1272.92 3028.90 81.17 2347.76 0937 2274.44 32.55 OSF 1.50 Pass 000000 4039.00 -483.82 456743 591353 3512.78 1275.58 3029.73 80.93 2395.19 08.36 2321.87 33.21 OSF 1.50 Pass 0050.00 4038.84 -513.03 4608.02 5917.37 351344 1278.19 3032.48 80.69 2442.71 09.35 2369.40 33.87 OSF1.50 Pass 0100.00 4038.68 -542.23 4648.60 5821.12 3514.06 1280.73 3035.15 80.48 2490.30 09.34 2417.01 34.54 OSF 1.50 Pass 0150.80 4038.52 -571.44 4889.18 5924.78 3514.71 1283.22 3037.78 80.24 2537.98 09.32 2464.69 3520 OSF 1.50 Pew 020000 4038.36 -600.64 4729.77 592835 351533 1285.68 304029 80.03 2585.73 06.30 251246 35.87 35F 1.50 Pass 0250.00 4038.28 519.84 477035 5931.84 3515.93 1288.05 3042.77 78.80 263358 09.28 256032 38.54 OSF 1.50 Pass 0300.00 4038.93 -659.06 4810.93 5935.29 3516.52 1280.42 3045.21 76.05 268162 09.24 2808.39 37.22 OSF 1.50 Pass 0350.00 4040.45 -68827 4851.47 5938.72 3517.12 1292.77 3047.63 73.53 2729.88 09.20 2856.67 37.91 OSF 1.50 Pass 0400.00 404229 -717.50 4892.00 5942.07 3517.70 1295.08 3049.99 73.33 2778.25 09.17 2705.06 38.59 OSF 1.50 Pass 0450.00 4044.13 -746.73 4932.52 594535 3518.27 1297.34 3052.30 73.13 2826.66 09.14 2753.50 39.27 OSF 1.50 Pass 0500.00 404597 -77596 497305 5948.56 3518.82 1299.56 3054.55 72.94 2975.12 09.11 2801.97 39.96 OSF 1.50 Pass 0550.00 4047.81 -805.19 5013.57 5951.70 3519.37 1301.73 3056.74 72.76 2923.62 09.08 285049 4064 OSF 1.50 Pass 0600.00 4049.65 -834.43 5054.09 5954.77 351990 1303.86 3058.89 72.58 2972.16 09.05 289905 41.33 OSF 1.50 Pass 0650.00 4051.49 -863.66 5094.62 5957.77 352043 1305.95 3060.98 7241 302074 09.02 294765 42.02 OSF 1.50 Pass 0700.00 4053.33 -892.89 5135.14 596071 352094 1307.99 306302 72.24 3069.36 09.00 299629 4270 OSF 1.50 Pass 0750.00 4055.17 -922.12 5175.66 5963.58 3521.44 1310.00 3065.02 72.08 311802 08.97 3044.96 4339 OSF 1.50 Pass 0800.00 405701 -951.35 5216.19 5966.40 3521.94 1311.97 3086.97 71.91 3166.70 08.94 3093.67 44.08 OSF 1.50 Pass 0850.00 4058.80 -98058 5258.71 5969.15 3522.42 1313.89 3068.88 73.00 3215.42 08.91 3142.41 44.77 OSF 1.50 Pew 0900.00 4059.94 -1009.87 5297.22 5971.79 3522.88 1315.75 3070.71 75.62 3284.09 08.88 3191.09 45.46 OSF 1.50 Pass 0950.00 4060.83 -1039.18 533771 5974.35 3523.33 1317.55 307248 75.47 3312.76 08.86 3239.78 48.15 OSF 1.50 Pass 1000.00 4061.72 -1068.49 5378.21 5976.87 3523.77 1319.31 307421 75.33 3361.47 08.83 3288.50 46.84 OSF 1.50 Pass 1050.00 4062.81 -1097.81 5418.71 5979.33 3524.21 1321.06 3075.90 75.19 3410.20 08.81 3337.26 47.53 OSF 1.50 Pass 1100.00 4063.50 -1127.12 5459.21 5981.74 3524.63 1322.75 3077.56 75.05 3458.97 08.78 3386.04 48.22 OSF 1.50 Pass 1150.00 4064.38 -1156.43 5499.71 5984.11 3525.05 1324.42 3079.18 74.92 3507.77 08.76 3434.86 48.91 OSF 1.50 Pew 1200.00 4065.27 -1185.74 5540.21 5986.43 3525.48 1326.06 3080.77 74.79 355859 08.73 348370 49.61 OSF 1.50 Pass 1250.00 4066.16 -1215.05 5680.70 5988.71 3525.86 1327.67 308232 74.66 360545 08.71 3532.57 50.30 OSF 1.50 Pass 1300.00 406705 -1244.36 5621.20 5990.94 3526.25 1329.28 3083.85 74.53 3654.33 08.68 3581.47 5099 OSF 1.50 Pass 1350.06 4087.94 -1273.67 566170 5993.13 3526.64 1330.81 308534 7441 3703.23 0866 363039 51.69 OSF 1.50 Pass 1400.00 4068.79 -1302.96 5702.21 599528 352702 133234 308691 74.57 375216 0863 3679.33 52.38 OSF1.50 Pass 1450.00 4069.46 -1332.16 5742.79 599742 3527.40 1333.87 3088.26 74.45 380106 0861 3728.25 53.08 OSF1.50 Pass 1500.00 4070.14 -136137 5783.37 5999.52 3527.77 133536 3089.58 74.34 3849.99 08.59 3777.20 53.77 OSF 1.50 Pew 1550.00 4070.82 -1380.57 5823.95 6001.58 3528.14 1336.83 3091.08 74.22 3898.95 0856 3826.17 54.47 OSF 1.50 Pass 1600.00 4071.50 -1419.77 5864.53 8003.61 3528.49 1338.28 309245 74.11 3947.93 0854 3875.16 55.17 OSF 1.50 Paw 1650.00 4072.18 -1448.97 5805.11 6005.59 3528.85 133970 3093.80 7401 3996.93 08.52 392417 55.86 OSF 1.50 Pass 1700.00 407286 -1478.18 594569 6907.55 352919 1341.10 3095.12 73.90 4045.95 08.49 3973.21 56.56 OSF 1.50 Pass 1750.00 4073.54 -1507.38 5986.27 6009.47 352954 134247 3096.41 73.80 4094.99 0847 4022.26 5726 OSF1.50 Pass 1800.00 4074.22 -1536.58 6026.85 6011.35 3529.87 1343.63 3097.68 73.70 4144.05 08.45 4071.34 57.95 OSF 150 Pass 1850.00 4074.90 -1565.79 6067.43 601320 3530.20 1345.16 3098.92 73.60 4193.13 08.43 412043 58.65 OSF 1.50 Pass 1900.00 4075.50 -1594.99 6108.01 8015.02 353052 1346.46 3100.14 75.31 4242.22 0841 4169.54 5935 OSF 1.50 Pass 1950.00 4075.38 -1624.22 6148.58 6016.76 3530.83 1347.72 3101.31 79.07 4291.24 08.39 4218.57 60.05 OSF 1.50 Pass 2000.00 4074.37 -1653.46 6189.12 601842 3531.13 1348.91 3102.43 81.94 4340.17 . 0837 4267.52 60.75 OSF 150 Pass 2060.00 4073.06 -1682.70 622968 502004 3531.42 135008 3103.51 81.86 4389.07 0835 4316.43 6144 OSF 1.50 Pass 2100.00 4071.76 -171195 6270.19 6021.63 353170 1351.23 3104.57 81.77 443800 08.33 436537 82.14 OSF 1.50 Pass 2150.00 4070.45 -1741.19 8310.73 6023.19 3531.98 1352.36 3105.61 81.69 4486.95 0831 4414.34 62.83 OSF 1.50 Pass 2270.00 406915 -1770.44 6351.26 602473 3532.26 1353.47 3106.64 81.81 4535.92 08.30 4463.32 63.53 OSF 1.50 Pass 2250.00 4067.84 -1799.68 639180 8026.24 3532.53 1354.56 3107.65 81.53 4584.92 08.28 4512.32 6422 OSF 1.50 Pass 230000 4066.54 -182892 643233 6027.73 3532.79 1355.64 3108.84 81.46 4633.93 08.26 4561.34 6492 OSF 1.50 Pew 2350.00 4065.23 -1858.17 647287 6028.19 3533.06 1356.70 3109.61 81.38 4682.96 08.25 4610.39 6562 OSF1.50 Pass 2400.00 4063.92 -1887.41 6513.40 603064 353331 1357.75 3110.57 81.30 4732.01 08.23 4659.45 66.32 OSF 1.50 Pew 245000 406292 -1916.86 6553.95 603207 3533.57 1358.79 3111.52 7810 478111 08.21 4708.57 67.02 OSF 150 Pass 2500.00 406270 -194591 659449 8033.52 3533.83 1359.84 3112.48 7545 4830.33 08.18 4757.80 6772 OSF 1.50 Pass 2550.00 4062.66 -1975.16 6635.05 6034.95 3534.09 136088 3113.43 75.37 4879.58 06.17 4807.06 6843 OSF 1.50 Pass End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\SI07-SE4(P3) 7/8/2014 9:06 AM Page 46 of 137 • • Field: A4kedchuq Well: SP18-N5 Structure: Spy Island Borehole: SP18-N5P81 Slot: SP18 Trajectory: SP18-N5P81 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plena,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0 08958397° Grid Seale Factor. 0999900152 Magnetic Declination: 20.842° Magnetic Declination Date: November 05,2011 Magnetic Model: BGGM 2011 Reference Point N orthine EasBna Elevation Structure Uric. $jgj.W11/ 6053640 670(ftUS) 511582 790(ftUS) 53.870(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Tralectory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Survevin9 Progl As Drilled Description MD From(R) MD To(R) EOU Frog Survey Tool Type Hole Sia(in) Casing Diameter(in) Borehole I Survey 0.000 40.770 Act-Stns SLB NSG*MSHOT-Depth Only-No Globs 16.000 13.375 SP18-N5PB1/SP18-N5PB1 40.770 760.000 Act-Shin SLB_NSG+MSHOT-No Globe 16.000 13.375 SP18-N5P81/SP18-N5PB1 760.000 2612.350 Act-Stns SLB_MW9*GMAG-No Gleba 16.000 13.375 SP18-N5P81/SP18-N5PB1 2612.350 2725.580 Act-Stns SLB MWO-INC ONLY FILLER-No Gobs 12.250 9.625 SPtO-N5PB7/SP18-N5P81 2725.580 3186.970 Act-Stns SLB MNA+GMAG-No Gob. 12.250 9.825 SP18-N5PB1/SP18-N5P81 3186.970 9420.890 ActSNs SLB MV0O+GMAG-No Globs 8.750 5.500 SP18-N5PB1/SP18-N5PB1 9420.690 9481.000 Act8Ns SLB BLIND*TREND-No Gobs 8.750 5.500 SP18-N5PB1 ISP18-N5PB1 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (*) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 6100.00ft<=MD r_16128.61 ft Results filtered:Ct-Ct separation<-1500.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 6100.00 4028.97 179748 405.89 5240.61 3893.11 107889 453.34 204.56 120042 80.72 148.28 22.56 OSF 150 Pea 6150.00 4031.82 1772.50 44910 5214.12 3886.94 105943 469.24 204.30 1220.48 80.27 166.64 23.07 OSF 150 Pan 6200.00 403407 1748.44 49171 5187.58 3880.78 103888 48486 205.68 1240.11 7994 186.49 23.54 OSF 1.50 Pan 6250 00 4035.84 171895 53344 516403 387534 1020.42 498.44 207.14 1258.94 7976 205.44 23.95 OSF 1.50 Paw 0300.00 4037.11 1690.07 574.23 5141.98 3870.23 1002.90 510.81 208.66 1277.08 79.58 22370 24.35 OSF 1.50 Pass 6350.00 4037.89 1659.86 814.06 5119.92 3865.10 985.14 522.84 209.93 129455 7967 241.11 24.68 OSF 1.50 Paw 6400.00 4038.51 162918 65354 5098.05 386000 967.31 534.44 209.72 1312.38 7982 25084 24.95 OSF 1.50 Paw 8450.00 4039.13 1598.51 693.02 5075.38 3854.70 948.61 546.10 209.52 1331.09 80.11 277.36 25.21 OSF 1.50 Paw 6500.00 403974 1567.83 732.50 5050.78 3848.73 928.16 558.42 209.29 1350.60 80.42 296.65 25.48 OSF 1.50 Pass 8550.00 4040.36 1537.15 771.98 5026.59 3842.60 907.96 57022 209.06 1370.84 80.94 316.55 25.70 OSF 1.50 Paw 8600.00 4040.97 1506.48 811.46 5002.82 3836.33 888.00 581.50 208.83 1391.83 81.44 337.21 25.93 OSF 1.50 Paw 8650.00 4041.54 1475.99 851.08 498016 3830.12 868.88 591.96 207.39 1413.74 82.07 358.69 26.13 OSF 1.50 Pass 8700.00 4041.70 1446.54 891.49 4959.95 3824.39 851.74 601.01 205.89 1437.48 82.81 381.94 26.33 OSF 1.50 Paw 6750.00 404178 1417.29 932.04 4940.20 3818.62 83490 809.57 205.70 1462.15 83.69 406.04 26.50 OSF 1.50 Pan 6800.00 4041.86 1388.04 97259 4920.87 3812.80 818.35 617.68 205.51 1487.55 8453 430.86 2619 OSF 1.50 Paw 890.00 4041.93 135878 2013.13 4901.95 3806.94 802.08 625.35 205.32 1513.63 85.50 456.31 26.85 OSF 1.50 Paw 6900.00 404201 1329.53 2053.68 4884.36 3801.37 786.9 632.25 205.15 1540.41 86.43 482.46 27.03 OSF 1.50 Paw 6950.00 4042.9 1300.28 2094.23 489.55 3796.39 773.11 638.21 20499 1567.89 87.44 509.25 27.19 OSF 1.50 Pass 7000.00 4042.16 1271.02 2134.78 4853.02 3791.57 759.47 643.83 204.85 1596.06 88.42 536.78 27.36 OSF 1.50 Paw 7050.00 4042.24 1241.77 2175.33 4837.80 3786.90 745.98 649.12 204.72 1624.91 89.48 564.92 27.52 OSF 1.50 Pass 7100.00 4042.32 1212.52 2215.88 4822.9 3782.38 73264 694.9 20459 1654.40 90.51 593.73 27.70 OSF 1.50 Paw 7150.00 4042.44 1183.28 2258.43 4808.22 3778.02 719.47 65875 204.72 1684.52 91.55 623.18 27.9 OSF 1.50 Pass 7200.00 4043.24 1154.01 2298.97 4793.95 3773.83 706.53 69.9 205.36 1715.34 92.51 93.34 28.10 OSF 1.50 Paw 7250.00 4044.68 1124.77 2337.51 4779.60 379.62 693.46 867.26 205.45 1746.83 93.49 684.18 28.31 OSF 1.50 Pass 7300.00 4048.15 195.54 2378.04 479.51 379.43 680.9 671.18 205.33 1778.87 94.45 715.57 28.53 OSF 1.50 Pass 7350.00 4047.63 1066.30 2418.57 475176 3781.28 668.00 674.83 20520 1811.43 95.50 747.43 28.73 OSF 1.50 Paw 7400.00 4049.10 1037.06 2459.11 4738.32 3757.16 655.67 678.23 205.08 1844.50 96.52 779.83 28.94 OSF 1.50 Paw 7450.00 4050.58 1007.82 249.64 4725.21 3753.9 643.61 681,40 20497 1878.07 97.56 812.70 29.15 OSF 1.50 Pass 7500.00 4052.05 978.58 2540.17 4712.41 3749.07 631.82 684.34 204.9 1912.11 9856 848.07 29.38 OSF 1.50 Paw 7550.00 4053.53 94934 2500.70 4699.91 3745.09 620.29 687.06 20475 1946.61 6844 900.69 y13 26 OSF 1.50 Paw 7600.00 4055.00 920.10 2621.24 4884.90 3740.26 606.42 90.18 204.61 1981.52 6834 935.63 .64.11 OSF 1.50 Paw 7650.00 4056.47 890.86 2661.77 4670.08 3735.46 592.71 893.12 204.49 2016.82 6826 970.98 4495 OSF 1.50 Pan 7700.00 405780 861.62 2702.31 465554 3730.71 579.24 95.9 203.78 2052.45 9.19 2006.67 45.79 OSF1.50 Pass 7750.00 4058.33 832.37 2742.85 4841.18 3725.9 56593 698.43 202.67 2088.33 9.14 2042.57 46.63 OSF 1.50 Paw 7800.00 4058 41 803.12 2783.40 4627.05 3721.31 552.82 700.83 202.55 2124.47 9.10 2078.75 47.48 OSF 1.50 Pass 7850.00 405848 773.87 2823.95 4813.20 3716.69 539.96 703.08 202.46 2160.96 9.07 2115.24 48.29 OSF 1.50 Paw 7900.00 4058.56 744.62 288450 4800.07 3712.28 527.75 70506 202.37 2197.76 9.05 2152.06 49.13 OSF 150 Paw 7950.00 405863 715.37 290506 4588.71 3708.48 517.17 706.67 202.29 2234.90 68.05 2169.20 49.96 OSF 1.50 Paw 8000.00 4058.71 686.11 2945.61 4577.57 3704.78 506.77 708.15 202.22 2272.37 68.05 2226.67 50.80 OSF 1.50 Paw 8050.00 4058.78 656.86 2986.16 458667 3701.18 496.56 79.48 202.16 2310.15 6806 2264.45 51.84 OSF 1.50 Paw 8100.00 405886 627.61 3026.71 455598 369768 486.53 710.9 202.9 2348.25 907 2302.54 52.48 OSF 1.50 Paw 8150.00 405893 98.36 3067.26 454551 3694.28 476.69 711.77 202.04 2386.65 9.10 2340.92 53.32 OSF1.50 Paw 8200.00 4059.01 569.11 3107.81 4535.25 390.97 467.03 712.74 201.98 2425.33 9.12 2379.9 5417 OSF 150 Paw 8250.00 405903 539.87 3148.37 4525.20 397.75 457.55 713.59 201.65 2464.30 6815 2418.54 55.01 OSF 1.50 Paw 8300.00 40998 510.67 319.95 4515.36 3684.62 448.24 714.34 201.60 2503.55 9.19 2457.78 55.86 OSF 1.50 Pass 8350.00 405890 48147 3229.54 4504.34 391.14 437.81 715.08 201.55 2543.05 6825 249722 58.9 OSF 1.50 Pass 8400.00 4058.84 452.26 3270.12 449.70 3676.22 423.00 716.03 201.48 2582.76 68.34 2538.87 57.50 OSF 1.50 Paw 8450.00 4058.77 423.08 3310.71 4473.29 3671.37 408.41 716.9 201.41 2622.64 68.44 2578.68 58.30 OSF 1.50 Paw 8500.00 405871 393.85 3351.29 449.11 3856.58 394.01 717.64 201.34 2862.69 6854 2616.9 9.10 OSF 150 Paw 8560.00 4058.64 384.65 3391.88 4443.15 3861.88 379.82 71830 201.28 2702.90 6866 2856.81 599 OSF 1.50 Paw 8600.00 4058.58 335.45 3432.46 4428.40 3657.23 365.84 718.87 201.21 2743.28 6877 2697.11 60.69 OSF 1.50 Pass 8850.00 405851 30624 3473.05 4413.88 3652.66 352.05 719.35 201.16 278382 9.9 2737.57 61.47 OSF 1.50 Paw 8700.00 409.45 277.04 3513.9 4403.56 3649.42 342.28 719.63 201.11 2824.53 9.9 2778.21 62.28 OSF 1.50 Paw 8750.00 405813 247.82 3554.20 4394.10 3648.43 333.30 719.83 200.13 295.39 6909 2819.00 63.09 OSF 1.50 Paw 8800.00 4056.98 218.54 394.72 4384.72 3643.45 324.41 719.98 19.9 2906.27 69.20 299.81 63.9 OSF 1.50 Paw 8850.00 4055.51 19.23 3635.20 4375.47 3640.51 315.64 720.03 19.07 2947.27 6931 290074 64.9 OSF 1.50 Pass 8900.00 4054.05 19.93 3675.69 4369.40 3637.60 307.05 720.04 19.05 298846 6943 2941.85 9.47 OSF 1.50 Paw 8950.00 4052.59 130.62 3716.17 4357.50 3634.75 298.61 720.00 19.03 3029.83 69.55 2983.14 66.27 OSF 1.50 Paw 9000.00 4051.13 101.32 3758.66 4348.78 3631.94 280.34 719.90 19.01 3071.38 69.66 3024.61 67.06 OSF 1.50 Paw 9050.00 4049.67 7201 3797.15 4340.18 3829.17 282.23 719.75 198.9 3113.10 6978 309.25 67.86 OSF 1.50 Paw Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\S107-SE4(P3) 7/8/2014 9:06 AM Page 51 of 137 • • Trajectory'.SI07-SE4(P3)Vs.SP18-N5PB1 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) (6) (ft) (ft) (ft) (6) (6) (8) (') (ft) (ft) (ft) 9100.00 4048.21 42.71 383763 433176 3626.44 274.26 719.55 198.97 315498 69.89 3108.06 88.68 OSF 1.50 Pass 9150.00 4046.74 13.40 3878.12 4323.50 3623.76 268.45 71931 198.95 319703 70.01 3150.03 69.45 OSF 1.50 Pass 9200.00 4045.28 -15.90 391860 4315.06 3621.01 258.47 719.01 198.93 323924 70.13 319216 70.25 OSF 1.50 Pass 9250.00 4043.82 45.21 3959.09 4305.55 3617.93 249.49 718.63 198.91 3281.59 70.26 3234.42 71.03 OSF 1.50 Pass 9300.00 4042.78 -74.49 390960 4296.25 3614.94 240.69 718.19 200.31 332415 70.32 3276.94 7189 OSF 1.50 Peso 9350.00 4042.42 -103.74 4040.15 4287.18 3612.06 232.10 717.72 200.80 3366.97 70.38 3319.73 7276 OSF 1.50 Pass 9400.00 4042.11 -133.00 4080.70 4278.27 3609.25 223.66 717.21 200.77 3409.93 70.45 3362.63 73.61 OSF 1.50 Peso 9450.00 4041.80 -162.25 4121.25 4269.49 3606.51 215.34 718.86 200.74 345301 70.58 3405.63 74.40 OSF 1.50 Pass 9500.00 4041.50 -191.50 4181.80 4260.85 3603.84 207.14 716.07 200.72 3496.21 70.70 3448.75 75.20 OSF 1.50 Pass 9550.00 4041.19 -220.75 4202.35 425234 360123 199.07 715.45 200.70 3539.53 70.83 3491.98 75.99 OSF 1.50 Peso 9600.00 4040.89 -250.00 4242.90 4243.97 3598.69 191.12 714.79 200.68 3582.97 70.98 3535.33 78.78 OSF 1.50 Peso 9650.00 4040.58 -279.25 4283.45 4235.72 359621 183.28 714.11 200.68 3626.52 71.09 3578.80 7758 OSF1.50 Pass 9700.00 4040.27 -308.50 4324.00 422760 359379 175.57 713.39 200.64 3670.17 71.21 3822.37 78.37 OSF 1.50 Pass 9750.00 4039.97 -337.75 4364.55 4218.80 3591.12 167.01 712.55 200.82 3713.94 71.33 3666.06 7917 OSF 1.50 Pass 9800.00 4039.66 -367.00 4405.10 4208.48 3588.12 157.40 711.57 200.60 3757.80 71.43 3709.85 79.99 OSF 1.50 Pass 985000 4039.47 -396.21 4445.68 419854 358514 147.96 710.58 200.78 3801.78 71.49 3753.79 80.87 OSF 1.50 Pass 9900.02 403932 -425.41 4486.26 4188.74 3582.19 138.67 709.56 200.75 3845.85 71.54 3797.83 81.74 OSF 1.50 Pass 9950.02 4039.18 -454.62 4526.85 4179.07 357927 129.51 708.53 200.73 3890.02 71.64 3841.93 8256 OSF 1.50 Pass 000.00 4039.00 -483.82 456743 4189.53 357636 120.48 707.49 200.71 3934.26 71.75 388610 83.38 OSF 1.50 Peso 00050.00 4038.84 -513.03 460802 4160.11 357348 111.59 706.42 260.68 3978.58 7185 393036 84.19 OSF 1.50 Pass 0100.00 4038.68 -542.23 4648.60 4150.83 3570.62 102.82 705.34 200.66 4022.99 71.96 397469 8501 OSF 1.50 Pass 0150.00 4038.52 -571.44 4889.18 4141.87 356778 94.18 704.25 200.64 4067.47 72.06 4019.10 85.82 OSF 1.50 Pass 0200.00 4038.36 -600.64 472977 4132.63 3564.97 85.66 703.14 200.62 4112.03 72.17 406359 8663 OSF 1.50 Pass 0250.00 4038.28 -629.84 4770.35 4123.66 3562.16 77.22 702.02 201.43 4156.88 72.26 4108.18 87.46 OSF 1.50 Pass 0300.00 403893 -65906 4810.93 4114.81 3559.34 68.90 700.89 203.38 4201.47 7231 415293 88.34 OSF 1.50 Pass 0350.00 4040.45 588.27 4851.47 4106.19 355653 60.83 699.78 205.12 424640 72.32 4197.86 89/7 OSF 1.50 Pass 0400.00 4042.29 -71750 4892.00 4097.73 355373 52.93 898.66 20507 4291.42 72.38 424284 90.14 OSF 1.50 Pass 0450.00 4044.13 -748.73 4932.52 4089.40 3550.91 45.17 69755 205.02 4336.51 72.48 4287.87 90.97 OSF 1.50 Pass 0500.00 4045.97 -77596 4973.05 408120 354808 37.54 696.45 204.97 4381.87 72.57 4332.96 9179 OSF 1.50 Pass 0550.00 4047.81 -805.19 5013.57 407312 354525 30.06 695.34 204.92 4426.89 72.67 4378.11 9261 OSF 1.50 Pass 0600.00 4049.65 -834.43 505409 4085.16 354241 22.71 69424 204.87 4472.17 72.77 4423.33 93.43 OSF1.50 Pass 0650.00 4051.49 -883.66 509462 4057.32 353957 15.48 693.13 204.82 4517.52 72.87 4488.81 94.25 OSF 1.50 Pass 070000 405333 -892.89 5135.14 4049.60 3536.73 8.39 692.04 20477 4562.93 72.98 4513.96 9507 OSF 1.50 Pass 0750.00 4055.17 -922.12 5175.66 404199 353388 1.42 690.94 20472 4808.40 73.06 4559.37 95.89 OSF1.50 Pass 0800.00 4057.01 -951.35 5216.19 4034.50 3531.04 -5.43 689.85 204.67 4653.93 73.15 4604.84 9671 OSF 1.50 Pass 0850.00 4058.80 -98058 5258.71 4028.72 3528.04 -12.51 688.71 203.93 4699.52 73.28 4650.35 97.52 OSF 1.50 Pass 0900.00 4059.94 -100987 5297.22 401852 3524.84 -19.96 687.49 202.34 474508 73.37 4695.84 9831 OSF 1.50 Pass 0950.00 4060.83 -1039.18 5337.71 4010.39 3521.61 -27.33 686.28 202.29 4790.67 73.48 4741.35 99.10 OSF 1.50 Pass 1000.00 4061.72 -1068.49 5378.21 400236 3518.39 -34.58 685.06 20224 4836.31 73.59 4788.92 9989 OSF1.50 Pass 1050.00 4062.61 -1097.81 5418.71 3994.44 3515.16 41.71 683.85 20219 4882.00 73.71 4832.53 100.88 OSF 1.50 Pass End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\S107-SE4\S107-SE4(P3) 7/8/2014 9:06 AM Page 52 of 137 • • Field: Nikeifchuq Well: SP18-N5 Stricture: Spy Island Borehole: SP18-N5 Slot SP18 Trajectory. SP18-N5 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27Aleska State Plane,Zone 04,US Feet North Reference: True Odd Convergence Angle: 0.08958397° Grid Scale Factor: 0999900152 Magnetic Declination: 20.842° Megnetic Declination Date: November 05,2011 Magnetic Model: BGGM 2011 Reference Point: Nom J:au ElevationStructure Unc. Slot Une. 6053640 670(ftUS) 511582.790(ftUS) 53.870(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Traiectory Error Model:ISCWSA0 3-D 95.000%Confidence 2.7956 sigma Survevino Prone'As Drilled Description MD From(ft) MD To 00 EOU Freq Survey Tool Type Hole Sin fin) Casing Diameter(n) Borehole I Survey 0.000 40.770 Act-Stns SLB NSG0MSHOT-Depth Only-No Global 16.000 13375 SP18-N5PB1 1 SP18-N5PB1 40.770 760030 Act-Sas SLB_NSG+MSHOT-NO Globe 16.000 13.375 5P18-N5PB1 ISP18-N5PB1 760.000 2612.350 Act-Stns SLB_MWO+GMAG-No Globe 16.000 13.375 5P18-N5PB1/SP18-N5PB1 2612.350 2725580 Act-Sins SLB MWD-INC ONLY FILLER-No Glebe 12.250 9.625 SP18-N5PB1/SP18-N5PB7 2725.580 3186.970 Act-SUs SLBMW9+GMAG-No Globe 12.250 9.825 SP18-N5PB1/SP18-N5PB1 3186.970 7695.640 Ad-Sins SLB_MWD+GMAG-No Globe 8.750 5.500 SP18-N5PB1/SP18-N5PBI 7895.640 13539910 Act-Stns SLB_MWD+GMAG-No Globe 8.750 5.500 SP18-N5/SP18-N5 13539.910 13001.000 Act-Sins SLB BLIND+TREND-No Globe 8.750 5.500 SP18-N5/SP18-N5 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Clearance OSF Controlling Rule Status (ft) (ft) (D) (5) (5) (H) (ft) (ft) (°) (ft) (8) (0) All local minima indicated. Results filtered:Depth 610000899 MD c_16128.61 ft Results filtered:Ct-Ct separation on 1500.00 ft Results highlighted:Ct-Ct separation c_1320.00 ft 6100.00 4028.97 179748 140589 5240.61 3893.11 107969 453.34 20456 1200.42 8072 1146.28 22.56 OSF 150 Pass 6150.00 4031.82 177250 144910 521412 388694 1059.43 469.24 204.30 122048 80.27 1166.64 23.07 OSF 1.50 Pass 6200.00 4034.07 1746.44 1491.71 5187.58 388078 1038.88 484.86 205.68 1240.11 79.94 1186.49 23.54 OSF 1.50 Pass 6250.00 4035.84 1718.95 1533.44 516403 387534 1020.42 498.44 207.14 1258.94 7976 1205.44 23.95 OSF 150 Pass 630000 4037.11 169007 157423 5141.98 387023 1002.90 510.81 208.66 127708 79.58 1223.70 2435 OSF 1.50 Pass 6350.00 4037.89 1659.86 1614.06 511992 3865.10 98514 522.84 20993 129455 79.67 1241.11 24.66 OSF 1.50 Pass 6400.00 4038.51 1629.18 1653.54 5098.05 3860.00 967.31 53444 209.72 1312.38 79.82 1258.84 2495 OSF 1.50 Pass 6450.00 4039.13 1598.51 1693.02 5075.38 3854.70 948.81 548.10 209.52 1331.09 80.11 1277.36 2521 OSF 1.50 Pam 6500.00 4039.74 156783 173250 5050.78 384873 92816 55842 209.29 1350.80 80.42 1296.65 25.48 OSF 1.50 Pass 6550.00 4040.36 1537.15 1771.98 5026.59 3842.60 907.96 570.22 209.06 1370.84 80.94 1316.55 25.70 OSF 1.50 Pass 6600.00 404097 150648 1811.46 5002.82 3836.33 888.00 581.50 206.83 1391.83 8144 1337.21 25.93 OSF 1.50 Pass 6650.00 404154 1475.99 185108 498016 3830.12 868.88 591.96 207.39 1413.74 82.07 1358.69 26.13 OSF 1.50 Pass 6700.00 4041.70 144654 189149 4959.95 3824.39 851.74 601.01 205.89 1437.48 8281 138194 28.33 OSF 1.50 Pass 6750.00 404178 1417.29 193204 494020 3818.62 834.90 609.57 205.70 1462.15 83.69 1406.04 26.50 OSF 150 Pass 6800.00 4041.86 138804 197259 492087 3812.80 818.35 617.68 205.51 1487.55 8453 1430.86 28.69 OSF 1.50 Pass 6850.00 4041.93 1358.78 2013.13 490195 380694 802.08 625.35 205.32 1513.63 85.50 1456.31 26.85 OSF 1.50 Pass 6900.00 404201 1329.53 205368 488436 3801.37 786.89 832.25 205.15 154041 86.43 1482.46 27.03 OSF 1.50 Pass 695000 4042.09 1300.28 2094.23 486855 3796.39 773.11 638.21 20499 156789 87.44 1509.26 27.19 OSF 1.50 Pass 7000.00 404216 1271.02 2134.78 4853.02 379157 759.47 643.83 204.85 159606 88.42 1536.78 27.36 OSF 1.50 Pass . 7050.03 4042.24 1241.77 217533 4837.80 3786.90 745.98 649.12 204.72 1624.91 89.48 1564.92 27.52 OSF 1.50 Pass 7100.00 4042.32 1212.52 2215.88 4822.86 378238 73264 654.09 204.59 1854.40 90.51 1593.73 2770 OSF 1.50 Pass 7150.00 4042.44 1183.26 225643 4808.22 3778.02 71947 658.75 204.72 168452 91.55 1623.18 27.88 OSF 1.50 Pass 7200.00 4043.24 1154.01 229697 4793.95 3773.83 706.53 663.09 205.36 1715.34 92.51 1653.34 28.10 OSF 1.50 Pass 7250.00 4044.68 1124.77 2337.51 4779.60 3769.62 693.46 887.26 205.45 174683 93.49 1684.18 28.31 OSF 1.50 Pass 7300.00 4046.15 1095.54 2378.04 4765.51 3765.43 680.59 671.18 205.33 1778.87 94.45 1715.57 28.53 OSF 1.50 Pass 7350.00 4047.63 1086.30 241857 4751.76 3761.28 668.00 674.83 205.20 1811.43 95.50 1747.43 28.73 OSF 1.50 Pass 7400.00 4049.10 1037.06 2459.11 4738.32 3757.16 65567 678.23 205.08 1844.50 96.52 1779.83 28.94 OSF 1.50 Pass 7450.00 4050.58 1007.82 2499.64 4725.21 3753.09 643.61 681.40 20497 1878.07 97.56 1812.70 29.15 OSF 1.50 Pass 7500.00 4052.05 978.58 2540.17 471241 3749.07 631.82 684.34 204.86 1912.11 98.56 1646.07 29.38 OSF 1.50 Pass 7550.00 4053.53 94934 2580.70 4699.91 3745.09 620.29 687.06 204.75 1946.61 68.44 1900.6.5 43.28 OSF 1.50 Pass 7600.00 4055.00 920.10 2621.24 4684.90 3740.26 606.42 690.18 204.81 1981.52 88.34 193563 44.11 OSF 1.50 Pass 7650.00 4056.47 890.86 286177 467008 3735.46 59271 693.12 204.49 2016.82 68.26 197098 4495 OSF 1.50 Pass 7700.00 4057.80 861.62 2702.31 4655.54 3730.71 579.24 695.86 203.78 2052.45 68.19 2006.67 4579 OSF 1.50 Pass 7750.00 4058.33 832.37 2742.85 4641.18 3725.99 565.93 898.43 202.67 2088.33 68.14 2042.57 46.63 OSF 1.50 Pass 7800.00 4058.41 803.12 2783.40 4627.05 3721.31 55282 700.83 202.56 2124.47 68.10 2078.75 47.46 OSF 1.50 Pass 7850.00 4058.48 773.87 2823.95 4613.20 3716.69 539.96 703.06 202.46 2160.96 6807 2115.24 48.29 OSF1.50 Pass 7900.00 4058.56 744.62 2864.50 4600.07 3712.28 527.75 705.06 202.37 2197.76 68.05 2152.06 49.13 OSF 1.50 Pass 7950.00 4058.63 71537 290506 4588.71 3708.48 517.17 706.67 202.29 2234.90 68.05 2189.20 49.96 OSF 1.50 Pass 8000.00 405871 686.11 2945.61 4577.57 370478 506.77 708.15 202.22 2272.37 68.05 2226.67 50.80 OSF 1.50 Pass 8050.00 4058.78 656.86 2986.16 4566.67 3701.18 496.56 709.48 202.18 2310.15 68.06 2264.45 51.64 OSF 1.50 Pass 8100.00 4058.86 627.61 3026.71 4555.98 3697.68 486.53 71069 202.09 2348.25 68.07 2302.54 52.48 OSF 1.50 Pass 8150.00 4058.93 598.36 306726 4545.51 3694.28 476.69 711.77 202.04 2386.65 68.10 234092 53.32 OSF 1.50 Pass 822.00 4059.01 56911 3107.81 4535.25 3690.97 467.03 712.74 201.98 2425.33 68.12 237959 54.17 OSF 1.50 Pass 825000 405903 539.87 3148.37 4525.20 368775 457.55 713.59 201.65 2464.30 68.15 2418.54 55.01 OSF 1.50 Pass 832.00 4058.96 510.67 318895 4515.36 3884.62 448.24 714.34 201.2 2503.55 68.19 2457.76 55.86 OSF 1.50 Pass 8350.00 4058.90 481.47 3229.54 4504.34 3681.14 437.81 715.2 201.56 2543.05 68.25 2497.22 56.69 OSF 1.50 Pass 842.2 4058.84 45226 327012 4488.70 3676.22 423.00 716.03 201.48 258276 68.34 2536.87 57.50 OSF 1.50 Pass 8450.00 4058.77 423.06 3310.71 4473.29 3671.37 42.41 718.89 201.41 2622.64 68.44 2576.88 58.30 OSF 1.50 Pass 8500.00 4058.71 393.85 3351.29 4458.11 3668.58 394.01 717.64 201.34 2662.69 68.54 2616.66 59.10 OSF 1.50 Pass 8550.00 4058.64 364.65 3391.88 4443.15 36661.88 379.82 718.30 201.28 270290 68.66 2656.81 59.89 OSF 1.50 Pass 8800.00 4058.58 33545 3432.46 4428.40 365723 365.84 718.87 201.21 2743.28 68.77 2897.11 60.69 OSF 1.50 Pass 8650.00 4058.51 30E24 3473.05 4413.86 3652.66 352.05 719.35 201.16 2783.82 68.89 2737.57 61.47 OSF 1.50 Pass 870000 4058.45 27704 351363 4403.56 364942 342.28 719.63 201.11 2824.53 6899 2778.21 62.28 OSF1.50 Pass 8750.00 4058.13 247.82 3554.20 4394.10 3646.43 333.30 719.83 200.13 2865.39 69.09 2819.00 6309 OSF 1.50 Pass 8800.00 4056.98 21854 3594.72 4384.72 364345 324.41 719.96 19909 290627 69.20 2859.81 63.89 OSF 1.50 Pass 8850.00 405551 189.23 3635.20 4375.47 3640.51 315.84 720.03 199.07 2947.27 69.31 2900.74 64.88 OSF 1.50 Pass 8900.00 4054.05 15993 3675.69 4366.40 3637.60 307.05 720.04 199.05 298846 69.43 2941.85 65.47 OSF 1.50 Pass 8950.00 4052.59 130.62 3718.17 4357.50 363475 298.61 720.00 19903 3029.83 6955 2983.14 66.27 OSF 1.50 Pass 920.00 4051.13 10132 3756.66 4348.76 3631.94 290.34 719.90 198.01 3071.38 69.66 3024.61 67.06 OSF 1.50 Pass • Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\S107-SE4\S107-SE4\S107-SE4(P3) 7/8/2014 9:06 AM Page 53 of 137 • • Trajectory'.S107-5E4(P3)Vs.SP18-N5 Minimum Traveling Cylinder Allowable EOU-EOU Reference MD Reference TD 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) (0) (8) (6) (6) (0) (R) (°) (ft) (9) (9) 9050.00 4048.67 72.01 3797.15 4340.18 362917 282.23 719.75 198.99 3113.10 69.78 3066.25 67.86 OSF 1.50 Pass 9100.00 4048.21 42.71 3837.63 433176 3626.44 27426 719.55 198.97 3154.98 69.89 3108.176 66.66 OSF 1.50 Pass 915000 4046.74 13.40 3878.12 4323.50 362376 286.45 719.31 198.95 319703 70.01 3150.03 69.45 OSF 1.50 Pass 9200.00 404528 -15.90 391860 4315.06 3621.01 258.47 719.01 198.93 3239.24 7013 319216 7025 OSF 1.50 Pass 9250.00 404382 -45.21 395909 4305.55 3617.93 249.49 718.63 198.91 3281.59 70.26 3234.42 71.03 OSF 1.50 Pass 9300.00 404278 -74.49 3999.60 4296.25 361484 240.69 718.19 200.31 3324.15 70.32 3278.94 71.89 OSF 1.50 Pass 935000 4042.42 -103.74 4040.15 4287.18 361206 232.10 717.72 200.80 3366.97 70.38 3319.73 7276 OSF 1.50 Pass 9400.00 404211 -133.00 4080.70 4278.27 3829.25 223.66 717.21 200.77 3409.93 70.45 336263 73.61 OSF 1.50 Pass 9450.00 4041.60 -162.25 4121.25 4269.49 360651 215.34 716.66 20074 345301 70.58 3405.63 7440 OSF 1.50 Pass 950000 4041.50 -191.50 4161.80 426085 3603.84 207.14 716.07 200.72 3496.21 70.70 3448.75 75.20 OSF 1.50 Pass 9550.00 4041.19 -220.75 4202.35 4252.34 3601.23 199.07 715.45 200.70 3539.53 70.83 3491.98 75.99 OSF 1.50 Paw 9600.00 4040.89 -250.00 424290 4243.97 3598.69 191.12 714.79 200.68 3582.97 70.96 3535.33 7678 OSF 1.50 Pecs 9650.00 4040.58 -278.25 428345 4235.72 359621 183.28 714.11 200.66 362652 7109 3578.80 77.58 OSF 150 Pass 9700.00 4040.27 -308.50 4324.00 422760 359379 175.57 713.39 200.64 3670.17 71.21 362237 78.37 OSF 1.50 Pass 9750.00 4039.97 -33775 4364.55 4218.60 3581.12 167.01 712.55 200.62 371394 71.33 3686.06 79.17 OSF 1.50 Pass 9800.00 4039.66 -367.00 4405.10 4208.48 3588.12 157.40 711.57 200.60 3757.80 71.43 3709.85 7999 OSF 1.50 Pass 985000 4039.47 -396.21 444568 4198.54 3585.14 147.98 710.58 200.78 3801.78 71.49 375379 80.67 OSF 1.50 Pass 9900.00 4039.32 -42541 4486.26 418874 3582.19 13887 709.56 200.75 384585 71.54 3797.83 81.74 OSP 1.50 Pass 9950.00 4039.16 -45462 4526.85 4179.07 3579.27 129.51 708.53 200.73 3890.02 71.64 3841.93 82.56 OSF 1.50 Pass 0000.00 4039.00 -48382 4567.43 4169.53 3578.36 120.48 707.49 200.71 3934.28 71.75 3886.10 83.38 OSF1.50 Pass 0050.00 4038.84 -51303 4608.02 4160.11 357348 11159 706.42 20068 3978.58 71.85 3930.36 8419 OSF1.50 Pass 0100.00 4038.68 -542.23 4648.60 4150.83 3570.62 102.82 705.34 20066 4022.99 71.96 3974.69 85.01 OSF 1.50 Pass 0150.00 403852 -57144 4689.18 4141.67 356778 94.18 70425 200.64 4067.47 72.06 4519.10 85.82 OSF 150 Pass 0200.00 4038.36 -600.64 472977 413263 356497 85.66 703.14 200.62 411203 72.17 4063.59 86.63 OSF 1.50 Pass 0250.00 4038.28 -629.84 4770.35 4123.66 3562.16 77.22 702.02 201.43 4156.68 72.26 4108.18 87.46 OSF 1.50 Pass 0300.00 4038.93 -85906 481093 411481 355934 68.90 700.89 203.38 4201.47 72.31 415293 88.34 OSF 1.50 Pass 0350.00 4040.45 -68827 4851.47 4106.19 3556.53 60.83 699.78 205.12 4246.40 7232 4197.86 89.27 OSF 1.50 Pass 0400.00 4042.29 -717.50 4892.00 4097.73 3553.73 52.93 698.66 205.07 4291.42 7238 4242.84 90.14 OSF 1.50 Pass 0450.00 404413 -748.73 4932.52 4089.40 355091 45.17 697.55 205.02 4336.51 72.48 428787 90.97 OSF 1.50 Pass 0500.00 4045.97 -775.96 4973.05 4081.20 3548.08 3754 696.45 204.97 4381.67 72.57 433298 91.79 OSF 1.50 Pass 0550.00 4047.81 -80519 5013.57 4073.12 3545.25 30.06 695.34 204.92 4426.89 72.67 4378.11 92.61 OSF 1.50 Pass 0600.00 4049.65 -834.43 505409 40 616 354241 22.71 694.24 204.87 4472.17 72.77 4423.33 93.43 OSF 1.50 Pass 0850.00 405149 -863.66 509462 4057.32 3539.57 15.48 693.13 204.82 4517.52 7287 446861 94.25 OSF1.50 Pass 0700.00 405333 -892.89 5135.14 404960 3536.73 8.39 692.04 204.77 4562.93 72.96 451396 95.07 OSF 1.50 Pass 0750.00 4055.17 -922.12 5175.66 404199 3533.88 1.42 690.94 204.72 4608.40 73.06 4559.37 95.89 OSF 1.50 Pass 0800.00 405701 -951.35 5218.19 403450 3531.04 -5.43 689.85 204.67 4853.93 73.15 4604.84 96.71 OSF1.50 Pass 0850.00 4058.80 -98058 5258.71 4026.72 3528.04 -12.51 688.71 203.93 4899.52 7326 4650.35 9752 OSF 1.50 Pass 0900.00 4059.94 -1008.87 5297.22 401852 3524.84 -19.96 68749 20234 4745.08 73.37 4895.84 98.31 OSF 1.50 Pass 0950.00 4080.83 -1039.18 5337.71 4010.39 352161 -27.33 686.28 202.29 4790.67 73.48 4741.35 99.10 OSF 1.50 Pass 1000.00 4061.72 -1068.49 5378.21 4002.36 3518.39 -34.58 68506 202.24 4836.31 73.59 478692 99.89 OSF1.50 Pass 1050.00 4062.61 -1097.81 541871 399444 3515.18 -41.71 683.85 202.19 488200 73.71 4832.53 100.68 OSF 1.50 Pass End of results Drilling Office 2.7.1043.0 Nikaitchuq\Spy Island\SI07-SE4\SI07-SE4\S107-SE4(P3) 7/8/2014 9:06 AM Page 54 of 137 I SPEO IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. EnIi 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). • • SPEO IDENTIFICATION CODE PAG 207 OF 338 ENI S.p.A. Eni 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 1/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. • • SPEO1111* IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. Enn E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of `Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. 0 • PEnIIs srEo IDENTIFICATION CODE PAG 209 0l 338 ENI S.p.A. 11 E&P Division REVISION STAP-P-1-M-6140 0 1 fligit LEAK-OFF TEST REPORT Report N° Date: WELL NAME: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud Type: FWGELS Rig type: J.UPs Hole Ci amete r(in): 12114 Weight(KgA): 1.3 R.K.B.eleLaton(m): 26 Last Csg.Shoe(m): 797 Marsh Uscosiry(sec/Qt): 44 Water Depth(m): 24 Csg.diameter(in): 13'3/8 P.V.(cps): 19 Pumps: 12-P-160 Grade: .155 Y.P.Qb/100 IF): 5 Oners(in): 6.5 Weight(1bIt): 61 Gels)b/100 t`): 2/8 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(coal min): 10.6 Utholog y Shale Expected DAN 1.68 Kg/cm2/10 rn Time Volume Pressure Time Volume Pressure Time Vdume Pressure (min) (bbl) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 9,5 2 480 3 0.75 200 10 2 470 4 1 D 0 300 10.5 2 463 5 125 400 11 2 455 6 150 500 11.5 2 450 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 low rate of(b bl): Volume pumped(bbl): bblume returned(bbl): (ps) 1000 900 800 stop pump rP 700 e 600 • shut in curve S 500S —i_��--a U 400 r 8 minutes E 300 200 100 0 . • 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbt) 11 Time mins RESULTS: ress.5 a+Press.Lo.)xl OlDepth=[(1.3 x 797 110)+(430 x 0.07)1 x 10 1797=1.68(Kg/cm2i10 m) Note: I Company Representatise Figure 15-1 - Leak-Off Test Report • 0 | // _ °B ■o§ r § 6D . 0' m § 0 1 • q & §' : [ § § ;.: . .o) .oj.1 : 0: : 0. iii9' ' Luz 0 §o! 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E n LO u_ cc, L a� &,...a o. � ) .�, , , r_ ILI, , ON. �' �''''� Ili iIIV 4 Ill tat\ o3 r tip' 0 J 0 Cvilliiiirlore it to., .... 'Alb .1) > . > 'VIIIII d Ca cn v ;;it 2 °�' ,- > a ` J '�� r = R R = r W � � � � o �_ G V Q C� f4 = Rf N ct Q — u 2 in 2 F 0 �= E ' er- uo (141 - - W io F. - m e is W Z OC Z0 •Gi r V OD a- z= H c �+ r A A r J w Q M 1 = M N M � Q 2 E �w r 6 16/ _ • • REV DATE BY CK APP DESCRIP11ON REV DATE BY CK APP DESCRIPTION 0 10/01/10 9:4S CC CC H ;c Draw r'S VICINITY MAP SCALE: 1" 2 V',es z N -- __ 4.Y ...„..„. , , _, .,, _ _ _.. _ ,„ t I ,, z:'... 1 J x ,4 19 2r. 51i >3, � THIS ......,;11..." 3a ' 25o F SURVEY 3O 29 2B 2i WW A.S.P. NAD83, Z4. 55. X 3I ,3. �`F., T14N T14N T13N T13N ,. 2 1 ounroK Own PAOit, ODDOKK 3 2 1 5 S.. . ,„ �s-3R 1P 11�, i' ' ? a 1 111 ,S x {, I, N. t N Y 'o% T v ' r --! .. .'':"+ f' s J SrAgN ll11 16 1 a � t 4 1,. --•\ l 3 DS-3Q,. t�t-.m � PAD r as DS‘, SFr ��- �- La: 21 ',.,>,,2 23 }r+ J n I((vs) �� t Y” {t Mine Si C tY , x° c '" �mmd. '"'t.+t.'"' s 0 if `t OS-3M 1 { ` tour ieo �IIJa B7 Is sc w ► man i` :r ' a ` w dP __ Ksi sm le • .1' �?— `' �1 #rt` t �A1t _ _R.-pD DRAWING NOTES; 1. GRID COORDINATES SHOWN ARE ALAKA STATE PLANE, ZONE 4, NAD83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD83. 3. BASIS OF LOCATION DERIVED FROM GPS STATIC OBS. PROCESSED INTO OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TOWNSHIP 14 NORTH, RANGE 9 EAST. UMIAT MERIDIAN. 5. ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. ALL SECTIONS SHOWN AND/OR REFERENCED IN THIS DRAWING ARE 'PROTRACTED SECTIONS'. 7. REFERENCE LOUNSBURY DOCUMENT E-087 FOR COORDINATE VALUES IN NAD27: SURVEYOR'S CERTIFICATE 0 '�• 49th i .ii SURVEYOR'S i#, • I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND • ' Y ' 0 LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF '%. :E :..-:, L.1,.../ ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ♦C� . FRANCIS JJ, CORNING ; i DONE BY ME OR UNDER MY DIRECT SUPERVISION AND •40‘-'0,,,,`•., Ls->obes •'r► THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT F .r AS OF OCTOBER 01, 2010 .j '� .kU/+ Ir I: "`+ + +4 ,,��SSI N 0 r6`#mss.. IF*1 el&Arroc SPY ISLAND DRILL SITE s '� WELL CONDUCTORS • , ' AS—BUILT LOCATIONS All[I ,t •1/ CAD FILE'EN13543D9 Ul S -perating DATE1DRAWING NO; Ent-3543—d9 PART: RE tOF 3 0 0 • REV, DATE BY CK APP DESCRIPTION REV DATE BY , CK APP DESCRIPTION 0 10/01/0 5. S CC CC -i•,ic, Drcw • g N , i ().‘\\r--.. c2 Pow' \Y 49 (1° 5cc 1B A Sec 1 t, _...._ Ser. 20 .... to A S P NAD83, 24. -.1 000'0°C)ul -- -Cr I; 00000° 4. IQ "" ••••• -'") S '',,,- N LP oCy3000 . -"*. l' CA tda (LI L° -A cr, to N teD CD --I 0000C° N 0 OD DETAIL A. SCALE: 1"-..80' SANDBAG 10E• voul-Otil GRAv0- i ! c vt s 4.1470.9:11-46"1 610101.;;.,4. i'aT''*4°'-. 2 DETAIL A CPC' w \''' Ik. . .I SPY ISLAND DRILL SITE (SID) rAnki V' op,vEt. -•Li) SCALE DE ANDBAG LEGEND 200 (,) 100 200 vii:07 4.3roov 0 = WELL CONDUCTOR AS-BUILT THIS SURVEY illUAL-1111 ____11, 1 Voit SPY ISLAND DRILL SITE 4. WELL CONDUCTORS a ,V • AS—BUILT LOCATIONS CAD FILE EN 354309 US peraitong °Alt. DRAWING NO: PART: REV: 10/01/2010 Eni-3543—d9 2 OF 3 0 �� 'REV DATE BY , CK APP DESCRIPTION .ncv DATE el' . CK APP _ DESCRIPTION 0 0/0`/O ]`"S CC CC ni1ic� D/c�'n� ' Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian ' Well No. Alaska State Plane, NAD83 GRID . NAD83Geo§mphic Section Line Offset Pad "yi 'X' Latitude (N) Longitude (W) F.N.L F.El Elev. (US ft.) (US ft,) _ 1 6053433.20 1651769.82 7033127.209' 149054'24.766" 797 _ 1171 12.4 2 6063421.65 . 1GS1761.D770°33'27,194"_ �33'%7.19A" 14954'36.000' 798 1179 12,4 3 6053420.07 1651754.10 70~33'37.I79^ 149^54'25.229" 800 1186 12.4 4 6063418.56 1651746.17 70033'27.164" 149^54'26.463' 801 1194 12.4 5 6053417.03 1651738.44 70^33'27.149" 149^54'25.692" 803 I202 12.4 6 , 6053415.54 1651730.54 7O^]3'27.134" 149°54'25.925" &04 1210 12.4 . 7 6053412.44 1651714.77 70033'27.104'' 149^54'26.391" 807 1226 12.4 8 6053410.91 165I706.96 70^]]'27.089" 149^54'26.622" 809 1234 12.4 ' 9 6053409.39 1651699.11 70°33'27.074" 149"54'26.853^ 810 1241 12.4 10 6053407.94 1651691.31 70033'27.060' 149^54'27.084" 812 1249 12.4 11 8053406.32 1651683.39 , 70°33'27.044" 149054'27.318" 813 1257 12.4 12 6053404.80 1651675.51 78^33'27.0I9" 149^54'I7.551" 816 1265 12.4 70033'26.986"l3 6053400.38 I65I652.80 7U^3]'J6�9D6149054'I8.221^ 819I288 12.4 14 6053398.83 1651644.95 70033136.971^ 149054128.453" 821 ' 1296 12.4 15 6053397.31 1651637.12 70033126.956" 149°54'28.685" .. Q2% 1304 12.4 16 6053395.82 1661629.26 70~33'26.942" 149^54'I8.917° 824 1311 12.4 17 6053394.32 1651621.47 70033'26.927" 149054129147" 825 , 1319 12.4 18 6053392J8 , 1651613.58 70°33'J6.912" 149^E4'29.380" 827 1327 12.4 19 6053389.63 1651597.90 70°33^26.081' 149054129.843" 830 1343 12.4 20 6053388.17 1651590.00 70033'26.867" 149r54'30.076' 831 1351 12.4 21 6053386.60 1651582.34 70033126.862" 149~54'30.306" 833 1358 12.422 6053385.19 , 1651574.35 70033136.8381' 149054130.538" ' 34 1366 . 12.4 23 6053383.64 1652566.41 70033120.823' 149054130.778" 836 1374 12.4 24 6053382.13 1651558.61 70~33'26.808" 149~54'31.003" 837 1382 , 12.4 25 6053377.65 1651535.94 70^33'26.764" l49^54'31.673" 842 1405 12.4 26 6053376.14 1651628.13 ' 70,33'26.750" 149054131.904" 843 1413 12.4 27 6053374.53 1651520.23 70~33'26.734" 149~54'32.137" 845 1421 12.4 28 6053373.11 1651512.46 70~33'26.728" 149054`32.366" 846 1428 12.4 29 6053371.56 165150449 70033126.705" 148054132.6021 848 1436 12.4 30 6063370.06 , 1651496.66 70033'26.690 149054132.833" 849 , 1444 12.4 31 6053367.05 1651480.97 70^33'26.66l" 149054'33.296" 852 1460 12.4 32 6053365.47 1651473.16 70~33'26.646" 149064133.527" 854 1468 12.4 33 6053363.93 1651465.32 70033126.6311 149^S4'33.762" 855 1476 13.4 34 6053362.44 1651457.37 70033'26.616" 149054133.993" 857 1483 12.4 35 6053360.91 1651449.52 70^33'26.601" I49^54'34.225" 858 1491 12.4 36 6053359.33 _ 1651441.62 70°33'26.586" 149^S4'34.459" 860 1499 12.4 37 , 605]]56.19 1651425.30 70^33'26.555" 149^64'34.94I^ 863 1516 !.4 38 6053364.74 165141732 70033136.541" 149054135.1771 864 1524 12.4 , !if* 00 8.4go cf ipI\ t SPY ISLAND DRILL SITE WELL CONDUCTORS * AS-BUILT LOCATIONS @nA ° CAD FILE"[N1354309 �� (�7��D�� wR DRAWING N� p�� `~^~ ~= r'`~^~~~^''"�� ,mt�/xmo _ Eni-3543--d9 3oF 3 O CrLo es o O 01 0 00 ,0 r O > • o C = W Ir v 5 avvvvvvv, vvvvv, vvvvvvvv . . . .. . • Y 0 t0 0) N N N N N N N N N N N N N N N N N N N N N N N N N N N N Q Z 0 NI d Lt, N N ei '-I N--I N--I N ."I e-I a-1 N e-I e-I a-1 ei e-I '-I '-I N--1 N--I •a-I N-I '-I '-I e-I I-I r-I .-I N 0J W . 0 en .i 01 t0 et N O O Cr .-i 01 N In CO l0 Ct ei 01 N M e-I CO l0 N N V) M ei 00 C U' N N 00 01 O N N M et N V1 10 00 Ol O c-1 .1 N 1n 1n 10 m 00 O e-I N N O U an N e-1 .-i e-I N N N N N N N N N N M m M M M M M M M M et et N ei -i 0 ti O e-I e-I .1 ei ci e--I e-I e--I e-1 N N N ei e-I N e-I ei ei c-I e•-I a-I e--I ri a-I c-I ei ri e-1 a C J C O J ^ 40 • .t NOL-101Tr 011111.0 u Z 01 0C1 O o O O O O N c-1 .1 .-1 c-I N N N N N M M M M NML1101L-INTr LA es 0 m m N Cr Cr In lL,_. 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III" m 4 iIlliif1i11i1fi1i66iillliiii; iiuu Egl /„ E I W E ! 6 g pi 6.ns.g. E Ws P P P 1B gg p" <S 7 § a IIIIgg. iFif i 1 ti cd Mml. � aR35 c We Uw O�Illui�� - % 411§ o g11c >♦ C LL`.84 W P ■•W $z U d O O(>N F p000ccc 1...ki �V >> WM . J� a;;; o) W u9ry .O . (A - LJ 0000coc J C 0 0 6' Q W 2222222'2i - . E L. sw El i �� 1 i fl- .9-.6LS g N .51 y Pio lig 4 W om' -- - �'n {�w li F c •F�.F ....... - .o-a06----r-- -- 4 mocgarrraxi mrx=_ _`mss..- -- ----. <------r-------.o-,00e &N, ..: . 1 z 1 //t/ .- 1 — i oo� 11> \��\\� 888w I 888 1 _ \�\\ 80000ao El 1 1 ,A, 1 2 - T--, q Te woo '>*.\/\/, II. VnItItItAtA a-.me-A-- -- { - �,t moi- - 1_, _1 .9-.009Mu uuuu >� 3 �1:1l r-- .i i ,_,-I , 1 5 igngggg ili 1 P-,2 h , ItirAt • . ..., , i 11 k r 6= o I:' il I• I •�iII1' ' “��1� _ k • itis: S$��0�Q�A k p 4,008_y___§ l_ _ _ - :.I _1_ _I_ .._IT R .0-.m) , � � N AI I Alii►—--- '0* ` L os \ i 8 g N n Y2. I ,: R€ J . 1 imi IO �,mz .ill- 7- ---r 8 t --+- i - �. 4. . n' 1 2 �--- ' H 4IE 1..f 8 [1[y �l_ 113�1� '_��;b�� a waw MI \\\ '•I -.4` -_ 1I�Ip Q.ILaMlA3JI/A�001• st i 3a1 .g F !— i .5 I> 1001&I r' "�� W �° I 4 `L___,/_14 1 fg 3 - -.=. m _ f 2e= I9,L9 = A A. Wy �I= g z" I 0i ► . Burst Design(13 3.2"Surface Casing) Collapse Design(13 3n3'Surface Casing) Axial Design(13 3!8"Surface Casing) 1 800- - . Boo-- 800 I _ _ f 1 - 1600- _i i -1400 1800 I - O - - u i i I 23 13 _. _ 2400-• _,_ __,_ 2400 ._ L1 2400--- l 1 • _ i al on 1 on 1 r g... F _ s ,y • 2 ! 2 _ I • 3200-0-- f._---_._- 3200-» 1 3200 i ) it 1 1 - Design Load Line _ - Destgi Load Line ! r - Deggn Load Lino E 4000 - 4000- _ __ q . I 4000 I Pipe Rating - Pie Rating 1 _ ;- Pipe Rating I I r r I r 1 1 r I I I i I I 'i 1111111111111111111 I r I I I I 1 r ' I I I I 1 I I r 1 50 0 3000 4500 0 750 1500 2250 700000 1050000 1 4000 00 Burst Rating(psi) Collapse Rating(psi) Axial Force Obt) 1d1111mum Safety Factors (13 idi- Surface Cs;r;) . . . MO(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Burst Load Data (13 318' Surtaoe Casing) 0 13 3/8-. 6$000 ppt. 1.40 N/A 502 912 + 100 00 C4 530 A4 530 A4 12 502 812 + 10000 C4 5.31 Al 5.30 A4 Drilling Load- Pressure Test 20 502 812 + 100 00 C4 5.31 Al 5.31 A4 Test Pressure: 0.00 psi 200 534 812 23.18 C4 541 144 5.38 A4 Mud Weight: 9A0 ppg 200 524 912 23.18 C4 4.26 A4 424 A4 Assigned Ext. Pressure: Fluid Gradients (wt Pore Pressure) 416 5.78 812 11.16 C4 3.35 A4 3.33 A4 500 548 B12 1100 C4 3.40 A4 334 A4 Ofilling Load. Fracture i. Shoe w! in BHP at Surface 700 648 912 0-10 C2 3A4 Al 339 At Surface Pressure (113 ` BHP) 587.59 psi 400 705 812 7.12 C2 3.40 1114 342 A4 Shoe Depth. MD: 31770 ustt 1000 736 812 6.44 C2 351 A4 3.44 44 Fracture Pressure at Shoe: 1598.26 psi 1100 769 812 5.89 C2 334 At 3.46 Al Fracture Margin of Error 0.00 ppg 1200 804 812 5A5 C2 3.57 04 3.48 AA 1300 841 812 50$ C2 3.60 A4 351 A4 Drilling Load: Green Cement Pressure Test . • 1 400 8 T9 912 4.77 C2 3.63 84 3.53 44 Test Pressure: 1000 00 psi • 1479 9-10 811 4.56 C2 3.64 84 3.55 A4 LW Weight at Shoe: 940 ppg 1700 9 17 811 407 C2 3:74 A4 352 A4 TOC. MD: 200 ush • 2000 9.27 811 3.56 C2 3.86 Al 3.71 14 Lead Slurry Density: 15.80 ppg . ' 2200 9-33 $11 329 C2 324 Al 3.77 A4 Displacement Fluid Density: 9A0 ppg 2300 936 811 3 1$ C2 3.99 At 381 A4 Float Collar Depth. MD. 3177.0 usft 2400 9.39 Blt 3.07 C2 403 Al 3.84 Al. 2500 9.42 811 2.98 C2 406 A4 386 A4 External Pressure: Riad Gradients (w! Pore Pressure) • ' 2600 944 811 284 C2 409 A4 388 A4 TOC, h0: 20.0 ustt 2700 9A7 811 282 C2 4.13 04 3.91 A4 Prior Shoe. 440: 0.0 ush 2$00 94 811 2.75 C2 4.17 A4 394 A4 Mud Weight Above TOC: 9.40 ppg 3000 954 $11 263 C2 425 Al 401 A4 Fluid Gradient Below TOC: 8.60 ppg 3100 9.56 811 2.57 C2 4.30 Al 4.04 14 Pore Pressure In Open Hole- Yes . 317$ 958 811 253 C2 4.33 Al 407 A4 3177 958 Ott 243 C2 4.33 At 4.07 44 •. 8 1 1 Fracture a Store w! 1J3 81-11. at Surface Cobpse Load Data (13 3 8 Surface Casing) . 912 Green Cement Pressure Test(Burst) Drilling Load: Cementing C2 Cementing hod Weigh at Shoe- 0.40 ppg C4 Lost Returns with Mid Drop TOC. bb: 20.0 usft . A4 Owerput Force Lead SlurryDenst!: 15.80 ppg Displacement Fluid Density: 9 40 ppg Float Collar Depth. 1.10: 3177.0 trsft ' assigned External Pressure: Cementing (Ext) Drilling Load: Lost Returns with Mud Drop Lost Returns Depth. MO: 6058.0 ustt Pore Pressure st Lost Returns Depth. 1702.79 psi Pore Pressure Gradient at Lost Returns Depth: 8.43 ppg mud ilterght: 9.40 ppg . . . Mad Drop Levet. MO 415.6 ustt . . . . - Assigned External Pressure. Fluid Gradients (o/ Pare Pressure) External Pressure. Fluid Gradients (us Pore Pressure) TOC. MD: 20.0 usft Prior Shoe. MO- 0 0 usft Fluid Gradient Above TOC. 9.40 ppg Fluid Gradient Below TOC: 9.40 ppg Pore Pressure In Open Hole 8e*ow TOC' No - . . . . . . . ' . ' . . . . ' - ' . _ Arial Load Data (13 3,8 Surface Casing) . Running in Hole - Arg. Speed: 01 Ills 0 • • 0100 Design(9 543"Intermo_d+ate Casing) Collapse Design(9 5+3'•Intermediate Casing) .4..131 Design(9 518"Intermediate Casing) $00- $00 800 1 ILon ' H 1600 _ 1 L 1600 k H 1800 - . Q. r ni 110 F 0 1 2400 _. ._ _. .. N 2400 Tl. LJ 2400 . . .m._. 3 Il0 <n EBB zn asv - 2 I 1 y' . k 3200 3200 t 7200 . ( 1 . . - Design►Load Line agn Load lice Deogn Load'Line . 4000 - Pipe Rating 4000 pe Raiing 4000 Pipe Rating T 1500 3000 4500 6000 0 1000 2000 3000 450000 600000 750000 900000 Burst Rating(psi) Collapse Rating(psi) Axial Force Qty) - Mremum Safety Factors (9 518" agestnediate Casing) ' 143(rn) OD1Weight/Grade Conection 9urst(A) Collapse(A) Axial(A) Triaxial(A) ' Burst Load Data (9 518'• Intermediate Casing) • 0 9 518-. 40000 pet. 140 N/A 5.15 912 • 100.00 C2 3.18 40 3.18 A4 ' 1 2 5.75 912 a 100.00 C4 3.18 A4 3J$A4 Drilling Load: Pressure Test 200 575 912 30.86 C4 2.89 A4 288 At - mud uueignt: 9.90 pp9 419 5.75 912 14,70 C4 2,57 A4 2.56 A4 Assigned Ext Pressure: Fluid Gradients (w1 Pore Pressure) 500 5.75 012 14.48 C4 2.60 Al 2.58 A4 700 5.75 912 1399 C4 2.61 A4 2.58 AA Drilling Load: Fracture l Shoe wf I13 BHP at Surface 900 575 912 1355 C4 2.62 As 2.59 A4 Surface Pressure (113 • BHP): 592.03 psi • . 1000 575 912 1335 C4 2.63 44 2.59 44 Shoe Depth, IAO: 60580 ustt . 1100 5.75 BI2 13.16 C4 2.64 A4 2.60 A4 Fracture Pressure at Shoe: 2623 28 psi . 1200 5.75 912 129$ C4 2.06 A4 2.61 A4 Fracture Margin of Error 0 0 Ppg . 1300 5.75 912 12.81 C4 2.67 A4 2.61 Al • 1 40 0 575 912 12.86 C4 268 A4 2.62 14 Drilling Load: Green Cement Pressure Test • 1 70 0 5.74 812 12.24 C4 2.72 A4 266 A4 Test Pressure: 1000.00 psi • • 2000 574 912 1186 C4 2.78 A4 2.70 Al Mid )31.419 ht 3t Shoe: 940 ppg - 2200 574 912 1182 C4 2.82 44 2.73 Art TOC. MO: 4460.0 sift 2300 5.74 912 11.51 C4 2.84 Al 2-74 A4 Lead Slums Density: 15.90 ppg 2400 574 912 1140 C4 286 At 2.76 AR Displacement Fluid Density: 9.40 ppg 2500 5.74 B12 11.30 C4 2.88 44 2.78 A4 Float Collar Depth, MD; 6059.0 usft 2600 5.74 912 11 21 C4 2,90 44 2.79 A4 2700 5.74 912 11.12 C4 2.92 A4 2.81 A4 External Pressure: Flied Gradients (wf Pure Pressure) 2800 574 812 11 D4 C4 2.94 AA 283 A4 TOC- MD: 4460.0 usft 3000 5 74 812 10.90 C4 2.09 A4 286 Al Prior Shoe, MD: 3177.0 usft 3100 574 912 10.82 C4 3.01 A4 2.88 A4 Mid 'Weight Above TOC: 0.40 pp9 ' 3177 5.74 912 10.78 C4 3.02 A4 2.89 14 Fluid Gradient Below TOC: 8.60 ppg 3200 5.74 912 10.74 C4 303 Al 2.90 A4 Pore Pressure In Open Rote: Yes 3244 5 74 012 1071 C4 304 A4 2.9044 3300 574 B12 10.66 C4 3.05 A4 2.91 A4 3400 5 74 912 10.58 C4 3,07 A4 2.03 44 Collapse Load Data (9 573 Intermediate Casing) . 3800 5.74 912 10.41 C4 3.11 14 2.95 A4 . 3800 574 B12 1022 C4 3.14 Al 2.98 44 Drilling Load: Cementing 4400 573 912 9.60 C4 3.29 Al 3.09 A4 IAA weight at Shoe: 9 40 ppg • 4450 5.73 912 9.65 C4 3.30 A4 3.10 Al TOC. MD. 4460.0 usft • 4800 543 912 9.40 C4 3.35 A4 3.13 Al Lead Slurry Density' 15 80 ppg • 4700 606 912 942 C4 3.38 A4 3.15 A4 Displacement Fluid Density 9.40 ppg • 4800 6.19 812 9.35 C4 3.41 44 3.18 Al Float Collar Depth, MD• 60580 usft - 4900 6.33 912 9.29 C4 3.44 14 3.20 144 Assigned External Pressure: Cementing (Eft) ' 50 00 646 012 9 21 C4 3.47 44 3.22 AA ' 5100 659 912 9.16 C4 3.51 Al 3.25 A4 Drilling Load Lost Returns with Mid Drop 5200 672 912 9.10 C4 354 A4 3.28 A4 lost Returns Depth. FAD 7623.1 usft 5264 6.80 911 907 C4 3.57 44 3.30 A4 Pore Pressure at Lost Returns Depth. 1776.09 psi 5300 079 011 90.3 C4 358 A4 3.31 Ari Pore Pressure Gradient at Lost Returns Depth 3.43 ppg 5600 672 911 8.52 C2 3 71 Al 3.41 A4 Mud Weight. 9.40 pp 5700 670 911 821 C2 3.75 Al 3.44 44 Mid Drop Leuel, MD 418-8 usft 5800 688 911 796 C2 378 Al 3.47 44 Assi.ned External Pressure Fluid Gradients (w! Pore Pressure) 5900 667 @II 778 C2 382 A4 3.49 A4 . 8000 866 Bit 7-66 C2 386 At 3.52 A4 External Pressure- Fluid Gradients (w1 Pore Pressure) 6057 666 B11 7-61 C2 3.88 A4 3.54 44 TOG. MO. 4460.0 usft • 8058 8.66 Bll 7.61 C2 3.88 A4 3.54 Art Prior Shoe, 6A0. 3177.0 usft Shoe eF I!3 9HP at Surtace Fluid Gradient Above TOG: 9.40 ppg . 811 Fracture B12 Green Cement Pressure Test(Burst) PoreFInid Gradient Below TOC: n40 ppg Pressure In Open Hole Below TOC: No • • C2 Cementing C4 Lost Returns ,Ah Med Drop Al Orerpu9 Force - Axial Load Data (9 518'• Intermediate Casing) Running in Hole - Aug. Speed: 0.7 ftfs Ouerpull Force: 150000 Ibf r 0 0 Client : Eni Petroleum Well : SI07-SE4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Section 5: WELLCLEAN II Simulator Fluids Concentrations Risk Mud on the Wall B a 6J I -0 6J--7... ' r— -0 500.- -500 500: _500 1400— —1000 1 000— —1000 - _ _ - " INV- -1500 ' 1500- -1500 `- i i i S - - - - a 2000- -2000 a a 2006- -2000 8 / 7504— —2500 2500— —2500 3000- -30.00 3000- -3000 1 I 4 3 i 4 3 r TO O 0 '0 o 0 3 'o a a o 3 2 2 1111.11 Mud 5-16-14 0 High ® Low ION Fresh Water I I Medium : None 12.5ppg DeepCRETE Surface Tail I I Surface Lead 1 1 MUDPUSH Il % ft 0 50 100 0 50 100 0_ < ) — -�I .1 l -- Std Betw.Cent. Mud Contaminatan -Cement Coverage -Uncontaminated Slurry '40 • Wilt 111711111 0 0 N J 0 0 0 v— Well Cement Coverage Uncontaminated Slurry Page 14 ENI SI07-SE4 CemCADE vl Initial 07-08-14.cfw;07-00-2014; LoadCase 13 3/tin Surface Casing;Version wcs-cem472_05 • 0 Client : Eni Petroleum Well : S107-SE4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Section 4: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :3157.0 ft Casing Shoe :3177.0 ft NB of Cent. Used :15 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent.I Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 137.0 3 1/1 NW-ST-13 3/8-8-ST-IIIA W13F 94.0 117.0 2697.0 0 0/0 0.0 2684.5 3177.0 12 1/1 NW-ST-13 3/8-8-ST-IIIA W13F 74.2 3177.0 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- W13F 13 3/8 18.386 14.685 No Hannover 16.000 984.66 3007.94 IIIA (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications (2)—Centralizer placement data is based on current ENI field practices ft % deg 0 50 100 0 25 50 75 - O— I Between Cent — Deviation r At Cent. O O— N O O O V— Well Pipe Standoff Deviation Page 13 ENISI07-SE4CemCADEvi Initial 07-08-14.cfw;07-08-2014; LoadCase133/8inSurface Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : SI07-SE4 Schi bergcr String : 133/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Simulated Slurry Temperaturesup for UCA to 24hours after Placement I o Depth= 3177 ft co API BHCT --- 3eoth.Profile ru.ular ' ids r11111 -1 1 11111111 1111111i- I-- ---. Ill .1111111111111■ CD ! A ■ �_ ■■■■■ - imilmil oco ili ci II 1 III al1 I_ 0 0 200 400 600 800 1000 1200 1400 1600 1800 Time(min) Page 12 ENI SI07-SE4 CemCADE v1 Initial 07-08-14.cfw;07-08-2014; LoadCase 13 3/Bin Surface Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : SI07-SE4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Simulated Fluid Friction Pressure Hierarchy Annulus ID : 9.625 in-OD: 16.000 in -Mud 5-16-14 MUDPUSHII Surface Lead 12.5ppg DeepCRETE Surface Tail N N O Q to � O U N_ 1 2 3 4 5 6 7 8 9 10 11 Flow Rate (bbl/min) Page 11 ENI SI07-SE4 CemCADE v1 Initial 07-08-14.cfw;D7-08-2014; LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 • • Client : Eel Petroleum Well : S107-SE4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Simulated Slurry Temperatures during Placement in _o e Last Sack Temp. -- A PI BHCT . f First Sack Temp. -__.m. _ w_ 0i oo Ci In ' _-�___�. . __ — ._m m.,�w ......1r:�_ 1_.__ _ co o '-Ln- ,_ o a^r" i_ X O _ _m_. o oti 1.. T.. _N c 13 CL c• -4- _ w. _ ; 00 CN -1 Cri CO -f-- 1 (D 1_,y5 .,:. _.....+___ 01 � i o CD l r r r r r r i r iNI 0 30 60 90 120 150 180 210 240 270 Time (min) Page 10 ENI S107-SE4 CemCADE v1 Initial 07-08-14.cfw;07-08-2014; LoadCase 13 3/Bin Surface Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : SI07-SE4 Schlkohrger String : 133/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 133/8in Surface Casing Simulated Surface Pressures during Placement i = ' : Calc.Pump Press a.i! J___. _ 1 ii)eL c� ■■ ill moo, T-- 1-� -- f 1111111111111111111= ! ch_ i W ^Mall MIMI ' a -1-4-j--14-I--.1-.1 '-4-14-4 4-4-1-4-1-_-3.1 _ _ _.; '� U)O . , I 1 r . r r . 1 0 25 50 75 100 125 150 175 200 225 250 Time (min) _ Fluids at 3177 ft NI -Acquired Q In - Q In C E c) 11111=011. r: : N _ O 1,. aVf 1—..-,--1--,-- 0 25 50 75 100 125 150 175 200 225 250 Time (min) Page 9 ENI SI07-SE4 CemCADE v1 Initial O7-08-14.cfw;O7-O8-2014; LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 • 0 Client : Eni Petroleum Well : S107-SE4 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Simulated ECDs at Previous shoe during Placement a, Depth = 160 ft rn Frac (_ �... Hydrostatic , . ' : ; , ; ; . . f ' - Dynamic "t aiiii10111 °' ..i.. 11111111111111111111 . . VIII , Ill . i 111111111111 ■ . ./i. _ $� _! . M.. .. ■t. ..l■. _ cp- 1110111111111111111111111111110101111111. ■ ' -- : .■.■■ iI■. . .■. ii illi .l� l.:l _ , ' I �a PPn A... .... NI INN _-ta N _ INS 'I .4 . r _ -}> �}tpt{ r V I I ... M MINN e .N. N r ■l. } ! b � r r i i 1 iL l i l t i I r r r r 1 0 25 50 75 100 125 150 175 200 225 250 Time (min) Page 8 ENI SI07-SE4 CemCAUE v1 Initial 07-08-14.cfw;07-08-2014; LoaciCase 13 318in Surface Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : SI07-SE4 Schlemderger String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Simulated ECDs at Casing Shoe during Placement I o Depth = 3177 ft ON. - Frac 1 i , - Pore I I 1 I Hydrostatic 1 I I I 1111111 00 Dynamic € t _. i E 1 111 11111 0 If'' 4 i i i �� iiiiiiiOIIIIiiIIII!: .� N IIIIIIIIIIIIIIIIILIII 1.g1 II11111� 111� r1111 '`'''� •: 11111111 o = i .--- I111111111 i CNI �—, lluhIIIIIiiiiii N N. { _ ___ _ r i ■ ■ IIIII■I No Nu/ ■uu 0 , 0 0 r--� 0 25 50 75 100 125 150 175 200 225 250 Time (min) Page 7 ENI S107-SE4 CemCADE v1 Initial 07-08-14.cfw;07-08-2014; LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 • Client : Eni Petroleum Well : SI07-SE4 Schlinkrier String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in 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<30 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) Top Plug is not Bumped at calculated Volume a) Pump% shoe track volume MAX b) If Bump not seen, shut in and hold pressure 4) 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 Page 6 ENI SI07-SE4 CemCADE v1 Initial 07-08-14.cfw;07-08-2014; LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 # 0 Client : Eni Petroleum Well : SI07-SE4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 133/8in 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) - Max Shut down time is 30-minutes; if time is being approached,contact Town Engineer - 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 - Maintain returns during cement job if possible (Report any losses /gain during cement job) - Attempt to follow highlighted flow rates as close as possible and within ranges specified o Please note variance from noted Rates in Job Report Start Job: Circulate BU, Ramp up Rates Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer ahead with Rig Pumps Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 2.0 0.0 80 Line Up Cement Unit Surface Lead 5.0 570.7 114.1 570.7 80 Mix/Pump Lead Slurry(3-7 BPM) Pause 0.0 0.0 5.0 0.0 80 Swap to Mix Tail 12.5ppg 5.0 62.5 12.5 62.5 80 Mix/Pump Tail Slurry(2-7 BPM) DeepCRETE Surface Tail Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Fresh Water 5.0 10.0 2.0 10.0 80 Kick Out Plug Mud 5-16-14 7.0 413.7 59.1 413.7 80 Line up to Pump Mud Mud 5-16-14 5.0 30.0 6.0 443.7 80 Start Displacment Mud 5-16-14 2.0 10.0 5.0 453.7 80 Slow Rate Shut-In 0.0 0.0 5.0 0.0 80 Slow to Bump Plug Total 03:53 1197.0 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 5 psi at 160.0 ft Pore 7 psi at 160.0 ft Collapse 1989 psi at 3097.0 ft Burst 4745 psi at 0.0 ft Temperature Results BHCT 66 degF Simulated Max HCT 77 degF Simulated BHCT 77 degF Max HCT Depth 3177.0 ft CT at TOC 71 degF Max HCT Time 01:37:56 hr:mn:sc Static temperatures: At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 71 degF 20 degF Bottom Hole (degF) 77 degF 52 degF Page 5 ENI SI07-SE4 CemCADE v1 Initial 07-08-14.cfw;07-08-2014; LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : SI07-SE4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Section 2: fluid sequence Job Objectives: Cement Surface Casing with Returns Seen at Surface Original fluid Mud 5-16-14 9.30 lb/gal k : 7.18E-3 Ibf.s^n/ft2 n : 0.694 Ty : 13.31 lbf/100ft2 Displacement Volume 463.7 bbl Total Volume 1197.0 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:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 lbf/100ft2 Surface Lead 570.7 2677.0 0.0 10.70 k:1.44E-1 Ibf.s^n/ft2 n:0.326 Ty:1.39 lbf/100ft2 12.5ppg DeepCRETE 62.5 500.0 2677.0 12.50 k:2.06E-2 Ibf.s^n/ft2 n:0.728 Ty:19.36 lbf/100ft2 Surface Tail Fresh Water 10.0 3030.2 8.32 k:5.23E-3 Ibf.s^n/ft2 n:0.291 Ty:1.04 lbf/100ft2 Mud 5-16-14 453.7 0.0 9.30 k:7.18E-3 Ibf.s^n/ft2 n:0.694 Ty:13.31 lbf/100ft2 Static Security Checks: Frac 8 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 1989 psi at 3097.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 58 ton Check Valve Diff Press 197 psi ft (x 1000) psi - ( j 0 2 -Hycrostatfa -Frac - -Pore • 0 1 1 J ii __4 r c. O Fluid Sequence Static Well Security Page 4 ENI SI07-SE4CemCADEvi Initial 07-08-14.cfw:07-082014: LoadCase 13 3/Bin Surface Casing:Version wcs-cem472_05 • • Client : Eni Petroleum Well : Sl07-SE4 Schlimberger String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 160.0 20 169.0 18.250 Landing Collar MD : 3097.0 ft Casing/liner Shoe MD : 3177.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 3177.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 164.3 Mean OH Equivalent Diameter: 19.563 in Total OH Volume : 1121.6 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 2000.0 16.000 190.0 20.063 2677.0 16.000 190.0 20.063 3177.0 16.000 35.0 16.822 Appendix 1 - Directional Survey Data Max. Deviation Angle : 61 deg Max. DLS : 4.019 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 749.5 11.70 8.40 SV-4 Siltstone 1066.0 11.50 8.40 SV-3 Sandstone 1321.0 11.50 8.40 SV-2 Siltstone 2000.0 11.50 8.40 B/Permafrost Shale 2199.0 12.50 8.40 Ugnu Top(UG4) Shale 2709.0 12.50 8.40 UG-2 Coal Bed Sandstone Mark 3177.0 12.50 8.40 13 3/8 Casing Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2000.0 1746.8 32 0.7 2955.0 2336.4 50 1.3 3177.0 2453.7 52 1.3 3178.0 2454.3 52 1.3 Page 3 ENI SI07-SE4 CemCADE v1 Initial 07-08-14.cfw;07-08-2014; LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : S107-SE4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 3177.0 ft BHST : 52 degF Bit Size : 16 in ft (x 1000) psi < 2 Fra I -.._—_-FD'E — — — Siltstone — 111-Siltstone— �j ••.....Sandstone.'•'•'• .'.'.'.Sandstone, Well Litholog;, Formation Press Page 2 ENI SI07-SE4CemCADEv1Initial 07-08-14.cfw;07-08-2014; Loadcase 133/tin Surface Casing Version wcs-cern4l2_Q5 • • Schlumberger CemCAD E*well cementing recommendation for 13 3/8 Surface Casing Operator : Eni Petroleum Well : S107-SE4 Country : USA State : Alaska Prepared for : Lara Occhionero Location : Spy Island Proposal No. : v1 Service Point : Prudhoe Bay,AK Date Prepared : 07/08/14 Business Phone : 907.659.2434 Approved By :Stephen Lauper Date Prepared by : Peter Cahill Phone : 907.690.2748 E-Mail Address : pcahill@slb.com 34 c��\G UAiTE Disclaimer Notice: Schlumberger submits this document with the benetit of its judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or infoematon provided by others,limitations,computer models.measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.Al.proposals,recommendations,or pied lotions ere opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED.EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS TITHE 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 ENI SI07-5E4 CemCADE v1 Initial 07-08-14.cfw;07-08-2014; LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 • Client : Eni Petroleum Well : SI07-SE4 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Section 6: operator summary MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.046 bbl D182 552.278 lb 6.000 lb/bbl of base fluid D047 20.000 gal 0.200 gal/bbl of spacer D031 9536.741 lb 95.37 Ib/bbl of spacer 12.5ppg DeepCRETE Surface Tail Volume :62.5 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: 22619 lb Design Mix Water 29.2 bbl 10.0 bbl LAS Design 12.5-0.82-53 22439.885 lb Fresh water 29.230 bbl 10.001 bbl .z Z 0046 44.880 lb 0.200%BWOB 0065 56.100 lb 0.250%BWOB D167 56.100 lb 0.250%BWOB D153 22.440 lb 0.100%BWOB Surface Lead Volume : 570.7 bbl Density : 10.70 lb/gal Yield :2.44 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 358.7 bbl 10.0 bbl LAS Design ASL B439(53) 131128.703 Fresh water 358.720 bbl 10.001 bbl lb Fresh Water Volume : 10.0 bbl Density: 8.32 lb/gal Code Quantity Design Fresh water 10.000 bbl Page 15 ENI SI07-SE4CerCADEv1Initial 07-08-14.cfw;07-08-2014; LoadCase133./8inSurface Casing;Version wcs-cem472_05 0 • Client : Eni Petroleum Well : S107-SE4 SGhlumkrgur String : 13 3/8 Surface Casing District : Prudhoe Bay,AK Country : USA Loadcase : 13 3/8in Surface Casing Appendix 1 - Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 330.0 0.000 100.0 100.0 0.0 330.0 0.000 200.0 200.0 0.0 330.0 0.000 300.0 300.0 1.5 330.0 1.500 400.0 399.8 5.0 330.0 3.500 500.0 499.1 8.5 330.0 3.500 600.0 597.5 12.0 330.0 3.500 700.0 694.6 15.5 330.0 3.500 800.0 790.1 19.0 330.0 3.500 900.0 883.6 22.5 330.0 3.500 1000.0 974.8 26.0 330.0 3.500 1100.0 1063.2 29.5 330.0 3.500 1200.0 1148.7 33.0 330.0 3.500 1300.0 1230.9 36.5 330.0 3.500 1400.0 1309.4 40.0 330.0 3.500 1459.3 1354.1 42.1 330.0 3.492 1500.0 1384.3 42.3 330.0 0.516 1600.0 1458.0 42.8 330.0 0.500 1700.0 1531.1 43.3 330.0 0.500 1800.0 1603.6 43.8 330.0 0.500 1900.0 1675.5 44.3 330.0 0.500 2000.0 1746.8 44.8 330.0 0.500 2100.0 1817.4 45.3 330.0 0.500 2152.2 1854.1 45.5 330.0 0.498 2200.0 1887.4 46.2 332.5 4.001 2300.0 1955.6 47.7 337.5 3.999 2400.0 2021.7 49.5 342.3 4.001 2500.0 2085.3 51.4 346.9 4.002 2600.0 2146.2 53.5 351.2 3.997 2700.0 2204.0 55.8 355.2 4.004 2800.0 2258.5 58.2 359.0 3.997 2899.9 2309.4 60.7 2.7 3.999 2900.0 2309.4 60.7 2.7 0.000 2945.2 2331.5 60.7 2.7 0.000 3000.0 2358.9 59.5 4.8 -3.998 3100.0 2411.3 57.3 8.8 -3.999 3177.0 2453.7 55.8 12.0 -4.019 Page 16 ENI SI07-SE4CemCADEv1Initial 07-08-14.cfw;07-08-2014; LoadCase133./8inSurface Casing;Version wcs-cem472_05 • • Schlumberger CemCAD E* well cementing recommendation for 9 5/8 Intermediate Casing Operator : Eni Petroleum Well : SI07-SE4 Country : USA State : Alaska Prepared for : Lara Occhionero Location : Spy Island Proposal No. : v1 Service Point : Prudhoe Bay,AK Date Prepared : 07/08/14 Business Phone : 907.659.2434 Approved By :Stephen Lauper Date Prepared by : Peter Cahill Phone : 907.690.2748 E-Mail Address : pcahill@slb.com kS0,N n 04„ 4LIATE Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is provided in accordance with generany accepted industry practice,relying on facts or information provided by others,limitations,computer models.measurements,assumptions and inferences that are not infallible. Calculators are estimates based on provided information.At 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 ENI S107-SE4 CemCADE vt Initial 07-08-14.cfw;07-08-2014; LoadCase 9 5/8in Intermediate Casing;Version wits-cem472_05 0 I Client : Eni Petroleum Well : Sl07-SE4 SCMUMbe ge String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD :6059.0 ft BHST : 85 degF Bit Size : 12 1/4 in ft (x 1000) psi Q- 0 2 3 — — — — kr) Fra .Siltstone ----Fo•e 0 - CI Shale o �r 0 o- ::::Sandstone..-:: --- C4 •Sandstone.••::, �I '.•.••',Sandstone,'••.•. __ • • • '::::::: one. • • • i Lr. •,•,•, ,••'.',' 1 IN I,_._ t 0 o- Well Lithology Formation Press. Page 2 ENI S107-SE4 CemCADE v1 Initial 07-08-14.cfw;07-08-2014; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : SI07-SE4 Schlimberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 3177.0 13 3/8 68.0 12.415 Landing Collar MD : 5978.0 ft Casing/liner Shoe MD : 6058.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 6058.0 9 5/8 40.0 40.0 8.835 L-80 3090 5750 BTC Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 13.370 in Total OH Volume : 500.5 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 6058.0 12.250 50.0 13.371 6059.0 12.250 0.0 12.250 Appendix 1 - Directional Survey Data Max. Deviation Angle : 84 deg Max. DLS : 4.006 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 749.5 11.70 8.40 SV-4 Siltstone 1066.0 11.50 8.40 SV-3 Sandstone 1321.0 11.50 8.40 SV-2 Siltstone 2000.0 11.50 8.40 B/Permafrost Shale 2199.0 12.50 8.40 Ugnu Top(UG4) Shale 2709.0 12.50 8.40 UG-2 Coal Bed Mark Sandstone 2767.0 12.50 8.40 13 3/8 Casing Sandstone 3413.0 12.50 8.40 Lower Ugnu Sandstone 4272.0 12.50 8.40 TOC Sandstone 5272.0 12.50 8.40 N Top Sandstone 6059.0 12.50 8.40 9 5/8 Casing TD Sandstone Geothermal Temperature Profile _ MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2054.0 1785.0 32 0.7 3177.0 2453.7 50 1.2 6059.0 4024.8 85 1.6 Page 3 ENI S107-SE4 CemCADE v1 Initial 07-08-14.cfw;07-08-2014; LoadCase 9 5/Bin Intermediate Casing;Version wcs-cem472_05 • I Client : Eni Petroleum Well : S107-SE4 Schlumbcrgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 4,272'(1,000'above the"N" Sand Top) Original fluid Mud 9.50 lb/gal k: 5.97E-3 Ibf.s^n/ft2 n : 0.616 TY: 8.86 lbf/100ft2 Displacement Volume 453.3 bbl Total Volume 708.8 bbl TOC 4272.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 1235.3 3036.7 10.50 k:5.23E-2 Ibf.s^n/ft2 n:0.324 Ty:12.92 lbf/100ft2 12.5ppg DeepCRETE 155.5 1786.0 4272.0 12.50 k:4.89E-3 Ibf.s^n/ft2 n:0.960 Ty:15.95 lbf/100ft2 Fresh Water 10.0 5846.1 8.32 viscosity:5.375 cP Mud 443.3 0.0 9.50 k:5.97E-3 lbf.s^n/ft2 n:0.616 TY:8.86Ibf/100ft2 Static Security Checks: Frac 378 psi at 3177.0 ft Pore 144 psi at 3177.0 ft Collapse 2753 psi at 5978.0 ft Burst 5750 psi at 0.0 ft Csg.Pump out 63 ton Check Valve Diff Press 174 psi ft (x 1000)psi 0 3 Hycrostatic -Frac -Pore �I cv - L.... Fluid Sequence Static Well Security Page 4 ENI 8107-SE4 CemCADE vi initial 07-08-14.cfw;07-08-2014; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : SI07-SE4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in 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) - Max Shut down time is 30-minutes; if time is being approached, contact Town Engineer - 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 - Maintain returns during cement job if possible (Report any losses /gain during cement job) - Attempt to follow highlighted flow rates as close as possible and within ranges specified o Please note variance from noted Rates in Job Report Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer ahead with Rig Pumps Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 2.0 0.0 80 Line Up Cement Unit 12.5ppg 5.0 155.5 31.1 155.5 80 Mix/Pump Lead Slurry(3-7 BPM) DeepCRETE Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Fresh Water 5.0 10.0 2.0 10.0 80 Kick Out Plug Pause 0.0 0.0 5.0 0.0 80 Line up to Pump Mud Mud 7.0 403.3 57.6 403.3 80 Start Displacment Mud 5.0 30.0 6.0 433.3 80 Slow Displacment Mud 2.0 10.0 5.0 443.3 80 Slow Rate to Bump Plug Shut-In 0.0 0.0 5.0 0.0 80 Static period after Placement Total 02:16 708.8 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 291 psi at 6059.0 ft Pore 140 psi at 3177.0 ft Collapse 2749 psi at 5978.0 ft Burst 5386 psi at 0.0 ft Temperature Results BHCT 83 degF Simulated Max HCT 72 degF Simulated BHCT 71 degF Max HCT Depth 0.0 ft CT at TOC 71 degF Max HCT Time 02:05:42 hr:mn:sc Static temperatures: At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 71 degF 66 degF Bottom Hole (degF) 71 degF 85 degF Page 5 ENI SI07-SE4 CemCADE v1 Initial 07-08•14.dw;07-08-2014; LoadCase 9 5/8in Intermediate Casing;Version wcs-cern472_05 • • Client : Eni Petroleum Well : S107-SE4 Schlimberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in 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<30 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) Top Plug is not Bumped at calculated Volume a) Pump %2 shoe track volume MAX b) If Bump not seen, shut in and hold pressure 4) 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 Page 6 [Ni 8107-SE4 CemCADE v1 Initial 07-08-14.ctw;07-08-2014; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : SI07-SE4 SChliihrger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated ECDs at Casing Shoe during Placement o Depth = 6058 ft c — Frac — N = Pore - Hydrostatic ' - Dynamic 0 N- O r=.•N Q �O 1 N N_ N CL C � i Q p N '_ 1 I {. EE a0_ . O _ 0 25 50 75 100 125 150 Time (min) Page 7 ENI SI07-S[4CemCADEv1Initial 07-08-14.cfw;07-08-2014; LoadCase95/Bin Intermediate Casing;Versionwcscem472_05 • • Client : Eni Petroleum Well : S107-SE4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated EGDs at Previous shoe during Placement 0 Depth = 3177 ft 0Frac t` N— — Pore — Hydrostatic 00 mom Dynamic CO-Iii......., .. I I LO a T- i [ no = i to LL 0 q CO-', LIIIIIM1011.1.1\tkifil ,11111111111111111•111111=111•..C 0 O O O 1 r 1 O , O 1 t r 0 25 50 75 100 125 150 Time (min) Page 8 ENI SI07-SE4 CemCADE v1 Initial 07-00-14.ctw;07-00-2014; LoadCase 9 5/ein Intermediate Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : S107-SE4 S hiberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK �j Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Surface Pressures during Placement Acquired Pressureg----1---, O ..... Calc.Pump P6ec� - _. I i { ! I , r O 1_ . to o_ 44—i i L ---- COO r ri r r r 0 25 50 75 100 125 150 Time (min) Fluids at 6058 ft Lo N-: Acquired Q In — , . Q In I _.1m_ L.__ n_.__ EO _ , 1111 r>3 _ N- 1 0 t rr r 0 25 50 75 100 125 150 Time (min) Page 9 ENI SI07-SE4 CernCADE v1 Initial 07-08-14.cfw;07-08-2014; LoadCase 9 5/8in Intermediate Casing;Version wcs-cern472_05 • • Client : Eni Petroleum Well : S107-SE4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Slurry Temperatures during Placement CO 1 —o Last Sack Temp. API BFiCT r 1 ;____. _.... I_._ I I I i I I I First Sack TPmn i . . _... _.... _.`•_.__ .... _._ _ i = T CO f O o .____. _ .__ N CO— (. co0) -- ._.CD —� o l'—_ O } _ X 1 N = 2 4— CB d . 00 � _ ! N _ i -(14___' CN N _ i 0 o 0 25 50 75 100 125 150 Time (min) Page 10 ENI SI07-SE4 CemCADE v1 Initial 07-08-14.clw;07-08-2014; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : SI07-SE4 SChilikerger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Fluid Friction Pressure Hierarchy Annulus ID: 9.625 in-OD: 12.250 in 0 N —Fresh Water 12.5ppg DeepCRETE —MUDPUSHII -Mud O O— O O O— O N 7 O— co coN U � "L O_ N 1 I I 1 2 3 4 5 6 7 8 9 10 11 Flow Rate (bbl/min) Page 11 ENI SI07-5E4 CemCADE v1 Initial 07-08-14.cfw;07-O8-2014; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : S107-SE4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Slurry Temperatures for UCA up to 24hours after Placement Depth= 6058 ft aD 00 -API BHCT -'1,eotn.Prof IPe Annulus iii ...._,___ Tubular Fluids . _. w� , , . . _ ..� . °IAC,r �� , _ VP" 1 111111111111111. ' nt 1 - , 7.4 - 00- t- Sill. ii III T wi i_ oCD_ _ _ __ _ _ .__..Vin _ A r ' 1111111111 N r-- _ _III NS �mII N — , 111111111111 an-® r � �__ _ IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII 111111111111111111111111 ______III �- i.._..-L-_ ___ ..- - .___�,... iii --I-._ ..-......� � -- ____ MIS L. _ �{v .._ t _.. IIIIIIII,_ 11111111111111111111111111 I— III ..„_.--___--4:t -__....v1� a._. __..;,..... _.._ ___ '. �..._.., . ?._. ;.. co __ p r r r r 0 250 500 750 1000 1250 1500 1750 Time(min) Page 12 ENI S107-SE4 CemCADE vi Initial 07-08-14.cfw;07-08-2014; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 • Client : Eni Petroleum Well : S107-SE4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Section 4: centralizer placement Top of centralization :4772.0 ft Bottom Cent. MD :6038.0 ft Casing Shoe :6058.0 ft NB of Cent. Used :25 NB of Floating Cent. :25 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 5298.0 13 1/1 HYDROFORM 0.0 5282.8 CENTRALIZER 5578.0 0 0/0 0.0 5298.0 6058.0 12 1/1 HYDROFORM 0.0 5593.3 CENTRALIZER 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 9 5/8 11.750 11.750 Yes N.A. N.A. N.A. CENTRALIZER (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications (2)—Centralizer placement data is based on current [NI field practices ft % deg o_ 0 50 100 0 30 60 90 Betw een Cent. Deviation + At Cent. O o— N O O o— 0 i`c 0 0 — Well Pipe Standoff Deviation Page 13 ENI 8107-SE4 CemCADE vi Initial 07-08-14.ctw;07-08-2014; LoadCase 9 5/8in Intermediate Casing;Version wcs-cern472_05 • • Client : Eni Petroleum Well : SlOJ-SE4 Seblumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Section 5: WELLCLEAN II Simulator Fluids Concentrations Risk.Mud on the Wall z z N i t 4400- 111 4400A400 - r 4400 a r' 4600- 4600 4600 4600 1 4800- -4800 4600 --.-' z 4800 5000- -5000 E. 5000 I i 5000 i- a 5200- 5200 a n 5440 It 5200 a SAGO- 111 5400 5400 _ 5400 0 5600- -5600 5600 it 5604 5800- -5800 5800 ,.' 5800 6000- -6000 0000 '' .-.1 8000 I � N o o N N N x x = Mud = High 1 Low Mil Fresh Water ( I Medium I I None 112.5ppg DeepCRETE r---1 MUDPUSH II ft % % 0 50 100 0 25 50 75 100 o_ < j _ a > I -Std Betw Cent. NAM Contamination -Cement Coverage -Uncontaminated Slurry O p O CV N O_ 7 A r O O O u-s n— Well Cement Coverage Uncontaminated Slurry Page 14 ENI SI07-SE4 CemCADE vl Initial 07-08-14.cfw;07-08-2014; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 • Client : Eni Petroleum Well : S107-SE4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Schlumberger UU Country : USA Loadcase : 9 5/8in Intermediate Casing Section 6: operator summary MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 90.625 bbl D047 20.000 gal 0.200 gal/bbl of spacer D182 543.750 lb 6.000 lb/bbl of base fluid D031 11722.021 lb 117.22 lb/bbl of spacer 12.5ppg DeepCRETE Volume : 155.5 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 72.7 bbl 10.0 bbl LAS Design 12.5-0.82-53 55796.156 lb Fresh water 72.678 bbl 10.001 bbl D046 111.592 lb 0.200%BWOB D065 139.490 lb 0.250%BWOB D167 139.490 lb 0.250%BWOB D153 55.796 lb 0.100%BWOB Fresh Water Volume : 10.0 bbl Density : 8.32 lb/gal Code Quantity Design Fresh water 10.000 bbl Page 15 ENI S107-SE4 CemCADE vl Initial 07-08-14.c1w;07-08-2014; LoadCase 9 5/Bin Intermediate Casing;Version wcs-cern472_05 4 0 • Client : Eni Petroleum Well : S107-SE4 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Appendix 1 - Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 330.0 0.000 100.0 100.0 0.0 330.0 0.000 200.0 200.0 0.0 330.0 0.000 300.0 300.0 1.5 330.0 1.500 400.0 399.8 5.0 330.0 3.500 500.0 499.1 8.5 330.0 3.500 600.0 597.5 12.0 330.0 3.500 700.0 694.6 15.5 330.0 3.500 800.0 790.1 19.0 330.0 3.500 900.0 883.6 22.5 330.0 3.500 1000.0 974.8 26.0 330.0 3.500 1100.0 1063.2 29.5 330.0 3.500 1200.0 1148.7 33.0 330.0 3.500 1300.0 1230.9 36.5 330.0 3.500 1400.0 1309.4 40.0 330.0 3.500 1459.3 1354.1 42.1 330.0 3.492 1500.0 1384.3 42.3 330.0 0.516 1600.0 1458.0 42.8 330.0 0.500 1700.0 1531.1 43.3 330.0 0.500 1800.0 1603.6 43.8 330.0 0.500 1900.0 1675.5 44.3 330.0 0.500 2000.0 1746.8 44.8 330.0 0.500 2100.0 1817.4 45.3 330.0 0.500 2152.2 1854.1 45.5 330.0 0.498 2200.0 1887.4 46.2 332.5 4.001 2300.0 1955.6 47.7 337.5 3.999 2400.0 2021.7 49.5 342.3 4.001 2500.0 2085.3 51.4 346.9 4.002 2600.0 2146.2 53.5 351.2 3.997 2700.0 2204.0 55.8 355.2 4.004 2800.0 2258.5 58.2 359.0 3.997 2899.9 2309.4 60.7 2.7 3.999 2900.0 2309.4 60.7 2.7 0.000 2945.2 2331.5 60.7 2.7 0.000 3000.0 2358.9 59.5 4.8 -3.998 3100.0 2411.3 57.3 8.8 -3.999 3177.4 2453.9 55.8 12.0 -3.999 3200.0 2466.7 55.4 13.0 -3.985 3300.0 2524.9 53.5 17.3 -4.002 3400.0 2585.5 51.9 21.9 -3.995 3500.0 2648.2 50.4 26.7 -4.004 3600.0 2712.9 49.1 31.7 -4.002 3700.0 2779.0 48.0 36.8 -3.996 3800.0 2846.4 47.2 42.1 -4.000 3900.0 2914.7 46.7 47.5 -4.000 4000.0 2983.6 46.3 53.0 -4.001 4100.0 3052.6 46.3 58.5 -3.999 4200.0 3121.6 46.5 64.1 4.003 4300.0 3190.1 47.0 69.5 4.000 4400.0 3257.8 47.7 74.8 3.996 4500.0 3324.4 48.7 80.1 3.999 4600.0 3389.6 49.9 85.1 4.001 4700.0 3453.0 51.3 89.9 4.002 4800.0 3514.3 53.0 94.6 4.002 4900.0 3573.3 54.7 99.0 4.002 5000.0 3629.7 56.7 103.2 3.999 5100.0 3683.1 58.7 107.3 3.993 Page 16 ENI S107-SE4 CemCADE v1 Initial 07-08-14.ctw;07-08-2014; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 • • Client : Eni Petroleum Well : SI07-SE4 SchlifiuMer String : 9 5/8 Intermediate Casing District : Prudhoe Bay,AK Country : USA Loadcase : 9 5/8in Intermediate Casing Appendix 1 - Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 5200.0 3733.3 60.9 111.2 4.004 5300.0 3780.1 63.2 114.9 4.004 5374.0 3812.4 65.0 117.5 3.995 5400.0 3823.4 65.0 117.5 0.000 5500.0 3865.7 65.0 117.5 0.000 5574.0 3897.0 65.0 117.5 0.000 5600.0 3907.7 66.0 117.6 3.986 5700.0 3945.2 70.0 118.1 4.006 5800.0 3976.1 74.0 118.6 3.994 5900.0 4000.3 78.0 119.0 4.004 6000.0 4017.7 81.9 119.5 4.002 6059.0 4024.8 84.3 119.7 3.955 Page 17 ENI S107-SE4 CemCADE v1 Initial 07-08-14.cfw;07-08-2014; loadCase 9 5/Bin Intermediate Casing;Version wcs-cem472_05 • Bettis, Patricia K (DOA) From: Lazzari Andrea <Andrea.Lazzari@enipetroleum.com> Sent: Thursday,July 10, 2014 3:23 PM To: Bettis, Patricia K (DOA) Subject: RE: Nikaitchuq SI07-SE4: Permit to Drill Application Good afternoon Patricia, No, we won't pre-produce S107-SE4. Best regards, Andrea Lazzari From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, July 10, 2014 3:20 PM To: Lazzari Andrea Subject: Nikaitchuq SI07-SE4: Permit to Drill Application Good afternoon, Andrea, Does ENI plan to pre-produce 5107-SE4 and if so,for what duration of time? 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 a(�alaska.gov. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Thursday, July 10, 2014 3:20 PM To: 'andrea.lazzari@enipetroleum.com' Subject: Nikaitchuq SI07-SE4: Permit to Drill Application Good afternoon,Andrea, Does ENI plan to pre-produce SI07-SE4 and if so,for what duration of time? 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: /k I4�t S! 0?— PTD: ?—PTD: { {—/c0 Development /Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: A (cu1-c POOL: it)r I 411 i -. ttckki' IJ 7- � Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well(name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging also 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 e • 1 '❑ 1Tow 0) 0 a) a w w O7 a) co Ili -a-) cC f6. • Q U. a LE w co C, I4) co 3 I v) o OC. O' Z C a3 IL) 0 a) E O 0 p„no orn a 0, o. a, o = E. • 3 s .N `) cp. co O W C. -o. O 'O _ c. O. u) N o m 0 2 73 o cco c C a - J O a c 0. �. co a) .0 0 = o• `�) 3 co a) c a w' M 0. m. 2 2. -o a). CO a3 a d -. 0 V LU C, W'. Q J., co C : CCO• : E "O, a) U .c. 3. H. a w, us c a) C, OD a7 0 o Q. p N �. �.-) a). �. c co a)' . CO -p. CO' a, CO a7 a3 4 N. E' 2 a • I- 0 2 w U. =. 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Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: June 17, 2015 Surface Data Logging End of Well Report SI07-SE4 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: SI07-SE4 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23519-00-00 Sperry Job Number: AK-XX-0902407754 Job Start Date: 18 May 2015 Spud Date: 19 May 2015 Total Depth: 16130’ MD, 4076’ TVD North Reference: True Declination: 18.956° Dip Angle: 81.098° Total Field Strength: 57501.472 nT Date Of Magnetic Data: 21 May 2015 Wellhead Coordinates N: North 70° 33’ 28.14100” Wellhead Coordinates W: West 149° 54' 15.00737" Drill Floor Elevation 53.91’ Ground Elevation: 13.10’ Permanent Datum: Mean Sea Level SDL Engineers: Alexander Kalenuik, Chris Silva, Kori Jo Plowman SDL Sample Catchers: Kruz Kleewein, Jermond Holloway Company Geologist: Josh Zuber Company Representatives: Jack Keener / Mike Ross / Bruce Simonson SSDS Unit Number: 110 DAILY SUMMARY 05/17/2015 SDL continues on location from previous well. Skid rig floor into drilling position. Rig up operation in preparation for pre-spud acceptance. Set SDL mud logging unit and rig up. 05/18/2015 Complete rig up operations. Calibrate gas equipment. Test surface equipment. Fill conductor casing. 05/19/2015 Clean conductor casing. Make up BHA #2 and drill ahead from 160’ MD to 1,164’ MD. Gas: Max gas observed was 26 units at 1,060’ MD with an average gas of 8 units. Fluids: No fluid lost to formation. 05/20/2015 Continue to drill ahead from 1,164’ MD to surface TD of 3,050’ MD. Begin to backream out of hole. Gas: Max gas observed was 988 units at 1,993’ MD with an average gas of 102 units. Fluids: No fluid lost to formation. 05/21/2015 Continue to backream out of hole to 218' MD. Lay down BHA #2. Pick up GBR casing tools. Rig up casing equipment. Make up shoe track to 119' MD. Begin to run 13 3/8” casing from 119' MD to 1,334' MD. Gas: Max gas observed was 1048 units at 3,050’ MD with an average gas of 40 units. Fluids: 7 bbls lost to formation. 05/22/2015 Continue to run in hole with 13 3/8" casing from 1,334' MD to 2,995' MD. Make up hanger, wash down and land at 3,035' MD. Circulate and condition mud for cementing. Pump cement and chase with mud. Rig down all equipment and casing tools. Lay down landing joint. Nipple down stack and load pipe in shed. Prepare well head and test. Install BOP stack. Gas: N/A Fluids: No fluid lost to formation. 05/23/2015 Nipple up and rig up for BOPE test. Fill and purge BOP stack. Test BOPE. Rig down test equipment. Pick up 14 stands drill pipe. Install test plug and wear ring. Rig up and perform casing test. Make up BHA #3. Run in hole and wash down from 2,904' MD to 2,953' MD. Drill out float equipment from 2,953' MD to 2,997' MD. Gas: Max gas observed was 8 units at 3,050’ MD with an average gas of 4 units Fluids: No fluid lost to formation. 05/24/2015 Continue to drill out float equipment to 3,050' MD. Drill out 20’ new formation to 3,070' MD. Displace well from Spud mud to LSND water-base mud. Pull out of hole to 2,997' MD and perform formation integrity test to 13.0 ppg. Rig down test equipment. Continue to pull out of hole and lay down BHA #3. Make up BHA #4 and run in hole to 3,070' MD. Drill from 3,070' MD to 3,375' MD. Gas: Max gas observed was 46 units at 3,196’ MD with an average gas of 29 units Fluids: No fluid lost to formation. 05/25/2015 Drill from 3,375' MD to 5,062' MD. Gas: Max gas observed was 48 units at 3,568’ MD with an average gas of 10 units Fluids: No fluid lost to formation. Geology: Samples consist of mainly sandstone with some areas of siltstone. 05/26/2015 Drill from 5,062' MD to 6,123' MD. Gas: Max gas observed was 1370 units at 5,758’ MD with an average gas of 44 units Fluids: No fluid lost to formation. Geology: Samples consist of mainly sandstone with some areas of siltstone. 05/27/2015 Drill from 6,123' MD to intermediate TD of 6,246' MD. Back ream out of hole from 6,146' MD to 3,284' MD. Rotate and reciprocate. Pull BHA through 13 3/8" casing while pumping. Rotate and reciprocate to 2,910' MD. Pull out of hole from 2,910' MD to 2,443' MD. Gas: Max gas observed was 1383 units at 6,221’ MD with an average gas of 25 units Fluids: No fluid lost to formation. Geology: Samples consist of mainly sandstone with some areas of siltstone and shale. 05/28/2015 Continue to pull out of hole and lay down BHA #4. Change rams to 9 5/8" casing rams. Remove wear ring, install test plug, test casing rams, remove test plug and reinstall wear ring. Move GBR casing tools to rig floor and rig up. Run in hole with 9 5/8" casing to 6,241' MD. Gas: No significant gas data. Fluids: No fluid lost to formation. 05/29/2015 Rig down casing equipment and rig up cement head. Fill casing, circulate and condition mud. Load cement plugs, pump mud push, and drop bottom plug. Pump cement, drop top plug and rig down cement equipment. Prepare and cut casing. Pull wear ring. Install 9 5/8" packoff. Set test plug and change out rams. Gas: No significant gas data. Fluids: No fluid lost to formation. Geology: No samples collected. 05/30/2015 Pick up 4 1/2" drill pipe. Transfer oil based mud to pits. Rig up and test BOPE. Rig down all lines. Pull test ring and install wear ring. Make up BHA #5. Gas: No significant gas data. Fluids: No fluid lost to formation. Geology: No samples collected. 05/31/2015 Pick up BHA #5. Run in hole to 1,511' MD and shallow hole test. Continue to run in hole to 4,174' MD. Logging pass from 4,174' MD to top of cement at 6,246' MD. Test casing and rig down test equipment. Displace well from LSND water-based mud to FazePro oil-based mud. Continue displacing while drilling through cement. Cut and slip drilling line and clean surface equipment. Drill out 20' new hole to 6,266' MD. Circulate bottoms up until even 9.4 ppg mud weight. Perform formation integrity test at 13.0ppg equivalent mud weight. Circulate while loading pipe shed with 5" drill pipe and pulling out of hole. Lay down unnecessary 4.5" drill pipe. Gas: Max gas observed was estimated to be 250 units. Exact reading was not possible due to a malfunctioning DataScan module. Fluids: No fluid lost to formation. 06/01/2015 Change out handling equipment to 5". Run in hole to 6,004' MD. Pull out of hole and change out handling equipment to 4.5". Run in hole to 6,163' MD with 4.5" drill pipe. Change out saver sub, service top drive. Wash to bottom at 6,266' MD. Drill from 6,266' MD to 7,464’ MD. Gas: Max gas observed was 1717 units at 7,190’ MD with an average gas of 582 units Fluids: No fluid lost to formation. Geology: Samples consist of mainly sandstone with some areas of siltstone and shale. 06/02/2015 Drill from 7,464' MD to 9,710' MD. Gas: Max gas observed was 1419 units at 9,243’ MD with an average gas of 586 units. Fluids: 19 bbls lost to formation. Geology: Samples consist of mainly sandstone with some areas of siltstone. 06/03/2015 Drill from 9,710' MD to 11,913' MD. Gas: Max gas observed was 1462 units at 11,522’ MD with an average gas of 655 units Fluids: 90 bbls lost to formation. Geology: Samples consist of mainly sandstone. 06/04/2015 Drill from 11,913' MD to 14,356' MD. Gas: Max gas observed was 1734 units at 12,676’ MD with an average gas of 875 units Fluids: 69 bbls lost to formation. Geology: Samples consist of mainly sandstone. 06/05/2015 Drill from 14,356' MD to 16,059' MD. Gas: Max gas observed was 1534 units at 14,435’ MD with an average gas of 562 units Fluids: 46 bbls lost to formation. Geology: Samples consist of mainly sandstone with some areas of siltstone. 06/06/2015 Drill from 16,059' MD to final TD at 16,130' MD. Circulate bottoms up for 5 stands to 15,688' MD. Backream out of the hole to 10,737' MD. Gas: Max gas observed was 1561 units at 16,028’ MD with an average gas of 744 units Fluids: 80 bbls lost to formation. Geology: Samples consist of mainly sandstone. 06/07/2015 Backream out of hole from 10,737' MD to 6,160' MD. Change out to 4.5" handling equipment. Pull out of hole to 5,690' MD and pump dry job. Pull out of hole to 1,038' MD, circulate, pump dry job. Pull out of hole and lay down BHA #5. Clear rig floor and service top drive. Mobilize cleanout BHA. Gas: Max gas observed while backreaming was 105 units Fluids: 67 bbls lost to formation. 06/08/2015 Make up cleanout BHA and run in hole to 5,994' MD. Change out to 5" handling equipment. Run in hole to 16,130' MD. Circulate and spot 750 barrels of 9.5ppg FazeAway breaker. Clear line and pump trip pill. Pull out of hole to 14,207' MD. Gas: Max gas observed was 6 units. Fluids: 54 bbls lost to formation. 06/09/2015 Pull out of hole from 14,207' MD to 6,178' MD. Circulate hole. Cut and slip drill line. Displace from oil- based mud to Brine. Clean surface equipment. Lay down 4.5" drill pipe from 6,178' MD. Lay down cleanout BHA. Clear rig floor and rig up 4.5" liner equipment. Run in hole with 4.5" liner to 882' MD. Gas: Max gas observed was 7 units. Fluids: 166 bbls lost to formation. 06/10/2015 Run in hole with 4.5" liner from 882' MD to 10,010' MD. Lay down Volant tool and rig up casing tongs. Make up packer. Run in hole with 5" drill pipe to 10,140' MD. Inspect and lay down hanger. Rig up Volant tool. Lay down 4.5" liner from 10,008' MD to 9,894' MD. Liner joints were damaged. Decision was made to reciprocate pipe from 9,894' MD to 9,844' MD. Gas: No gas observed. No circulation. Fluids: 88 bbls lost to formation. 06/11/2015 Reciprocate liner from 9,985' to 9,935'. Rig up equipment. Pick up 3 joints of 4.5" liner to 10,010'. Change out equipment to 5" and clear floor. Make up packer. Run in hole 1 stand 5" drill pipe. Verify circulation. Run in hole from 10,151' to 16,130'. Pull up to 16,110'. Drop 1.685" ball. Set hanger and test. OK. Lay down 5" drill pipe. Lay down running tool. Lay down 5" drill pipe with mousehole. Rig up tubing equipment. Run 4.5" completion tubing to 845'. Gas: No gas observed. Fluids: 62 bbls lost to formation. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 0 5 10 15 20 25 30 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: SI07-SE4 OPERATOR: ENI Petroleum MUD CO: MI Swaco RIG: Doyon 15 SPERRY JOB: AK-XX-0902407754 Days vs. Depth 18 March 2015 Sperry SDL Continued on Location LOCATION: Nikaitchuq AREA: North Slope Borough STATE: Alaska SPUD: 19-May-2015 TD: 6-Jun-2015 Commenced 16 " Surface Hole Section On Bot: 06:30 19 May 2015 TD Surface Hole Section 3050' MD, 2487' TVD Off Bot: 19:42 20 May 2015 Commenced 12.25" Intermediate Hole Section On Bot: 19:00 24 May 2015 Landed 13.375" Casing 3035' MD, 2477' TVD 22 May 2015 TD Intermediate Hole Section 6246' MD, 4071' TVD Off Bot: 02:00 27 May 2015 Landed 9.625" Casing 6241' MD, 4070' TVD 28 May 2015 Commenced 8.75" Injection Hole Section On Bot: 22:15 31 May 2015 TD Injection Hole Section 16130' MD, 4076' TVD Off Bot: 00:20 06 June 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Difficulties experienced: We did not experience any difficulties. Recommendations: Make adjustments to computers so that updates are not automatically done. Innovations and/or cost savings: N/A No major issues were encountered throughout surface section. INSITE and gas equipment worked properly for the most part. SI07-SE4 Nikaitchuq ENI Petroleum North Slope AK-XX-0902407754 Alaska Doyon 15 Surface Chris Silva 21-May-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: We experienced no diffuculties. Recommendations: N/A Innovations and/or cost savings: N/A All equipment and software functioned properly. All personel worked as a team to achieve a successful logging of this section of the well. SI07-SE4 Nikaitchuq ENI Petroleum North Slope AK-XX-0902407754 Alaska Doyon 15 Intermediate Alexander Kalenuik 28-May-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: The sampling and geologic work went as planned. For the most part, our systems functioned well, with a few exceptions, noted below. SI07-SE4 Nikaitchuq ENI Petroleum North Slope AK-XX-0902407754 Alaska Doyon 15 Injection Gregory Dellner 6-Jun-2015 What went as, or better than, planned: Difficulties experienced: We had a few minor issues with our data collection and gas systems. These issues have either been corrected or are being corrected internally before the next well. There was also a brief outage of Petrolink from the Petrolink side. Recommendations: If possible, see if Canrig can send personnel to give us a better setup. One of our connections can be secured better, but it requires special equipment. Innovations and/or cost savings: N/A Surface Data Logging After Action Review WELL NAME:SI07-SE4 LOCATION:Nikaitchuq OPERATOR:ENI Petroleum AREA:North Slope Borough MUD CO:MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:19-May-2015 SPERRY JOB:AK-XX-0902407754 TD:6-Jun-2015 Marker MD INC AZ TVD TVDSS 16" Surface Borehole 20" Conductor Shoe 160.0 0.6 333.8 160.0 -106.1 SV-4 775.4 19.5 332.3 768.2 -714.3 SV-3 1,169.3 32.7 328.2 1,118.8 -1,064.9 SV-2 1,493.4 41.4 331.4 1,378.7 -1,324.8 Permafrost Base 2,045.0 44.5 331.4 1,774.7 -1,720.8 SV-1 2,280.0 44.5 340.8 1,940.2 -1,886.3 Ugnu Top (UG4)2,745.0 45.0 0.5 2,268.2 -2,214.3 13 3/8" Casing Shoe 3,035.0 43.9 16.9 2,476.5 -2,422.6 TD 16" Borehole 3,050.0 43.8 17.4 2,487.3 -2,433.4 12 1/4" Intermediate Borehole UG-2 Coal Bed Marker 3,578.5 59.0 44.9 2,820.3 -2,766.4 Lower Ugnu 4,976.5 58.7 102.4 3,552.6 -3,498.7 Schrader Bluff 5,564.5 63.6 124.7 3,844.4 -3,790.5 N Sequence Top 5,612.5 64.0 124.8 3,865.6 -3,811.7 N Sand Top 5,720.5 64.3 124.0 3,912.8 -3,858.8 N Sequence Bottom 5,800.0 65.3 124.2 3,946.6 -3,892.7 N Sequence Base 5,892.0 68.5 123.5 3,982.9 -3,929.0 OA-Sand Top 6,230.0 82.1 124.7 4,068.6 -4,014.7 9 5/8" Intermediate Casing 6,241.0 82.5 124.8 4,070.0 -4,016.1 TD 12 1/4" Borehole 6,246.0 82.7 124.9 4,070.7 -4,016.8 8 3/4" Injection Lateral OA-2 6,289.0 84.6 125.9 4,075.7 -4,021.6 OA-3 6,539.5 90.5 131.0 4,082.1 -4,028.2 OA-3 6,799.0 90.2 127.9 4,080.5 -4,026.6 OA-2 7,075.0 90.9 127.4 4,078.2 -4,024.3 OA-2 7,394.0 86.5 126.8 4,083.3 -4,029.4 OA-3 7,485.0 85.2 126.2 4,090.0 -4,036.1 OA-3 8,937.0 92.0 125.5 4,106.4 -4,052.5 OA-2 9,027.0 91.6 125.1 4,103.5 -4,049.6 OA-2 9,870.0 89.2 127.5 4,112.9 -4,059.0 OA-3 10,496.0 87.9 126.4 4,115.5 -4,061.6 OA-3 11,669.0 92.1 123.2 4,112.2 -4,058.3 OA-2 12,056.0 91.6 126.7 4,101.5 -4,047.6 OA-2 12,929.0 88.0 126.4 4,103.0 -4,049.1 OA-3 13,087.0 88.0 125.8 4,108.7 -4,054.8 OA-3 14,870.0 92.2 125.8 4,101.1 -4,047.2 OA-2 15,660.0 92.2 127.6 4,080.4 -4,026.5 OA-2 16,078.0 89.0 126.2 4,075.4 -4,021.5 TD SI07-SE4 8 3/4" Borehole 16,130.0 89.0 126.3 4,076.3 -4,022.4 Formation Tops SI07-SE4 ENI Petroleum MI Swaco Doyon 15 AK-XX-0902407754 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 18-May 0 8.75 185 32 47 18/36/47 111/79/60/43/17/14 2/NA 3.0 0/97 0.00 0.15 9.7 22.0 .10/.20 1750 120 Rig Up 19-May 918 9.20 108 33 37 25/49/65 103/70/58/42/18/15 1/NA 4.0 3/93 0.20 0.30 9.7 23.0 .20/.80 4000 120 Drill 16" hole 20-May 3050 9.40 106 32 34 25/47/64 98/66/54/39/18/16 1/NA 5.0 1/94 0.20 0.20 9.6 24.0 .10/.60 3800 120 Drill 16" hole 21-May 3050 9.40 96 30 36 24/43/61 102/66/53/38/16/14 1/NA 4.0 1/95 0.20 0.20 9.7 23.0 .15/.60 3700 120 BROOH 22-May 3050 9.30 45 13 15 6/11/15 41/28/18/12/6/4 1/NA 4.0 0/96 1.00 0.20 9.5 19.0 .10/.50 3700 120 Pump cement 23-May 3050 9.20 41 13 13 ------------RIH 24-May 3125 9.30 52 10 26 10/12/15 46/36/31/25/12/9 2/NA 4.0 3/93 -1.60 10.0 1.0 1.20/2.70 5600 80 Drill 12.25" hole 25-May 4964 9.20 59 14 32 12/15/18 60/46/39/30/13/11 2/NA 4..5 3/93 0.10 1.30 9.6 11.0 .60/1.80 2700 80 Drill 12.25" hole 26-May 5964 9.40 59 15 28 11/13/16 58/43/36/28/13/10 2/NA 5.0 3/92 0.10 1.20 9.7 11.0 .50/1.30 2250 80 Drill 12.25" hole 27-May 6246 9.40 57 15 27 12/14/17 57/42/14/11 2/NA 5.0 3/92 0.10 1.20 9.6 10.0 .50/1.3 2100 80 BROOH 28-May 6246 9.30 64 16 26 13/15/18 58/27/36/27/13/11 2/NA 5.0 3/92 0.10 1.00 9.2 10.0 .50/1.10 2100 80 Run 9.63" casing 29-May 6246 9.30 58 13 15 5/7/9 41/28/23/17/6/4 2/NA 5.0 3/92 0.10 0.90 9.0 9.0 .50/1.00 2000 80 Cement casing Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Alka POM Excess Lime Elec Stab CaCl2 WPS LGS/HGS ASG Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%ml ppb volts ppb ppm ppb ASG 30-May 6246 9.3 44 11 13 6/6/7 ------------Test BOPE 31-May 6266 9.4 46 12 13 6/7/7 4.9 37/25/19/14/6/5 NA/2 2.6 66/34 2.7 3.51 563 29.78 -7.96/545.54 2.7 L/D 4.5" DP 1-Jun 7033 9.4 52 11 21 7/8/8 4.7 43/32/24/18/7/6 NA/2 6.56 67/33 2.5 3.25 588 30.21 -13.65/51.26 2.8 Drill 8.75" hole 2-Jun 9242 9.4 47 12 20 7/7/8 4.6 44/32/26/19/7/6 NA/2 7.34 65/35 2.4 3.12 772 27.93 -9.24/61.04 2.7 Drill 8.75" hole 3-Jun 11751 9.4 47 13 17 7/7/8 4.3 43/30/24/18/7/6 NA/1 8.53 67/33 2.4 3.12 775 26.68 -24.95/62.11 2.9 Drill 8.75" hole 4-Jun 14006 9.4 46 13 17 6/7/7 4.3 43/30/24/17/7/6 NA/1 8.94 69/31 2.1 2.73 808 26.7 -27.28/64.4 2.9 Drill 8.75" hole 5-Jun 15686 9.4 46 13 17 6/7/7 4.1 43/30/24/18/7/6 NA/1 8.79 70/30 2.6 3.38 890 29.64 -27.99/62.59 2.9 Drill 8.75" hole 6-Jun 16130 9.4 47 13 17 6/7/7 4.3 43/30/24/18/7/6 NA/1 9.03 69/31 1.8 2.34 930 27.06 -32.18/62.2 3 BROOH 7-Jun 16130 9.4 47 12 18 6/7/7 4.3 42/30/24/18/7/6 NA/1 8.88 69/31 1.8 2.34 960 26.68 -30.02/62.16 3 P/U Cleanout BHA 8-Jun 16130 9.4 50 13 16 6/6/7 -42/29/23/17/7/6 NA/-8.83 69/31 2.3 2.99 700 26.98 -29.72/61.92 3 POH Cleanout BHA 9-Jun 16130 9.2 28 ---------------Run 4.5" Liner 10-Jun 16130 9.2 28 ---------------Reciprocate Pipe 11-Jun 16130 9.2 28 ---------------Run 4.5" Completion Tubing Casing Record SPUD:19-May-2015 SPERRY JOB:TD:6-Jun-2015 Remarks 20" Conductor @ 160' MD, 160'TVD 13.375" Casing @ 3035' MD, 2477'TVD 9.625" Casing @ 6241' MD, 4070'TVD WELL NAME:LOCATION:Nikaitchuq OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG: W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 2 100 1 Smith XR+ Mill Tooth 16.00 160 3050 2890 18.80 1.117 69.6 20 40 1850 775 1-1-WT-A-E-1-NO-TD Surface Section TD 3 200 2 Hycalog SKHI716D-E8C PDC 12.25 3050 3070 20 1.00 0.969 20.0 ----1-1-CT-G-X-In-No-BHA Clean out shoe track and 20' formation 4 300 3 Hycalog SK716-E11C-Z PDC 12.25 3070 6246 3176 34.90 0.969 91.1 15 40 1800 800 1-4-CT-A-X-IN-BT-TD Intermediate Section TD 5 400 4 Hycalog SKH616M-E1D PDC 8.75 6246 16130 9884 70.80 0.902 139.6 12 140 2800 500 1-2-CT-T-X-IN-WT-TD Injection Section TD WELL NAME:SI07-SE4 LOCATION:Nikaitchuq OPERATOR:ENI Petroleum AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902407754 TD:6-Jun-2015 MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:19-May-2015 B i t R e c o r d . . * 24 hr Recap:Rig Up. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1750.00 0 19-May-2015 12:00 AM Current Pump & Flow Data: 12 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 15 Report For: ConditionBit # 3.08.75 Size 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) WOB Avg Min Comments RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst Type Spud 5.80'47 Depth in / out YP (lb/100ft2) 9.70 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 Fill Conductor PV Footage B. Simonson/ O. Amend ShClyst TuffGvlCoal cP 32 Gas Summary 0 0 0 (current) Avg to0' 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-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 22.0185 MBT 0' pH 0 0 0 Siltst Units* Casing Summary Lithology (%) 00 0 (907) 685-0772Unit Phone: 0 Chris Silva Maximum Report By:Logging Engineers:Kori Jo Plowman/Chris Silva Set AtSize Grade (max)(current) 0 0 Cly 0 . . * 24 hr Recap:Clean conductor to 160' MD. Back ream out of hole for BHA change. Make up BHA. Drill from 160' MD to 1164' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 4000.00 0 19-May-2015 12:00 AM Current Pump & Flow Data: 1032 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 28.20 Doyon 15 Report For: ConditionBit # 1 4.0 16Mill Tooth 9.20 Size 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 160' WOB 5.9811.11 Avg Min Comments RPM ECD (ppg) ml/30min 17Background (max)Trip Average Mud Type Lst Type spud 4.9918'37 Depth in / out YP (lb/100ft2) 9.70 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 Drill 16" Hole PV Footage B. Simonson/ O. Amend ShClyst TuffGvlCoal cP 33 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 753.0 Flow In (gpm) Flow In (spm) 160' 1164' 1004' Max @ ft Current 1057'56.7 Date: Time: Daily spud mud loss: 0 bbls. 8 in 3 1026'Minimum Depth C-5n 1060' 84.8 C-2 26 SPP (psi) Gallons/stroke TFABit Type Depth 23.0108 MBT 0' pH 1.117 0 0 0 Siltst 645 152 Units* Casing Summary Lithology (%) 02186 15 (907) 685-0772Unit Phone: 0 Chris Silva Maximum Report By:Logging Engineers:Kori Jo Plowman/Chris Silva Set AtSize Grade (max)(current) 0 0 Cly 2137 . . * 24 hr Recap: (max)(current) 0 0 Cly 88613 Set AtSize Grade (907) 685-0772Unit Phone: 0 Chris Silva Maximum Report By:Logging Engineers:Kori Jo Plowman/Chris Silva 13210 84 847 200 Units* Casing Summary Lithology (%) 0 MBT 3050' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 24.0106 C-5n 1993' 0.0 C-2 988 in 3 3029'Minimum Depth Time: Daily spud mud loss: 0 bbls. 102 1164' 3050' 1886' Max @ ft Current 2197'93.8 Date: Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: 679.8 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Simonson/ O. Amend ShClyst TuffGvlCoal cP 32 2890' Footage 35.10 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 BROOH PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 000 spud 4.63050'34 Depth in / out Mud Type Lst Type Average 19Background (max)Trip 8.9110.39 Avg Min Comments RPM ECD (ppg) ml/30min Tools SP motor, Telescope 825, ARC 825 API FL Chromatograph (ppm) 160' 3050' WOB 100% Gas In Air=10,000 UnitsConnection 0 ConditionBit # 1 5.0 16Mill Tooth 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.93 Doyon 15 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-May-2015 12:00 AM Current Pump & Flow Data: 1741 Max 0 Chlorides mg/l 3800.00 Drilled 16" surface hole from 1164' MD to 3050' MD. Back ream out of hole from 3050' MD to 2521' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Back ream out of hole from 2521' MD to 218' MD. Lay down BHA. Pick up GBR tools. Rig up casing equipment. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 3700.00 0 21-May-2015 12:00 AM Current Pump & Flow Data: 41 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 15 Report For: Condition 1-1WT-A-E-1-NO-TD Bit # 1 4.0 16Mill Tooth 9.40 Size 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools SP motor, Telescope 825, ARC 825 API FL Chromatograph (ppm) 27.5160' 3050' WOB Evermar Avg Min Comments RPM ECD (ppg) ml/30min 3Background (max)Trip Average Mud Type Lst Type 19.0 spud 4.83050'30 Depth in / out YP (lb/100ft2) 9.70 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 Run 13 3/8" Casing PV 2890' Footage 35.10 B. Simonson/ O. Amend ShClyst TuffGvlCoal cP 36 Gas Summary 0 0 0 (current) Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 3050' 3050' 0' Max @ ft Current Date: Time: Make up shoe track to 119' MD. Run Casing from 119' MD to 1334' MD. Daily spud mud loss: 7 bbls. 40 in 2Minimum Depth C-5nC-2 1048 SPP (psi) Gallons/stroke TFABit Type Depth 23.096 MBT 3050' pH 1.117 0 0 0 Siltst Units* Casing Summary Lithology (%) 03287 0 (907) 685-0772Unit Phone: 0 Chris Silva Maximum Report By:Logging Engineers:Alexander Kalenuik/Chris Silva Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) 0 0 Cly 122627 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade 20.00'' (907) 685-0772Unit Phone: 0 Chris Silva Maximum Report By:Logging Engineers:Alexander Kalenuik/Chris Silva 0 0 13.38'' Units* Casing Summary Lithology (%) 0 L-80 MBT 3050' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 19.045 C-5nC-2 in Minimum Depth Time: Circulate and condition mud for cementing. Pump cement and chase with mud. Rig down all equipment and GBR tools. Lay 3050' 3050' 0' Max @ ft Current Date: Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Simonson/ O. Amend ShClyst TuffGvlCoal cP 13 2890' Footage 35.10 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 Install BOP PV 24 hr Max 68.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 000 19.0 spud 5.23050'15 Depth in / out Mud Type Lst Type Average Background (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools SP motor, Telescope 825, ARC 825 API FL Chromatograph (ppm) 27.5160' 3050' WOB Evermar 100% Gas In Air=10,000 UnitsConnection 0 Install BOP stack. Daily spud mud loss: 0 bbls. down landing joint. Install bell guide and elevators, wash stack. Nipple down stack, load pipe in shed. Prepare well head and test. 3035' 160' Condition 1-1WT-A-E-1-NO-TD Bit # 1 4.0 16Mill Tooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 15 Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 22-May-2015 12:00 AM Current Pump & Flow Data: 11 Max 0 Chlorides mg/l 3700.00 Run in hole with 13 3/8" casing from 1334' MD to 2995' MD. Make up hanger, wash down and land at 3035' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Nipple up BOPE. Install lines and clean cement valves. Rig up for BOPE test. Fill and purge BOP stack. Test BOPE. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 0 23-May-2015 12:00 AM Current Pump & Flow Data: 678 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 6 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 15 Report For: Condition 1-1WT-A-E-1-NO-TD Bit # 1 16Mill Tooth 9.20 Size 2997' MD. Daily spud mud loss: 0 bbls. 8test. Make up BHA 3. Run in hole to 2904' MD. Wash down from 2904' MD to 2953' MD. Drill out float equipment from 2953' MD to 3035' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools SP motor, Telescope 825, ARC 825 API FL Chromatograph (ppm) 27.5160' 3050' WOB Evermar Avg Min Comments Surface RPM ECD (ppg) ml/30min 6Background (max)Trip Average Mud Type Lst Type 19.0 spud3050'13 Depth in / out YP (lb/100ft2) 000 00 CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 Drill float equipment PV 2890' Footage 35.10 B. Simonson/ O. Amend ShClyst TuffGvlCoal cP 13 Gas Summary 0 0 0 (current) Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 3050' 3050' 0' Max @ ft Current Date: Time: Rig down test equipment. Pick up 14 stands drill pipe. Pull mouse hole. Install test plug and wear ring. Rig up and perform casing 4 in 2Minimum Depth C-5nC-2 8 SPP (psi) Gallons/stroke TFABit Type Depth 41 L-80 MBT 3050' pH 1.117 0 0 0 Siltst 13.38'' 524 124 Units* Casing Summary Lithology (%) 00 0 (907) 685-0772Unit Phone: 0 Chris Silva Maximum Report By:Logging Engineers:Alexander Kalenuik/Chris Silva Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 6927 Set AtSize 178.9 X-65 Grade 20.00'' (907) 685-0772Unit Phone: 10 Chris Silva Maximum Report By:Logging Engineers:Alexander Kalenuik/Chris Silva 40 4119 16 13.38'' 744 176 Units* Casing Summary Lithology (%) 0 L-80 MBT 3375' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1.052 C-5n 3196' 199.0 C-2 46 in 4 3335'Minimum Depth Time: LOT/FIT to 13.0 ppg equal mud weight. Rig down test equipment. Pull out of hole from 2997' MD to 570' MD. Lay down BHA 3. 29 3070' 3375' 305' Max @ ft Current 3131'61.4 Date: Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: 740.5 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Simonson/ O. Amend ShClyst TuffGvlCoal cP 10 2890' 12.25 Footage 35.10 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 Dril 12.25" hole PV 24 hr Max 68.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.00 900 19.0 PCD LSND 6.2 3050' 3125'26 Depth in / out Mud Type Lst 60 Type Average 28Background (max)Trip 9.639.75 Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools SP motor, Telescope 825, ARC 825 API FL Chromatograph (ppm) 27.5160' 3050' WOB Evermar 100% Gas In Air=10,000 UnitsConnection 0 2 Make up BHA 4. Run in hole from 670' MD to 3070' MD. Drill from 3070' MD to 3375' MD. Daily LSND mud loss: 0 bbls. 3035' 160' Condition 1-1WT-A-E-1-NO-TD Bit # 1 4.0 16Mill Tooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.08 Doyon 15 Report For: Morning Report Report # 7 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 24-May-2015 12:00 AM Current Pump & Flow Data: 1020 Max 0 Chlorides mg/l 5600.00 Drill out float equipment from 2997' MD to 3050' MD. Drill to 3070' MD. Pull out of hole to 2997' MD. Rig up LOT/FIT. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill from 3375' MD to 5062' MD. Daily LSND mud loss: 0 bbls. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2700.00 0 25-May-2015 12:00 AM Current Pump & Flow Data: 1449 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.06 Doyon 15 Report For: Condition 1-1WT-A-E-1-NO-TD Bit # 1 4.5 16Mill Tooth 9.20 Size 2 3035' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools SP motor, Telescope 825, ARC 825 API FL Chromatograph (ppm) 27.5160' 3050' WOB Evermar 9.389.82 Avg Min Comments Surface RPM ECD (ppg) ml/30min 5Background (max)Trip Average Mud Type Lst 95 Type 19.0 PCD LSND 6.1 3050' 4964'32 Depth in / out YP (lb/100ft2) 9.60 000 00 CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 5 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 Dril 12.25" hole PV 2890' 12.25 Footage 35.10 B. Simonson/ O. Amend ShClyst TuffGvlCoal cP 14 Gas Summary 0 0 0 (current) Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: 496.2 Flow In (gpm) Flow In (spm) 3375' 5062' 1687' Max @ ft Current 4961'74.0 Date: Time: 10 in 4 4549'Minimum Depth C-5n 3568' 0.0 C-2 48 SPP (psi) Gallons/stroke TFABit Type Depth 11.059 L-80 MBT 5062' pH 1.117 0 0 0 Siltst 13.38'' 804 190 Units* Casing Summary Lithology (%) 0 5 1075 0 (907) 685-0772Unit Phone: 0 Chris Silva Maximum Report By:Logging Engineers:Alexander Kalenuik/Chris Silva Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 0 0 Cly 7075 . . * 24 hr Recap: (max)(current) BTC 454 0 Cly 149917 Set AtSize 178.9 X-65 Grade 20.00'' (907) 685-0772Unit Phone: 0 Chris Silva Maximum Report By:Logging Engineers:Alexander Kalenuik/Chris Silva 30 4677 0 13.38'' 796 188 Units* Casing Summary Lithology (%) 0 L-80 MBT 6123' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 11.059 C-5n 5758' 52.8 C-2 1370 in 2 5295'Minimum Depth Time: 44 5062' 6123' 1061' Max @ ft Current 5093'46.1 Date: Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: 547.7 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) M. Ross / R. Wimmer ShClyst TuffGvlCoal cP 15 2890' 12.25 Footage 35.10 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 Dril 12.25" hole PV 24 hr Max 68.0 Weight 12 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 000 19.0 PCD LSND 5.8 3050' 5964'28 Depth in / out Mud Type Lst 70 Type Average 31Background (max)Trip 8.989.96 Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools SP motor, Telescope 825, ARC 825 API FL Chromatograph (ppm) 27.5160' 3050' WOB Evermar 100% Gas In Air=10,000 UnitsConnection 49 2 3035' 160' Condition 1-1WT-A-E-1-NO-TD Bit # 1 5.0 16Mill Tooth 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.25 Doyon 15 Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 26-May-2015 12:00 AM Current Pump & Flow Data: 1752 Max 0 Chlorides mg/l 2250.00 Drill ahead from 5062' MD to 6123' MD. Daily LSND mud loss: 0 bbls. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill from 6123' MD to 6246' MD. Back ream out of hole fro 6146' MD to 3284' MD. Rotate and reciprocate. Pull BHA Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2100.00 0 27-May-2015 12:00 AM Current Pump & Flow Data: 0 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 15 Report For: Condition 1-1WT-A-E-1-NO-TD Bit # 1 5.0 16Mill Tooth 9.40 Size 2 Daily LSND mud loss: 0 bbls. 3035' 160' 100% Gas In Air=10,000 UnitsConnection 197 Tools SP motor, Telescope 825, ARC 825 API FL Chromatograph (ppm) 27.5160' 3050' WOB Evermar Avg Min Comments Surface RPM ECD (ppg) ml/30min 3Background (max)Trip Average Mud Type Lst Type 19.0 PCD LSND 5.7 3050' 6246'27 6246' Depth in / out YP (lb/100ft2) 9.60 000 00 CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 11 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 BROOH PV 2890' 12.25 Footage 3196' 35.10 M. Ross / R. Wimmer ShClyst TuffGvlCoal cP 15 Gas Summary 0 170 118 (current) Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: 223.0 Flow In (gpm) Flow In (spm) 6123' 6246' 123' Max @ ft Current 6244'5.3 Date: Time: through 13.375" casing while pumping. Rotate and recipricate to 2910' MD. Pull out of hole from 2910' MD to 2443' MD. 25 in 2 6246'Minimum Depth C-5n 6221' 0.0 C-2 1383 SPP (psi) Gallons/stroke TFABit Type Depth 10.057 L-80 MBT 6246' pH 1.117 0 149 0 Siltst 13.38'' 0 0 Units* Casing Summary Lithology (%) 03921 0 (907) 685-0772Unit Phone: 53 Chris Silva Maximum Report By:Logging Engineers:Alexander Kalenuik/Chris Silva Set AtSize 178.9 X-65 Grade 20.00'' (max)(current) BTC 610 0 Cly 146185 . . * 24 hr Recap:Back ream out of hole from 2443' MD to 200' MD. Lay down BHA. Change rams to 9 5/8" casing rams. Remove wear Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2100.00 0 28-May-2015 12:00 AM Current Pump & Flow Data: 12 Max 1-4-CT-A-X-IN-BT-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 15 Report For: Condition 1-1WT-A-E-1-NO-TD Bit # 1 5.0 16Mill Tooth 9.30 Size 2 9 5/8" casing to 6242' MD. Daily LSND mud loss: 0 bbls. 3035' 160' 100% Gas In Air=10,000 UnitsConnection 197 Tools SP motor, Telescope 825, ARC 825 API FL Chromatograph (ppm) 6 27.5160' 3050' WOB Evermar Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst Hydril S63 Type 23 19.0 PCD LSND 5.6 3050' 6246'26 6246' Depth in / out YP (lb/100ft2) 9.20 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 11 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 Run 9 5/8" Casing PV 2890' 12.25 0.969 Footage 34.70 3196' 35.10 M. Ross / R. Wimmer ShClyst TuffGvlCoal cP 16 40.0 Gas Summary 0 170 118 (current) Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 6246' 6246' 0' Max @ ft Current Date: Time: ring. Install test plug. Test casing rams. Remove test plug. Install wear ring. Move GBR tools to rig floor and rig up. Run in hole with in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 0.164 L-80 MBT 6246' pH 1.117 0 149 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 03921 0 (907) 685-0772Unit Phone: 53 Chris Silva Maximum Report By:Logging Engineers:Alexander Kalenuik/Chris Silva Set AtSize 178.9 X-65 Grade L-806242' 20.00'' 9.63'' (max)(current) BTC 610 0 Cly 146185 . . * 24 hr Recap:Rig down Volant. Rig up cement head. Fill casing. Circulate & condition mud. Load cement plugs, pump mud push, Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2000.00 0 29-May-2015 12:00 AM Current Pump & Flow Data: 11 Max 1-4-CT-A-X-IN-BT-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 12 Customer: Well: Area: Location: Rig: SI07-SE4 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 15 Report For: Condition 1-1WT-A-E-1-NO-TD Bit # 1 5.0 16Mill Tooth 9.30 Size 2 ring. Install 9 5/8" packoff. Nipple up choke, kill, and flow lines. Set test plug. Change out rams. Daily LSND mud loss: 0 bbls. 3035' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools SP motor, Telescope 825, ARC 825 API FL Chromatograph (ppm) 6 27.5160' 3050' WOB Evermar Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst Hydril S63 Type 23 19.0 PCD LSND 5.9 3050' 6246'15 6246' Depth in / out YP (lb/100ft2) 9.00 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902407754 Changing Rams PV 2890' 12.25 0.969 Footage 34.70 3196' 35.10 M. Ross / R. Wimmer ShClyst TuffGvlCoal cP 13 40.0 Gas Summary 0 0 0 (current) Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 6246' 6246' 0' Max @ ft Current Date: Time: and drop bottom plug. Pump cement, drop top plug. Rig down cement equipment. Prepare to cut casing. Cut casing. Pull wear in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 9.058 L-80 MBT 6246' pH 1.117 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 (907) 685-0772Unit Phone: 0 Chris Silva Maximum Report By:Logging Engineers:Alexander Kalenuik/Chris Silva Set AtSize 178.9 X-65 Grade L-806242' 20.00'' 9.63'' (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: Cly Hydril S63 Report By: 20.00'' 9.63'' Logging Engineers:Alexander Kalenuik / Chris Silva (max)(current) BTC Bit Type RPM 23.0 Hours (907) 685-0772Unit Phone: 0 Chris Silva Set AtSize 178.9 X-65 Grade 0 C-2 Gas Summary 0 0 0 0 0 0 0 0 Minimum Depth 13.38'' Maximum in 0 0 0 Install wear ring. Bring BHA to floor. Make up BHA. Daily Fazepro mud loss: 0 bbls. Alkal Coal Gallons/stroke L-80 0 6246' 6246' 0' Lime TuffGvl C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Max @ ft Date: Time: API FL Depth 6246' Avg to160' Current (current) Units* ClystSsChtSilt Lithology (%) 0.969 1144 3196' 8.75 0.902 Footage 40.0 Depth in / out Pick Up BHA PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Oil / Water 0 Intermediate Cement C-1 C-5i ShSiltst C-4n Chromatograph (ppm) 0 0 00 C-4iC-3 Bit # 0 Lst 6.0 (lb/100ft2) 9.30 Type 13 PCD Casing Summary L-806242' Mud (lb/bbl)ml/30min (max) 0Average Comments Surface Background Trip 3035' 100% Gas In Air=10,000 UnitsConnection 2 12.25 3050' 3 6246' 34.70 1-4-CT-A-X-IN-BT-TD Size 160'ConductorEvermar 6246' WOB PCD TFA Condition MWD Summary 96% %Mud Type Fazepro Ratio Mud Data Depth 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 6246' Cor Solids Avg Min YP MaxECD (ppg) Tools SP Motor, Telescope 825, ARC 825 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 13 Customer: Well: Area: Location: Rig: SI07-SE4 30-May-2015 12:00 AM AK-AM-0902407754 ROP ROP (ft/hr) M. Ross / R. Wimmer 24 hr Max Pick up 4 1/2" drill pipe. Transfer oil based mud to pits. Rig up and test BOPE. Rig down all lines. Pull test ring. Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Cly Hydril S63 Report By: 20.00'' 9.63'' Logging Engineers: Alexander Kalenuik / Greg Dellner (max) (current) BTC Bit Type RPM 23.0 Hours (907) 685-0772 Unit Phone: 0 Greg Dellner Set At Size 178.9 X-65 Grade Gas Summary 250* 30 (current) Units* 0 00 C-2 0 0 0 0Minimum Depth 13.38'' Maximum in 0 0 0 L-80 *Note: Max Gas is an estimate based on instantaneous gas readings directly from Total Hydrocarbon Analyzer. Waiting on new DataScan module to record gas readings. % Alkal Coal Gallons/stroke Comments 6246' 6266' 20' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Depth Present Avg to 6246' Current 126.8 - MWD Summary Clyst Ss Cht Silt C-4n Lithology (%) 0.969 12 46 3196' 8.75 0.902 Footage 40.0 Depth in / out - - L/D 4.5" DP PV cP 68.0 Weight Flow In (gpm) Flow In (spm) 0 Intermediate Cement C-1 C-5i Sh Siltst 0 C-4i 0 0 0 Lst 65 Chromatograph (ppm) 0 0 Type 13 PCD Casing Summary L-80 6242' 2 12.25 3050' Bit # Mud (lb/bbl) ml/30min 3.51 2.70 (max) 0Average Background 3035' 100% Gas In Air =10,000 Units Connection 5 C-3 shed w/5" DP. L/D 4.5"DP. P/U BHA #5. RIH f/377' t/1511'. SHT. RIH f/1511' t/4174'. MAD Pass f/4174' t/TOC @6146'. Test casing, R/D test Trip surface equip. Drill out 20' new hole t/6266'. CBU until even 9.4ppg mud weight, performLOT/FIT, FIT @13.0ppg. Circ, load pipe 3 6246' 34.70 1-4-CT-A-X-IN-BT-TD 6.0 Size 160'Conductor Evermar 6246' WOB PCD TFA Condition Mud Type Fazepro NA Ratio Mud Data Depth 66/34 9.40 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 6266'2.6 Cor Solids Avg Min YP Max ECD (ppg) Tools Xceed 675, EcoScope 675, TeleScope 675 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: 215.4 Morning Report Report # 14 Customer: Well: Area: Location: Rig: SI07-SE4 31-May-2015 12:00 AM AK-AM-0902407754 ROP ROP (ft/hr) M. Ross / R. Wimmer 24 hr Max Max @ ft 6255' 0 0 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 35 17 12:00 AM AK-AM-0902407754 1900 ROP ROP (ft/hr) M. Ross / R. Wimmer 24 hr Max Max @ ft 7288'422.0 Morning Report Report # 15 Customer: Well: Area: Location: Rig: SI07-SE4 1-Jun-2015 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: 10.65 Cor Solids 10.44 Avg Min YP Max ECD (ppg) Tools Xceed 675, EcoScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 7033'6.6 10.03 Mud Type Fazepro NA Ratio Mud Data Depth 67/33 9.40 Oil / Water (lb/100ft 2) 6246' WOB PCD TFA Condition 1-4-CT-A-X-IN-BT-TD 6.0 Size 160'Conductor Evermar C/O handling equip t/5", RIH f/1990 t/6004'. POOH f/6004' t/1990', C/O handling equip t/4.5". RIH f/1990' t/6163' Trip 3 6246' 100% Gas In Air =10,000 Units Connection C-3 74 Background (max) 262 Average Mud (lb/bbl) ml/30min 3.25 2.50 21 PCD Casing Summary L-80 6242' 2 12.25 3050' Bit # 3035' Chromatograph (ppm) 511 131 55 C-4i 51 89 0 0 Intermediate Cement C-1 C-5i Sh Siltst Lst - - Drilling 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Lithology (%) 0.969 11 52 3196' 8.75 0.902 Footage 40.0 Depth in / out Clyst Ss Cht Silt 10 80 Present Avg to 6246' Current 243.1 45.0 MWD Summary Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 128 SPP (psi) Comments 6266' 7464' 1198' Lime Tuff Gvl Surface 96% % 530 Alkal Coal Gallons/stroke L-80 582 7190' 0 96 54 6395'Minimum Depth 13.38'' Maximum in 4 Depth 0 68041 66 133146 033 C-2 0 C-4n Gas Summary 1717 10 (current) Units* (907) 685-0772 Unit Phone: 24 Greg Dellner Set At Size 178.9 X-65 Grade Bit Type RPM 23.0 Hours 34.70 Cly Hydril S63 Report By: 20.00'' 9.63'' Logging Engineers: Alexander Kalenuik / Greg Dellner (max) (current) BTC . . * 24 hr Recap: Report By: 20.00'' 9.63'' Logging Engineers: Alexander Kalenuik / Greg Dellner (max) (current) BTC 23.0 Hours 34.70 Cly Hydril S63 (907) 685-0772 Unit Phone: 78 Greg Dellner Set At Size 178.9 X-65 Grade Gas Summary 1419 (current) Units* 169942 028 C-2 0 C-4n 0 81482 135 6395'Minimum Depth 13.38'' Maximum in 6 Depth 7190' 0 244 157 L-80 586 % 518 Alkal Coal Gallons/stroke Comments 7464' 9710' 2246' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 123 SPP (psi) Present Avg to 6246' Current 294.2 165.0 MWD Summary Ss Cht Silt 100 Lithology (%) 0.969 12 47 3196' 8.75 0.902 Footage 40.0 Depth in / out - - Drilling 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Intermediate Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 154 212 0 0 Chromatograph (ppm) 298 199 6242' 2 12.25 3050' Bit # 3035' Bit Type Mud (lb/bbl) ml/30min 3.12 2.40 (max) 199 Average 57 Background 100% Gas In Air =10,000 Units Connection C-3 Drill f/7,464' to 9,710' MD. Daily FazePro loss: 19 bbls. Trip 3 6246' 6.0 Size 160'Conductor Evermar PCD Casing Summary L-80 6246' WOB PCD TFA Condition 1-4-CT-A-X-IN-BT-TD 20 RPM Mud Type Fazepro NA Ratio Mud Data Depth 65/35 9.40 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 9242'7.3 10.16 10.94 Cor Solids 10.61 Avg Min YP Max ECD (ppg) Tools Xceed 675, EcoScope 675, TeleScope 675 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: 514.8 Morning Report Report # 16 Customer: Well: Area: Location: Rig: SI07-SE4 2-Jun-2015 12:00 AM AK-AM-0902407754 2300 ROP ROP (ft/hr) J. Keener / O. Amend 24 hr Max Max @ ft 9157' 125 61 185 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Report By: 20.00'' 9.63'' Logging Engineers: Alexander Kalenuik / Greg Dellner (max) (current) BTC 175394 0 23.0 Hours 34.70 Cly Hydril S63 L-80 Comments Intermediate (907) 685-0772 Unit Phone: 54 Greg Dellner Set At Size 178.9 X-65 Grade Gas Summary 1462 (current) Units* 162 C-2 0 C-4n 0 77984 74 11570' Depth Present 0.969 13 Minimum Depth 13.38'' Maximum in 8 Lithology (%) 2 Bit # 11522' 0 172 117 655 % 521 Alkal Coal Gallons/stroke 9710' 11913' 2203' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 123 SPP (psi) Avg to 6246' Current 285.1 100.7 MWD Summary Ss Cht Silt 100 3196' 8.75 0.902 Footage 40.0 Depth in / out 6242' 12.25 3050' - - Drilling 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 87 148 0 0 Chromatograph (ppm) 301 131 3035' Bit Type Mud (lb/bbl) ml/30min 3.12 2.40 (max) 147 C-3 Average 51 Background 100% Gas In Air =10,000 Units Connection Drill f/9,710' to 11,913' MD. Daily FazePro loss: 90 bbls. Trip 3 6246' 6.0 Size 160'Conductor Evermar PCD Casing Summary L-80 6246' WOB PCD TFA Condition 1-4-CT-A-X-IN-BT-TD 17 RPM 47 Mud Type Fazepro NA Ratio Mud Data Depth 67/33 9.40 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 11751'8.5 10.65 11.21 Cor Solids 10.90 Avg Min YP Max ECD (ppg) Tools Xceed 675, EcoScope 675, TeleScope 675 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: 470.1 Morning Report Report # 17 Customer: Well: Area: Location: Rig: SI07-SE4 3-Jun-2015 12:00 AM AK-AM-0902407754 2500 ROP ROP (ft/hr) J. Keener / O. Amend 24 hr Max Max @ ft 11489' 83 44 106 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 61 26 86 12:00 AM AK-AM-0902407754 2600 ROP ROP (ft/hr) J. Keener / O. Amend 24 hr Max Max @ ft 12140'462.0 Morning Report Report # 18 Customer: Well: Area: Location: Rig: SI07-SE4 4-Jun-2015 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: 11.43 Cor Solids 11.11 Avg Min YP Max ECD (ppg) Tools Xceed 675, EcoScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 14006'8.9 10.42 Mud Type Fazepro NA Ratio Mud Data Depth 69/31 9.40 Oil / Water (lb/100ft 2) 6246' WOB PCD TFA Condition 1-4-CT-A-X-IN-BT-TD 17 RPM 46 6.0 Size 160'Conductor Evermar PCD Casing Summary L-80 Drill f/11,913’ MD to 14,356’ MD. Daily FazePro loss: 69 bbls. Trip 3 6246' 100% Gas In Air =10,000 Units Connection Average 22 Background Mud (lb/bbl) ml/30min 2.73 2.10 (max) 140 C-3 Bit Type Chromatograph (ppm) 269 120 78 145 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i - - Drilling 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 6242' 12.25 3050' 3035' Ss Cht Silt 100 Avg to 6246' Current 293.5 6.5 MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 120 SPP (psi) 11913' 14356' 2443' Lime Tuff Gvl Surface 96% Date: % 505 Alkal Coal Gallons/stroke 875 12676' 0 152 98 Minimum Depth 13.38'' Maximum in 8 Lithology (%) 2 Bit # 83964 59 14133' Depth Present 0.969 13 186 C-2 0 C-4n 0 Gas Summary 1734 (current) Units* (907) 685-0772 Unit Phone: 47 Greg Dellner Set At Size 178.9 X-65 Grade 23.0 Hours 34.70 Cly Hydril S63 L-80 Comments Intermediate 3196' Report By: 20.00'' 9.63'' Logging Engineers: Alexander Kalenuik / Greg Dellner (max) (current) BTC 205769 0 . . * 24 hr Recap: Report By: 20.00'' 9.63'' Logging Engineers: Alexander Kalenuik / Greg Dellner (max) (current) BTC 185941 0 23.0 Hours 34.70 Cly Hydril S63 L-80 Comments Intermediate 3196' (907) 685-0772 Unit Phone: 36 Greg Dellner Set At Size 178.9 X-65 Grade Gas Summary 1534 (current) Units* C-2 0 C-4n 0 50496 32 15685' Depth Present 0.969 13 57 Minimum Depth 13.38'' Maximum in 9 Lithology (%) 2 Bit # 14435' 0 114 74 562 % 520 Alkal Coal Gallons/stroke 14356' 16059' 1703' Lime Tuff Gvl Surface 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 123 SPP (psi) Avg to 6246' Current 248.8 181.0 MWD Summary Ss Cht Silt 100 8.75 0.902 Footage 40.0 Depth in / out 6242' 12.25 3050' 3035' - - Drilling 8.75" Hole PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 46 116 0 0 Chromatograph (ppm) 292 93 Mud (lb/bbl) ml/30min 3.38 2.60 (max) 109 C-3 Average 49 Background 100% Gas In Air =10,000 Units Connection Drill f/14,356’ MD to 16059’ MD. Daily FazePro loss: 46 bbls. Trip 3 6246' 6.0 Size 160'Conductor Evermar PCD Casing Summary L-80 Bit Type 6246' WOB PCD TFA Condition 1-4-CT-A-X-IN-BT-TD 17 RPM 46 Mud Type Fazepro NA Ratio Mud Data Depth 70/30 9.40 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 15686'8.8 11.00 11.54 Cor Solids 11.25 Avg Min YP Max ECD (ppg) Tools Xceed 675, EcoScope 675, TeleScope 675 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: 455.1 Morning Report Report # 19 Customer: Well: Area: Location: Rig: SI07-SE4 5-Jun-2015 12:00 AM AK-AM-0902407754 2800 ROP ROP (ft/hr) J. Keener / O. Amend 24 hr Max Max @ ft 14494' 33 747 Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity 45 11 63 12:00 AM AK-AM-0902407754 2200 ROP ROP (ft/hr) J. Keener / O. Amend 24 hr Max Max @ ft 16072'330.6 Morning Report Report # 20 Customer: Well: Area: Location: Rig: SI07-SE4 6-Jun-2015 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: 11.45 Cor Solids 11.40 Avg Min YP Max ECD (ppg) Tools Xceed 675, EcoScope 675, TeleScope 675 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 16130'9.0 11.34 Mud Type Fazepro NA Ratio Mud Data Depth 69/31 9.40 Oil / Water (lb/100ft 2) 6246' WOB PCD TFA Condition 1-4-CT-A-X-IN-BT-TD 17 RPM 47 6.0 Size 160'Conductor Evermar PCD Casing Summary L-80 Bit Type Drill f/16,059' to TD at 16,130' MD. Downlink, shoot survey & slow pump rates. CBU x 1 for 5 stds to 15,688'. BROOH Trip 3 6246' 100% Gas In Air =10,000 Units Connection Average -Background Mud (lb/bbl) ml/30min 2.34 1.80 (max) 169 C-3 Chromatograph (ppm) 261 61 65 84 32 34 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i - - BROOH PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 6242' 12.25 3050' 3035' Ss Cht Silt 100 Avg to 6246' Current 263.4 - MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: 119 SPP (psi) 16059' 16130' 71' Lime Tuff Gvl Surface 96% Date: % 504 Alkal Coal Gallons/stroke 744 16059' 2 80 57 Minimum Depth 13.38'' Maximum in 156 Lithology (%) 2 Bit # 96298 44 16061' Depth Present 0.969 13 14385 C-2 0 C-4n 17 Gas Summary 1400 (current) Units* (907) 685-0772 Unit Phone: 21 Greg Dellner Set At Size 178.9 X-65 Grade 23.0 Hours 34.70 Cly Hydril S63 L-80 Comments Intermediate 3196' Report By: 20.00'' 9.63'' Logging Engineers: Alexander Kalenuik / Greg Dellner (max) (current) BTC 165758 49 . . * 24 hr Recap: Report By: 20.00'' 9.63'' Logging Engineers: Alexander Kalenuik / Greg Dellner (max) (current) BTC 402 0 140 23.0 Hours 34.70 Cly Hydril S63 L-80 Comments Intermediate 3196' (907) 685-0772 Unit Phone: 0 Greg Dellner Set At Size 178.9 X-65 Grade Gas Summary 105 (current) Units* C-2 0 C-4n 0 26 Depth Present 0.969 12 0Minimum Depth 13.38'' Maximum in 3 Lithology (%) 2 Bit # 0 0 0 8 % Alkal Coal Gallons/stroke 16130' 16130' 0' Lime Tuff Gvl Surface 1-2-CT-T-X-IN-WT-TD 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Avg to 16130' Current MWD Summary Ss Cht Silt 100 8.75 0.902 Footage 40.0 Depth in / out 6242' 12.25 3050' 16130' 3035' - - P/U Cleanout BHA PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 0 0 0 9884' Chromatograph (ppm) 0 0 Mud (lb/bbl) ml/30min 2.34 1.80 (max) C-3 Average -Background 100% Gas In Air =10,000 Units Connection BROOH f/10,737' to 6,160'. C/O to 4.5" handling equip. Circ at 6,160' to 6,067'. POH to 5,690'. Pump dry job. POH to Trip loss: 67 bbls. 3 6246' 70.80 12 6.0 Size 160'Conductor Evermar PCD Casing Summary L-80 Bit Type 6246' WOB PCD TFA Condition 1-4-CT-A-X-IN-BT-TD 18 RPM 47 Mud Type Fazepro NA Ratio Mud Data Depth 69/31 9.40 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 16130'8.9 Cor Solids Avg Min YP Max ECD (ppg) Tools None ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 21 Customer: Well: Area: Location: Rig: SI07-SE4 7-Jun-2015 12:00 AM AK-AM-0902407754 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-0902407754 ROP ROP (ft/hr) J. Keener / O. Amend 24 hr Max Max @ ft Morning Report Report # 22 Customer: Well: Area: Location: Rig: SI07-SE4 8-Jun-2015 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP Max ECD (ppg) Tools None 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 16130'8.8 Mud Type Fazepro NA Ratio Mud Data Depth 69/31 9.40 Oil / Water (lb/100ft 2) 6246' WOB PCD TFA Condition 1-4-CT-A-X-IN-BT-TD 16 RPM 50 12 6.0 Size 160'Conductor Evermar PCD Casing Summary L-80 Bit Type M/U BHA #6. RIH to 5,994'. C/O to 5" equip. P/U 6 jts 5" DP. RIH to 16,130'. Circ. Spot 750 bbls 9.5 ppg FazeAway Trip 3 6246' 70.80 100% Gas In Air =10,000 Units Connection Average -Background Mud (lb/bbl) ml/30min 2.99 2.30 (max) C-3 9884' Chromatograph (ppm) 0 0 0 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i - - POH Cleanout BHA PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 6242' 12.25 3050' 16130' 3035' Ss Cht Silt 100 Avg to 16130' Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) 16130' 16130' 0' Lime Tuff Gvl Surface 1-2-CT-T-X-IN-WT-TD 96% Date: % Alkal Coal Gallons/stroke 4 0 0 0 Minimum Depth 13.38'' Maximum in 2 Lithology (%) 2 Bit # Depth Present 0.969 13 0 C-2 0 C-4n 0 Gas Summary 6 (current) Units* (907) 685-0772 Unit Phone: 0 Greg Dellner Set At Size 178.9 X-65 Grade 140 23.0 Hours 34.70 Cly Hydril S63 L-80 Comments Intermediate 3196' Report By: 20.00'' 9.63'' Logging Engineers: Kori Jo Plowman / Greg Dellner (max) (current) BTC 0 0 . . * 24 hr Recap: Report By: 20.00'' 9.63'' Logging Engineers: Kori Jo Plowman / Greg Dellner (max) (current) BTC 0 0 140 23.0 Hours 34.70 Cly Hydril S63 L-80 Comments Intermediate 3196' (907) 685-0772 Unit Phone: 0 Greg Dellner Set At Size 178.9 X-65 Grade Gas Summary 7 (current) Units* C-2 0 C-4n 0 Depth Present 0.969 0Minimum Depth 13.38'' Maximum in 2 Lithology (%) 2 Bit # 0 0 0 5 % Alkal Coal Gallons/stroke 16130' 16130' 0' Lime Tuff Gvl Surface 1-2-CT-T-X-IN-WT-TD 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Avg to 16130' Current MWD Summary Ss Cht Silt 100 8.75 0.902 Footage 40.0 Depth in / out 6242' 12.25 3050' 16130' 3035' - - Run 4.5" Liner PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 0 0 0 9884' Chromatograph (ppm) 0 0 Mud (lb/bbl) ml/30min (max) C-3 Average -Background 100% Gas In Air =10,000 Units Connection POH f/14,207' to 6,178'. Circ hole. Cut & slip drill line. Displace to Brine. Clean surface equip. L/D 4.5" DP f/6,178'. Trip 3 6246' 70.80 12 6.0 Size 160'Conductor Evermar PCD Casing Summary L-80 Bit Type 6246' WOB PCD TFA Condition 1-4-CT-A-X-IN-BT-TD RPM 28 Mud Type Brine Ratio Mud Data Depth 9.20 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 16130' Cor Solids Avg Min YP Max ECD (ppg) Tools None ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 23 Customer: Well: Area: Location: Rig: SI07-SE4 9-Jun-2015 12:00 AM AK-AM-0902407754 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-0902407754 ROP ROP (ft/hr) J. Keener / R. Wimmer 24 hr Max Max @ ft Morning Report Report # 24 Customer: Well: Area: Location: Rig: SI07-SE4 10-Jun-2015 ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP Max ECD (ppg) Tools None 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 16130' Mud Type Brine Ratio Mud Data Depth 9.20 Oil / Water (lb/100ft 2) 6246' WOB PDC TFA Condition 1-4-CT-A-X-IN-BT-TD RPM 28 12 6.0 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type RIH 4.5" liner f/882' to 10,010'. L/D Volant. R/U GBR tongs. M/U packer. RIH 1 std 5" DP to 10,140'. Inspect & L/D Trip Brine loss: 88 bbls. 3 6246' 70.80 100% Gas In Air =10,000 Units Connection Average -Background Mud (lb/bbl) ml/30min (max) C-3 9884' Chromatograph (ppm) 0 0 0 0 0 Cement C-1 C-5i Sh Siltst Lst Clyst C-4i - - Reciprocate Pipe PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type 8.75 0.902 Footage 40.0 Depth in / out 6242' 12.25 3050' 16130' 3035' Ss Cht Silt 100 Avg to 16130' Current MWD Summary Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) 16130' 16130' 0' Lime Tuff Gvl Surface 1-2-CT-T-X-IN-WT-TD 96% Date: % Alkal Coal Gallons/stroke 0 0 0 Minimum Depth 13.38'' Maximum in Lithology (%) 2 Bit # Depth Present 0.969 0 C-2 0 C-4n 0 Gas Summary (current) Units* (907) 685-0772 Unit Phone: 0 Greg Dellner Set At Size 178.9 X-65 Grade 140 23.0 Hours 34.70 Cly Hydril S63 L-80 Comments Intermediate 3196' Report By: 20.00'' 9.63'' Logging Engineers: Kori Jo Plowman / Greg Dellner (max) (current) BTC 0 0 . . * 24 hr Recap: Report By: 20.00'' 9.63'' Logging Engineers: Kori Jo Plowman / Greg Dellner (max) (current) BTC 0 0 140 23.0 Hours 34.70 Cly Hydril S63 L-80 Comments Intermediate 3196' (907) 685-0772 Unit Phone: 0 Greg Dellner Set At Size 178.9 X-65 Grade Gas Summary (current) Units* C-2 0 C-4n 0 Depth Present 0.969 0Minimum Depth 13.38'' Maximum in Lithology (%) 2 Bit # 0 0 0 % Alkal Coal Gallons/stroke 16130' 16130' 0' Lime Tuff Gvl Surface 1-2-CT-T-X-IN-WT-TD 96% Date: Time: API FL C-5n Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Avg to 16130' Current MWD Summary Ss Cht Silt 100 8.75 0.902 Footage 40.0 Depth in / out 6242' 12.25 3050' 16130' 3035' - - Run 4.5" Comp. Tubing PV cP 68.0 Weight Flow In (gpm) Flow In (spm) Type Cement C-1 C-5i Sh Siltst Lst Clyst C-4i 0 0 0 9884' Chromatograph (ppm) 0 0 Mud (lb/bbl) ml/30min (max) C-3 Average -Background 100% Gas In Air =10,000 Units Connection Recip. liner f/9,985' to 9,935'. R/U equip. P/U 3 jts 4.5" liner to 10,010'. C/O equip to 5" & clear floor. M/U packer. RIH Trip running tool. L/D 5" DP w/mousehole. R/U tbg equip. Run 4.5" comp tbg to 845'. Daily Brine loss: 62 bbls. 3 6246' 70.80 12 6.0 Size 160'Conductor Evermar PDC Casing Summary L-80 Bit Type 6246' WOB PDC TFA Condition 1-4-CT-A-X-IN-BT-TD RPM 28 Mud Type Brine Ratio Mud Data Depth 9.20 Oil / Water (lb/100ft 2) 4.23 @ Current Pump & Flow Data: Doyon 15 Report For: 16130' Cor Solids Avg Min YP Max ECD (ppg) Tools None ENI Petroleum Nikaitchuq Spy Island Job No.: Daily Charges: Total Charges: Rig Activity: Morning Report Report # 25 Customer: Well: Area: Location: Rig: SI07-SE4 11-Jun-2015 12:00 AM AK-AM-0902407754 ROP ROP (ft/hr) J. Keener / R. Wimmer 24 hr Max Max @ ft Density (ppg) out (sec/qt) Viscosity WELL INFORMATION Created On : Jul 09 2015 Customer :ENI Petroleum Well Name :SI07-SE4 Job Number :AK-XX-0902407754 Platform :SID 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 0.00 330.00 0.00 0.00 N 0.00 E 0.00 0.00 40.81 0.00 330.00 40.81 0.00 N 0.00 E 0.00 0.00 70.83 0.23 324.31 70.83 0.05 N 0.04 W -0.06 0.77 133.15 0.32 329.38 133.15 0.30 N 0.20 W -0.33 0.15 162.83 0.64 334.05 162.83 0.52 N 0.31 W -0.55 1.09 224.08 0.79 330.31 224.07 1.20 N 0.67 W -1.23 0.26 254.81 1.08 337.90 254.80 1.65 N 0.88 W -1.67 1.02 347.66 3.67 341.90 347.56 5.28 N 2.14 W -4.78 2.79 360.62 3.68 342.31 360.49 6.07 N 2.39 W -5.44 0.22 453.54 5.34 321.78 453.13 12.31 N 5.97 W -11.96 2.47 546.39 7.34 328.71 545.41 20.78 N 11.73 W -21.52 2.30 639.27 11.18 333.37 637.06 33.90 N 18.85 W -34.88 4.21 732.65 17.15 334.47 727.56 54.44 N 28.85 W -54.85 6.40 826.08 22.25 330.30 815.50 82.25 N 43.56 W -82.86 5.66 919.51 24.67 331.61 901.20 114.77 N 61.60 W -116.29 2.65 976.74 26.80 329.95 952.75 136.45 N 73.74 W -138.67 3.93 1070.17 30.90 331.05 1,034.57 175.69 N 95.91 W -179.34 4.42 1163.80 32.69 328.13 1,114.15 218.21 N 120.90 W -224.19 2.52 1256.70 33.65 328.97 1,191.91 261.57 N 147.41 W -270.78 1.15 1350.33 37.26 329.44 1,268.17 308.22 N 175.21 W -320.31 3.87 1443.30 40.12 329.99 1,340.73 358.40 N 204.50 W -373.09 3.10 1536.70 42.43 329.98 1,410.92 411.75 N 235.32 W -428.94 2.47 1630.16 42.72 329.52 1,479.74 466.37 N 267.18 W -486.36 0.46 1723.48 46.21 330.97 1,546.33 523.12 N 299.59 W -545.46 3.89 1816.84 45.13 330.34 1,611.57 581.34 N 332.31 W -605.66 1.25 1910.06 44.15 330.58 1,677.90 638.32 N 364.61 W -664.80 1.07 2003.36 44.11 330.56 1,744.87 694.90 N 396.53 W -723.40 0.05 2096.78 44.97 332.42 1,811.45 752.48 N 427.79 W -782.03 1.67 2190.09 45.97 336.79 1,876.91 812.55 N 456.29 W -839.83 3.51 2283.51 44.46 340.99 1,942.73 874.37 N 480.19 W -894.86 3.58 INSITE V8.1.10 Page 1Job No:AK-XX-0902407754 Well Name:SI07-SE4 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2376.88 44.88 343.16 2,009.13 936.81 N 500.38 W -947.22 1.69 2470.20 45.20 347.89 2,075.09 1,000.72 N 516.87 W -997.38 3.60 2563.25 45.63 352.34 2,140.43 1,065.97 N 528.23 W -1044.12 3.44 2656.59 45.37 355.56 2,205.86 1,132.16 N 535.25 W -1087.83 2.48 2749.93 44.96 0.74 2,271.69 1,198.27 N 537.40 W -1127.51 3.96 2843.33 43.64 6.40 2,338.56 1,263.32 N 533.38 W -1161.53 4.46 2936.62 43.95 12.87 2,405.94 1,326.91 N 522.57 W -1189.15 4.81 2968.89 44.40 14.97 2,429.08 1,348.73 N 517.16 W -1197.23 4.74 3067.99 43.72 17.90 2,500.31 1,414.82 N 497.68 W -1219.18 2.17 3104.55 44.17 20.25 2,526.63 1,438.79 N 489.39 W -1226.14 4.63 3198.03 46.01 26.51 2,592.66 1,499.47 N 463.09 W -1239.40 5.13 3291.40 50.98 32.85 2,654.55 1,560.07 N 428.38 W -1245.73 7.36 3384.72 53.67 40.24 2,711.63 1,619.28 N 384.39 W -1243.66 6.90 3478.18 55.25 44.24 2,765.97 1,675.55 N 333.26 W -1234.05 3.87 3571.56 58.85 44.87 2,816.75 1,731.37 N 278.29 W -1221.04 3.90 3664.94 61.36 45.22 2,863.29 1,788.56 N 221.01 W -1206.91 2.71 3758.27 61.27 46.17 2,908.08 1,845.75 N 162.41 W -1191.72 0.90 3851.75 60.63 49.07 2,953.48 1,900.83 N 102.06 W -1173.87 2.80 3945.10 59.60 53.37 3,000.01 1,951.52 N 39.00 W -1151.29 4.14 4038.49 59.44 58.24 3,047.40 1,996.73 N 27.54 E -1122.72 4.50 4131.80 58.13 61.00 3,095.77 2,037.09 N 96.36 E -1089.49 2.89 4225.12 57.04 63.12 3,145.79 2,074.01 N 165.95 E -1053.66 2.25 4318.50 55.93 67.40 3,197.37 2,106.59 N 236.62 E -1014.46 4.00 4411.93 55.03 71.93 3,250.34 2,133.35 N 308.77 E -970.71 4.11 4505.36 55.23 76.12 3,303.77 2,154.44 N 382.44 E -922.46 3.69 4598.62 57.75 82.06 3,355.28 2,169.08 N 458.74 E -868.36 5.96 4692.05 59.04 86.55 3,404.26 2,176.95 N 537.89 E -808.04 4.32 4785.37 58.68 90.99 3,452.54 2,178.67 N 617.71 E -743.63 4.09 4878.58 58.14 96.76 3,501.40 2,173.32 N 696.88 E -675.72 5.30 4971.83 58.84 102.29 3,550.16 2,160.16 N 775.23 E -603.98 5.11 5065.19 56.87 105.06 3,599.84 2,141.50 N 852.03 E -530.37 3.28 5158.58 58.03 109.05 3,650.10 2,118.40 N 927.26 E -455.50 3.81 5252.04 59.91 113.09 3,698.29 2,089.59 N 1,001.95 E -377.79 4.21 5345.36 61.59 117.52 3,743.90 2,054.78 N 1,075.52 E -297.56 4.52 5438.72 62.71 122.68 3,787.54 2,013.39 N 1,146.89 E -215.35 5.03 5531.89 63.29 124.56 3,829.84 1,967.42 N 1,216.01 E -132.37 1.90 5625.24 64.07 124.85 3,871.23 1,919.79 N 1,284.80 E -48.70 0.88 5718.66 64.24 124.04 3,911.95 1,872.23 N 1,354.13 E 35.37 0.80 5811.97 65.42 124.20 3,951.64 1,824.86 N 1,424.04 E 119.81 1.27 5905.39 69.04 123.43 3,987.79 1,776.94 N 1,495.60 E 205.92 3.95 5998.76 72.40 123.04 4,018.62 1,728.64 N 1,569.31 E 294.00 3.62 6092.08 76.83 122.54 4,043.37 1,679.93 N 1,644.93 E 383.88 4.78 6162.28 79.53 123.49 4,057.75 1,642.50 N 1,702.54 E 452.54 4.07 6262.38 83.31 125.20 4,072.68 1,586.66 N 1,784.24 E 551.50 4.14 6348.99 87.55 127.35 4,079.58 1,535.59 N 1,853.82 E 637.78 5.49 INSITE V8.1.10 Page 2Job No:AK-XX-0902407754 Well Name:SI07-SE4 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6375.45 88.02 128.67 4,080.60 1,519.31 N 1,874.65 E 664.19 5.29 6468.66 89.86 130.79 4,082.33 1,459.75 N 1,946.32 E 757.05 3.01 6562.06 90.72 131.01 4,081.85 1,398.60 N 2,016.91 E 849.96 0.95 6655.40 90.69 129.39 4,080.70 1,338.36 N 2,088.20 E 942.90 1.74 6748.85 89.64 128.01 4,080.44 1,279.93 N 2,161.13 E 1036.15 1.86 6842.25 90.71 127.74 4,080.15 1,222.59 N 2,234.85 E 1129.44 1.18 6935.64 89.84 127.19 4,079.70 1,165.78 N 2,308.98 E 1222.74 1.10 7028.97 91.08 127.17 4,078.95 1,109.39 N 2,383.33 E 1315.99 1.33 7122.08 90.64 127.59 4,077.56 1,052.87 N 2,457.31 E 1409.01 0.65 7215.48 88.82 126.38 4,078.00 996.68 N 2,531.91 E 1502.35 2.34 7308.95 88.90 126.99 4,079.85 940.85 N 2,606.85 E 1595.76 0.66 7402.33 86.25 126.73 4,083.81 884.89 N 2,681.49 E 1689.00 2.85 7495.53 85.02 126.14 4,090.90 829.70 N 2,756.26 E 1781.90 1.46 7588.83 86.43 126.71 4,097.85 774.46 N 2,831.12 E 1874.91 1.63 7682.11 89.36 127.09 4,101.28 718.49 N 2,905.65 E 1968.06 3.17 7775.34 89.79 126.21 4,101.97 662.84 N 2,980.45 E 2061.25 1.05 7868.63 88.85 126.57 4,103.08 607.50 N 3,055.54 E 2154.50 1.08 7962.01 88.60 125.81 4,105.16 552.38 N 3,130.88 E 2247.84 0.86 8055.41 88.77 125.66 4,107.30 497.84 N 3,206.68 E 2341.21 0.24 8148.93 90.40 126.56 4,107.98 442.73 N 3,282.23 E 2434.70 1.99 8241.85 90.09 125.82 4,107.58 387.87 N 3,357.22 E 2527.60 0.86 8335.35 89.78 125.75 4,107.69 333.19 N 3,433.07 E 2621.09 0.34 8429.59 90.55 125.50 4,107.41 278.30 N 3,509.67 E 2715.33 0.86 8523.09 89.10 125.91 4,107.70 223.74 N 3,585.59 E 2808.82 1.61 8615.48 89.53 126.07 4,108.80 169.45 N 3,660.34 E 2901.19 0.50 8708.71 89.65 125.58 4,109.47 114.88 N 3,735.93 E 2994.40 0.54 8802.00 90.21 126.06 4,109.59 60.28 N 3,811.58 E 3087.68 0.79 8895.37 91.91 125.54 4,107.86 5.68 N 3,887.29 E 3181.02 1.90 8988.74 92.01 125.40 4,104.67 48.47 S 3,963.29 E 3274.34 0.18 9082.23 90.97 124.61 4,102.23 102.08 S 4,039.84 E 3367.79 1.40 9175.40 90.21 125.64 4,101.27 155.68 S 4,116.03 E 3460.96 1.37 9268.85 89.24 125.17 4,101.72 209.82 S 4,192.20 E 3554.40 1.15 9362.17 89.33 125.33 4,102.89 263.68 S 4,268.40 E 3647.71 0.20 9455.58 89.17 125.01 4,104.11 317.48 S 4,344.76 E 3741.11 0.38 9548.92 89.30 125.14 4,105.36 371.11 S 4,421.14 E 3834.45 0.20 9642.30 87.96 124.46 4,107.59 424.39 S 4,497.79 E 3927.80 1.61 9735.68 88.40 126.49 4,110.56 478.55 S 4,573.80 E 4021.12 2.22 9828.95 89.32 127.53 4,112.41 534.68 S 4,648.26 E 4114.31 1.49 9922.30 89.10 127.48 4,113.70 591.51 S 4,722.31 E 4207.56 0.24 10015.71 89.92 127.04 4,114.50 648.06 S 4,796.65 E 4300.90 1.00 10109.04 90.70 126.55 4,113.99 703.96 S 4,871.38 E 4394.18 0.99 10202.36 91.10 126.32 4,112.53 759.38 S 4,946.45 E 4487.46 0.49 10295.71 90.04 126.28 4,111.60 814.64 S 5,021.68 E 4580.78 1.14 10389.03 88.95 125.24 4,112.42 869.17 S 5,097.40 E 4674.08 1.61 10482.39 87.86 126.43 4,115.02 923.81 S 5,173.06 E 4767.39 1.73 INSITE V8.1.10 Page 3Job No:AK-XX-0902407754 Well Name:SI07-SE4 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10575.74 87.91 125.90 4,118.46 978.85 S 5,248.37 E 4860.66 0.57 10669.15 89.63 126.55 4,120.47 1,034.04 S 5,323.70 E 4954.02 1.97 10762.57 89.30 126.53 4,121.34 1,089.66 S 5,398.76 E 5047.41 0.35 10855.88 89.99 126.51 4,121.92 1,145.19 S 5,473.74 E 5140.68 0.74 10949.23 90.13 125.92 4,121.82 1,200.34 S 5,549.06 E 5234.01 0.65 11042.56 89.89 124.80 4,121.81 1,254.35 S 5,625.17 E 5327.34 1.23 11135.91 89.56 124.24 4,122.25 1,307.25 S 5,702.08 E 5420.68 0.70 11229.29 91.28 124.87 4,121.57 1,360.21 S 5,778.98 E 5514.05 1.96 11322.70 90.25 125.96 4,120.32 1,414.33 S 5,855.10 E 5607.45 1.61 11416.08 91.11 125.46 4,119.21 1,468.83 S 5,930.92 E 5700.81 1.07 11509.50 91.22 125.10 4,117.31 1,522.78 S 6,007.17 E 5794.21 0.40 11602.86 92.09 124.82 4,114.62 1,576.25 S 6,083.65 E 5887.53 0.98 11696.21 92.13 122.53 4,111.18 1,627.98 S 6,161.27 E 5980.79 2.45 11789.62 91.97 124.20 4,107.84 1,679.31 S 6,239.24 E 6074.10 1.79 11882.95 90.97 124.11 4,105.45 1,731.69 S 6,316.44 E 6167.39 1.08 11976.34 91.38 126.13 4,103.53 1,785.41 S 6,392.81 E 6260.75 2.21 12069.72 91.58 126.76 4,101.12 1,840.86 S 6,467.90 E 6354.07 0.71 12163.03 90.65 126.25 4,099.30 1,896.36 S 6,542.89 E 6447.33 1.14 12256.52 89.10 125.60 4,099.51 1,951.21 S 6,618.59 E 6540.80 1.80 12349.87 89.52 126.13 4,100.63 2,005.90 S 6,694.24 E 6634.13 0.72 12443.29 90.16 126.72 4,100.89 2,061.37 S 6,769.41 E 6727.52 0.93 12536.68 90.47 127.22 4,100.38 2,117.53 S 6,844.02 E 6820.86 0.63 12630.16 90.50 126.86 4,099.59 2,173.84 S 6,918.63 E 6914.27 0.39 12723.66 90.11 126.87 4,099.09 2,229.93 S 6,993.44 E 7007.72 0.42 12817.39 88.91 126.73 4,099.89 2,286.07 S 7,068.49 E 7101.40 1.29 12910.31 88.01 126.54 4,102.39 2,341.50 S 7,143.02 E 7194.25 0.99 13003.69 87.92 125.78 4,105.70 2,396.56 S 7,218.37 E 7287.55 0.82 13097.07 88.03 125.76 4,109.00 2,451.11 S 7,294.08 E 7380.86 0.12 13190.40 89.66 126.97 4,110.88 2,506.43 S 7,369.22 E 7474.14 2.17 13283.88 89.23 128.39 4,111.79 2,563.57 S 7,443.20 E 7567.51 1.59 13377.23 90.17 128.12 4,112.28 2,621.37 S 7,516.50 E 7660.71 1.05 13470.62 89.04 127.49 4,112.92 2,678.61 S 7,590.28 E 7753.99 1.39 13563.93 90.16 127.11 4,113.57 2,735.15 S 7,664.51 E 7847.22 1.27 13657.25 89.79 126.99 4,113.62 2,791.38 S 7,738.99 E 7940.48 0.42 13750.63 90.24 125.76 4,113.59 2,846.76 S 7,814.17 E 8033.83 1.40 13844.06 89.36 125.24 4,113.92 2,901.01 S 7,890.23 E 8127.25 1.09 13937.49 90.34 124.86 4,114.16 2,954.67 S 7,966.72 E 8220.68 1.12 14030.75 88.31 122.92 4,115.26 3,006.66 S 8,044.12 E 8313.91 3.01 14124.18 89.21 122.89 4,117.28 3,057.40 S 8,122.54 E 8407.25 0.96 14217.50 90.16 123.01 4,117.80 3,108.16 S 8,200.85 E 8500.51 1.03 14310.71 92.13 123.74 4,115.93 3,159.42 S 8,278.67 E 8593.66 2.25 14403.96 92.80 123.92 4,111.92 3,211.29 S 8,356.06 E 8686.80 0.74 14497.32 91.64 124.89 4,108.31 3,264.00 S 8,433.02 E 8780.08 1.62 14590.71 89.00 122.58 4,107.78 3,315.86 S 8,510.68 E 8873.44 3.76 14684.17 92.16 123.65 4,106.84 3,366.91 S 8,588.94 E 8966.83 3.57 INSITE V8.1.10 Page 4Job No:AK-XX-0902407754 Well Name:SI07-SE4 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14777.49 91.37 124.41 4,103.96 3,419.10 S 8,666.24 E 9060.09 1.17 14870.85 92.16 125.80 4,101.09 3,472.77 S 8,742.58 E 9153.40 1.71 14964.02 91.28 125.55 4,098.29 3,527.08 S 8,818.23 E 9246.52 0.98 15057.37 90.72 125.50 4,096.66 3,581.31 S 8,894.19 E 9339.85 0.60 15150.79 91.22 125.36 4,095.08 3,635.46 S 8,970.30 E 9433.26 0.56 15244.10 91.10 124.43 4,093.19 3,688.83 S 9,046.82 E 9526.55 1.00 15337.52 91.74 124.92 4,090.88 3,741.96 S 9,123.62 E 9619.94 0.86 15430.89 91.78 125.70 4,088.01 3,795.90 S 9,199.78 E 9713.26 0.84 15524.21 91.68 125.63 4,085.19 3,850.29 S 9,275.56 E 9806.53 0.13 15617.26 92.16 127.27 4,082.07 3,905.54 S 9,350.37 E 9899.50 1.84 15710.60 92.25 127.90 4,078.48 3,962.42 S 9,424.28 E 9992.67 0.68 15803.94 91.60 127.76 4,075.35 4,019.64 S 9,497.96 E 10085.84 0.71 15897.34 91.18 127.18 4,073.08 4,076.44 S 9,572.07 E 10179.13 0.77 15990.63 88.31 126.06 4,073.50 4,132.08 S 9,646.93 E 10272.37 3.30 16061.94 89.03 126.14 4,075.15 4,174.09 S 9,704.53 E 10343.65 1.02 16130.00 89.00 126.32 4,076.32 4,214.31 S 9,759.43 E 10411.68 0.27 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 125.00 degrees (True) - A total correction of 18.96 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 16,130.00 feet is 10,630.46 feet along 113.36 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 5Job No:AK-XX-0902407754 Well Name:SI07-SE4 Survey Report