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215-097
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c J 5 - 097 Well History File Identifier Organizing(done) ❑ Two-sided 0 Rescan Needed RES AN: OVERSIZED: NOTES: Color Items: ❑ Map tGrayscale Items: ogs: 0 Poor Quality Originals: ❑ Other: 0 Other: BY: AM Date: 1 I lac)/ F ✓ /s/ VII P Project Proofing c."VlBY: Maria Date: I IGI o f IS /s/ Scanning Preparation x 30 = 940 + = TOTAL PAGES J IS' (Count does not include cover sheet) BY: Maria Date: I ` go is- /s/ Production Scanning Stage '1 Page Count from Scanned File: 1 1 (0 (Count does include cove sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Mari ) _ Date: I I I aQ fa— /s/ gilf Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 410 NO TOTAL PAGES: --T 2 Digital version appended by: Meredith ,k6Michal Date: 1 2.1 ` `5.-- /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: I, q 8 Scanning is complete at this point unless rescanning is required. 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N c z O C 2 = N ,> E E Z aai N w m w .` rn N CO U 0 w Fa a) 0 0 u) c CD a3 O co— .., V o rn ` g o o p QU 71 a) L • - v a .3 o a a E Q UO N y 0 3 Z o O` N 0 O o G O O a. 2 o 0 a C7 0 0 a 1 O 1 0 • 6215078 215097 26114 26115 HAL_LI BURTON - DATA LOGGED t?/2015 M.K.BENDER Sperry Drilling RECEWED To: Alaska Oil and Gas Conversation Commission 333 W 7th Ave Suite 100 AUG 14 2015 Anchorage, AK 99501 Attn: Meredith Guhl AOGCC 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 — SP04-SE7 &SP04-SE7 L1 AFE # 6464 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 Med2a41414) Sign Name Date Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. STATE OF ALASKA ... ALASOPOIL AND GAS CONSERVATION COMMISN AUG 0 7 2015 WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 . Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ , Exploratory ❑ GINJ ❑ WINJ WAGE WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,SuAp., or MU 14. Permit to Drill Number/ Sundry: ENI US Operating Co. Inc. Aband.: 7/.772015 215-097 3.Address: 7. Date Spudded: AAIT 15.API Number: 3800 Centerpoint Drive, Ste. 300,Anchorage,AK 99503 7/x/2015 50-629-23542-60-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number Surface: 4489.1 FSL 1170.6 FEL S19 T14N R9E UM 7/15/2015 SP01-SE7 L1 . Top of Productive Interval: 9. KB(ft above MSL): .53.6 17. Field/Pool(s): 3815 FSL 2693 FEL 17 T14N R9EUM GL(ft above MSL): ,,13.08 Nikaitchuq/Schrader Bluff Oil Pool . Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 3742 FSL 551 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- 511739.02 y- 6053671.08 Zone- 4 ,19,093'MD/4,163'TVD ADL 417493 TPI: x- 515471.68 y- 6058283.07 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 522921.48 y- 6052950.31 Zone- 4 N/A 2,000'MD/1,783'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) AI4 k. qj 151':no%-ti s7t'" 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 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 178.89 X-65 36.85 160 36.85 160 Driven N/A N/A 13.375 68 L-80 36.85 3577 36.85 2502 16 10.7 ppg : 518 bbls N/A 12.5 ppg :68 bbls 9.625 40 L-80 35.53 10148 35.53 4169 12.25 12.5 ppg : 163.6 bbls N/A 15.8 ppg : 57.2 bbls 5.5 15.5 L-80 9864 19065 4149 4163 8.75 Slotted Liner 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 9,406 N/A Slotted Liner , 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. ( Was hydraulic fracturing used during completion? Yes❑ No 0 6' , Per 20 AAC 25.283(i)(2)attach electronic and printed information I tip ,;, , , ,; DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing,gas lift,etc.): Planned on September 1st.Waiting for Packer swelling. ESP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 24h Test Period -Ow. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): 24-Hour Rate f- is 1S-0 4&7 Rcvi3cd:./x&15 ....t COWTI4d4E-B ON f 2Npmit ORICINIAL oily /" ' 77 °' 1 ���� �l��lls- RDDMS AUG 1 4 20150 28.CORE DATA Conventional Core(s Yes ❑ No ❑✓ Sidewall Cores: • _f No ✓j If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,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 E Permafrost-Top surf surf If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 2000 1783 Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Top Ugnu 2844 2289 Top Lower Ugnu 7488 3638 Top Schrader Bluff 8556 3959 Top N sand 8848 4022 Top OA Sand 10035 4162 Formation at total depth: OA Sand 19093 4162 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 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&Completion Engineering Manager Signature Phone: (907)865-3328 Date: 8/5/2015 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 1 a: 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 Z 0_N N w W ✓ ' P o y W O c 0 m co V 0 0 A W N -+ 7C w 01 CO = {a, -1 v Q y O CO O w co ° < O (n. m Oorn .p m wg 00005 (D OD O (31 o cp o *k -+ W W WAAAaf VCO0 I-- -0U) / / I 1 1 0) 0ow� cno � wenra, 5. m p n X � `< N co V co V t0 i0 V A N Or N D 37 Ca NEC cl; .\\ O — -- (D I"" < / Q wN pp = (D i ° \ `/ (0 w 5 3(Q - �� \\I = W (0 0) WxV pp0 * ` i v T - = O0 (O 13 em (D v T -, O - D 0i a3 (1,) ,z \ Cfl 7 > (D ....ih (n TIO CO O D n N N (n O G 5- CD (D w N u). v O O CD ` I O (n 2 (D O _' N Cn / (p N , p 0 c p x- �' p -O 0, s** ,10, cc r - p 0 - CD <co —(Q U)- -0 p. pi) {ate m (D O N + CD O o G v U)-...4 -0 c_, A*) I ` /....‘`...1..'''''.. N w CO m 0 It N N v n N L CO O co y Q * m y CD C H --1 p- m ° 0 —1 0 ao 5 .4 ' F (D ? w G < O 3 N < s` m t0 w F. Q- O (Q D p '— G 0 OD �n c� m I x -a is a)`< co = m r o p 0 opoo � � � D 0 IP. 0 3 � w v o CD . 6 Q Off I fm u) � O. v Q CD (C)o 01 X OBD _ e ". CD I * in LT = pp cp = -0 0 p (D N Cn o"< � 0 0 N -0 r 0 -o m \ � X v \ oo v Iy coou - c5- 0 c - o * nQ CD c. Cr) cn m cn 0 CD x -, W cn I 01 Os CT w c 0 m " " ' I ES) c� r Cn o - Q_ co w W v' r o Q w 0 N p CD cn 0 0 X CO-0 TJ ' Cl) (D 0 o ON to_ v \ CP "O v D _ _ CD 41' r- ((D 0 Cn \ w �' O 4 o AK 03 I I y H 3 v W r� (D r I I s m r 5. o O o N m I _ W 73 ` coW CD o0 o - Cn 1 'co I I O < o • a71 5 -o. (Du' m -4 n = '"'' 11 om I I_ I I � �, � � No Mo —S . .. O OZ N = V+ ^? I 1 • Z I Ir 0 0 N � -D .ocn rri o < �, , I oCO -� 1 1 _ L• c CI cD =1; CI C p O co EL elli 0,0 N W co C)s of p O 5 _i w CD (D n < -I 0 0 01 Eni E&P Division • Well Name: E7 L1 lifY* ENI Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUO • Date:7/7/2015 - Re ort#: 1 API/UWI:50-629-23542-60-00 " " p page 1 of 1 Wellbore name: SP01-SE7 L1 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) 16.31 3 99 11.14 6.66 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) SP01-5E7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 -0.75 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 99.0 02 Cloudy ENE @ 40 MPH Daily summary operation 24h Summary RIH 5.5"Liner and MKZXP W/5"D.P.F/11,090'to 19,090'MD HST 235K,SLK 85K.No losses.Orient MLZXP Hanger to 38°Left as per Schlumberger MWD&DD.Setting depth 19,157'MD.Pull tension to Hook Load 220K.Witnessed by Co Rep,Baker Reps,Schlumberger DD and MWD onsite.As per Baker Rep onsite,drop 1.625"ball.Pump down @ 95 GPM,380 PSI.,ball seat @ 156.8 bbl away.Press.up to 500 PSI,increase to 2,200 PSI to set Hanger.SLK to 70K Block Wt.Press.up to 2,600 PSI to activate Pusher Tool and set MLZXP.Stage up to 3,500 PSI to release running tool. Press.up to 4,050 PSI to neutralize Pusher Tool.Test Annulus 9 5/8"X 5.5"to 1,500 PSI for 15 Min.All charted.Witnessed by Co Rep onsite.Tag TOL @ 9,999'MD.Pump out 1 stand 5"D.P.@ 3 bpm, 130 PSI to 10,017'MD.POOH 5"D.P.and running tool on Elevators F/10,017'to 9,550'MD.HST 195K,SLK 125K.No losses.Pump 25 bbl 10.9 ppg slug in 5"D.P.Cont.to POOH 5"D.P.on Elevators F/9,550'to 122'MD.HST 200K.PJSM W/all essential personnel for laying down running Assy.UD String Magnets W/about only 5 lb of cut metal recovered from well.UD Liner running tools and Slim Pulse as per Baker,Co Rep and Schlumberger DD and MWD onsite.Clean rig Boor.UD Baker Liner running tools.P/U Baker Whipstock and components and Schlumberger MWD tools as per Baker and Schlumberger Reps onsite.Service and lubricate rig.PJSM W/all essential personnel for picking up Whipstock and MWD.P/U M/U 150'MD Whipstock and MWD BHA.Orient MWD to Whipstock as per Schlumberger DD and MWD and Baker Rep onsite.Verified by Co Rep onsite. Operation at 07.00 RIH Whipstock BHA on 5"D.P.to 4,343'MD. 24h Forecast PJSM W/all essential personnel for Whipstock BHA.P/U M/U 8 1/2"Window Mill to 9 5/8"Gen II Whipstock Slide W/35K Shear Bolt as per Baker Rep onsite.Verified by Co Rep onsite.RIH Whipstock on 5"D.P.and shallow hole lest MWD.Cont.to RIH to 9,100'MD.Slip and cut drilling line.Cont.to RIH and orient Whipstock at 9,999'MD.W/all parties involved on site.Mill Window as per Baker Rep onsite.POOH and UD running Assy.Test BOPE. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 18:00 19:00 1.00 1.00 DRILL G 20 P PJSAP/U Baker Whipstock and components and Schlumberger MWD tools as per Baker and Schlumberger Reps onsite. 19:00 20:00 1.00' 2.00 DRILL 'G 25 P Service and lubricate ng. 20:00 00:00 4.00 6.00 DRILL G -20 •P PJSM W/all essential personnel for picking up Whipstock and MWD.P/U M/U 150'MD Whipstock and MWD BHA.Orient MWD to Whipstock as per Schlumberger DD and MWD and Baker Rep onsite.Verified by Co Rep onsite. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 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 Paul Holley ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.cow 907-980-7545 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') Eni E&P Division • Well Name: E7 L1 ENI Petroleum Co.Inc. Daily Re p o t..}L Well Code:27978 Field Name:NIKAITCHUQ enri Date:7/8/2015 - Report#: 2 API/UWI:50-629-23542-60-00 'I I' page 1 of 1 Wellbore name: SP01-SE7 L1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(FL) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.31 3.99 11.14 6.66 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) SP01-SE7 L1 DRILLING 7/8/2015 5.876.54 2.779.47 73.68 37.7 0.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,049.83 1268.02 9.75 0.50 19.5 102.0 1.1 Cloudy WC 25` NE @ 14 MPH Daily summary operation 24h Summary M/U Milling assy.to Whipstock and RIH 617'and perform SHT.Cont.to RIH to 9111'and Cut&Slip 119'drill line and inspect brakes.RIH to 9556'and Orient Whipstock to 17L,work to 9999'and latch into liner top.Shear mill assy.wd 40k dwn,15k over pull and sheared @ 35k dwn.Mill window f/9957'-9974'and dress window as required.Pump 2-Hi-Vis sweeps.Drill rathole to 10,006'and pump sweep.BROOH f/10,006'-9897'.100 lbs of metal recovered.Pump dry job and POOH to 98'.L/D Milling assy.to 52'. Operation at 07.00 Testing BOPE. 24h Forecast Complete L/D Baker Milling assy.M/U and clean out stack.R/U and test BOPE as per AOGCC specs w/4.5"&5"test jts.Witness waived by Lou Grimaldi.M/U 8.75"drilling assy.and RIH and perform SHT.Cont.to RIH to top of window@ 9957'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11264 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 4 P PJSA M/U Mill assy.to Whipstock as per Baker.RIH to 154'. 00.30 01:00 0.50 1.00 DRILL E 12 P PJSA RIH w/Whipstock/Milling assy.to 617'.Perform shallow hole test @ 350 gpm,340 psi. 01:00 07:00 6.00 7.00 DRILL E 4 P PJSA RIH 6 617'-9111',185k puw,125k sow,fill pipe every 2000'. 07:00 08:30 1.50 8.50 DRILL E 25 P PJSA Cut and slip 119'of drill line,inspect brakes. 08:30 09:00 0.50 9.00 DRILL E 4 P PJSA RIH f/9111'-9556'. 09:00 10:30 1.50 10.50 DRILL E 19 P PJSA Orient Whipstock as per Baker/SLB to 17L @ 9999'.Set down 10k down,pull 10k over to confirm latched.Shear out by 40k dwn,15k over pull and sheared @ 35k awn. 10:30 12:00 1.50 12.00 DRILL E 14 P PJSA Milling window as per Baker @ 9957'@ 425 gpm,1210 psi,90 rpm,10-15k tq,182k puw,130k sow,150k rotes. 12:00 18:00 6.00 18.00 DRILL E 14 P PJSA Mill window as per Baker f/9957'to 9974'@ 430 gpm,1230 psi,90-100 rpm,9-12k tq,1-5k wob,pump 2-hi-vis sweeps.Dress window as required.Pull through window w/pumps off,190k puw,122k sow.Cean out rat hole 6 9974'- 10,006'and pump sweep.BROOH f/10,006'-9897'@ 430 gpm,1230 rpm.100 lbs of metal recovered. 18:00 22:30 4.50 22.50 DRILL E 4 P PJSA Monitor well 6 10 min.POOH f/9897'-9523',200k puw,122k sow.Pump dry job and POOH to 98'. 22:30 00:00 1.50 24.00 DRILL E 4 P PJSA L/D milling assy.f/98'-52'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Matls Coordinator Eni representative Paul Holley ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-960-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date 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') • • Eni E&P DivisionWell Name: E7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27978 • Field Name:NIKAITCHUQ ,re^n` Date:7/9/2015 - Report#: 3 APIIUWI:50-629-23542-60-00 'I I" page 1 of 1 Wellbore name: SP01-SE7 L1 • 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) 16.31 3.99 11.14 6.66 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Pha.se Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP01-SE7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 1.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,049.83 1.268.02 0.00 101.0 1.1 Clear NE @ 16 MPH Daily summary operation 24h Summary Milling Assy as per Baker Rep onsite.Window in gauge.P/U stack washer and X/O.Wash BOPE 80 ROM,8 BPM.LID stack washer.Clean and clear rig floor of Mill BHA.Pull Wear Bushing and set test plug as per Vetco Grey Rep onsite.R/U test Equip for BOPE and flood all lines W/H2O.Test BOPE.R/D all test Equip.Blow down lines and Choke Manifold.Clean and Gear ng floor.Pull test plug and set Wear Bushing as per Vetco Grey Rep onsite.(9.0"ID)PJSM W/all essential personnel for P/U BHA#6.P/U M/U 8.75"BHA#6 and load Nuclear source as per Schlumberger DD and MWD onsite.to 368'MD.RIH to 1500'and perform SHT.Cont to RIH to 9192'.Rig repair;C/O Top-Drive RLA. Operation at 07.00 Install replacement RLA. 24h Forecast Complete R/D RLA and install replacement,inspect and test.Cont.to RIH and cleanout hole to 10,006'.CBU and pull pipe to inside of window.Perform LOT/FIT.Drill ahead as per SLB. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 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 PJSA L/D Milling Assy as per Baker Rep onsite.Window in gauge. 00:30 01:00 0.50 1.00 DRILL C 20 P PJSA P/U stack washer and X/O.Wash ROPE 80 ROM,8 BPM.L/D stack washer. 01:00 01:30 0.50 1.50 DRILL E '20 P 'PJSA Clean and clear rig floor of Mill BHA. 01:30 02:30 1.00 2.50 DRILL C 5 P PJSA Pull Wear Bushing and set test plug as per Vetco Grey Rep onsite. 02:30 03:30 1.00 3.50 DRILL C 20 P PJSA R/U test Equip for BOPE and flood all lines W/H2O. 03:30 08:30 5.00 8.50 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 1,500 PSI,System 3,000 PSI,Annular 700 PSI,after function:Manifold 1,500 PSI, System 1,500 PSI,Annular 700 PSI.200 PSI increase in 43 Sec.Full charge 206 Sec.5 Nitrogen average 2,400 PSI. AOGCC witnessed waived by Louis Grimaldi 7-8-15 11:26 am. 08:30 09:00 0.50 9.00 DRILL C 20 P PJSA R/D all test Equip.Blow down lines and Choke Manifold.Clean and clear rig floor. 09:00 09:30 0.50 9.50 DRILL C 5 P PJSA Pull test plug and set Wear Bushing as per Vetco Grey Rep onsite.(9.0"ID) 09:30 12:00 2.50 12.00 DRILL E 20 P PJSM W/all essential personnel for P/U BHA#6.P/U M/U 8.75"BHA#6 and load Nuclear source as per Schlumberger DD and MWD onsite.to 368'MD. 12:00 16:00 4.00 16.00'DRILL E 4 P PJSA RIH f/368'-1500'and perform shallow hole test @ 400 gpm,760 psi.Cont.to RIH to 9192',180k puw,122k sow. 16:00 00:00 8.00' 24.00 DRILL E 25 TR04 PJSA Rig Repair;C/O RLA on Top-Drive.Install FOSV in drill string,load top-drive table to rig floor and assemble,prep. IBOP valve for removal,remove top-drive quill assy,link tilt yoke,pipe handler and shot pin assy. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Malls Coordinator Eni representative Paul Holley ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOtf(kgf/cm') Eni E&P Division • Well Name: E7 L1 ENI Petroleum Co.Inc. Daily Report` Well Code:27978 Field Name: NIKAITCHUQ • Date:7/10/2015 - Report#: 4 API/UWI:50-629-23542-60-00 e" page 1 of 1 Wellbore name: SPO1-SE7 L1 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) 16.31 3.99 11.14 6.66 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) SP01-SE7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 2.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,049.83 1268.02 0.00 104.0 1.1 Mostly Cloudy E@ 7 MPH Daily summary operation 24h Summary CIO RLA on top-drive.R/D old RLA and install replacement RLA and R/U same.31 hrs total repair time.RIH f/9192'-9480'.C/O handling equipment f/4.5"to 5". Operation at 07.00 Dolling ahead in Lateral @ 10,037'MD 24h Forecast Fill pipe and work down to 9997'.CBU and pull into window and perform FIT/LOT.Drill ahead as per SLB. Lithology Shows MAASP(kgf/cm') Mud Weight(gWL) 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 25 TR04 PJSA 0/0 RLA on Top-Drive;Remove load ring retainer and load ring,remove all hoses on upper RLA and cap,drain gear lube f/top-dove housing,unbolt RLA f/top-drive and remove. 06-.00 08:00 2.00 8.00 DRILL E 25 TR04 PJSA Dress replacement RLA and prep.top-dove for installation. 08:00 12:00 4.00 12.00 DRILL E 25 TR04 PJSA Install RLA,load collar,shot pin assy.and fill gear case. 12:00 18:00 6.00 18.00 DRILL E 25 TR04 PJSA Cont.w/shot pin assy,R/U hydraulic lines,install motor alignment cylinder,back up wrench assy.and IBOP valves. 18:00 23:00 5.00 23.00 DRILL E 25 TR04 PJSA Install tool joint locks,IBOP actuator,link tilt yoke.Remove work platform and L/D. 23:00 00:00 1.00 24.00 DRILL E 4 P PJSA RIH f/9192'- 9480',190k puw,120k sow CIO handling equipment f/4.5"to 5". Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Malls Coordinator Eni representative Paul Holley ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 3,040.08 1,267.45 OBM 1126.4 55.5 1564.6 198.2 04040 1 1, Eni E&P Division • Well Name: E7 L1 EN/Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUQ enn Date:7/11/2015 - Report#: 5 APIIUWI:50 629-23542-60-00 'I f'II page 1 of 1 wellbore name: SP01-SE7 L1 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) 16.31 3.99 11.14 6.66 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) SP01-5E7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 325 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 3,619.20 1,280.31 569.37 12.98 43.9 105.0 1.1 Cloudy NE @ 17 MPH Daily summary operation 24h Summary RIH f/9480'-9995',CBU and perform FIT to 13.0 EMW.Wash&ream to 10,006'.Drlg.ahead f/10,006'-11,874'MD(4201'TVD). Operation at 07.00 Drilling @ 12,400'MD 24h Forecast Drill lateral f/11,874'as per SLB/Geologists. Lithology Shows MAASP(kgf/cm2) Mud Weight(gIL) 1132.4 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 4 P PJSA RIH f/9480'-9995',190k puw,125k sow. 00.30 01:30 1.00 1.50 DRILL E "7 P PJSA CBU and condition mud @ 432 gpm,2100 psi,190k puw,125k sow. 01:30 03:00 1.50 3.00 DRILL E 9 P PJSA Pull 1 stand and rack back.R/U and perform FIT to 13.0 EMW by pumping in to 790 psi.B/D&R/D from testing. 03:00 03:30 0.50 3.50 DRILL E 6 P PJSA Wash and ream f/9945'-10,006'.SPRs @ 9942'MD(4155'ND)w/9.4 MW;#1/#3 @ 20-200,@ 30-280. 03:30 12:00 8.50 12.00 DRILL E 3 P PJSA Ddg.f/10,006'-10,690'MD(4168'ND)@ 555 gpm,3040 psi,40-140 rpm,8-12k wob,13-15k tqn,10-11k tqf, 190k puw,112k sow,152k rotw,10.70 ECD,Max Gas 2036,5.40 ADT/Bit,56.50 Jars. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Orig.f/10,690'-11,406'MD(4195'ND)@ 550 gpm,3100 psi,140-180 rpm,2-12k wob,14k tqn,12k tqf,210k puw,100k sow,150k rotw,10.76 ECD,Max Gas 2737,3.95 ADT,9.35 Bit,60.45 Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Orig.f/11,406'-11,874'MD(4201'ND)@ 550 gpm,3150 psi,140-180 rpm,2-14k wob,15k tqn,11k tqf,205k puw,105k sow,150k rotw,10.77 ECD,Max Gas 2065,3.63 ADT,12.98 Bit,64.08 Jars.SPRs @ 11,811'MD(4201'ND) w/9.45 MW;#1/#2/#3 @ 20-210,@ 30-290. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 En:representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Matls Coordinator Eni representative Paul Holley ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date 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) 3,040.08 1,267.45 OBM 1126.4 55.5 1564.6 198.2 .3.., Eni E&P Division . Well Name: E7 Li ENI Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUQ • 2^n Date:7/12/2015 - Report#: 6 API/UWI:50-629-23542-60-00 II II II page 1 of 1 Wellbore name: SP01-SE7 L1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(FI) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.31 3.99 11.14 6.66 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) SP01-SE7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 4.25 Daily Information i End Depth(mKB) I End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,140 40 1.267.07 521.21 16.87 30.9 105.0 2.8 Overcast NE @ 22 MPH Daily summary operation 24h Summary Drill 8.75"Lateral f/11,874'-13,584'MD(4157'TVD).Control drill f/13,375'-13,584'©30'/hr as per program. Operation at 07.00 Controlled Drilling @ 13,685'MD 24h Forecast Control drill @ 30'/hr f/13,584'-13,800'as per program,then drill ahead as per SLB. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1132.4 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/11,874'to 12,559'MD(4,201'TVD)550 GPM,3,270 PSI,140-180 RPM,TON 14-15K, TQF 14-15K,WOB 6-14K,HST 210K,SLK 100K,ROT 153K,ECD 10.96 ppg W/9.45 ppg MW.Max Gas 2,065 units.ADT 3.93,Bit Hrs 16.91,Jar Hrs 68.01.Monitor well,static. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/12,559'to 13,051'MD(4,175'ND)550 GPM,3,340 PSI,140-180 RPM,TON 16-17K, TOF 13-14K,WOB 6-14K,HST 220K,SLK 82K,ROT 151 K,ECD 11.23 ppg W/9.45 ppg MW.Max Gas 1,831 units.ADT 3.70,Bit Hrs 20.61,Jar Hrs 71.71.Monitor well,static. SPR @ 12,930'MD(4,186'ND)W/9.45 ppg MW MP#1 20-250,30-340 MP#2 20-250,30-340 MP#3 20-250,30-340 12:00 18:00 6.00 18.00 DRILL E 3 P 'PJSA Ddg.f/13,051'-13,453'MD(4155'ND)@ 550 gpm,3250 psi,140 rpm,2-14k wob,15k tqn,13k tqf,235k puw, N/A sow,150k rotw,11.13 ECD,Max Gas 142,4.94 ADT,25.55 Bit,76.65 Jars.Note;@ 13,350'started control drilling @ 30'/hr as per program for close encounter to 13,800'. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Control drill f/13,453'-13,584'MD(4157'ND)@ 550 gpm,3250 psi,140 rpm,2-4k wob,15-17k tqn,14-16k tqf, 225k puw,N/A sow,150k rotw,11.01 ECD,Max Gas 21,4.3 ADT,29.85 Bit,80.95 Jars.SPRs @ 13,523'MD(4156'ND) WI 9.45 MW;#1/#2/#3 @ 20-230,@ 30-320. Daily Contacts Position Contact Name Company Title i E-mail Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Matls Coordinator Eni representative Paul Holley ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.corn 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date 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') 3,040.08 1,267.45 OBM 1126.4 55.5 1564.6 198.2 troos. Eni E&P Division S Well Name: E7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUQ • Date:7/13/2015 - Report#: 7 API/UWI:50-629-23542-60-00 �" " p page 1 of 1 Wellbore name: SP01-SE7 L1 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) 16.31 3.99 11.14 6.66 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) SP01-5E7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 5.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,567.43 1,276.93 427.02 17.75 24.1 103.0 22 Overcast N @ 6 MPH Daily summary operation 24h Summary Control drill at 30'/hr f/13,584'-13,800'.Drill ahead in Lateral with regular parameters f/13,800'-14,985'MD(4191'TVD). Operation at 07.00 Drilling ahead in Lateral @ 15,639'MD 24h Forecast Drill ahead in Lateral as per SLB to an Est.TD of 19,100'+/-. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 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 Control drill @ 30'ft/hr 8.75"Production hole F/13,584'to 13,744'MD(4,156'ND)550 GPM,3,330 PSI,140-170 RPM,TQN 14-15K,TQF 13-14K,WOB 2-4K,HST 235K,SLK N/A,ROT 152K,ECD 11.13 ppg W/9.45 ppg MW.Max Gas 21 units.ADT 5.16,Bit Hrs 35.01,Jar Hrs 86.11.Monitor well,static. Taking surveys every 33'during control drilling. 06.00 1200 6.00 12.00 DRILL E 3 P PJSA Control drill @ 30'R/hr 8.75"Production hole F/13,744'to 14,145'MD(4,155'ND)550 GPM,3,350 PSI,140-180 RPM,TQN 16-17K,TQF 14-15K,WOB 2-14K,HST 245K,SLK N/A,ROT 152K,ECD 11.41 ppg W/9.45 ppg MW.Max Gas 40 units.ADT 3.59,Bit Hrs 38.6,Jar Hrs 89.7.Monitor well,static.Taking surveys every 33'during control drilling. SPR @ 14,052'MD(4,155'ND)W/9.45 ppg MW MP#2 20-240,30-330 MP#3 20-240,30-330 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Ddg.f/14,145'-14,562'MD(4179'ND)@ 550 gpm,3400 psi,140-160 rpm,2-12k wob,16k tqn,13k tqf,252k puw,N/A sow,152k rotw,11.31 ECD,Max Gas 785,4.52 ADT,43.12 Bit,94.22 Jars. 18.00 00:00 6.00 24.00'DRILL E 3 'P PJSA Ddg.(/14,562'-14,985'MD(4191'ND)@ 550 gpm,3440 psi,140-180 rpm,2-14k wob,16-17k tqn,15k tqf,230k puw,N/A sow,152k rolw,11.33 ECD,Max Gas 1100,4.48 ADT,47.60 Bit,96.7 Jars.SPRs @ 14,798'MD(4186'ND)w/ 9.45 MW;#1/#2 @ 20-240,@ 30-340. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Malls Coordinator Eni representative Paul Holley ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondnlling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,040.08. 1,267.45 OBM 1126.4 55.5 1564.6 198.2 •Eni E&P Division well Name: E7 Li 0,41 EN!Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUQ • n n Date:7/14/2015 - Report#: 8 APIIUWI:50-629-23542-60-00 `�II �'II page 1 of 1 Wellbore name: SP01-SE7 L1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(FT) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.31 3.99 11.14 6.66 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) SP01-5E7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 6.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,194.10 1,267.17 626.67 12.75 49.2 102.0 3.3 Overcast N @ 5 MPH Daily summary operation 24h Summary Dog.f/14,985'-16,233'and BROOH to 16,200'.Replace Hyd.motor on pipe handler,leaking bottom seal.Service ng.Cont.dog f/16,233'-17,041'MD(4158'TVD). Operation at 07.00 Dolling ahead in Lateral @ 17,693'MD 24h Forecast Drill ahead in Lateral as per SLB f/17,041'to an Est.TD of 19,100'+/-. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1132.4 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 Dog.1/14,985'-15,826'MD(4184'TVD)@ 550 gpm,3580 psi,140-190 rpm,8-14k wob,16-17k tqn,14-16k tqf, 240k puw,N/A sow,155k rotw,11.40 ECD,Max Gas 1583,3.4 ADT,51.0 Bit,102.1 Jars.Monitor well-falling.SPRs @ 15,826'MD(4184'TVD)w/9.45 MW;#1/#2#3 @ 20-230,@ 30-330. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drig.f/15,826'-16,013'MD(4177'TVD)@ 550 gpm,3450 psi,140-190 rpm,8-14k wob,16-18k tqn,13-17k tqf, 230k puw,N/A sow,155k rotw,11.17 ECD,Max Gas 1572,5.17 ADT,56.17 Bit,107.27 Jars.Monitor well-static. 12:00 13:00 1.00 13.00 DRILL E 3 P PJSA Ddg.f/16,013'-16,233'MD(4171'TVD)@ 550 gpm,3600 psi,140-160 rpm,2-14k wob,15-16k tqn,13k tqf,232k puw,N/A sow,150k rotw.BROOH f/16,233'-16,200'. 13:00 16:00 3.00 16.00 DRILL E 25 TRO4 PJSA Replace hydraulic motor for pipe handler do to leaking bottom seal. 16:00 17:00 1.00 17.00 DRILL E 25 P PJSA Service and inspect Top-Drive and traveling equipment. 17:00 18:00 1.00 18.00 DRILL E 3 P PJSA Wash down f/16,200'-16,233'and Drlg.8 16,233'-16,292'MD(4169'TVD)@ 550 gpm,3600 psi,140-180 rpm,2- 16k wob,15k tqn,16-17k tqf,233k puw,N/A sow,150k rotw,11,19 ECD,Max Gas 1161,1.26 ADT,57,43 Bit,108.53 Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Ddg.8 16,292'-17,041'MD(4158'TVD)@ 540 gpm,3600 psi,140-160 rpm,2-16k wob,17k tqn,13-14k tqf,240k puw,N/A sow,152k rotw,11.50 ECD,Max Gas 1847,2.92 ADT,60.35 Bit,111.45 Jars.SPRs @ 16,760'MD(4157'TVD) w/9.45 MW;#1/#2/#3 @ 20-260,@ 30-360. Daily Contacts Position Contact Name Company Title E-mail Office 1 Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.corn 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.corn 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Malls Coordinator Eni representative Paul Holley ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 1 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3,040.08 1,267.45 OBM 1126.4 55.5 1564.6 198.2 •Eni E&P Division Well Name. SE7 Li cfl* ENI Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUO • Date:7/15/2015 - Report#: 9 API/UWI:50-629-23542-60-00 2" " p page 1 of 1 Wellbore name: SP01-SE7 L1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type SOUTH PASS 46(RI.) ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.31 3.99 11.14 6.66 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) SP01-5E7 LI DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 7.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,819.55 1,268.80 625.45 12.83 48.7 102.0 1.1 Fog NE @ 15 MPH Daily summary operation 24h Summary Drill Lateral f/17,041'.19,093'Geologists TD.Monitor well,perform SPRs and BROOH as per K&M to 18,909'. Operation at 07.00 BROOH @ 17,975'MD 24h Forecast BROOH as per K&M. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 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 Ddg.5 17,041'-17,795'MD(4157'TVD)@ 540 gpm,3660 psi,140-180 rpm,2-10k wob,16-17k tqn,14-15k tqf, 260k puw,N/A sow,155k rotw,11.66 ECD,Max Gas 2253,3.62 ADT,63.97 Bit,115.07 Jars.Monitor well-static.SPR5 @ 17,786'MD(4154'TVD)w/9.45 MW;#1/#2/#3 @ 20-290,@ 30-390. 06.00 12:00 6.00 12.00 DRILL E 3 P PJSA Ddg.f/17,795'-18,059'MD(4161'TVD)@ 540 gpm,3740 psi,120-180 rpm,8-16k wob,17-18k tqn,14-15k tqf, 250k puw,N/A sow,157k rotw,11.65 ECD,Max Gas 1796,4.84 ADT,68.81 Bit,119.91 Jars.Monitor well-static. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Ddg.f/18,059'-18,814'MD(4164'TVD)@ 530 gpm,3780 psi,140-160 rpm,2-14k wob,17k tqn,15k tqf,250k puw,N/A sow,150k rotw,11.87 ECD,Max Gas 3064,3.39 ADT,7220 Bit,123.3 Jars. 18:00 19:30 1.50 19.50 DRILL E 3 P PJSA Ddg.f/18,814'-19,093'MD(4162'TVD)Geologists TD,@ 520 gpm,3720 psi,140 rpm,2-12k wob,16k tqn,13k • tqf,250k puw,N/A sow,150k rotw,11.94 ECD,Max Gas 3568,.98 ADT,72.20 Bit,123.3 Jars. 19:30 00:00 4.50 24.00 DRILL E 4 P PJSA Monitor well f/15 min-static.SPRs @ 19,093'MD(4162'TVD)wl 9.45 MW;#1/#2/#3 @ 20-400,@ 30-480. BROOH as per K&M,CBU and rack stand back f/19,093'-18,909'@ 540 gpm,3950 psi,140 rpm,16k tq.Toady fluid losses 4 bbls while CBU. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Malls Coordinator Eni representative Paul Holley ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3,040.08 1,267.45 OBM 1126.4 55.5 1564.6 198.2 ° Eni E&P Division i Well Name: E7 L1 ENI Petroleum Co.Inc. Daily Report` Well Code:27978 Field Name:NIKAITCHUO ilil Date:7/16/2015 - Report#: 10 API/UWI:50-629-23542-60-00 �" page 1 of 1 Wellbore name: SP01-SE7 L1 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) 16.31 3.99 11.14 6.66 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) SP01-5E7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 825 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,819.55 1,268.80 0.00 103.0 1.7 Fog NE @ 18 MPH Daily summary operation 24h Summary BROOH as per K&M f/18,909'-14,200'@ 550 gpm,140 rpm.At 14,200'entered shale and BROOH f/14,200'-13,732'@ 500 gpm,120 rpm,N/A puw in shale zone. Operation at 07.00 BROOH @ 13,490'MD 24h Forecast Cont.to BROOH @ 500 gpm,120 rpm until out of shale @ 12,994'then bring parameters to 550 gpm,140 rpm. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1132.4 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 4 P PJSA BROOH f/18,909'-17,509'@ 550 gpm,3800 psi,140 rpm,13-14k tq,11.50 ECD,225k puw,N/A sow,150k rotw. 06:00 12:00 6.00 12.00 DRILL E 4 P PJSA BROOH f/17,509'-15,455'@ 550 gpm,3650 psi,140 rpm,12-14k tq,11.28 ECD,220k puw,N/A sow,156k rotw. 53 bbls Tourly fluid losses. 12:00 18:00 6.00 18.00 DRILL E 4 P PJSA BROOH f/15,455'-14,200'@ 550 gpm,3650 psi,140 rpm,15k tq,11.09-11.30 ECD,N/A puw due to shale,N/A sow,140k rotw Cont.BROOH f/14,200'-14,085'@ 500 gpm,3000 psi,120 rpm,12-14k tq,through out of zone area.N/A puw/sow,11.39-9.45 ECD. 18.00 00.00 6.00 24.00 DRILL E 4 P PJSA BROOH 1/14,085'-13,732'@ 500 gpm,2960 psi,120 rpm,13-15k tq,N/A puw/sow,150k rotw,11.3-11.52 ECD.20 bbls Toudy fluid losses. 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 Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Malls Coordinator Eni representative Dano Smith ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date 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) 3,040.08 1,267.45 OBM 1126.4 55.5 1564.6 1982 jr,.., Eni E&P Division , . Well Name: E7 L1 ENI Petroleum Co.Inc. Daily Report l Well Code:27978 Field Name:NIKAITCHUQ • en n Date:7/17/2015 - Report#: 11 API/UWI:50-629-23542-60-00 II "I4 page 1 of 1 Wellbore name: SPO1-SE7 L1 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) 16.31 3.99 11.14 6.66 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) SP01-SE7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 9.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,819.55 1,268.80 0.00 101.0 4.4 Cloudy E @ 6 MPH Daily summary operation 24h Summary BROOH through shale section f/13,732'-12,994'then sands f/12,994'-10,320'. Operation at 07.00 BROOH @ 9,310'MD 24h Forecast Work BHA through Window 9974'-9957'and continue to BROOH to 1150'.POOH and L/D BHA. 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 06:00 6.00 6.00 DRILL E 4 'P PJSA BROOH through shale f/13,732'-13,400'@ 500 gpm,2950 psi,120-130 rpm,14-15k tq,11.00 ECD,N/A puw/ sow,140k rotw. 06:00 12:00 6.00 12.00 DRILL E 4 P PJSA BROOH f/13,400'-13,121'@ 500 gpm,2850 psi,120-130 rpm,14-15k tq,10.99 ECD,N/A puw/sow,140k rotw.28 bbls Tourly Fluid Losses. 12:00 18:00 6.00 18.00 DRILL E 4 P PJSA BROOH f/13,121'-12,460'@ 550 gpm,3060 psi,120 rpm,11-12k tq,10.83 ECD,195k puw,115k sow,150k rotw. 18:00 00:00 6.00 24.00 DRILL E 4 P PJSA BROOH f/12,460'-10,320'@ 550 gpm,2960 psi,120 rpm,9-1ok tq,10.58 ECD,180k puw,125k sow,148k rotw. 26 bbis Tourly Fluid Losses. Daily Contacts Position Contact Name Company Title i E-mail Office Mobile Eni representative Jack Keener 'ENI Senior Drilling Supv SIDDniling@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 Vance Dale ENI Matls Coordinator Eni representative Dano Smith ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3,040.08 1,267A5 OBM 1126.4 55.5 1564.6 198.2 ifooliiiii. Eni E&P Division • Well Name: E7 LI 1 EN/Petroleum Co.Inc. Daily Report Well Code:27978 Field Name: NIKAITCHUQ • Date:7/18/2015 - Report#: API/UWI:50-629-23542-60-00 l�f' �I page 1 of 1 Wellbore name: SP01-SE7 L1 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) 16.31 3.99 11.14 6.66 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) SP01-SE7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 10.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 5,819.55 1268.80 0.00 101.0 4.4 Overcast W @ 4 MPH Daily summary operation 24h Summary BROOH f/10,320'-10,040',pump thru Window f/10,040'-9947',then BROOH f/9947'-9480'.C/O saver sub f/5"to 4.5"and service rig.BROOH f/9480'-1791'. Operation at 07.00 Lay Down BHA 24h Forecast Complete BROOH @ 1150'.CBU X 2 or until shakers clean.POOH and UD BHA.Clear and clean rig floor.C/O saver sub. Load floor w/Baker Whipstock Retrieval Tools&M/U as per Baker/SLB.RIH on 5"DP to 9900'and cut&slip drill line.Wash down to Whipstock and orient Hook.Engage Whipstock and pull free.POOH and L/D all tools. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 4 P PJSA BROOH f/10,320'-10,040'@ 550 gpm,2900 psi,120 rpm,10-11k tq,10.51 ECD,185k puw,110k sow,140k rotw. 02:00 02:30 0.50 2.50 DRILL E 4 P PJSA Pump thru Window f/10,040'-9947'@ 3 bpm,375 psi,165k puw. 02:30 04:30 2.00 4.50 DRILL E 4 P PJSA BROOH f/9947'-9480'@ 550 gpm,2825 psi,120 rpm,10-11 k tq,10.53 ECD,180k puw,130k sow,153k rotw 04:30 06:30 2.00 6.50 DRILL E 20 P PJSA CIO Saver sub f/5"to 4.5". 06:30 07:00 0.50 7.00 DRILL E 25 P PJSA Service draw works,top-drive and traveling equipment. 07:00 12:00 5.00 12.00 DRILL E 4 P PJSA BROOH f/9480'-8148'@ 550 gpm,2825 psi,120 rpm,8-10k tq,10.46 ECD,172k puw,130k sow,150k rotw.27 bbls Toady Fluid Losses. 12:00 18:00 6.00 18.00 DRILL E 4 P PJSA BROOH f/8148'-4915'@ 550 gpm,2100 psi,120 rpm,5k tq,10.29 ECD,140k puw,118k sow,128k rotw 18:00 00:00 6.00 24.00 DRILL E 4 P PJSA BROOH f/4915'-1791'@ 550 gpm,1350 psi,120 rpm,3k tq,10.17 ECD,115k puw,112k sow,114k rotw.5 bbls Tautly 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 Dnlling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Matls Coordinator Eni representative Dano Smith ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3,040.08 1,267.45 OBM 1126.4 55.5 1564.6 198.2 Eni E&P Division i well Name: E7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUQ e Date:7/19/2015 - Report#: 13 API/UWI:50-629-23542-60-00 e" page 1 of I Wellbore name: SP01-SE7 L1 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) 16.31 3.99 11.14 6.66 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) SP01-SE7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 11.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,819.55 1,268.80 0.00 105.0 4.4 Fog N @ 2 MPH Daily summary operation 24h Summary BROOH f/1791'-1127'then POOH and LID BHA#6.CIO saver sub f/4.5"to 5".M/U Baker Whipstock retrieval assy.and RIH to 1520'.Perform SHT and RIH to 9456'.Cut&slip drill line and adjust brakes.RIH to 9922'and obtain SPRs.Orient hook to 163 degrees right and wash down and up over Whipstock latch.P/U and orient 17 degrees left and circulate down and latcth onto Whipstock.P/U 50k over string wt.and shear unloader.Pull up to 100k over and released anchor.Monitor well and observed bubbles and slight flow.CBU and well static.POOH w/Whipstock to 9082'. Operation at 07.00 POOH w/Whipstock @ 6,000'MD 24h Forecast POOH vd Whipstock and L/D.Clear and clean rig floor and stage tools for RAM Seal Bore Diverter run.M/U same w/Baker and RIH. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 11324 Time Log Start End I Cum Time Time Dur(hr),Dur(hr), Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50'DRILL E 4 P PJSA BROOH f/1791'-1127'@ 550 gpm,1300 psi,120 rpm,2-3k tq,10.28 ECD,110k puw,109k sow,110k roles. 01:30 02:30 1.00 2.50'DRILL E 4 P PJSA POOH f/1127'-368',85k puw,86k sow. 02:30 05:00 2.50' 5.00'DRILL E 4 P PJSA UD BHA and unload nuclear source f/368'-surface as per SLB. 05:00 05:30 0.50 5.50'DRILL E 20 P PJSA Clear and clear rig floor and prep.for Whipstock retrieval run. 05:30 07:30 2.00 7.50'DRILL E 20 P PJSA C/O saver sub f/4.5"to 5". 07:30 10:00 2.50 10.00 DRILL E 4 P PJSA P/U&M/U Baker retrieving hook assy.as per Baker/SLB from surface to 120'. 10:00 10:30 0.50 10.50 DRILL E 4 P PJSA RIH f/120'-1520',107k puw,105k sow. 10:30 11:00 0.50 11.00 DRILL E 12 P PJSA Perform shallow hole test @ 360 gpm,1100 psi. 11:00 12:00 1.00 12.00 DRILL E 4 P PJSA RIH f/1520'-2734',121k puw,112k sow.11 bbls Tourly Fluid Losses. - 12:00 15:30 3.50 15.50 DRILL E 4 P PJSA RIH f/2734'-9456',180k puw,130k sow. 15:30 17:00 1.50' 17.00'DRILL E 25 P PJSA Cut and slip 95'of drill line and adjust brakes. 17:00 17:30 0.50' 17.50 DRILL E 4 P PJSA RIH f19456'-9922',180k puw,130k sow. 17:30 19:00 1.50 19.00 DRILL E 19 P PJSA Obtain SPRs @ 9922'MD(4154'ND)w/9.45 MW;#1/#2/#3 @ 20-220,@ 30-320.Orient Hook to 163 degrees right and wash down and up over Whipstock latch @ 10 bpm,1750 psi.Pull up and orient to 17 degrees to the left. Circulate down to 9962'and set 15k downt to latch in.P/U 50k over string wt.and sheared unloader.Cont.to pull up to 100k over and released anchor. 19:00 19:30 0.50' 19.50'DRILL E 19 P PJSA Monitor well f/15 min and observed bubbles and slight flow. 19:30 20:30 1.00 20.50 DRILL E 7 P PJSA CBU @ 10 bpm,1450 psi.Monitor well-static. 20:30 00:00 3.50 24.00 DRILL E 4 P PJSA POOH wd Whipstock(/9962'-9082',188k puw. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Mails Coordinator Eni representative Dano Smith ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,040 08 1,267.45 OBM 1126.4 55.5 1564.6 198.2 Eni E&P Division • Well Name. SE7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUQ • Date:7/20/2015 - Report#: 14 API/UWI:50-629-23542-60-00 2" " page 1 of 1 Wellbore name: SP01-SE7 L1 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) 16.31 3.99 11.14 6.66 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Pha se Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP01-SE7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 12.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 5.819.55 1,268.80 0.00 105.0 5.6 Overcast se 7 MPH Daily summary operation 24h Summary POOH w/Whipstock and UD retrieval BHA 8 Whipstock.M/U BAKER CLEANOUT ASSY.AND RIH TO 9998'.PERFORM SPRS AND WASH DOWN INSIDE OF LINER TO 10,035'.P/U TO 10,026'AND CBU.PULL OUT OF LINER TO 9998'AND MONITOR WELL.WELL HAD BUBBLES AND SLIGHT FLOW,CBU. Operation at 07.00 POOH W/CLEANOUT ASSY.@ 5,850'MD 24h Forecast MONITOR WELL-STATIC.POOH,CLEAN MAGNETS AND CLEAN BOOT BASKETS.UD BHA IF ALL IS GOOD.M/U BAKER RAM DIVERTER ASSY.W SLB AND RIH. 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 06:00 6.00 6.00 DRILL E 4 P PJSA POOH w/Whipstock f/9082'-4321',140 puw. 06:00 12:00 6.00 12.00 DRILL E 4 P PJSA POOH w/Whipstock f/4321'-surface,80k puw.L/D retrieval BHA and Whipstock setting on the bar.16 bbls Toudy Fluid Losses, 12:00 13:00 1.00 13.00 DRILL E 4 P PJSA L/D SLIDE AND HANGER ASSY.AS PER BAKER. 13:00 14:00 1.00 14.00 DRILL E 20 P PJSA CLEAR AND CLEAN RIG FLOOR. 14:00 15:00 1.00 15.00 DRILL E 20 U Once BHA#7 reached surface,the magnets were found to have a significant amount of metal on them.The decision was made to make a cleanout run with 2 bootbaskets and 2 magnets. PJSA LOAD RIG FLOOR W/BAKER CLEANOUT ASSY.TOOLS 15:00 16:30 1.50 16.50 DRILL E 4 U PJSA M/U BAKER CLEANOUT ASSY.AND RIH TO 102',85K PUW/SOW. 16:30 21:00 4.50 21.00 DRILL E 4 U PJSA RIH F/102'-9998',190K PUW,135K SOW. 21:00 21:30 0.50 21.50 DRILL E 4 U PJSA PERFORM SPRS @ 9998'MD W/9.45MW;#1/#2/#3 @ 20-190,@ 30-230.WASH DOWN F/9998'- 10,035'(INSIDE OF LINER)@ 10 BPM,900-1330 PSI,AND TAG NO-GO W/10K,P/U TO 10,026',190K PUW,135K SOW. 21:30 22:30 1.00 22.50 DRILL E 7 U PJSA CBU @ 10,026'W/10 BPM,1330 PSI. 22:30 23:00 0.50 23.00 DRILL E 4 U PJSA PULL OUT OF LINER TO 9998'.MONITOR WELL F/15 MIN.WELL HAD BUBBLES AND SLIGHT FLOW, 23.00 00:00 1.00 24.00 DRILL E 7 U PJSA CBU @ 9998'W/10 BPM,950 PSI. 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 Vance Dale ENI Matls Coordinator Eni representative Dano Smith ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980.7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3,040.08 1,267.45 OBM 1126.4 55.5 1564.6 198.2 doica" Eni E&P Division • Well Name: SE7 Li ENI Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUO enn Date:7/21/2015 - Report#: 15 APIIUWI:50-629-23542-60-00 'f page 1 of 1 Wellbore name: SP01-SE7 L1 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) 16.31 3.99 11.14 6.66 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) SP01-SE7 L1 DRILLING 7/8/2015 5,876.54 2779.47 73.68 37.7 13.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,819 55 1,268.80 0.00 106.0 5.0 Mostly Cloudy NE @ 28 MPH Daily summary operation 24h Summary POOH W/Clean out Assy.F/9,998'to 102'MD.UD Clean out Assy.as per Baker Hughes Rep onsite F/102'.10 lb of metal on magnets.Clear and clean rig floor of components&empty boot baskets. 10 lb metal and cement from boot baskets.MOB Seal Bore Diverter components to Pipe Shed and prep for M/U.P/U M/U Anchor Assy,DB Nipple Assy.,Seal Bore Diverter Assy.W/FJD running tool stick up&orient as per Baker Rep onsite.Test RAM Diverter to endure release id greater then MWD turn on.500 GPM released.P/U MWD and orientate to RAM Diverter as per Baker,Schlumberger DD and MWD and Co Rep onsite.RIH RAM Diverter on 5"D.P.to 9,926'MD.HST 190K,SLK 135K.Shallow hole test MWD @ 1,520'MD 330 GPM,550 PSI.Orientate RAM Diverter to 1°Right.Pump down W/300 GPM,860 PSI F/9,926'to 10,031'MD.Engage latch @ 23°Left.Set down F/20-40K and pick up 30-60K several times as per Baker Rep.Orientation changed F/19°when picked up to 23°when SLK.Co Rep onsite.Called town to verify latch orientation.Circ.100 GPM,200 PSI.Service TDS-8,Blocks,Drawworks,ST-80 and Crown.Decision made to set latch.SLK 20K onto latch,pump 550 GPM,2,450 PSI as per Baker Rep onsite,unlatch F/10,031'to 10,020'MD.Monitor well,static.Pull 5"D.P.5 stands F/10,020'to 9,646'MD.Pump 16 bbl 11.7 ppg Dry Job.Cont.POOH 5"D.P.and running Assy.F/9,646'to 6,482'MD.HST 168K,SLK 120K.Calculated displacement 80 bbl,actual 80 bbl.No losses. Operation at 07.00 Clean and clear rig floor of running tool.Lay down 4.5"D.P. 24h Forecast Cont.to POOH 5"D.P.and running Assy.6,482'MD.UD Running Assy.L/D 4.5"D.P.and test BOPE. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 7.00 7.00 DRILL E 4 U PJSA POOH W/Clean out Assy.F/9,998'to 102'MD.HST 80K,SLK 83K. 07:00 08:00 ' 1.00 8.00 DRILL E 4 U PJSM UD Clean out Assy.as per Baker Hughes Rep onsite F/102'.10 lb of metal on magnets. 08:00 09:00 ' 1.00 9.00 DRILL E 20 U PJSA Clear and clean ng floor of components&empty boot baskets.10 lb metal and cement from boot baskets. 09:00 09:30 0.50 9.50 DRILL G 20 P PJSM MOB Seal Bore Diverter components to Pipe Shed and prep for M/U. 09:30 12:00 2.50 12.00 DRILL G 20 P PJSM P/U M/U Anchor Assy,DB Nipple Assy,Seal Bore Diverler Assy.W/FJD running tool stick up&orient as per Baker Rep onsite. 12:00 13:00 ' 1.00 13.00 DRILL G 12 P PJSA Test RAM Diverter to endure release id greater then MWD tum on.500 GPM released.P/U MWD and orientate to RAM Diverter as per Baker,Schlumberger DD and MWD and Co Rep onsite. 13:00 17:00 4.00 17.00 DRILL G 4 P PJSM RIH RAM Diverter on 5"D.P.to 9,926'MD.HST 190K,SLK 135K.Shallow hole test MWD @ 1,520'MD 330 GPM, 550 PSI. 17:00 20:00 3.00 20.00 DRILL G 19 P PJSA Orientate RAM Diverter to 1°Right.Pump down W/300 GPM,860 PSI F/9,926'10 10,031'MD.Engage latch @ 23° Left.Set down F/20-40K and pick up 30-60K several times as per Baker Rep.Orientation changed F/19°when picked up to 23°when ELK.Co Rep onsite.Called town to verify latch orientation.Circ.100 GPM,200 PSI.Service TDS-8,Blocks, Drawworks,ST-80 and Crown. SPR @ 9,928'MD W/9.45 ppg MW MP#1 20-240,30-280 MP#2 20-240,30-280 20:00 20:30 0.50 20.50 DRILL G 19 P PJSA Decision made to set latch.SLK 20K onto latch,pump 550 GPM,2,450 PSI as per Baker Rep onsite,unlatch F/ 10,031'to 10,020'MD.HST 190K. 20:30 00:00 3.50 24.00 DRILL G 4 P PJSA Monitor well,static.Pull 5"D.P.5 stands F/10,020'to 9,646'MD.Pump 16 bbl 11.7 ppg Dry Job.Cont.POOH 5" D.P.and running Assy.Fl 9,646'to 6,482'MD.HST 168K,SLK 120K.Calculated displacement 80 bbl,actual 80 bbl.No 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 Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Malls Coordinator Eni representative Dano Smith ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 3,040 08 1.267.45 OBM 1126.4 55.5 1564.6 198.2 Eni E&P Division • Well Name: E7 Li EN!Petroleum Co.Inc. Daily Report Well Code:27978 • Field Name:NIKAITCHUQ �illf* Date:7/22/2015 - Report#: 16 page 1 of 1 APIIUWI:50-629-23542-60-00 (. I II II Wellbore name: SPO1-SE7 L1 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) 16.31 3.99 11.14 6 66 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) SP01-5E7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 7368 37.7 14.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,819.55 1,268.80 0.00 105.0 2.2 Fog NE @ 26 MPH Daily summary operation 24h Summary POOH F/6,482',L/D BHA,L/D 165 Jots 4 1/2"DP,R/U and Test BOPE,R/D Test Equipment and blow do lines,pull test plug and install wear ring,PJSM R/U and RIH W/5 1/2"Liner to 2,141'MD Operation at 07.00 RIH W/5 1/2"Slotted liner @ 5,600' 24h Forecast Cont.RIH with 5.5"liner set liner and pull out of hole. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1132.4 Time Log Start End Cum Time j Time Dur(hr) Dur(hr) Phase Opr. ' Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL G 4 P PJSM,POOH F/6,482'MD,HST 77K,SLK 78K 02:30 04:00 1.50 4.00 DRILL G 5 P PJSM,L/D MWD,FJD Running Tool,Clean&Clear Rig Floor of BHA Components&Prep for laying down 4 1/2"DP 04:00108:30 4.50 8.50 DRILL G 5 P PJSM,UD 165 Jnts 4 1/2"DP Using mouse hole 08:30 10:00 1.50 10.00 DRILL C 12 P PJSM,R/U and perform stack flushing ops W/Vetco grey on site,5 lbs of metal recovered from stack flush. 10:00 10:30 0.50 10.50 DRILL C 12 P PJSM,Pull wear ring and install test plug W/Vetco Grey rep. 10:30 12:00 1.50 12.00 DRILL C 12 P PJSM,R/U and perge stack and test equipment including choke and and perform body test.good test 12:00 17:00 5.00 17.00 DRILL C 12 P PJSM,TEST BOPE,Test all choke valves 1-14 to 250/3500 PSI,Test ANN.to 250/2500 psi W/4/5"test jnt,test upper and lower rams W/4.5&5.5"Test jot to 250/3500 Blind rams to 250/3500 psi,Test dart&FOSV,man.&choke and kill line& HCR's upper&lower IBOP'S to 250/3500 psi,test man.&super choke to 1500 psi,Perform koomey test with start and stop -man.3000 psi,sys=1450 psi,Ann.650 psi/after function-man=1450 psi,sys=1500 psi,Ann=600 psi.200 psi increase= 35 secs.full system charge 173 sec.5 bottles average 2452 psi,all tests charted and were good.AOGCC John Crisp Waived Witness to BOP Test. 17:00 17:30 0.50 17.50 DRILL C 12 P PJSM,R/D Test Equipment and blow down lines. 17:30 18:00 0.50 18.00 DRILL C 12 P PJSM,Pull test plug and install wear ring as per Vetco Grey. 18:00 '19:30 1.50 19.50 DRILL G 1 P PJSM,Bring GBR Tools amd equipment to rig floor and R/U to run 5 1/2"liner. 19:30 00:00 4.50 24.00 DRILL G 4 P PJSM,RIH W/5 1/2"liner as per tally and K&M recomendations to 2,141'MD,PU-100 K,SO-100 K,total losses for the day 10 bbls, Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com '907-685-0715 715-6434 Eni representative Mitch Billington ENI Rig Clerk akrigderksdoyon15@enipetroleum.com 907-685-0722 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Matls Coordinator Eni representative Dano Smith ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com ,907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 5 4.276 -0.06 5,811 01 7/23/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,040.08 1,267 45 ORM 1126.4 55.5 1564.6 198.2 - Eni E&P Division • Well Name: E7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUO p Date:712312015 - Report#: 17 API/DWI:50-629-23542-60-00 "-" " page 1 of 1 Wellbore name: SP01-SE7 L1 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) 16.31 3.99 11.14 6.66 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) SP01-SE7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 15.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 5,819.55 1,268.80 0.00 106.0 0.6 Overcast NE @ 9 MPH Daily summary operation 24h Summary RIH W/5 1/2"Slotted liner,RID GBR Equip.,R/U RIH With5 1/2" liner on 5"DP,Set Ram Hanger Assy.Drop ball release from ram hanger assy.,pull up hole psi up and shear ball seat,Verified No Go in seal bore diverter.POOH to 9,336'MD Operation at 07.00 POOH W/Ram hanger running tool @ 3,600'and 24h Forecast POOH with running tool,Lay down mining tool,Pick up Lem Assembly,RIH set,Pull up&displace well with 9.28 Brine,Come out of hole laying dn DP. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 08:00 8.00 8.00 DRILL G 4 P PJSM,RIH F/2,141'MD T/9,084'MD W/15.58 L-80 Hyd 521 Liner.HST 148K,SLK 110K. 08:00 08:30 0.50 8.50 DRILL G 4 P PJSM,R/D GBR Volanl CRT. 08:30 10:00 1.50 10.00 DRILL G 4 P PJSM,P/U M/U Ram Hanger ASSY.F/9,084'MD T/9,130'MD with Baker reps onsite 10:00 12:00 2.00 12.00 DRILL G 4 P PJSM<Run Liner in hole W/5"DP F/9,084'MD T/9,877'MD HST 153K SIk 120K with ROT 135K,fill pipe as required. 12:00 18:30 6.50 18.50 DRILL G 4 P PJSM,Cont RIH W/5 1/2"Liner on 5"DP F/9,877'MD T/19,026',HST 230K SLK 95K,Drift DP from derrick on way in. (2.91 Drift) 18:30 20:00 1.50 2060 DRILL G 4 P PJSM,Wash do @ 3 BPM 320 PSI F/19,026 T/19,065'MD,Attempt to latch up W/out rotating several times (Unsuccessful),ROT 20 RPM 16 K Tq SD 50K and latch up,PU T/250K and snap out,set down and latch up again the same. 20:00 23:00 3.00 23.00 DRILL G 7 P PJSM,Drop 1"ball and pump dn @ 3 BPM 300 psi,slow to 1 BPM @ 800 Stokes pumped.Cant to pump to 2500 stks no ball seat,P/U drill string 15'215K and slack back off to 100K,cont cirq @ 3 BPM for 100 stks ball on seat.Pressure up to 2,300 psi and release from Ram hanger,bleed off,POOH 40'to T/9,895'MD,pressure up to 4,100 psi&bleed off, pressure up to 4,300 psi to shear off ball seat(Successful)POOH F/9,895'MD T/9,854'MD,slack off to 9,874'MD and verified No Go in seal bore diverter. 23:00 23:30 0.50 23.50 DRILL G I4 P PJSM,POOH T/9,802'MD&Monitor well(Static) 23:30 00:00 0.50 24.00 DRILL G 4 P POOH F/9,802'T/9,336'MD 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 Mitch Billington ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Matls Coordinator Eni representative Dano Smith ENI HSE Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 5 4.276 -0.06 5,811.01 7/23/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,040.08 1,267.45 OBM 1126.4 55.5 1564.6 198.2 fitEni E&P Division . Well Name: SE7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUQ • II Date:7/24/2015 - Report#: 18 APIIUWI:50-629-23542-60-00 " " page 1 of 1 Wellbore name: SP01-SE7 L1 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) 16.31 3.99 11.14 6.66 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) SP01-SE7 L1 DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 16.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,819.55 1,268.80 0.00 105.0 1.7 Overcast N @ 8 MPH Daily summary operation 24h Summary POOH F/9,336'W/Ram liner hanger running tool,L/D Running tools,Service rig,Cut&Slip DL,P/U M/U LEM ASSY,RIH&Set LEM,Pressure test back side.,PJSM for displacing well to brine, Displacing well W/9.2 Brine Operation at 07.00 POOH laying down 5"DP @ 5,260'MD 24h Forecast Finish dispalcing well with 9.2 brine,POOH laying down 5"DP,UD LEM running assy.,Lay down 46 stands 4 1/2"DP (138 Jnts)R/U to run completion Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL G 4 P PJSM,POOH F/9,336'W/Ram hanger running tool, Pumped 15 bbls 11.38 Trip Pill 05:00 06:00 1.00 6.00 DRILL G 5 P PJSM,L/D Liner packer running tool as per Baker rep. 06:00 06:30 0.50 6.50 DRILL G 25 P PJSM,Service Crown,Top Drive. 06:30 08:30 2.00 8.50 DRILL G 25 P PJSM,Cut&Slip Drill line Ajust Breaks,cut 107'. 08:30 09:00 0.50' 9.00 DRILL G 5 P PJSM,Bring Baker Lem tools and equipment to rig floor 09:00 11:30 ' 2.50' 11.50 DRILL G 5 P PJSM,M/U Lem,Slim Pulse MWD,and packer,Orientate MWD and fill packer W/PAL Mix 11:30 12:00 0.50' 12.00 DRILL G 1 P PJSM,RIH W/LEM on 5"DP T/378'MD SHT @ 90 GPM 280 PSI(Test Good) 12:00 18:00 6.00' 18.00 DRILL G 4 P PJSM,Cont.RIH W/LEM on 5"DP F/378'to 9,900'MD,PU 185K,SO 125K 18:00 18:30 0.50' 18.50 DRILL G 4 P PJSM,Pump 100 GPM 500 PSI orientate LEM 30°right,SO T/9,948'MD setting 20K down,Observed tool face turn T/30' left and latch in,over pull 20K(Good Latch)per baker reps on site. 18:30 20:30 2.00 20.50 DRILL G 9 P PJSM,Drop 1 5/8"Ball&pump down 3 BPM @ 650 PSI @ 1,200 stks slow pumps to 2 BPM 390 PSI,Ball on seat W/ 1,535 stks,increase psi to 2,000 psi hold for 1 min.,cont to increase pressure 300 psi increments and hold for 30 sec.all the way to 4,200 PSI @ 4,200 psi SO 20 K and hold for 5 Min.Bleed off.Rig up and test back side T/1,500 psi and hold for 15 min.(good Test)all test charted.UD 1 jnt of 5"DP,Std back 1 stand to 9,835'MD 20:30 23:30 ' 3.00 23.50 DRILL G 7 P PJSM with all parties,Displace well U 9.2# 3%KCL/NACL Brine,pump 41 bbls LVT,98 bbls hivis citric acid spacer,700 bbls KCUNACL Brine @ 7.4 BPM,ICP 510 psi,FCP 260 psi,HST 220 K,SLK 115K V a 23:30 00:00 0.50 24.00 DRILL G 1 P 'PJSM,Clean surface equipment of MOBM interface,B/D,T/D,monitor well.0 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 Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Malls Coordinator Eni representative Dano Smith ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson 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 5 4.276 -0.06 5,811.01 7/23/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.040.08 1,267.45 OBM 1126.4 55.5 1564.6 198.2 Eni E&P Division Well Name: -SE7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27978 Field Name:NIKAITCHUO e APIIUWI:50-629-23542-60-00 e If^t ii Date:7/25/2015 - Report#: 19 page 1 of 1 Wellbore name: SPO1-SE7 L1 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) 16.31 3.99 11.14 6.66 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) SP01-SE7 Ll DRILLING 7/8/2015 5,876.54 2,779.47 73.68 37.7 17.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,819.55 1,268.80 0.00 112.0 1.7 Overcast NW @ 8 MPH Daily summary operation 24h Summary Operation at 07.00 24h Forecast R/U to run completion,LAST DRILLING REPORT 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 06:00 6.00 6.00 DRILL G 4 P PJSM,POOH F/9,835'T/2,339'MD laying down DP,HST 125K SLK 110K 06:00 08:00 2.00 8.00 DRILL G 4 P Cont.laying down DP F/2,339'T/98',Layed dn.313 jots.5"DP,8 bbl loss 08:00 09:00 1.00 9.00 DRILL G 5 P PJSM,UD running tool&slim pulse MWD 09:00 09:30 0.50 9.50 DRILL G 1 P PJSM,Clear&Clean rig floor and install mouse hole in rotary table 09:30 12:00 2.50 12.00 DRILL M 5 P PJSM,Via mouse hole lay down 3 stands 5"DP&21 stands 4 1/2"DP from derrick. 12:00 13:00 1.00 13.00 DRILL M 5 P Cont laying down 4 1/2"DP,20 stands. 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 Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Wade Thomas ENI Eni representative Vance Dale ENI Malls Coordinator Eni representative Dano Smith ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilhng.com 907-685-0716 Tool Push Chad Johnson Doyon Dnlling Tool Pusher rig15@doyondnIling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 5 4.276 -0.06 5,811.01 7/23/2015 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3,040.08 1,267.45 OBM 1126.4 55.5 1564.6 198.2 III • In p 12 (pp (((ryyyy p_p d o spy�p tmp o Os O OOM .v..WO0MS MANN' np nNNOmN OWNNM VASO y^�TO N888.8 dp,20 .-m- 22222 N_p c 2 11111 W**N N 2 2 2 2 2 0 2O 2 2 2 �t02002 pp 2 00 2 N NH 2 2 8 8 8 0008, 8 p.8 8 N 2 NNN NNN N NN NN SON NN 0,”1,0 N 08, 00000 00000 00000 0000 ^0000 00000 0000 00000 00000 0^OA 0 0 Q O qa{pp.1p�j ;ggyy N . 88N,”F, ,U .•A101NO aFigRn ii `M7'M5 a`s R18 ANI 0 N NOM S ENrD in FIR c7.-lo arl O N N r r pMp OMoM pMp pMp oPIMQ t�pNCpp pppp pppp pppppppp ppppo ppp�pypp pp p p_ p J 0,0,0aa as a as Ta a as aT aaa 828'8 T$Waa 88888 as a t t t t t 0 t t t 0 0 0 t t t 0 0 0 0@ 0 0 0 x 0 t t t t t t Ott t °i6 8884.R N24:68 2Mt0A8O 8O8 8227% $C740N 2F442 82 1vT8L! mrd 7:"21mwpp8na �1Cgn TT- n^AAA nNN 00000 NNNNN 00000�� y�� NNNNN 00.00 NNNNN 00.00 N N F C OOOSM �;;;8Y> 8:7888 4V0VV 882W0 tyt8W11488 10(20pC202 :18 _I�^AAr A • rNN 0 O W N 38 880R2 208g 2T WOdN d 88888 888888 82888 88888 82888 88888 82888 88 N a0Nm 0.Npt A ,na 0V1OVVNOV 0pp0n1. 0NOmaaR,7.O=Z0.-00 .-e-ON ro� 7NVi000,,- Wkti. �.. .i lV ,-0 tel , -88,7-22 WAF422 10MP1108 9 0.1400 88'48'4 l1R� 1:58 8882? po 0044 99000 s";:: R `9MV2 a.WTOv NS<NS —N NW m L .C] p f J g pp 2 '00000 OOVNO 281:7487OV2t$388 p8�1AD,�808 aA'*81.30 MM�bO RR pV W y C i 00990 00 7NMN MpF�N NMtT'IOVNi iMO ITD�m aOD.-Oela Nt7 N JN _r r r r Q pp a 9 T 8 > Qct N e -88.122 Q d T Nm MA :2-4222 Y 22 4SR2 .DOVSE: pN N N!O W 8'6°,4 OdSS DEQ C p p 00000 GOON �pN�Q��pD� pp �Olh syn Ogp�NM �pDONM Qam NaC tp�Q OIO 0 E?§` ,28267 O•1� p oopp•' d N ay 1. 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O N O O co NC .2mas ai O2NO<2O C tL O O d o m m m ..,,',0.0,6 R Y e 1 v e ^ N V v ri a m N 2° U E r 0 m N O g O O o W, x rrrr o 0 �-(00)00, m<Z .07),:-;_t to 0 LL n~ N N m A b LL Ill CO N o �' °'oNNN Y _;to mmmm m w ' 0F,aoi m � N N `d Q LL LL LL V m o d V c o M U o 0o u ,Ti,m S m > 0 to 0 r r ° N y ul O O n J E C) 8 a N 12 e? o E is)0. 0 E 2 2 E o >> 0 gm 0 • RECEIVED S JUL 2 2 2015 1552_ ff AOGCC HALLIBURTON • Einiii Pei ©Ileum 1111 Sperry Drilling PACKING LIST Spy Island Drillsite Nikaitchuq SP01-5E7 1.1 Shipping Date: 17-Jul-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 Descriptiallik Interval Packaging Box Description SP01-SE7 1.1 MD Washed and Dried Samples-50' 10000'-13350' Paper envelopes 1 of 3 Washed and Dried Samples-50' 13400'-16200' Paper envelopes 2 of 3 Washed and Dried Samples-50' 16250'-19093' Paper envelopes 3 of 3 One(1)Bundle Contains Bundle 1-Three(3)Boxes Notes: Total Packages this Shipment: 1 Please notify sender upon receipt of delivery; Josh Zuber 907-223-6659 -7-(2,[� Received by Expediter: • • Date: _l • VIII I II II I�IIIIIIiII I IIIIIIIIIIII P80659105 SHIP ATE ER7 1 CEI,15 ‘;;04 1800 E. istAvenue •Anchorage,AK 99501ORIGIN: PRU TERM, AKDEST: ANC TERM, AK 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 -iax•im11.magreirrcmg APP DA E: IME: B ENI PETROLEUM S ENI PETROLEUM g AOGCC H 38E0300RD NTERPOINT DR P Noc WAREHOUSE OLIKTOK DOCK N 333 WEST 7TH AVE Ls STE 100 N ANCHORAGE AK 99503 E 12 ACRE PAD N ANCHORAGE AK 99501 G 907-865-3300 R PRUDHOE BAY AK 99734 E MEREDITH GUHL 907-670-8613 E 907-793-1235 PCS UNIT HIM DESCRIPTION OF ARTICLES AND SPECIAL MARKS WEIGHT(LBS) RATE CHARGES 1 EA 3 BOXES WASHED DRIED SAMPLES 101 6952,989,SPO1-5E7L1 11N x 241N x 181N FT3 **HIGHOCLAIMS RISK, HANDLE WITH CA BECEI N E D 1JUL 222015 101 AOGCC Page 1 of 1 ALL EREIGH I DESCRIBED ABOVE RECEIVED fN GOOD CONDITION WO H SHRINK WRAP/BANDING INTAC f EXCEPT AS NO FED. ADDITIONAL SERVICES PERFORMED- SIGNATURE: DATE: 7�02��15 ,o- ADDITIONAL CHARGES MAY APPLY ❑RES • PRINTED NAME TIME: .So F-7 LTD ACCESS n r -� LIFTGATE E INSIDE PIECES DELIVERED: / INITIALS: DRIVER:—M^- �,J ,! ri APPOINTMENT x EXCEPTIONS: �f OTHER: RECEIVED !ill n `' 2015 Af GCC €<' ENI Nikaitchuq Freight Service Request Form us oiler a ng Date: 17-Jul-15 FSR# SID 989 Requester: VANCE DALE WeII# Phone: (907)-685-0718 SAO l 5 C1 Ll Consignee: AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Contact: Meredith Guhl 907-793-1235 Bill Freight To: ENI PETROLEUM 3800 CENTERPOINT DRIVE, SUITE 300 ANCHORAGE,ALASKA 99503 Phone: (907)865-3300 Transportation Carlile Transportation Provider: Contact: Matt/Mark Phone: 907-659-2398 Email: deadhorsedispatch@carlile.biz Call-Off# AFE Lc.el 5 2- Shipper: Shipper: ENI PETROLEUM Spy Island OLIKTOK POINT,ALASKA Phone: 907-685-0718 Vance or Greg Freight Description: 1 Bundles of 3 Boxes Washed & Dried Samples Weight SP01-SE7 L1 Dimensions Special Instruction: Carlile BOL: 80659105 THIS FREIGHT SERVICE REQUEST FORM MUST BE ATTACHED TO BILL OF LADING FOR DELIVERY Shipper: Eni petroleum Carrier: Carlile Transport Printed Name: Vance Dale Printed Name: Signature: 'Awe Vale Signature: Date: 17-Jul-15 Date: .s., OF 7. 0 0,P"\\I%/�,s, THE STATE Alaska Oil and Gas ��,�� �,,�A ®fA LASKA Conservation Commission ., __=__:. ittst == ff 333 West Seventh Avenue �" GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0' Main: 907.279.1433 ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Davide Simeone Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP01-SE7L1 ENI US Operating Co. Inc. Permit No: 215-097 Surface Location: 4490' FSL, 1171' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 3626' FSL, 410' FEL, SEC. 21, T14N, R9E, UM Dear Mr. Simeone: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 215-078, API No. 50-629- 23542-00-00. Production should continue to be reported as a function of the original API number stated above. 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, .0 Daniel T. Seamount, Jr. Commissioner DATED this/day of June, 2015. RECEIVED • STATE OF ALASKA • JUN 0 8 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION r ✓ L\kb1k`' PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil Q► Service- Winj ❑ Single Zone Q . 1 c.Specify if well is proposed for: Drill ❑ •Lateral Q Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ElShale Gas ❑ _ 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627‘ SP01-SE7L1 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 19280 v TVD: 4146 ' Nikaitchuq/Schrader Bluff . 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 4490 FSL,1171 FEL,S19 T14N R9E UM ` ADL 388582,ADL 388583,ADL 391283• Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3783 FSL,2616 FEL,S17 T14N R9E UM ADL 417493 7/17/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3626 FSL,410 FEL,S21 T14N R9E UM 6954 ' 692'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: . 54.1 feet 15.Distance to Nearest Well Open Surface:x- 511739 y- 6053671 Zone- 4, GL Elevation above MSL: • 13.1 feet to Same Pool: 2454'to SP04-SE5 16.Deviated wells: Kickoff depth: 9666 feet - 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 98.53 degrees - Downhole: 1864 psig• Surface: 1408 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 3348 35 35 3383 2454 In place/Completed 12.25" 9-5/8" 40 L-80 Hydril 563 9633 33 33 9666 4134 In place/Completed 8-3/4" 5-1/2" 15.5 L-80 Hydril 521 9814 9466 4117 19280 4146 Sidetrack-Liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 19244 4165 Casing Length Size Cement Volume MD TVD Conductor/Structural 160 20" Driven 160 160 Lead 1025sx 10.7ppg Surface 3,348 13-3/8" 3383 2454 Tail:227sx 12.5ppg Lead 471sx 12.5ppg Intermediate 10,055 9-5/8" Tail:233sx 15.8ppg 10088 4171 Production Liner 9,355 5-1/2" Liner/Open Hole 19244 4165 Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch ✓ Drilling Program ./ Time v.Depth Plot _ Shallow Hazard Analysis 7 Diverter Sketch 4 Seabed Report Drilling Fluid Program -/ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 6/4/2015 22. I hereby certify that the foregoing is true and correct. Contact Andrea Lazzari 907865 3323 Email andrea.lazzariCotenipetroleum.com Printed Name avide1Sim n Title Well Operation Project Manager Signature 0" 40 ,, / Phone (907)865-3320 Date 6/4/2015 Commission Use Only Permit to Drill A I Nu ber: Permit Approval See cover letter for other Number: c- O 50-(Q /G - 3,3 141-G,° -CC Date: r . (1G(`e) requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Lir Other: .,./ ' ,5a 0 e5.: f / f- Samples req'd: Yes❑ No[a' Mud log req'd: Yes ❑ No 21/ H25 measures: Yes❑ No[7f Directional svy req'd: Yes [17f No❑ Z/" Spacing exception req'd: Yes❑ No[yr Inclination-only svy req'd:Yes❑ No[ APPROVED BY Approved by: COMMISSIONER THE COMMI SIGN Date /4(45 6 -6-- is- 6/1//Y- Submit Form and Fo 10-401(Revised 10/2012) ORIGINAL ir ivihs from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate //.s • • otio • • Eno PtiroHeum r__2),. en 11 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Davide Simeone Phone(907)865-3320 Email: davide.simeone@enipetroleum.com June 4,2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer SP01-SE7 Ll Dear Commissioners, Eni US Operating Co. Inc. hereby applies for a Permit to Drill (Sidetrack Existing SP01-SE7) for the Offshore Producer well SPO1-SE7.This well will be drilled/sidetracked and completed using the rig Doyon 15. The planned spud date could be as early as 07/17/2015. Please find attached for the review of the Commission forms 10-401, the information required by 20 ACC 25.005. If you have any questions or require further information,please contact Andrea Lazzari at 907 865 3323 Sincerely, Davide Sim-. - Well Ops Pr. -,t Manager 410* • • • Enli ° 2nn Application for Permit to Drill SP01-SE7 Li Saved:4-Jun-15 Application for Permit to Drill Document Producer Well SP01-SE7 L1 Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(0 3 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) 3 Please see Attachment 7:Surface Platt 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 AAC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 AAC 25005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 5 8. Drilling Fluid Program 6 Requirements of 20 AAC 25005(c)(8) 6 Lateral Mud Program 6 (MI FazePro Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25 005(c)(9) 6 10. Seismic Analysis 6 Requirements of 20 AAC 25005(c)(10) 6 11. Seabed Condition Analysis 6 AOGCC PERMIT Document Page 1 of 7 Printed:4-Jun-15 Vos, •• Enli Petrolleum eno Application for Permit to Drill SP01-SE7 L1 Saved:4-Jun-15 Requirements of 20 AAC 25.005(c)(11) 6 12. Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13. Proposed Drilling Program 7 Requirements of 20 AAC 25:005(c)(13) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15. Attachments 7 Attachment 1 Drilling Procedure 7 Attachment 2 Directional Plan 7 Attachment 3 Drilling Hazards Summary 7 Attachment 4 BOP and Diverter Configuration 7 Attachment 6 Formation Integrity And Leak Off Test Procedure 7 Attachment 7 Surface Platt 7 AOGCC PERMIT Document Page 2 of 7 Printed:4-Jun-15 • • tot • Enli P 2nn Application for Permit to Drill SP01-SE7 L1 Saved:4-Jun-15 1. Well Name Requirements of 20 MC 25.005(0 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC25.040(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: SP01-SE7 Ll 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 fol/owing items,except for an item a/ready on file with the commission and identified in the application: (2)a p/at 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 4490 FSL, 1171 FEL, S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 54.1'AMSL Northing: 6,053,671' Easting:511,739' Pad Elevation 13.1'AMSL Location at Top of Productive Interval 3783 FSL, 2616 FEL, S17 T14N R9E UM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 10,002' Northing: 6,058,251' Easting: 515,549' Total Vertical Depth, RKB: 4,068' Total Vertical Depth,55: 4,014' Location at Total Depth 3626 FSL, 410 FEL, S21 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 19,280' Northing: 6,052,833' Easting: 523,064' Total Vertical Depth, RKB: 4,134' Total Vertical Depth, SS: 4,080' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC25.050(6); Requirements of 20 MC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a p/at,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 and (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. AOGCC PERMIT Document Page 3 of 7 Printed:4-Jun-15 • • Al* Enil Petrolleuim 2f�t1� Application for Permit to Drill SP01-SE7 L1 Saved:4-Jun-15 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 a/ready on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC25.035,20 AAC25.036,or 20 MC 25.037,as app/icable; Please see Attachment 4: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 MC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; / The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the planned vertical depth of the OA sand formation is: MPSP = (4,141' TVDss)(0.45 - 0.11 psi/ft) = 1408 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 geopressured 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 MC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item a/ready 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 AAC 25.0300; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document Page 4 of 7 Printed:4-Jun-15 • • en II • Eiriiii Petroleum Application for Permit to Drill SP01-SE7 L1 Saved:4-Jun-15 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dri/l 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 20AAC 25.030,and a description of any slotted liner,pre- perforated liner,or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (/b/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 Driven 178.89 X-65 Welded 124 36/ 36 160'/ 160' Pre-Installed 13-3/8 16 68 L-80 BTC 3348' 35 / 35 3383'/ 2454' In place/Completed 9-5/8 12-1/4 40 L-80 Hydril 563 9633' 33 / 33 9666'/ 4134' In place/Completed 8-3/4"OA 5-1/2 Sand 15.5 L-80 Hydril 521 9814' 9466'/ 4117' 19280'/ 4146' 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 AAC25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 4: BOP and Diverter Configuration. AOGCC PERMIT Document Page 5 of 7 Printed:4-Jun-15 • • iff011bt 2no • Eiriii PtiroIIuiim Application for Permit to Drill SP01-SE7 L1 Saved:4-Jun-15 8. 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 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: HTHP Fluid loss (ml/30 min Qa <5.0 Lateral Mud Program 200psi&100°F (MI FazePro Mineral Oil Base) Oil/Water 60/ 40 Value Ratio Density(ppg) 9.2 -9.4 Electrical >600 Plastic Viscostiy 15 - 25 Stability (CP) Yield Point 15 20 (lb/100 st) Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 MC 25,005(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 stratgraphic test well,a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 MC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 MC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 MC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC25.025(Bonding)have been met; Evidence of bonding for ENI is on file with the Commission. AOGCC PERMIT Document Page 6 of 7 Printed:4-Jun-15 • • t* • Einii PetiroIkum en Application for Permit to Drill SP01-SE7 L1 Saved:4-Jun-15 13. Proposed Drilling Program Requirements of 20 AAC 25,005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item a/ready on file with the commission and identified in the application: Please refer also to Attachment 1 — Drilling Procedure 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 25.005(c)(14) An application fora Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (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. , 15. Attachments Attachment 1 Drilling Procedure Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 BOP and Diverter Configuration Attachment 5 Formation Integrity And Leak Off Test Procedure Attachment 6 Surface Platt AOGCC PERMIT Document Page 7 of 7 Printed:4-Jun-15 • • Attachment 1 Drilling Procedure • • ni us operrahirrg WELL SP01-SE7 L1 Drilling Procedure SP01-SE7 L1 Spy Island Conductor slot #01 Reservoir location #SE7 L1 Producer (Schrader Bluff) Nikaitchuq Project SP01-SE7 Ll Drilling Wellplan Page 1 of23 06/08/15 1 • • us operating WELL SP01-SE7 L1 Iiiiii Spy Island Nikaitchuq Field ' en' pehrole"m North Slope - Alaska SP01-SE7L1 DIR/LWD FORM DEPTH 1 1101E CASING MUD IMO MWD MD TVD SIZE SPECS INFO Cement to Surface — - . r 20" Hole Angle a 5-65 0' 20"Conductor Shoe 160' 160' Driven Welded N/A 0 GR/Res 'v v. e1.'6ce ren_ I2 /PWD ei e 13-3/0 V. 68# MW(ppg) Wellbore Stability Mud Motor 8/Permafrost 1,940' 1,752' _ L-80,BTC 8.8-9.5 Lost Circulation a HWe Claanirg ei Casing Sections KOP:300' °__ Casing Wear DS: Surface T/Tail Cement 2,878 2,315' 0-3.5'/100 Ilola Angle 74.73 Deg 13-3/6"Cog 3,383' 2,454' _ 16" SO'F WWI GR I RES/PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation treed 900 405 MW(0p9) Hole Cleaning 1-80,Hydra 563 8.8-9.5 Torque&Drag Casng Sections Tangent Anne: _ Casing Wear 85.00 Deg BHA Expense intemedlate TOC 8,015' 3,821' . .1 Pick-up Top of Sand 585 N Top 9,015' 4,068' Hog Angle TOL 9,466' 4,117 86.73 Deg ease Whlpstodt 9,666' 4,134' 0_ 12-1/4" 85°F W804 GR/RES/ I�I f�I {d Ecoscope/periSCOPE il Wellbore Stabety i,' , --LEI I Lost Circulation iPetted Liner Hole Cleaning 5-1/2' Torque&Drag 15.5.5 MW(PPM Casing Sections %oeed 675 �1 I L-80,Hydnl 521 9.2-9.4 Casng Wear 9 I I BHA Expense 4 Liner shoe TD 19,281' 4,146' 14 Hole Angle 92.73 Deg 8-3/4.. 85'F M08M SPOI-SE7 LI Drilling Wellplan Page 2 of 23 06/08/15 • • em us operating WELL SP01-SE7 L1 Table of Contents WELL PLAN SUMMARY 4 WELL HISTORY 6 RIH WHIPSTOCK AND 9 5/8" MILLING OPERATIONS 7 Pick Up Production Drilling Assembly 9 PRODUCTION SECTION 10 Production Drilling 12 Production Liner 13 ATTACHMENTS 18 Recommended Drilling Practices 19 Health, Safety& Environment 20 Safety Meeting Topics 21 Well Shut In Procedure While Running Production Tubing 23 SP01-SE7 L1 Drilling Wellplan Page 3 of 23 06/08/15 • n us perra ng WELL SP01-SE7 L1 • WELL PLAN SUMMARY Rig: Doyon 15 Type of Well: Producer Well Design: 13-3/8"Surface x 9-5/8"Intermediate x 5-1/2"Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survey Program &Procedures Take MWD surveys as frequently as needed,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-go lines. If a no-go or hard line has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. SP01-SE7 Ll Drilling Wellplan Page 4 of 23 06/08/15 • • pnil us perrahng WELL SPO1-SE7 L1 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. Cut window in the 9 5/8"casing and drill 2nd lateral per the well plan. Maximum dogleg severity in the landing shall be no greater than 4.00/100' DLS. 3. Execute the setting and orientation of the whipstock per the wellplan. 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. SPOI-SE7 LI Drilling Wellplan Page 5 of 23 06/08/15 • • emm us operating WELL SP01-SE7 L1 WELL HISTORY Current Status Well SP01-SE7 is currently planned to be drilled. After the production phase a new lateral in 8 3/4" will be performed. Scope of Work Scope of this work is drill a new 8 3/4"lateral section, RIH a second 5 '/z" slotted liner and run in with a new TTC-ESP system to have a commingle production for both lateral.. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1861 psi during the drilling time,which ✓'` places the fluid level below surface. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind/Flowcross/pipe SP01-SE7 Ll Drilling Wellplan Page 6 of 23 06/08/15 • • los Pno us op rra ng WELL SP01-SE7 L1 RIH WHIPSTOCK AND 9 5/8" MILLING OPERATIONS 1. RIH with a clean out BHA to the top of the previous 5''/z"liner. Mill a window in 9 5/8"40#casing. Notes: a) It is important that the whipstock assembly is spaced out to ensure that the entire window is milled between casing collars. b) The approximate overall length of the casing window to be milled is 14'-16'ft. c) All measurement and procedures are to be double-checked and approved by Co.Man prior to running the whipstock/window milling assembly in the hole. d) Ensure drill pipe pup joints are available for the correct space out e) After the window is milled,the upper watermelon mill should be gauged.If the upper watermelon mill is more that 1/8"under gauge a cleanup trip is recommended to ensure window is fully open.A back up set of mills should be on location. 0 Ditch magnets should be placed in the flow line to recover all metal circulated out of the well Whipstock/Window Milling Guidelines: D Check with Geologist to confirm if there is a concretion at the window milling depth. D Never rotate a bit on the face of the whipstock D Orient the BHA(if motor is used)above the window before attempting to exit the window.Bit rotation may "catch"the edge of the whipstock and damage the face making recovery operations more difficult. D If at any time during operations a problem is encountered tripping through the window area,a watermelon or string mill should be run in the drilling assembly to clean up the window area D Always trip slowly and carefully(+/-90 seconds per stand)with all BHA's through the milled window SPO1-SE7 Ll Drilling Wellplan Page 7 of 23 06/08/15 • i rP in 11 us operefing WELL SP01-SE7 L1 Procedure: 1. Prior to mill the window,hold a Tech Planning meeting to discuss this phase of the well.Review the well plan and discuss any discrepancies or concerns with the drilling superintendent 2. RIH the whipstock assembly 3. At surface align the MWD with the whipstock face 4. Shallow test the MWD tools 5. RIH to setting depth 6. 45'above setting depth establish circulation and work torque out of string. 7. Orient the whipstock as per well plan.Once the correct orientation is confirmed,reciprocate the whipstock to confirm that the face has not rotated.Re-check the orientation with an additional survey. 8. Once orientation and depth have been agreed upon by all relevant parties,set the whipstock assembly. 9. Initiate circulation and obtain a survey of the installed whipstock orientation 10. Start 9 5/8"casing milling operation.Establish rotation to begin milling the window. 11. After the window is complete and before POOH,shut pumps and work milling assembly through window several times watching for drag.POOH and L/D milling assembly. 4/ SP01-SE7 L1 Drilling Wellplan Page 8 of 23 06/08/15 • • of* eng us operaE fine WELL SP01-SE7 L1 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly as per the BHA diagram. ➢ 8-3/4"PDC ➢ Rotary Steerable D. Flow rate: 550 GPM ➢ 120—140 RPM Oil Based Mud Fluid Displacement 2. Drill 20'-50'of new hole using the Oil Based Reservoir Drill-In fluid. 3. 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 12.5 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. D. Plot on LOT form in N drive SP01-SE7 Ll Drilling Wellplan Page 9 of 23 06/08/15 • • %kis (pm m us operating WELL SP01-SE7 L1 PRODUCTION SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (7)) True Measured Formation Tops Vertical Comments Depth,ft Depth, ft SV-4 765 761 SV-3 1147 1075 SV-2 1461 1 380 B/Permafrost 1832 1762 SV-1 2205 1950 Ugnu Top(UG4) 2795 2281 13-3/8" Csg 3383 2454 SCP UG-2 Coal Bed Marker 4820 2832 Lower Ugnu 7408 3609 Schrader Bluff Top 8711 4012 N Sequence Top 8813 4033 N Top 9012 4068 ReCalc Intermediate Cement w/Actual N Bottom 9117 4083 N Sequence Base 9470 4117 Base Window @ 9,666'MD OA Top 10002 4168 9-5/8" Csg 10088 4171 IN PLACE OA Top 13099 4171 OA Top 14397 4157 5 1/2" Liner 19280 4146 Total Depth SP01-SE7 Ll Drilling Wellplan Page 10 of 23 06/08/15 • • volos a enus cep'erreing WELL SP01-SE7 L1 Production Mud Program: FazePro Density HTHP FL Electrical Interval YP Oil:water Stability (ppg) (ml/30min) miVolts Production 9.2-9.4 15-20 <5.0 60:40 >600 Production Logging/Formation Evaluation Program: Production: MWD Directional/PWD(Pressure While Drilling) LWD GR/Res/Ecoscope Production Drill Pipe Tool Joint Body DP Tool Make Up Tensile Pipe WT Grade Conn. Joint Joint Body Torque Torsion Torsional capacity Capacity (PPP type OD ID(in) al Yield Yield w/conn. (in) ID(in) (ft.lbs) (ft lbs) (ft.lbs) (gal/ft) (fps) 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. SPO1-SE7 L1 Drilling Wellplan Page 11 of 23 06/08/15 • • c rn ll us oxxrraHrrig WELL SP01-SE7 L1 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. ➢ Geosteering will be required to remain in the target boundary 100%of the time ➢ Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. > Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: > At TD circulate 50%of calculated TAD cleanup cycle pulling 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 backreamin2 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 SP01-SE7 L1 Drilling Wellplan Page 12 of 23 06/08/15 • • tr1 D us ope rra tt g WELL SP01-SE7 L1 ➢ When out of hole,down load the recorded tool data and send to the Geologist in town 8. RIH with retrieving tool assembly to retrieve the whipstock assembly 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) (laps) 5-1/2 15.5 L-80 H521i1 5.713 4.950 4.825 4990 7000 242 Production Liner Connection Make Up Torque(ft-lbs) Min. TarD WT Makeget Max. (i (p Yield Grade Conn.Type PP I Torque,Up ft- Make Up Make Up Torque lbs Torque* Torque 5-1/2 15.5 L-80 Hydril 521 4600 8100 N/A 24,000 * See attached TenarisHydril Guidelines for make-up torque recommendations Production Liner Centralization From To Quantity/Joint Fixed/Floating Type Shoe Liner 1/joint Fixed 5-1/2"x 7" top -Mid joint -Crimped on -Hydroform,Volant(Crimp on) Liner Running Procedure Notes: • Ensure proper crossover from DP to slotted liner is on the rig floor in case of a well control situation. • Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. • Ensure accurate torque and drag data is gathered. Record pick up and slack off weights every stand and free rotating torque every five stands. Data gathered will assist in future liner running operations throughout the project. • Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well and recorded in WelIView. • 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. SPO1-SE7 L1 Drilling Wellplan Page 13 of 23 06/08/15 • • ung us ®perraling WELL SP01-SE7 L1 • Torque ratings for string components: String Components Yield Torque(ft-lb) 5" 19.5#TT525 Drill Pipe 74,100 HRD Running Tool 40,000 7"29#Hydril 563 39,000 5-1/2" 15.5#Hydril 521 24,000 • Shear pressures for liner hanger assembly: Item Description Shear Value Shear Range HRD Running Tool,7" Nominal- 3192 psi 15%+ 3671 psi 6795 mch rel,3 pins 15%- 2713 psi Pusher Tool Activation Nominal- 1986 psi 15%+ 2284 psi 15%- 1688 psi Pusher Tool Neutrlz. Nominal- 3588 psi 15%+ 4126 psi 15%- 3050 psi Ball Seat SOLID *****Make-up torque for liner hanger sub-assembly,including running tool connections,should be torqued to 14,000 ft-lbs prior to deliver to rig. Procedure: 1. Hold Pre job safety meeting to ensure all parties understand operation 2. PU the Liner Assembly and Running/Inner String as outlined above.' 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. Fill Liner Tieback Sleeve with"pal mix"and ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 minutes for mixture to set up. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. Record ROTATE,PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIH with Liner Assembly as hole conditions allow,but do not exceed running speed of one stand per minute. Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. Circulate minimum of one DP volume and record ROTATE,PU and SO weights. 8. Record PU,SO,and Rotating torque in open hole every 500'to ensure friction factors are sufficient to run the liner to bottom successfully. If friction trend indicates liner will not go to bottom then call Drilling Supt.immediately. 9. Rotating liner 20-60 RPM will be necessary to run to bottom. 10. Continue RIH with Liner Assembly to proper setting depth. Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8"window. 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"Window. 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. SP01-SE7 Ll Drilling Wellplan Page 14 of 23 06/08/15 • • 101.- Pni u opereong WELL SP01-SE7 L1 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. SP01-SE7 Ll Drilling Wellplan Page 15 of 23 06/08/15 • • enri us operaHnc WELL SP01-SE7 L1 RIH ESP Completion SP01-SE7 LI Drilling Wellplan Page 16 of 23 06/08/15 • • ...vios WELL SP01-SE7 L1 Prepare to RIH completion: 1. MU ESP assembly and RIH to setting depth. 2. Land hanger,RILDS and test hanger. 3. Install BPV and nipple down BOP. 4. NU tubing adapter and tree. 5. Pull BPV,install test plug and test tree. 6. Circulate Freeze protect through tree down IA. 7. Shut in well. 8. RDMO Below the final schematic of the well after completion: r I4-WI2Gp9fPlodubonTublng II *Nit •/-2,300'MO 2.01*TVD 49°Inc•GLM KBMG. 4.W x 1",weth 2000 petSTatsoVinstalled eni petroleum J 4-'6"a-cpie cable daerga.lot ESP Power 1. II Cable,(I)3/8'Chem IN Line wh 2300 •�9240 M[t6Ye Neo-GLFt KBMG 4-ti`x 1',lerk413.I psi cheek valve el Warm SP01-SE7 "` Dual Lateral Producer . OOpki ISTS-1saV*Wake with ESP Lift is •r•9280 MD 4 t I?'TVD-nwahatge Gauet Sub As Planned ` .F.9.380'MCI 4 114'TVD,45"Inc-Drapes rd Mobs CeMlatger Gc.NR 4I ESP 114 P7 stay,Flee 17 S SX13-t4 stage G22 6X13 a+rrw•40 ctepe GINPSHL SXO S13 GS83 • seats 210 elP M4P250 motor gas separator 40 - -/-9.440'MO 32*Shroud Nsembry aver cable and chemical Surt Caemg /,/. intoctwn tate feted-Bays 3.5•Patotated las Itsoetsoon lube 13-3/8,68* 4 IV Lateral Entry •<-3 383'MD ,,,..."1„ Module ITEM)w/3.6D Silver Bupet Ecc Nose TD 8 3/4' 2 454'ND s Sal Bon 5•is'IS 5r17 pc+ Stade D int.)Shoe 19279 M 74*lac Mb L80 Slatted Loner 1?:a5o'Mt) 4 13d' 4 t45"TVD el-11,460,4,696* TVD.90"Ing /4,13.1`41,134*TV .a,/74` D 93'Inc. 51,444 MD.4,t t6 /I� Cesnq Ea*Window 11/0-LI-Baker SI XP Linert4angetlPacker •1.- g 400'WO RAM Manger 396^2"Lateral One ID 3.688•Marnbtee DIA 12 -- 4-'S-■9-5ra �y ; ti141 Sc,':',,,,, t7e Swed 10 8 3/4' Beal Bae D.eerter y\ Sealbaa Receptacle pa I'.c ;-19.243 MD n'3 88"Seal Sole4 7S"10 y 4 165' 88`Inc •t 9 d84 M0 4.081 ryD _ Baker MLXP User )4 V'r Hanger/Packer p Bottom of Set . ' __ Assernmy Interm Casrnq - - _— 9-518`.d0a 5-7. 15.5;apt l80 Sloped Loner Silver Bu@e,Ect.rose Guide Sebe •/-10,085'MD a' • -4 19.229 MD 4.24?TVD.88°Inc ^SRattnuv F.,4-Ser!cane TVD 85°Inc SPO1-SE7 L1 Drilling Wellplan Page 17 of 23 06/08/15 • • i r� us op&&aNng WELL SP01-SE7 L1 9. ATTACHMENTS 10. Recommended Drilling Practices 11. Health,Safety,and Environment 12. Safety Meeting Topics 13. Well Shut In Procedure While Running Tubing 14. Conductor Broaching Contingency Plan 15. Port Collar Decision Tree SPO1-SE7 L1 Drilling Wellplan Page 18 of 23 06/08/15 • ! P. n3 us OxxiralIng WELL SP01-SE7 L1 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 ftph 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. SPO1-SE7 L1 Drilling Wellplan Page 19 of 23 06/08/15 • 0100,, nus operating WELL SP01-SE7 L1 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 HZS. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H,S encounter,drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures,full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,daily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. SPO1-SE7 L1 Drilling Wellplan Page 20 of 23 06/08/15 S • AV* operahng WELL SP01-SE7 L1 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. > Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. SPO1-SE7 L1 Drilling Wellplan Page 21 of 23 06/08/15 ! • P. ti us opering WELL SPO1-SE7 L1 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. SPO1-SE7 L1 Drilling Wellplan Page 22 of 23 06/08/15 • • ifiy* us operraiing WELL SPO1-SE7 L1 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. �. SPO1-SE7 L1 Drilling Wellplan Page 23 of 23 06/08/15 • • Attachment 2 Directional Plan • • N O , d N M 717g2'4 7NMn v M O N M 882;2 NO;rn dOmmb M m 7 O N b n 0 Y,N ;b�n b 0 p 7M U1 N fes. 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Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming 1 Drilling Hazards Summary 7/9/2014 11:58:00 AM • • Attachment 4 BOP & Diverter Configuration • • gg gg GI VI . . Y J . ,! . 83i N WW � >-6 ie 0 w cD a-- -J 0 ..7. !0°1:.: ! °Oh 4:1—': .. °Z 3 Lai < ,_ . h p -. a 2 0 J 0 z 00]] Y U E m H -i 'L� [S IT N M < LC) .O h 01 tt10_ • r 11 Pi: ° oY W j i o ii 2 .D EP,' qVN J W LO '�/\ m N Wqul -41111111111._ 4] S / ' O z O tib, O —I'I O :d ✓ •mamsemommommor 41 W • O WF k— ts it m d T U -- • Cl Q ft.41 I K C _ g $ a S , _ 8 ._ S R: ' 4x y� 0 m 1 m & I q n S 1 ' F A ! .'2, g .*:%9i = g 1.9 ig. - ii g 133 10 ql1Pg1 ! !I I ON ,I IA t_ a j Ii `� V a > 3 -IrLAV-1-Ictfl TZ .. 1,1 Z 1 i - WA 11 OA m n C fl b (1 b 11 - i 'I� 'I .. i .Ls s r. j . j .. 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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). • • VOS S P E 0 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 I/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. • • SPEO IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. Em 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. • • > 01 SPEO IDENTIFICATION CODE PAG 209 OF 338 ENI S.p.A. E i E&P Division REVISION STAP-P-1-M-6140 0 1 • 14 LEAK-OFF TEST REPORT Report N° Date: WELL Ni 1E: WELL CODE: CONTRACTOR: RIG NM E: RIG CODE: Open hole depth(m): 825 Mud Ttpe: FWGELS Rigttpe: J.UPs Hole Llameter(in): 12"1 i4 lOJeight(Kgl): 1.3 R.K.B.elewilt on(m): 26 Last Csg.Shoe(m): 797 Marsh Viscosity(sec/Qt): 44 Water Depth(m): 24 C .diameter en): 13'3/3 P.V.(cps): 19 Pumps: 12-P-160 Grade: J-55 Y.P.(1b/100 ft°): 5 liners(in): 6.5" Weight(lbtt): 61 Gels(Ib/100 t''): 2r88 Flow Rate(bpi): 0.25 Mao.Burst pres(psi): 3103 W.L(cotO min): 10.5 Litholog v: Shale Expected EMVV 1.68 Kgtcm2il 0 m Time Volume Pressure Time Volume Pressure Time Vdume Pressure (min) (bdl (Psi) (mini (bbll (Psi] (mini fbbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 95 2 _ 480 3 075 200 10 2 470 4 100 300 10.6 2 463 5 125 400 11 2 455 6 150 500 11.5 2 450 175 570 12 2 445 8 200 600 13 2 8 200 550 14 2 437 8.5 200 505 15 2 435 Nd e: Pumped with a constant low rate of(bbl): I.,,blume pumped(bbl): \klume returned(bbl): (pal 1000 900 800 • stop pump F 700 • r - e 600 shut in curve 500 ti 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(bbl) 41 11 Time mins RESULTS:(Press..+Press.L.0.)x10/Depth=[(1.3 x 797 i 101+(430 x 0.07)]x10 i 797=1.68(Kglcm2t1 0 m) Note: I Company Represerrtatir,a Figure 15-1 - Leak-Off Test Report • • Attachment 7 Surface Platt • • REV DATE BY CK APP DESCRIPTION REYL DATE BY ,_ CK APP — DESCRIPTION D 'O/u'/'C S z c , .:w ' VICIN IT MAP SCALE: - 2 N I .r �r,� I g 0 ' THIS .. _____r_______ ____ _ .26 — --;5 is 7,a SURVEYu30 29 7 r,; ii giit W A.S.P NAD83, 24. 5:: $g; 31 3" T SA i..- K 1.1 +• .5; :, - T14N T14N , T13N 1 113N 1 ', •, KTOK POINT"AD,, 0oCK y' t% 1 ' NitI I r 4 ? r 1 1 'NOgs 0o�cc -� i � +- - ) (� 1E eT.094 22 15 14 i 35x30•._ (tI,.rM PDO ;� i .ems 6 CI , J F _ �. DS 30 c4_ L W, ;, .. 13--3M 2 (9 in .,- 26 2/ ii �e v DS 1 v 'ya * ♦n VJ ,r IVI + ' sAK le ,v - rC_ L 33 36 ‘t .,¢ i' �•N. a �„� D II 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 8,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. 10,061106MiIt\ • (--): SURVEYOR'S CERTIFICATE : �. 49tH 1 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND 0 ,01 LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF '7.;: .: •. Cd m,....--p ALASKA AND THAT THIS PLAT REPRESENTS .A SURVEY 0 �+c FRANCIS 8. CORNING (J w DONE BY ME OR UNDER MY DIRECT SUPERVISION AND OA s LS-10685 •:' a` J THAT ALL DIMENSIONS ANO OTHER DETAILS ARE CORRECT • "� Q r AS OF OCTOBER 01, 2010 1. '�Q'••.to/4 1Zio (.4 ior 500,,ISJo�, SPY ISLAND DRILL SITE q WELL CONDUCTORS �.n AS—BUILT LOCATIONS 2111111 '',, ' CAD FIIE.F.Ni354.339 US op Itim DATE DRAWING NO: PART: REV: •oiro;r,-a Eni-3543—d9 1 of 3 0 • • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP T, DESCRIPTION N . tr t.li A,S.P. NAD83, Z4. _, l d' J 1 7,.! N N N ra N W �,�, t•-) o P 6 W ..r�l1CJlA° J W"� W 00 UP W N Q 0 G+ O, 4. c DETA'L A. SCALE: 1"=80' S N, 0BBAG12 GRAVEL 54CULDER ego ypao� e. wow* a jO ao '° 44C. 0 a .Yu DETAIL A �P SPY ISLAND DRILL SITE (SID) GRn`IEL -, I \\''''''.'"----- AroeaG TOE LEGEND SCALE 200 9 100 200 0 = WELL CONDUCTOR AS-BUILT THIS SURVEY 1" _ 200' __.iiit S„PV&4880C SPY ISLAND DRILL SITE sE 4" WELL CONDUCTORS AS-BUILT LOCATIONS @i II1I .i ._. e • ,,nxa CA. LUSS` ��)p rating DAtiQ/01/2010 DRAWING NO: Eni-3543—d9 PARREV: 10/01/2010 ,., : II • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian Well No, Alaska State Plane, NAD83 GRID NAD83 Geographic Section Line Offset Pad 'Y' 'X' Latitude (N) Longitude (W) F N.L F.E_L [lev. ,'r (US ft.) (US ft.) ( 1 605342120 1651769.82 70033'27.209" 149°54'24.765" 797 1171 12.4 6053421.65 1651761.87 70033'27.194" 149054'25.000" 798 1179 12,4 3 6053420.07 1651754.10 70033'27.179" 149054'25.229" 800 1186 12.4 4 6053418.56 1651746.17 70°33'27.164" 149°54'25.463" 801 1194 12.4 5 6053417.03 1651738.44 70°33'27.149" 149°54'25.692" 803 1202 12.4 6 6053415.54 1651730.54 70°33'2.7.134" 149°54'25.925" 804 1210 12.4 _ 7 6053412.44 1651714.7770033'27.104" 149°54'26.391" 807 1226 12.4 8 6053410.91 1651706.96 70033'27.089" 149054'26.622" 809 1234 12.4 9 6053409.39 1651699.11 70°33'27.074" 149054'26.853" 810 1241 12.4 10 6053407.94 1651691.31 70033'27.060" 149054'27.084" 812 1249 12.4 11 6053406.32 1651683,39 70°33'27.044" 149054'27.318" 813 1257 12.4 12 6053404.80 1651675.51 70033'27,029" 149°54'27.551" 815 1265 12.4 13 6053400.38 1651652.80 70°33'26.986" 149°54'28.221" 819 1288 12.4 14 6053398.83 1651644.95 70°33'26.971" 149°54'28.453" 821 1296 12.4 15 6053397.31 1651637,12 R 70°33'26.956" 149054'28.685" 822 1304 12.4 16 6053395.82 1651629.26 70°33'26.942" 149°54'28,917" 824 1311 12.4_ 17 6053394.32 1651621.47 70033'26.927" 149054'29.147" 825 1319 12.4 18 6053392.78 1651613.58 70033'26.912" 149°54'29.380" 827 1327 12.4 19 6053389.63 1651597.90 70033'26.881" 149054'29.843" 830 1343 12.4 20 6053388.17 1651590.00 70033'26.867" 149054'30.076" 831 1351 12.4 21 6053386.60 1651582.24 70°33'26.852" 149°54'30.306" 833 1358 12.4 22 6053385.19 1651574.35 70033'26.838" 149054'30.538" 834 1366 12.4 23 6053383.64 1651566.41 70°33'26.823" 149054'30.773" 8361374 12.4 24 6053382.12 1651558.61 70033'26.808" 149°54'31.003" 837 _ 1382 12.4 25 6053377.65 1651535.94 70°33'26.764" 149°54'31.673" 842 1405 _ 12.4 26 6053376.14 1651528.13 70°33'26.750" 149054'31.904" 843 1413 12.4 27 6053374.53 1651520.23 70033'26.734" 149°54'32.137" 845 1421 12.4 28 6053373.11 1651512.46 70033'26.720" 149054'32.366" 846 1428 12.4 29 6053371.56 1651504.49 70033'26.705" 149°54'32.602" 848 1436 12.4 _ 30 6053370.06 1651496.66 70°33'26.690" 149054'32.833" 849 1444 12.4 _ _ 31 6053367.05 1651480.97 70033'26.661" 149°54'33.296" 852 1460 12.4 32 6053365.47 1651473.16 70033'26.646" 149054'33.527" 854 1468 12.4 33 6053363.93 1651465.22 70°33'26.631" 149°54'33.762" 855 1476 I 12.4 34 6053362.44 1651457.37 70"33'26.616" 149"54'33.993" 857 1483 12_.4 35 6053360.91 1651449.52 70°33'26.601" 149°54'34.225" 858 1491 12.4 36 6053359.33 1651441.62 70033'26.586" 149°54'34.459" 860 1499 12.4 37 6053356.19 1651425.30 70"33'26.555" 149°54'34.941" 863 1516 12.4 38 6053354.74 1651417.32 70°33'26.541" 149°54'35.177" 864 1524 12.4 __ S@0,4&arson SPY ISLAND DRILL SITE :: WELL CONDUCTORS • AS-BUILT LOCATIONS us C oprairin DATE, DRAWING NO: PART: REV: 10/01/200 Eni-3543-d9 3 OF 3 0 A v a N o o � ro �ILI • NI u = Lu -a a 7 d 7 7 10 .0 V V a a .0 a a v v a .0 V .0 .0 a .0 v V Y U 01 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 < 20 a w H H H H H H H 1 .--1 .-1 H H H H H H H H H .-I H H H H H H H H N 06 'C • w . 3 c N -J e-1 01 l0 7 N 0 tO CF e-1 al f\ V1 CO t0 V H01 I, CO e-1 00 t0 V N VI M H00 ON N 00 01 0 r1 N en .0 .0 VI to 00 01 0 v--I H N V Vl UI tO I, CO 0 -I N N O 3 w . 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N tO to tO to t0 Io v1 to 7 16 >- M M M m m m m m m M Y m m M M m M cn M M M Q In to In to In to In In v1 u1 @ 0 0 0 0 0 0 0 0 0 0 y0 Q tD t0 t0 t0 t0 t0 t0' t0 to tD u U7 U O = O O 5,'•-•..,... t\r1O CO O m O (..) N O 'O O Z Ol O ri Ni M In t0 N 00 CO rtis, N M m M M m M M M M 0 E. Y w E a, Y, a, V O f0 _o to 0 V 0 0 0 0 • • Attachment 8 1/4 Mile Scan Report 0 0 O O o O O O 0 0 0 co O O o 0 0 0 0 0 0 0 0 0 CO LC) V CO N ,- O 7 N 1 1 1 1 1 I o R.-o - a - o co a_ CO n a n Cn W L ,L (n a. V. O o o - Z Y_ CD d L - o L. N Z CI) N cCQtes E co g O �! a o r o O8 0 C/3 Cl) Y co P.A m J W il; it O M %949 �8`[a W CO O 3 O C7 CD 7 O i C O V .U. ,`oft at(. d O Cl) Z r Cr' a, • y� C/) L Y p'/8[ F. 1t111.'A "= a ru CO CD or f .�p •' p p t1/`4 L t6 • 0 0 S 9 Y d m R H .4': +''iH8 Z 4`( o co • Z � t ` /° Z J O ' "¢t(B °req J `° ami 0 N o _ O ••"� :: yyi r[b �.C, b/ O 7 d p - Cr pp�,Gp[f5(f Oma,/ P - O 11 cr LL co Fi ,9 e '16.0e,a p ° J 0) .o �(•� -I/�f 12( co W co Y E�,�,o���,,� [[: m •F. O '{(49, O'((Bd!D'CC �`r[(Dp ° p��01 iY ° O cn i °;1;2:',,,„/ -1.1. ,,,,Q:Neii Qte,04, -,?..,,, -° 4 14 �/.•p___111((( , ,e‘96/4u)11' `� E 1, N �LL _ m ^ D Jb PA Abl;: M / M `ILoMa a • o%0a o j Z �( amO Ob % K WY p • CO CO a. C w • :GAL i 0'.,,'..r1 � O a[� 06q .e: � O 6. ! ,, .57 .4, 1°4 .. ('-ze(7* ii .i.L1i ` . ,i 00 0 0 00 0 0 0 0 0 o n o 0 0 0 0 0 CD lO Z J V CDs--N N W Z Z °D n Li, a v (11)0096:6=eleoS(14)SN CD o <7 Cl to CD • • SP01-SE7L1 (P7)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: June08.2015-12:21 North Reference: True Analysis Machine: AKA-DEC-9010 Client Eni Petroleum Database I Protect: localhosnddlling-Nikaitchuq 2.8 572 Version I Patch: 2.8.572.0 NOTE:Measured Depth is referenced to individual borehole elevation. ND,NS,EW are referenced to the reference trajectory's wellhead location and borehole elevation. A minimum of 0.300 m is always included for borehole diameters. All local minima Indicated. Results filtered:Depth 9650.00 ft c=MD<=19279.65 ft,Ct-Ct separation<=1500.00 ft Results highlighted:EOU-EOU separation<=1320.00 ft And-Collision Rules Used Rule Set Name DAM AnbCollision Standard 5002 v5.1/5.2 Exemption Risk Level: Minor Sole Name Risk Level Rule Tone Rule Label Romeo Roll SLB Alert Zone Threshold OSF=5.05002 v5.1/5.2 Alert Ratio OSF=5.00 SLB Minor Risk Threshold OSF=1.5 S002 v5.1/5.2 Minor Ratio OSF=1.50 X SLB Major Risk Threshold OSF=1.0 S002 v5.1/5.2 Major Ratio OSF=1.00 SLB Surface Rule 5002 v5.115.2 Major CT_CT MAS=32.01(ft) SLB Alert Zone Threshold CtCt<=15m 5002 v5.15.2 Alen CT_CT MAS=49.21(ft) • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 1 of 13 • • Reference Trajectory Summary Field: Nikekchuq Well: SPOISE7 Structure: Spy Island Borehole: SPOISE7LI Slot SP01 Trajectory: SPOI-SE7LI(P7) Client: Eni Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Plane,Zane 04,US Feet North Reference: True Grid Convergence Angle: 0.09079271° Grid Scale Factor: 0.999900157 Magnetic Declination: 18908° Magnetic Declination Date: June 20 2015 Magnetic Model: BGGM 2015 Reference Point Northing EGO/111.9 J=,leveSog Structure Unc Slot Unc 6053671.080(ftUS) 511739.020(ftUS) 54 100(ft)MSL 0.000(ft)(1 sigma) 0000(ft)(1 sigma) Traleclory Error Model'ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prod'While Drilling Description Part MD From(ft) MD To(ft)EOU Freq(ft) Survey Tool Type Hole Site(In) Casing Diameter(In) Borehole/Survey 1 0.000 41.000 1/100.000 SLB_GWD70-Depth Only-No Gleba 16.000 13.375 SP01-SE7/SP01-5E7(P7) 1 41.000 850.000 1/100.000 SLB_GW07O-No Gleba 16.000 13.375 SP01-SE7/SPO1-SE7(P7) 1 850.000 2350.000 1/100.000 SLB_MWD+SAG-No Gleba 16.000 13.375 SP01-SE7/SP01SE7(P7) 2 850.000 3383.369 1/100.000 SLB MIW+GMAG-No Globe 16.000 13375 SP01-SE7/SP013E7(P7) 2 3383.369 4880.000 1/100.000 SLB_MWD+SAG-No Gleba 12.250 9.625 SP01-SE7/SP01-SE7(P7) 3 3383.369 9650.000 1/100.000 SLB_MWD+GMAG-No Globe 12.250 9.625 SP01-SE7/SP01SE7(P7) 3 96509 00. 00 100000 1/100.000 SLB MWD-INC_ONLY FILLER-No Globe 8.750 5.500 SP01-SE7L1/SP01SE7LI(P7) 3 10000.000 11500.000 1/100.000 SLB MWD+SAG-No Globe 8.750 5.500 SP01-SE7L7/SP01SE7LI(P7) 4 10000.000 19279.645 1/100.000 SLB_MWD+GMAG-No Globe 8.750 5.500 SP01-SE7L1/SP01SE7L1(P7) Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 2 of 13 • S Offset Trajectory Summary Offset Selection Criteria; Offset Selection Criteria:Definitive Surveys-Definitive Plans-Definitive surreys exclude definitive plans - -All Non-Def Surveys when no Det-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Selection Summary Wells Selected:6 Boreholes Selected:10 Definitive Surveys Selected:8 Non-Def Surveys Selected:0 Definitive Plans Selected:2 Non-Det Plans Selected:0 Total Trajectories:10 OSF filter in detailed report None 'Excluded:The trajectory was analyzed and fully passed all criteria so the detailed resuhs have been excluded from this report for clarity. Trajectory Borehole Well Type Passing Excluded' SP01 SE7(P7) SPOISE7 SP01SE7 Det Plan Nikaitchrxi 4 Nikaitchuq 4 Nikaitchuq 4 Def Survey Nikaitchuq 4PB1 Nikaitchuq 4PB1 Nikaitchuq 4 Def Survey Nikaitchuq 3PB1 Nikaitchuq 3PB1 Nikaitchuq 3 Def Survey Nikaitchuq 3PB2 Nikaitchuq 3PB2 Nikaitchuq 3 Def Survey Niketohuq 3PB3 Nikaitchuq 3PB3 Nikaitchuq 3 Def Survey Nikaitchuq 3 Nikaitchuq 3 Nikaitchuq 3 Def Survey 5102-SE6(P3) S102-SE6 5102-SE6 Def Plan Nikaitchuq 1 Nikaitchuq 1 Nikaitchuq 1 Def Survey Nikaitchuq 2 Nikaitchuq 2 Nikaitchuq 2 Def Survey Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 3 of 13 • • Field: Nika0rhuq Well: SPOT-SE7 Structure: Spy Island Borehole: SPOI-SE7 Slot SPOT Trajectory. SPOISE7(P7) Client: Eni Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Glen.,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.09079271° Grid Scale Factor. 0.899900157 Magnetic Declination: 18.908° Magnetic Declination Date: June 20,2015 Magnetic Model: BGGM 2015 Reference Point Northine Eastlna Elevation Structure Unc. Slot Unc. 6053671 080(ftUS) 511739.020(998) 54.100(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Traiectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Survevin9 Proo:While Drilling Description Part MD From(ft) MD To(R) EOU Freq(ft) Survey Tool Type Nota Site fin) Casing Diameter(in) Borehole I Survey 1 0.000 41.000 1/100.000 SLB_GW070-Depth Only-No Global 16.000 13.375 SPOI-SE7/SP01SE7(P7) 1 41.000 850.000 1/100.000 SLB_GWD70-No Globa 16.000 13.375 SP01-SE7/SP01-SE7(P7) 1 850.000 2350.000 1/100.000 SLB_MWD+SAG-No Globa 16.000 13.375 SP01-SE7/SP01SE7(P7) 2 850.000 3383.389 1/100800 SLB_MWD+GMAG-No Globa 16.000 13.375 SP01-SE7/SP01SE7(P7) 2 3383.389 4880.000 1/100000 SLB_MWD+SAG-No Globe 12.250 9.625 SP01-SE7/SP01SE7(P7) 3 3383.369 10084.947 1/100.000 SLB MWD+GMAG-NO Globe 12250 9.625 SP01-SE7/SP01SE7(P7) 3 10084.947 11600.000 1/100.000 SLB_MWD+SAG-No Globa 8.750 5.500 SPOISE7/SP01SE7(P7) 4 10084.947 19243.574 1/100.000 SLB_MWD+GMAG-NO Globe 8.750 5.500 SP01-SE7/SP01SE7(P7) Minimum Allowable Traveling Cylinder Allowable Deviation from EOU-EOU Controlling Reference MD Reference NO Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW North Azim Ct-Ct Distance Separation Reference Clearance OSF Rule Stabs (9) (ft) (ft) (ft) (9) (ft) (ft) (ft) Cl (h) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 9650.00 ft<=MD<=19279.65 ft Results filtered:Ct-Ct separation Se 1500.00 ft Results highlighted:Ct-Ct separation<_1320.006 9650.00 4132.90 4798.11 3551.89 9650.00 413290 4798.11 3551.89 ( 0.001 80.:. 1114,M -001 OSF1.50 Fail 9666.00 4134.06 4788.93 3563.27 9666.00 473430 4786.84 3563.16 284.07 0 28 30.81 -13053 -87.33 IMMEED OSF1.50 Fail 9750.00 4139.76 4729.51 3624.31 9749.93 414161 4727.72 362228 256.89 3.28 4946 -146.18�'- Ii 0.02 05F1.50 Fail 9800.00 4144.60 4696.69 366172 979982 4145.96 4692.57 3657.43 233.98 6.10 529 -96.6 0.05 OSF1.50 Fail 10098.69 4171.03 4515.08 3896.95 1009576 4171.75 4484.11 3865.89 217.30 43.87 93.54 -149.6 E.ga 0.33 OSF1.50 Fail 10100.00 417103 451431 3898.00 10087.05 417186 4483.20 3866.80 217.42 44.07 93.81 515arg 033 OSF1.50 Fail 11150.00 4164.06 3890.08 4741.87 11158.58 4171.53 3817.14 4689.30 220201 90.24 21727 -127.05 -5504 0.62 OSF1.50 Fail 11500.00 4186.04 3687.36 5026.32 11507.74 4189.52 3612.86 497245 205.44 93.41 231.351- -137951 -61241 0.61 OSFI.50 Fail 12500.00 4193.41 3102.07 5836.97 12507.79 4178.81 3027.94 5783.46 206 is'IMINEp1616' 22767 -13509 -59.61 0.61 OSF1.50 Fail 12850.00 4184.38 2898.02 6121.13 1285770 418480 2823.26 6067.18 216.1 4 g51ig 243.04 -150.85 -7024 0.56 OSF1.50 Fail 13000.0 4176.42 2810.28 6242.53 1300726 4188.29 2735.78 6188.44 223.18 92.83 249.32 -156.49 -73.,. OSF1.50 Fail 13046.35 4173.13 278326 6280.04 13053.53 4188.33 2708.72 6225.95 22562 93.50 250.61 IIRA11 17171711k1910 OSF1.50 Fai 13600.00 4103.59 2465.24 6727.50 13812.40 4109.14 238942 6675.58 218.1.Iniii1IMME2 26423 - .1• +'.4•gf OSF1.50 Fail 13631.12 1702.81 2447.63 6753.16 13613.35 4104.85 2371.89 67170.71 275.47 92.15 264.4fik156O5FI.50 Fail 14150.00 4111.50 2153.38 7179.84 14160.44 4113.16 2080.84 7126.64 21674 89.971 27939 -189.42 �. r. OSF1.50 Fail 14200.00 4118.85 2124.58 7220.04 1420997 4118.60 2051.64 7166.27 215.62 9082 280.280.. 0• 0SF1.50 Fail 1470000 4177.86 183113 7618.67 14706.01 4164.19 175759 7562.82 208,77 93.31 29038 -1• .' -100.64 0.48 OSF1.50 Fail 15900.00 4163.76 1120.14 8584.89 15908.04 4164.19 104576 853122 2161 917 33674 -245.01 -133.17 0.40 OSFI.50 Fail 16050.00 4156.29 1032.43 8706.35 16057 68 4167.06 958.22 8652.55 222.52 9230 34368 -251.39 -137.4 0.401 06E150 Fail 16650.00 4148.32 88142 919281 16657.91 4164.87 607.05 9139.30 226,051 93,10 363.99 -27089 -149.97 038 0SF1.50 Fail 1740000 4166.39 242.78 9800.82 17407.76 4168.98 168.48 974726 21610 915 38962 -298. -168.561 0.31 05F1.50 Fail 17450.00 4168.52 213.80 9841.37 17457.58 416484 139.37 9787.63 213.44 9172 389.78' -298.061 -168.54 0.35 OSF1.50 Fe 1824217 4172.25 -249.72 10483.67 18249.71 4153.52 -323.93 10429.91 2042 40673 -31320 -178.03 0.34 OSF1.50 Fai 1905000 415663 -721 81 11138.84 19057.54 4158.88 -796.42 1108492 ' 217.i. fiEE 450.43 158.35 -208.62 0.30 OSF1.50 Fai 1915000 4151.87 -780.29 11219.81 19157.20 416242 -854.68 11165.69 222.36 9 -9 45511 -362.52 -211.24 0.301 OSF1.50 Fai .00 192004149.49 -80953 11260.30 19207.02 4164.19 403.81 11206.08 224.90 93.13 456.33) -363.201 -211.50 0.30 05F150 Fai 19250.00 4147.11 -838.77 11300.79 19243.57 4165.50 -905.18 1123570 226.74 94.78 455.88 -361.10 -209.55 931 OSF1.50 Fai 1927985 4145.70 -856.11 1132479 19243.57 4165.50 -905.18 1123570 226.74 103.61 430.07 -326.48 -183.51 0.36 05F1.50 Fai End of results • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 4 of 13 • • Field: Nikedchuq Well: Nikeifchug4 Structure: Nikaitchuq Exploration Borehole: Nikaitchug4 Slot Nike4chuq 4 Trajectory: Nikaitchuq 4 Client ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.15195056° Grid Scale Factor: 0.999900438 Magnetic Declination: 24.253' Magnetic Declination Date: February 28,2005 Magneto Model: BGGM 2008 Reference Point: Northi d2195805 Eleva8on Structure Unc. Slot Unc. 6054828 380(ftUS) 519642.990(ftUS) 31.260(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Trajectory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Surveyjns Pros:As Drilled Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Size(In) Casing Diameter fin) Borehole l Survey 0.000 28.920 1/98.425 SLB_MWD+GMAG-Deprn Only-No Global 30000 30.000 Nikaitchuq 4PB1/Nikaitchuq 4PB1 28920 28920 Act-Stns SLB_MWD+GMAG-Depth Only-No Global 30.000 30.000 Nikaitchuq 4PB1/Nikaitchuq 4PB1 28920 2842.580 Act-Stns SLB_MW9+GMAG-No Global 30.000 30.000 Nikaitchuq 4PBI/Nikaitchuq 4PB1 2842.580 7577.000 ActSbis SLB_MWO+GMAG-No Global 30.060 30.000 Nikaitchuq 4/Nikaitchuq 4 Minimum Allowable Traveling Cylinder Allowable Deviation from EOU-EOU Controlling Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Reference Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (5) (8) (°) (ft) (8) (ft) (ft) All local minima indicated. Results filtered:Depth 9650.00 ft<O MD<=19279.65 ft Results filtered.Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation no 1320.00ft 9650.00 4132.90 4798.11 3551.89 7577.00 4207.98 4320.00 5666.68 49.20 2169.46 44.93 024.54 2070.94 23.31 OSF1.50 Pass 9668.00 413406 4786.93 3563.27 7577.00 4207.98 4320.00 5666.68 45.57 2155.88 45.82 010.06 2056.75 23.02 OSF1.50 Pass 9686.00 4135.20 4773.06 3577.64 7577.00 4207.98 4320.00 5666.68 4557 2138.85 46.05 99280 2039.57 22.81 OSF1.50 Pass 9700.00 4136.04 4763.39 358772 7577.00 4207.98 4320.00 5666.68 45.78 2126.93 46.21 980.72 2027.54 22.65 OSF1.50 Pass 9750.00 4139.76 4729.51 3624.31 7577.00 4207.98 4320.00 5666.68 46.62 2084.14 46.90 93724 1984.27 22.10 OSF1.50 Pass 9800.00 4144.60 4696.69 3661.72 7577.00 4207.98 4320.00 5665.68 47.66 2041.03 47.60 893.43 1940.68 21.54 OSF1.50 Pass 9850.00 4150.54 466498 3699.90 7577.00 4207.98 4320.00 5666.68 48.90 1997.63 48.87 848.76 1896.42 20.90 00F1.50 Pass 9885.00 4155.50 4642.84 3727.86 7577.00 420798 4320.00 5666.68 4991 1966.22 49.89 816.33 1864.32 20.43 OSF1.50 Pass 9900.00 4157.48 4634.35 3738.81 7577.00 4207.98 4320.00 5666.58 48.89 195398 50.45 803.53 1851.70 20.22 OSF1.50 Pass 9950.00 4163.43 4604.11 3778.18 7577.00 4207.98 4320.00 566668 4519 1910.27 53.98 756.30 1805.63 19.30 OSF1.50 Pass 0000.00 4167.68 4573.99 381786 7577.00 4207.98 4320.00 5666.68 4144 1886.62 5713 709.49 1759.86 18.47 OSF1.50 Pass 0050.00 4170.22 454405 3857.82 7577.00 4207.98 4320.00 566668 3765 1823.08 60.41 66267 1714.12 17.66 OSF1.50 Pass 0098.69 4171.03 4515.08 3896.95 7577.00 420798 4320.00 5666.88 33.97 1780.83 63.71 817.13 1669.66 16.89 OSF1.50 Pass 0100.00 417103 451431 389800 7577.00 420758 4320.00 5666.68 33.87 1779.70 63.80 615.91 1668.47 16.87 OSF1.50 Pass 0142.10 4170.38 448946 393197 7577.00 4207.98 4320.00 566668 30.72 174337 64.70 578.67 1631.53 16.43 OSF1.50 Pass 0150.00 4170.15 4484.81 3938.36 7577.00 4207.98 4320.00 5666.68 30.72 1736.57 64.88 571.70 1624.81 16.35 OSF1.50 Pass 0200.00 4168.66 4455.40 3978.77 7577.00 4207.98 4320.00 5666.68 30.72 169379 66.01 527.79 1581.06 15.84 OSF1.50 Pass 0250.00 4167.16 4425.99 4019.18 7577.00 4207.98 4320.00 5666.68 30.72 165141 67.21 484.20 1537.87 15.33 05F1.50 Pass 0300.00 4165.67 4396.58 4059.59 7577.00 4207.98 4320.00 5666.68 30.72 160947 68.47 44101 149509 14.82 OSF1.50 Pass 0350.00 4184.18 4367.17 4100.00 7577.00 4207.98 4320.00 566668 30.72 156801 69.82 398.19 1452.71 14.32 OSF1.50 Pass 0400.00 4162.69 4337.77 4140.41 7577.00 4207.98 4320.00 5666.68 30.72 152705 71.22 355.83 1410.81 13.83 OSF1.50 Pass 0426.19 4181.90 4322.36 4161.57 7577.00 4207.98 4320.00 566068 30.72 1505.82 71.99 333.83 1389.06 13.58 OSF1.50 Pass 0450.00 4181.32 4308.29 4180.77 7577.00 4207.98 4320.00 5666.68 31.96 1488.69 72.71 313.98 1369.44 13.34 06F1.50 Pass 0454.31 4161.24 430573 4184.23 7577.00 4207.98 4320.00 5666.68 3219 1483.25 72.84 310.41 1365.92 13.30 OSF1.50 Pass 0478.79 4180.94 4291.10 4203.86 757700 4207.98 432000 5066.68 33.43 1463.86 73.61 290.25 1346.01 13.07 OSF1.50 Pass 0500.00 4160.79 4278.35 422081 7577.00 4207.98 4320.00 5666.68 33.43 144724 74.30 272.93 1328.92 12.87 OSF1.50 Pass 0550.00 416044 424831 4260.78 7577.00 4207.98 4320.00 5666.68 33.43 1408.53 76.02 23251 1289.06 12.40 OSF1.50 Pass 0600.00 4180.09 421827 4300.75 757700 4207.98 432000 5666.68 33.43 137055 77.80 19275 1249.89 11.94 OSF1.50 Pass 0650.00 4159.73 4188.23 4340.72 7577.00 4207.98 4320.00 5666.68 33.43 1333.37 79.70 153.67 1211.44 11.48 OSF1.50 Pass 070000 4159.38 4158.19 438089 7577.00 420798 4320.00 5666.68 3343 1297.04 8185 115.39 1173.81 11.05 OSF1.50 Pass 075000 4159.03 4128.15 4420.66 7577.00 420798 4320.00 5666.68 33.43 1261.66 83.74 07792 113703 10.62 OSF1.50 Pass 0800.00 4158.68 4098.11 4460.62 7577.00 420798 4320.00 5666.68 33.43 1227.29 85.87 041.42 1101.25 10.20 OSF1.50 Pass 0850.00 4158.33 4058.07 450059 7577.00 4207.98 4320.00 5666.68 33.43 1194.03 88.12 005.91 1066.48 9.80 OSFI.50 Paas 090000 4157.97 4038.03 454056 7577.00 4207.98 432000 5666.68 33.43 1161.96 90.40 971.56 1032.90 9.42 OSF1.50 Pass 0950.00 4157.62 4007.99 4580.53 757700 4207.98 432000 5666.68 3343 1131.20 92.78 938.44 1000.57 905 OSF1.50 Pass 095483 4157.59 400521 4584.23 7577.00 4207.98 4320.00 5666.68 33.43 1128.42 92.98 935.44 99765 9.02 OSFI.50 Pass 0971.57 4157.53 399505 459778 7577.00 4207.98 4320.00 5666.68 33.59 1118.34 93.78 924.56 98704 890 OSF1.50 Pass 1000.00 4157.70 3978.06 4620.58 7577.00 4207.98 4320.00 5666.68 33.84 1101.71 95.11 908.60 969.53 870 OSF1.50 Pass 1050.00 4158.80 3948.43 466083 7577.00 4207.98 4320.00 5666.68 34.24 1073.41 9749 87593 '.66 8.37 OSF1.50 Pass 1100.00 4160.93 3919.10 4701.27 7577.00 4207.98 4320.00 566688 34.80 1046.40 848.57 9 . OSFI.50 Peas 113792 4163.23 3897.06 4732.05 7577.00 4207.98 4320.00 5666.68 34.84 1.+.': 201.61 825.24 890.38 7.83 OSF1.50 Pass 1150.00 4164.06 389008 4741.87 7577.00 4207.98 432000 5666.68 34.84 4 r.81 202.18 818.62 883.96 76 . F1.50 Pass 1200.00 418749 3861.15 478251 757700 4207.98 4320.00 5666.68 34.:• 996.97 204.50 79247 85861 OSF1.50 Pass 1250.00 4170.92 383223 4823.15 7577.00 4207.98 432000 5666 61 • 3975.11 206.78 768.33 83526 724 OSF1.50 Pass 150000 4186.04 3687.36 5026.32 7316.98 4206.93 4092.05 5791.66 -27 866.01 211.00 655.01 723.��^7s 6 `SF1.50 Pass 3400.00 4123.38 257991 656502 5618.02 4186.12 2619.99 6638.35 353.59 104.50 15774 -53.231 -2.47J 0.9 0 1.50 Fail 3550.00 4106.03 2493.81 6686.55 5488.38 4185.81 2504.88 670182 317.521 81.95 88.81 5.86 21.87 1.38 OS 1.50 Fad 3700.00 4102.13 2408.85 6810.07 534861 4185.44 2384.44 6768.99 27674 96.05 128.06 32011 10.041 1.121 OS' .50 Fail 375000 410156 2380.70 685139 530745 4185.95 2348.65 678931 268.09 109.56 145.531 35961 11.89 1.12 OS' .50 Fail End of results • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 5 of 13 I • Field: Nikadchuq Well: Nikaifchuq 4 Structure: Nikadchuq Exploration Borehole: Nikaifchuq 4P81 Slot Nikadchuq 4 Trajectory: Nikeilchuq 4PB1 Client EN! Type: De/Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feel North Reference: True Grid Convergence Angle: 0.15195056° Gdd Scale Factor. 0999900438 Magnetic Declination: 24.261° Magnetic Declination Date: February 21,2005 Magnetic Model: BGGM 2008 Reference Point Norihi05 Eastlno Elevation Structure Unc. Slot Unc. 6054828.380(ftUS) 519642990(NUS) 31.260(ft)MSL 0.000(ft)(1 sigma) 0000(ft)(1 sigma) Tralectory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Surveying Pros:As Drilled Description MD From(ft) MD To OR EOU Freq Survey Tool Type Hole Sloe(In) Casing Diameter(in) Borehole/Survey 0.000 28.920 1/98.425 SLB_MWD+GMAG-Depth Only-No Global 30.000 30.000 Nikaifchuq 4PB1/Nikaifchuq 4P B1 28.920 28.920 Act-Stns SLB_MWD+GMAG-Depth Only-No Global 30000 30.000 Nikaifchuq 4PB1/Nikaitchuq 4PB1 28.920 4310.000 Act-Stns SLB_MWD+GMAG-No Global 30.000 30.000 Nikaifchuq 47131/Nikaitchuq 4781 Minimum Allowable Traveling Cylinder Allowable Deviation from EOU-EOU Controlling Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Reference Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 9650.00 ft<=MO<=19279.65 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 15400.00 4177.74 1412.75 8179.82 4159.94 4181.41 1144.34 8006.69 216.531 319.421 213.92 105.51 176.17 225 0071.50 Warning 1545000 4177.38 1383.47 822034 4160.46 418193 1144.34 8006.71 216.63 320.70 218.331 102.371 174.501 2711 0571.50 Warning End of results Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 6 of 13 I • Field: Nikakchuq Well: Nikeitchug3 Structure: Nikeitchuq Exploration Borehole: Nikeitchuq 3P131 Slot Nikeitchuq 3 Trajectory: Nikeitchuq 3P81 Client: EN) Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: Tnre Grid Convergence Angle: 0.15001276° Grid Seale Factor: 0.999900427 Magnetic Declination: 24.250° Magnetic Declination Date: March 01,2005 Magnetic Model: BGGM 2008 Reference Point Norhlna 5451(80 Elevation Structure Unc. Slot Une. 6054826.970(ftUS) 519392490(ftUS) 31.400(ft)MSL 0000(ft)(1 sigma) 0.000(ft)(1 sigma) Traleetory Error Model:ISCWSAO 3-0 95.000%Confidence 2.7955 sigma Survevino Proof:As Drilled Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Size(In) Casing Diameter(In) Borehole/Survey 0.000 29060 1/98.425 SLB_MWD+GMAG-Depth Only-No Global 30000 30.000 Nikeitchuq 3P131/Nikeitchuq 3PB1 29.060 29060 Act-Stns SLB_MWD+GMAG-Depth Only-No Global 30.000 30.000 Nikeitchuq 3P131/Nikeitchuq 3PB1 29.060 9309000 Act-Stns SLB_MWD+GMAG-No Global 30.000 30000 Nikaitchug3PB1/Nikaifchuq 3PB1 Minimum Allowable Traveling Cylinder Allowable Deviation from EOU-EOU Controlling Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azlm Ct-Ct Distance Separation Reference Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 9650.00 ft<=MD<=19279.65 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation co 1320.00 ft 1510874 4179.44 158404 7944.27 4153.10 4175.33 117786 7650.57 216.7.E 20944 291.81 360.99 3.61 OSF1.50 Warning 15131.31 4179.48 1570.47 796229 415309 417532 1177.86 7650.57 21632 501.32 21091 290.411 360. 3.58 OSF1.50 Warning 15150.00 417946 1559.31 797729 4153.02 4175.25 1177.86 7650.57 215.96 502.26 211.88) 290.381 360.3 3.571 OSF1.50 Warning End of reruns Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 7 of 13 • • Field: Nikwtchuq Well: Nikaitchug3 Structure: Nikefichug Exploration Borehole: Nikaitchuq 3PB2 Slot Nikedchug 3 Trajectory: Nikaitchuq 3PB2 Client: ENI Type: Dal Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.15001276' Grid Scale Factor 0.999900427 Magnetic Declination: 24.222' Magnetic Declination Date: March 25.2005 Magnetic Model: BGGM 2008 Reference Point NorthingEd5852 Elevation Structure Line. Slot Unc. 6054826 970(ftUS) 519392.490(505) 31.400(ft)MSL 0000(ft)0 sigma) 0000(ft)(1 sigma) Traleetory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prov:As Drilled Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Size(in) Casing Diameter(In) Borehole/Survey 0.000 29060 1/98.425 SLB_MWD+GMAC-Depth Only-No Global 30000 30.000 Nikaitchuq 3P01/Nikaitchuq 3PB1 29060 29.060 Act-Stns SLB_MWD+GMAG-Depth Only-No Global 30.000 30.000 Nikaitchuq 3P91/Nikaitchuq 3PB1 29.060 7991 620 Act-Stns SLB_MWD+GMAG-No Global 30.000 30.000 Nikaitchuq 3P81/Nikaitchuq 3P81 7991.620 9640.000 Act-Stns SLB_MWD+GMAG-No Global 30000 30.000 Nikaitchuq 3PB2/Nikaitchuq 3PB2 Minimum Allowable Traveling Cylinder Allowable Deviation from EOU-EOU Controlling Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Reference Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (51 (ft) (°) (ft) (ft) (ft) (ft) All local minima indicated. Results filtered:Depth 9650.00 ft<=MD c 19279.65 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation<=132000 ft 15108 74 4179.44 1584.04 7944.27 415310 4175.33 1177.86 7850.57 216.7 08'40 209.44 291.81 300.99 3.61 05F1.50 Warning 15131.31 4179.48 1570.47 7962.29 4153.09 4175.32 1177.86 7650.57 216.32 501.32 210.91. 280.41 360.08 3.58 05E1.50 Waming 15150.00 4179.46 1559.31 797729 4153.02 417525 1177.86 7650.57 215.96 50226 211681 290.38 380.371 3.51 OSF1.50 Waming End of results Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 8 of 13 • • Field: Nikaitchuq Well: Nikaitchug3 Structure: Nikaitchuq Exploration Borehole: Nikaitchuq 3PB3 Slot. Nikaitchuq 3 Trajectory. Nikaitchuq 3PB3 Client ENI Type: Del Survey Coordinate System: NAD27 Alaska Stele Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.15001276° Grid Scale Factor: 0.999900427 Magnetic Decilnafon: 24.222° Magnetic Declination Date: March 25.2005 Magnetic Model: BGGM 2008 Reference Point NOM�in Easana Elevation Structure Une. Slot Unc. 6054826.970(SOS) 519392.490(ftUS) 31.400(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Trajectory Error Model:ISCWSA03-D 95.000%Confidence 2.795S sigma Survevine Prod:As Drilled Description MD From(R) MD To(R) EOU Freq Survey Tool Type Hole Size(in) Casing Diameter(in) Borehole/Survey 0.000 29.060 1/98.425 SLB_MWD+GMAG-Depth Only-No Global 30.000 30.000 Nikaitchuq 3PB1/Nikaitchuq 3PB1 29.060 29.060 Act-Stns SLS_MWD+GMAG-Depth Only-No Global 30.000 30.000 Nikaitchuq 3PB1/Nikaitchuq 3PB1 29.060 6659.010 Act-Stns SLB_MWDvGMAG-No Global 30000 30.000 Nikaitchuq 3P61/Nikaitchuq 3PB1 8659.010 9292.000 Act-Stns SLB_MWD+GMAG-No Global 30.000 30.000 Nikaitchuq 3PB3/Nikaitchuq 3PB3 Minimum Allowable Traveling Cylinder Allowable Deviation from EOU-EOU Controlling Reference MD Reference TVD Reference NS Reference EW Offset MD Offset ND Offset N5 Offset EW North Azim Ct-Ct Distance Separation Reference Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (9) (ft) (ft) All local minima indicated. Results filtered:Depth 9650.00 ft<=MD<=19279.65 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted Ct-Ct separation r_1320.00 ft 15108 74 4179.44 1584.04 794427 4153.10 417533 1177.86 7650.57 216721 501.261 209.44 291.81 360.99""9 3.61 OSF1.50 Warning 1513131 4179.48 1570.47 7962.29 415309 4175.32 1177.86 7850.57 21632 501.32 21091. 290.411 360.01 3.58 09F1.50 Warning 1515000 4179.48 155931 797729 415302 4175.25 1177.86 7650.57 215.96 502.26 21181 290381 360.371 3.571 OSF1.50 Warning End of results Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 9 of 13 • I Field: Nikadchuq Well: Nikailchug3 Structure: Nikaitchuq Exploration Borehole: Nikailchug3 Slot Nikaddruq 3 Trajectory: Nlkailchuq 3 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.15001276' Grid Scale Factor: 0999900427 Magnetic Declination: 24.203. Magnetic Declination Date: 46110,2005 Magnetic Model: BGGM 2008 Reference Point NOMina .E _shi Elevation Structure Unc. Slot Unc. 6054826 970(ftUS) 519392.490(ftUS) 31.400(ft)MSL 0.000(ft)(1 sigma) 0000(ft)(1 sigma) Tra)ectory Error Model:ISCWSAO 0-0 93.000%Confidence 2.7935 sigma Surveying Prot As Drilled Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Size(in) Casing Diameter(in) Borehole I Survey 0.000 29060 1198.425 SLB_MWD+GMAG-Depth Only-No Global 30.000 30.000 Nikaitcluq 3PB1/Nikaitchuq 3PB1 29060 29060 Act-Stns SLB MWD+GMAG-Depth Only-No Global 30.000 30.000 Nikaitchuq 3PB1/Nikaitchuq 3PB7 29060 6659.010 Act-Sins SLB_MWD+GMAG-No Global 30.000 30.000 Nikaitchuq 3PB1/Nikaitchuq 3PB1 6659.010 9143.680 Act-Stns SLB_MWD+GMAG-No Global 30.000 30.000 Nikaitchuq 3PB3/Nikaitchuq 3PB3 9143.680 12066.000 Act-Stns SLB_MWD+GMAG-No Global 30.000 30.000 Nikaltchuq 3/Nikaitchuq 3 Minimum Allowable Traveling Cylinder Allowable Deviation from EOU-EOU Controlling Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Reference Clearance OSF Rule Status (ft) (ft) (ft) (RI (ft) (8) (8) (0) ('1 (ft) (ft( (ft) (ft) All local minima indicated. Results filtered.Depth 9650.00 ft<=MD<0 19279.65 ft Results filtered.Ct-Ct separation<=150.00 0 Results highlighted:Ct-Ct separation<=1320.00 ft 15108.74 4179.44 1584.04 7944.27 4153.10 4175.33 1177.86 7650.57 216.7.E 209.44 291.81 360.99 3.61 OSF1.50 Warning 15131.31 4179.48 1570.47 7962.29 4153.09 4175.32 1177.86 7650.57 216.32 501.32 21091 20.411 360.08 3.58 OSF1.50 VWming 15150.0 4179.46 1559.31 797729 4153.02 4175.25 1177.86 7850.57 215.96 502.26 211881 20 303 3.571 OSF1.0 Warning End of results Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 10 of 13 • . Field: NiktNchuq Well: 5102-SE6 Structure: Spy Island Borehole: SI02-SE6 Slot SP02 Trajectory: SI02-SE6(P3) Client: En/Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.09073117 Grid Scale Factor: 0.999900156 Magnetic Declination: 20.204. Magnetic Declination Date: December 15,2012 Magnetic Model: BGGM 2011 Reference Point: oN rthlna .M .gin Elevation Structure Unc. Slot Unc. 6053669.530(ftUS) 511731.060(ftUS) 54.100(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Tralectory Error Model:ISCWSAO 3-1) 95.000%Confidence 2.7955 sigma Survevino Proc:While Drilling Description Part MD From(ft) MD To(ft)EOU Freg(ft) Survey Tool Type Hole Size(in) Casing Diameter(In) Borehole I Survey 1 0.000 41.000 1/100.000 SLB GWD70-Depth Only-No Globe 16.000 13.375 S102SE6/S102-SE6(P3) 1 41.000 1000.000 1/100.1100 SLBGW070-No Globe 16000 13.375 0102SE6/5102-5E6(P3) 1 1000.000 2717.529 1/100.000 SLB_MW_D+SAG-NO Globs 16.000 13.375 5102SE6/5102-SEB(P3) 00 2 10.000 2717.528 1/100.000 SLB_MWD+GMAG-No Globe 16.1100 13.375 S102-5E6/S102-SE6(P3) 2 2717.528 4220.000 1/100.000 SLBMWD+SAG-No Globe 12250 9.825 S102SE6/SI02-SE6(P3) 3 2717.489 8383.040 1/100.000 SLB_M_WD+GMAG-No Globe 12250 9.625 5102-SE6 I 5102-5E6(P3) 3 8383.040 9880.000 1/100.000 SLB_MWD+SAG-NO Globs 8.750 5.500 S102SE6/SI02-SE6(P3) 4 8363.040 18268.818 1/100.000 SLB_MWD+GMAG-No Globe 8.750 5.500 5102-SE6/S102-SE6(P3) Minimum Allowable Traveling Cylinder Allowable Deviation from EOU-ECU Controlling Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Reference Clearance O5F Rule Status (6) (0) (ft) (ft) (ft) (ft) (11) (5) (') (ft) (0) (ft) (ft) All local minima indicated. Results filtered:Depth 9650.00 ft<=MD<=19279.65 ft Results filtered:Ct-Ct separation<-1500.00 ft Results highlighted:Ct-Ct separation<=1320.00ft 11137.92 4163.23 3897.06 4732.05 9539.16 4078.92 2764.75 394427 211.•r�. .0 213.57 115206 1222.84 1222.8--4rr 9.641 OSF1 50 Pass 1145000 418171 2 211.21 1366.21 50 Pass 11500.00 4186.04 368736 5026.32 9900.62 4080.78 257575.42 4985.70 9850.67 408052 2 4239.8 211.18 1366.14 227.17 1138981 1214.291 9.061 OSF1.50 Pass 13500.00 4110.20 2522.50 6645.81 11895.06 4091.02 1422.54 5866.38 214.4.ililiniK 261.38 1086.88 1173.60 777 06F1.50 Pass 19279.65 4145.70 -5611 1132479 17666.24 4120.66 -1914.43 10574.91 214.7. 464.411 832.891 987.291 4 201 06F1.50 Warning End of results Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 11 of 13 • . Field: Nikeitchuq Well: Nikeitchuq I Structure: Nikeitchuq Exploration Borehole: Nikeitchuq 1 Slot Nikeitchuq 1 Trajectory: Nikeitchuq I Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska State Plane.Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.15098706° Grid Scale Factor: 0999900433 Magnetic Declination: 24.690° Magnetic Declination Date: February 28,2004 Magnetic Model: BGGM 2008 Reference Point oN Mlng Eastina Elevation Structure Une. Slot Unc. 6054881.080(ftUS) 519518.280(ftUS) 35 940(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Traleetory Error Model:ISCWSA03-D 95.000%Confidence 2.7955 sigma Surveying Pro%As Drilled Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Size(in) Casing Diameter(In) Borehole/Survey 0.000 33.600 1/98.425 SLB_MWD+GMAG-Depth Only-No Global 30.000 30.000 Nikeitchuq 1/Nikeitchug1 33.600 33.600 Act-Stns SLB_MWD+GMAG-Depth Only-No Global 30.000 30.000 Nikeitchuq 1/Nikeitchuq 1 33.600 11010.000 Act-Stns SLB_MWD+GMAG-No Global 30.000 30.000 Nikeitchuq 1/Nikeitchuq 1 Minimum Allowable Traveling Cylinder Allowable Deviation from EOU-E0U Controlling Reference MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW North Azim Ct-Ct Distance Separation Reference Clearance OSF Rule Status (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (ft) All local minima indicated. Results filtered Depth 9650.00 ft c=MD<=1927965 ft Results filtered.Ct-Ct separation c=1500.00 ft Results highlighted'.Ct-Ct separation<=1320.00 ft 11500.00 4186.04 368736 5026.32 5030.66 4179.04 3693.98 7679.69 3922 265339 169.70 2483.69 2538.47 24.17 05F1.90 Pass 13900.00 409966 229623 6975.34 4034.52 3426.92 3040.97 7669.45 67.97 122036 176.66 1043.69 1101.16 1058) 0891.50 Pass 14000.00 409979 2239.74 7057.84 399668 3400.73 3018.00 7668 72 70.09 1211.43 174231 1037.2(1( 1093.95 10.64 OSF1.50 Pass 14050.00 410198 2211.12 7098.78 3983.58 3388.62 300739 7668.39 71.221 1211.361 172.67 1038.69 1094.98 10.73 OSF1.50 Pass End of results Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 12 of 13 • I Field: Nikadchuq Well: Nikaithug2 Structure: Nikedchug Exploeeo'on Borehole: Nikaithuq 2 Slot Nikadchug 2 Trajectory: Nikeilchuq 2 Client: ENI Type: Del Survey Coordinate System: NAD27 Alaska Stele Plane,Zone 04,US Feet North Reference: True Grld Convergence Angle: 0.21235468° Geld Seale Factor. 0.99990)857 Magnetic Declination: 24.898° Magnetic Destination Date: March 20.2004 Magnetic Model: BGGM 2008 Reference Point ftorthlnq Easting Elevation StructuUnc. re Slot Una. 6052263.000(ftUS) 527462330(SUS) 39.950(ft)MSL 0.000(ft)(1 sigma) 0.000(ft)(1 sigma) Tralectory Error Model:ISCWSAO 3-6 95.000%Confidence 2.7955 sigma Surveying Prom As Drilled Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Size(In) Casing Diameter(In) Borehole I Survey 0.000 37.610 Act-Stns SLB MWD+GMAG-Depth Only-No Global 30.000 30.000 Nikaitehuq 2/Nikaitchug2 37.610 343160 1/98.425 SLB_MWD0GMAG-No Global 30.000 30.000 Nikaithuq 2/Nikaitchug2 343.460 11001.000 Act-Stns SLB_MWD+GMAG-No Global 30.000 30.000 Nikaitchuq 2/Nikaitchug 2 Minimum Allowable Traveling Cylinder Allowable Deviation horn EOU-EOU Controlling Reference MD Reference ND Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW North Azim Ct-Ct Distance Separation Reference Clearance OSF Rule Status (ft) (ft) (ft) (ft) (5) (ft) (0) (8) (°) (ft) (ft) (8) (ft) All local minima indicated. Results filtered:Depth 9650.00 ft<=MD<C 19279.65 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 1927965 4145.70 -856.11 11324.79 3892.62 3497.75 -14.97 15783.93 44.451 4583.811 254.531 4329.281 4411.381 27.861 OSF1.50 Pass End of results • Drilling Office 2.8.572.0 Nikaitchuq\Spy Island\SP01-SE7\SP01-SE7L1\SP01-SE7L1(P7) 6/8/2015 12:22 PM Page 13 of 13 • • 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: I\) t c1-ch S O 1-•SE7 L,1 PTD: /S l ✓ Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: IJ �h�1Lcti POOL: /v i j\c.r fah �GIikJ-�201 L / Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. a.J_�- O� API No. 50-CZ1 - 02_36-1-1 -t3� - Gc� / (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( 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 conservation Spacing Exception 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 also required for this well: Well Logging 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 2/2015 0 0 N , , , , N a) a N N , - C O, QU, 0. L I f6 C' mp, C C, , c0' L, H O, , C, J ami "ii U0: , , 3, f0 Q in, v, W, W Q. 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JD555UwOOn. aU5, Q, a, Z, UUUUUU, Q, Q, , Om, m, U 5, y 2, a-, 0, u), U, U,a O e- N M [t LO CO I's 00 O O N M ti-) CO Imo. co O O .-- N Min (0 I-- a0 O E 7- N M 47 M (O T C0 0) ,- 1- e- v- �•' '- <- N N N N N N N N N N M M M M C9 M M M M M U _ in tr) 4) o EO a) O a) p U C ct O O 0a) to _) 0) m '0 O 0) O N d Lo ate+ (D c M co 0 E J p 0 °1 O O J k G m c a U) o a m 0 W dIQ Q a c a -1 0 oy a s W Q U Q Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: August 4, 2015 Surface Data Logging End of Well Report SP01-SE7 SP01-SE7 L1 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: SP01-SE7 & SP01-SE7 L1 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23542-00-00 (SP01-SE7) 50-629-23542-60-00 (SP01-SE7 L1) Sperry Job Number: AK-XX-0902490118 Job Start Date: 13 June 2015 Spud Date: 15 June 2015 Total Depth: 19180’ MD, 4150’ TVD (SP01-SE7) 19093’ MD, 4163’ TVD (SP01-SE7 L1) North Reference: True Declination: 18.881° Dip Angle: 81.097° Total Field Strength: 57500.227 nT Date Of Magnetic Data: 07 July 2015 Wellhead Coordinates N: North 70° 33' 28.24578" Wellhead Coordinates W: West 149° 54' 13.38141" Drill Floor Elevation 53.51’ Ground Elevation: 13.10’ Permanent Datum: Mean Sea Level SDL Engineers: Kori Jo Plowman, Gregory Dellner, Leigh Ann Rasher, A. Paul Kalenuik, Rebecca Mulkey SDL Sample Catchers: Kyle Blazian, Jacob Floyd, Mario Luescher Company Geologist: Josh Zuber Company Representatives: Jack Keener / Mike Ross / Bruce Simonsen SSDS Unit Number: 110 DAILY SUMMARY 06/13/2015 SDL continues on location from previous well. Skid rig floor into drilling position. Rig up operation in preparation for pre-spud acceptance. 06/14/2015 Rig continues rig up operations. Set SDL mud logging unit. SDL unit receives power and begins rig up operations. Begin to calibrate gas equipment and network computers for sending data. Nipple up and test diverter system. Test cement lines. Pick up 5” drill pipe. 06/15/2015 Complete gas calibrations and computer networking. Test mud line. Make up BHA #1. Drill out conductor casing to 160’ MD and pull out of hole. Make up BHA #2 and wash down to 160’ MD. Drill to 391’ MD. Pull out of hole to make up remaining BHA. Drill from 391’ MD to 778’ MD. Gas: Max gas observed was 10 units at 696' MD with an average gas of 6 units Fluids: No fluid lost to formation 06/16/2015 Continue to drill surface section from 778’ MD to 2,843’ MD. Gas: Max gas observed was 1542 units at 2,502' MD with an average gas of 154 units Fluids: No fluid lost to formation 06/17/2015 Continue to drill surface section from 2,843’ MD to surface TD of 3,597’ MD. Begin to backream out of the hole. Gas: Max gas observed was 190 units at 3,068' MD with an average gas of 93 units Fluids: No fluid lost to formation 06/18/2015 Continue to backream out of hole. Lay down BHA #2. Rig up Volant casing equipment and run in the hole with 13-3/8” casing. Make up hanger and landing joint and land casing. Circulate and condition mud for cement job. Gas: Max gas observed was 11units Fluids: No fluid lost to formation 06/19/2015 Perform cement job. Nipple up diverter and test hanger. Nipple up BOP and install test plug. Test BOP, pull test plug and install wear ring. Pick up 5” drill pipe 06/20/2015 Continue to pick up 5” drill pipe. Pick up BHA #3. Run in the hole to 1,750’ MD and shallow hole test tools. Continue to run in to 3,493’ MD and test cement. Service rig. Drill out float equipment, casing shoe, and 20’ of new formation to 3,617’ MD. Displace well from spud mud to LSND water-based mud. Gas: Max gas observed was 29 units at 3,613' MD with an average gas of 19 units Fluids: No fluid lost to formation 06/21/2015 Continue to displace well. Perform leak-off test to 12.52 lb/gal equivalent mud weight. Cut and slip drill line. Drill ahead through 12.25” intermediate section from 3,617’ MD to 6,051’ MD. Gas: Max gas observed was 139 units at 3,859' MD with an average gas of 31 units Fluids: No fluid lost to formation Geology: Samples consist of mainly clean sandstone with areas of siltstone and coal 06/22/2015 Continue to drill intermediate hole section from 6,051’ MD to 8,290’ MD. Gas: Max gas observed was 51 units at 8,057' MD with an average gas of 16 units Fluids: No fluid lost to formation Geology: Samples consist of mainly clean sandstone with areas of siltstone 06/23/2015 Continue to drill intermediate section from 8,290’ MD to intermediate TD of 10,168’ MD. Begin to backream out of the hole. Gas: Max gas observed was 3891 units at 10,059' MD with an average gas of 143 units Fluids: No fluid lost to formation Geology: Samples consist of sandstone with large areas of siltstone between 9,250’ MD and 10,000’ MD 06/24/2015 Continue to backream out of the hole Gas: Max gas observed while backreaming was 185 units Fluids: No fluid lost to formation 06/25/2015 Continue to backream out of the hole. Lay down BHA #3. Rig up Volant casing equipment. Run in the hole with 9-5/8” casing. Gas: Max gas observed was 5 units Fluids: No fluid lost to formation 06/26/2015 Continue to run in the hole with 9-5/8” casing to 10,148’ MD. Rig down casing equipment and rig up cement head. Circulate and condition mud. Gas: No significant gas data. Fluids: No fluid lost to formation 06/27/2015 Continue to circulate and condition mud. Cement 9-5/8” casing. Rig down cement head. Raise BOP stack, cut casing and pull casing wear ring. Nipple up BOP and lines. Rig up BOP testing equipment and test BOP Gas: No significant gas data. Fluids: No fluid lost to formation 06/28/2015 Rig down BOP test equipment, pull test plug and set wear ring. Test 9-5/8” casing. Pick up 4.5” drill pipe. Pick up BHA #4 and run in hole to 1,786’ MD and shallow hole test MWD tools. Continue to run in the hole with BHA #4. Gas: No significant gas data. Fluids: No fluid lost to formation 06/29/2015 Change over to 5” handling equipment and rotate in hole to top of cement at 10,043’ MD. Displace well from LSND to 9.4 lb/gal FazePro oil-based mud. Drill out shoe track to 10,128’ MD and cut and slip drill line. Continue to drill out shoe track and 20’ of new hole. Perform formation integrity test to 12.95 lb/gal equivalent mud weight. Drill ahead through 8.75” production hole section to 11,524’ MD. Gas: Max gas observed was 1442 units at 10,851' MD with an average gas of 726 units Fluids: No fluid lost to formation Geology: Samples consist of clean fine grain sandstone 06/30/2015 Continue to drill ahead through 8.75” production hole section from 11,524’ MD to 14,328’ MD. Gas: Max gas observed was 1764 units at 12,703' MD with an average gas of 478 units Fluids: No fluid lost to formation Geology: Samples consist of clean fine grain sandstone from 11,500’ MD to 13,350’ MD and sandstone and siltstone from 13,350’ MD to 14,300’ MD 07/01/2015 Continue to drill ahead through 8.75” production hole section from 14,328’ MD to 16,849’ MD. Gas: Max gas observed was 1062 units at 16,695' MD with an average gas of 431 units Fluids: No fluid lost to formation Geology: Samples consist of clean fine grain sandstone 07/02/2015 Continue to drill ahead through 8.75” production hole section from 16,849’ MD to 19,089’ MD. Gas: Max gas observed was 2110 units at 18,873' MD with an average gas of 920 units Fluids: 37 barrels lost to formation Geology: Samples consist of clean fine grain sandstone 07/03/2015 Continue to drill ahead through 8.75” production hole section from 19,089' to production TD at 19,180' MD. Downlink, shoot survey, and perform slow pump rates. Circulate bottoms up for two stands and backream to 18,998'. Backream out of hole from 18,998' MD to 14,270' MD. Gas: Max gas observed was 1649 units at 19,132' MD with an average gas of 1247 units Fluids: 105 barrels lost to formation Geology: Samples consist of clean fine grain sandstone 07/04/2015 Backream out of hole from 14,270' MD to 9,473' MD. Service and inspect top drive, blocks, hook and shot pin and change out saver sub. Gas: Max gas observed while tripping was 16 units Fluids: 49 barrels lost to formation 07/05/2015 Backream out of hole from 9,473' MD to 1,120' MD. Circulate hole and reciprocate pipe from 1,120' MD to 1,060' MD. Pull out of hole on elevators to 362' MD. Lay down BHA #4. Service rig. Change out saver sub for 5" drill pipe. Gas: Max gas observed while tripping was 8 units Fluids: 33 barrels lost to formation 07/06/2015 Change out saver sub. Service crown, top drive, and draw works. Rig up Volant casing tool. Run in hole with 5.5" slotted liner to 9,119' MD. Rig down Volant casing equipment. Bring Baker equipment to rig floor. Make up liner hanger assembly, slim hole MWD, and scribe. Make up Baker string magnets and crossover to 9,194' MD. Run in hole one stand of 5" drill pipe. Run in hole on elevators with 5" drill pipe to 10,250' MD. Rotate to 10,595' MD. Run in hole on elevators from 10,595' MD to 11,059' MD. Gas: Max gas observed while running liner was 10 units Fluids: No fluid lost to formation 07/07/2015 Run in hole with 5.5" liner with 5" drill pipe on top from 11,059' MD to 19,090' MD. Orient and set hanger. Set packer and release running tool. Test Packer. Pull of hole with 5" drill pipe to 122' MD. Lay down string magnets, running tool and Slim Hole MWD. Clear rig floor. Mobilize Baker tools to floor. Lubricate rig. Makeup whipstock BHA and orient. Gas: Max gas observed was 4 units Fluids: 11 barrels lost to formation 07/08/2015 Run in hole with whipstock and mill assembly from 154' MD to 617' MD. Test MWD tools. Run in hole to 9,111' MD. Cut and slip drill line. Run in hole to 9,556' MD. Orient whipstock. Confirm latch and shear from whipstock. Mill 9-5/8" casing. Mill new hole to 10,006' MD. Backream out of hole to 9,897' MD. Pull out of hole to 98' MD. Lay down milling assembly BHA. Gas: Max gas observed was 16 units Fluids: 17 barrels lost to formation 07/09/2015 Continue to lay down milling assembly BHA. Flush stack. Rig up and test BOPEs. Rig down test equipment. Pull test plug. Set wear ring. Clear rig floor. Make up BHA #6. Run in hole from 368' MD to 1,500' MD and shallow test MWD tools. Run in hole to 9,192' MD. Rig up top drive table. Work on top drive. Gas: Max gas observed was 38 units Fluids: No fluid lost to formation 07/10/2015 Continue to work on top drive. Disassemble work platform and lay down. Clean rig floor. Run in hole on elevators from 9,192' MD to 9,480' MD. Change out 4.5" handling equipment to 5". Gas: No significant gas data. Fluids: No fluid lost to formation 07/11/2015 Run in hole from 9,480' MD to 9,995' MD. Circulate one annular volume. Stand one stand back to 9,945' MD. Conduct formation integrity test to 13.0 lb/gal equivalent mud weight. Wash down from 9,945' MD to 10,006' MD. Drill 8.75" lateral hole from 10,006' MD to 11,933’ MD. Gas: Max gas observed was 2737 units at 10,682' MD with an average gas of 1156 units Fluids: No fluid lost to formation Geology: Samples consist of clean fine grain sandstone 07/12/2015 Drill 8.75" lateral hole from 11,874' MD to 13,350' MD. Control drilling for anti-collision at 30 ft/hr per geologist to 13,599' MD. Gas: Max gas observed was 1912 units at 12,504' MD with an average gas of 714 units Fluids: No fluid lost to formation Geology: Samples consist of clean fine grain sandstone with areas of siltstone and shale 07/13/2015 Control drilling 8.75" lateral hole for anti-collision at 30 ft/hr per geologist from 13,584' MD to 13,800' MD. Drill from 13,800' MD to 15,079' MD. Gas: Max gas observed was 1150 units at 14,882' MD with an average gas of 249 units Fluids: No fluid lost to formation Geology: Samples consist of clean fine grain sandstone with areas of siltstone and shale 07/14/2015 Drill 8.75" lateral hole from 15,079' MD to 16,233' MD. Backream out of hole from 16,233' MD to 16,200' MD. Repair top drive shot pin motor. Wash down from 16,200' MD to 16,233' MD. Drill from 16,233' MD to 17,133' MD. Gas: Max gas observed was 1895 units at 16,748' MD with an average gas of 249 units Fluids: No fluid lost to formation Geology: Samples consist of clean fine grain sandstone with areas of siltstone and shale 07/15/2015 Drill 8.75" lateral hole from 17,133' MD to lateral TD at 19,093 MD. Backream out of hole and circulate one bottoms-up per stand from 19,093' MD to 18,909' MD. Gas: Max gas observed was 1895 units at 16,748' MD with an average gas of 249 units Fluids: 4 barrels lost during backreaming. Geology: Samples consist of clean fine grain sandstone 07/16/2015 Backream out of hole from 18,909' MD to 13,732' MD. Gas: Max gas observed during backreaming was 111 units Fluids: 20 barrels lost during backreaming. 07/17/2015 Backream out of hole from 13,732' MD to 10,338' MD. Gas: Max gas observed during backreaming was 35 units Fluids: 54 barrels lost during backreaming. 07/18/2015 Backream out of hole from 10,338' MD to 1,791' MD. Gas: Max gas observed during backreaming was 8 units Fluids: 32 barrels lost during backreaming. 07/19/2015 Finish backreaming out of hole. Run in hole to 9,922' MD to retrieve whipstock. Pull out of hole from 9,962' MD to 9,082' MD. Gas: Max gas observed during circulation was 10 units Fluids: 11 barrels lost during backreaming. 07/20/2015 Pull out of holw with whipstock from 9,082' MD to surface. Run in hole with clean out assembly. Gas: Max gas observed was 7 units. Fluids: 16 barrels lost while pulling out of hole. 07/21/2015 Pull out of hole with clean out assembly. Run in hole with diverter to 9,926' MD. Pull out of hole to 6,482' MD. Gas: Max gas observed was 6 units. Fluids: 9 barrels lost while running in and out of hole. 07/22/2015 Pull out of hole from 6,482' MD to 40' MD. Lay down tools. Test BOPE. Rig up and run in hole with 5.5" Liner to 2,141' MD. Gas: Max gas observed was 5 units. Fluids: 10 barrels lost while running in and out of hole. 07/23/2015 Run in hole from 2,141' MD to 19,026' MD with 5.5" Liner. Pull out of hole to 9,802' MD. Gas: Max gas observed was 4 units. Fluids: No fluid lost. 07/24/2015 Pull out of hole with 5" drill pipe from 9,336' MD to 80' MD. Run in hole to 9,900' MD with lateral entry module. Pull out of hole to 8,705' MD. Gas: Max gas observed was 4 units. Fluids: 16 barrels lost. 07/25/2015 Pull out of hole with 5" DP from 9,835' MD to 98' MD and lay down in pipe shed. Gas: Max gas observed was 3 units. Fluids: 8 barrels lost. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 0 5 10 15 20 25 30 35 40 45 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: SP01-SE7 & SP01-SE7 L1 OPERATOR: ENI Petroleum MUD CO: MI Swaco RIG: Doyon 15 SPERRY JOB: AK-XX-0902490118 Days vs. Depth 13 June 2015 Sperry SDL Continue on Location LOCATION: Nikaitchuq AREA: North Slope Borough STATE: Alaska SPUD: 15-Jun-2015 TD: 15-Jul-2015 Commenced 16" Surface Hole Section On Bot: 08:00 15 Jun 2015 TD Surface Hole Section 3597' MD, 2508' TVD Off Bot: 08:45 17 Jun 2015 Landed 13.375" Casing 3577' MD, 2502' TVD 18 Jun 2015 Commenced 12.25" Intermediate Hole Section On Bot: 04:30 21 Jun 2015 Commenced 8.75" Production Hole Section On Bot: 11:00 29 Jun 2015 TD Intermediate Hole Section 10168' MD, 4171' TVD Off Bot: 21:30 23 Jun 2015 Landed 9.625" Casing 10148' MD, 4170' TVD 26 Jun 2015 TD Production Hole Section 19180' MD, 4150' TVD Off Bot: 00:30 3 Jul 2015 Mill Window Top: 9957' MD, 4157' TVD Bot: 9974' MD, 4158' TVD Commenced 8.75" L1 Production Hole Section On Bot: 03:30 11 Jul 2015 TD Production Hole Section 19093' MD, 4163' TVD Off Bot: 19:45 15 Jul 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: The gas chromatograph started to read very small values of "unknown" gas. This problem was resolved by recalibrating the chromatograph. Recommendations: Make sure all gas equipment has a good calibration and configurations before drilling. Innovations and/or cost savings: N/A No major issues were encountered during surface section. SP01-SE7 Nikaitchuq ENI Petroleum North Slope AK-XX-0902490118 Alaska Doyon 15 Surface Leigh Ann Rasher 21-Jun-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: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: The rig power did go out for a short time but backup power worked as it should to keep all equipment on and functional. There were no other real difficulties. Intermediate section went smoothly. Recommendations: N/A Innovations and/or cost savings: N/A Doyon 15 Intermediate Kori Jo Plowman 28-Jun-2015 What went as, or better than, planned: There were no major issues during intermediate section. Computers and equipment ran well SP01-SE7 Nikaitchuq ENI Petroleum North Slope AK-XX-0902490118 Alaska Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: The #4 computer failed but was able to restart without problem. Recommendations: Currently all systems are functioning as they should and have been streamlined to maximum efficency. No recommendations at this time. Innovations and/or cost savings: N/A All systems ran as they should. We were able to log the well and monitor systems without hinderence from malfuntion. Sample collection went well with no problems. Regular maintenance and properly installed equipment did not result in condensation causing issues with the gas gear. Did not experience any networking problems. SP01-SE7 Nikaitchuq ENI Petroleum North Slope AK-XX-0902490118 Alaska Doyon 15 Production Alexander Kalenuik 3-Jul-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: Sperry Drilling Confidential Document v 3.0 What went as, or better than, planned: Systems ran as they should. We were able to log the well and monitor systems with minor malfuntion. Sample collection went well with no problems. Computers worked as expected. Did not experience any networking problems. SP01-SE7 Nikaitchuq ENI Petroleum North Slope AK-XX-0902490118 Alaska Doyon 15 Production L1 Rebecca Mulkey 23-Jul-2015 Difficulties experienced: The 8900 chromatograph began to register false "unknown" peaks. Switched to the back up 8900 chromatograph. The backup failed to ignite when attempted to bring it online. Both units where sent to the shop for maintenance. This malfuntion lead to 870' of lost chromatograph data. Recommendations: Make sure to check backup equipment functionality on a regular basis to avoid downtime. Innovations and/or cost savings: N/A Surface Data Logging After Action Review WELL NAME:SP01-SE7 & SP01-SE7 L1 LOCATION:Nikaitchuq OPERATOR:ENI Petroleum AREA:North Slope Borough MUD CO:MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:15-Jun-2015 SPERRY JOB:AK-XX-0902490118 TD:15-Jul-2015 Marker MD INC AZ TVD TVDSS 16" Surface Borehole 20" Conductor Shoe 160.0 0.4 293.8 160.0 -106.5 SV-4 773.0 13.1 17.7 770.0 -716.4 SV-3 1,151.0 29.4 11.8 1,120.4 -1,066.9 SV-2 1,469.0 42.0 9.6 1,380.5 -1,327.0 Permafrost Base 2,000.0 39.5 12.2 1,783.3 -1,729.8 SV-1 2,230.0 47.5 12.9 1,950.9 -1,897.3 Ugnu Top (UG4)2,844.0 67.8 11.8 2,289.0 -2,235.5 13 3/8" Casing Shoe 3,577.0 73.8 9.9 2,503.0 -2,449.5 TD 16" Borehole 3,597.0 73.7 10.1 2,508.6 -2,455.1 12.25" Intermediate Borehole UG-2 Coal Bed Marker 5,020.0 74.8 9.2 2,883.9 -2,830.4 Lower Ugnu 7,488.2 68.4 68.4 3,637.9 -3,584.3 Schrader Bluff 8,555.7 77.2 109.4 3,958.6 -3,905.1 N Sequence Top 8,630.0 77.9 111.5 3,974.5 -3,921.0 N Sand Top 8,848.3 77.3 119.9 4,022.0 -3,968.8 N Sand Bottom 9,020.0 79.6 127.4 4,056.7 -4,003.2 N Sequence Base 9,250.0 83.5 134.0 4,090.8 -4,037.3 OA Sand Top 10,028.0 85.4 134.5 4,163.2 -4,109.7 OA-2 10,110.0 87.2 134.7 4,168.3 -4,114.8 9 5/8" Intermediate Casing 10,148.0 87.2 134.3 4,170.2 -4,116.7 TD 12 1/4" Borehole 10,168.0 87.4 134.2 4,171.2 -4,117.7 8.75" Lateral Borehole OA-3 10,170.0 87.4 134.2 4,171.3 -4,117.8 OA-3 11,210.0 90.9 123.8 4,182.3 -4,128.8 OA-2 11,310.0 91.0 123.8 4,180.3 -4,126.7 OA Sand Top 13,166.2 93.6 126.9 4,177.2 -4,123.7 OA Sand Top 14,826.0 87.0 125.1 4,168.4 -4,114.9 OA-2 15,993.6 88.0 123.2 4,171.6 -4,118.1 OA-3 16,114.0 88.0 123.6 4,175.8 -4,122.3 OA-3 17,698.5 92.2 123.4 4,163.3 -4,109.8 OA-2 17,805.0 93.0 124.5 4,158.6 -4,105.1 TD SP01-SE7 19,180.0 89.9 126.0 4,149.6 -4,096.1 8.75" Lateral Borehole TOW 9,957.0 85.1 134.1 4,157.1 -4,103.6 BOW 9,974.0 87.0 133.4 4,158.3 -4,104.8 OA Sand Top 10,035.0 85.6 131.4 4,162.2 -4,108.7 OA-2 10,127.0 87.9 128.5 4,168.5 -4,115.0 OA-2 10,254.0 91.4 124.5 4,168.5 -4,115.0 OA-2 11,145.0 88.2 128.0 4,183.0 -4,129.5 OA-3 11,275.0 86.2 130.0 4,188.6 -4,135.1 OA-3 12,720.0 92.7 125.4 4,194.0 -4,140.5 OA-2 12,809.0 92.4 125.0 4,190.4 -4,136.9 OA Sand Top 12,993.0 93.7 129.2 4,180.1 -4,126.6 OA Sand Top 14,200.0 85.1 124.3 4,173.3 -4,119.8 OA-2 14,262.0 86.0 124.5 4,178.1 -4,124.6 OA-3 14,336.0 88.8 124.3 4,181.5 -4,128.0 OA-3 16,302.0 91.9 127.5 4,169.3 -4,115.8 OA-2 16,531.0 91.9 126.8 4,163.7 -4,110.2 OA-2 17,695.0 88.1 127.7 4,154.4 -4,100.9 OA-3 17,803.0 87.9 128.0 4,158.4 -4,104.9 TD SP01-SE7 L1 19,093.0 90.3 126.2 4,162.7 -4,109.1 Formation Tops SP01-SE7 SP01-SE7 L1 SP01-SE7 & SP01-SE7 L1 ENI Petroleum MI Swaco Doyon 15 AK-XX-0902490118 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/R 6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec cP lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 14-Jun 160 8.80 196 37 57 21/40/54 -131/94/75/54/21/18 2/NA 3.0 0/97 0.00 0.20 9.7 22.0 .10/.30 1500 100 Install Diverter Pup 15-Jun 665 9.00 130 34 40 21/51/66 5.0 108/74/61/45/21/19 2/NA 3.8 0/96.25 0.15 0.30 9.7 24.0 .20/.65 2700 100 Drilling 16" Hole 16-Jun 2644 9.40 118 28 33 22/51/65 4.9 89/61/50/37/26/18 2/NA 4.0 0/96 0.15 0.25 9.7 24.0 .15/.60 2700 80 Drilling 16" Hole 17-Jun 3597 9.40 93 29 30 21/50/66 4.8 88/59/47/34/16/14 2/NA 4.5 0/96 0.15 0.25 9.7 24.0 .15/.60 2600 80 BROOH 18-Jun 3597 9.40 68 22 16 --60/38/22/16/8/5 ----------Cement 19-Jun 3597 9.40 58 17 14 --48/31/21/15/8/5 ----------P/U 5" DP 20-Jun 3617 9.30 46 8 22 8/10/11 6.3 38/30/25/20/11/8 2/NA 4.0 2/94 -3.50 9.8 -3.00/2.00 5750 100 Displace Well 21-Jun 5765 9.30 61 16 38 17/20/24 6.3 70/54/49/40/17/15 2/NA 4.5 3/93 0.10 1.30 9.9 6.0 .60/2.20 4800 120 Drilling 12.25" Hole 22-Jun 7998 9.30 56 15 25 12/24/35 5.8 55/40/34/26/13/10 2/NA 5.0 3/93 0.10 1.00 9.8 11.0 .60/2.10 5300 120 Drilling 12.25" Hole 23-Jun 10135 9.50 62 17 25 15/36/53 5.8 59/42/35/26/15/12 2/NA 5.3 3/92 -1.10 9.8 13.0 .70/2.10 5000 120 Drilling 12.25" Hole 24-Jun 10168 9.50 58 16 22 13/39/66 5.7 54/38/33/23/13/11 2/NA 5.5 3/92 0.15 1.10 9.7 14.0 .70/2.10 5100 120 BROOH 25-Jun 10168 9.30 54 13 21 10/26/41 6.0 47/34/28/20/12/9 2/NA 5.0 3/93 0.20 1.00 9.6 14.0 .60/2.10 4000 120 RIH 9-5/8" Csg 26-Jun 10168 9.50 52 15 16 8/15/20 -46/31/27/20/8/7 ----------Condition Mud 27-Jun 10168 9.30 49 15 15 8/14/18 -45/30/25/19/8/7 ----------BOP Testing Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/R 6/R3 Cake Solids Oil/Water Alka POM Excess Lime Elec Stab CaCl2 WPS LGS/HGS ASG Remarks ft - MD ppg sec cP lb/100 lb/100ft2 m/30m Rheometer 32nds %%ml ppb volts ppb ppm ppb ASG 28-Jun 10168 9.35 46 12 14 6/7/7 4.9 38/26/16/15/7/6 NA/2 NA 66/34 2.6 3.38 550 29.78 -7.96/54.54 2.7 RIH w/ BHA #4 29-Jun 11232 9.45 47 13 17 7/7/6 5.0 43/30/24/17/7/6 NA/2 6.5 65/35 2.6 3.38 658 29.69 -4.43/56.37 2.7 Drilling 8.75" Hole 30-Jun 13978 9.4 46 13 17 7/8/8 4.3 43/30/23/18/7/6 NA/2 7.72 66/34 2.3 2.99 730 --13.08/62.15 2.8 Drilling 8.75" Hole 1-Jul 16617 9.45 47 14 14 6/7/7 4.5 42/28/22/16/7/6 NA/1 8.14 67/33 2.1 2.73 725 28.91 -14.37/65.17 2.8 Drilling 8.75" Hole 2-Jul 18675 9.45 46 14 14 6/6/7 4.5 42/28/22/15/6/5 NA/1 8.5 67/33 2.4 3.12 740 29.31 -13.68/68.81 2.8 Drilling 8.75" Hole 3-Jul 19180 9.4 47 13 15 6/6/7 4.5 40/27/20/15/6/5 NA/1 8.29 67/33 2 2.6 745 29.62 -13.03/67.33 2.8 BROOH 4-Jul 19180 9.4 46 13 13 6/6/6 -39/26/20/15/6/5 NA/-8.28 68/32 2 2.6 730 29.99 -15.75/65.56 2.8 C/O Saver Sub 5-Jul 19180 9.4 46 13 12 6/6/6 -38/25/19/15/6/5 NA/-8.38 68/32 1.8 2.34 735 29.44 -16.83/65.78 2.8 C/O Saver Sub 6-Jul 19180 9.4 46 12 13 5/5/6 -37/25/17/12/6/5 -/-8.28 68/32 2.3 2.99 745 29.99 -15.75/65.56 2.8 Run 5.5" Liner 7-Jul 19180 9.4 55 13 13 5/5/6 -39/26/19/14/6/5 -/-8.28 68/32 2.1 2.73 740 29.99 -15.75/65.56 2.8 M/U Whipstock BHA 8-Jul 10006 9.4 52 14 11 5/5/6 -39/25/19/14/6/5 -/NA 8.28 68/32 2.2 2.86 690 29.99 -16.85/64.87 2.8 L/D Mill BHA 9-Jul 10006 9.45 52 15 12 5/6/6 -42/27/21/14/6/5 -/NA 8.23 68/32 2.3 2.99 660 30.25 -15.49/65.27 3 Work on Top Drive 10-Jul 10006 9.4 47 15 13 5/6/6 -43/28/22/15/6/5 NA/-8.28 68/32 2.1 2.73 670 29.99 -15.75/65.56 2.8 C/O Handling Equip 11-Jul 11714 9.45 49 14 12 5/5/6 4.6 40/26/18/13/6/5 NA/2 8.38 68/32 2.1 2.73 692 29.99 -15.98/66.30 2.8 Drilling 8.75" Hole 12-Jul 13521 9.45 52 17 13 5/6/6 4.8 47/30/23/15/6/5 NA/2 8.49 67/33 2.4 3.12 670 28.19 -21.36/64.04 2.9 Drilling 8.75" Hole 13-Jul 14798 9.45 50 17 10 5/6/6 4.6 44/27/21/14/6/5 NA/-8.59 67/33 2.2 2.86 610 29.18 -21.93/64.59 2.9 Drilling 8.75" Hole 14-Jul 16667 9.45 52 18 9 5/6/6 4.6 45/27/20/13/6/5 NA/2 8.64 66/34 1.7 2.21 670 27.95 -20.41/66.59 2.9 Drilling 8.75" Hole 15-Jul 19064 9.45 55 21 15 6/7/7 4.5 57/36/28/19/7/6 NA/2 8.89 67/33 2.0 2.6 616 29.08 -21.41/67.59 2.9 BROOH 16-Jul 19093 9.45 56 20 14 6/7/7 4.5 54/34/27/19/7/6 NA/2 8.83 66/34 2.1 2.73 695 28.79 -20.01/67.97 2.8 BROOH 17-Jul 19093 9.45 56 19 14 6/7/7 4.5 52/33/26/18/7/6 NA/2 8.83 65/35 2.2 2.86 688 27.93 -21.6/62.48 2.9 BROOH 18-Jul 19093 9.4 55 20 14 6/7/7 4.6 54/34/26/17/6/5 NA/2 8.66 64/36 2.1 2.73 747 28.62 -114.59/69.7 2.8 BROOH 19-Jul 19093 9.45 55 18 14 6/7/7 -50/32/24/16/6/5 NA/8.51 64/36 2.4 3.12 770 29.36 -13.77/68.88 2.8 POOH with whipstock 20-Jul 19093 9.45 57 18 14 6/7/7 -50/32/25/17/6/5 NA/-8.56 65/35 2.3 29.78 785 29.78 -16.15/67.66 2.8 POOH 21-Jul 19093 9.45 60 18 15 6/7/7 -51/33/26/18/6/5 NA/-8.64 65/35 2.3 2.99 750 29.78 -16.15/67.66 2.8 POOH 22-Jul 19093 9.45 60 18 15 6/7/7 -51/33/24/16/6/5 NA/-8.54 65/35 2.3 2.99 725 29.78 -17.25/66.98 2.8 RIH w/5.5" liner 23-Jul 19093 9.45 60 18 15 6/7/7 -51/33/26/16/6/5 NA/-8.26 65/35 2.3 2.99 695 30.07 -10.7/68.49 2.7 POOH 24-Jul 19093 9.45 60 18 15 6/7/7 -51/33/26/17/6/5 NA/-8.23 65/35 2.3 2.99 700 30.20 ---POOH 25-Jul 19093 9.2 28 ---------------POOH 26-Jul 19093 9.2 28 ---------------RIH Casing Record Remarks 20" Conductor @ 160' MD, 160'TVD 13.375" Casing @ 3577' MD, 2502'TVD 9.625" Casing @ 10148' MD, 4170'TVD WELL NAME:LOCATION:Nikaitchuq OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:15-Jun-2015 SPERRY JOB:TD:15-Jul-2015 W a t e r a n d O i l B a s e d M u d R e c o r d 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+ Milltooth 16.00 160 3597 3437 26.00 1.117 132.2 20 40 1850 800 2-1-CT-A-E-I-SD-TD TD 16" Surface Hole Section 3 200 2 Hycalog SKHI716D-E10C PDC 12.25 3597 10168 6571 38.00 0.969 173.1 10 180 2700 900 1-1-BT-A-X-IN-NO-TD TD 12.25" Intermediate Section 4 300 3 Hycalog SK616M-K1D PDC 8.75 10168 19180 9012 51.10 0.902 176.5 10 170 3750 550 1-1-CT-A-X-IN-WT-TD TD 8.75" Production Section 6 500 4 Hycalog SK616M-K1D PDC 8.75 9974 19093 9119 73.20 0.902 124.6 10 140 3650 550 1-2-BT-G-X-In-No-TD TD 8.75" L1 Production Section Alaska RIG:Doyon 15 SPUD:15-Jun-2015 WELL NAME:SP01-SE7 & SP01-SE7 L1 LOCATION:Nikaitchuq OPERATOR:ENI Petroleum AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902490118 TD:15-Jul-2015 MI Swaco STATE: B i t R e c o r d . . * 24 hr Recap:Continue rig up operations. Spot rockwasher, cuttings tank and assemble suitcases from rockwasher to SID WIF. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) - 0 14-Jun-2015 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: ConditionBit # 3.08.80 Size fabrication of diverter line pup & install same. diverter line pup. Continue rig up operations. Test cmt line to 4000 psi. OK. Diverter test w/5" DP. OK. P/U 5" DP & 5" HWDP. Finish 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools None API FL Chromatograph (ppm) WOB EVERMAR Avg Min Comments Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type SPUD 5.8160'57 Depth in / out YP (lb/100ft2) 0.20 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 - - Install Diverter Pup PV Footage O. Amend/R. Wimmer ShClyst TuffGvlCoal cP 37 Gas Summary 0 0 0 (current) Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 160' 160' 0' Max @ ft Current Date: Time: Mobilize 13-3/8" hanger in pipe shed. M/U speed head & test. OK. N/U diverter system. Test upper diverter seal. OK. Fabricate in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 0/97196 Oil / Water Present Alkal 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Greg Dellner Maximum Report By:Logging Engineers:Kori Jo Plowman / Greg Dellner Set AtSize 178.9 X-65 Grade 20.00'' 9.625" (max)(current) 0 0 Cly 0 . . * 24 hr Recap:Test mud line, flood conductor. M/U BHA #1 & hold Pre-Spud meeting. Drill out conductor to 160' MD. M/U and orient Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2700.00 0 15-Jun-2015 12:00 AM Current Pump & Flow Data: 839 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: ConditionBit # 1 3.8 16 9.00 Smith XR+ Milltooth 9.00 Size MD. Drill ahead to 778' MD. No losses reported. 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools SP Motor 1.83, GyroPulse Collar, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 160' WOB EVERMAR Avg Min Comments RPM ECD (ppg) ml/30min 2Background (max)Trip Average Mud Type Lst Type SPUD 5.0665'40 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-0902490118 Drill 16" Section PV Footage O. Amend/R. Wimmer ShClyst TuffGvlCoal cP 34 Gas Summary 0 0 0 (current) Avg to160' Yesterday's Depth: Current Depth: 24 Hour Progress: 468.3 Flow In (gpm) Flow In (spm) 160' 778' 618' Max @ ft Current 528'152.3 Date: Time: smart BHA f/ 32' MD to 115' MD & wash down to 160' MD. Drill ahead to 391' MD. POOH to 114' MD & M/U remaining BHA to 391' 6 Max Gas: 10u @ 696' MD Avg Gas: 6u in 3 177'Minimum Depth C-5n 696' 81.3 C-2 10 SPP (psi) Gallons/stroke TFABit Type Depth 24130 MBT 778' pH 1.117 0 0 0 Siltst 13.38'' 598 141 Units* Casing Summary Lithology (%) 0294 14 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade 20.00'' 9.625" (max)(current) 0 0 Cly 1038 . . * 24 hr Recap: (max)(current) 0 0 Cly 188132 Set AtSize 178.9 X-65 Grade 20.00'' 9.625" 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 19026 52 13.38'' 733 173 Units* Casing Summary Lithology (%) 0 MBT 2843' pH 1.117 0 5 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 24118 C-5n 2502' 111.8 C-2 1542 in 5 848'Minimum Depth Time: 154 Max Gas: 1542u @ 2502' MD Avg Gas: 154u 778' 2843' 2065' Max @ ft Current 968'167.0 Date: Avg to778' Yesterday's Depth: Current Depth: 24 Hour Progress: 476.8 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) O. Amend/R. Wimmer ShClyst TuffGvlCoal cP 28 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902490118 Drill 16" Section PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 000 SPUD 4.92644'33 Depth in / out Mud Type Lst Type Average 80Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools SP Motor 1.83, GyroPulse Collar, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 160' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 160' ConditionBit # 1 4.0 16 9.50 Smith XR+ Milltooth 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 16-Jun-2015 12:00 AM Current Pump & Flow Data: 1458 Max 0 Chlorides mg/l 2700.00 Drill ahead f/ 778' MD to 2843' MD. No losses reported. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill ahead f/ 2843' MD to surface TD of 3597' MD. BROOH. No losses reported. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2600.00 0 17-Jun-2015 12:00 AM Current Pump & Flow Data: 1282 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: ConditionBit # 1 4.5 16 9.50 Smith XR+ Milltooth 9.40 Size 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools SP Motor 1.83, GyroPulse Collar, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 160' 3597' WOB EVERMAR Avg Min Comments RPM ECD (ppg) ml/30min Background (max)Trip Average 533 Mud Type Lst Type SPUD 4.83576'30 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-0902490118 BROOH PV Footage B. Simonson/R. Wimmer ShClyst TuffGvlCoal cP 29 Gas Summary 0 0 0 (current) Avg to2843' Yesterday's Depth: Current Depth: 24 Hour Progress: 400.0 Flow In (gpm) Flow In (spm) 2843' 3597' 754' Max @ ft Current 2964'209.9 Date: Time: 93 Max Gas: 190u @ 3068' MD Avg Gas: 93u in 3 3499'Minimum Depth C-5n 3068' C-2 190 SPP (psi) Gallons/stroke TFABit Type Depth 2493 MBT 3597' pH 1.117 0 0 0 Siltst 13.38'' 846 201 Units* Casing Summary Lithology (%) 013668 42 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade 20.00'' 9.625" (max)(current) 0 0 Cly 26372 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade 20.00'' 9.625" 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 0 0 13.38'' Units* Casing Summary Lithology (%) 0 L-80 MBT 3597' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 68 C-5nC-2 in Minimum Depth Time: mud for cmt. Prep to cmt 13-3/8" csg. Max Gas: 11u 3597' 3597' 0' Max @ ft Current Date: Avg to3597' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Simonson/R. Wimmer ShClyst TuffGvlCoal cP 22 3437' Footage 26.00 Ss (ppb Eq) C-1 C-5i AK-AM-0902490118 Cement PV 24 hr Max 68.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 000 40 SPUD3597'16 Depth in / out Mud Type Lst Type Average 11Background (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 20160' 3597' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 3583' 160' Condition 2-1-CT-A-E-I-SD-TD Bit # 1 16Smith XR+ Milltooth 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 18-Jun-2015 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l Cont to BROOH. L/D BHA #2. R/U csg equip & RIH w/ 13-3/8" csg. M/U hanger & landing jt and land csg. Circ & cond Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Perform cmt job. N/D diverter & N/U multibowl & test hanger seals. N/U BOP & install test plug. Test BOP. Pull test Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 0 19-Jun-2015 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 6 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 2-1-CT-A-E-I-SD-TD Bit # 1 16Smith XR+ Milltooth 9.40 Size 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 20160' 3597' WOB EVERMAR Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst Type 40 SPUD3597'14 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-0902490118 P/U 5" DP PV 3437' Footage 26.00 B. Simonson/R. Wimmer ShClyst TuffGvlCoal cP 17 Gas Summary 0 0 0 (current) Avg to3597' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 3597' 3597' 0' Max @ ft Current Date: Time: plug & install wear ring. P/U 5" DP. in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 58 L-80 MBT 3597' pH 1.117 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 4167 Set AtSize 178.9 X-65 Grade 20.00'' 9.625" 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 2448 0 13.38'' Units* Casing Summary Lithology (%) 0 L-80 MBT 3617' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 46 C-5n 3613' C-2 29 in 3 3597'Minimum Depth Time: test csg. Service rig. Drill out float equip,csg shoe & 20' of new formation. Displace well f/ Spud mud to LSND. 19 3597' 3617' 20' Max @ ft Current 3600'142.3 Date: Avg to3597' Yesterday's Depth: Current Depth: 24 Hour Progress: 226.3 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Simonson/R. Wimmer ShClyst TuffGvlCoal cP 8 3437' 12.25 0.969 Footage 26.00 Ss (ppb Eq) C-1 C-5i AK-AM-0902490118 Displace well PV 24 hr Max 68.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 000 40 Hycalog SKHI716-E10C PDC LSND 6.3 3597' 3617'22 Depth in / out Mud Type Lst Type Average 103Background (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 20160' 3597' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 2 3577' 160' Condition 2-1-CT-A-E-I-SD-TD Bit # 1 4.0 16Smith XR+ Milltooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 7 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-Jun-2015 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l 5750.00 P/U 5" DP. P/U BHA #3. RIH w/ BHA to 1750' MD & SHT MWD tools. Cont to RIH to 3432' MD. W/D to 3493' MD & Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Cont displace well f/ spud mud to LSND. Perform LOT to 12.52 ppg EMW. Cut & slip drill line. Drill ahead through Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 4800.00 0 21-Jun-2015 12:00 AM Current Pump & Flow Data: 1345 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 2-1-CT-A-E-I-SD-TD Bit # 1 4.5 16 9.30 Smith XR+ Milltooth 9.30 Size 2 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 20160' 3597' WOB EVERMAR Avg Min Comments Surface RPM ECD (ppg) ml/30min 7Background (max)Trip Average Mud Type Lst 100 Type 40 Hycalog SKHI716-E10C PDC LSND 6.3 3597' 5765'38 Depth in / out YP (lb/100ft2) 9.90 000 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-0902490118 Drill 12.25" Section PV 3437' 12.25 0.969 Footage 26.00 B. Simonson/R. Wimmer ShClyst TuffGvlCoal cP 16 Gas Summary 0 0 0 (current) Avg to3617' Yesterday's Depth: Current Depth: 24 Hour Progress: 445.5 Flow In (gpm) Flow In (spm) 3617' 6051' 2434' Max @ ft Current 4472'275.3 Date: Time: intermediate section f/ 3617' MD to 6051' MD. Samples have consisted of mostly clean sst w/ tr sltst & coal. No losses reported. 31 Max Gas: 139u @ 3259' MD Avg Gas: 31u in 5 3827'Minimum Depth C-5n 3859' 81.3 C-2 139 SPP (psi) Gallons/stroke TFABit Type Depth 661 L-80 MBT 6051' pH 1.117 0 0 0 Siltst 13.38'' 749 177 Units* Casing Summary Lithology (%) 04201 10 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade 20.00'' 9.625" (max)(current) BTC 0 0 Cly 19976 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 8323 Set AtSize 178.9 X-65 Grade 20.00'' 9.625" 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 1979 0 13.38'' 715 167 Units* Casing Summary Lithology (%) 0 L-80 MBT 8290' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1156 C-5n 8057' 153.8 C-2 51 in 5 7226'Minimum Depth Time: sltst. No losses reported. 16 Max Gas: 51u @ 8057' MD Avg Gas: 16u 6051' 8290' 2239' Max @ ft Current 6556'250.3 Date: Avg to6051' Yesterday's Depth: Current Depth: 24 Hour Progress: 406.6 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Simonson/R. Wimmer ShClyst TuffGvlCoal cP 15 3437' 12.25 0.969 Footage 26.00 Ss (ppb Eq) C-1 C-5i AK-AM-0902490118 Drill 12.25" Section PV 24 hr Max 68.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 000 40 Hycalog SKHI716-E10C PDC LSND 5.8 3597' 7998'25 Depth in / out Mud Type Lst 100 Type Average 10Background (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 20160' 3597' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 2 3577' 160' Condition 2-1-CT-A-E-I-SD-TD Bit # 1 5.0 16 9.30 Smith XR+ Milltooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 22-Jun-2015 12:00 AM Current Pump & Flow Data: 1546 Max 0 Chlorides mg/l 5300.00 Cont to drill 12.25" intermediate section f/ 6051' MD to 8290' MD. Samples have consisted of mainly clean sst w/ tr Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Cont to drill 12.25" section f/ 8290' MD to intermediate TD of 10168' MD. CBU while racking back 1 stnd. BROOH. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 5000.00 0 23-Jun-2015 12:00 AM Current Pump & Flow Data: 2609 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 2-1-CT-A-E-I-SD-TD Bit # 1 5.3 16Smith XR+ Milltooth 9.50 Size 2 3577' 160' 100% Gas In Air=10,000 UnitsConnection 730 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 20160' 3597' WOB EVERMAR Avg Min Comments Surface RPM ECD (ppg) ml/30min 90Background (max)Trip Average 98 Mud Type Lst 90 Type 40 Hycalog SKHI716-E10C PDC LSND 5.8 3597' 10135'25 Depth in / out YP (lb/100ft2) 9.80 000 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-0902490118 BROOH PV 3437' 12.25 0.969 Footage 26.00 B. Simonson/R. Wimmer ShClyst TuffGvlCoal cP 17 Gas Summary 0 714 516 (current) Avg to8290' Yesterday's Depth: Current Depth: 24 Hour Progress: 472.2 Flow In (gpm) Flow In (spm) 8290' 10168' 1878' Max @ ft Current 9771'229.1 Date: Time: Samples consisted of sst w/ majority sltst f/ 9250' MD to 10000' MD. No losses reported. 143 Max Gas: 3891u @ 10059' MD Avg Gas: 143u in 5 8681'Minimum Depth C-5n 10059' C-2 3891 SPP (psi) Gallons/stroke TFABit Type Depth 1362 L-80 MBT 10168' pH 1.117 0 600 0 Siltst 13.38'' 885 212 Units* Casing Summary Lithology (%) 0 10 18175 71 907-685-0772Unit Phone: 224 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade 20.00'' 9.625" (max)(current) BTC 1790 0 Cly 363635 . . * 24 hr Recap:Cont to BROOH. No losses reported. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 5100.00 0 24-Jun-2015 12:00 AM Current Pump & Flow Data: 2609 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 2-1-CT-A-E-I-SD-TD Bit # 1 5.3 16Smith XR+ Milltooth 9.50 Size 2 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed 900, TeleScope 825, ARC 825 API FL Chromatograph (ppm) 20160' 3597' WOB EVERMAR Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max)Trip Average 185 Mud Type Lst Type 40 Hycalog SKHI716-E10C PDC LSND 5.7 3597' 10168'22 Depth in / out YP (lb/100ft2) 9.70 000 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-0902490118 BROOH PV 3437' 12.25 0.969 Footage 26.00 B. Simonson/O. Amend ShClyst TuffGvlCoal cP 16 Gas Summary 0 0 0 (current) Avg to10168' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 10168' 10168' 0' Max @ ft Current Date: Time: Max Gas: 185u in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 1458 L-80 MBT 10168' pH 1.117 0 0 0 Siltst 13.38'' 885 212 Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade 20.00'' 9.625" 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 0 0 13.38'' Units* Casing Summary Lithology (%) 0 L-80 MBT 10168' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1454 C-5nC-2 in Minimum Depth Time: & install wear bushing. RIH w/ 9-5/8" csg. No losses reported. 10168' 10168' 0' Max @ ft Current Date: Avg to10168' 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 3437' 12.25 0.969 Footage 38.00 6571' 26.00 Ss (ppb Eq) C-1 C-5i AK-AM-0902490118 RIH 9-5/8" Csg PV 24 hr Max 68.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 000 180 40 Hycalog SKHI716-E10C PDC LSND 6.0 3597' 10168'21 10168' Depth in / out Mud Type Lst Type Average 5Background (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 10 20160' 3597' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 2 3577' 160' Condition 2-1-CT-A-E-I-SD-TD Bit # 1 5.0 16Smith XR+ Milltooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-1-BT-A-X-In-No-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 25-Jun-2015 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l 4000.00 BROOH. L/D BHA #3. Change to 9-5/8" rams. Pull wear bushing, install test plug & test 9-5/8" rams. Pull test plug Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:RIH w/ 9-5/8" csg to 10148' MD. R/D csg equip & R/U cmt head. Circ & cond mud. No losses reported. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 0 26-Jun-2015 12:00 AM Current Pump & Flow Data: Max 1-1-BT-A-X-In-No-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 2-1-CT-A-E-I-SD-TD Bit # 1 16Smith XR+ Milltooth 9.50 Size 2 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 10 20160' 3597' WOB EVERMAR Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst Hydril 583 Type 180 40 Hycalog SKHI716-E10C PDC LSND 3597' 10168'16 10168' Depth in / out YP (lb/100ft2) 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902490118 Circ & Cond Mud PV 3437' 12.25 0.969 Footage 38.00 6571' 26.00 B. Simonson/O. Amend ShClyst TuffGvlCoal cP 15 40.0 Gas Summary 0 0 0 (current) Avg to10168' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 10168' 10168' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 52 L-80 MBT 10168' pH 1.117 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher 0 0 13.38'' Units* Casing Summary Lithology (%) 0 L-80 MBT 10168' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 49 C-5nC-2 in Minimum Depth Time: cut csg & pull csg wear ring. Set/test pack off. N/U BOP and lines. C/O handling equip to 4.5". R/U BOP testing equip & test BOP. 10168' 10168' 0' Max @ ft Current Date: Avg to10168' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) B. Simonson/O. Amend ShClyst TuffGvlCoal cP 15 3437' 12.25 0.969 Footage 38.00 6571' 26.00 Ss (ppb Eq) C-1 C-5i AK-AM-0902490118 Test BOPs PV 24 hr Max 68.0 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 000 180 40 Hycalog SKHI716-E10C PDC LSND 3597' 10168'15 10168' Depth in / out Mud Type Lst Hydril 583 Type Average Background (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 10 20160' 3597' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 2 losses reported. 3577' 160' Condition 2-1-CT-A-E-I-SD-TD Bit # 1 16Smith XR+ Milltooth 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 14 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-1-BT-A-X-In-No-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 27-Jun-2015 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l Circ & cond mud. Cmt 9-5/8" csg. R/D cmt head & C/O bails/elevators. N/D choke/kill/flow lines. Raise BOP stack, Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:R/D test equip & pull test plug, set wear ring. Test 9-5/8" csg. P/U 4.5" DP. P/U BHA #4 & RIH w/ 4.5" DP. SHT MWD Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 3.38 0 28-Jun-2015 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-BT-A-X-In-No-TD Bit # 2 NA 12.25Hycalog SKHI716-E10C PDC 9.35 Size 3 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 API FL Chromatograph (ppm) 103597' 10168' WOB EVERMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst Hydril 583 Type 180 Hycalog SK616M-K1D PDC FazePro NA 10168' 10168'14 Depth in / out YP (lb/100ft2) 2.60 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 RIH w/ BHA #4 PV 6571' 8.75 0.902 Footage 38.00 B. Simonson/O. Amend ShClyst TuffGvlCoal cP 12 40.0 Gas Summary 0 0 0 (current) Avg to10168' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 10168' 10168' 0' Max @ ft Current Date: Time: tools @ 1786' MD. Cont RIH w/ BHA #4. No losses reported. in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 66/3446 L-80 Oil/Water 10168' Alkal 0.969 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 00 0 907-685-0772Unit Phone: 0 Leigh Ann Rasher Maximum Report By:Logging Engineers:Kori Jo Plowman / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 152 0 Cly 191229 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 8 Leigh Ann Rasher Maximum Report By:Logging Engineers:Alexander Kalenuik / Leigh Ann Rasher 10 88956 139 13.38'' 515 125 Units* Casing Summary Lithology (%) 46 L-80 Oil/Water 11524' Alkal 0.969 0 61 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 65/3547 C-5n 10851' 162.8 C-2 1442 Max Gas: 1442u @ 10851' MD Ave Gas: 726u in 3 10168'Minimum Depth Time: out shoe track t/ 10128' MD. Cut & slip DL. Cont to drill out shoe track & 20' of new hole to 10188' MD. Perform FIT to 12.95 ppg 726 10168' 11524' 1356' Max @ ft Current 10875'241.9 Date: Avg to10168' Yesterday's Depth: Current Depth: 24 Hour Progress: 395.6 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 58 37 (current) B. Simonson/O. Amend ShClyst TuffGvlCoal cP 15 6571' 8.75 0.902 Footage 38.00 Ss Ratio C-1 C-5i AK-AM-0902490118 Drill 8.75" Section PV 24 hr Max 68.0 Weight 101 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.60 04333 180 Hycalog SK616M-K1D PDC LSND NA 10168' 11232'15 Depth in / out Mud Type Lst 90 Hydril 583 Type Average 862Background (max)Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 API FL Chromatograph (ppm) 103597' 10168' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 81 3 EMW. Drill ahead through 8.75" production section. Samples have consisted of clean f gr sst. No looses reported. 3577' 160' Condition 1-1-BT-A-X-In-No-TD Bit # 2 6.5 12.25 9.45 Hycalog SKHI716-E10C PDC 9.45 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 16 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 29-Jun-2015 12:00 AM Current Pump & Flow Data: 2669 Max 55 Lime (lb/bbl) 3.38 C/O handling equip to 5" & rotate in hole to TOC @ 10043' MD. Displace from LSND to 9.4 ppg FazePro OBM. Drill Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Cont drilling 8.75" production section f/ 11524'MD to 14328' MD. Samples consisted of sst f/ 11500' MD-13350' MD & Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.99 45 30-Jun-2015 12:00 AM Current Pump & Flow Data: 2842 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 17 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-BT-A-X-In-No-TD Bit # 2 7.7 12.25 9.55 Hycalog SKHI716-E10C PDC 9.40 Size 3 3577' 160' 100% Gas In Air=10,000 UnitsConnection 96 Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 API FL Chromatograph (ppm) 103597' 10168' WOB EVERMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 15Background (max)Trip Average Mud Type Lst 60 Hydril 583 Type 180 Hycalog SK616M-K1D PDC LSND NA 10168' 13978'17 Depth in / out YP (lb/100ft2) 2.30 84334 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 94 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 Drill 8.75" Section PV 6571' 8.75 0.902 Footage 38.00 B. Simonson/O. Amend ShClyst TuffGvlCoal cP 13 40.0 Gas Summary 0 76 56 (current) Avg to11524' Yesterday's Depth: Current Depth: 24 Hour Progress: 465.5 Flow In (gpm) Flow In (spm) 11524' 14328' 2804' Max @ ft Current 12651'269.0 Date: Time: sst & sltst f/ 13350' MD to 14300' MD. No losses reported. 478 Max Gas: 1764u @ 12703' MD Ave Gas: 478u in 3 13589'Minimum Depth C-5n 12703' 168.9 C-2 1764 SPP (psi) Gallons/stroke TFABit Type Depth 66/3446 L-80 Oil/Water 14328' Alkal 0.969 0 78 0 Siltst 13.38'' 496 118 Units* Casing Summary Lithology (%) 42 40 53783 182 907-685-0772Unit Phone: 22 Leigh Ann Rasher Maximum Report By:Logging Engineers:Alexander Kalenuik / Leigh Ann Rasher Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 192 0 Cly 221748 . . * 24 hr Recap: (max)(current) BTC 202 0 Cly 140494 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 21 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner 46022 173 13.38'' 552 130 Units* Casing Summary Lithology (%) 48 L-80 Oil/Water Present Alkal 0.969 0 105 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 67/3347 C-5n 16695' 91.0 C-2 1062 in 10 16046'Minimum Depth Time: 431 14328' 16849' 2521' Max @ ft Current 16671'240.6 Date: Avg to10168' Yesterday's Depth: Current Depth: 24 Hour Progress: 409.5 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 109 70 (current) B. Simonson/O. Amend ShClyst TuffGvlCoal cP 14 6571' 8.75 0.902 Footage 38.00 Ss Ratio C-1 C-5i AK-AM-0902490118 - - Drill 8.75" Section PV 24 hr Max 68.0 Weight 90 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.10 95432 180 Hycalog SK616M-K1D PDC FazePro NA 10168' 16617'14 Depth in / out Mud Type Lst 100 Hydril 583 Type Average 41Background (max) Trip 10.6611.62 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 API FL Chromatograph (ppm) 103597' 10168' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 107 3 3577' 160' Condition 1-1-BT-A-X-In-No-TD Bit # 2 8.1 12.25Hycalog SKHI716-E10C PDC 9.45 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.77 DOYON15 Report For: Morning Report Report # 18 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 1-Jul-2015 12:00 AM Current Pump & Flow Data: 3400 Max 49 Lime (lb/bbl) 2.73 Drill f/14,328' to 16,849' MD. No losses reported. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) BTC 275 0 Cly 264692 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 22 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner 108242 79 13.38'' 549 130 Units* Casing Summary Lithology (%) 64 L-80 Oil/Water Present Alkal 0.969 0 117 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 67/3346 C-5n 18873' 139.3 C-2 2110 in 11 18256'Minimum Depth Time: 920 16849' 19089' 2240' Max @ ft Current 18532'295.3 Date: Avg to10168' Yesterday's Depth: Current Depth: 24 Hour Progress: 468.3 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 109 74 (current) B. Simonson/O. Amend ShClyst TuffGvlCoal cP 14 6571' 8.75 0.902 Footage 38.00 Ss Ratio C-1 C-5i AK-AM-0902490118 - - Drill 8.75" Section PV 24 hr Max 68.0 Weight 135 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.40 117046 180 Hycalog SK616M-K1D PDC FazePro NA 10168' 18675'14 Depth in / out Mud Type Lst 100 Hydril 583 Type Average 108Background (max) Trip 11.4311.76 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 API FL Chromatograph (ppm) 103597' 10168' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 142 3 3577' 160' Condition 1-1-BT-A-X-In-No-TD Bit # 2 8.5 12.25Hycalog SKHI716-E10C PDC 9.45 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.12 DOYON15 Report For: Morning Report Report # 19 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 2-Jul-2015 12:00 AM Current Pump & Flow Data: 3700 Max 67 Lime (lb/bbl) 3.12 Drill f/16,849' to 19,089' MD. Daily FazePro loss: 37 bbls. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill f/19,089' to TD at 19,180' MDDownlink, shoot survey & slow pump rates. CBU x 1 for 2 stds 18,998'. BROOH Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.60 89 3-Jul-2015 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 20 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.12 DOYON15 Report For: Condition 1-1-BT-A-X-In-No-TD Bit # 2 8.3 12.25Hycalog SKHI716-E10C PDC 9.40 Size 3 3577' 160' 100% Gas In Air=10,000 UnitsConnection 104 Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 API FL Chromatograph (ppm) 103597' 10168' WOB EVERMAR 11.8612.01 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst 100 Hydril 583 Type 180 Hycalog SK616M-K1D PDC FazePro NA 10168' 19180'14 Depth in / out YP (lb/100ft2) 2.00 137956 040 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 172 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 - - BROOH PV 6571' 8.75 0.902 Footage 38.00 B. Simonson/O. Amend ShClyst TuffGvlCoal cP 13 40.0 Gas Summary 2 93 63 (current) Avg to10168' Yesterday's Depth: Current Depth: 24 Hour Progress: 301.2 Flow In (gpm) Flow In (spm) 19089' 19180' 91' Max @ ft Current 19121'263.1 Date: Time: f/18,998' to 14,270'. Daily FazePro loss: 105 bbls. 1247 in 85 19091'Minimum Depth C-5n 19132' C-2 1649 SPP (psi) Gallons/stroke TFABit Type Depth 67/3347 L-80 Oil/Water Present Alkal 0.969 26 95 35 Siltst 13.38'' Units* Casing Summary Lithology (%) 81161651 10926 907-685-0772Unit Phone: 21 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 225 41 Cly 212908 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 0 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner 0 13.38'' 550 130 Units* Casing Summary Lithology (%) L-80 Oil/Water Present Alkal 0.969 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 68/3246 C-5nC-2 16 in 6Minimum Depth Time: Daily FazePro loss: 49 bbls. 11 19180' 19180' 0' Max @ ft Current Date: Avg to10168' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) B. Simonson/O. Amend ShClyst TuffGvlCoal cP 13 6571' 8.75 0.902 Footage 38.00 Ss Ratio C-1 C-5i AK-AM-0902490118 - - C/O Saver Sub PV 24 hr Max 68.0 Weight Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.00 180 Hycalog SK616M-K1D PDC FazePro NA 10168' 19180'13 Depth in / out Mud Type Lst 100 Hydril 583 Type Average Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 API FL Chromatograph (ppm) 103597' 10168' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 3 3577' 160' Condition 1-1-BT-A-X-In-No-TD Bit # 2 8.3 12.25Hycalog SKHI716-E10C PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 21 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 4-Jul-2015 12:00 AM Current Pump & Flow Data: 2600 Max Lime (lb/bbl) 2.60 BROOH f/14,270' to 9,473'. Service & inspect top drive, blocks, hook and torque up shot pin and change saver sub. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:BROOH f/9,473' to 1,120'. Circ hole & reciprocate pipe from 1,120' to 1,060'. POH elevators to 362'. L/D BHA #4. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.60 5-Jul-2015 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 22 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-BT-A-X-In-No-TD Bit # 2 8.4 12.25Hycalog SKHI716-E10C PDC 9.40 Size 3 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools None API FL Chromatograph (ppm) 103597' 10168' WOB EVERMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst 100 Hydril 583 Type 180 Hycalog SK616M-K1D PDC FazePro NA 10168' 19180'12 Depth in / out YP (lb/100ft2) 1.80 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 - - C/O Saver Sub PV 6571' 8.75 0.902 Footage 38.00 B. Simonson/O. Amend ShClyst TuffGvlCoal cP 13 40.0 Gas Summary 0 0 0 (current) Avg to19180' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 19180' 19180' 0' Max @ ft Current Date: Time: Clear rig floor. Lubricate rig. Change out saver sub to TT525 for 5" DP. Daily FazePro loss: 33 bbls. 7 in 6Minimum Depth C-5nC-2 8 SPP (psi) Gallons/stroke TFABit Type Depth 68/3246 L-80 Oil/Water Present Alkal 0.969 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 0 907-685-0772Unit Phone: 0 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 0 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner 0 13.38'' Units* Casing Summary Lithology (%) L-80 Oil/Water Present Alkal 0.969 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 68/3246 C-5nC-2 10 in 3Minimum Depth Time: per detail to 9,119'. R/D Volant csg equip. Bring Baker equip. to rig floor. M/U liner hanger assembly, slim hole MWD & scribe. M/U 8 19180' 19180' 0' Max @ ft Current Date: Avg to19180' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) B. Simonson/O. Amend ShClyst TuffGvlCoal cP 12 6571' 8.75 0.902 Footage 51.10 9012' 38.00 Ss Ratio C-1 C-5i AK-AM-0902490118 - - Run 5.5" Liner PV 24 hr Max 68.0 Weight Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.30 170 180 Hycalog SK616M-K1D PDC FazePro NA 10168' 19180'13 19180' Depth in / out Mud Type Lst 100 Hydril 583 Type Average Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools None API FL Chromatograph (ppm) 10 103597' 10168' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 3 elevators f/10,595' to 11,059'. No Daily FazePro loss. Baker string magnets & XO to 9,194'. RIH 1 std 5" DP. MWD OK. RIH on elevators w/5" DP to 10,250'. Rotate to 10,595'. RIH on 3577' 160' Condition 1-1-BT-A-X-In-No-TD Bit # 2 8.3 12.25Hycalog SKHI716-E10C PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 23 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-1-CT-A-X-IN-WT-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 6-Jul-2015 12:00 AM Current Pump & Flow Data: Max Lime (lb/bbl) 2.99 Change out saver sub, service crown, top drive and drawworks. R/U GBR and Volant tool. RIH w/5.5" slotted liner as Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:RIH 5.5" liner w/5" DP on top f/11,059' to 19,090'. Orient and set hanger. Set packer & release running tool. Test Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.73 7-Jul-2015 12:00 AM Current Pump & Flow Data: Max 1-1-CT-A-X-IN-WT-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 24 Customer: Well: Area: Location: Rig: SP01-SE7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-BT-A-X-In-No-TD Bit # 2 8.3 12.25Hycalog SKHI716-E10C PDC 9.40 Size 3 floor. Mobilize Baker tools to floor. Lubricate rig. M/U Whipstock BHA & orient to 150'. Daily FazePro loss: 11 bbls. 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Whipstock API FL Chromatograph (ppm) 10 103597' 10168' WOB EVERMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst 100 Hydril 583 Type 170 180 Hycalog SK616M-K1D PDC FazePro NA 10168' 19180'13 19180' Depth in / out YP (lb/100ft2) 2.10 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 - - M/U Whipstock BHA PV 6571' 8.75 0.902 Footage 51.10 9012' 38.00 O. Amend / R. Wimmer ShClyst TuffGvlCoal cP 13 40.0 Gas Summary 0 0 0 (current) Avg to19180' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 19180' 19180' 0' Max @ ft Current Date: Time: Packer. OK. TOL at 9,999' MD. POH w/5" DP to 9,550'. POH to 122'. L/D string magnets, running tool & Slim Hole MWD. Clear rig 3 in 3Minimum Depth C-5nC-2 4 SPP (psi) Gallons/stroke TFABit Type Depth 68/3255 L-80 Oil/Water Present Alkal 0.969 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 0 907-685-0772Unit Phone: 0 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 81 0 Cly 1607 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 40 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner 513 0 13.38'' 426 100 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water Alkal 0.969 0 48 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 68/3252 C-5n 9976' C-2 16 in 8 9988'Minimum Depth Time: whipstock. Confirm latch & shear f/whipstock. Mill 9-5/8" csg. Mill new hole to 10,006'. BROOH to 9,897'. POH to 9,523'. POH to 98'. 11 9957' 10006' 49' Max @ ft Current 9992'32.7 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 270.8 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 57 33 (current) O. Amend / R. Wimmer ShClyst TuffGvlCoal cP 14 6571' 8.75 0.902 Footage 51.10 9012' 38.00 Ss Ratio C-1 C-5i AK-AM-0902490118 - - L/D Mill BHA PV 24 hr Max 68.0 Weight 2 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.20 010 170 180 Hycalog SK616M-K1D PDC FazePro NA 10168' 19180'11 19180' Depth in / out Mud Type Lst 100 Hydril 583 Type Average Background (max) Trip 10.7310.73 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools None API FL Chromatograph (ppm) 10 103597' 10168' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 193 3 L/D mill BHA. Daily FazePro loss: 17 bbls. 3577' 160' Condition 1-1-BT-A-X-In-No-TD Bit # 2 8.3 12.25Hycalog SKHI716-E10C PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.73 DOYON 15 Report For: Morning Report Report # 25 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-1-CT-A-X-IN-WT-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 8-Jul-2015 12:00 AM Current Pump & Flow Data: 1200 Max 3 Lime (lb/bbl) 2.86 RIH whipstock/mill assembly f/154' to 617'. Test MWD. OK. RIH to 9,111'. Cut & slip drill line. RIH to 9,556'. Orient Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:L/D mill BHA. Flush stack. Rig up and test BOPE's. R/D test equip. Pull test plug. Set wear ring. Clear rig floor. M/U Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.99 9-Jul-2015 12:00 AM Current Pump & Flow Data: Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 26 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.2 8.75Hycalog SK616M-K1D PDC 9.45 Size 4 trip tank. No daily FazePro loss. 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst 100 Hydril 583 Type 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 10006'12 Depth in / out YP (lb/100ft2) 2.30 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 - - Work on Top Drive PV 9012' 8.75 0.902 Footage 51.10 O. Amend / R. Wimmer ShClyst TuffGvlCoal cP 15 40.0 Gas Summary 0 0 0 (current) Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 10006' 10006' 0' Max @ ft Current Date: Time: BHA #6. RIH f/368' to 1,500' & shallow test MWD. OK. RIH to 9,192'. Rig up top drive table. Work on top drive. Monitor well utilizing 7 in 5Minimum Depth C-5nC-2 38 SPP (psi) Gallons/stroke TFABit Type Depth 68/3252 L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 0 907-685-0772Unit Phone: 0 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 0 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner 0 13.38'' Units* Casing Summary Lithology (%) L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 68/3247 C-5nC-2 in Minimum Depth Time: 9,480'. C/O 4.5" handling equip to 5". No daily loss. 10006' 10006' 0' Max @ ft Current Date: Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) O. Amend / R. Wimmer ShClyst TuffGvlCoal cP 15 9012' 8.75 0.902 Footage 51.10 Ss Ratio C-1 C-5i AK-AM-0902490118 - - C/O Handling Equip PV 24 hr Max 68.0 Weight Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.10 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 10006'13 Depth in / out Mud Type Lst 100 Hydril 583 Type Average Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 4 3577' 160' Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.3 8.75Hycalog SK616M-K1D PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Morning Report Report # 27 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 10-Jul-2015 12:00 AM Current Pump & Flow Data: Max Lime (lb/bbl) 2.73 Work on top drive. Disassemble work platform and lay down. Clean rig floor. Run in hole on elevators f/9,192' to Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Run in hole f/9,480' to 9,995'. Circulate one annular volume. Stand one std back to 9,945'. Conduct LOT/FIT. Wash Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.73 89 11-Jul-2015 12:00 AM Current Pump & Flow Data: 3100 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 28 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.95 DOYON 15 Report For: Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.4 8.75Hycalog SK616M-K1D PDC 9.45 Size 4 3577' 160' 100% Gas In Air=10,000 UnitsConnection 143 Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR 10.2810.71 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 84Background (max) Trip Average Mud Type Lst 100 Hydril 583 Type 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 11714'12 Depth in / out YP (lb/100ft2) 2.10 148438 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 130 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 - - Drill 8.75" Lateral PV 9012' 8.75 0.902 Footage 51.10 O. Amend / R. Wimmer ShClyst TuffGvlCoal cP 14 40.0 Gas Summary 0 130 61 (current) Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: 409.4 Flow In (gpm) Flow In (spm) 10006' 11933' 1927' Max @ ft Current 11731'257.8 Date: Time: down f/9,945' to 10,006'. Drill 8.75" lateral f/10,006' to 11,933’ MD. No Daily FazePro loss. 1156 in 32 11842'Minimum Depth C-5n 10682' 35.0 C-2 2737 SPP (psi) Gallons/stroke TFABit Type Depth 68/3249 L-80 Oil/Water Present Alkal 0.902 0 95 0 Siltst 13.38'' 550 130 Units* Casing Summary Lithology (%) 9599109 118 907-685-0772Unit Phone: 23 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 204 0 Cly 315673 . . * 24 hr Recap: (max)(current) BTC 278 0 Cly 323959 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 38 Gregory Dellner Maximum Report By:Logging Engineers:Alexander Kalenuik / Gregory Dellner 50 85431 189 13.38'' 550 130 Units* Casing Summary Lithology (%) 42 L-80 Oil/Water Present Alkal 0.902 0 136 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 67/3352 C-5n 12504' 37.0 C-2 1912 in 8 12355'Minimum Depth Time: No daily losses. 714 11933' 13599' 1666' Max @ ft Current 12004'224.4 Date: Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: 402.3 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 164 90 (current) O. Amend / R. Wimmer ShClyst TuffGvlCoal cP 17 9012' 8.75 0.902 Footage 51.10 Ss Ratio C-1 C-5i AK-AM-0902490118 - - Drill 8.75" Lateral PV 24 hr Max 68.0 Weight 73 Hours C-3 20 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.40 155538 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 13521'13 Depth in / out Mud Type Lst 30 Hydril 583 Type Average 11Background (max) Trip 10.7311.04 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 195 4 3577' 160' Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.5 8.75Hycalog SK616M-K1D PDC 9.45 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.62 DOYON 15 Report For: Morning Report Report # 29 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 12-Jul-2015 12:00 AM Current Pump & Flow Data: 3200 Max 50 Lime (lb/bbl) 3.12 Drill 8.75" lateral f/11,874' MD to 13,350' MD. Control drilling for anti-collision at 30 ft/hr per geologist to 13,599' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Control drilling 8.75" lateral for anti-collision at 30 ft/hr per geologist from 13,584' MD to 13,800' MD. Drill from Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.86 24 13-Jul-2015 12:00 AM Current Pump & Flow Data: 3400 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 30 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.89 DOYON 15 Report For: Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.6 8.75Hycalog SK616M-K1D PDC 9.45 Size 4 3577' 160' 100% Gas In Air=10,000 UnitsConnection 167 Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR 10.9511.32 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 19Background (max) Trip Average Mud Type Lst 100 Hydril 583 Type 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 14798'10 Depth in / out YP (lb/100ft2) 2.20 52713 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 43 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 - - Drill 8.75" Lateral PV 9012' 8.75 0.902 Footage 51.10 O. Amend / R. Wimmer ShClyst TuffGvlCoal cP 17 40.0 Gas Summary 0 169 80 (current) Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: 437.0 Flow In (gpm) Flow In (spm) 13599' 15079' 1480' Max @ ft Current 14992'199.7 Date: Time: 13,800' MD to 15,079' MD. No daily losses. 249 in 10 14918'Minimum Depth C-5n 14882' 182.0 C-2 1150 SPP (psi) Gallons/stroke TFABit Type Depth 67/3350 L-80 Oil/Water Present Alkal 0.902 0 131 0 Siltst 13.38'' 550 130 Units* Casing Summary Lithology (%) 2131698 149 907-685-0772Unit Phone: 38 Gregory Dellner Maximum Report By:Logging Engineers:Kori Jo Plowman / Gregory Dellner Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 262 0 Cly 216623 . . * 24 hr Recap: (max)(current) BTC 287 0 Cly 359545 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 43 Gregory Dellner Maximum Report By:Logging Engineers:Kori Jo Plowman / Gregory Dellner 108338 130 13.38'' 540 128 Units* Casing Summary Lithology (%) 78 L-80 Oil/Water Present Alkal 0.902 0 159 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 66/3452 C-5n 16748' 181.5 C-2 1895 in 8 16692'Minimum Depth Time: motor. Wash down from 16,200' MD to 16,233' MD. Drill from 16,233' MD to 17,133'. No daily losses. 756 15079' 17133' 2054' Max @ ft Current 17056'321.0 Date: Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: 464.4 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 209 87 (current) J. Keener / R. Wimmer ShClyst TuffGvlCoal cP 18 9012' 8.75 0.902 Footage 51.10 Ss Ratio C-1 C-5i AK-AM-0902490118 - - Drill 8.75" Lateral PV 24 hr Max 68.0 Weight 119 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 1.70 2410052 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 16667'9 Depth in / out Mud Type Lst 100 Hydril 583 Type Average 55Background (max) Trip 11.0811.40 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 180 4 3577' 160' Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.6 8.75Hycalog SK616M-K1D PDC 9.45 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.70 DOYON 15 Report For: Morning Report Report # 31 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 14-Jul-2015 12:00 AM Current Pump & Flow Data: 3600 Max 86 Lime (lb/bbl) 2.21 Drill 8.75" lateral from 14,985' MD 16,233' MD. BROOH from 16,233' MD to 16,200' MD. Repair Topdrive shot pin Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill 8.75" lateral from 17,133' MD to 19,093 MD / 4,162' TVD. BROOH and circulate 1 BU per stand from 19,093' MD Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.60 142 15-Jul-2015 12:00 AM Current Pump & Flow Data: 3800 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 32 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.01 DOYON 15 Report For: Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.9 8.75Hycalog SK616M-K1D PDC 9.45 Size 4 3577' 160' 100% Gas In Air=10,000 UnitsConnection 237 Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR 11.3811.74 Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min 213Background (max) Trip Average Mud Type Lst 100 Hydril 583 Type 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 19064'15 Depth in / out YP (lb/100ft2) 2.00 4215678 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 187 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 - - BROOH PV 9012' 8.75 0.902 Footage 51.10 J. Keener / R. Wimmer ShClyst TuffGvlCoal cP 21 40.0 Gas Summary 0 223 92 (current) Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: 445.3 Flow In (gpm) Flow In (spm) 17133' 19093' 1960' Max @ ft Current 17056'292.1 Date: Time: to 18,909' MD. No losses while drilling. 4 bbl loss while BROOH. 1457 in 10 17497'Minimum Depth C-5n 18806' - C-2 3568 SPP (psi) Gallons/stroke TFABit Type Depth 67/3355 L-80 Oil/Water Present Alkal 0.902 0 159 0 Siltst 13.38'' 536 127 Units* Casing Summary Lithology (%) 123226958 215 907-685-0772Unit Phone: 36 Gregory Dellner Maximum Report By:Logging Engineers:Kori Jo Plowman / Gregory Dellner Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 143 0 Cly 602139 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 0 Gregory Dellner Maximum Report By:Logging Engineers:Kori Jo Plowman / Gregory Dellner 0 13.38'' 506 120 Units* Casing Summary Lithology (%) L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 66/3456 C-5nC-2 111 in 3Minimum Depth Time: 13 19093' 19093' 0' Max @ ft Current Date: Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) J. Keener / R. Wimmer ShClyst TuffGvlCoal cP 20 9012' 8.75 0.902 Footage 51.10 Ss Ratio C-1 C-5i AK-AM-0902490118 - - BROOH PV 24 hr Max 68.0 Weight Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.10 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 19093'14 Depth in / out Mud Type Lst 100 Hydril 583 Type Average Background (max) Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 4 3577' 160' Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.8 8.75Hycalog SK616M-K1D PDC 9.45 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Morning Report Report # 33 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 16-Jul-2015 12:00 AM Current Pump & Flow Data: 2900 Max Lime (lb/bbl) 2.73 BROOH from 18,909' MD to 13,732' MD. 20 bbl loss during BROOH. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:BROOH from 13,732' MD to 10,338' MD. Daily losses 54 bbls. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.86 17-Jul-2015 12:00 AM Current Pump & Flow Data: 3000 Max Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 34 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.8 8.75Hycalog SK616M-K1D PDC 9.45 Size 4 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst 100 Hydril 583 Type 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 19093'14 Depth in / out YP (lb/100ft2) 2.20 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 - - BROOH PV 9012' 8.75 0.902 Footage 51.10 J. Keener / R. Wimmer ShClyst TuffGvlCoal cP 19 40.0 Gas Summary 0 0 0 (current) Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 19093' 19093' 0' Max @ ft Current Date: Time: 12 in 3Minimum Depth C-5nC-2 35 SPP (psi) Gallons/stroke TFABit Type Depth 65/3556 L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst 13.38'' 555 131 Units* Casing Summary Lithology (%) 0 907-685-0772Unit Phone: 0 Gregory Dellner Maximum Report By:Logging Engineers:Kori Jo Plowman / Gregory Dellner Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Kori Jo Plowman / Rebecca Mulkey 0 13.38'' 546 132 Units* Casing Summary Lithology (%) L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 64/3655 C-5nC-2 8 in 2Minimum Depth Time: 5 19093' 19093' 0' Max @ ft Current Date: Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) J. Keener / R. Wimmer ShClyst TuffGvlCoal cP 20 9012' 8.75 0.902 Footage 51.10 Ss Ratio C-1 C-5i AK-AM-0902490118 BROOH PV 24 hr Max 68.0 Weight Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.10 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 19093'14 Depth in / out Mud Type Lst 100 Hydril 583 Type Average Background (max)Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 4 3577' 160' Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.7 8.75Hycalog SK616M-K1D PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Morning Report Report # 35 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 18-Jul-2015 12:00 AM Current Pump & Flow Data: 1182 Max Lime (lb/bbl) 2.73 BROOH from 10,338' MD to 1,791' MD. Daily losses 32 bbls. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:finish BROOH. RIH to 9,922' to retrieve whipstock. POOH from 9,962' to 9,082'. Daily losses 11 bbls. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 3.12 19-Jul-2015 12:00 AM Current Pump & Flow Data: 1182 Max 1-2-BT-G-X-In-No-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 36 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.5 8.75Hycalog SK616M-K1D PDC 9.45 Size 4 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst 100 Hydril 583 Type 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 19093'14 19093' Depth in / out YP (lb/100ft2) 2.40 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 POOH with wipstock PV 9012' 8.75 0.902 Footage 9087' 51.10 J. Keener / R. Wimmer ShClyst TuffGvlCoal cP 18 40.0 Gas Summary 0 0 0 (current) Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 19093' 19093' 0' Max @ ft Current Date: Time: 5 in 3Minimum Depth C-5nC-2 10 SPP (psi) Gallons/stroke TFABit Type Depth 64/3655 L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst 13.38'' 546 132 Units* Casing Summary Lithology (%) 0 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Kori Jo Plowman / Rebecca Mulkey Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Kori Jo Plowman / Rebecca Mulkey 0 13.38'' 546 132 Units* Casing Summary Lithology (%) L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 65/3557 C-5nC-2 7 in 2Minimum Depth Time: 5 19093' 19093' 0' Max @ ft Current Date: Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) J. Keener / R. Wimmer ShClyst TuffGvlCoal cP 18 9012' 8.75 0.902 Footage 9087' 51.10 Ss Ratio C-1 C-5i AK-AM-0902490118 POOH PV 24 hr Max 68.0 Weight Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.30 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 19093'14 19093' Depth in / out Mud Type Lst 100 Hydril 583 Type Average Background (max)Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 1010168' 19180' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 4 3577' 160' Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.6 8.75Hycalog SK616M-K1D PDC 9.45 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Morning Report Report # 37 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-2-BT-G-X-In-No-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-Jul-2015 12:00 AM Current Pump & Flow Data: 182 Max Lime (lb/bbl) 2.99 POOH with whipstock from 9,082' MD to surface. RIH with clean out assembly. Daily losses 16 bbls. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Kori Jo Plowman / Rebecca Mulkey 0 13.38'' 546 132 Units* Casing Summary Lithology (%) L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 65/3560 C-5nC-2 6 in 3Minimum Depth Time: Daily losses: 9 bbls. 5 19093' 19093' 0' Max @ ft Current Date: Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) J. Keener / O. Amend ShClyst TuffGvlCoal cP 18 9012' 8.75 0.902 Footage 73.20 9087' 51.10 Ss Ratio C-1 C-5i AK-AM-0902490118 POOH PV 24 hr Max 68.0 Weight Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.30 124.6 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 19093'15 19093' Depth in / out Mud Type Lst 100 Hydril 583 Type Average Background (max)Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 10 1010168' 19180' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 4 3577' 160' Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.6 8.75Hycalog SK616M-K1D PDC 9.45 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Morning Report Report # 38 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-2-BT-G-X-In-No-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 21-Jul-2015 12:00 AM Current Pump & Flow Data: 182 Max Lime (lb/bbl) 2.99 POOH with clean out assy from 9,998' MD to 102' MD. RIH with diverter to 9,926' MD. POOH to 6,482' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:POOH from 6,482' MD to 40' MD. L/D Tools. Test BOPE. R/U & RIH with 5.5" Liner to 2141' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.99 22-Jul-2015 12:00 AM Current Pump & Flow Data: 182 Max 1-2-BT-G-X-In-No-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 39 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.5 8.75Hycalog SK616M-K1D PDC 9.45 Size 4 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 10 1010168' 19180' WOB EVERMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst 100 Hydril 583 Type 124.6 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 19093'15 19093' Depth in / out YP (lb/100ft2) 2.30 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 RIH PV 9012' 8.75 0.902 Footage 73.20 9087' 51.10 J. Keener / M. Billington ShClyst TuffGvlCoal cP 18 40.0 Gas Summary 0 0 0 (current) Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 19093' 19093' 0' Max @ ft Current Date: Time: Daily losses: 10 bbls. 4 in 3Minimum Depth C-5nC-2 4 SPP (psi) Gallons/stroke TFABit Type Depth 65/3560 L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 0 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Kori Jo Plowman / Rebecca Mulkey Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Kori Jo Plowman / Rebecca Mulkey 0 13.38'' Units* Casing Summary Lithology (%) L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 65/3560 C-5nC-2 4 in 3Minimum Depth Time: Daily losses: 0 bbls. 4 19093' 19093' 0' Max @ ft Current Date: Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) J. Keener / M. Billington ShClyst TuffGvlCoal cP 18 9012' 8.75 0.902 Footage 73.20 9087' 51.10 Ss Ratio C-1 C-5i AK-AM-0902490118 POOH PV 24 hr Max 68.0 Weight Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 2.30 124.6 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 19093'15 19093' Depth in / out Mud Type Lst 100 Hydril 583 Type Average Background (max)Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 10 1010168' 19180' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 4 3577' 160' Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.3 8.75Hycalog SK616M-K1D PDC 9.45 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Morning Report Report # 40 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-2-BT-G-X-In-No-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 23-Jul-2015 12:00 AM Current Pump & Flow Data: 182 Max Lime (lb/bbl) 2.99 RIH from 2,141' MD to 19,026' MD with 5.5" Liner. POOH to 9,802' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: POOH with 5" DP from 9,336' MD to 80' MD. RIH to 9,900' MD with LEM. POOH to 8705' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.99 24-Jul-2015 12:00 AM Current Pump & Flow Data: 182 Max 1-2-BT-G-X-In-No-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 41 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.2 8.75Hycalog SK616M-K1D PDC 9.45 Size 4 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 10 1010168' 19180' WOB EVERMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst 100 Hydril 583 Type 124.6 170 Hycalog SK616M-K1D PDC FazePro NA 10006' 19093'15 19093' Depth in / out YP (lb/100ft2) 2.30 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 POOH PV 9012' 8.75 0.902 Footage 73.20 9087' 51.10 J. Keener / M. Billington ShClyst TuffGvlCoal cP 18 40.0 Gas Summary 0 0 0 (current) Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 19093' 19093' 0' Max @ ft Current Date: Time: Daily losses: 16 bbls. 4 in 3Minimum Depth C-5nC-2 4 SPP (psi) Gallons/stroke TFABit Type Depth 65/3560 L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 0 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Kori Jo Plowman / Rebecca Mulkey Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 . . * 24 hr Recap: (max)(current) BTC 0 0 Cly 0 Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Kori Jo Plowman / Rebecca Mulkey 0 13.38'' Units* Casing Summary Lithology (%) L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth C-5nC-2 4 in 3Minimum Depth Time: Daily losses: 8 bbls. 4 19093' 19093' 0' Max @ ft Current Date: Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 0 (current) J. Keener / M. Billington ShClyst TuffGvlCoal cP 9012' 8.75 0.902 Footage 73.20 9087' 51.10 Ss Ratio C-1 C-5i AK-AM-0902490118 PV 24 hr Max 68.0 Weight Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 124.6 170 Hycalog SK616M-K1D PDC 10006' 19093' 19093' Depth in / out Mud Type Lst 100 Hydril 583 Type Average Background (max)Trip Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 10 1010168' 19180' WOB EVERMAR 100% Gas In Air=10,000 UnitsConnection 0 4 3577' 160' Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.75Hycalog SK616M-K1D PDC Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Morning Report Report # 42 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE 1-2-BT-G-X-In-No-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth 25-Jul-2015 12:00 AM Current Pump & Flow Data: 182 Max Lime (lb/bbl) POOH with 5" DP from 9,835' MD to 98' MD and L/D in pipe shed. M/U centrilift BHA. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:RIH with completion string to 8,140' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 26-Jul-2015 12:00 AM Current Pump & Flow Data: 182 Max 1-2-BT-G-X-In-No-TD Conductor ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 43 Customer: Well: Area: Location: Rig: SP01-SE7 L1 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON 15 Report For: Condition 1-1-CT-A-X-IN-WT-TD Bit # 3 8.75Hycalog SK616M-K1D PDC 9.20 Size 4 3577' 160' 100% Gas In Air=10,000 UnitsConnection 0 Tools Xceed 675, EcoScope 675, TeleScope 675 API FL Chromatograph (ppm) 10 1010168' 19180' WOB EVERMAR Avg Min Comments Surface Mud RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst 100 Hydril 583 Type 124.6 170 Hycalog SK616M-K1D PDC 10006' 19093' 19093' Depth in / out YP (lb/100ft2) 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight Hours C-3 Ss Ratio C-1 C-5i AK-AM-0902490118 RIH PV 9012' 8.75 0.902 Footage 73.20 9087' 51.10 J. Keener / M. Billington ShClyst TuffGvlCoal cP 40.0 Gas Summary 0 0 0 (current) Avg to10006' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 19093' 19093' 0' Max @ ft Current Date: Time: Daily losses: 0 bbls. 3 in 3Minimum Depth C-5nC-2 3 SPP (psi) Gallons/stroke TFABit Type Depth 28 L-80 Oil/Water Present Alkal 0.902 0 0 0 Siltst 13.38'' Units* Casing Summary Lithology (%) 0 907-685-0772Unit Phone: 0 Rebecca Mulkey Maximum Report By:Logging Engineers:Kori Jo Plowman / Rebecca Mulkey Set AtSize 178.9 X-65 Grade L-8010148' 20.00'' 9.625" (max)(current) BTC 0 0 Cly 0 WELL INFORMATION Created On : Aug 11 2015 Customer :ENI Petroleum Well Name :SP01-SE7 Job Number :AK-XX-0902490118 Platform :Spy Island 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 12.00 0.00 0.00 N 0.00 E 0.00 0.00 40.41 0.00 12.00 40.41 0.00 N 0.00 E 0.00 0.00 79.86 0.41 265.09 79.86 0.01 S 0.14 W -0.11 1.04 130.19 0.53 268.00 130.19 0.04 S 0.55 W -0.43 0.24 162.83 0.37 297.19 162.83 0.01 N 0.80 W -0.66 0.84 180.92 0.19 91.14 180.92 0.03 N 0.82 W -0.69 3.02 226.37 1.07 89.79 226.36 0.03 N 0.32 W -0.28 1.94 255.16 1.09 70.35 255.15 0.13 N 0.21 E 0.10 1.27 345.09 1.67 52.52 345.05 1.21 N 2.05 E 0.99 0.80 358.64 1.87 44.58 358.60 1.49 N 2.36 E 1.08 2.33 451.51 3.26 26.67 451.37 4.93 N 4.61 E 0.95 1.71 544.38 5.44 20.92 543.97 11.40 N 7.37 E -0.50 2.39 637.23 7.16 24.76 636.26 20.77 N 11.37 E -2.60 1.91 730.59 10.75 19.85 728.46 34.24 N 16.76 E -5.91 3.93 824.62 15.96 15.99 819.92 54.94 N 23.30 E -12.42 5.62 917.50 20.77 14.72 908.05 83.16 N 31.01 E -22.29 5.20 1010.87 23.10 12.58 994.65 117.05 N 39.21 E -35.02 2.64 1068.08 25.44 13.20 1,046.80 139.97 N 44.46 E -43.86 4.11 1161.40 29.91 11.69 1,129.43 182.29 N 53.76 E -60.52 4.85 1254.93 31.16 9.93 1,209.98 228.96 N 62.65 E -80.00 1.64 1348.02 36.26 9.37 1,287.40 279.88 N 71.29 E -102.13 5.49 1441.23 41.70 9.78 1,359.83 337.67 N 81.06 E -127.28 5.84 1534.65 42.85 9.25 1,428.95 399.65 N 91.44 E -154.33 1.29 1627.97 41.97 9.77 1,497.85 461.72 N 101.84 E -181.41 1.02 1721.28 40.63 10.01 1,567.95 522.39 N 112.41 E -207.55 1.45 1814.71 39.82 10.81 1,639.29 581.73 N 123.31 E -232.66 1.03 1908.13 38.33 10.74 1,711.81 639.58 N 134.32 E -256.82 1.60 2001.39 39.52 12.21 1,784.36 697.00 N 145.99 E -280.20 1.62 2094.74 42.04 11.82 1,855.04 756.63 N 158.67 E -304.01 2.71 2188.17 46.04 12.81 1,922.19 820.06 N 172.54 E -329.03 4.34 INSITE V8.3.0 Page 1Job No:AK-XX-0902490118 Well Name:SP01-SE7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2281.60 49.20 13.06 1,985.16 887.32 N 187.99 E -354.95 3.39 2374.96 51.68 13.74 2,044.62 957.33 N 204.68 E -381.44 2.72 2468.35 52.95 13.34 2,101.71 1,029.18 N 221.98 E -408.48 1.40 2561.81 54.74 12.78 2,156.84 1,102.69 N 239.03 E -436.68 1.98 2655.13 60.32 12.73 2,206.92 1,179.45 N 256.40 E -466.47 5.98 2748.49 64.32 13.00 2,250.28 1,260.03 N 274.81 E -497.61 4.29 2841.66 67.70 11.80 2,288.16 1,343.15 N 293.07 E -530.33 3.81 2934.71 69.97 11.20 2,321.75 1,428.18 N 310.37 E -564.93 2.51 3028.05 73.14 9.48 2,351.28 1,515.27 N 326.25 E -601.88 3.82 3121.39 72.73 8.71 2,378.68 1,603.38 N 340.35 E -640.86 0.90 3214.79 72.29 9.79 2,406.75 1,691.30 N 354.67 E -679.56 1.20 3308.08 74.37 9.26 2,433.51 1,779.44 N 369.46 E -718.00 2.30 3401.51 76.32 8.32 2,457.14 1,868.76 N 383.26 E -757.92 2.30 3494.94 74.83 9.20 2,480.42 1,958.19 N 397.04 E -797.93 1.84 3515.28 74.04 9.10 2,485.88 1,977.53 N 400.16 E -806.47 3.91 3615.06 73.64 10.36 2,513.65 2,071.99 N 416.35 E -847.39 1.28 3665.03 73.46 11.68 2,527.80 2,119.03 N 425.51 E -866.86 2.56 3758.18 73.40 13.29 2,554.37 2,206.19 N 444.81 E -901.05 1.66 3851.49 73.53 13.57 2,580.92 2,293.20 N 465.59 E -933.94 0.32 3944.94 74.80 14.13 2,606.42 2,380.49 N 487.11 E -966.37 1.48 4038.30 75.35 14.90 2,630.47 2,467.82 N 509.72 E -997.94 0.99 4131.59 75.49 14.73 2,653.95 2,555.10 N 532.81 E -1029.09 0.23 4224.80 75.50 15.40 2,677.30 2,642.24 N 556.26 E -1059.86 0.70 4318.16 75.16 15.51 2,700.94 2,729.29 N 580.33 E -1090.08 0.38 4411.52 74.75 13.93 2,725.18 2,816.48 N 603.24 E -1121.32 1.69 4504.94 75.09 12.91 2,749.48 2,904.22 N 624.17 E -1154.50 1.12 4598.28 74.69 11.85 2,773.81 2,992.24 N 643.49 E -1189.16 1.18 4691.52 75.10 10.68 2,798.11 3,080.52 N 661.08 E -1225.39 1.29 4785.03 74.47 9.34 2,822.65 3,169.38 N 676.76 E -1263.51 1.54 4878.38 75.29 9.43 2,847.00 3,258.29 N 691.46 E -1302.47 0.88 4971.68 74.69 9.03 2,871.17 3,347.24 N 705.91 E -1341.65 0.76 5065.07 74.93 9.37 2,895.64 3,436.21 N 720.32 E -1380.87 0.44 5158.43 74.86 11.01 2,919.97 3,524.91 N 736.27 E -1418.69 1.70 5251.78 74.86 11.98 2,944.35 3,613.22 N 754.22 E -1454.63 1.00 5345.08 74.93 12.22 2,968.66 3,701.29 N 773.11 E -1489.68 0.26 5438.51 74.93 11.91 2,992.95 3,789.52 N 791.96 E -1524.84 0.32 5531.87 74.76 10.29 3,017.36 3,877.94 N 809.31 E -1561.34 1.68 5625.33 75.11 9.12 3,041.65 3,966.89 N 824.52 E -1599.91 1.27 5718.48 75.26 9.39 3,065.47 4,055.77 N 839.01 E -1639.02 0.32 5811.83 74.99 10.22 3,089.44 4,144.68 N 854.37 E -1677.43 0.91 5905.23 74.15 11.95 3,114.29 4,233.03 N 871.68 E -1713.93 2.00 5998.64 74.58 11.53 3,139.46 4,321.10 N 889.98 E -1749.45 0.63 6091.88 74.39 14.03 3,164.41 4,408.71 N 909.85 E -1783.42 2.59 6185.30 74.29 18.80 3,189.64 4,494.97 N 935.26 E -1812.08 4.92 6278.69 73.67 21.11 3,215.41 4,579.33 N 965.89 E -1835.38 2.47 INSITE V8.3.0 Page 2Job No:AK-XX-0902490118 Well Name:SP01-SE7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6372.02 73.24 22.78 3,241.99 4,662.31 N 999.32 E -1855.59 1.78 6465.38 72.55 25.05 3,269.46 4,743.88 N 1,035.49 E -1872.75 2.44 6558.85 71.14 29.22 3,298.59 4,822.90 N 1,075.97 E -1884.91 4.50 6652.18 70.18 32.61 3,329.51 4,898.44 N 1,121.20 E -1891.19 3.58 6745.58 69.01 35.40 3,362.08 4,971.01 N 1,170.15 E -1892.72 3.07 6838.93 67.33 39.27 3,396.80 5,039.90 N 1,222.67 E -1889.21 4.25 6932.30 66.93 42.44 3,433.09 5,104.96 N 1,278.94 E -1880.44 3.16 7025.62 67.71 45.68 3,469.08 5,166.82 N 1,338.81 E -1866.88 3.31 7118.87 68.37 49.44 3,503.97 5,225.16 N 1,402.62 E -1848.07 3.81 7212.27 68.70 54.27 3,538.16 5,278.83 N 1,470.96 E -1822.87 4.83 7305.61 69.25 60.10 3,571.68 5,326.01 N 1,544.15 E -1789.98 5.86 7398.99 68.68 63.11 3,605.20 5,367.46 N 1,620.80 E -1750.96 3.07 7492.35 68.37 68.61 3,639.40 5,402.97 N 1,700.05 E -1706.42 5.49 7585.84 68.79 72.48 3,673.56 5,431.95 N 1,782.09 E -1655.83 3.88 7679.26 69.26 75.10 3,707.00 5,456.29 N 1,865.84 E -1601.19 2.67 7772.63 69.43 77.09 3,739.94 5,477.29 N 1,950.65 E -1543.77 2.00 7866.01 70.86 79.72 3,771.66 5,494.93 N 2,036.67 E -1483.42 3.06 7959.33 72.75 85.61 3,800.82 5,506.22 N 2,124.55 E -1417.90 6.33 8052.58 74.38 88.33 3,827.21 5,510.94 N 2,213.86 E -1347.46 3.30 8145.95 74.59 92.79 3,852.19 5,510.05 N 2,303.79 E -1273.28 4.61 8239.16 74.23 97.66 3,877.26 5,501.88 N 2,393.17 E -1195.38 5.05 8332.58 74.17 101.48 3,902.70 5,486.94 N 2,481.79 E -1114.21 3.94 8425.90 74.96 105.20 3,927.55 5,466.19 N 2,569.30 E -1030.63 3.93 8519.22 76.72 108.34 3,950.38 5,440.08 N 2,655.92 E -944.70 3.77 8612.64 77.97 110.95 3,970.85 5,409.43 N 2,741.75 E -856.81 3.04 8706.06 77.74 113.77 3,990.51 5,374.69 N 2,826.20 E -767.70 2.96 8799.32 76.82 118.34 4,011.05 5,334.75 N 2,907.91 E -677.87 4.88 8892.67 77.68 121.33 4,031.66 5,289.46 N 2,986.88 E -587.20 3.26 8986.10 79.10 125.78 4,050.47 5,238.88 N 3,063.12 E -495.74 4.91 9079.53 80.52 130.13 4,067.01 5,182.33 N 3,135.60 E -403.93 4.83 9172.89 82.08 133.62 4,081.13 5,120.74 N 3,204.30 E -312.33 4.06 9266.28 83.74 134.10 4,092.66 5,056.52 N 3,271.12 E -220.76 1.85 9359.74 83.73 133.29 4,102.86 4,992.35 N 3,338.29 E -128.93 0.86 9453.06 84.24 133.71 4,112.64 4,928.46 N 3,405.61 E -37.14 0.71 9546.42 84.45 133.95 4,121.84 4,864.12 N 3,472.63 E 54.66 0.34 9639.59 85.11 134.25 4,130.31 4,799.56 N 3,539.26 E 146.28 0.78 9732.93 85.18 134.22 4,138.21 4,734.68 N 3,605.89 E 238.08 0.08 9825.98 85.21 133.26 4,146.01 4,670.57 N 3,672.88 E 329.72 1.03 9919.32 85.09 133.75 4,153.90 4,606.54 N 3,740.34 E 421.71 0.54 10012.72 85.07 134.50 4,161.91 4,541.75 N 3,807.14 E 513.59 0.80 10106.01 87.30 134.73 4,168.12 4,476.38 N 3,873.40 E 605.35 2.40 10125.11 86.95 134.39 4,169.08 4,463.00 N 3,886.99 E 624.17 2.55 10218.80 87.83 133.98 4,173.34 4,397.77 N 3,954.10 E 716.56 1.04 10247.21 89.48 135.29 4,174.01 4,377.81 N 3,974.31 E 744.56 7.41 10340.66 89.99 135.06 4,174.44 4,311.53 N 4,040.19 E 836.54 0.60 INSITE V8.3.0 Page 3Job No:AK-XX-0902490118 Well Name:SP01-SE7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10433.94 89.13 133.11 4,175.16 4,246.64 N 4,107.19 E 928.64 2.28 10527.33 88.41 130.68 4,177.16 4,184.30 N 4,176.68 E 1021.32 2.71 10620.75 87.92 128.00 4,180.15 4,125.11 N 4,248.89 E 1114.42 2.91 10714.16 87.81 125.12 4,183.64 4,069.52 N 4,323.86 E 1207.72 3.08 10807.46 89.15 125.27 4,186.11 4,015.76 N 4,400.07 E 1300.98 1.45 10900.84 90.15 125.37 4,186.68 3,961.78 N 4,476.26 E 1394.36 1.08 10994.15 91.03 125.10 4,185.72 3,907.95 N 4,552.47 E 1487.66 0.99 11087.47 91.05 124.74 4,184.03 3,854.54 N 4,628.98 E 1580.97 0.39 11180.83 90.61 123.61 4,182.67 3,802.10 N 4,706.21 E 1674.31 1.30 11274.15 91.43 124.12 4,181.01 3,750.11 N 4,783.68 E 1767.59 1.03 11367.56 90.29 123.33 4,179.61 3,698.25 N 4,861.36 E 1860.97 1.48 11460.89 89.56 123.09 4,179.73 3,647.14 N 4,939.45 E 1954.25 0.82 11554.26 88.63 123.56 4,181.21 3,595.85 N 5,017.45 E 2047.57 1.12 11647.61 89.55 124.19 4,182.69 3,543.82 N 5,094.95 E 2140.89 1.19 11740.96 90.28 125.92 4,182.83 3,490.21 N 5,171.36 E 2234.23 2.01 11834.40 89.15 126.29 4,183.29 3,435.15 N 5,246.85 E 2327.65 1.27 11927.83 89.61 125.65 4,184.30 3,380.28 N 5,322.46 E 2421.06 0.84 12021.20 88.91 125.86 4,185.51 3,325.72 N 5,398.23 E 2514.42 0.78 12114.58 90.28 125.26 4,186.17 3,271.42 N 5,474.19 E 2607.79 1.60 12208.00 90.99 126.13 4,185.13 3,216.92 N 5,550.05 E 2701.19 1.20 12301.42 91.25 126.87 4,183.31 3,161.36 N 5,625.13 E 2794.56 0.84 12394.76 91.14 127.50 4,181.36 3,104.96 N 5,699.48 E 2887.81 0.69 12488.14 90.45 127.55 4,180.07 3,048.08 N 5,773.53 E 2981.09 0.74 12581.50 89.42 128.79 4,180.17 2,990.39 N 5,846.93 E 3074.31 1.73 12674.86 90.53 129.76 4,180.21 2,931.29 N 5,919.20 E 3167.40 1.58 12768.19 88.96 129.75 4,180.63 2,871.61 N 5,990.94 E 3260.41 1.68 12861.34 88.79 129.00 4,182.46 2,812.53 N 6,062.94 E 3353.27 0.83 12954.65 90.93 127.73 4,182.69 2,754.62 N 6,136.09 E 3446.41 2.67 13048.10 91.10 126.79 4,181.03 2,698.05 N 6,210.46 E 3539.77 1.02 13141.46 92.09 127.35 4,178.43 2,641.80 N 6,284.92 E 3633.03 1.22 13234.75 97.62 125.66 4,170.54 2,586.52 N 6,359.60 E 3725.92 6.20 13327.96 100.47 123.05 4,155.88 2,534.57 N 6,435.57 E 3817.94 4.12 13421.29 100.38 122.60 4,139.00 2,484.82 N 6,512.71 E 3909.67 0.48 13514.68 100.55 124.59 4,122.03 2,434.00 N 6,589.20 E 4001.47 2.10 13608.10 98.70 124.88 4,106.41 2,381.53 N 6,664.89 E 4093.57 2.00 13701.44 95.36 123.36 4,094.99 2,329.58 N 6,741.57 E 4186.18 3.93 13794.68 90.92 122.99 4,089.88 2,278.65 N 6,819.48 E 4279.21 4.78 13888.19 86.75 123.04 4,091.78 2,227.72 N 6,897.85 E 4372.63 4.46 13981.54 87.24 125.13 4,096.68 2,175.48 N 6,975.06 E 4465.83 2.30 14074.84 86.48 127.18 4,101.79 2,120.52 N 7,050.27 E 4558.97 2.34 14168.23 84.65 126.65 4,109.01 2,064.60 N 7,124.71 E 4652.02 2.04 14261.59 82.43 126.38 4,119.51 2,009.40 N 7,199.26 E 4744.75 2.40 14354.94 83.78 124.83 4,130.72 1,955.45 N 7,274.61 E 4837.41 2.19 14448.24 83.41 125.17 4,141.13 1,902.27 N 7,350.56 E 4930.13 0.54 14541.67 83.89 125.17 4,151.46 1,848.78 N 7,426.46 E 5022.99 0.51 INSITE V8.3.0 Page 4Job No:AK-XX-0902490118 Well Name:SP01-SE7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14635.03 87.31 125.48 4,158.63 1,794.97 N 7,502.40 E 5116.06 3.68 14728.49 87.04 125.10 4,163.23 1,741.04 N 7,578.59 E 5209.40 0.50 14821.64 86.89 125.08 4,168.16 1,687.57 N 7,654.70 E 5302.42 0.16 14914.99 89.97 126.51 4,170.72 1,633.00 N 7,730.38 E 5395.71 3.64 15008.39 90.41 126.77 4,170.41 1,577.26 N 7,805.33 E 5489.07 0.55 15101.80 90.98 126.86 4,169.28 1,521.29 N 7,880.10 E 5582.43 0.62 15195.04 90.52 126.86 4,168.06 1,465.36 N 7,954.70 E 5675.61 0.49 15288.46 90.55 127.12 4,167.19 1,409.15 N 8,029.31 E 5768.97 0.28 15381.85 90.56 127.00 4,166.28 1,352.88 N 8,103.83 E 5862.30 0.13 15475.18 90.43 125.93 4,165.47 1,297.41 N 8,178.89 E 5955.59 1.15 15568.54 89.73 125.31 4,165.34 1,243.04 N 8,254.78 E 6048.94 1.00 15662.01 89.20 124.20 4,166.22 1,189.76 N 8,331.57 E 6142.41 1.32 15755.34 89.38 124.53 4,167.37 1,137.08 N 8,408.60 E 6235.73 0.40 15848.74 89.71 125.05 4,168.11 1,083.79 N 8,485.31 E 6329.12 0.66 15942.09 88.16 124.40 4,169.85 1,030.62 N 8,562.01 E 6422.45 1.80 16035.46 87.92 122.17 4,173.04 979.42 N 8,640.02 E 6515.72 2.40 16128.78 88.05 123.81 4,176.33 928.64 N 8,718.24 E 6608.92 1.76 16222.03 87.56 125.84 4,179.90 875.43 N 8,794.73 E 6702.10 2.24 16315.43 88.07 127.63 4,183.46 819.61 N 8,869.52 E 6795.38 1.99 16408.78 89.55 126.79 4,185.40 763.17 N 8,943.85 E 6888.64 1.82 16502.15 91.01 126.76 4,184.94 707.27 N 9,018.63 E 6981.96 1.56 16595.51 90.99 126.54 4,183.31 651.55 N 9,093.52 E 7075.27 0.24 16689.00 90.87 125.95 4,181.79 596.28 N 9,168.91 E 7168.72 0.64 16782.42 90.71 125.34 4,180.51 541.85 N 9,244.82 E 7262.13 0.67 16875.79 88.86 125.01 4,180.86 488.06 N 9,321.14 E 7355.49 2.01 16969.17 90.44 125.07 4,181.43 434.45 N 9,397.59 E 7448.87 1.69 17062.49 90.56 126.42 4,180.61 379.94 N 9,473.33 E 7542.17 1.45 17155.74 90.50 126.80 4,179.75 324.33 N 9,548.18 E 7635.38 0.41 17249.11 91.42 127.27 4,178.19 268.10 N 9,622.70 E 7728.68 1.11 17342.32 91.82 126.88 4,175.55 211.93 N 9,697.04 E 7821.79 0.60 17435.74 91.95 124.73 4,172.48 157.31 N 9,772.76 E 7915.14 2.30 17529.06 92.14 124.46 4,169.15 104.36 N 9,849.53 E 8008.40 0.35 17622.37 91.82 123.41 4,165.92 52.30 N 9,926.90 E 8101.64 1.18 17716.34 92.23 123.37 4,162.60 0.62 N 10,005.31 E 8195.51 0.44 17809.22 93.00 124.57 4,158.37 51.22 S 10,082.25 E 8288.28 1.53 17902.48 90.79 125.91 4,155.28 105.00 S 10,158.37 E 8381.48 2.77 17995.83 90.07 127.19 4,154.58 160.59 S 10,233.36 E 8474.79 1.57 18089.26 90.39 128.09 4,154.21 217.65 S 10,307.34 E 8568.12 1.02 18182.69 90.22 127.70 4,153.71 275.03 S 10,381.07 E 8661.43 0.46 18276.05 90.81 127.39 4,152.87 331.92 S 10,455.09 E 8754.69 0.71 18369.44 90.17 126.68 4,152.07 388.17 S 10,529.64 E 8848.02 1.02 18462.90 90.40 125.15 4,151.61 442.99 S 10,605.33 E 8941.46 1.66 18556.22 89.95 124.82 4,151.32 496.49 S 10,681.78 E 9034.78 0.60 18649.58 89.93 125.62 4,151.42 550.33 S 10,758.05 E 9128.14 0.86 18742.75 89.56 126.48 4,151.83 605.16 S 10,833.38 E 9221.29 1.00 INSITE V8.3.0 Page 5Job No:AK-XX-0902490118 Well Name:SP01-SE7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 18835.80 90.21 126.50 4,152.02 660.50 S 10,908.19 E 9314.31 0.70 18929.14 90.89 126.19 4,151.12 715.81 S 10,983.36 E 9407.62 0.80 19022.48 90.66 126.22 4,149.86 770.94 S 11,058.67 E 9500.93 0.25 19114.91 89.85 125.95 4,149.45 825.38 S 11,133.37 E 9593.34 0.92 19180.00 89.85 125.95 4,149.62 863.59 S 11,186.06 E 9658.42 0.00 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 125.00 degrees (True) - A total correction of 18.91 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 19,180.00 feet is 11,219.35 feet along 94.41 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 V8.3.0 Page 6Job No:AK-XX-0902490118 Well Name:SP01-SE7 Survey Report WELL INFORMATION Created On : Aug 11 2015 Customer :ENI Petroleum Well Name :SP01-SE7 L1 Job Number :AK-XX-0902490118 Platform :Spy Island 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 12.00 0.00 0.00 N 0.00 E 0.00 0.00 40.41 0.00 12.00 40.41 0.00 N 0.00 E 0.00 0.00 79.86 0.41 265.09 79.86 0.01 S 0.14 W -0.11 1.04 130.19 0.53 268.00 130.19 0.04 S 0.55 W -0.43 0.24 162.83 0.37 297.19 162.83 0.01 N 0.80 W -0.66 0.84 180.92 0.19 91.14 180.92 0.03 N 0.82 W -0.69 3.02 226.37 1.07 89.79 226.36 0.03 N 0.32 W -0.28 1.94 255.16 1.09 70.35 255.15 0.13 N 0.21 E 0.10 1.27 345.09 1.67 52.52 345.05 1.21 N 2.05 E 0.99 0.80 358.64 1.87 44.58 358.60 1.49 N 2.36 E 1.08 2.33 451.51 3.26 26.67 451.37 4.93 N 4.61 E 0.95 1.71 544.38 5.44 20.92 543.97 11.40 N 7.37 E -0.50 2.39 637.23 7.16 24.76 636.26 20.77 N 11.37 E -2.60 1.91 730.59 10.75 19.85 728.46 34.24 N 16.76 E -5.91 3.93 824.62 15.96 15.99 819.92 54.94 N 23.30 E -12.42 5.62 917.50 20.77 14.72 908.05 83.16 N 31.01 E -22.29 5.20 1010.87 23.10 12.58 994.65 117.05 N 39.21 E -35.02 2.64 1068.08 25.44 13.20 1,046.80 139.97 N 44.46 E -43.86 4.11 1161.40 29.91 11.69 1,129.43 182.29 N 53.76 E -60.52 4.85 1254.93 31.16 9.93 1,209.98 228.96 N 62.65 E -80.00 1.64 1348.02 36.26 9.37 1,287.40 279.88 N 71.29 E -102.13 5.49 1441.23 41.70 9.78 1,359.83 337.67 N 81.06 E -127.28 5.84 1534.65 42.85 9.25 1,428.95 399.65 N 91.44 E -154.33 1.29 1627.97 41.97 9.77 1,497.85 461.72 N 101.84 E -181.41 1.02 1721.28 40.63 10.01 1,567.95 522.39 N 112.41 E -207.55 1.45 1814.71 39.82 10.81 1,639.29 581.73 N 123.31 E -232.66 1.03 1908.13 38.33 10.74 1,711.81 639.58 N 134.32 E -256.82 1.60 2001.39 39.52 12.21 1,784.36 697.00 N 145.99 E -280.20 1.62 2094.74 42.04 11.82 1,855.04 756.63 N 158.67 E -304.01 2.71 2188.17 46.04 12.81 1,922.19 820.06 N 172.54 E -329.03 4.34 INSITE V8.3.0 Page 1Job No:AK-XX-0902490118 Well Name:SP01-SE7 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2281.60 49.20 13.06 1,985.16 887.32 N 187.99 E -354.95 3.39 2374.96 51.68 13.74 2,044.62 957.33 N 204.68 E -381.44 2.72 2468.35 52.95 13.34 2,101.71 1,029.18 N 221.98 E -408.48 1.40 2561.81 54.74 12.78 2,156.84 1,102.69 N 239.03 E -436.68 1.98 2655.13 60.32 12.73 2,206.92 1,179.45 N 256.40 E -466.47 5.98 2748.49 64.32 13.00 2,250.28 1,260.03 N 274.81 E -497.61 4.29 2841.66 67.70 11.80 2,288.16 1,343.15 N 293.07 E -530.33 3.81 2934.71 69.97 11.20 2,321.75 1,428.18 N 310.37 E -564.93 2.51 3028.05 73.14 9.48 2,351.28 1,515.27 N 326.25 E -601.88 3.82 3121.39 72.73 8.71 2,378.68 1,603.38 N 340.35 E -640.86 0.90 3214.79 72.29 9.79 2,406.75 1,691.30 N 354.67 E -679.56 1.20 3308.08 74.37 9.26 2,433.51 1,779.44 N 369.46 E -718.00 2.30 3401.51 76.32 8.32 2,457.14 1,868.76 N 383.26 E -757.92 2.30 3494.94 74.83 9.20 2,480.42 1,958.19 N 397.04 E -797.93 1.84 3515.28 74.04 9.10 2,485.88 1,977.53 N 400.16 E -806.47 3.91 3615.06 73.64 10.36 2,513.65 2,071.99 N 416.35 E -847.39 1.28 3665.03 73.46 11.68 2,527.80 2,119.03 N 425.51 E -866.86 2.56 3758.18 73.40 13.29 2,554.37 2,206.19 N 444.81 E -901.05 1.66 3851.49 73.53 13.57 2,580.92 2,293.20 N 465.59 E -933.94 0.32 3944.94 74.80 14.13 2,606.42 2,380.49 N 487.11 E -966.37 1.48 4038.30 75.35 14.90 2,630.47 2,467.82 N 509.72 E -997.94 0.99 4131.59 75.49 14.73 2,653.95 2,555.10 N 532.81 E -1029.09 0.23 4224.80 75.50 15.40 2,677.30 2,642.24 N 556.26 E -1059.86 0.70 4318.16 75.16 15.51 2,700.94 2,729.29 N 580.33 E -1090.08 0.38 4411.52 74.75 13.93 2,725.18 2,816.48 N 603.24 E -1121.32 1.69 4504.94 75.09 12.91 2,749.48 2,904.22 N 624.17 E -1154.50 1.12 4598.28 74.69 11.85 2,773.81 2,992.24 N 643.49 E -1189.16 1.18 4691.52 75.10 10.68 2,798.11 3,080.52 N 661.08 E -1225.39 1.29 4785.03 74.47 9.34 2,822.65 3,169.38 N 676.76 E -1263.51 1.54 4878.38 75.29 9.43 2,847.00 3,258.29 N 691.46 E -1302.47 0.88 4971.68 74.69 9.03 2,871.17 3,347.24 N 705.91 E -1341.65 0.76 5065.07 74.93 9.37 2,895.64 3,436.21 N 720.32 E -1380.87 0.44 5158.43 74.86 11.01 2,919.97 3,524.91 N 736.27 E -1418.69 1.70 5251.78 74.86 11.98 2,944.35 3,613.22 N 754.22 E -1454.63 1.00 5345.08 74.93 12.22 2,968.66 3,701.29 N 773.11 E -1489.68 0.26 5438.51 74.93 11.91 2,992.95 3,789.52 N 791.96 E -1524.84 0.32 5531.87 74.76 10.29 3,017.36 3,877.94 N 809.31 E -1561.34 1.68 5625.33 75.11 9.12 3,041.65 3,966.89 N 824.52 E -1599.91 1.27 5718.48 75.26 9.39 3,065.47 4,055.77 N 839.01 E -1639.02 0.32 5811.83 74.99 10.22 3,089.44 4,144.68 N 854.37 E -1677.43 0.91 5905.23 74.15 11.95 3,114.29 4,233.03 N 871.68 E -1713.93 2.00 5998.64 74.58 11.53 3,139.46 4,321.10 N 889.98 E -1749.45 0.63 6091.88 74.39 14.03 3,164.41 4,408.71 N 909.85 E -1783.42 2.59 6185.30 74.29 18.80 3,189.64 4,494.97 N 935.26 E -1812.08 4.92 6278.69 73.67 21.11 3,215.41 4,579.33 N 965.89 E -1835.38 2.47 INSITE V8.3.0 Page 2Job No:AK-XX-0902490118 Well Name:SP01-SE7 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6372.02 73.24 22.78 3,241.99 4,662.31 N 999.32 E -1855.59 1.78 6465.38 72.55 25.05 3,269.46 4,743.88 N 1,035.49 E -1872.75 2.44 6558.85 71.14 29.22 3,298.59 4,822.90 N 1,075.97 E -1884.91 4.50 6652.18 70.18 32.61 3,329.51 4,898.44 N 1,121.20 E -1891.19 3.58 6745.58 69.01 35.40 3,362.08 4,971.01 N 1,170.15 E -1892.72 3.07 6838.93 67.33 39.27 3,396.80 5,039.90 N 1,222.67 E -1889.21 4.25 6932.30 66.93 42.44 3,433.09 5,104.96 N 1,278.94 E -1880.44 3.16 7025.62 67.71 45.68 3,469.08 5,166.82 N 1,338.81 E -1866.88 3.31 7118.87 68.37 49.44 3,503.97 5,225.16 N 1,402.62 E -1848.07 3.81 7212.27 68.70 54.27 3,538.16 5,278.83 N 1,470.96 E -1822.87 4.83 7305.61 69.25 60.10 3,571.68 5,326.01 N 1,544.15 E -1789.98 5.86 7398.99 68.68 63.11 3,605.20 5,367.46 N 1,620.80 E -1750.96 3.07 7492.35 68.37 68.61 3,639.40 5,402.97 N 1,700.05 E -1706.42 5.49 7585.84 68.79 72.48 3,673.56 5,431.95 N 1,782.09 E -1655.83 3.88 7679.26 69.26 75.10 3,707.00 5,456.29 N 1,865.84 E -1601.19 2.67 7772.63 69.43 77.09 3,739.94 5,477.29 N 1,950.65 E -1543.77 2.00 7866.01 70.86 79.72 3,771.66 5,494.93 N 2,036.67 E -1483.42 3.06 7959.33 72.75 85.61 3,800.82 5,506.22 N 2,124.55 E -1417.90 6.33 8052.58 74.38 88.33 3,827.21 5,510.94 N 2,213.86 E -1347.46 3.30 8145.95 74.59 92.79 3,852.19 5,510.05 N 2,303.79 E -1273.28 4.61 8239.16 74.23 97.66 3,877.26 5,501.88 N 2,393.17 E -1195.38 5.05 8332.58 74.17 101.48 3,902.70 5,486.94 N 2,481.79 E -1114.21 3.94 8425.90 74.96 105.20 3,927.55 5,466.19 N 2,569.30 E -1030.63 3.93 8519.22 76.72 108.34 3,950.38 5,440.08 N 2,655.92 E -944.70 3.77 8612.64 77.97 110.95 3,970.85 5,409.43 N 2,741.75 E -856.81 3.04 8706.06 77.74 113.77 3,990.51 5,374.69 N 2,826.20 E -767.70 2.96 8799.32 76.82 118.34 4,011.05 5,334.75 N 2,907.91 E -677.87 4.88 8892.67 77.68 121.33 4,031.66 5,289.46 N 2,986.88 E -587.20 3.26 8986.10 79.10 125.78 4,050.47 5,238.88 N 3,063.12 E -495.74 4.91 9079.53 80.52 130.13 4,067.01 5,182.33 N 3,135.60 E -403.93 4.83 9172.89 82.08 133.62 4,081.13 5,120.74 N 3,204.30 E -312.33 4.06 9266.28 83.74 134.10 4,092.66 5,056.52 N 3,271.12 E -220.76 1.85 9359.74 83.73 133.29 4,102.86 4,992.35 N 3,338.29 E -128.93 0.86 9453.06 84.24 133.71 4,112.64 4,928.46 N 3,405.61 E -37.14 0.71 9546.42 84.45 133.95 4,121.84 4,864.12 N 3,472.63 E 54.66 0.34 9639.59 85.11 134.25 4,130.31 4,799.56 N 3,539.26 E 146.28 0.78 9732.93 85.18 134.22 4,138.21 4,734.68 N 3,605.89 E 238.08 0.08 9825.98 85.21 133.26 4,146.01 4,670.57 N 3,672.88 E 329.72 1.03 9919.32 85.09 133.75 4,153.90 4,606.54 N 3,740.34 E 421.71 0.54 9957.00 85.08 134.05 4,157.13 4,580.51 N 3,767.39 E 458.80 0.79 9974.00 87.00 133.35 4,158.30 4,568.79 N 3,779.65 E 475.56 12.02 10063.20 85.00 130.53 4,164.53 4,509.33 N 3,845.83 E 563.88 3.87 10156.58 89.26 127.59 4,169.20 4,450.59 N 3,918.23 E 656.87 5.54 10249.94 91.43 124.65 4,168.64 4,395.56 N 3,993.63 E 750.20 3.91 10343.39 89.70 122.15 4,167.72 4,344.13 N 4,071.63 E 843.60 3.25 INSITE V8.3.0 Page 3Job No:AK-XX-0902490118 Well Name:SP01-SE7 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10436.67 90.29 121.27 4,167.73 4,295.10 N 4,150.99 E 936.72 1.14 10530.06 89.98 121.13 4,167.51 4,246.72 N 4,230.87 E 1029.91 0.36 10623.48 89.07 121.19 4,168.28 4,198.38 N 4,310.81 E 1123.11 0.98 10716.89 88.48 121.24 4,170.28 4,149.99 N 4,390.67 E 1216.30 0.63 10810.19 88.12 123.96 4,173.05 4,099.75 N 4,469.23 E 1309.47 2.94 10903.57 88.96 125.75 4,175.42 4,046.40 N 4,545.83 E 1402.81 2.12 10996.88 87.83 127.20 4,178.04 3,990.95 N 4,620.83 E 1496.05 1.97 11090.20 88.21 128.12 4,181.26 3,933.97 N 4,694.66 E 1589.21 1.07 11183.56 88.19 127.84 4,184.20 3,876.55 N 4,768.22 E 1682.40 0.30 11276.88 86.20 130.07 4,188.76 3,817.95 N 4,840.69 E 1775.37 3.20 11370.29 87.63 130.32 4,193.79 3,757.76 N 4,911.94 E 1868.26 1.55 11463.62 89.08 128.31 4,196.47 3,698.65 N 4,984.11 E 1961.28 2.65 11556.99 88.61 125.98 4,198.35 3,642.29 N 5,058.51 E 2054.56 2.55 11650.34 89.58 125.92 4,199.83 3,587.49 N 5,134.07 E 2147.89 1.04 11743.69 89.73 124.94 4,200.39 3,533.38 N 5,210.14 E 2241.23 1.06 11837.13 90.21 124.71 4,200.44 3,480.02 N 5,286.84 E 2334.67 0.57 11930.56 89.28 122.10 4,200.85 3,428.59 N 5,364.83 E 2428.05 2.97 12023.93 90.46 123.32 4,201.06 3,378.13 N 5,443.39 E 2521.35 1.82 12117.31 90.38 124.19 4,200.38 3,326.25 N 5,521.02 E 2614.70 0.94 12210.73 90.25 124.47 4,199.87 3,273.56 N 5,598.17 E 2708.11 0.33 12304.15 90.35 122.94 4,199.38 3,221.73 N 5,675.88 E 2801.51 1.64 12397.49 89.06 122.20 4,199.86 3,171.48 N 5,754.54 E 2894.76 1.59 12490.87 89.34 123.32 4,201.16 3,120.96 N 5,833.06 E 2988.06 1.24 12584.23 91.78 123.34 4,200.25 3,069.66 N 5,911.05 E 3081.36 2.61 12677.59 93.21 126.14 4,196.18 3,016.52 N 5,987.69 E 3174.62 3.37 12770.92 92.08 124.61 4,191.88 2,962.55 N 6,063.70 E 3267.85 2.04 12864.07 92.89 125.49 4,187.84 2,909.11 N 6,139.89 E 3360.91 1.28 12957.38 93.72 127.65 4,182.46 2,853.61 N 6,214.70 E 3454.02 2.48 13050.83 93.72 131.60 4,176.39 2,794.15 N 6,286.51 E 3546.95 4.22 13144.19 93.95 130.55 4,170.15 2,732.94 N 6,356.73 E 3639.58 1.15 13237.48 93.97 128.82 4,163.71 2,673.52 N 6,428.35 E 3732.33 1.85 13330.69 91.70 128.93 4,159.10 2,615.09 N 6,500.82 E 3825.21 2.44 13361.15 91.88 127.28 4,158.14 2,596.30 N 6,524.78 E 3855.61 5.45 13393.57 91.04 126.88 4,157.32 2,576.76 N 6,550.63 E 3888.00 2.87 13424.02 90.40 126.62 4,156.94 2,558.55 N 6,575.03 E 3918.43 2.27 13455.48 89.88 125.89 4,156.86 2,539.94 N 6,600.40 E 3949.88 2.85 13487.10 89.81 127.00 4,156.94 2,521.16 N 6,625.83 E 3981.49 3.52 13517.41 89.79 126.14 4,157.05 2,503.10 N 6,650.18 E 4011.79 2.84 13551.74 89.96 125.00 4,157.13 2,483.13 N 6,678.10 E 4046.12 3.36 13582.34 90.38 124.61 4,157.03 2,465.67 N 6,703.23 E 4076.72 1.87 13610.83 90.31 123.92 4,156.86 2,449.63 N 6,726.77 E 4105.20 2.43 13644.67 90.27 123.18 4,156.69 2,430.92 N 6,754.97 E 4139.03 2.19 13676.06 90.32 122.67 4,156.53 2,413.86 N 6,781.32 E 4170.40 1.63 13704.17 90.40 123.75 4,156.35 2,398.47 N 6,804.84 E 4198.50 3.85 13733.14 89.92 123.21 4,156.27 2,382.49 N 6,829.00 E 4227.45 2.49 INSITE V8.3.0 Page 4Job No:AK-XX-0902490118 Well Name:SP01-SE7 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 13797.41 89.85 125.21 4,156.40 2,346.35 N 6,882.15 E 4291.72 3.11 13890.92 90.12 125.67 4,156.43 2,292.13 N 6,958.33 E 4385.22 0.57 13984.27 88.82 125.76 4,157.29 2,237.64 N 7,034.12 E 4478.56 1.40 14077.57 85.01 125.03 4,162.31 2,183.69 N 7,110.05 E 4571.70 4.16 14170.96 84.68 124.22 4,170.70 2,130.84 N 7,186.59 E 4664.71 0.93 14264.32 86.03 124.47 4,178.26 2,078.34 N 7,263.42 E 4757.76 1.47 14357.67 89.66 124.21 4,181.77 2,025.73 N 7,340.43 E 4851.02 3.90 14450.97 90.97 125.91 4,181.26 1,972.14 N 7,416.80 E 4944.31 2.30 14544.40 90.15 126.33 4,180.35 1,917.07 N 7,492.26 E 5037.72 0.99 14637.76 88.13 126.85 4,181.75 1,861.43 N 7,567.21 E 5131.03 2.23 14731.22 88.13 126.78 4,184.80 1,805.45 N 7,641.99 E 5224.39 0.07 14824.37 88.56 126.51 4,187.49 1,749.88 N 7,716.70 E 5317.46 0.55 14918.47 89.66 125.28 4,188.95 1,694.72 N 7,792.92 E 5411.54 1.75 15011.12 89.47 125.86 4,189.65 1,640.82 N 7,868.28 E 5504.18 0.66 15104.53 90.26 125.49 4,189.87 1,586.35 N 7,944.16 E 5597.58 0.93 15197.77 91.00 124.09 4,188.85 1,533.15 N 8,020.72 E 5690.81 1.70 15291.19 90.79 123.59 4,187.39 1,481.14 N 8,098.31 E 5784.20 0.58 15384.58 90.69 124.29 4,186.18 1,429.00 N 8,175.78 E 5877.57 0.76 15477.91 90.41 123.70 4,185.29 1,376.82 N 8,253.15 E 5970.88 0.70 15571.27 90.15 125.50 4,184.83 1,323.81 N 8,330.00 E 6064.23 1.95 15664.74 89.69 123.66 4,184.96 1,270.76 N 8,406.95 E 6157.69 2.03 15758.07 90.66 124.40 4,184.67 1,218.53 N 8,484.30 E 6251.01 1.31 15851.47 91.63 124.59 4,182.81 1,165.65 N 8,561.26 E 6344.39 1.06 15944.82 91.56 124.73 4,180.21 1,112.58 N 8,638.01 E 6437.70 0.17 16038.19 92.13 127.15 4,177.20 1,057.81 N 8,713.56 E 6531.00 2.66 16131.51 91.17 127.75 4,174.52 1,001.09 N 8,787.62 E 6624.19 1.21 16224.76 92.01 126.51 4,171.93 944.83 N 8,861.93 E 6717.34 1.61 16318.78 91.92 127.69 4,168.70 888.15 N 8,936.87 E 6811.24 1.26 16411.51 90.55 128.10 4,166.71 831.20 N 9,010.03 E 6903.83 1.54 16504.88 92.02 126.93 4,164.61 774.36 N 9,084.07 E 6997.08 2.01 16598.24 91.55 126.47 4,161.70 718.59 N 9,158.89 E 7090.35 0.70 16691.73 90.14 125.89 4,160.33 663.41 N 9,234.34 E 7183.81 1.63 16785.15 90.38 124.50 4,159.90 609.57 N 9,310.68 E 7277.23 1.51 16878.52 90.24 125.40 4,159.40 556.08 N 9,387.21 E 7370.60 0.98 16971.90 90.95 126.43 4,158.43 501.31 N 9,462.83 E 7463.96 1.34 17065.22 90.83 125.77 4,156.98 446.34 N 9,538.22 E 7557.25 0.72 17158.47 90.00 124.64 4,156.30 392.58 N 9,614.41 E 7650.49 1.50 17251.84 90.58 124.86 4,155.83 339.36 N 9,691.13 E 7743.86 0.66 17345.05 90.36 126.32 4,155.06 285.12 N 9,766.92 E 7837.06 1.58 17438.47 90.89 126.23 4,154.05 229.85 N 9,842.23 E 7930.45 0.58 17531.79 90.78 126.32 4,152.69 174.64 N 9,917.46 E 8023.74 0.15 17625.57 89.13 126.71 4,152.76 118.84 N 9,992.82 E 8117.48 1.81 17718.53 87.77 128.00 4,155.27 62.46 N 10,066.69 E 8210.32 2.02 17811.95 87.94 127.97 4,158.77 5.00 N 10,140.27 E 8303.55 0.18 17905.21 88.09 127.29 4,162.00 51.90 S 10,214.08 E 8396.66 0.75 INSITE V8.3.0 Page 5Job No:AK-XX-0902490118 Well Name:SP01-SE7 L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 17998.56 90.10 128.48 4,163.48 109.21 S 10,287.74 E 8489.87 2.50 18091.99 88.20 128.96 4,164.86 167.65 S 10,360.63 E 8583.09 2.10 18185.42 89.69 126.83 4,166.58 225.02 S 10,434.34 E 8676.38 2.78 18278.78 90.16 124.53 4,166.70 279.47 S 10,510.17 E 8769.72 2.51 18372.17 91.13 123.01 4,165.65 331.37 S 10,587.79 E 8863.08 1.93 18465.63 90.38 124.11 4,164.42 383.03 S 10,665.66 E 8956.50 1.42 18558.95 90.46 123.50 4,163.74 434.95 S 10,743.20 E 9049.80 0.66 18652.31 89.55 123.34 4,163.73 486.37 S 10,821.13 E 9143.12 0.99 18745.48 89.70 123.93 4,164.34 537.98 S 10,898.70 E 9236.26 0.65 18838.53 90.63 124.38 4,164.07 590.22 S 10,975.70 E 9329.30 1.11 18931.87 90.25 125.71 4,163.35 643.81 S 11,052.11 E 9422.64 1.48 19025.85 90.25 126.15 4,162.94 698.96 S 11,128.21 E 9516.60 0.47 19093.00 90.25 126.15 4,162.65 738.57 S 11,182.43 E 9583.74 0.00 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 125.00 degrees (True) - A total correction of 18.91 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 19,093.00 feet is 11,206.79 feet along 93.78 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 V8.3.0 Page 6Job No:AK-XX-0902490118 Well Name:SP01-SE7 L1 Survey Report
