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212-019
Remark: AOGCC Coordinate Conversion Check 26 July 2019 INPUT State Plane, NA027 5003 - Alaska 3, U.S. Feet NorthingN,. 5914755.67 Easting/X: 349352.14 Convergence: -1 08 27.09604 Scale Factor: 0. 999925781 Z (2- --n/% OUTPUT Geographic, NA027 Red Wolf 2 1/1 Latitude: 70 10 27.23299 Longitude: 147 12 45.79319 Corpscon v6.0.1, U.S. Army Corps of Engineers Remark: AOGCC Coordinate Conversion Check 26 July 2019 INPUT State Plane, NAD27 5003 -Alaska 3, U.S. Feet 212,--61V OUTPUT �� Geographic, NAD83 Accuracies of conversions from NAD 27 to NAD 83 are typically 12 to 18 cm. Red Wolf 2 1/1 NorthingfY: 5914755.67 Latitude: 70.173991269 EastinglX: 349352.14 Longitude: 147.215687699 Convergence: -1 08 27.09604 Scale Factor: 0.999925781 Datum Shift (m.): Delta Lat. = -26.788, Delta Lon = 112.375 Corpscon v6.0.1, U.S. Army Corps of Engineers •► • RECEIVED SAVANT ALASKA 601 W. 5th Avenue, Suite 310 MAIZ016 Anchorage, Alaska 99501 Phone: (907) 334-6745 Fax: (907) 334-6735 AOGCC DATA TRANSMITTAL Date: May 24, 2016 To: Meredith Guhl From: Anna M. Belanger Petroleum Geology Assistant Senior Geologist Alaska Oil and Gas Conservation Commission Cook Inlet Energy, LLC 333. W. 7th Ave, Suite 100 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 Anchorage, AK 99501 Phone: (907) 793-1235 Phone: (907)433 -3837 FAX: (907)334-6735 Item No. Qty Description 1 1 B1-18A Mudlog LAS file zip - bb 3 t Sc 1 1 Red Wolf#2 Mudlog LAS file 212- 0 : 2-15.13- Email ,\ -Email completed transmittal to: abelanger@glacieroil.com Please sign below to acknowledge rece'. . Received By: Date: Returned to Cook Inlet Energy, LLC Date Accepted By: SCANNED MAY 2 5 2016 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 i by direct inspection of the file. a(a_ 0 1 q Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: of Items: ❑ Maps: rayscale Items: ogs: 011 up) ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: MOP Date: g /3 /s/ 1 Project Proofing BY: all° Date: f IS 1 /s/ Scanning Preparation I o. x 30 = 3&O + '3 1D= TOTAL PAGES 3 3 • = a I (Count does not include cover sheet) BY: AM Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: 3 Count does include cover sh g �( ) Page Count Matches Number in Scannin Prepa ation: ES NO p BY: tig. Date: Is— `I+ /s/ 04f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: eat NO TOTAL PAGES: 3(0 ..---1/n Digital version appended by: Meredith Michal IV rr Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Lt0 0 Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc z 00 o � N o • r-- Lc) N to J O CO 0 _ 0 N N N •N • N • G r> z c _ r N a> E E0 a) a) a) a O. a a o. +>` , cocv U OI 2 it J J J a) > •C o 5 'I } (0 w 0 LL O LL 0 LL 0 LL 1 .N O` o N H 0 0 0 0 0 0 0 0 • . O O o > 2 O (0 > N N N LO N N N tOO 0 0 p O 0 Z Cal -ID I w a) N N w w w w w w 0 J J •O N f>0->'' .N (/) _ . w J C C C () F. ii) O 0 O O O O O O O m O W 0 >,>. 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L L o 0 a m 02 �`o U U� I pp Q I I\ a N C Q Q co d Z Z c E a; @ E } 1 io I— 0 � � C ��// co U) LL J aci m J 0 a 4f a) — 7 — f0 as 0 U ama 0) ! ^ E r) -- as E CL y fq - 0 LLI (n Z 0 aS a co I— LE E 1 I as U w Q m co0) Q 1 V d E Z 8 a d �? 0 0 o •o N co ICC 10 W J O. C J 0 co2 0 0 CL c c c 5gctto C •_N 0 N 0E CIO N 0 w &) 0 c 4 N } } CJ E cn n Q` LL . O Occl r J .0 j 0 a 0 o co 1 co 3 N 0 5r 0 re N -cii N co C r CO CU M a N E W Z c 0 F- E •C n m - co m CO : :y o0 1 •- rn 0 1 v/ Q Co N``M c _ G Q c - m m c v a F" co - o c 0. - - O O i) t Q Z EO 0) 0 T D E U o o ' "-----------)m Z d N 7 co c (Q \ N N J ^ CU E J1 o a }}c 1 ii co .1 o w o } II m >_ - • I- C 0 V N — W E a 0 0 us 0 N a7 0) W .c ° t N a) a w 1 rt 0 5 2 > EL a m co as 1 0 N N y 0w W CC G c Z U o - m Q o o Q o o 0 c c U E U D a -o o a (0 0 E • a C o - LL E O o E E E a 2 3 i o a 0 0 o To 0 0 0 Guhl, Meredith D (DOA) From: Erik Opstad [Erik.Opstad@savantalaska.com] Sent: Thursday, June 05, 2014 9:31 AM To: Guhl, Meredith D (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: Badami Red Wolf 2, PTD 212-019: Directional Survey Attachments: Red Wolf#2 Definitive Survey- Excel Format.xlsx Meredith, Li? (c) D'?:) As you requested, attached please find an Excel version of the definitive survey for Red Wolf #2. Let me know if you need anything else. Regards, Erik SAVANT ALASKA Erik A. Opstad, Manager Savant Alaska,LLC-Drilling&Wells Group 4720 Business Park Blvd. Suite G40, Anchorage,AK 99503 (C)907-244-5210•(0)907-433-7803•(NS)907-448-6010 E-Mail:Erik.Opstad@SavantAlaska.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Monday, June 02, 2014 3:44 PM To: Erik Opstad Cc: Davies, Stephen F (DOA) Subject: Badami Red Wolf 2, PTD 212-019: Directional Survey Hello Erik, I am completing the final compliance review for Red Wolf 2,due for release to the public on 5/30/2014. During my review I noted that the definitive survey was only provided in PDF format. Could you please email me a text or excel version of the final definitive survey? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 1 Guhl, Meredith D (DOA) From: Decker, Paul L(DNR) Sent: Wednesday, May 28, 2014 4:17 PM To: Guhl, Meredith D (DOA) Cc: Davies, Stephen F (DOA); Bettis, Patricia K(DOA) Subject: RE: Red Wolf 2, PTD 212-019 Hi Meredith, No, DNR has not received any request for extended confidentiality on the subject well. Thanks, -Paul Paul L.Decker,Petroleum Geologist Resource Evaluation Manager Alaska Division of Oil&Gas 550 W.7th Ave,Ste.1100 Anchorage,AK 99501 (907)269-8791 paul.decker@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Department of Natural Resources(DNR),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the DNR is aware of the mistake in sending it to you,contact Paul Decker at(907) 269-8791 or paul.decker@alaska.gov. From: Guhl, Meredith D (DOA) Sent: Wednesday, May 28, 2014 3:22 PM To: Decker, Paul L(DNR) Cc: Davies, Stephen F (DOA); Bettis, Patricia K (DOA) Subject: Red Wolf 2, PTD 212-019 Hello Paul, Red Wolf 2, drilled by Savant Alaska LLC and completed on 4/30/2012, is due to be released on 5/30/2014. Has extended confidentiality been requested for this well? Sorry for the short notice. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, 1 Release of Confidential Data Coversheet Well Name: Vj 2-12- 017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: ONE Gas❑ SPLUG❑ Other❑ Abandoned ❑' Suspended❑ 1b.Well Class. n 20AAC 25.105 20AAC 25.110 Development 0 Exploratory0 GINJ❑ WINJ 1:1 WAGE] WDSPLI No.of Completions:_0 Service Slratigraphic Test❑ 2.Operator Name: 5.Date Abandoned:,t/i/fi 12.Permit to Drill Number: SAVANT ALASKA LLC 4a201JY r 212019 3/Z-/73 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 112212,Anchorage, AK 99511-2212 4/3/2012 , 50-029-23465-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1,349'FSL&4,363'FEL,Sec 36,T1ON,R19E 4/21/2012 - Red Wolf#2 Top of Productive Horizon: None 8.KB(ft above MSL): 35.5 15.Field/Pool(s): GL(ft above MSL): 4.5 Total Depth: 1,327'FSL&4,451'FEL,Sec 36,T1ON,R19E 9.Plug Back Depth(MD+TVD): Badami/Kekiktuk {Straight Hole} N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 349.352.14 y- 5,914,755.67 Zone- 3 11,859'MD 111,857'TVD ADL 367005 TPI: None 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 349,263.53 y- 5,914.735.03 Zone- 3 N/A N/A 18.Directional Survey: Yes lJ No U 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 MC 25.050) N/A (ft MSL) 1,950'MD/TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Latel'al Top Window MD/TVD: ROP,DGR,EWR,ADR,ALD,CTN, PWD, Sonic&FEL N/A I 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT. TOP BOTTOM TOP BOTTOM PULLED 1 20" 91.1# H-40 0 73' 0 73 24" Cemented to Surface 9-5/8" 47# L-80 30' 3847' 30' , 3847' 12-1/4"- 472BbI Lead 50Bbl Tail 24.Open to production or injection? Yes U No 2 If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) ...::,,,.::,.416. ACID,FRACTURE,CEMENT SQUEEZE,ETC. MAY 1. 5 2012 / - 9 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 11,859'-11,348' Balanced Plug,40 Bbls Class"G"at 15.8 ppg ((��C '741.�� 3,847'Retainer Squeeze 17 Bbls"G",15 Bbls Injected,2 Bbls Atop ✓ AOG�.l 310'to Surface 13 Bbls 15.7 ppg Arctic Set-1 Slurry '.,, See EOW Report for Details 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: - Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(torr): Press. 24-Hour Rate -.0' 28. CORE DATA Conventional Core(s)Acquired? Yestj No ❑ Sidewall Cores Acquired? Yes U No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 1 RBDMS MAY - 7 2013 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE t ,l 5,13 Submit original only 9 (/ c • 29. GEOLOGIC (List MARKERSall formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑Yes ado If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top 31' 31' needed,and submit detailed test Information per 20 AAC 25.071. Permafrost-Base 1950' 1950' Base Unconsolidated Gravel 3315' 3315' Seismic Marker 1 5302' 5302' Correlation Marker 1 6182 6182 Seismic Marker 2 6693' 6693' Ugnu 6825' 6825' West Sak 7167' 7167' Seismic Marker 3 7782' 7781' M 85 8115' 8114' Killian Sand Not Present Not Present Hue Shale 11245' 11243' Top HRZ 11405' 11403' Base HRZ 11600' 11598' LCU/Kekiktuk Zone 2 11655' 11653' Kekiktuk Zone 1 Not Reached Not Reached Formation at TD: Kekiktuk 11859 11857 31. List of Attachments: Listed LWD logs,Formation Evaluation Logs,P&A Photos,Summary Morning Reports,Digital Data Disk SLB Cement End of Well Report,Baroid Drilling Fluid Recap,HES Bit Recap,Definitive Survey&Other 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Opstad (Alt.907-244-5210) Printed Name: Erik O•stad, , Title: Drilling & Wells Manager I/, Signature: j / Phone: 907-868-1258 x-101 Date: 5/15/2012 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b:TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump.Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 1212009 ?fZ- 0f9 ei�lao4 sc: PhysBc�V location: 6 G --A N3.7 Transrn tta/1 May 22, 2012 To: Christine Mahnken Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Re: Savant Alaska LLC- Red Wolf#2 Exploration Well Data Package Submitted: 1. As Built Well Location 2. AOGCC Form 10-407—Well Completion Report w/ Photos 3. Definitive Survey Report w/ Digital Data 4. BAT Bi-Modal Acoustic(TVD/MD paper log & digital data) 5. Dual GR &Azimuthal Deep Resistivity(TVD/MD paper log &digital data) 6. Azimuthal Lithodensity(TVD/MD paper log & digital data) 7. Compensated Thermal Neutron (TVD/MD paper log & digital data) 8. Electromagnetic Wave Resistivity(TVD/MD paper log &digital data) 9. Rate of Penetration (TVD/MD paper log &digital data) 10. Drilling Morning Reports—Rig Acceptance to Rig Release 11. Schlumberger—EOW Report I Cementing Services 12. Halliburton—EOW Report I Drilling Fluid Recap 13. HES & NOV EOW Reports I Bit Run Recaps Received by: 1 AOGCC Representative Submitted by: Erik Opstad, Manager Savant Alaska LLC _ y Page 1 of 1 Drill Floor to Sea Level 35' Referenced to Nabors Rig 7ES Drill Floor to Tubing Hanger 24.0' Referenced to Nabors Rig 7ES OD ID Weight Length MD TVD Ground Level to Sea Level 4.5' inch inch Lbs/ft ft DF(ft) DF(ft) , , , �� ,Tundra surface Gra,,,Au i Fl '`r' 10'Diameter Cellar Culvert-cutoff 3'below tundra level Abandonment Marker Abandonment Marker 20"Cap Plate-Company,PTD#, Well Name and API#are bead welded on cap. Cap is approximately 4-feet below tundra surface level. 20"Conductor Shoe 20.000 19.124 91.1 73 73 Cement Retainer w/Artic Set Cement Atop 310 310 ♦— TAM 9-5/8"Port Collar 11.250 2.250 40 3.32 500 500 i. day 1 rti Perma Frost 1950 1950 ti 71 r• 2 bbls"G" ti ,h q{, r. yr" Retainer �.. 9-5/8"Surface Casing 47#L-80 BTC @ 0732 bpf 9.625 8.681 47 3847 3847 y.ti.y.{.ti r•r•r.r•r' :r:gi r 17 bbls"G" tirtireSe y.y.ti.y.ti. {:{r{:{r{rti .rtirtirtirtir•. •r•r•r•r•r ti.ti.y.y.ti.y r•r•r•r•r•� A (2 •r•r•r•r•r•, ,"))-1-1--- riff%r, SGA Killian Sand(Not Present) Top Open Hole •r.r,r•r•r• , Top Hue Shale 11245 11243 Plug @ 11234' r• • •r•r•r• r•r•r•r•r•r• .514 f44 Top HRZ 11405 11403 'r ri.wrr�'i.w 1.13.1/1=.:;. 40 bbls"G" :;.r.{:{::ii Base HRZ •r•r•r•r•r. 11600 11598 r•i}ter i r• r•r•r•r•r•r•r� KK•ti•ti••.•ti/ LCU I To Kekiktuk Zone 2 11655 11653 'r•r•r•r•r•r4 .r•r•r•r•r•�, Base Open Hole 'r'r'r'r'r'%' r•r•r•r•r•r� Plug @ y�w+.�... Open HoIeTD 11859 11857 r.r•r•r•r•r� lu 11859 y;�..;ti.yw.. No. Rev.by Comments/Date Red Wort. #2 1 Erik Opstad P&A Schematic Badami Unit API No. 50-029-234650-00-00 PTD#212-019 April-2012 SA ANT ALASKA —.0 Drill Floor to Sea Level 35' Referenced to Nabors Rig 7ES Drill Floor to Tubing Hanger 24.0' Referenced to Nabors Rig 7ES OD ID Weight Length MD TVD Ground Level to Sea Level 4.5' inch inch Lbs/ft ft DF(ft) DF(ft) Tundra surface 10'Diameter Cellar Culvert-cutoff 3'below tundra level II` Abandonment Marker ; rti{ti74:%+, r?::: Abandonment Marker 20"Cap Plate-Company,PTD#, _ify?L5151f+f1f+?�f..__ r•r•rtirtirtir-r•r.r•r. Well Name and API#are bead welded on cap. Cap is s L.L. L.L.L.•-. ;i;di?i?4r.{t{{{{{?;r.:: approximately 4-feet below tundra surface level. i•r.r•r•r•r•r•r•r•r•r d:r:•L.L•L.L•L•L•L.h r•rM•r•r•rY•r; L•L•L•L•L•L•L•L... =?�J•r-r.r•r•r•r•r•r 20"Conductor Shoe 20.000 19.124 91.1 73 73 'r:s r is}::3:}:?. Cement Retainer w/Artic Set Cement Atop 310 310 f— TAM 9-518"Port Collar 11.250 2.250 40 3.32 500 500 Perma Frost 1950 1950 2 bbls"G" :i Retainer r'' 9-5/8"Surface Casing 47#L-80 BTC @.0732 bpf 9.625 8.681 47 3847 3847 :rsf:r.f' L.L.ti•L.L tirtirtir•r.r.r.tif 17 bbls"G" rtir i4tifr •rtirtirtirtir•, {{{{{r{r{:L 3.4.4:rtiry 'f{rtirti:tirti 'rtirtirtirtir•. Killian Sand(Not Present) Top Open Hole r•r.r•r•r. Top Hue Shale 11245 11243 •5�•LK•L/L• Plug @ 11234' ::4:{:;,:{r• �•r•r•r•r•r• , L•L•L•L•L•L .e.e.;;{ Top HRZ 11405 11403 •r•r•r•r•r• 40 bbls"G' •.Xr5rtirti4ti Base HRZ L:{�ti::{r, 11600 11598 f•r•r•r•r•r• ...~.r•r.rr. .•r•r•r•r•r%. LCU/Top Kekiktuk Zone 2 11655 11653 �•r•r•r•r•r•�, •r•r•r•r•r•�, Base Open Hole 'r'r'r' 'r';' 41-1.111,...11:• •r • •+ O en HoIeTD 11859 11857 Plug @ 11859' � p No. Rev.by Comments/Date Red Wort.#2 1 ,Erik Opstad P&A Schematic Badami Unit API No. 50-029-234650-00-00 PTD#212-019 April-201 SA ANT ALASKA NOTES: 1. COORDINATE DATUM IS NAD27, ALASKA STATE PLANE ZONE 3. BfAUFORTARESEA Ia imPROJECT ' 2. ELEVATION DATUM IS M.S.L. �, HARRISON BFECHEY 3. HORIZONTAL AND VERTICAL CONTROL IS BASED ON THE BADAMI BAY q �pOINT -- BARTER -A PIPELINE R.O.W. MONUMENTATION. PRIMARY MONUMENT #54. ` .._,{Pruahoe py ISLAND ISLAND 1 NPRA r- `�1.`M j 4. THE ENTIRE COASTLINE, SAGAVANIRKTOK, PUTILIGAYUK, KUPARUK N ft Kaki? RIVERS AND ALL MAN MADE FEATURES FROM TOWNSHIP 10N TO •1 fl 1THE NORTH AND FROM RANGE 20 TO THE WEST WERE DRAWN a:t a' FROM THE UNIT OPERATOR'S 1:6000 MAPS, 1973 PHOTOGRAPHY 't I I 1 1 1 WITH PERIODIC UPDATES THROUGH 1993. ccl {DEMARCATION, UMIAT--- SAGAVANIRKTOK MOUNT POINT 5. ALL SECTIONS LINE ARE UNSURVEYED AND UNMARKED LOCATIONS MICHELSON-- QQ PLOTTED FROM B.L.M. DATA. . 1" C Z 6. DATE OF SURVEY: MARCH 31, 2012. A r t 7. FIELD BOOK: M112-01 PGS. 62-64. / - F ANWR r< — J '- LEGEND VICINITY MAP N.T.S. 4- AS-BUILT WELL LOCATION 1C� LION POINT 2 6V 10 12 I 7 5 9 N. /' \\ J$ MII(KELSEN �� 111 I 'c� 15 1a ,11 13ESS lc2 I �� 1 DDVAIDAK WEST ISLAND ISLAND ,, // 'S .:''''' ° S MIKKELSEN /. ++6 C", °°° 9 BAY 4 / ° IIIVVV /� Q e y RELIANCE POINT * °T✓ e ' -`I 21 23 2 r- ..°. .. °...c...°.. i, 13 ae 21 _ °.� WEST I i��� MIKKELSEN I 0 . °. e , BAY 3 c• m i_ Richard Allison N °. - 29 28 20, _;‘, 25 i-2 ix" 3� ?9 �' °° 1 f!•08 �� z8 ,° iR:D WOLF #2 , � ;P61`fS5I0sW ‘'°%%` IIIi%%% % , MlKKEL32 -, 33 /i SEN BAY ;�' 31 SURVEYORS CERTIFICATE • �'2 1 HEREBY CERTIFY THAT I AM -- _ F " iL. .I PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN ' • THE STATE OF ALASKA AND THAT 5 a 3 2 1 THIS PLAT REPRESENTS A SURVEY I ( 6 4 MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL — DIMENSIONS AND OTHER DETAILS ARE C ' ' BADAMI CORRECT AS OF MARCH 31, 2012. ,•-• `-tom 8 9 ( h 7 . / JJ } I@ %:11 (t .12" 7 . SO \\, 7 — . � • \ �.� p , GRAPHIC SCALE '"\_. C:::/). 0 4,000 8,000 16,000 41 1 1 17 ,,,...._..r) 15 . (5 r T �'' MIKKEL BA/ STAT 1 7 (� inch FEET ) 1 =8,000ft. LOCATED WITHIN PROTRACTED SEC. 36, T. 10 N., R. 19 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC TOP ICE SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DO) ELEV. OFFSETS Y=5,914,755.67 N N/A 70'10'27.233" 70.1742314' 1,349' FSL RW #2 4 X= 349,352.14 E N/A _14712'45.793" 147.2127203' 6. 4,363' FEL DRAWN SAVANT F Robert _. KWH — hol '4' CHECKED JZW ,til ._�.__.—.__...-_.._._ DRAWING z ALASKA °RF 812 RW2 02 S1-EE' JOB SAVANT ALASKA -- :asset. SCALE RED WOLF #2 1 OF 1 SO 4/01/12 ISSUED FOR DWORMAIION kw+,zM' AS—BUILT WELL LOCATION S'N` .441"O®we 1" - 8000" NC 001E REVISION 0Y HK �Wa[ 9MU -,17,:- 2.12,-019' DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:02 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:2 DSS: 1 EST DAYS LEFT 66 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LL(CONTRACTOR:NABORS ALASKA DRILL DEPTH: 24 HRS ROP: CUM ROT.HRS: CO MAN:DROLLINGER TOOLPUSHER:PERRY/TIEDEMANN PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE GPM: WOB: NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: PRES: 1 _CONTINENTAL 5.50 10.00 TORO: SPR: / 2 CONTINENTAL _ 5.50 10.00 AVDP: AVDC: ' - --- - MUD WT: 8.8 VISC: 66 PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT: STR WT: BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: SLACK-OFF WT: 1 0 0.00 JAR HOURS: SHOCK-SUB HRS BHA HRS: o 00 DP ON DP 4 14.00 S-135 376, LOCATION DC ON DC 4 3/4 NC35 SPIRAL 9; LOCATION LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS CASING BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION CONN GAS: (100 SURV GAS 000 TRIP GAS: 0 00 BOP TEST FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 00:00 02:00 2.00 _ 1.D RIG UP (GBR REPS CONTINUE INSTALL LANDING _—. RING&4"OUTLETS ON CONDUCTOR)HANG BRIDAL LINES STANDS DP _ IN DERRICK;UNTIE SERVICE LOOP&BLOWER HOSE;HANG SINGLES _ TONGS;R/U FLOOR KELLY DOWN 02:00 04:30 2.50 1.D RIG UP-CONT.BERMING SUB BASE&PITS COMPLEX; READY PITS T/TAKE ON FLUID;INSTALL CUTTINGS BOX TOTAL LID;OFFLOAD TRUCKS; REMARKS 04'30 12:00 7.50 1.0 RIG UP-CONT.BERMING;SPOT HALLIBURTON MODULES; REPLACE LEAKING TOPDRIVE HOSE;MAINTENANCE DRAG SEC;PTSM=1;PJSM=5 CHAIN&REPAIR STEAM HEATER LEAKS;PROCESS 5"4 PJSM BEFORE TASK;C-O-M;FIRE DRILL CRT=77 SEC; 1/2 IF DP;INSTALL HALLIBURTON DRAWWORKS ENCODER; TEST PVT,FLO-SHO;PTSM;PJSM=11; CONT.ALLOWING STARTING HEAD TO COOL UNTIL 1:30PM; 12:00 13:30 1.50 _ 1.0 TRANSPORT ALLOWING STARTING HEAD TO COOL UNTIL UEL USED=2267 GAL. 1:30PM;SET DIVERTER IN CELLAR;INSTALL CHUTE FOR _ CUTTINGS BOX;PREP 5"DP IN PIPE SHED;TAKE ON FRESH WATER TO PITS @ 1300 HRS;ACCEPT RIG 1300 HRS ED=105 BBL 13:30 00:00 10.50 14.0 NIPPLE UP/DOWN DIVERTER SYST;NU STARTING HEAD, DIVERTER&RISER;INSTALL DIVERTER LINES SED=O BBL -._ -- ---- ANTICIPATED 24 HOUR OPERATION . COM/FOM: ACCUM PRESS.: SWIVEL HRS: 0.00 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1 : #2: #3 #4: #5: MUD COST DAILY: FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN BUZBY NO 12 MECH.IELEC DAVID GUESS NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3671 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00:00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:03-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333444204100_NADDaily_sgl. Page 1 of 1 0 ' DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:03 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:3 DSS: 2 EST DAYS LEFT 65 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 308 PROPOSED DEPTH: 12100 OPERATOR: SAVANT ALASKA LLI CONTRACTOR:NABORS ALASKA DRILL DEPTH: 418 24 HRS ROP: CUM ROT.HRS: 7.00 CO MAN:DROLLINGER TOOLPUSHER:PERRY/TIEDEMANN PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 1 12.25 QHC1GRC 16.0/16.0/14.0/14.0/0.0/0.0/0.0/0.0 308.00 110.00 418.00 11748199 GPM: 332.19 WOB: 5.01) NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: 45.00 PRES: 1 CONTINENTAL 5.50 65.00 19077 95.00 10.00 TORQ: SPR: / 2 CONTINENTAL 5.50 55.00 16142 95.00 10.00 AVDP: 5.00 AVDC:8.00 MUD WT: 9.0 VISC: 300 PH: WL: PV/YP: / SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.00 STR WT: 45,000 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: SLACK-OFF WT: 1 BIT 12.25 1.02 JAR HOURS: 0.00 SHOCK-SUB HRS 0.00 BHA HRS: 0.00 DP 4 14.00 S-135 376; 1 MOTOR,MUD 8 30.52 DP ON LOCATION 1 FLOAT SUB 8 2.16 1.X/0 7.28. 2.39 DC ON DC 4 3/4 NC35 SPIRAL 9; LOCATION LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS CASING BG GAS: 0.0o SURVEY DEPTH DEG. DIRECTION CONN GAS: 0.00 I SURV GAS 0.00 _ TRIP GAS: 0.00 BOP TEST FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 36.09 02:00 2.00 14.0 NIPPLE UP/DOWN DIVERTER SYST-CONT.INSTALL DIVERTER LINES 4STANDS DP 368.95 02:00 05:30 3.50 6.E PICK UP DRILL PIPE-P/U&RACK BACK 44 STDS 5" SINGLES 19.5#4 1/2 IF DP;M/U TO=27K FT/LBS;2 7/8"DRIFT KELLY DOWN 05:30 07:00 1.50 6.E PIC-KU -D PRI♦..L PIPE P/U&RACK BACK 15 JTS. 5" . #4 1/2IF HH/DP TOTAL 07:00 12:00 5.00 .0 TEST DIVERTER-INSTALL GROUND STRAP;SECURE REMARKS DIVE 1E&POST DIVERTER WARNING SIGNS;TIE ...-.7 P FLOW PADDLE;TEST PVT&GAS ALARMS FUNCTION PJSM BEFORE TASK;INSP.DRK;C-O-M;FUNCTION!BO TEST&TIME KNIFE VALVE AOGCC LOU GRIMALDI WITNESS P5€TM'S;D-3 DRILL CRT=100 SEC;TEST PVT,FLO-SHO; TEST; PTSM;PJSM=11; 12:00 13:30 1.50 15.0 TEST DIVERTER;ADD SUPPORTS AND SECURE DIVERTER LINE AS PER AOGCC REP LOU GRIMALDI;INSTALL GRATING IN CELLAR; USED=2637 GAL. 13.30 16:00 2.50 6.0 PICK UP BHA;PU BIT;MOTOR,FLT SUB W/PORTED FLOAT,X/O,STD HWDP SED=155 BBL 16.00 17:00 1.00 5.D CIRCULATE AND CONDITION;PRE-SPUD MTG,FILL HOLE; SLK DN&TAG @ 110' ` ED=52 BBL 100 00:00 7.00 2.A ROTARY DRILLING;DRLG F/110'TO 405';5K WOB; 1/ ANTICIPATED 24 HOUR OPERATION 120 SPM;350 GPM; 470 PSI ON;435 PSI OFF;1.3K TQ ON;0.6K TQ OFF;40K UWT;40K DWT;45K RWT; 45RPM;ART=5.98 HRS;AST=0 HRS;ADT=5.98 HRS; BIT=5.98 HRS COM/FOM: ACCUM PRESS.: SWIVEL HRS: 8.00 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN BUZBY NO 13 MECH./ELEC DAVID GUESS NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3672 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00:00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:04-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333531279406_NADDaily_sgl. Page 1 of 1 8 1 DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:04 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:4 DSS: 1 EST DAYS LEFT 64 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 854 PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LL(CONTRACTOR:NABORS ALASKA DRILL DEPTH: 1,272 24 HRS ROP: 70.35 CUM ROT.HRS: 30.50 CO MAN:DROLLINGER TOOLPUSHER:TIEDEMANN/YEAROUT PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 1RR 1225 QHC1GRC 16.0/16.0/14.0/14.0/0.0/0.0/0.0/0.0 854.00 12.14 70.35 418.00 1.272.00 11748199 1RR 12.25 QHC1GRC 16.0/16.0/14.0/14.0/0.0/0.0/0.0/0.0 854.00 12.14 70.35 418.00 1.272.00 11748199 GPM: 422.62 wog: 15_00 NO. PUMP MFG LINER SPM PRES GPM RPR ' STRK RPM: 110.00 PRES:1.013.00 1 CONTINENTAL 5.50 79.00 231 85 95.00 10.00 TORO:1.40 SPR: / • 2 CONTINENTAL 5.50 , 65.00 '190.77 95.00 10.00 AVDP: AVDC:8.00 MUD WT: 9.3 VISC: 300 PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.00 STR WT: 80 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: SLACK-OFF WT: JAR HOURS: 1212_72 SHOCK-SUB HRS 0.0o BHA HRS: o.00 1 BIT 12.25 1.02 DP 4 14.00 S-135 376; 1 MOTOR,MUD 8 30.52 DP ON LOCATION 1 STABILIZER 12.125 4.37 1 SUB,X-OVER 8 1.55 DC ON DC 4 3/4 NC35 SPIRAL 9: 1 DM COLLAR 8 9.06 LOCATION 1 SUB,X-OVER 8.1 1.88 1 DGR 6.75 4.39 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 EWR-P4 8 12.04 CASING 1 HCIM 8 4.89 BG GAS: o.00 SURVEY DEPTH DEG. DIRECTION 1 HOC 8.1 9.45 CONN GAS: o.00 1 FLOAT SUB 8.06 2.16 SURV GAS o.00 1 STABILIZER 8.1 5.41 TRIP GAS: 0.00 BOP TEST 1 FLEX COLLAR 8.13 30.36 1 FLEX COLLAR 8.1 30.53 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 734.41 00:00 02:00 2.00 2.A ROTARY DRILLING-CONT.DRLG F/405'T/497';5K WOB;120 SPM;350 GPM; 470 PSI ON;435 PSI OFF; STANDS DP 0 1.3K TQ ON;0.6K TQ OFF;45K UWT;45K DWT;45K 0 SINGLES 0 RWT;45RPM' 0 KELLY DOWN 0 02:00 03:00 1.00 6.6 TRIP OUT OF HOLE-(a497'MD CIRCULATE 850STKS (BUS)(a 355GPM 456PSI;MONITOR WELL;POOH F/497' TOTAL .T/SURFACE;UWT=45K;DWT=45K; REMARKS 03:00 05:00 2.00 6.0 PICK UP BHA-PJSM;CLEAN&CLEAR RIGFLOOR;P/U 12 1/4"SURFACE BHA AS PER HALLIBURTON REP;TQ H90 PJSM BEFORE TASK;INSP.DRK;C-O-M;MAN DOWN DRIL T/53K FT/LBS;TQ REG T/56K FT/LBS;USE RIG TONGS L CRT=65 SEC;TEST PVT,FLO-SHO;PTSM;PJSM=8 ON SMART TOOL CONNECTIONS; 1✓ 05:00 06:00 1.00 6.G _PICK UP 3RD PARTY TOOLS-TEST MWD TOOLS AS PER HALLIBURTON REP 06:00 08:00 2.00 6.0 PICK UP BHA-CONT.M/U BHA;P/U 8"NON MAG FLEX UEL USED=2927GAL. COLLARS(3JTS.)M/U T/32K FT/LBS;P/U JARS&5" HWDP;SHALLOW HOLE PULSE TEST AS PER MWD SED=175 BBL 08:00 12:00 ' 4.00 ' 2.A ROTARY DRILLING-DRLG F/497'T/642';10K WOB; 173 SPM;420 GPM; 1030PSI ON;975 PSI OFF;1.9K SED=576 BBL TQ ON;0.6K TQ OFF;65K UWW T;65K DT;57K RWT; ANTICIPATED 24 HOUR OPERATION 90RPM;35BBL/HR H2O;ART=3.9 HRS;AST=0 HRS; ADT=3.9 HRS;BIT=11.9 HRS;JARS=2.3 HRS 12:00 00:00 '.12.00 2.A ROTARY DRILLING F/642'TO 1272'; 15K WOB;144 SPM;421 GPM;1043 PSI ON;969 PSI OFF;1.4K TO COM/FOM: ACCUM PRESS.: SWIVEL HRS: 31.50 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN BUZBY NO 13 MECH.IELEC DAVID GUESS NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3673 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00:00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 Wy 2012 TIME: 00:00 Report Date:05-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333627352296_NADDaily_sgl. Page 1 of 2 RIG NO.:7ES DATE:04 Apr 2012 WELL• A1070 007ES-RED WOL, Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS ON;1K TO OFF;76K UWT;76K DWT;80K RWT;110 RPM. ART=8.24 HRS;AST=0 HRS;ADT=8.24HRS BIT= 20.99 HRS; JARS=12.72 HRS DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 FLEX COLLAR 8.11 29.97 1 SUB,X-OVER 7.28 2.39 5 5"HWDP 5 153.89 1 JARS,HYDRAULIC 6.22 31.53 12 5"HWDP 5 369.00 Report Date:05-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333627352296_NADDaily_sgl. Page 2 of 2 r t DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:05 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:5 DSS: 2 EST DAYS LEFT 63 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 413 PROPOSED DEPTH: 12.100 OPERATOR: SAVANT ALASKA LLI CONTRACTOR:NABORS ALASKA DRILL DEPTH: 1 815 24 HRS ROP: 48.02 CUM ROT.HRS: 49.50 CO MAN:DROLLINGER TOOLPUSHER:PERRY/TIEDEMANN PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 2 12.25 EQH12DRC 16.0/16.0/16.0/14.0/0.0/0.0/0.0/0.0 413.00 6.10 67.70 1.402.00 1.815.00 11966739 2 12.25 EQH12DRC 16.0/16.0/16.0/14.0/0.0/0.0/0.0/0.0 413.00 6.10 67.70 1,402.00 1,815.00 11966739 GPM: 425.56 WOB: 15.00 NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: 130.00 PRES:1.050.00 1 CONTINENTAL 5.50 80.00 23478 95.00 10.00 TORO:Z.1.4 SPR: / 2 CONTINENTAL 5.50 65.00 180.77 95.00 10.00 AVDP: 0,QQ AVDC:8.00 MUD WT: 9.3 VISC: 300 PH: WL: PV/YP: / SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:000 STR WT: 92 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 40000 SLACK-OFF WT: 40.000 1 BIT 12.25 1.02 JAR HOURS: 21.86 SHOCK-SUB HRS 0 00 BHA HRS: 0.00 1 MOTOR,MUD 8 30.52 DP ON DP 4 14.00 S-135 376; LOCATION 1 STABILIZER 12.125 4.37 1 SUB,X-OVER 8 1.55 DC ON DC 4 3/4 NC35 SPIRAL 9; 1 DM COLLAR 8 9.06 LOCATION 1 SUB,X-OVER 8.1 1.88 1 DGR 6.75 4._39 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 EWR-P4 8 12.04 CASING 1 HCIM 8 4.89 BG GAS: 000 SURVEY DEPTH DEG. DIRECTION 1 HOC 8.1 9.45 CONN GAS: 0.00 1 FLOAT SUB 8.06 2.16 SURV GAS 9 4Q 1 STABILIZER 8.1 5.41 TRIP GAS: 000 BOP TEST 1 FLEX COLLAR 8.13 30.36 1 FLEX COLLAR 8.1 30.53 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 734.41 00:00 03:00 3.00 2.A ROTARY DRILLING-CONT.DRILLING F/1272'T/ 1402'; 15K WOB;144 SPM:421 GPM;1133 PSI ON; 11 STANDS DP 0 1040.1 1010 PSI OFF;2K TO ON:.75K TO OFF;77K UWT;76K 0 SINGLES 0 0 DWT;82K RWT;110 RPM;ADT=2HRS;ART=2HRS;AST=0; BIT HRS=0;JAR HRS=14.72 0 KELLY DOWN 0 40.49 03:00 03:30 0.50 5.D CIRCULATE AND CONDITION-CIRCULATE BOTTOMS UP TOTAL 1815 WHILE RECIPROCATING PIPE:2500STKS;430GPM(a) REMARKS 920PSI;65RPM;.75K TO;UWT=80K;DWT=80K;RWT=82K - 03:30 04:00 0 50 6.B TRIP OUT OF HOLE-POOH F/140TMD T/741'MD; PJSM BEFORE TASK;INSP.DRK;C-O-M;FUNCTION ISO MONITOR WELL;(STATIC);UWT=70K;DWT=70K;NO TIGHT PS€'"'S;SPILL DRILL CRT=85 SEC;TEST PVT,FLOSHO; HOLE OBSERVED; / PTSM;PJSM=8; 04:00 06:00 2.00 6.0 LAY DOWN BHA-CONT.POOH F/741'T/SURFACE; V RACK BACK 5"HWDP&FLEX COLLARS;CHECK FLOAT; INSTALL NEW 12.250"BIT; USED=3088 GAL. 06:00 07:00 1.00 6.0 PICKUP BHA-PLUG INTO SMART TOOLS&DOWNLOAD AS PER MWD SED=175 BBL 07:00 07:30 0.50 7.B SERVICE TOP DRIVE-HOLD PJSM;GREASE WASHPIPE AND SERVICE TOP DRIVE SED=774 BBL 07:30 12:00 4.50 ' 1.R RIG ON STANDBY WAITING ON TRUCKS-WAITING ON ANTICIPATED 24 HOUR OPERATION SUPERSUCKER TRUCKS F/EMPTYING CUTTINGS BOX 12:00 14:00 2.00 6.0 PICK UP BHA;UPLOAD MWD;RIH BHA TO 734';65K UWT;65K DWT;(STACK WT @ 290';PU THEN SLACK I THROUGH W/NO DRAG) COM/FOM: ACCUM PRESS.: SWIVEL HRS: 51.00 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M 5/DAILY:0.00 ENGINE KW-#1 : #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: 1 DRILLERS: OBM: CREW JUSTIN BUZBY NO 12 MECH./ELEC DAVID GUESS NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3674 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00_00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:06-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333704685671_NADDaily_sgl. Page 1 of 2 RIG NO.:7ES DATE:05 Apr 2012 WELL: A1070 007ES-RED WOL Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS 14:00 15:00 1.00 6 A- TRIP IN HOLE;RIH 734'10 749';10K DRAG @ 710'; STACK WT @ 749';PU TO 730`,WASH/REAM 730'TO 829';40 RPM;0.8 K TQ;410 GPM;777 PSI;WORK 730'TO 829'W/NO OVERPULL OR DRAG;SHALLOW HOLE TEST MWD @ 793';BLOW DN TOP DRIVE 15:00 16:00 1.00 6.A TRIP IN HOLE F/829'TO 1301';PRECAUTIONARY REAM F/1301'TO 1402';80K UWT;80K DWT;80K RWT; 403 GPM;833 PSI;40 RPM;0.8K TQ; (2'FILL ON BOTTOM) 16:00 00:00 8.00 2.A ROTARY DRILLING F/1402'TO 1815';15K WOB;145 SPM;425 GPM;1050 PSI ON;1004 PSI OFF;2.1K TO ON;1K TO OFF;90K UWT;90K DWT;92K RWT;130 RPM; ART=6.10 HRS;AST=0 HRS;ADT=6.10 HRS BIT= 6.10 HRS; JARS=21.86 HRS DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 FLEX COLLAR 8.11 29.97 1 SUB,X-OVER 7.28 2.39 5 5"HWDP 5 153.89 1 JARS,HYDRAULIC 6.22 31.53 12 5"HWDP 5 369.00 Report Date:06-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333704685671_NADDaily_sgl. Page 2 of 2 1 DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:06 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:6 DSS: 3 EST DAYS LEFT 62 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 770 PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LL(CONTRACTOR:NABORS ALASKA DRILL DEPTH: 2 585 24 HRS ROP: 81.14 CUM ROT.HRS: 74.00 CO MAN:DROLLINGER TOOLPUSHER:PERRY/TIEDEMANN PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 2 1225 EQH12DRC 16.0/16.0/16.0/14.0/0.0/0.0/0.0/0.0 1.183.00 15.59 75.88 1.402.00 2,585.00 11966739 2RR 12.25 EQH12DRC 16.0/16.0/16.0/14.0/0.0/0.0/0.0/0.0 2.585.00 2,585.00 11966739 GPM: WOB: NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: PRES: 1 CONTINENTAL 5.50 _ 10.00 TORO:2.10 SPR: / 2 CONTINENTAL 5.50 10.00 AVDP: AVDC: ' MUD WT: 9.2 VISC: 300 PH: WL: PV I YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:000 STR WT: 92 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: SLACK-OFF WT: JAR HOURS: 21.66 SHOCK-SUB HRS 0.00 BHA HRS: o.00 1 BIT 12.25 1.02 DP 4 14.00 S-135 376; 1 MOTOR,MUD 8 30.52 DP ON LOCATION 1 STABILIZER 12.125 4.37 1 SUB,X-OVER 8 1.55 DC ON DC 4 3/4 NC35 SPIRAL 9; 1 DM COLLAR 8 9.20 LOCATION 1 SUB,X-OVER 8.1 1.78 1 DGR 6.75 5.07 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 EWR-P4 8 12.18 CASING 1 HCIM 8 4.85 BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION 1 HOC 8.1 9.77 CONN GAS: 0.00 1 FLOAT SUB 8.06 2.16 SURV GAS o.00 1 STABILIZER 8.1 5.41 TRIP GAS: 0.00 BOP TEST 1 FLEX COLLAR 8.13 30.36 1 FLEX COLLAR 8.1 30.53 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 735.55 00:00 11:00 11.00 2.A ROTARY DRILLING F/1815'TO 2582';10-15K WOB; 152 SPM;445 GPM;1220 PSI ON;1050 PSI OFF;2.1K STANDS DP 0 TQ ON;1K TO OFF;100K UWT;100K DWT;97K RWT;130 0 SINGLES 0 0 RPM;ART=8.7 HRS;AST=0 HRS;ADT=8.7HRS BIT= 15.5 HRS; JARS=30.56 HRS ()KELLY DOWN 0 11:00 11:30 0.50 6.B TRIP OUT OF HOLE-POOH F/2582'T/2428'AS PER TOTAL HALLIBURTON DD TO CONFIRM ERRONEOUS SURVEY;@ LP REMARKS SURVEY DEPTH OF 2526';UWT=100K;DWT=100K 11.30 12:00 0.50 6.A TRIP IN HOLE-RIH F/2428'T/2582'UWT=100K; ,✓ T=80 SEC;TEST PVT,FLO-SHO;PTSM=1;PJSM=2; DWT=100K;TO CONT.DRILLING PJSM BEFORE TASK;INSP.DRK;C-O-M;SPILL DRILL 12:00 12:30 0.50 2.A ROTARY DRILLING F/2582'TO 2585';15K WOB;152 CRT=77 SEC;TEST PVT,FLO-SHO;PTSM;PJSM=9; SPM;445 GPM; 1220 PSI ON;1050 PSI OFF;5K TO ON;1 K TO OFF;100K UWT;100K DWT;97K RWT;130 UEL USED=2821 GAL. RPM;ART=0.03 HRS;AST=0 HRS;ADT=0.03 HRS; BIT=15.59 HRS;JARS=39.84 HRS 12:30 13:30 1.00 6.B TRIP OUT OF HOLE;MWD FAILURE;POOH F/2585'TO SED=200 BBL 1720';PULL 25K OVER @ 1720' 13:30 14:30 1.00 3.B BACK REAMING;WASH DN TO 1770';BK REAM 1770'TO SED=356 BBL 1675';144 SPM;423 GPM;1053 PSI;2K TQ;55 RPM; ANTICIPATED 24 HOUR OPERATION 85K UWT;85K DWT;85K RWT;SLK DN F/1675'TO ----__- -_-- 1770'NO DRAG 14:30 15:30 1.00 63 TRIP OUT OF HOLE POOH F/1770'TO BHA 734';(20K OVERPULLS @ 1663';1648;';1599';1576';1497': COM I FOM: ACCUM PRESS.: SWIVEL HRS: 76.50 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN BUZBY NO 13 MECH./ELEC DAVID GUESS NO 9 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3675 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00:00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 My 2012 TIME: 00:00 Report Date:07-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333790929562_NADDaily_sgl. Page 1 of 2 t r RIG NO.:7ES DATE:06 Apr 2012 WELL: A1070 007ES-RED WOL, Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS WORK THROUGH ALL O.K.) 15:30 19:00 3.50 6.B TRIP OUT OF HOLE F/734';STAND BACK HWDP&FLEX DCS;DOWNLINK MWD;LD HOC,HCIM COLLAR,EWR-P4 COLLAR,DGR COLLAR,X/O,DM COLLAR 19:00 21:00 2.00 6.0 PICK UP BHA;PU MWD;DOWNLINK MWD 21:00 22:30 1.50 6.0 PICKUP BHA F/87';FLEX DCS,HWDP TO 735' 22:30 23:30 1.00 6.A TRIP IN HOLE 5'DP STDS F/735'TO 2235';(20K DRAG @ 1962';WORK THROUGH O.K.) 23:30 00:00 0.50 6.A TRIP IN HOLE;TAKE MWD CHECK SURVEY @ 2148';402 GPM;1294 PSI;100K UWT;95K DWT DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 FLEX COLLAR 8.11 29.97 1 SUB,X-OVER 7.28 2.39 5 5"HWDP 5 153.89 1 JARS,HYDRAULIC 6.22 31.53 12 5"HWDP 5 369.00 Report Date:07-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333790929562_NADDaily_sgl. Page 2 of 2 1 102-NABORS ALASKA ,ILY MORNING REPORT , ,TY: NORTH SLOPE BOROUGH ST.: ALASKA RIG NO.:7ES RPT DATE:07 Apr 2012 WRK DATE:06 Apr 2012 JOB#:A1070 WELL NAME:007ES-RED WOLF 2 DAY#:7 DSS: 4 EST DAYS LEFT:61 API#:50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG: 1 264 PROPOSED DEPTH: 12,100 OPERATOR:SAVANT ALASKA LLC CONTRACTOR:NABORS ALASKA DRILL DEPTH: 3849.00 24 HRS ROP:134.18 CUM ROT.HRS: 102.50 CO MAN:DROLLINGER TOOLPUSHER:TIEDEMANN/YEAROUT PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 2RR 12.25 EQH12D'1 16.0/16.0/16.0/14.0/0.0/0.0/0.0/0.0 1,264.00 9.42 134.18 2,585.00 3,849.00 11966739 GPM: 428.49 WOB: 18_00 NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: 110.00 PRES 1 CONTINENTAL 5.50 74.00 217.18 95.00 10.00 TORO: 3.60 SPR: 2 CONTINENTAL 5.50 72.00 211.31 95.00 10.00 AVDP: 5.00 AVDC: 8.00 MUD WT: 93 VISC: 300 PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT: 0.00 STR WT: 130 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 132 SLACK-OFF WT: 125 ' JAR HOURS: 49.46 SHOCK-SUB HRS 0.00 BHA HRS: 0.00 1 BIT 12.25 1.02 DP 4 14.00 S-135 376: 1 MOTOR,MUD 8 30.52 DP ON • 1 STABILIZER 12.125 4.37 LOCATION 1 SUB,X-OVER 8 1.55 DC 4 3/4 NC35 SPIRAL 9; DC ON 1 DM COLLAR 8 9.20.LOCATION 1 SUB,X-OVER 8.1 1.78 1 DGR 6.75 5.07 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 EWR-P4 8 12.18 CASING 1 HCIM 8 4.85 BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION 1 HOC 8.1 9.77 CONN GAS: 0.00 1 FLOAT SUB 8.06 2.16 SURV GAS 0.00 1 STABILIZER 8.1 5.41 TRIP GAS: 0.00 1 FLEX COLLAR 8.13 30.36 BOP TEST 1 FLEX COLLAR 8.1 30.53 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 735.55 00.00 01:30 1.50 6.A TRIP IN HOLE;TIH F/2235';T/2585',20',OF FILL 33 STANDS DP 0 3114.26 UWT 95K;SOW 85 K;14 HRS TROUBLE TIME DUE TO MWD 0 SINGLES 0 0 FAILURE 01:30 12:00 10.50 2.A ROTARY DRILLING:DRILL F/2585',T/3190',WOB=12 0 KELLY DOWN 0 0 K,GPM=420,SPM=143,PSI ON=1385,PSI OFF=1217. TOTAL 3849.81 RPM=110,TO ON=4.0K,TO OFF=3.OK,UWT=110K, SOW=105K,ROT=112K,AST=O,ART=8.66,ADT=8.66, REMARKS JARS=51.60,BIT=2431, 12:00 00:00 12.00 2.A ROTARY DRILLING F/3190'TO 3849';18 WOB;146 PJSM BEFORE TASK;INSP.DRK;C-O-M;FUNCTION SPM;429 GPM;1440 PSI ON;1380 PSI OFF,3.6K TQ AIR&MANUAL IBOP;TEST PVT,FLO-SHO; ON;2K TO OFF;132K UWT;125K DWT;130K RWT; FIRE DRILL CRT 75 SEC; PTSM-1;PJSM 5;PJSM BEFORE TASK;INSP.DRK;C-O-M;FIRE 110RPM;ART=9.14 HRS;AST=0.28 HRS,ADT=9.42 DRILL C RT=92 SEC;TEST PVT,FLO-SHO;PTSM;PJSM=8; -- - HRS;BIT=33.70 HRS, JARS=49.46 HRS ULSD/ARTIC FUEL REC=OGAL.; RIG FUEL=6194 GAL.;FUEL USED=2961 GAL. RIG H2O REC=220 BBL;RIG H2O=180 BBL;RIG H2O U SED=230 BBL PIT H2O REC=575 BBL;PIT H2O=520 BBL;PIT H2O U SED=511 BBL ANTICIPATED 24 HOUR OPERATION COM/FOM: ACCUM PRESS.: SWIVEL HRS: 105.00 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED: FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 14 MECH-/ELEC DAVID GUESS NO 11 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3676 RIG ON COMPANY DATE: TIME TOP DRIVE ON DATE:01 Apr 2012 TIME:0:00 RIG RELEASE DATE:07 Jun 2012 TIME 0:00 TOP DRIVE RELEASE DATE:30 May 2012 TIME: 0:00 08-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333890118984_NDUSADaily_ Page 1 of 2 1 r BORS ALASKA I..-►ILY MORNING REPORT kL NORTH SLOPEBORO L;f:-:NTY: NORTH SLOPE BOROUGH ST.: ALASKA RIG NO.:7ES RPT DATE:07 Apr 2012 WRK DATE:06 Apr 2012 JOB#:A1070 WELL NAME:007ES-RED WOLF 2 DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 FLEX COLLAR 8.11 29.97 1 SUB,X-OVER 7.28 2.39 5 5"HWDP 5 153.89 1 JARS,HYDRAULIC 6.22 31.53 12 5"HWDP 5 369.00 08-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333890118984_NDUSADaily_ Page 2 of 2 t 1102-NABORS ALASKA ..,LILY MORNING REPORT __.�NTY: NORTH SLOPE BOROUGH ST.: ALASKA RIG NO.:7ES RPT DATE:08 Apr 2012 WRK DATE:07 Apr 2012 JOB#:A1070 WELL NAME:007ES-RED WOLF 2 DAY#:8 DSS: 5 EST DAYS LEFT:60 API#:50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG: 23 PROPOSED DEPTH: 12,100 OPERATOR:SAVANT ALASKA LLC CONTRACTOR:NABORS ALASKA DRILL DEPTH: 3872.00 24 HRS ROP: CUM ROT.HRS: 109.00 CO MAN:DROLLINGER TOOLPUSHER:TIEDEMANN/YEAROUT PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 2RR 12.25 EQH12DI 16.0/16.0/16.0/14.0/0.0/0.0/0.0/0.0 1,287.00 9.42 136.62 2,585.00 3,872.00 11966739 GPM: WOB: NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: PRES 1 CONTINENTAL 5.50 95.00 10.00 TORQ: 3.60 SPR: 2 CONTINENTAL 5.50 95.00 10.00 AVDP: AVDC: MUD WT: 93 VISC: 155 PH: WL: PV I YP: / SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT: 0.00 STR WT: 130 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 132 SLACK-OFF WT: 125 1 BIT 12.25 1.02 JAR HOURS: 49.46 SHOCK-SUB HRS 0.00 BHA HRS: 0100 1 MOTOR,MUD 8 30.52 DP ON DP 4 14.00 S-135 376; 1 STABILIZER 12.125 4.37 LOCATION 1'SUB,X-OVER 8 1.55 DC 4 3/4 NC35 SPIRAL 9; ON 1 DM COLLAR 8 9.20 DC LOCATION 1 SUB,X-OVER 8.1 1.78 1 DGR 6.75 5.07 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS - 1 EWR-P4 8 12.18 CASING 1 HCIM 8 4.85 BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION 1 HOC 8.1 9.77 CONN GAS: 0.00 1 FLOAT SUB 8.06 2.16 SURV GAS 0.00 1 STABILIZER 8.1 5.41 TRIP GAS: 0.00 1 FLEX COLLAR 8.13 30.36 BOP TEST 1 FLEX COLLAR 8.1 30.53 FROM TO HRS CDEI DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 735.55 00:00 00:30 0.50 2.A ROTARY DRILLING;DRILL F/3849',TITD @ 3872, 34 STANDS DP 0 3136.45WOB=20 K,GPM=433,SPM=148,PSI ON=1490,PSI 1 SINGLES 0 OFF=1395,RPM=110,TO ON=3.1K,TO OFF=2.3K. UWT=132K,SOW=125K,ROT=130K,AST=0,ART=.81, 0 KELLY DOWN 0 0 ADT=.81,JARS=50.27,BIT=34.51, TOTAL 3872 00:30 02:00 1.50 5.D CIRCULATE AND CONDITION;CIRC/BU @ 3872';148 SPM 433 GPM 1390 PSI; REMARKS 02:00 03:30 1.50 6.J SHORT TRIP;PJSM MONT HOLE F/5 MIN PULL 15 STNDS F/3872',T/2527',UWT 130K;SOW 115K; PJSM BEFORE TASK;INSP.DRK;C-O-M;FUNCTION 03:30 05:00 1.50 6.J SHORT TRIP;MONT HOLE F/5 MIN TIH F/2527', AIR&MANUAL IBOP;TEST PVT,FLO-SHO; SPILL DRILL CRT 80 SEC; 1/3872',TAG BTM NO FILL.UWT 130K;SOW 115K; PTSM-1;PJSM 10;PJSM BEFORE TASK;INSP.DRK;C-O-M;MAN 05:00 06:00 1.00 5.D CIRCULATE AND CONDITION;CIRC CARBIDE BOMB ' DOWN DRI LL CRT=60 SEC;TEST PVT,FLO-SHO;PTSM;PJSM AROUND.@ 144 SPM,424 GPM,1399 PSI,45 RPM,TO =8 ; 1.2K, ARCTIC/ULSD FUEL REC=5425 GAL.;RIG FUEL=9436 G AL.;FUEL 06:00 09:00 3.00 6.B TRIP OUT OF HOLE;POOH F/3872',T/735',HOLE IS USED=2183 GAL. GOOD NO TIGHT SPOTS. _RIG H2O REC=70 BBL;RIG H20=140 BBL;RIG H2O US ED=110 09:00 12:00 3.00 6.D LAY DOWN BHA;PJSM LD/BHA DRAIN MOTOR BREAK BIT. BBL 12:00 14:00 2.00 6.D LAY DOWN BHA;DOWNLINK MWD;LD HOC,HCIM,EWR-P4. PIT H2O REC=200 BBL;PIT H2O=490BBL,PIT H2O U SED=230 DGR,X/0,DM,X/O,STAB,MOTOR;CLEAN RIG FLOOR ANTICIPATED 24 HOUR OPERATION 14:00 15:00 1.00 12.A RIG UP/DOWN TO RUN CASING;PU CSG TOOLS& EQUIPMENT;MAKE DUMMY RUN W/HGR&LANDING JT TO 29.94' 15:00 17:30 2.50 12.A RIG UP/DOWN TO RUN CASING;CHG BALES,RU TO RUN COM/FOM: ACCUM PRESS.: SWIVEL HRS: 114.00 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED: FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 14 MECH./ELEC DAVID GUESS NO 11 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3677 RIG ON COMPANY DATE: TIME TOP DRIVE ON DATE:01 Apr 2012 TIME:0:00 RIG RELEASE DATE:07 Jun 2012 TIME 0:00 TOP DRIVE RELEASE DATE:30 May 2012 TIME: 0:00 09-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333964393265_NDUSADaily_ Page 1 of 2 l ' RS LASKA v r1ILY MORNING REPORT _~1 s__-,NTY: NORTH SLOG EABOROUGH ST.: ALASKA RIG NO.:7ES RPT DATE:08 Apr 2012 WRK DATE:07 Aor 2012 JOB#:A1070 WELL NAME:007ES-RED WOLF 2 Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS 9-5/8"CSG 17.30 00:00 6.50 12.B RUN CASING;RUN 9-5/8"478 CSG TO 2324;130K UWT;110K DWT;AVG MU TO 11000 FT/LBS;(CIRC 5 BBLS @ 3 BPM PER 5 STANDS) DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 FLEX COLLAR 8.11 29.97 1 SUB,X-OVER 7.28 2.39 5 5"HWDP 5 153.89 1 JARS,HYDRAULIC 6.22 31.53 12 5"HWDP 5 369.00 II 09-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1333964393265_NDUSADaily_ Page 2 of 2 t 1..MILY MORNING REPORT . 102-NABORSALASKA ,-JNTY: NORTH SLOPE BOROUGH ST.: ALASKA RIG NO.:7ES RPT DATE:09 Apr 2012 WRK DATE:08 Apr 2012 JOB#:A1070 WELL NAME:007ES-RED WOLF 2 DAY#:9 DSS: 6 EST DAYS LEFT:59 API#:50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG: 23 PROPOSED DEPTH: 12,100 OPERATOR:SAVANT ALASKA LLC CONTRACTOR:NABORS ALASKA DRILL DEPTH: 3872.00 24 HRS ROP: CUM ROT.HRS: 109.00 CO MAN:DROLLINGER TOOLPUSHER:TIEDEMANN/YEAROUT PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE GPM: WOB: NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: PRES 1 CONTINENTAL 5.50 95.00 10.00 TORO: SPR: 2 CONTINENTAL 5.50 95.00 10.00 AVDP: AVDC: MUD WT: 9.3 VISC: 85 PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT: 0.00 STR WT: 130 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 132 SLACK-OFF WT: 125 'JAR HOURS: 0.00 SHOCK-SUB HRS 0.00 BHA HRS: 0.00 1 0 0.00 DP ON DP 4 14.00 S-135 376; 'LOCATION DC ON DC 4 3/4 NC35 SPIRAL 9; LOCATION LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS CASING BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION r CONN GAS: 0.00 _ SURV GAS 0.00 TRIP GAS: 0.00 BOP TEST FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 00:00 03:00 3.00 12.B RUN CASING;RUN 9-5/8"47#CSG F/2324';T/3847', /f 34 STANDS DP 0 3136.45 _, 195K UWT;175K DWT;AVG MU TO 11000 FT/LBS;(CIRC sl/"^✓Y ' 1 SINGLES 0 0 5 BBLS @ 3 BPM PER 5 STANDS) 1 03:00 04:30 1.50 5.D CIRCULATE AND CONDITION,CIRC BU 161 GPM 250 PSI, cam`' 1 0 KELLY DOWN 0 0 04:30 05:30 1.00 12.0 PRIMARY CEMENTING,PU/LANDING JNT.RU/CMT HEAD. TOTAL CIRC T/CONDITION MUD @ 72 SPM,214 GPM,370 PSI, F/CMT JOB. REMARKS J 05:30 08:00 2.50 21.0 WAITING ON 3RD PARTY TOOLS,CONT T/CIRC WAITING ON VAC TRUCK FOR CMT DISP PJSM BEFORE TASK;INSP.DRK;C-O-M;FUNCTION 08:00 11:30 3.50 12.0 PRIMARY CEMENTING,PUMP 5 BBL 10.1 PPG MUD PUSH AIR&MANUAL BOP;TEST PVT,FLO-SHO; TEST LINES T/2600 PSI, MAN DOWN DRILL CRT 90 SEC; ' 11:30 12:00 0.50 12.0 PRIMARY CEMENTING,CONT T/PUMP MUD PUSH @ 10.1 PTSM-1;PJSM 3;PJSM BEFORE TASK;INSP.DRK;C-O-M;FIRE , DRILL C RT=85 SEC;TEST PVT,FLO-SHO;PTSM;PJSM=8: PPG @ SBBUMIN ARCTIC FUEL REC=()GAL RIG FUEL=7177 GAL.;FUEL 12:00 14:30 2.50 12.0 PRIMARY CEMENTING;SLB CONT.PUMP MUD PUSH,100 USED=2259 GAL. BBLS 10.1 PPG TOTAL MUD PUSH;DROP BTM PLUG,SLB RIG H2O REC=65 BBL;RIG H20=110 BBL;RIG H2O US ED=95 BBL UMP 472 BBLS 10.7 PPG LEAD @ 4.8 BPM;50 BELS PIT H2O REC=200 BBL;PIT H2O=456 BBL;PIT H2O U SED=234 15.8 PPG TAIL @ 4.8 BPM;DROP TOP PLUG;10 BBLS BBL - ' WATER 14:30 '15:30 1.00 12.0 PRIMARY CEMENTING;RIG DISPLACE W/265 BBLS MUD @ ANTICIPATED 24 HOUR OPERATION 4.3 BPM,680 PSI;PRESSURE TO 1300 PSI;BLEED PRESSURE,CK FLOATS=HOLDING;CIP 1522 HRS 15:30 18:00 2.50 12.A RIG UP/DOWN TO RUN CASING;RD&BLOW DN CMT LINES,LD CMT HEAD,LD 350 TON ELEVATORS,CHG BALES COM/FOM: ACCUM PRESS.: SWIVEL HRS: 115.50 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5 MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED: FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 14 MECH./ELEC DAVID GUESS NO 11 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3678 RIG ON COMPANY DATE: TIME TOP DRIVE ON DATE:01 Apr 2012 TIME:0:00 RIG RELEASE DATE:07 Jun 2012 TIME 0:00 TOP DRIVE RELEASE DATE:30 May 2012 TIME: 0:00 10-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334051032187_NDUSADaily_ Page 1 of 2 BORS �+/'1ILY MORNING REPORT 102-NA� SLOPEASKA .-_ NTY: NORTH SLOPE BOROUGH ST.: ALASKA RIG NO.:7ES RPT DATE:09 Apr 2012 WRK DATE:08 Apr 2012 JOB#:A1070 WELL NAME:007ES-RED WOLF 2 Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS 18:00 18:30 0.50 12.D TOP CEMENT JOBS;MOVE 5 STDS 5"HWDP F/ODS TO DS 18:30 19:30 1.00 12.D TOP CEMENT JOBS;MU TAM COMBO TOOL&SGL JT 5"DP 19:30 20:00 0.50 12.D TOP CEMENT JOBS;C/O DS 4"VALVE ON 20"CONDUCTOR 20:00 22:30 2.50 12.D TOP CEMENT JOBS;RIH TAM COMBO TOOL ON 5"DP; LATCH @ 510';RU CMT HOSE&VALVES;PT 600 PSI; BLEED TO 200 PSI,SHIFT TAM COLLAR OPEN W/25K DWT 22:30 23:30 1.00 12.D TOP CEMENT JOBS;CIRC DN DP THROUGH TAM COLLAR TO OPEN 4"CONDUCTOR VALVES;1 BPM;27 PSI;45 BBLS 9.3 PPG MUD;TRACE OF MUD PUSH;NO CEMENT RETURNS 23:30 00:00 0.50 12.0 TOP CEMENT JOBS;PREP FOR CEMENT JOB • 10-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334051032187_NDUSADaily_ Page 2 of 2 r 102-NABORS ALASKA �.-.ILY MORNING REPORT �...NTY: NORTH SLOPE BOROUGH ST.: ALASKA RIG NO.:7ES RPT DATE:10 Apr 2012 WRK DATE:09 Apr 2012 JOB#:A1070 WELL NAME:007ES-RED WOLF 2 DAY#:10 DSS: 7 EST DAYS LEFT: 58 API#:50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG: 23 PROPOSED DEPTH: 12,100 OPERATOR:SAVANT ALASKA LLC CONTRACTOR:NABORS ALASKA DRILL DEPTH: 3872.00 24 HRS ROP: CUM ROT.HRS: 109.00 CO MAN:HAMMON TOOLPUSHER:TIEDEMANN/YEAROU1 PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE GPM: WOB: NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: PRES 1 CONTINENTAL 5.50 95.00 10.00 TORO: SPR: / 2 -CONTINENTAL 5.50 95.00 10.00 AVDP: AVDC: MUD WT: 9.0 VISC: 70 PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT: 0,00 STR WT: 130 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 132 SLACK-OFF WT: 125 JAR HOURS: 0.00 SHOCK-SUB HRS 0.00 BHA HRS: 0.00 1 0 0.00 DP 4 14.00 S-135 376; DP ON LOCATION DC ON DC 4 3/4 NC35 SPIRAL 9; LOCATION LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS CASING BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION CONN GAS: 0.00 - SURV GAS 0.00 - TRIP GAS: 0,00 BOP TEST FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 00.00 03.00 3.00 12.D TOP CEMENT JOBS,WAITING ON CMT AND WATER FOR TOP STANDS DP JOB.ND/DIVERTER. SINGLES 03:00 04:00 1.00 12.D TOP CEMENT JOBS,PJSM PUMP 10 BBL WATER PT/CMT LINE 0 PSI. KELLY DOWN 04:00 04:30 0.50 12.D TOPCEMENT CEMENT JOBS,PUMP 150 BBL 10.7 PPG CMT @ 3 TOTAL BPM.HAD GOOD 10.7#CEMENT RETURNS TO SURFACE 04.30 06:00 1.50 12.0 PRIMARY CEMENTING.PUMP 6 BBLS WATER CLOSE PORT COLLAR PT COLLAR T/1000 PSI.TEST WAS GOOD. /� REMARKS RELEASE SHIFTING TOOL PT T/1000 PSI PULL UP& I/(),IC/ PJSM BEFORE TASK;INSP.DRK;C-O- FUNCTION PRESSURE UP T/2500 PSI T/BLOW OUT CHOKE.PUMP 50 ` AIR&MANUAL BOP,TEST PVT,FLO-SHO; BBLS WATER T/FLUSH OUT DP&CASING FIRE DRILL CRT 75 SEC; PTSM-1;PJSM 9;PJSM BEFORE TASK;INSP.DRK;C-O-M;SPILL 06:00 07:00 1.00 12.D TOP CEMENT JOBS,RD/CMT EQUIPMENT.BRAKE DOWN XO'S&PUMP IN SUB. DRILL CRT=70 SEC;TEST PVT,FLO-SHO;PTSM;PJSM=8; ARCTIC FUEL REC=4176 GAL.;RIG FUEL=9625GAL.;FUEL 07'.00 08.30 1.50 12.D TOP CEMENT JOBS CLEAN CMT CELLAR OUT OF CELLAR. USED=1728GAL 08.30 09:30 1.00 6.F LAY DOWN DRILL PIPE,PJSM LD/16 JNTS DP&SHIFTING RIG H2O REC=85 BBL;RIG H2O=110 BBL;RIG H2O US ED=85 BBL TOOL. PIT H2O REC=220 BBL;PIT H2O=686 BBL;PIT H2O U SED=10 BBL 09.30 10:30 1.00 12.B RUN CASING PICK UP OTHER HALF OF LANDING JNT BACK OUT OF HANGER.LD/LANDING JNT. IRMO :.:11.NIPPLE UP/DOWN DIVERTER SYST,REMOVE LAST PIECE ANTICIPATED 24 HOUR OPERATION OF DIVERTER.REMOVE RISER&4"VALVES FROM CONDUCTOR INSTALL 4"PIPE PLUGS ON 20"CONDUCTOR. 12:00 15:00 3.00 14.0 NIPPLE UP/DOWN DIVERTER SYST;ND RISER, DIVERTER,&SPEEDHEAD ADAPTER;(CHANGE TO 5" COM/FOM: ACCUM PRESS.: SWIVEL HRS: 115.50 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1: #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5 MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED: FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 14 MECH.IELEC DAVID GUESS NO 11 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3679 RIG ON COMPANY DATE: TIME TOP DRIVE ON DATE:01 Apr 2012 TIME:0:00 RIG RELEASE DATE:07 Jun 2012 TIME 0:00 TOP DRIVE RELEASE DATE:30 May 2012 TIME: 0:00 11-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334149596531_NDUSADaily_ Page 1 of 2 ILY MORNING NABORS : SLOPEBOROUGH NORTH SLOPE B ST.: ALASKA RIG NO.:7ES RPT DATE:10 Apr 2012 WRK DATE:09 Apr 2012 JOB#:A1070 WELL NAME:007ES-RED WOLF 2 Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS LINERS#1 PUMP) 15:00 18:00 3.00 14.1 INSTALL WELLHEADS;INSTALL CSG&TUBING HEADS,& DSA,SET BOP STACK;FMC REP PT METAL TO METAL SEAL 1000 PSI/10 MIN. 18:00 22:30 4.50 14.A NIPPLE UP BOPS;(TORQUE BOLTS AT CSG HEAD,TBG HEAD,DSA,BOP);INSTALL RISER;CHANGE TOP DRIVE SAVER SUB F/4-1/2 IF TO 4"HT-40 22:30 00:00 1.50 15.G PU TEST TOOLS;RU TO TEST BOPE it 11-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334149596531_NDUSADaily_ Page 2 of 2 _ALY MORNING REPORT : 102-NABORS ASKA __JNTY: SLOPEB NORTH SLOPE BOROUGH ST.: ALASKA RIG NO.:7ES RPT DATE:11 Apr 2012 WRK DATE:10 Apr 2012 JOB#:A1070 WELL NAME:007ES-RED WOLF 2 DAY#:11 DSS: 8 EST DAYS LEFT:57 API#:50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG: 23 PROPOSED DEPTH: 12,100 OPERATOR:SAVANT ALASKA LLC CONTRACTOR:NABORS ALASKA DRILL DEPTH: 3872.00 24 HRS ROP: CUM ROT.HRS: 109.00 CO MAN:DROLLINGER TOOLPUSHER:TIEDEMANN/YEAROUT PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE GPM: WOB: NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: PRES 1 CONTINENTAL 5.50 95.00 10.00 TORO: SPR: / 2 CONTINENTAL 5.50 95.00 10.00 AVDP: AVDC: ' MUD WT: 9_0 VISC: 70 PH: WL: PV/YP: / SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT: 0.00 STR WT: 130 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 132 SLACK-OFF WT: 125 1 0 0.00 JAR HOURS: 0.00 SHOCK-SUB HRS 0.00 BHA HRS: 0.00 DP ON DP 4 14.00 S-135 376; LOCATION DC ON DC 4 3/4 NC35 SPIRAL 9; LOCATION LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS CASING BG GAS: 000 SURVEY DEPTH DEG. DIRECTION CONN GAS: 0.00 SURV GAS 0.00 TRIP GAS: BOP TEST 11 Apr 2012 .FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 00:00 05:30 5.50 15.A TEST BOPS UPPER/LOWER RAMS,BLINDS STANDS DP 250/4000 PSI 5 MIN.EACH,ANN.250/2500 SINGLES PSI 5 MIN.EACH.TEST WITNESSED BY AOGCC JOHN CRISP&TP PAUL YEAROUT. KELLY DOWN 05:30 07:00 1.50 15.11 RD/LD TEST TOOL,BD/CHOKE MANIFOLD, TOTAL CHOKE&KILL LINE,TOP DRIVE,TEST PUMP. PULL TEST PLUG. REMARKS 07:00 07:30 0.50 6.K INSTALUREMOVE WEAR BUSHING 07:30 10:00 2.50 6.A TRIP IN HOLE,PJSM,TIH W/5"DP F/DERRICK PJSM BEFORE TASK;INSP.DRK;C-O-M;FUNCTION - T/3679',CLEAN RIG FLOOR. AIR 8 MANUAL IBOP;TEST PVT,FLO-SHO; 10:00 12:00 2.00 6.F LAY DOWN DRILL PIPE F/3675 T/2831'-UT 90K SOW BOP DRILL CRT 80 SEC; W - 90K PTSM-1;PJSM 7; CLOSE TIME'S F/HCR'S 6 SEC.F/ANN 36 SEC.F/PIP E RAMS 20 12:00 15:30 3.50 6.F LAY DOWN DRILL PIPE F/2831'ALL 5"DP 1 SEC.F/BLINDS 14 SEC. LAID DOWN WEAR BUSHIN LENGTH 37.0 IN ID 8 7/8 IN OD 10 3/8 IN. 15:30 20:00 4.50 6.E PICK UP DRILL PIPE;PU 90 JTS 4"HT-40 DP TO KOOMEY TEST 200 PSI RECOVERY TIME 20 SEC.AVG B OTTLE 2819;63K UWT;65K DWT PSI 2100.FINISH TIME 80 SEC PJSM BEFORE TASK;INSP.DRK; 20:00 21:30 1.50 6.B TRIP OUT OF HOLE,STD BACK 4"DP Fl C-O-M;D-1 DRILL CR T=123 SEC;TEST PVT,FLO-SHO;PTSM; 2819' PJSM=7; 21:30 00:00 2.50 6.E PICK UP DRILL PIPE 4"HT-40,SGLS TO ANTICIPATED 24 HOUR OPERATION 1880 COM/FOM: ACCUM PRESS.: SWIVEL HRS: 115.50 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY:0.00 ENGINE KW-#1: #2: #3 #4: #5 MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED: FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 1 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 14 MECH./ELEC DAVID GUESS NO 11 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3680 RIG ON COMPANY DATE: TIME TOP DRIVE ON DATE:01 Apr 2012 TIME:0:00 RIG RELEASE DATE:07 Jun 2012 TIME 0:00 TOP DRIVE RELEASE DATE:30 May 2012 TIME: 0:00 12-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334233446513_NDUSADaily_ Page 1 of 1 DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:12 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:12 DSS: 9 EST DAYS LEFT 56 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 15 PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LI2 CONTRACTOR:NABORS ALASKA DRILL DEPTH: 3,887 24 HRS ROP:150.00 CUM ROT.HRS: 113.00 CO MAN:HAMMON/ TOOLPUSHER:TIEDEMANN/YEAROUT PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 2RR 1225 EQH12DRC 16.0/16.0/16.0/14.0/0.0/0.0/0.0/0.0 1.287.00 9.42 136.62 2.585.00 3.872.00 11966739 3 8.50 QHC1D2R 18.0/18.0/18.0/0.0/0.0/0.0/0.0/0.0 93.00 2.15 43.26 3,872.00 3,965.00 11748540 GPM: 519.06 wog: moo NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: 110.00 PRES:1,270.00 1 CONTINENTAL 5.00 107.00 25953 95.00 10.00 TORQ: SPR: 35 065 2 CONTINENTAL 5.00 107.00 259.53 95.00 10.00 AVDP: 4.00 AVDC:4.00 - MUD WT: 9.0 VISC: 75 PH: WL: PV/YP: / SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.00 STR WT: 90 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 132 SLACK-OFF WT: 125 1 BIT 8.5 0.90 JAR HOURS: 0.97 SHOCK-SUB HRS o.00 BHA HRS: 0.00 1 DP 4 14.00 S-135 376; BIT SUB 6 2.57 DP ON LOCATION 1 X/O 6 2.46 6 4"HWDP 4 183.13 DC ON DC 4 3/4 NC35 SPIRAL 9; 1 JARS,HYDRAULIC 6.87 31.35 LOCATION 14 4"HWDP 4 426.45 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS CASING BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION CONN GAS: 0.00 SURV GAS 0.00 TRIP GAS: o.00 BOP TEST 11 Apr 2012 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 646.86 00:00 01:00 , 1.00 6.E PICK UP DRILL PIPE 4"HT-40,SGLS IN F/1880'- T/2821',UWT 60K SOW 65K; 34 STANDS DP 3197.59 01 00 02:30 1.50 6.B TRIP OUT OF HOLE 30 STDS 4"DP,UWT 65K SOW 65K SINGLES 02:30 06:00 3.50 6.E PICK UP DRILL PIPE 4"SGLS T/2821',UWT 60K SOW KELLY DOWN 42.55 60K 06:00 07:00 1.00 6.B TRIP OUT OF HOLE 30 STDS 4"DP,UWT 65K SOW 65K TOTAL 07:00 09:00 2.00 6.0 PICK UP BHA,PJSM,20 JTS 4"HWDP&JARS. REMARKS 09:00 12:00 3.00 6.E PICK UP DRILL PIPE,PU 4"HT-40 SGLS F/646'- T/2747',UWT 60K SOW 60K Pa€T^^S;FUNCTION TOP RAMS;FIRE DRILL CRT=90 SEC; 12:00 12:30 0.50 6.E PICK UP DRILL PIPE;PU 4"DP F/2747'TO 3277'; EST PVT,FLO-SHO;PTSM;PJSM=6;(TBG LDS RKB 78K UWT;80K DWT 25.22';CSG LDS RKB 27.48) 12:30 14:30 2.00 9.A CUT DRILLING LINE;CUT&SLIP 105'DRILL LINE; SERVICE DRAWWORKS 14:30 15:00 0.50 7.0 SERVICE TOP DRIVE;SERVICE TOP DRIVE;CALIBRATE FUEL USED=1892 GAL. BLOCK HEIGHT 15:00 15:30 0.50 6.A TRIP IN HOLE F/3277'TO 3656' ED=80 BBL 15:30 16:00 0.50 2.0 DRILLING CEMENT;WASH/REAM F/3656'TO 3764';5K WOB;625 PSI;234 GPM;1.2K TQ;50 RPM;83K UWT; D=188 BBL 84K DWT;85K RWT; ANTICIPATED 24 HOUR OPERATION 16:00 17:00 1.00 12.E PRESSURE TEST CSG/SHOE;PT 9-5/8 CSG TO 2500 PSI /15 MIN;3.2 BBLS 9.3 PPG MUD 17:00 18.30 1.50 2.0 DRILLING CEMENT;DRLG FC 3766'&SHOE TRACT TO 3840';10K WOB;234 GPM;850 PSI;50 RPM;2K TO; COM I FOM: ACCUM PRESS.: SWIVEL HRS: 121.00 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1 : #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 12 MECH.IELEC DAVID GUESS NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3681 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00:00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012. TIME: 00;00 Report Date:13-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334329826546_NADDaily_sgl. Page 1 of 2 RIG NO.:7ES DATE:12 Apr 2012 WELL: A1070 007ES-RED WO, Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS 83K UWT;84K DWT;85K RWT:110 FT/HR ROP 18:30 19:30 1.00 12.E PRESSURE TEST CSG/SHOE;PT CSG @ 3840';2500 PSI /15 MIN;2.9 BBLS 9.3 PPG MUD;BLOW DN KILL LINE 19:30 21:00 1.50 5.D CIRCULATE AND CONDITION;DISPLACE TO 9.0 PPG LSND;RECIP 3835'-3750';50 RPM;0.8 TO;88K RWT;172 SPM;418 GPM;880 PSI;(SPR TAKEN @ 20:50 HRS;3839'TVD;3840 MD;#1 @ 2BPM= 160 PSI;#1 @ 3BPM=220 PSI) 21:00 22:00 1.00 2.0 DRILLING CEMENT;DRLG CMT,SHOE,RAT HOLE TO 3872';248 GPM;440 PSI;1.3K TQ;70 RPM;85K UWT; 87K DWT;90K RWT 22:00 23:00 1.00 2.A ROTARY DRILLING;DRLG NEW HOLE F/3872'TO 3887'; 10K WOB;532 GPM;1250 PSI;110 RPM;85K UWT;87K DWT;90K RWT;ART=0.97 HRS;ADT=0.97 HRS;BIT= 0.97 HRS;JARS=0.97 HRS 23:00 00:00 1.00 12.1 FORMATION INTEGRITY TEST(FIT) • Report Date'13-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334329826546_NADDaily_sgl. Page 2 of 2 DAILY MORNING REPORT k LEASE:RED WOLF#2 RIG NO.:7ES DATE:13 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:13 DSS: 10 EST DAYS LEFT 55 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 938 PROPOSED DEPTH: 12 100 OPERATOR: SAVANT ALASKA LL(CONTRACTOR:NABORS ALASKA DRILL DEPTH: 4 825 24 HRS ROP:119.64 CUM ROT.HRS: 125.00 CO MAN:HAMMON/ TOOLPUSHER:TIEDEMANN/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 3 8.50 QHC1D2R 18.0/18.0/18.0/0.0/0.0/0.0/0.0/0.0 93.00 2.15 43.26 3,872.00 3.965.00 11748540 6 8.50 PDC 13.0/13.0/13.0/0.0/0.0/0.0/0.0/0.0 860.00 5.79 148.53 3,965.00 4,825.00 130543 GPM: 548.17 WOB: 10.00 NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: 80.00 PRES:2.150.00 1 CONTINENTAL 5.00 116.00 281.36 95.00 10.00 TORO: SPR: 35 /leo 2 CONTINENTAL 5.00 110.00 266.81 95.00 10.00 AVDP: 95.50 AVDC:90.00 MUDWT: 8.9 VISC: 52 PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.00 STR WT: 100 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 132 SLACK-OFF WT: 125 1 BIT 8.5 1.00 JAR HOURS: 8 SHOCK-SUB HRS 4.04 BHA HRS: c op DP 414.00 S-135 376; 1 MOTOR,MUD 7- 26.39 DP ON LOCATION 1 INTEGRAL BLADE 6.86 5.62 1 DM COLLAR 6.75 9.20 DC ON DC 4 3/4 NC35 SPIRAL 9; 1 MWD 6.78 1.32 LOCATION 1 DGR 6.75 3.88 1 SUB,X-OVER 6.75 12.61 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 HCIM 6.75 7.84 CASING 1 PWD 6.75 12.88 BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION 1 HOC 6.9 9.16 CONN GAS: 1 SUB,FLOAT 6.75 2.64 SURV GAS 0.00 3 FLEX JOINT,NON-MAGNE 6.79 93.12 TRIP GAS: 4_44 BOP TEST 11 Aor2012 1 SUB,X-OVER 6 2.46 6 4"HWDP 4 183.13 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 829.05 00:00 02:30 2.50 2.A ROTARY DRILLING F/3887'TO 3965';10K WOB;216 SPM;523 GPM;1308 PSI ON;1280 PSI OFF;1.7K TO 42 STANDS DP 3950.38 ON;1K TQ OFF;87K UWT;90K DWT;90K RWT;110 RPM; SINGLES ART=2.05 HRS:ADT=2.05 HRS;BIT=3.02 HRS;JARS =3.02 HRS KELLY DOWN 7.575 02:30 03:00 0.50 5.D CIRCULATE AND CONDITION:CBU;524 GPM;1293 PSI; TOTAL 115 RPM;1K TQ;90K RWT;87K UWT;90K DWT:RECIP - REMARKS 3965'-3935';(SPR TAKEN @ 02:50 HRS;3965'MD; 3964'TVD;#1 @ 2BPM=160 PSI;3BPM=180 PSI) PJSM BEFORE TASK;INSP.DRK;C-O-M;SPILL DRILL 03:00 05:30 2.50 6.8 TRIP OUT OF HOLE;MONITOR WELL;BLOW DN TOP CRT=80;TEST PVT,FLO-SHO;PTSM;PJSM=3; DRIVE;POOH F/3965'T/646', 05:30 07:30 2.00 6.D LAY DOWN BHA,PJSM LD/BHA.CLEAN RIG FLOOR.GET PJSM BEFORE TASK;INSP.DRK;C-0-M;FUNCTION TOOLS READY FOR NEXT BHA. 07:30 09:30 2.00 6.0 PICK UP BHA,PJSM PU BHA, ------ 09:30 11:00 1.50 6.0 PICK UP BHA,TEST MWD TOOL @ SURFACE BD/TOP DRIVE. 11:00 12.00 1.00 6.0 PICK UP BHA,CONT T/PU BHA,MAKE UP BIT, 12:00 14:30 2.50 6.A TRIP IN HOLE,TIH F/829'173965', 14:30 15:00 0.50 2.A ROTARY DRILLING,EST BASE LINE ECD. ANTICIPATED 24 HOUR OPERATION 15:00 23:58 8.97 2.A ROTARY DRILLING F/3965',T/4787',WOB=10K, GPM=550,PSI ON=2150,PSI OFF=1985,RPM=80,TO ON=2.3K,TO OFF=1.2K,UWT=108K,SOW=104K, ROT=100K,CAL ECD=9.55PPG,ACT ECD=9.83PPG, COM/FOM: ACCUM PRESS.: SWIVEL HRS: 133.50 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1 : #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 22 MECH.IELEC JUSTIN KNIGHTEN NO 19 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3682 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00_00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:14-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334408177609_NADDaily_sgl. Page 1 of 2 RIG NO.:7ES DATE:13 ADr 2012 WELL: A1070 007ES-RED WOL. Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS AST=.27,ART=5.52,ADT=5.79,BIT=5.79,JARS=8.81, 23:58 00:00 0.03 2.A ROTARY DRILLING SPR TAKEN @ 4027-MD,4026'-TVD, MP#1@2BPM=200PSI,@3BPM=280PSI, MP#2@2BPM=200PSI,@3BPM=260PSI,MW=9.OPPG DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 JARS,HYDRAULIC 6.87 31.35 14 4"HWDP 4 426.45 Report Date:14-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334408177609_NADDaily_sgl. Page 2 of 2 DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:14 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:14 DSS: 11 EST DAYS LEFT 54 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 1,393 PROPOSED DEPTH: 12 100 OPERATOR: SAVANT ALASKA LL(CONTRACTOR:NABORS ALASKA DRILL DEPTH: 6,180 24 HRS ROP:137.38 CUM ROT.HRS: 141.50 CO MAN:HAMMON/ TOOLPUSHER:TIEDEMANN/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 6 8.50 PDC 13.0/13.0/13.0/0.0/0.0/0.0/0.0/0.0 2,215.00 15.93 139.05 3,965.00 6.180.00 130543 6 8.50 PDC 13.0/13.0/13.0/0.0/0.0/0.0/0.0/0.0 2,215.00 15.93 139.05 3,965.00 6.180.00 130543 GPM: 548.17 WOB: NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: PRES: 1 CONTINENTAL 5.00 118.00 28621 95.00 10.00 TORQ:150 SPR: 35 /300 2 CONTINENTAL 5.00 108.00 26196 95.00 10.00 AVDP: 4.0o AVDC:610 MUD WT: 9.3 VISC: 75 PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.0o STR WT: 124 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 132 SLACK-OFF WT: 125 JAR HOURS: 24.74 SHOCK-SUB HRS o.00 BHA HRS: 0.00 1 BIT 8.5 1.00 DP 4 14.00 S-135 376; 1 MOTOR,MUD 7 26.39 DP ON LOCATION 1 INTEGRAL BLADE 6.86 5.62 1 DM COLLAR 6.75 9.20 DC 4 3/4 NC35 SPIRAL 9; DC ON 1 MWD 6.78 1.32 LOCATION 1 DGR 6.75 3.88 _ 1 SUB,X-OVER 6.75 12.61 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 HCIM 6.75 7.84 CASING p625 3851 13.20 4,550.000 1 PWD 6.75 12.88 BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION 1 HOC 6.9 9.16 CONN GAS: 0.00 1 SUB,FLOAT 6.75 2.64 SURV GAS 0.00 _ 3 FLEX JOINT,NON-MAGNE 6.79 93.12 TRIP GAS: 0.00 BOP TEST 11 Apr 2012 1 SUB,X-OVER 6 2.46 6 4"HWDP 4 183.13 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 829.05 00:00 04:00 4.00 2.A ROTARY DRILLING F/4787'T/5234';10K WOO;226 SPM;550 GPM;2300 PSI ON;2080 PSI OFF;3.4K TQ 56 STANDS DP 0 5267.89 ON;1.3 TQ OFF;112K UWT;108K DWT;106K RWT;80 ()SINGLES 0 0 RPM; 04:00 12:00 8.00 2A ROTARY DRILLING;DRILL F/5234',T/5909',WOB=15 OKELLY DOWN 0 83.06 K,GPM=550,SPM=227,PSI ON=2730,PSI OFF=2428, TOTAL 6180 RPM=75,TQ ON=3.5K,TQ OFF=1.1 K,UWT=120K, REMARKS SOW=120K,ROT=120K,9.55CECD;10.08AECD AST=.86, ART=7.53,ADT=8.39,JARS=22.19,BIT=14.18, 12:00 1300 100 2.A ROTARY DRILLING;DRILL F/5909',T/6003',TVD 6002'WOB=15 K,GPM=550,SPM=227,PSI ON=2730,PSI OFF=2428,RPM=75,TQ ON=3.5K,TQ OFF=1.1K, PJSM BEFORE TASK;INSP.DRK;C-O-M;FUNCTION UWT=120K,SOW=120K,ROT=120K, 13:00 14:30 1.50 5.D CIRCULATE AND CONDITION PUMP HIGH VIS SWEEP 520 GPM;2040 PSI;UWT=120K;SOW=120K;25 RPM;SPR TAKEN @ 6002'MD/6001'TVD;PMP#1;2 BBL/MIN=300;3BBUMIN=400;PMP#2;2 BBUMIN= 300;3BBL/MIN=400;MW 9.1 LB/GAL 14:30 16:30 2.00 613 TRIP OUT OF HOLE POOH F/6003'T 3449';UWT=98K; ANTICIPATED 24 HOUR OPERATION Sow=95K;PULL 25K OVER@ 4167;4215;4275;4460; WAS ABLE TO WORK THROUGH TIGHT SPOTS 16:30 17:00 0.50 6.E PICK UP DRILL PIPE P/U 9 JOINTS OF 4"DP; 17:00 18:00 100 7.B SERVICE TOP DRIVE GREASE W/P;SERVICE TD AND COM I FOM: ACCUM PRESS.: SWIVEL HRS: 153.00 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1 : #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 21 MECH.IELEC MILTON PEERY NO 9 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3683 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00:00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:15-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334493948953_NADDaily_sgl. Page 1 of 2 , RIG NO.:7ES DATE:14 Apr 2012 WELL: A1070 007ES-RED WOL. Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND D REMARKS__ BLOCKS 18:00 19:30 1.50 11.A OPEN HOLE LOGS MAD PASS F/3860'1 3975'WITH SURVEY @ 3932'MAX 180'/HR;540 GPM;@ 2004PSI 19:30 20:30 1.00 3 A REAMING/WASHING WASH DOWN F/3975'T 4500';545 GPM;2170 PSI;UWT=107K;SOW 105K @ 4580'MD 20:30 22:00 1.50 6.A TRIP IN HOLE RIH F/4500'TO 5908'; 22:00 22:30 0.50 3.A REAMING/WASHING WASH DOWN FROM 5908'T 6002' 540GPM;@ 2500 PSI 22:30 00:00 1.50 2.A ROTARY DRILLING;DRILL F/6002',T/6180',WOB=15 K,GPM=550,SPM=227,PSI ON=2800,PSI OFF=2428, RPM=75,TQ ON=3.5K,TQ OFF=1.3K,UWT=130K, SOW=128K,ROT=124K,OECD=9.71;AECD=10.02 AST=.0, ART=1.75,ADT=1.75,JARS=24.74,BIT=16.4 DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 JARS,HYDRAULIC 6.87 31.35 14 4"HWDP 4 426.45 Report Date:15-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334493948953_NADDaily_sgl. Page 2 of 2 DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:15 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:15 DSS: 12 EST DAYS LEFT 53 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 1 840 PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LL(CONTRACTOR:NABORS ALASKA DRILL DEPTH: 8,020 24 HRS ROP:109.46 CUM ROT.HRS: 189.50 CO MAN:HAMMON/ TOOLPUSHER:TIEDEMANN/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 6 8.50 PDC 13.0/13.0113.0/0.0/0.0/0.0/0.0/0.0 4.055.00 32.74 123.85 3,965.00 8,020.00 130543 6 8.50 PDC 13.0/13.0/13.0/0.0/0.0/0.0/0.0/0.0 4,055.00 32.74 123.85 3,965.00 8,020.00 130543 GPM: 550.59 WOB: 10.00 NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: 95_00 PRES:3.340.00 1 CONTINENTAL 5.00 115.00 278.93 95.00 10.00 TORO:4 00 SPR: ss 300 2 CONTINENTAL 5.00 112.00 271 66 95.00 10.00 AVDP: 4.00 AVDC:6.75 MUDWT: 9A VISC: 76 PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:9.o0 STR WT: 150 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 132 SLACK-OFF WT: 125 JAR HOURS: 41_50 SHOCK-SUB HRS coo BHA HRS: 0.00 1 BIT 8.5 1.00 DP 4 14.00 S-135 376; 1 MOTOR,MUD 7 26.39 DP ON LOCATION 1 INTEGRAL BLADE 6.86 5.62 1 DM COLLAR 6.75 9:20 DC ON DC 4 3/4 NC35 SPIRAL 9: 1 MWD 6.78 1.32 LOCATION 1 DGR 6.75 3.88 1 SUB,X-OVER 6.75 12.61 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 HCIM 6.75 7.84 CASING 9625 3851 13.20 4,550.000 0 1 PWD 6.75 12.88 BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION 1 HOC 6.9 9,16 CONN GAS: 0.00 1 SUB,FLOAT 6.75 2.64 SURV GAS 0.00 3 FLEX JOINT,NON-MAGNE 6.79 93.12 TRIP GAS: 0.00 BOP TEST 11 Apr 2012 1 SUB,X-OVER 6 2.46 6 4"HWDP 4 183.13 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 829.05 00:00 11:59 11 98 2A ROTARY DRILLING;SPRa€r S TAKEN©07:00 HRS,MD 6756aEf.,TVD 675450.,#1(81 2 BPM 320 PSI,3 BPM 420 76 STANDS DP 0 7149.88 PSI,#2 a 2 BPM 320 PSI,3 BPM 440 PSI, ()SINGLES 0 0 11:59 12:00 0.02 2.A ROTARY DRILLING;DRILL F/6180',T/7132',WOB=10 K,GPM=546,SPM=226,PSI ON=3000,PSI OFF=2700, ()KELLY DOWN 0 41.1 RPM=95,TO ON=3.6K,TO OFF=1.3K,UWT=140K, TOTAL 8020.03 SOW=135K,ROT=135K,9.72CECD;10.01AECD AST=0, REMARKS ART=7.94,ADT=7.94,JARS=32.68,BIT=24.61, . . . - - 12:00 23:59 11.98 2.A ROTARY DRILLING DRILL F/7132',T/8020',WOB= 10K,GPM=550,SPM=226,PSI ON=3440,PSI OFF=3200, RPM=95,TO ON=4.0KK,TO OFF=1.5K,UWT=155K, SOW=150K,ROT=150K,9.8CECD:10.09AECD AST=O, PJSM BEFORE TASK;C-O-M;FUNCTION BOPS€T""S; ART=8.87,ADT=8.87,JARS=41.55,BIT=33. 23:59 00:00 0.02 2.A ROTARY DRILLING SPR @ 7696'MD/7695'TVD SPR#1 @ 2BBL/MIN=300;3 BBL/MIN=400 SPR#2©2BBL/MIN=300;3 BBL/MIN=400 ANTICIPATED 24 HOUR OPERATION COM/FOM: ACCUM PRESS.: SWIVEL HRS: 201.00 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 13 MECH./ELEC MILTON PEERY NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3684 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00:00 RIG RELEASE DATE: 07 Jun 2012 TIME:00_00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:16-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334568488921_NADDaily_sgl. Page 1 of 2 RIG NO.:7ES DATE:15 Apr 2012 WELL: A1070 007ES-RED WOL DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 JARS,HYDRAULIC 6.87 31.35 14 4"HWDP 4 426.45 Report Date:16-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334568488921_NADDaily_sql. Page 2 of 2 DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:16 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:16 DSS: 13 EST DAYS LEFT 52 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 1,547 PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LU CONTRACTOR:NABORS ALASKA DRILL DEPTH: 9 379 24 HRS ROP:207.40 CUM ROT.HRS: 235.50 CO MAN:HAMMON/ TOOLPUSHER:TIEDEMANN/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 6 8.50 PDC 13.0/13.0/13.0/0.0/0.0/0.0/0.0/0.0 5.414.00 40.20 139.36 3.965.00 9.379.00 130543 6 8.50 PDC 13.0/13.0/13.0/0.0/0.0/0.0/0.0/0.0 5,414.00 40.20 139.36 3,965.00 9,379.00 130543 GPM: 548.16 WOB: 12_06 NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: 95_00 PRES:4.050.00 1 CONTINENTAL 5.00 115.00 27893 95.00 10.00 TORO:5.40 SPR: 35 /480 2 CONTINENTAL 5.00 111.00 269.23 95.00 10.00 AVDP: 4.06 AVDC:6.i5 MUD WT: 9.5 VISC: 70 PH: WL: PV/YP: / SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.00 STR WT: 155 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 132 SLACK-OFF WT: 125 1 BIT 8.5 1.00 JAR HOURS: 54.45 SHOCK-SUB HRS 6.09 BHA HRS: 0.00 1 MOTOR,MUD 7 26.39 DP ON DP 4 14.00 S-135 376; LOCATION 1 INTEGRAL BLADE 6.86 5.62 1 DM COLLAR 6.75 9.20 DC ON DC 4 3/4 NC35 SPIRAL 9; 1 MWD 6.78 1.32 LOCATION 1 DGR 6.75 3.88 1 SUB,X-OVER 6.75 12.61 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 HCIM 6.75 7.84 CASING 9625 3851 13.20 4,550.000 0 1 PWD 6.75 12.88 BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION 1 HOC 6.9 9.16 CONN GAS: o.00 1 SUB,FLOAT 6.75 2.64 SURV GAS 000 3 FLEX JOINT,NON-MAGNE 6.79 93.12 TRIP GAS: 0.00 • BOP TEST 11 Apr 2012 1 SUB,X-OVER 6 2.46 6 4"HWDP 4 183.13 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 829.05 00:00 11:59 11.98 2.A ROTARY DRILLING SPRa€T"'S TAKEN 009:00 HRS,MD 8637a€T'",TVD 8635a€T"",#1(a1 2 BPM 360 PSI,3 BPM 470 90 STANDS DP 0 8466.66 PSI,#2 t6a 2 BPM 340 PSI,3 BPM 450 PSI, OSINGLES 0 0 11.59 12:00 0.02 2.A ROTARY DRILLING;DRILL F/8020',T/8825',WOB=12 OKELLY DOWN 0 83.29 K,GPM=550,SPM=226,PSI ON=3830,PSI OFF=3599, RPM=95,TQ ON=4.5K,TO OFF=1.6K,UWT=165K, TOTAL 9379 SOW=160K,ROT=160K,9.8CECD;10.19AECD AST=O, REMARKS ART=8.89,ADT=42.15,JARS=50.44,BIT=42.15, 12:00 22:00 10.00 2.A ROTARY DRILLING DRILL F/8637',T/9379',WOB=12K, GPM=550,SPM=226,PSI ON=4050,PSI OFF=3695, RPM=95,TQ ON=5.3K,TO OFF=1.6K,UWT=175K, SOW=167K,ROT=164K,9.8CECD;10.26AECD AST=1.44, PJSM BEFORE TASK;C-O-M; _ ART=6.02,ADT=7.46,JARS=54.45,BIT=49.61, 22:00 23:00 1.00 7.0 CHANGE/REPLACE PUMP EXPENDABLES CHANGE SUCTION GASKET,FOUND CRACKED FLUID END 23:00 00:00 1.00 51) CIRCULATE AND CONDITION GPM=250,PSI=1170,BUILD SWEEP,SPR=;1 @ 2BPM=350 PSI;3BPM=480 PSI; #2©2BPM=340 PSI;3BPM=480 PSI @9107MD;9105TVD; ANTICIPATED 24 HOUR OPERATION COM/FOM: ACCUM PRESS.: SWIVEL HRS: 248.00 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1 : #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 13 MECH./ELEC MILTON PEERY NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3685 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00:00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 20.12 TIME: 00:00 Report Date:17-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334651158453_NADDaily_sgl. Page 1 of 2 RIG NO.:7ES DATE:16 Apr 2012 WELL: A1070 007ES-RED WOL. DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 JARS,HYDRAULIC 6.87 31.35 14 4"HWDP 4 426.45 Report Date:17-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334651158453_NADDaily_sgl. Page 2 of 2 DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:17 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:17 DSS: 14 EST DAYS LEFT 51 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG PROPOSED DEPTH: 12.100 OPERATOR: SAVANT ALASKA LL(CONTRACTOR:NABORS ALASKA DRILL DEPTH: 9 379 24 HRS ROP: CUM ROT.HRS: 235.50 CO MAN:HAMMON/ TOOLPUSHER:TIEDEMANN/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 6 8.50 PDC 13.0/13.0/13.0/0.0/0.0/0.0/0.0/0.0 5,414.00 49.60 109.15 3,965.00 9,379.00 130543 6 8.50 PDC 13.0/13.0/13.0/13.0/13.0/13.0/13. 5,414.00 49.60 109.15 3,965.00 9,379.00 130543 GPM: 536.04 WOB: NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: 45.00 PRES:3,535.00 1 CONTINENTAL 5.00 119.00 28864 95.00 10.00 TORQ:Ea SPR: 35 /480 2 CONTINENTAL 5.00 102.00 247.40 95.00 10.00 AVDP:LEE AVDC:ELE MUD WT: 9,5 VISC: PH: WL: PV/YP: / SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:000 STR WT: 0 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: .5 SLACK-OFF WT: 1 1 BIT 8.5 1.00 JAR HOURS: 54.45 SHOCK-SUB HRS Q00 BHA HRS: 000 1 MOTOR,MUD 7 26.39 DP ON DP 4 14.00 S-135 376; LOCATION 1 INTEGRAL BLADE 6.86 5.62 1 DM COLLAR 6.75 9.20 DC ON DC 4 3/4 NC35 SPIRAL 9; 1 MWD 6.78 1.32 LOCATION 1 DGR 6.75 3.88 1 SUB,X-OVER 6.75 12.61 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 HCIM 6.75 7.84 CASING 9625 3851 13.20 4,550.000 1 PWD 6.75 12.88 BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION 1 HOC 6.9 9.16 CONN GAS: 4.Q _ 1 SUB,FLOAT 6.75 2.64 SURV GAS 4.911 3 FLEX JOINT,NON-MAGNE 6.79 93.12 TRIP GAS: 0.00 BOP TEST 11 Apr 2012 1 SUB,X-OVER 6 2.46 6 4"HWDP 4 183.13 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 829.05 00:00 01:30 1.50 5.D CIRCULATE AND CONDITION;CIRC/11.0 PPG WEIGHTED HI VIS SWEEP 90 STANDS DP 0 01:30 07:59 6.48 6.8 TRIP OUT OF HOLE;PJSM MONT HOLE F/5 MIN.POOH 0 SINGLES 0 0 F/9378'T/3838'UWT 175K SOW 167K.TIGHT SPOTS @ 0 KELLY DOWN 0 8180'25K OVER.8130'&8072,35K OVER PULL 5 X'S BR/F/8166'T/7918',250 GPM,1100 PSI 50 RPM 1.4 I TOTAL TO. _ REMARKS 07:59 08:00 0.02 6.1 WORKING PIPE/TIGHT SPOT;CONT T/POOH, PULL 25K OVER @ 7920',7807',7743',7564',7544',7530',7518', 7460',7372',7260',7149',7140',7113',7086',6997', 6787',WAS ABLE T/WORK THROUGH TIGHT SPOTS,MONT PJSM BEFORE TASK;C-O-M;FUNCTION BOPS€*'"S; HOLE @ SHOE PUPM DRY JOB. 08:00 10:00 2.00 6.B TRIP OUT OF HOLE;CONT T/POOH F/3838'T/829',UWT 95K;SOW 95K;MONT HOLE F/5 MIN BEFORE PULLING__BHA THROUGH STACK. 10:00 12:00 2.00 6.13 LAY DOWN BHA;PJSM LD/BHA,STND BACK HWDP&FLEX COLLARS,DOWN LOAD MWD TOOL,PULL UP DRAIN MOTOR BRAKE BIT. 12:00 12:30 0.50 22.D PRE JOB SAFETY PJSM W/HALLIBURTON&RIG CREW ON ANTICIPATED 24 HOUR OPERATION LD BHA 12:30 14:00 1.50 6.D LAY DOWN BHA PJSM;UD BIT;MTR;CLEAN FLOOR 14:00 16:30 '2.50 5.1 CLEAN OUT MUD SYSTEM JOHNNY WHACK THE STACK SEVERAL TIMES DUE TO AMOUNT OF CLAY AROUND STACK COM/FOM: ACCUM PRESS.: SWIVEL HRS: 255.00 DAILY R&M$: TM: ATM: LOR: ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 13 MECH./ELEC MILTON PEERY NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3686 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00_00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:18-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334741355812_NADDaily_sgl. Page 1 of 2 RIG NO.:7ES DATE:17 Apr 2012 WELL: A1070 007ES-RED WOL Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS AND WEAR RING 16:30 1800 1.50 15.G PU TEST TOOLS RIG UP TO TEST BOP'S;INSTALL TEST PLUG;4"TEST JNT,4"TIW&DART 18:00 18:30 0.50 22.A DRILLS-BOP ETC FILL STACK&LINES W/H20,WELL KILL DRILL-PUMP THROUGH KILL LINE T/CHOKE MANIFOLD AND DEGASSER TOTAL OF 15BBLS,GPM=52 18:30 20:00 1.50 15.A TEST BOPS TEST BOP'S;250 LOW;4000 HIGH F/5MIN EACH;W/4"TEST JNT;TEST ANN 250 LOW;3500 HIGH- GOOD TEST 20:00 22:30 2.50 15.H LD TEST TOOL TEST ACCUMULATOR,INITAL PSI=,AFTER FUNCTIONING PSI=,200PSI INCREASE IN SEC,FULL RECOVERY IN SEC,AVERAGE BOTTLE PSI=,PULL 4"TEST JNT,RD TIW,BD TD 22:30 23:00 0.50 15.A TEST BOPS TEST BLINDS,250PSI LOW,4000PSI HI,F/ 5MIN EACH-GOOD TEST,CLOSING TIMES: ANNULAR=22SEC,TPR=7SEC,BLINDS=15SEC,BPR=6SEC, HCR KILL=1 SEC,HCR CHOKE=1SEC 23:00 00:00 1.00 15.H LD TEST TOOL RIG DOWN TEST EQUIPMENT;PULL TEST PLUG;BLOW DOWN CH MANIFOLD;CHOKE LINE;KILL LINE; DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 JARS,HYDRAULIC 6.87 31.35 14 4"HWDP 4 426.45 Ili Report Date:18-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334741355812_NADDaily_sql. Page 2 of 2 DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:18 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:18 DSS: 15 EST DAYS LEFT 50 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 71 PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LL(CONTRACTOR:NABORS ALASKA DRILL DEPTH: 9 450 24 HRS ROP: 71.00 CUM ROT.HRS: 237.50 CO MAN:HAMMON/ TOOLPUSHER:TIEDEMANN/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 7 8.50 DTX619M-D613.0/13.0/13.0/13.0/13.0/13.0/0.0/0. 71.00 1.00 71.00 9,379.00 9.450.00 127834 7 8.50 DTX619M-D613.0/13.0/13.0/13.0/13.0/13.0/0.0/0. 71.00 1.00 71.00 9.379.00 9.450.00 127834 GPM: 494.81 WOB; 8.00 NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: 85.00 PRES:41.&00 1 CONTINENTAL 5.00 110.00 266.81 95.00 10.00 TORO:5.10 SPR: 35 / 2 _CONTINENTAL 5.00 94.00 228.00 95.00 10.00 AVDP: 95.00 AVDC:9090_00 MUD WT: 9.6 VISC: PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.00 STR WT: 167 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 85 SLACK-OFF WT: 87 1 BIT 8.5 1.00 JAR HOURS: 55.45 SHOCK-SUB HRS 0.00 BHA HRS: 0.00 1 MOTOR,MUD 7 26.32 DP ON DP 4 14.00 S-135 376; LOCATION 1 INTEGRAL BLADE 6.86 5.62 1 DM COLLAR 6.75 9.21 DC ON DC 4 3/4 NC35 SPIRAL 9; 1 DGR 6.75 6.44 LOCATION 1 PWD 6.75 4.41 1 EWR-P4 6.75 16.52 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 HCIM 6.75 8.34 CASING 9.625 3851 13.20 4,550.000 0 1 ALD 6.75 14.22 BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION 1 CTN 6.75 13.85 CONN GAS: 0.00 1 HOC 6.9 9.84 SURV GAS 0.00 1 MWD 6.75 22.04 TRIP GAS: 0.00 BOP TEST 17 Apr 2012 1 FLOAT SUB 6.75 2.21 3 FLEX JOINT,NON-MAGNE 6.8 93.12 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 876 28 00:00 00:30 0.50 6.K INSTALL/REMOVE WEAR BUSHING;INSTALL WEAR DUSHINC 00:30 02:30 2.00 6.A TRIP IN HOLE;TIH WITH RTTS TOOL 6 STNDS HWDP 12 91 STANDS DP 4 8560.66 STNDS 4"HT 40 DP T/1688', 0 SINGLES 0 0 SET RTTS TEST TAM PORT COLLAR T/2000 PSI F/5MIN. 02:30 04:30 2.00 6.B TRIP OUT OF HOLE;POOH T/RTTS TOOL LD/TOOL. 0 KELLY DOWN 0 13.06 04:30 05:30 1.00 6.0 PICK UP BHA;PJSM RU/FLOOR T/PU BHA TOTAL 9450 05:30 09:30 4.00 6.0 PICK UP BHA;PU/BHA MU/BIT UP LOAD MWD TOOL. REMARKS LOAD NUKS. 09:30 12:00 2.50 6.A TRIP IN HOLE;TIH F/876',T/2381',UWT 80K;SOW 80K; 12,00 15:00 3.00 6.A TRIP IN HOLE;TIH F/2381'T/3791'UWT 80K;SOW 80K; PJSM BEFORE TASK;C-O-M; 15:00 15:30 0.50 22.D PRE JOB SAFETY PJSM W/RIG CREW ON CUT&SLIP - DRILL LINE 15:30 16:30 1.00 9.A CUT DRILLING LINE SLIP N CUT 110'DRILLING LINE; 16 WRAPS;INSPECT DRAW WORKS AND BRAKE PADS; -- _ 16:30 17:00 0.50 7.B SERVICE TOP DRIVE SERVICE TOP DRIVE;GREASE CHOKE MANIFOLD; 17:00 17:30 0.50 15.J TEST STANDPIPE MANIFOLD PSI TEST MUD PUMP#2 ANTICIPATED 24 HOUR OPERATION 4000PSI,LOOKS GOOD-NO LEAKS 17:30 18:00 0.50 20.A DIRECTIONAL SURVEYS SHALLOW HOLE TEST MWD, GPM=514,PSI=2369,-GOOD TEST 18:00 22:00 4.00 6.A TRIP IN HOLE RIH F/3791'T/9342;WASH DOWN EVERY COM/FOM: ACCUM PRESS.: SWIVEL HRS: 257.00 DAILY R&M$: TM: 0.00 ATM: 0.00 LOR: 0.00 ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M 5/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 13 MECH./ELEC MILTON PEERY NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3687 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00_00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:19-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334825360406_NADDaily_sgl. Page 1 of 2 RIG NO.:7ES DATE:18 Apr 2012 WELL A1070 007ES-RED WOL Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS 10TH STAND;420 GPM;2900 PSI;UWT=176;SOW=170; 22:00 00:00 2.00 2.A ROTARY DRILLING DRILL F/9379',T/9450',WOB=8K K, GPM=500,SPM=209,PSI ON=4050,PSI OFF=3800, RPM=85,TQ ON=5.1 K,TQ OFF=1.8K,UWT=176K, SOW=171K,ROT=168K,9.910ECD;10.39AECD ASTM, ART=1,ADT=1,JARS=55.45,BIT=1, DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 SUB,X-OVER 6 2.21 6 4"HWDP 4 183.13 1 JARS,HYDRAULIC 6.87 31.35 14 4"HWDP 4 426.45 Report Date:19-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334825360406_NADDaily_sgl. Page 2 of 2 r DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:19 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:19 DSS: 16 EST DAYS LEFT 49 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 1 397 PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LLI CONTRACTOR:NABORS ALASKA DRILL DEPTH: 10,847 24 HRS ROP: 77.58 CUM ROT.HRS: 297.46 CO MAN:HAMMON/ TOOLPUSHER:PERRY/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 7 8.50 DTX619M-D613.0/13.0/13.0/13.0/13.0/13.0/0.0/0. 1.468.20 19.01 77.23 9.379.00 10.847.20 127834 7 8.50 DTX619M-D613.0/13.0/13.0/13.0/13.0/13.0/0.0/0. 1,468.20 19.01 77.23 9,379.00 10.847.20 127834 GPM: 514.20 wog: 15.00 NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: 7.00 FRES:4.080.00 1 CONTINENTAL 5.00 106.00 25710 95.00 10.00 TORO:6.20 SPR: 35 /420 2 CONTINENTAL 5.00 106.00 257.10 95.00 10.00 AVDP: 95_00 AVDC:9090_00 - MUD WT: 9.5 VISC: PH: WL: PV/YP: / SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0,0o STR WT: 204 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 132 SLACK-OFF WT: 125 1 BIT 8.5 1.00 JAR HOURS: 7346 SHOCK-SUB HRS 0.00 BHA HRS: 0.00 DP ON 'DP 4 14.00 S-135 376; 1 MOTOR,MUD 7 26.32 ' LOCATION 1 INTEGRAL BLADE 6.86 5.62 1 DM COLLAR 6.75 9.21 DC ON DC 4 3/4 NC35 SPIRAL 9; 1 DGR 6.75 6.44 LOCATION 1 PWD 6.75 4.41 1 EWR-P4 6.75 16.52 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 HCIM 6.75 8.34 CASING 9625 3851 13.20 4,550.000 0 ' 1 ALD 6.75 14.22 BG GAS: 0.00 SURVEY DEPTH DEG. DIRECTION 1 CTN 6.75 13.85 CONN GAS: 0.00 1 HOC 6.9 9.84• SURV GAS 0.00 1 MWD 6.75 22.04 TRIP GAS: 0.00 BOP TEST 17Apr 2012 1 FLOAT SUB 6.75 2.21 3 FLEX JOINT,NON-MAGNE- 6.8 93.12 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 876.28 00:00 11:58 11.97 2.A ROTARY DRILLING;DRILL F/9450',T/10094',WOB=20 K,GPM=506,SPM=208,PSI ON=3920,PSI OFF=3627, 106 STANDS DP 4 9970.92 RPM=50,TO ON-5.5K,TO OFF=2.OK,UWT=185K, ()SINGLES 0 0 SOW=1BOK,ROT=180K,9.910ECD;9.99AECD AST=O, , ART=8.19,ADT=8.19,JARS=63.64,BIT=9.19, ()KELLY DOWN 0 0 11,58 12:00 0.03 2 A ROTARY DRILLING;SPRa€7"S TAKEN @ 10:00 HRS,MD TOTAL 10847.2 10,0016€70,TVD 9,999x€'"^,#1 @ 2 BPM 340 PSI,3 BPM REMARKS 480 PSI,#2 @ 2 BPM 360 PSI,3 BPM 480 PSI, MW=9.5PPG 12:00 23:59 11.98 2.A ROTARY DRILLING DRILL F/10094',1/10847',TVD= 10845';WOB=15K,GPM=515,SPM=213,PSI ON=4060, PSI OFF=3690,RPM=7,TO ON=6.2K,TO OFF=2.2K, PJSM BEFORE TASK;INSP DRK,C-O-M; UWT=204K,SOW=194K,ROT=190K,9.91 CECD;10.O6AECD AST=.3,ART=9.52,ADT=9.82,JARS=73.46,BIT=19.01 23:59 00:00 0.02 2.A ROTARY DRILLING SPR=;1 @ 2BPM=420 PSI; 3BPM=540 PSI;#2 @ 2BPM=400 PSI;3BPM=540 PSI@ 10565MD;10563 TVD,MW=9.5PPG ANTICIPATED 24 HOUR OPERATION COM/FOM: ACCUM PRESS.: SWIVEL HRS: 316.96 DAILY R&M$: TM: 0.00 ATM: 0.00 LOR: 0.00 ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 13 MECH./ELEC MILTON PEERY NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3688 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00_00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:20-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334912243406_NADDaily_sgl. Page 1 of 2 , RIG NO.:7ES DATE:19 Apr 2012 WELL: A1070 007ES-RED WOL DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 SUB,X-OVER 6 2.21 6 4"HWDP 4 183.13 1 JARS,HYDRAULIC 6.87 31.35 14 4"HWDP 4 426.45 Report Date:20-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334912243406_NADDaily_sgl. Page 2 of 2 I _ DAILY MORNING REPORT 1 LEASE:RED WOLF#2 RIG NO.:7ES DATE:20 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:20 DSS: 17 EST DAYS LEFT 48 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 523 PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LL( CONTRACTOR:NABORS ALASKA DRILL DEPTH: 11,370 24 HRS ROP: 54.97 CUM ROT.HRS: 314.48 CO MAN:HAMMON/ TOOLPUSHER:TIEDEMANN/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 7 8.50 DTX619M-D613.0/13.0/13.0/13.0/13.0/13.0/0.0/0. 2.376.00 37.07 64.09 9.379.00 11.755.00 127834 7 8.50 DTX619M-D613.0/13.0/13.0/13.0/13.0/13.0/0.0/0. 2,376.00 37.07 64.09 9,379.00 11,755.00 127834 GPM: 497.23 WOB: 14.00 NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: am PRES:3.995.00 1 CONTINENTAL 5.00 118.00 286.21 95.00 10.00 TORQ:6.40 SPR: 35 /440 2 CONTINENTAL 5.00 98.00 237.70 95.00 10.00 AVDP: 95_00 AVDC:9090_00 MUDWT: 9.6 VISC: PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.09 STR WT: 204 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 40.000 SLACK-OFF WT: 40,000 JAR HOURS: 8297 SHOCK-SUB HRS o.00 BHA HRS: 009. 1 BIT 8.5 1.00 DP 4 14.00 S-135 376; 1 MOTOR,MUD 7 26.32 DP ON LOCATION 1 INTEGRAL BLADE 6.86 5.62 1 DM COLLAR 6.75 9.21 DC ON DC 4 3/4 NC35 SPIRAL 9; 1 DGR 6.75 6.44 LOCATION 1 PWD 6.75 4.41 1 EWR-P4 6.75 16.52 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS 1 HCIM 6.75 8.34 CASING 9625 3851 13.20 4,550.000 0 1 ALD 6.75 14.22 BG GAS: 9.00 SURVEY DEPTH DEG. DIRECTION 1 CTN 6.75 13.85 CONN GAS: 0.00 1 HOC 6.9 9,84 SURV GAS o 00 1 MWD 6.75 22.04 TRIP GAS: 0.00 BOP TEST 17 Apr 2012 1 FLOAT SUB 6.75 2.21 3 FLEX JOINT,NON-MAGNE 6.8 93.12 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 876.28 00.00 11:59 11.98 2.A ROTARY DRILLING;DRILL F/10847',T/11370',W0B=14 __ --- K, _K,GPM=505,SPM=208,PSI ON=3995,PSI OFF=3706, 115 STANDS DP 4 10816.87 - RPM=B,TO ON=6.4K,TQ OFF=2.1K,UWT=208K, 0 SINGLES 0 0 SOW=200K,ROT=200K,9.910ECD;10.04AECD AST=O, ART=9.51,ADT=9.51,JARS=82.97,BIT=28.52, 0KELLY DOWN 0 61.85 11:59 12:00 _0.02 2.A ROTARY DRILLING;SPRa€r.S TAKEN Cad 03:30 HRS,MD TOTAL 11755 11035a€T"',TVD 110335E5.,#1(off 2 BPM 420 PSI,3 BPM 530 REMARKS PSI,#2 @ 2 BPM 410 PSI,3 BPM 540 PSI, 12:00 17.30 _5.50 2.A ROTARY DRILLING DRILL F/11370',T/11645',WOB=18 K,GPM=515,SPM=208,PSI ON=4080,PSI OFF=3780, RPM=6,TO ON=6.4K,TQ OFF=2.2K,UWT=215K, SOW=208K, PJSM BEFORE TASK'C-0-M• 17:30 18:30 • 1.00 5.0 CIRCULATE AND CONDITION CIRCULATE BUS=11200+; CHECK TO SEE IF IN NEW FORMATION;GPM=499;@3989 PSI; 18:30 23:59 5.48 2.A ROTARY DRILLING DRILL F/11645',T/11755",WOB=15 K,GPM=515,SPM=208,PSI ON=4130,PSI OFF=3840, RPM=30,TQ ON=6.5K,TQ OFF=2.3K,UWT=217K, SOW=208K,ROT=202K,9.810ECD;10.02AECD AST=O, I ANTICIPATED 24 HOUR OPERATION ART=8.55,ADT=8.55,JARS=91.52,BIT=37.07, 23:59 00:00 _0.02 2.A ROTARY DRILLING SPR=;1 @ 2BPM=440 PSI; 3BPM=600 PSI;#2 @ 2BPM=440 PSI;3BPM=600 PSI;@ 11599MD;11597 TVD;MW=9.6PPG COM/FOM: ACCUM PRESS.: SWIVEL HRS: 334.98 DAILY R&M$: TM: 0.00 ATM: 0.00 LOR: 0.00 ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN KNIGHTEN NO 16 MECH.IELEC MILTON PEERY NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3689 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00_00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 20.12 TIME: 00:00 Report Date:21-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334999369906_NADDaily_sgl. Page 1 of 2 • I ) RIG NO.:7ES DATE:20 Apr 2012 WELL: A1070 007ES-RED WOL DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 SUB,X-OVER 6 2.21 6 4"HWDP 4 183.13 1 JARS,HYDRAULIC 6.87 31.35 14 4"HWDP 4 426.45 • Report Date:21-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1334999369906_NADDaily_sgl. Page 2 of 2 DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:21 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:21 DSS: 18 EST DAYS LEFT 47 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 104 PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LL(CONTRACTOR:NABORS ALASKA DRILL DEPTH: 11,859 24 HRS ROP: 17.18 CUM ROT.HRS: 321.98 CO MAN:HAMMON/ TOOLPUSHER:PERRY/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 7 8.50 DTX619M-D613.0/13.0/13.0/13.0/13.0/13.0/0.0/0. 2,480.10 43.13 57.50 9,379.00 11,859.10 127834 7 8.50 DTX619M-D613.0/13.0/13.0/13.0/13.0/13.0/0.0/0. 2,480.10 43.13 57.50 9,379.00 11,859.10 127834 GPM: 468.13 wog: 20_00 NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: 10.00 PRES:4,150.00 1 CONTINENTAL 5.00 85.00 20617 95.00 10.00 TORO: SPR: 35 /465 2 CONTINENTAL 5.00 108.00 261.96 95.00 10.00 AVDP: 93.00 AVDC:96.00 MUD WT: 9.5 VISC: PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.00 STR WT: 0 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: 40.000 SLACK-OFF WT: 40,000 •JAR HOURS: 0.00 SHOCK-SUB HRS o.00 BHA HRS: o.00 1 BIT 8.5 1.00 DP 4 14.00 S-135 376; 1 MOTOR,MUD 7 26.32 DP ON •LOCATION 1 INTEGRAL BLADE 6.86 5.62 1 DM COLLAR 6.75 9.21 DC ON DC 4 3/4 NC35 SPIRAL 9; 1 DGR 6.75 6.44 LOCATION 1 PWD 6.75 4.41 1 EWR-P4 6.75 16.52 LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS CASING 9625 1 HCIM 6.75 8.34 3851 13.20 4,550.000 1 ALD 6.75 14.22 BG GAS: o.00 SURVEY DEPTH DEG. DIRECTION 1 CTN 6.75 13.85 CONN GAS: 0.00 1 HOC 6.9 9.84 SURV GAS 0.00 1 MWD 6.75 22.04 TRIP GAS: o.00 BOP TEST 17 Apr 2012 1 FLOAT SUB 6.75 2.21 FLEX JOINT,NON-MAGNE 6.8 93.12 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS 3 BHA SUB-TOTAL -876 28 00:00 07:30 7.50 2.A ROTARY DRILLING DRILL F/11755',T/11859', j WOB=15-30K,GPM=475,PSI ON=4150,PSI OFF=3800, STANDS DP RPM=10-30,TQ ON=6.5K,TQ OFF=2.3K,UWT=217K, OSINGLES 0 0. SOW=210K,ROT=207K, 9.86AECD AST=.5,ART=5.56, 0 KELLY DOWN ADT=6.06,JARS=95.58,BIT=43.13,SPR=;1 @ 2BPM =465PSI;3BPM=630PSI TOTAL 07:30 08:30 1.00 5.D CIRCULATE AND CONDITION-@ 11859'MD PUMP REMARKS BOTTOMS UP,476GPM,3882PSI,43RPM,2.5K TQ; SHUTDOWN PUMPS MONITOR WELL;(STATIC); 08:30 10:00 1.50 6.B TRIP OUT OF HOLE-POOH F/11859'T/10647'; UWT=200K;DWT=195K;MONITOR WELL;(STATIC);PUMP 2OBBL DRYJOB;B/D TOPDRIVE&REMOVE BLOWER HOSE PJSM BEFORE TASK;C-O-M;FUNCTION BOPa€* S; 10:00 12:00 2.00 6.B TRIP OUT OF HOLE-CONT.POOH F/10647'T/7500'; UWT=160K;DWT=160K • 12:00 14:00 2.00 6.8 TRIP OUT OF HOLE POOH F/7500 T/3850;UWT 160K; SOW 160K 14:00 17:00 3.00 6.F LAY DOWN DRILL PIPE POOH L/D DP 93 JTS F/3779' T/876';UWT=96K;SOW=96K;MONITOR WELL-STATIC 17:00 23:00 6.00 60 LAY DOWN BHA PJSM L/D BHA;POOH T/LAST FLEX ANTICIPATED 24 HOUR OPERATION COLLAR;PJSM T/PULL NUKE SOURCE;DOWNLOAD DATA PER MWD HAND;FINISH L/D BHA;CLEAN FLOOR; 23:00 00:00 1.00 6.A TRIP IN HOLE P/U PERFORATED BULL NOSE,RIH T/ ,' 2000' COM I FOM: ACCUM PRESS.: SWIVEL HRS: 343.48 DAILY R&M$: TM: 0.00 ATM: 0.00 LOR: 0.00 ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1 : #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN BUZBY NO 13 MECH./ELEC MILTON PEERY NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3690 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00:00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:22-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1335085966125_NADDaily_sgl. Page 1 of 2 I 1 • RIG NO.:7ES DATE:21 Apr 2012 WELL: A1070 007ES-RED WOL DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 SUB,X-OVER 6 2.21 64"HWDP 4 183.13 1 JARS,HYDRAULIC 6.87 31.35 14 4"HWDP 4 426.45 Report Date:22-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1335085966125_NADDaily_sgl. Page 2 of 2 1 11 Y DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:22 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:22 DSS: 19 EST DAYS LEFT 46 API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG 104 PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LU CONTRACTOR:NABORS ALASKA DRILL DEPTH: 11,859 24 HRS ROP: 17.18 CUM ROT.HRS: 321.98 CO MAN:HAMMON/ TOOLPUSHER:PERRY/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE GPM: WOB: NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: PRES: 1 CONTINENTAL 5.00 10.00 TORQ: SPR: 35 /465 2 CONTINENTAL 5.00 _ 10.00 AVDP: AVDC: MUD WT: 9.5 VISC: PH: WL: PV/YP: / SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.00 STR WT: 0 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: o SLACK-OFF WT: o 'JAR HOURS: 9595_58 SHOCK-SUB HRS o.00 BHA HRS: 43.13 1 BIT 8.5 1.00 DP 4 14.00 S-135 376; 1 MOTOR,MUD 7 26.32 DP ON LOCATION 1 INTEGRAL BLADE 6.86 5.62 1 DM COLLAR 6.75 9.21 DC ON DC 4 3/4 NC35 SPIRAL 9; 1 DGR 6.75 6.44 LOCATION 1 PWD 6.75 4.41 1 EWR-P4 6.75 16.52 LAST SIZE SET AT SHOE TEST PROPOSED TO ACCUM HRS 1 HCIM 6.75 8.34 CASING 9 625 3851 13.20 4,550.000 0 1 ALD 6.75 14.22 BG GAS: o.00 SURVEY DEPTH DEG. DIRECTION 1 CTN 6.75 13.85 CONN GAS: o.00 1 HOC 6.9 9.84 SURV GAS o.00 1 MWD 6.75 22.04 TRIP GAS: o.90 BOP TEST 17 Apr 2012 1 FLOAT SUB 6.75 2.21 3 FLEX JOINT,NON-MAGNE' 6.8 93.12 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 876 28 00:00 02:30 2.50 6.A TRIP IN HOLE-HOLD PJSM;RIH F/2000'T/3872'; UWT=90K;DWT=90K 115STANDS DP 0 0 02:30 05:00 2.50 6.E PICK UP DRILL PIPE-HOLD PJSM;RIH W/4"HT4ODP 0 SINGLES 0 0 SINGLES F/PIPESHED;F/3872'MD T/7258'MD; OKELLY DOWN 0 0 UWT=123K;DWT=123K;BREAKING CIRCULATION EVERY 2000'UNTIL RETURNS ARE OBSERVED; TOTAL 876.28 05:00 07:00 2.00 6.A TRIP IN HOLE-CONT.RIH W/PIPE IN DERRICK REMARKS F/7258'MD T/11856'MD;UWT=195K;DWT=175K; 07:00 08:00 1.00 12.K INSTALL CMNT LINES-L/D TOP SINGLE STAND#126: P/U 25'PUP;HOLD PJSM;R/U TO CEMENT;M/U PUMP IN SUB&MANIFOLD;BLOW AIR TO SLB CEMENTERS;INSTALL CEMENT HOSE PJSM BEFORE TASK;C-O-M; 08:00 09:30 1.50 5.D CIRCULATE AND CONDITION-ATTEMPT TO CIRCULATE BOTTOMS UP;15SPM 1550PS1;PARTIAL RETURNS;S/D PUMPS BREAK OUT HEADPIN;M/U TD PUMP BUS WHILE RECIPROCATING PIPE;11,423STKS;@ 250GPM;1150PSI: 09:30 12:00 2.50 12.0 PRIMARY CEMENTING-HOLD PJSM;OPEN HOLE CMT PLUT SET F/11859',T/11234',SLB PUMP 2BBL H20;PT LINES T/3000PSI;PUMP 1OBBL H2O SPACER;4OBBLS ANTICIPATED 24 HOUR OPERATION 15.8PPG CMT;WASH UP LINES;DROP WIPER BALL; DISPLACE CEMENT W/RIG PUMPS 225GPM;378PSI; 12:00 13.00 1.00 6.B TRIP OUT OF HOLE POOH FROM 11850'T/10790'UWT= 200K;SOW=195K; COM/FOM: ACCUM PRESS.: SWIVEL HRS: 346.48 DAILY R&M$: TM: 0.00 ATM: 0.00 LOR: 0.00 ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN BUZBY NO 13 MECH./ELEC MILTON PEERY NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3691 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00:00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:23-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1335170173000_NADDaily_sgl. Page 1 of 2 $ i I r RIG NO.:7ES DATE:22 Apr 2012 WELL: A1070 007ES-RED WOL. Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS 13:00 13:30 0.50 5.L SPOT PILL PUMP 10 BBL DRY JOB;170 GPM.600 PSI. B/D TOP DRIVE 13:30 15:30 2.00 6.B TRIP OUT OF HOLE PJSM;POOH F/10790'T/7966'; UWT=175K;SOW=170K; 15:30 22:30 7.00 6.F LAY DOWN DRILL PIPE PJSM;POOH;LDDP;F/7966'T/ 14';LD PERFORATED BULL NOSE;UWT 135K;SOW 132K; CLEAN RIG FLOOR 22:30 00:00 1.50 6.A TRIP IN HOLE MAKE UP BHA;RIH WITH CMNT RETAINER: PER BAKER REP;TRIP T/1100'; 907 MIN;PER BAKER REP; DRILLING ASSEMBLY OVERFLOW NO ITEM SIZE LENGTH 1 SUB,X-OVER 6 2.21 6 4"HWDP 4 183.13 1 JARS,HYDRAULIC 6.87 31.35 14 4"HWDP 4 426.45 Report Date:23-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1335170173000_NADDaily_sgl. Page 2 of 2 1 M DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:23 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:23 DSS: 20 EST DAYS LEFT API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LLI CONTRACTOR:NABORS ALASKA DRILL DEPTH: 11,859 24 HRS ROP: CUM ROT.HRS: 321.9_8 CO MAN:HAMMON/ TOOLPUSHER:PERRY/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE 7 8.50 DTX619M-D613.0/13.0/13.0/13.0/13.0/13.0/0.0/0. 2.480.10 43.13 57.50 9.379.00 11.859.10 . 127834 GPM: WOB: NO. PUMP MFG LINER SPM PRES GPM RPR STRK RPM: PRES: 1 CONTINENTAL 5.00 10.00 TORO: SPR: ss /465 2 CONTINENTAL 5.00 10.00 AVDP: AVDC: - - MUD WT: 8.4 VISC: PH: WL: PV/YP: I SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.00 STR WT: 0 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: aoao aoo SLACK-OFF WT: 40,000 JAR HOURS: o.99 SHOCK-SUB HRS 0.00 BHA HRS: 0 00 1 0 0.00 DP ON DP 4 14.00 S-135 376; LOCATION DC ON DC 4 3/4 NC35 SPIRAL 9; LOCATION LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS CASING s 625 3851 13.20 4,550.000 0 BG GAS: o.00 SURVEY DEPTH DEG. DIRECTION CONN GAS: 0.00 SURV GAS o.00 TRIP GAS: 0.00 BOP TEST 17 Apr 2012 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 00:00 01:30 1.50 6.A TRIP IN HOLE-CONT.RIH F/1100'MD T/3777'; RUNNING SPEED 90FT/MIN;UWT=75K;DWT=75K;M/U TD STANDS DP - &SET RETAINER PLUG AS PER BAKER REP @ 3777' SINGLES 01.30 02:00 0.50 12.8 INSTALL CMNT LINES M/U HEAD PIN&CEMENT MANIFOLD KELLY DOWN -- - TI STRING;INTALL CMT HOSE;FILL LINES 02:00 02:30 _0.50 12E'PRESSURE TEST CSG/SHOE PSI TEST CSG AND CMT TOTAL ,RETAINER THROUGH KILL AGAINST TPR,2200PSI F/ REMARKS -- 15MIN-GOOD TEST 02:30 03.30 1.00 12.J CIRCULATE/CEMENT/DISPLACE BLOW AIR T/SLB . CEMENTERS;P/U&UNSTING F/RETAINER;SLB FLOOD LINES W/H2O&PT T/3000PSI;RE-STING INTO _ RETAINER&SLACK OFF 50K TO CONFIRM SET PJSM BEFORE TASK;C-O-M;FUNCTION BOPS€T"S; 03:30 04:00 0.50 12 F CEMENT PLUGS-SLB CEMENTERS PERFORM LOT 1500PSI _ @ 3BPM;EMW=16.4PPG;PERFORM BULLHEAD CEMENT SQUEEZE AS PER SLB CEMENTERS; 04:00 04:30 0.50 12.J CIRCULATE/CEMENT/DISPLACE;DISPLACE CEMENT W/ RIG PUMPS;2BPM @ 440PSI;PUMP 35 BBLS&SHUTDOWN; UNSTING F/RETAINER;DUMP 50'CMT ON TOP OF RETAINER;R/D CEMENT MANIFOLD;LID 6 JTS.T/ ANTICIPATED 24 HOUR OPERATION _3594MD&DROP WIPER BALL -- - 04:30 05:00 _0.50 12.J CIRCULATE/CEMENT/DISPLACE-M/U T/D;DISPLACE DP WIPER&CIRCULATE BUS;460GPM;1150PSI;UWT=72K; DWT=72K;3783 STKS TOTAL;52%RETURN FLOW COM/FOM: ACCUM PRESS.: SWIVEL HRS: 346.48 DAILY R&M$: TM: 0.00 ATM: 0.00 LOR: 0.00 ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: 0.00 FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN BUZBY NO 13 MECH./ELEC MILTON PEERY NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3692 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00_00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:24-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1335263865156_NADDaily_sgl. Page 1 of 2 RIG NO.:7ES DATE:23 Apr 2012 WELL: A1070 007ES-RED WC Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS 05:00 08:30 3.50 6.F LAY DOWN DRILL PIPE-RACK BACK 1 STD.IN DERRICK;B/D TOPDRIVE;INSTALL STRIPPING RUBBERS& CONT POOH UD REMAINDER OF 4"DP 08:30 09:00 0.50 6.D LAY DOWN BHA-UD RUNNING TOOL&CROSSOVER AS PER BAKER REPS 09:00 09:30 0.50 6.0 PICK UP BHA-M/U BAKER CIBP W/RUNNING TOOL AS PER BAKER REP 09:30 10:00 0.50 6.A TRIP IN HOLE-RIH ON 4"DP T/205'MD;HYDRAULIC SET CIBP AS PER BAKER REP;DROP BALL PRESSURE UP T/1200PSI;BLEED T/400PSI;PULL 50K;SLACK OFF 15K TO CONFIRM SET;R/U HEAD PIN&CEMENT MANIFOLD;BLOW AIR T/SLB CEMENTERS 10:00 11:00 1.00 12.F CEMENT PLUGS-PUMP CEMENT ON TOP OF CIBP AS PER SLB CEMENTERS;FLOOD LINES&PT T/3000PSI; DISPLACE WELL T/H20;PUMP 13BBLS 15.7PPG CEMENT; TOC @ 45';WASH UP THRU TEE ON FLOOR&PUMP.4BBLS DOWN DP; 11:00 11:30 0.50 12.J CIRCULATE/CEMENT/DISPLACE (RACK BACK 1 STD.UD 2 JTS.);R/U CEMENT MANIFOLD &HEAD PIN;SLB CEMENTERS DISPLACE W/3OBBLS (RETARD CEMENT RETURNS) 11:30 12:00 0.50 12.J CIRCULATE/CEMENT/DISPLACE-RIH W/4"DP&FLUSH W/RETARDANT PILL;FLUSH CEMENT MANIFOLD 12:00 13:00 1.00 6.K INSTALUREMOVE WEAR BUSHING PJSM;P/U SINGLE D/P; M/U XO TO W/R PULLER;PULL WEAR RING;CLEAN FLOOR; 13:00 18:00 5.00 14.0 CHANGE RAMS PJSM;REMOVE ALL RAMS PER STACK OUT PROCEDURE;CLOSE BOP DOORS AND TIGHTEN 18:00 00:00 6.00 14.B NIPPLE DOWN BOPS PJSM;PULL RISER;PREPARE STACK FOR SPLITTING;MADE ALL BREAKS ON STACK;RD KILL LINE Report Date:24-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1335263865156_NADDaily_sgl. Page 2 of 2 DAILY MORNING REPORT LEASE:RED WOLF#2 RIG NO.:7ES DATE:24 Apr 2012 WELL: A1070 007ES-RED WOLF 2 DAY#:24 DSS: 21 EST DAYS LEFT API#: 50-029-23465-00 CONTRACT: DAY WORK 24 HR FTG PROPOSED DEPTH: 12,100 OPERATOR: SAVANT ALASKA LL(CONTRACTOR:NABORS ALASKA DRILL DEPTH: 11,859 24 HRS ROP: CUM ROT.HRS: 321.98 CO MAN:MCINNIS TOOLPUSHER:PERRY/BARR PRESENT ACTIVITY: CO-MAN PHONE: RIG PHONE: 907-659-0633 BIT SIZE TYPE NOZZLES FEET HRS ROP DEPTH IN DEPTH OUT SN/GRADE GPM: WOB: NO. PUMP AVG LINER SPM PRES GPM RPR STRK RPM: PRES: 1 CONTINENTAL 5.00 _ 10.00 TORO: SPR: se /acs 2 CONTINENTAL 5.00 • 10.00 AVDP: AVDC: MUD WT: VISC: PH: WL: PV/YP: / SOLIDS: SAND: OIL: CHL: FORMATION: DRILLING ASSEMBLY(At end of Tour) EFF BHA WT:0.00 STR WT: 0 BHA INSP NO. ITEM SIZE LENGTH PICK-UP WT: o SLACK-OFF WT: o 1 0 0.00 JAR HOURS: 0.00 SHOCK-SUB HRS 0.00 BHA HRS: o.00 DP ON DP 4 14.00 S-135 376; LOCATION DC ON DC 4 3/4 NC35 SPIRAL 9; LOCATION LAST SIZE SET AT SHOE TEST PROPOSED TD ACCUM HRS CASING 9625 3851 13.20 4,550.000 0 BG GAS: o.00 SURVEY DEPTH DEG. DIRECTION CONN GAS: 0.00 SURV GAS oea TRIP GAS: 0.00 BOP TEST 17 Apr 2012 FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS BHA SUB-TOTAL 00:00 02:00 2.00 14.8 NIPPLE DAWN BOPS-HOLD PJSM;RACK STACK BACK;RD DSA,TBG SPOOL;&SPEED HEAD;REMOVE SPOOLS FROM STANDS DP CELLAR; SINGLES 02:00 03:30 1.50 6.E PICK UP DRILL PIPE-HOLD PJSM;P/U 2 SINGLES& KELLY DOWN HT40 BOX X 4 1/2 IF PIN X-OVER;M/U 8 1/2"CUTTER W/3 1/2"BLADES AS PER BAKER REP;RIH T/35';M/U TOTAL TOPDRIVE&CUT 9 5/8 CASING 4.4'BELOW GROUD REMARKS LEVEL;RPM=60;STAGE PUMPS HELD 600PSI ON MECHANICAL CUTTER WHILE CUTTING 03:30 04.30 1.00 6.B TRIP OUT OF HOLE-POOH W/CUTTER L/D&FLUSH CUTTER;PULL MASTER BUSHINGS&PICK 9 5/8 CUT JT. &FLUTED MANDREL HANGAR T/RIG FLOOR PJSM BEFORE TASK;C-O-M;FUNCTION BOPS€"S; 04:30 06:30 2.00 7.A SERVICE RIG -INSTALL CATCH ALL RISER&AIR UP BOOT;HOLD PJSM;REMOVE WASHPIPE PACKING AS PER PROCEDURE;L/D;GREASE&COVER PACKING THREADS ON T/D 06:30 07:30 1.00 7.8 SERVICE TOP DRIVE-LOWER T/D TO RIGFLOOR&CLEAN W/WASH DOWN GUN;PLACE LANDING JTS.&TEST JTS. IN PIPESHED iai/4 07:30 09:00 1.50 14.J PREPARE CELLAR AND WELLHEAD-WELDER CUT 20" ANTICIPATED 24 HOUR OPERATION CONDUCTOR OFF 3.75'BELOW GROUND LEVEL;REMOVE CONDUCTOR FROM CELLAR&FILL 9 5/8 CSG&20" CONDUCTOR W/CEMENT T/1'BELOW 20"CONDUCTOR COM/FOM: ACCUM PRESS.: SWIVEL HRS: 346.48 DAILY R&M$: TM: 0.00 ATM: 0.00 LOR: 0.00 ACCUM R&M$: 0.00 KILL SWITCHES-#1 : #2: #3 #4: #5: AVG R&M$/DAILY: 0.00 ENGINE KW-#1: #2: #3 #4: #5: MUD COST DAILY: FUEL USED: CUM FUEL USED FUEL ON RIG: CUM.MUD COST: 0.00 ACCIDENTS?: NO CREW SHORT: 0 ROTATE MSHL(YES/NO): WEATHER:WIND: SEAS: DRILLERS: OBM: CREW JUSTIN BUZBY NO 13 MECH./ELEC MILTON PEERY NO 10 PROBLEMS: TOP DRIVE INSTALLED? YES DOWN TIME: SER#:2005452 SAFETY MEETING TOPIC DAYS NLTA: 3693 RIG ON COMPANY DATE: TIME: TOP DRIVE ON COMPANY 01 Apr 2012 TIME: 00:00 RIG RELEASE DATE: 07 Jun 2012 TIME:00:00 TOP DRIVE RELEASE 30 May 2012 TIME: 00:00 Report Date:24-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1335338170984_NADDaily_sgl. Page 1 of 2 1 • F r' RIG NO.:7ES DATE:24 Apr 2012 WELL: A1070 007ES-RED WO, Time Detail Continued FROM TO HRS CDE DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS 09:00 10:30 1.50 1.A MOBILIZATION-HOLD PJSM;CLEAN AND CLEAR RIGFLOOR;REMOVE HANDLING EQUIP;RIG TONGS&SUBS FROM RIGFLOOR;SECURE ROUGHNECK;INSTALL A-LEG BRACE; 10:30 12:00 1.50 1.A MOBILIZATION N-HOLD PJSM;PULL STEAM TABLES AND CLEAN W/SUPERSUCKER;CLEAN UNDERNEATH SKATE SUMP; 12:00 21:00 9.00 1.B DEMOBILIZATION PJSM;PULL ROTARY TABEL COVER AND CLEAN UNDER ROTARY TABEL AND DW 21:00 23:59 2.98 1.8 DEMOBILIZATION BD STEAM&H2O IN PITS,DISCONNECT INTERCONECT,PJSM W/PEAK&RIG CREW,PULL PITS AWAY F/RIG,STAGE ON PAD,HOOK JEEP UP,REINSTAL ROTARY TABEL COVER,PREP FLOOR F/LD DRK,REMOVE BAILS 23:59 00:00 0.02 1.8 DEMOBILIZATION RIG RELEASED A@ 23:59 HRS,F/RED WOLF#2,T/GO TO THE NAD YARD AND STACK { Report Date:24-Apr-2012 Copyright(c)2012 by Canrig Drilling Technology Ltd.All Rights Reserved. 1335338170984_NADDaily_sgl. Page 2 of 2 Savant Red Wolf Exploration Red Wolf#2 API: 50-029-23465-00 / PTD: 212-019 Sperry Drilling Services Definitive Survey Report 03 May, 2012 1111110 HALLIBURTON AMIE Sperry Drilling Services Halliburton Company Definitive Survey Report Company: Savant Local Co-ordinate Reference: Well Red Wolf 2 Project: Red Wolf TVD Reference: Red Wolf#2 Actual @ 35.50ft(7-ES 29.1 KB-ICE/1.9' Site: Exploration MD Reference: Red Wolf#2 Actual @ 35.50ft(7-ES 29.1 KB-ICE/1.9' Well: Red Wolf 2 North Reference: True Wellbore: Red Wolf#2 Survey Calculation Method: Minimum Curvature Design: Red Wolf#2 Database: .AK_PRD16 Project Red Wolf Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 03 Using geodetic scale factor Well Red Wolf 2 a Well Position +N/-S 0.00 ft Northing: 5,914,755.67 ft Latitude: 70.174231 +E/-W 0.00 ft Easting: 349,352.14 ft Longitude: -147.212720 Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 4.50 ft Wellbore Red Wolf#2 Magnetics Model Name Sample Date Declination Dip Angle .Field Strength (°) (°) (nT) BGGM2011 4/9/2012 21.67 81.10 57,692 Design Red Wolf#2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 31.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 31.00 0.00 0.00 90.76 I I Survey Program Date 5/17/2012 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 220.69 3,851.00 MWD+SC(Red Wolf#2) MWD+SC Fixed:v2:standard dec&axial correction 03/30/2012 3,851.00 11,790.62 MWD+SC(Red Wolf#2) MWD+SC Fixed:v2:standard dec&axial correction 03/30/2012 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/1001 (ft) Survey Tool Name 31.00 0.00 0.00 31.00 -4.50 0.00 0.00 5,914,755.67 349,352.14 0.00 0.00 UNDEFINED 220.69 0.12 106.15 220.69 185.19 -0.06 0.19 5,914,755.61 349,352.33 0.06 0.19 MWD+SC(1) 444.93 0.09 182.97 444.93 409.43 -0.30 0.41 5,914,755.37 349,352.54 0.06 0.41 MWD+SC(1) 501.22 0.09 247.51 .501.22 465.72 -0.36 0.36 5,914,755.31 349,352.50 0.17 0.37 MWD+SC(1) 591.95 0.25 235.81 591.95 556.45 -0.50 0.13 5,914,755.17 349,352.26 0.18 0.14 MWD+SC(1) 684.24 0.20 123.92 684.24 648.74 -0.70 0.10 5,914,754.97 349,352.23 0.41 0.11 MWD+SC(1) 777.79 0.40 68.51 777.79 742.29 -0.67 0.54 5,914,754.99 349,352.67 0.35 0.55 MWD+SC(1) 876.91 0.31 39.69 876.91 841.41 -0.34 1.03 5,914,755.31 349,353.17 0.20 1.04 MWD+SC(1) 970.37 0.45 55.23 970.36 934.86 0.07 1.50 5,914,755.71 349,353.64 0.18 1.50 MWD+SC(1) 1,065.90 0.64 63.97 1,065.89 1,030.39 0.51 2.28 5,914,756.14 349,354.43 0.22 2.28 MWD+SC(1) 1,159.67 0.41 108.42 1,159.66 1,124.16 0.64 3.07 5,914,756.25 349,355.23 0.48 3.06 MWD+SC(1) 1,255.61 0.25 107.44 1,255.59 1,220.09 0.47 3.60 5,914,756.07 349,355.75 0.17 3.59 MWD+SC(1) 1,349.33 0.68 146.07 1,349.31 1,313.81 -0.06 4.10 5,914,755.53 349,356.24 0.54 4.10 MWD+SC(1) 5/17/2012 12:23:34PM Page 2 COMPASS 2003.16 Build 73 4 Halliburton Company Definitive Survey Report Company: Savant Local Co-ordinate Reference: Well Red Wolf 2 Project: Red Wolf TVD Reference: Red Wolf#2 Actual @ 35.50ft(7-ES 29.1 KB-ICE/1.9' Site: Exploration MD Reference: Red Wolf#2 Actual @ 35.50ft(7-ES 29.1 KB-ICE/1.9' Well: Red Wolf 2 North Reference: True Wellbore: Red Wolf#2 Survey Calculation Method: Minimum Curvature Design: Red Wolf#2 Database: .AK_PRD16 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,439.27 0.98 164.46 1,439.24 1,403.74 -1.24 4.61 5,914,754.34 349,356.72 0.44 4.62 MWD+SC(1) 1,538.19 0.79 153.96 1,538.15 1,502.65 -2.67 5.13 5,914,752.90 349,357.22 0.25 5.17 MWD+SC(1) 1,633.92 1.16 156.33 1,633.87 1,598.37 -4.15 5.81 5,914,751.41 349,357.87 0.39 5.87 MWD+SC(1) 1,728.23 1.44 173.03 1,728.15 1,692.65 -6.20 6.34 5,914,749.35 349,358.36 0.50 6.42 MWD+SC(1) 1,822.94 1.73 162.90 1,822.83 1,787.33 -8.75 6.90 5,914,746.79 349,358.87 0.42 7.02 MWD+SC(1) 1,916.86 1.43 169.63 1,916.71 1,881.21 -11.25 7.53 5,914,744.27 349,359.45 0.38 7.68 MWD+SC(1) 2,011.33 1.64 165.75 2,011.15 1,975.65 -13.72 8.08 5,914,741.79 349,359.94 0.25 8.26 MWD+SC(1) 2,105.68 1.73 160.28 2,105.46 2,069.96 -16.37 8.89 5,914,739.12 349,360.70 0.20 9.11 MWD+SC(1) 2,200.42 1.76 163.63 2,200.15 2,164.65 -19.11 9.78 5,914,736.37 349,361.54 0.11 10.04 MWD+SC(1) 2,294.55 1.80 168.48 2,294.24 2,258.74 -21.95 10.49 5,914,733.52 349,362.19 0.17 10.78 MWD+SC(1) 2,388.22 1.60 175.15 2,387.86 2,352.36 -24.69 10.89 5,914,730.77 349,362.54 0.30 11.22 MWD+SC(1) I. 2,482.04 1.54 179.84 2,481.65 2,446.15 -27.26 11.00 5,914,728.20 349,362.60 0.15 11.37 MWD+SC(1) 2,576.33 1.68 180.25 2,575.90 2,540.40 -29.91 11.00 5,914,725.55 349,362.54 0.15 11.40 MWD+SC(1) 2,670.53 1.79 175.33 2,670.06 2,634.56 -32.76 11.12 5,914,722.70 349,362.60 0.20 11.55 MWD+SC(1) 2,764.75 1.46 173.39 2,764.24 2,728.74 -35.42 11.37 5,914,720.04 349,362.81 0.36 11.84 MWD+SC(1) 2,860.14 1.49 183.63 2,859.60 2,824.10 -37.86 11.44 5,914,717.59 349,362.82 0.28 11.94 MWD+SC(1) 2,954.21 1.31 174.41 2,953.64 2,918.14 -40,15 11.46 5,914,715.30 349,362.80 0.31 12.00 MWD+SC(1) 3,048.60 1.41 148.79 3,048.01 3,012.51 -42.22 12.17 5,914,713.22 349,363.47 0.65 12.73 MWD+SC(1) 3,145.50 2.43 148.88 3,144.85 3,109.35 -45.00 13.85 5,914,710.41 349,365.09 1.05 14.45 MWD+SC(1) 3,240.86 1.53 143.87 3,240.15 3,204.65 -47.76 15.64 5,914,707.62 349,366.83 0.96 16.28 MWD+SC(1) 3,331.66 1.72 143.12 3,330.92 3,295.42 -49.83 17.18 5,914,705.52 349,368.32 0.21 17.84 MWD+SC(1) 3,428.63 1.74 123.69 3,427.84 3,392.34 -51.81 19.28 5,914,703.49 349,370.38 0.60 19.96 MWD+SC(1) 3,522.00 1.42 140.75 3,521.18 3,485.68 -53.49 21.19 5,914,701.77 349,372.26 0.61 21.90 MWD+SC(1) 3,615.80 1.48 147.06 3,614.95 3,579.45 -55.40 22.58 5,914,699.83 349,373.61 0.18 23.32 MWD+SC(1) 3,709.29 1.61 132.62 3,708.40 3,672.90 -57.31 24.20 5,914,697.90 349,375.20 0.44 24.96 MWD+SC(1) 3,894.01 1.03 176.53 3,893.08 3,857.58 -60.72 26.21 5,914,694.44 349,377.14 0.61 27.02 MWD+SC(2) 3,985.16 1.00 183.68 3,984.21 3,948.71 -62.33 26.21 5,914,692.83 349,377.10 0.14 27.04 MWD+SC(2) 4,079.58 0.79 190.18 4,078.62 4,043.12 -63.80 26.04 5,914,691.37 349,376.91 0.25 26.89 MWD+SC(2) 4,171.88 0.83 185.50 4,170.91 4,135.41 -65.09 25.87 5,914,690.08 349,376.70 0.08 26.73 MWD+SC(2) 4,267.77 0.75 183.11 4,266.79 4,231.29 -66.41 25.77 5,914,688.77 349,376.58 0.09 26.65 MWD+SC(2) 4,360.76 0.90 189.54 4,359.77 4,324.27 -67.73 25.61 5,914,687.44 349,376.40 0.19 26.51 MWD+SC(2) 4,456.16 0.96 176.00 4,455.16 4,419.66 -69.27 25.54 5,914,685.91 349,376.30 0.24 26.46 MWD+SC(2) 4,549.27 0.96 183.12 4,548.26 4,512.76 -70.83 25.56 5,914,684.35 349,376.28 0.13 26.50 MWD+SC(2) 4,644.12 0.75 192.10 4,643.10 4,607.60 -72.23 25.38 5,914,682.96 349,376.08 0.26 26.34 MWD+SC(2) 4,738.04 0.76 181.52 4,737.01 4,701.51 -73.45 25.24 5,914,681.74 349,375.91 0.15 26.21 MWD+SC(2) 4,832.50 0.96 310.10 4,831.47 4,795.97 -73.57 24.62 5,914,681.63 349,375.28 1.64 25.59 MWD+SC(2) 4,926.93 0.74 300.39 4,925.88 4,890.38 -72.75 23.48 5,914,682.47 349,374.17 0.28 24.45 MWD+SC(2) 5,021.04 0.74 304.22 5,019.99 4,984.49 -72.10 22.46 5,914,683.14 349,373.16 0.05 23.42 MWD+SC(2) 5,114.95 0.92 302.86 5,113.89 5,078.39 -71.35 21.32 5,914,683.91 349,372.04 0.19 22.27 MWD+SC(2) 5,209.01 0.83 285.28 5,207.94 5,172.44 -70.76 20.03 5,914,684.53 349,370.76 0.30 20.97 MWD+SC(2) 5/17/2012 12:23:34PM Page 3 COMPASS 2003 16 Build 73 Halliburton Company Definitive Survey Report Company: Savant Local Co-ordinate Reference: Well Red Wolf 2 Project: Red Wolf TVD Reference: Red Wolf#2 Actual @ 35.50ft(7-ES 29.1 KB-ICE/1.9' Site: Exploration MD Reference: Red Wolf#2 Actual @ 35.50ft(7-ES 29.1 KB-ICE/1.9' Well: Red Wolf 2 North Reference: True Wellbore: Red Wolf#2 Survey Calculation Method: Minimum Curvature Design: Red Wolf#2 Database: .AK PRD16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 5,302.27 0.64 276.49 5,301.19 5,265.69 -70.52 18.86 5,914,684.79 349,369.59 0.24 19.80 MWD+SC(2) 5,396.62 0.83 281.56 5,395.53 5,360.03 -70.33 17.67 5,914,685.01 349,368.40 0.21 18.60 MWD+SC(2) 5,491.12 0.70 278.77 5,490.02 5,454.52 -70.10 16.43 5,914,685.26 349,367.17 0.14 17.36 MWD+SC(2) 5,583.84 1.11 308.11 5,582.73 5,547.23 -69.46 15.16 5,914,685.93 349,365.92 0.65 16.09 MWD+SC(2) 5,679.45 1.27 313.23 5,678.32 5,642.82 -68.16 13.66 5,914,687.25 349,364.44 0.20 14.57 MWD+SC(2) 5,773.04 1.19 305.28 5,771.89 5,736.39 -66.89 12.11 5,914,688.55 349,362.92 0.20 13.00 MWD+SC(2) 5,868.19 1.29 309.96 5,867.02 5,831.52 -65.63 10.48 5,914,689.85 349,361.32 0.15 11.36 MWD+SC(2) 5,958.51 1.20 305.92 5,957.32 5,921.82 -64.43 8.94 5,914,691.08 349,359.79 0.14 9.80 MWD+SC(2) 6,056.79 1.08 298.08 6,055.58 6,020.08 -63.39 7.29 5,914,692.16 349,358.17 0.20 8.13 MWD+SC(2) 6,150.00 1.06 296.39 6,148.77 6,113.27 -62.59 5.74 5,914,692.98 349,356.63 0.04 6.57 MWD+SC(2) 6,244.05 1.19 303.71 6,242.80 6,207.30 -61.66 4.15 5,914,693.94 349,355.06 0.21 4.97 MWD+SC(2) 6,338.46 1.30 303.71 6,337.19 6,301.69 -60.52 2.44 5,914,695.12 349,353.38 0.12 3.25 MWD+SC(2) 6,431.25 1.29 306.57 6,429.96 6,394.46 -59.32 0.73 5,914,696.36 349,351.69 0.07 1.52 MWD+SC(2) 6,525.92 1.08 302.30 6,524.61 6,489.11 -58.20 -0.88 5,914,697.50 349,350.10 0.24 -0.11 MWD+SC(2) 6,620.53 0.92 297.70 6,619.20 6,583.70 -57.38 -2.31 5,914,698.36 349,348.69 0.19 -1.54 MWD+SC(2) 6,712.21 0.78 299.14 6,710.87 6,675.37 -56.73 -3.50 5,914,699.03 349,347.51 0.15 -2.75 MWD+SC(2) 6,807.88 0.90 293.99 6,806.53 6,771.03 -56.11 -4.76 5,914,699.67 349,346.27 0.15 -4.01 MWD+SC(2) 6,901.88 0.80 309.80 6,900.52 6,865.02 -55.39 -5.94 5,914,700.42 349,345.10 0.27 -5.20 MWD+SC(2) 6,995.57 0.74 310.58 6,994.20 6,958.70 -54.57 -6.90 5,914,701.25 349,344.16 0.07 -6.17 MWD+SC(2) 7,091.25 0.82 310.08 7,089.87 7,054.37 -53.73 -7.89 5,914,702.11 349,343.18 0.08 -7.18 MWD+SC(2) 7,185.01 0.88 317.74 7,183.62 7,148.12 -52.77 -8.89 5,914,703.09 349,342.20 0.14 -8.19 MWD+SC(2) 7,279.51 0.68 307.66 7,278.11 7,242.61 -51.89 -9.82 5,914,703.99 349,341.29 0.26 -9.13 MWD+SC(2) 7,369.74 0.93 311.00 7,368.33 7,332.83 -51.08 -10.80 5,914,704.82 349,340.33 0.28 -10.12 MWD+SC(2) 7,467.40 0.97 311.23 7,465.98 7,430.48 -50.01 -12.02 5,914,705.91 349,339.13 0.04 -11.35 MWD+SC(2) 7,556.87 0.97 306.27 7,555.44 7,519.94 -49.07 -13.20 5,914,706.88 349,337.97 0.09 -12.54 MWD+SC(2) 7,656.43 1.06 314.14 7,654.98 7,619.48 -47.93 -14.54 5,914,708.05 349,336.65 0.17 -13.90 MWD+SC(2) 7,750.51 0.86 318.53 7,749.05 7,713.55 -46.79 -15.63 5,914,709.20 349,335.58 0.23 -15.01 MWD+SC(2) 7,844.09 1.09 316.28 7,842.62 7,807.12 -45.62 -16.71 5,914,710.39 349,334.53 0.25 -16.10 MWD+SC(2) 7,938.66 1.10 303.95 7,937.17 7,901.67 -44.47 -18.09 5,914,711.58 349,333.17 0.25 -17.49 MWD+SC(2) 8,032.03 0.96 307.93 8,030.52 7,995.02 -43.48 -19.45 5,914,712.58 349,331.83 0.17 -18.87 MWD+SC(2) 8,125.54 0.97 310.43 8,124.02 8,088.52 -42.49 -20.67 5,914,713.60 349,330.63 0.05 -20.10 MWD+SC(2) 8,219.79 1.12 299.81 8,218.26 8,182.76 -41.51 -22.07 5,914,714.61 349,329.25 0.26 -21.52 MWD+SC(2) 8,313.48 1.22 285.32 8,311.93 8,276.43 -40.80 -23.83 5,914,715.36 349,327.50 0.33 -23.28 MWD+SC(2) 8,407.63 1.23 279.10 8,406.05 8,370.55 -40.37 -25.79 5,914,715.82 349,325.55 0.14 -25.25 MWD+SC(2) 8,502.56 1.27 273.96 8,500.96 8,465.46 -40.14 -27.85 5,914,716.10 349,323.50 0.13 -27.31 MWD+SC(2) 8,594.76 1.52 275.02 8,593.13 8,557.63 -39.96 -30.09 5,914,716.32 349,321.27 0.27 -29.55 MWD+SC(2) 8,685.23 1.73 276.16 8,683.57 8,648.07 -39.71 -32.64 5,914,716.62 349,318.72 0.23 -32.11 MWD+SC(2) 8,779.71 1.58 284.33 8,778.01 8,742.51 -39.23 -35.32 5,914,717.15 349,316.05 0.30 -34.79 MWD+SC(2) 8,875.83 1.43 280.40 8,874.10 8,838.60 -38.69 -37.78 5,914,717.74 349,313.60 0.19 -37.27 MWD+SC(2) 8,973.06 1.35 278.18 8,971.30 8,935.80 -38.31 -40.11 5,914,718.17 349,311.28 0.10 -39.60 MWD+SC(2) 5/17/2012 12:23:34PM Page 4 COMPASS 2003.16 Build 73 Halliburton Company Definitive Survey Report Company: Savant Local Co-ordinate Reference: Well Red Wolf 2 Project: Red Wolf TVD Reference: Red Wolf#2 Actual @ 35.50ft(7-ES 29.1 KB-ICE/1.9' Site: Exploration MD Reference: Red Wolf#2 Actual @ 35.50ft(7-ES 29.1 KB-ICE/1.9' Well: Red Wolf 2 North Reference: True Wellbore: Red Wolf#2 Survey Calculation Method: Minimum Curvature Design: Red Wolf#2 Database: .AK PRD16 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) r) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,064.13 1.38 284.60 9,062.34 9,026.84 -37.88 -42.23 5,914,718.64 349,309.16 0.17 -41.73 MWD+SC(2) r 9,160.95 1.71 295.11 9,159.13 9,123.63 -36.97 -44.67 5,914,719.60 349,306.75 0.45 -44.17 MWD+SC(2) 9,255.18 1.79 293.34 9,253.31 9,217.81 -35.79 -47.29 5,914,720.83 349,304.15 0.10 -46.81 MWD+SC(2) 9,347.08 1.96 283.85 9,345.16 9,309.66 -34.85 -50.14 5,914,721.83 349,301.32 0.38 -49.67 MWD+SC(2) 9,396.49 1.78 286.27 9,394.55 9,359.05 -34.43 -51.70 5,914,722.28 349,299.77 0.40 -51.23 MWD+SC(2) 9,490.19 1.89 296.31 9,488.20 9,452.70 -33.34 -54.48 5,914,723.43 349,297.01 0.36 -54.03 MWD+SC(2) 9,583.67 1.79 311.67 9,581.63 9,546.13 -31.68 -56.95 5,914,725.13 349,294.58 0.54 -56.52 MWD+SC(2) 9,677.88 1.56 317.60 9,675.80 9,640.30 -29.76 -58.91 5,914,727.09 349,292.65 0.31 -58.51 MWD+SC(2) 9,772.23 1.39 310.97 9,770,12 9,734.62 -28.06 -60.64 5,914,728.83 349,290.95 0.26 -60.26 MWD+SC(2) 9,865.90 1.62 309.49 9,863.76 9,828.26 -26.47 -62.52 5,914,730.45 349,289.11 0.25 -62.17 MWD+SC(2) 9,959.71 1.57 316.84 9,957.53 9,922.03 -24.69 -64.43 5,914,732.27 349,287.24 0.22 -64.09 MWD+SC(2) 10,053;83 1.77 316.63 10,051.61 10,016.11 -22.69 -66.31 5,914,734.30 349,285.40 0.21 -66.00 MWD+SC(2) 10,148.52 1.96 298.32 10,146.25 10,110.75 -20.86 -68.74 5,914,736.18 349,283.01 0.66 -68.45 MWD+SC(2) 10,241.70 1.86 279.41 10,239.38 10,203.88 -19.86 -71.63 5,914,737.24 349,280.13 0.68 -71.36 MWD+SC(2) 10,337.17 2.10 276.19 10,334.79 10,299.29 -19.42 -74.90 5,914,737.75 349,276.88 0.28 -74.63 MWD+SC(2) 10,429.66 2.09 266.52 10,427.22 10,391.72 -19.34 -78.27 5,914,737.90 349,273.51 0.38 -78.00 MWD+SC(2) 10,521.56 1.76 264.36 10,519.07 10,483.57 -19.58 -81.34 5,914,737.72 349,270.43 0.37 -81.07 MWD+SC(2) 10,614.75 1.49 266.51 10,612.22 10,576.72 -19.79 -83.98 5,914,737.56 349,267.79 0.30 -83.71 MWD+SC(2) 10,709.18 1.05 252.31 10,706.63 10,671.13 -20.13 -86.03 5,914,737.26 349,265.74 0.57 -85.75 MWD+SC(2) 10,806.49 0.98 231.26 10,803.92 10,768.42 -20.92 -87.52 5,914,736.50 349,264.22 0.39 -87.24 MWD+SC(2) 10,901.00 0.57 221.52 10,898.43 10,862.93 -21.78 -88.47 5,914,735.66 349,263.26 0.45 -88.17 MWD+SC(2) 10,994.71 0.20 141.64 10,992.13 10,956.63 -22.26 -88.67 5,914,735.19 349,263.05 0.61 -88.37 MWD+SC(2) 11,088.97 0.44 225.29 11,086.39 11,050.89 -22.64 -88.83 5,914,734.81 349,262.88 0.49 -88.52 MWD+SC(2) 11,182.16 0.66 205.32 11,179.58 11,144.08 -23.38 -89.31 5,914,734.08 349,262.39 0.31 -88.99 MWD+SC(2) 11,274.77 0.83 209.48 11,272.18 11,236.68 -24.44 -89.87 5,914,733.02 349,261.81 0.19 -89.54 MWD+SC(2) 11,368.85 0.25 221.93 11,366.26 11,330.76 -25.19 -90.34 5,914,732.29 349,261.32 0.63 -90.00 MWD+SC(2) 11,465.18 0.25 266.13 11,462.59 11,427.09 -25.36 -90.69 5,914,732.12 349,260.97 0.20 -90.35 MWD+SC(2) 11,554.26 0.26 30.73 11,551.66 11,516.16 -25.20 -90.78 5,914,732.29 349,260.88 0.51 -90.44 MWD SC(2) 11,650.79 0.47 13.06 11,648.19 11,612.69 -24.62 -90.58 5,914,732.86 349,261.09 0.24 -90.25 MWD+SC(2) 11,745.74 0.97 55.03 11,743.14 11,707.64 -23.78 -89.84 5,914,733.68 349,261.85 0.73 -89.51 MWD+SC(2) 11,790.12 1.11 48.93 11,787.51 11,752.01 -23.29 -89.20 5,914,734.17 349,262.50 0.40 -88.89 MWD+SC(2) 11,860.00 1.11 48.93 11,857.38 11,821.88 -22.40 -88.18 5,914,735.03 349,263.53 0.00 -87.88 PROJECTED to TD 5/17/2012 12:23:34PM Page 5 COMPASS 2003.16 Build 73 .-- _ 111.I.11,11111.1"IllIllMMIMIMlk:11 - m 4 —,,i"II"MMALIIMIIIwmmo .„,„- ,..„ ., , 411111011.111111111 4111111.11111111.10M6— '1, ..4 _,, ''' f ...� p�4.aw .. ..,yr ut4 '"'"0104.11111611001.11111r 11111.NPIMIIhr .- Z # - , li .„. .4040.01.1111Mit 7: alle. ' .a _ ^ ' o-...- - .. • f ,ic 44414111.111111.v. or * , Y :. 1 I i y c .r► lillikepolit „,„ .....,16.7„,".*:el:.,,,: ...1.1'. djok J " 4 OA ''•i ,/ >4- i> a `..'�� - -,,,—°L- ?� e.'-"'"1.1*- .,, r.. \1111111.' .4 - ,,,._ , P k's, ,k /* 4r r� , n4 . • ,4 • AN « 41m 'j. wf milli Mb t2sa:mam Liu W.`§kur eM `' a' .s.L-,:.'E'T3 - ZAP +c,_ A a \2-V Cementing End of Well Report A Company: Savant Well Name: Red Wolf#2 Field: Badami State: AK Date: 03/31/2012 Conductor Pipe,04/23/2012 Final Plug Well Location: Nabors 007 ES Report Number: V1 Contact: Mr. Erik Opstad Made By: Jeff Long Service from District: Prudhoe Bay,Ak District Phone: 907-659-2434 Objective: To provide Conductor and Surface casing cementing with Lead slurry to surface, and a competent shoe for drilling ahead. Provide Plug and Abandonment cement and pumping to permanently abandon the well bore. Disclaimer Notice Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. measurements.tisprovidedlinferences withgenerallyare not yacllible industry practice.relying on facts or information provided by others.limitations,computer models, Schlumberger tionsesassumptions and in provide that rme not infallible Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED.EFFECTIVENESS OF MATERIAL.PRODUCTS OR SUPPLIES, RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. 1,1 �.,Fa ss"4 w,. • EXECUTIVE SUMMARY Schlumberger Pressure Pumping Services provided cementing products and service for the Red Wold#2 well on the North Slope of Alaska. We appreciate having had the opportunity to work on this well.We understand how important this well was to Savant,and that the limited drilling window that was available did not allow time for any service delays. We certainly hope that we met your expectations, and we look forward to serving you again on future projects. Schlumberger provided job designs,lab-testing,blending,pumping equipment and personnel to do the job,with NO NPT for the rig. Schlumberger has established a safety policy as well as Key Service Quality Requirements, to which all Schlumberger personnel must adhere. Prior to pumping, the job design had been peer-reviewed by not less than (2) qualified engineers, reviewed with Operational Management, who then reviewed all aspects of the planned operation with the Field Specialist. All job parameters were discussed and agreed,blending and load sheets confirmed,and contingencies were reviewed and documented. Minimum lab-testing for pilot blends was complete prior to blending, and field-blend lab testing was complete prior to pumping. Pre-job safety meetings were held with customer representatives and other on location personnel to familiarize everyone with existing hazards and safety procedures. We appreciate the close cooperation between the customer representative and the Schlumberger representative that provided a safe operation. The Conductor Casing:set at 69 ft.was not in the original cementing plan for the well, but was handled by Schlumberger when called out.The crew arrived on location and pumped 42.25 bbls of Arctic Set 1 cement slurry mixed at 15.7 ppg,(253 sacks, 0.93 cuft/sk yield). This brought returns to surface,and successfully anchored the Conductor Casing. For the Surface Casing:prejob planning called for lead to be pumped until sufficient indication of cement returns at surface.120%(14.8 in equivalent hole diameter)average excess volume of cement was planned(230% excess through the Permafrost, and 45% excess below) and was available on location. No cement or spacer returns were seen at surface during the primary job. A Port-Collar had been run at —500 ft.The port-collar was opened and a Top-out job was performed using ASL Lead slurry with returns to surface. The job was accomplished without incident.. The casing was run and set at —3872 ft. Full circulation was established. The cement job proceeded as follows: 1. 100 bbls of MUDPUSH II spacer,with red dye,mixed at 10.1 ppg(4.8 bpm avg.) 2. 472 bbls of Arctic-Set-Lite,Lead Slurry,mixed to 10.7 ppg,at 5.0 bpm avg.pump rate(1082 sacks,2.45 cuft/sk yield) 3. 50 bbls of Tail slurry mixed to 15.8 ppg,at 4.0 bpm avg.pump rate(242 sacks,1.16 cuft/sk yield) 4. Displaced with the rig pumps. 5. Plug was bumped. 6. No returns of slurry to surface. 7. Opened Ported Collar,and established circulation 8. ASL cement blended in Prudhoe Bay,and sent to location. 9. 148 bbls of ASL Slurry,Mixed to 10.7 ppg,at 3.9 bpm avg.pump rate(339 sacks,2.45 cuft/sk yield) 10. Cement returns were noted at surface. 11. 6 bbls of water was pumped to displace. 12. The port collar was closed 13. Pressured up to 1000 psi with the cement unit,to pressure test. 14. After nippling up,cement was drilled and a LOT confirmed shoe isoloation. 2 of 3 Schlumberger Pk- 111L The plug and abandonment of the Red Wolf 2 well, was accomplished starting on April 22, 2012. There were 3 plugging operations including an open-hole plug, which required tagging to verify proper placement, a retainer-squeeze to abandon the section at the surface casing shoe,and a surface plug for final isolation. Plug#1 was a balanced plug set from 11,859 ft to 11,348 ft,using 40 bbls of Class G cement slurry,mixed at 15.8 ppg(194 sks, 1.16 cuft/sk yield) The plug was tagged on depth 12 hrs.after setting. Plug#2 was a squeeze through a retainer set at—3847 ft,using 17 bbls Class G cement slurry,mixed at 15.8 ppg(83 sks, 1.16 cuft/sk yield) 15 bbls were injected below the retainer and 2 bbls were left on top. Plug#3 was a balanced plug from 310 ft to surface,using—13.0 bbls of Arctic-Set 1 cement slurry, mixed at 15.7 ppg(79 sks,0.93 cuft/sk yield) Attached with this report please find the CemCADE design,lab tests,and Field job Report. Thank you for Using Schlumberger. Please do not hesitate to contact me with any questions or concerns. Sincerely, Jeff Long 907-273-1778 Jlongl@slb.com 3 of 3 Schlumberger Schlumberger Cementing Job Report CemCAT v1.4 • Well RED WOLF#2 Client SAVANT Field SIR No. 65746 Engineer Donny Bergonzini Job Type Conductore Country United States lob Date 03-31-2012 Time Pressure Rate Density Messages 03/31/2013 14:32:07 14:32:07 priime up pump 14:42:00 J j 14:52:00 Reset Total,Vol=14.42 bbl 1 water ahead 15:02:00 1 1.3 bbls ahead I Rt Reset Total,Vol=0.73 bbl batch up 15:12:00 down hole 15:22:00 cement @ surface End Spacer 15:32:00 15:42:00 ishut down wash uo 15:52:00 15:59:21 hh:mm:ss 0.00 1000 2000 3000 a000 soon 0.00 2.0 4.0 6.0 8.0 10.0 5.0 10.0 15.0 20.0 25.0 03/31/301215:53:21 PSI - -B/M LB/G 04/02/2012 09:06:52 Schlumberger Cementing Service Report Customer Job Number SAVANT 65746 Well Location(legal) Schlumberger Location Job Start RED WOLF#2 Prudhoe Bay AK Mar/31/2012 Field Formation Name/Type Deviation Bit Size Well MD Well TVD deg in ft ft County USA State/Province AK BHP BUST BHCT Pore Press.Gradient Well Master API/UWI psi degF degF lb/gal Rig Name Drilled For Service Via Casing/Liner n/a Depth,ft Size,in Weight,lb/ft Grade Thread Offshore Zone Well Class Well Type New Drilling Fluid Type Max.Density Plastic Viscosity Tubing/Drill Pipe lb/gal cP T/D Depth,ft Size,in Weight,lb/ft Grade Thread Service Line Job Type Cementing Conductors Max.Allowed Tub.Press Max.Allowed Ann.Press WH Connection Perforations/Open Hole psi psi Top,ft Bottom,ft shot/ft No.of Shots Total Interval Service Instructions ft ft ft Cement 69'of 25'x20'conductor and 18inches in the cellar with ft ft Diameter 253 sacks of Arctic SET-1 slurry,yield=0.93 cuft/sk(42.25 bbls) mixed at 15.7 ppg. ft ft in Use C-pump to place ------ --- Treat Down Displacement Packer Type Packer Depth bbl ft Tubing Vol. Casing Vol. Annular Vol. Openhote Vol. bbl bbl bbl bbl Casing/Tubing Secured ❑ 1 Hole Vol.Circulated prior to Cement ❑ Casing Tools Squeeze Job Lift Pressure psi Shoe Type Squeeze Type Pipe Rotated ❑ Pipe Reciprocated E Shoe Depth ft Tool Type No.Centralizers Top Plugs Bottom Plugs Stage Tool Type Tool Depth ft Cement Head Type Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Arrived on Location Leave Location Collar Type Tail Pipe Depth ft Mar/31/2012 Mar/31/2012 Mar/31/2012 Collar Depth P ft Sqz.Total Vol. bbl Date Time Treating Flow Density Volume Message 24-hr Pressure Rate LB/G BBL clock PSI B/M 03/31/2012 14:32:07 0 0.0 -0.00 0.0 Started Acquisition 03/31/2012 14:32:37 0 0.0 -0.00 0.0 03/31/2012 14:32:38 0 0.0 -0.00 0.0 priime up pump 03/31/2012 14:33:07 0 0.0 -0.00 0.0 03/31/2012 14:33:37 0 0.0 -0.00 0.0 03/31/2012 14:34:07 0 0.0 -0.00 0.0 03/31/2012 14:34:37 0 0.0 -0.00 0.0 03/31/2012 14:35:07 0 0.0 -0.00 0.0 03/31/2012 14:35:37 0 0.0 -0.00 0.0 03/31/2012 14:36:07 0 0.0 -0.00 0.0 03/31/2012 14:36:37 0 0.0 -0.00 0.0 03/31/2012 14:37:07 -4 0.0 8.25 0.0 03/31/2012 14:37:37 5 0.0 8.01 0.0 03/31/2012 14:38:07 5 0.0 7.47 0.0 03/31/2012 14:38:37 32 0.0 8.01 0.0 03/31/2012 14:39:07 138 0.0 8.38 0.0 03/31/2012 14:39:37 151 0.0 8.39 0.0 03/31/2012 14:40:07 0 0.3 8.10 0.0 03/31/2012 14:40:37 0 0.5 -3.13 0.3 03/31/2012 14:41:07 32 4.0 -3.13 1.0 03/31/2012 14:41:37 64 3.8 8.33 2.9 Page 1 of 5 Well 1 Field Job Start Customer lob Number RED WOLF#2 Mar/31/2012 SAVANT 65746 I , Date Time Treating Flow Density Volume Message 24-hr Pressure Rate WO BBL dock PSI B/N 03/31/2012 14:42:37 14 1.8 8.38 7.7 03/31/2012 14:43:07 64 3.0 8.35 7.9 03/31/2012 14:43:37 142 5.5 8.38 10.6 03/31/2012 14:44:07 165 5.7 8.39 13.0 __ 03/31/2012 14:44:37 5 0.2 8.38 13.6 , 03/31/2012 14:45:07 I 5 0.2 8.38 13.7 - 03/31/2012 1 14:45:37 1 5 0.2 8.39 13.8 03/31/2012 14:46:07 5 0.3 8.39 13.9 03/31/2012 14:46:37 5 0.3 8.39 14.1 03/31/2012 14:47:07 0 0.4 8.25 14.2 03/31/2012 14:47:37 5 0.2 8.28 14.4 03/31/2012 14:48:07 0 0.0 8.38 14.4 03/31/2012 14:48:37 5 0.0 8.39 14.4 03/31/2012 14:49:07 5 0.0 8.38 14.4 03/31/2012 14:49:37 5 0.0 8.38 14.4 03/31/2012 14:50:07 1 0 0.0 8.38 14.4 ' 03/31/2012 14:50:37 0 0.0 8.39 14.4 03/31/2012 14:51:07 0 0.0 8.38 14.4 03/31/2012 14:51:37 0 0.0 8.38 14.4 03/31/2012 14:51:53 0 I 0.0 8.38 14.4 Reset Total,Vol=14.42 bbl 03/31/2012 14:52:07 0 0.0 8.38 0.0 L 03/31/2012 14:52:37 0 0.0 8.38 0.0 T 03/31/2012 14:53:07 0 0.0 8.38 0.0 03/31/2012 14:53:37 0 0.0 8.38 0.0 03/31/2012 14:54:07 0 0.0 8.38 0.0 03/31/2012 14:54:37 0 0.0 8.38 0.0 _L 03/31/2012 14:55:07 0 0'.0 8.38 0.0 03/31/2012 14:55:37 0 0.0 8.38 0.0 03/31/2012 14:56:07 0 0.0 8.38 0.0 03/31/2012 14:56:37 0 0.0 8.38 0.0 03/31/2012 14:57:07 0 0.0 8.38 0.0 03/31/2012 14:57:37 19 0.0 8.38 0.0 03/31/2012 14:58:07 51 0.0 8.39 0.0 -1- 03/31/2012 14:58:37 46 0.0 8.39 0.0 03/31/2012 14:59:07 51 0.0 8.39 0.0 03/31/2012 14:59:37 46 0.0 8.39 0.0 03/31/2012 15:00:07 46 0.0 8.39 0.0 03/31/2012 15:00:37 51 0.0 8.39 0.0 03/31/2012 15:00:39 51 0.0 8.40 0.0 water ahead 03/31/2012 15:01:07 46 0.0 8.39 0.0 03/31/2012 15:01:37 0 0.2 8.39 0.0 03/31/2012 15:02:07 -4 0.3 8.38 0.1 r i 03/31/2012 i 15:02:37 -9 0.3 8.36 0.2 03/31/2012 1 15:03:07 19 0.3 8.38 0.4 03/31/2012 1 15:03:37 -13 0.2 8.39 0.5 03/31/2012 15:03:51 -13 0.2 8.39 0.5 1.3 bbls ahead 03/31/2012 1 15:04:07 -13 0.2 8.39 0.6 03/31/2012 15:04:37 -4 0.1 8.39 0.6 03/31/2012 15:04:43 -4 0.2 8.39 0.7 pt I 03/31/2012 I 15:04:58 37 0.9 8.39 0.7 Reset Total,Vol=0.73 bbl 03/31/2012 15:05:07 1520 0.0 8.39 0.1 03/31/2012 15:05:37 131.4i 0.0 8.39 0.1 03/31/2012 15:06:07 0 i 0.1 8.39 0.1 03/31/2012 15:06:37 1 55 f 0.0 8.39 0.1 Page 2 of 5 Well Field I lob Start Customer lob Number RED WOLF#2 Mar/31/2012 SAVANT 65746 I Date Time Treating Flow Density Volume Message 24-hr Pressure Rate LB/G BBL dock PSI BM 03/31/2012 15:07:18 55 0.0 8.39 0.1 batch up 03/31/2012 15:07:37 60 0.0 8.39 0.1 03/31/2012 15:08:07 101 0.0 8.38 0.1 I 03/31/2012 15:08:37 96 0.0 8.24 0.1 03/31/2012 15:09:07 96 0.0 ! 8.49 0.1 03/31/2012 15:09:37 I 96 0.0 8.94 0.1 03/31/2012 15:10:07 96 0.0 10.37 0.1 03/31/2012 15:10:37 96 0.0 11.53 0.1 03/31/2012 15:11:07 96 0.0 12.25 0.1 03/31/2012 15:11:37 96 0.0 12.69 0.1 03/31/2012 15:12:07 -13 I 0.0 12.99 0.1 03/31/2012 15:12:37 -18 0.0 13.88 0.1 03/31/2012 15:13:07 -9 0.0 15.15 0.1 03/31/2012 15:13:20 78 0.4 15.62 0.1 !down hole r 03/31/2012 I 15:13:37 92 0.4 15.94 0.2 03/31/2012 15:14:07 87 0.4 15.81 0.4 r- ------ -------j --- -__-. _...------ ----.. 03/31/2012 15:14:37 87 0.4 15.82 0.6 03/31/2012 15:15:07 87 0.4 15.87 0.8 03/31/2012 15:15:37 87 0.3 15.77 1.0 03/31/2012 15:16:07 87 0.3 15.63 1.2 03/31/2012 15:16:37 87 0.3 15.62 1.4 03/31/2012 15:17:07 92 0.3 15.63 1.5 03/31/2012 15:17:37 92 0.3 15.69 1.7 03/31/2012 15:18:07 87 0.3 { 15.74 1.9 03/31/2012 15:18:37 I 87 0.3 - -- 15.84 2.0 ---� 03/31/2012 15:19:07 ' 87 0.3 15.73 2.2_. 03/31/2012 15:19:37 87 I 0.3 4_ 15.68 2.3 03/31/2012 , 15:20:07 87 0.3 15.74 2.5 03/31/2012 15:20:37 87 0.3 15.81 2.6 03/31/2012 15:21:07 87 0.3 15.81 2.8 03/31/2012 15:21:23 87 0.3 15.76 2.8 cement @ surface 03/31/2012 15:21:36 , 87 0.3 15.73 2.9 End Spacer 03/31/2012 , 15:21:37 I 87 0.3 15.72 2.9 03/31/2012 15:22:07 87 0.3 15.71 3.003/31/2012 15:22:37 1 92 0.3 15.78 3.2 03/31/2012 15:23:07 ' 87 0.3 15.75 3.3 03/31/2012 15:23:37 87 0.2 15.62 3.4 03/31/2012 15:24:07 87 0.3 15.46 3.5 03/31/2012 15:24:37 87 0.21 15.82 3.7 03/31/2012 15:25:07 92 0.2 16.18 3.8 03/31/2012 15:25:37 87 0.2 15.98 3.9 03/31/2012 15:26:07 ' 87 0.2 15.88 4.0 03/31/2012 15:26:37 87 0.2 15.88 4.1 L 03/31/2012 15:27:07 87 0.2 15.76 4.2 03/31/2012 15:27:37 87 0.2 15.64 I 4.3 03/31/2012 15:28:07 87 0.2 15.55 4.4 03/31/2012 15:28:37 87 0.2 15.39 4.5 03/31/2012 15:29:07 87 0.2 15.67 4.6 _- 03/31/2012 15:29:37 --- 87 0.2 15.84 4.7 03/31/2012 15:30:07 87 0.2 15.80 4.8 F-- 03/31/2012 15:30:37 87 0.2 15.75 4.9 03/31/2012 15:31:07 87 0.1 15.72 5.0 03/31/2012 I 15:31:37 87 0.1 15.69 5.0 L 03/31/2012 15:32:07 87 0.1 15.79 5.1 Page 3 of 5 Well Field Job Start Customer Job Number RED WOLF#2 Mar/31/2012 SAVANT 65746 Date TimeTreating flow Density _-.-.- Volume --.-.`_- Sliming* 24-hr. Pressure Rate .B/B BBL dock PSI BM I 03/31/2012 15:33:07 87 0.1 15.67 5.2 ___-.----------- 03/31/2012 15:33:37 87 0.1 15.50 5.3 03/31/2012 15:34:07 87 0.1 15.44 5.3 03/31/2012 15:34:37 83 li 0.0 15.48 5.4 03/31/2012 15:35:07 83 0.0 15.43 5.4 03/31/2012 15:35:37 83 0.0 15.63 5.4 03/31/2012 15:36:07 83 0.0 15.72 5.4 03/31/2012 15:36:37 87 0.0 15.78 5.4 03/31/2012 15:37:07 83 0.0 15.79 5.4 03/31/2012 15:37:37 83 0.0 15.72 5.4 03/31/2012 15:38:07 83 0.0 15.63 5.4 03/31/2012 15:38:37 83 0.0 15.52 5.4 03/31/2012 15:39:07 78 0.0 15.47 5.4 03/31/2012 15:39:37 87 0.0 16.03 5.4 03/31/2012 ! 15:40:07 87 0.0 16.21 5.4 03/31/2012 15:40:37 83 0.0 15.75 5.4 03/31/2012 I 15:41:07 83 0.0 15.85 5.4 03/31/2012 15:41:37 83 0.0 15.59 5.4 03/31/2012 15:42:07 83 0.0 ! 15.52 5.4 - 03/31/2012 7 15:42:37 83 0.0 15.53 5.4 03/31/2012 15:43:07 83 0.0 15.81 5.4 ! _� 03/31/2012 15:43:37 83 0.0 15.57 5.4 03/31/2012 15:44:07 83 0.0 15.61 5.4 ' 03/31/2012 it 15:44:37 - - 83 0.0 15.66 5.4 03/31/2012 15:45:07 83 -_ 0.0 yl 15.65 5.4 03/31/2012 15:45:37 78 0.0 15.58 5.4 03/31/2012 15:46:07 83 0.0 15.81 5.4 03/31/2012 15:46:37 j 78 0.0 15.73 5.4 -_,- - --._..-. . . ------ -- j 03/31/2012 15:47:07 83 0.0 15.97 5.4 03/31/2012 15:47:37 115 0.0 15.97 5.4 03/31/2012 15:48:07 115 0.0 15.97 5.4 03/31/2012 15:48:37 115 ! 0.0 15.97 5.4 03/31/2012 15:49:07 115 0.0 15.97 5.4 03/31/2012 15:49:37 110 0.0 -_.15.97 5.4 ---__--- --___-- __-- 03/31/2012 15:50:07 110 0.0 15.97 5.4 I � 03/31/2012 15:50:37 III 110 0.0 15.97 5.4 03/31/2012 15:50:56 19 0.0 15.97 II 5.4 shut down wash uo 03/31/2012 15:51:07 -9 0.0 15.94 i 5.4 5.4 15.93 j 03/31/2012 15:51:37 -13 0.0 03/31/2012 15:52:07 -13 0.0 15.94 ! 5.4 03/31/2012 15:52:37 j -13 0.0 15.94 5.4 03/31/2012 15:53:07 -18 0.0 15.94 5.4 03/31/2012 15:53:37 -13 0.0 15.95 5.4 03/31/2012 15:54:07 -13 0.0 15.95 5.4 I 03/31/2012 15:54:37 -4 0.0 15.95 5.4 03/31/2012 15:55:07 -9 I 0.0 15.96 5.4 03/31/2012 15:55:37 -9 , 0.0 15.98 5.4 i, 03/31/2012 15:56:07 -9 0.0 16.00 5.4 03/31/2012 15:56:37 -9 0.0 16.00. 5.4 03/31/2012 15:57:07 -9 0.0 16.00 5.4 03/31/2012 15:57:37 -9 0.0 1 15.99 5.4 ----------- 03/31/2012 ' 15:58:07 -4 0.0 1 16.00 5.4 03/31/2012 15:58:37 -9 0.0 15.99 5.4 Paye 4 of 5 Well Field Job Start Customer Job Number 1 RED WOLF#2 Mar/31/2012 SAVANT 65746 1 � Post Job Summary Average Pump Rates,bbl/min Volume of Fluid Injected,bbl Slurry N2 Mud Maximum Rate Total Slurry Mud Spacer N2 0.6 5.7 42.25 0.0j 0.0 Treating Preesure Summary,pal Breakdown Fluid Maximum Final Average Bump Plug to Breakdown Type Volume Density 1520 0 79 bbl lb/gal Avg.N2 Percent Designed Slurry Volume Displacement Mix Water Temp Cement Circulated to Surface? n Volume bbl 0/0 42 bbls 0.0 bbl degF Washed Thru Perfs n To ft Customer or Authorized Representative Schlumberger Supervisor 1 Circulation Lost n Job Completed ❑ GARY HAMMOND t Donny Bergonzini _ Page 5 of 5 Schlumberger Laboratory Cement Test Report Nabors 2ES Red Wolf 2 Conductor Field Blend Signatures Fluid No :PAK 12cnd1006 Client :Savant Location/Rig :Nabors 2ES Date :Mar-31-2012 Well Name :Red Wof#2 Field :Badami Daniel Himel Job Type Conductor Depth 500.0 ft TVD 600.0 ft BHST 32 degE BHCT 65 degF BHP 500 psi Starting Temp. 80 degF Time to Temp. 00:20 hr.mn Heating Rate -0.75 degF/min Starting Pressure 132 psi Time to Pressure 00:20 hrmn Schedule 9.2-1 Composition Slurry Density 15.70 lb/gal Yield 0.93 ft3/sk Mix Fluid 3.539 gal/sk Solid Vol Fraction 49.1 % Porosity 50.9% Slurry type Conventional Code Concentration Sack Reference Component Blend Density Lot Number D816 80 lb of BLEND Blend 174.59 lblft3 Fresh water 3.519 gal/sk Base Fluid I D110 0.020 gal/sk Retarder TU1J0171A0 I Rheology Tem. rature 80 d=.F 65 c:1-..F Up Down Average Up Down Average (rpm) (deg) (deg) (deg) (deg) (deg) (deg) 300 85.0 85.0 86.0 87.0 87.0 87.0 200 59.0 64.0 61.5 63.0 64.0 63.5 100 25.0 28.0 28.5 28.0 29.0 28.5 60 18.0 18.0 18.0 19.0 19.0 19.0 30 14.0 11.0 12.5 12.0 12.0 12.0 01 o 6 10.4 4.8 7.6 5.8 5.2 5.5 s 3 8.3 4.8 6.5 4.6 4.9 4.8 E 10 sec Gel 12 deg-12.27 Ibf/100ft2I 10 deg-10.99 lbf/100ft2 a- 10 min Gel 76 deg-81.44 lbf/100ft2 49 deg -52.73 lbf/100ft2 CD Rheo.computed I Viscosity:82.294 cP Yield Point:3.65 lbf/100ft2 I Viscosity:85.429 cP Yield Point:3.05 lbf/100ft2 m Thickenin! Time v Consistency Time N 30 Bc 02:31 hr:mn o 70 Bc 02:48 hr:mn 100 Bc 02:53 hr:mn 1 Page 1 Instrument:8240#5 Schlumberger Sampling Period:5 seconds Prudhoe Bay Well Services Laboratory Telephone:+1 907 659 6155 Facsimile: +1 907 659 9221 250 12000- 100- • 225 10800- 90- 200 9600- 80— ' 175 8400- 70- 151 .y 7200- m 60- m n = > _ 125 5 6000- d 50- a, N N _ . C 101 d 4800— 3 40 75 13 3600- 30- ' 0 0 I 2400- 20- 25 1200— 10 ■ 0 0 0 i . . , , i . . . , 1 , . . . I . . i 0:00 0:30 1:00 1:30 2:00 2:30 3:00 Time(HH:MM) Location:Red Wolf 2 30 Bc:2:31:45 File Name: pakl2cnd1006-2-cell5.tst Customer:Savant 50 Bc:2:43:15 Supervisor:{Info:Supervisor} 70 Bc:2:48:55 Test Started:3/31/2012 1:24:21 PM Density:15.7 Ibm/gal 100 Bc:2:53:35 Test Stopped:3/31/2012 4:17:56 PM System:AS1+.02D110 BHCT:65 degF Printed:3/31/2012 4:28:11 PM BHST:32 degF Job Type:Conductor Rig Name:{Info:Rig ID) Page 1 Schlumberger CemCAD E*well cementing recommendation for 9 5/8" Surface Operator : Savant Alaska Well : Red Wolf#2 Country : USA Field : Badami State : AK Prepared for : Mr.G.Hammon Location : Nabors 2-ES Proposal No. : Draft v4 Service Point : Prudhoe Bay,Alaska Date Prepared : 03-26-2012 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLong1@slb.com &TE ) Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is prodded in accordance with generally accepted industry practice,relying on facts or information provided by others.limitations,computer models,measurements.assumptions and nterences that are not infallible. Calculations are estimates based on provided information.All proposals.recommendations.or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL.PRODUCTS OR SUPPLIES.RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom Iran infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. *Mark of Schlumberger Client : Savant Alaska Well : Red Wolf#2 Schlumliner String : 9 5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9 5/8 Surface(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 4550.0 ft BHST : 65 degF Bit Size : 12 1/4 in ft (x 1000) psi 4 . i 0 2 4 -- Frac —Pore - Siltstone- CD Sandstone.'.' o— kr, (-" Coal :.Sandstone'.'. o " 0 0 0 Well Lithology Formation Press. Page 2 red wolf 2 draft v2 12--12-2011.cfw;03-26-2012; LoadCase 9 5/8 Surface(a);Version wcs-cem471_02 Client : Savant Alaska Well : Red Wolf#2 Schlumkerger String : 9 5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9 5/8 Surface(a) Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 80.0 20 94.0 19.124 Landing Collar MD : 4470.0 ft Casing/liner Shoe MD : 4550.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 4550.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 BTC Mean OH Diameter : 12.250 in Mean Annular Excess : 120.3 % Mean OH Equivalent Diameter: 14.804 in Total OH Volume : 951.6 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1900.0 12.250 230.0 16.797 4550.0 12.250 45.0 13.263 Max. Deviation Angle : 3 deg Max. DLS : 0.066 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) _ __ 1900.0 12.60 8.40 Base of Permafrost Siltstone 2500.0 13.00 8.42 Sandstone 2900.0 13.50 8.43 Coal 3725.0 13.80 8.44 Sandstone 4550.0 14.00 8.45 Shale Page 3 red wolf 2 draft v2 12--12-2011.ctw,03-26-2012, LoadCase 9 5/8 Surface(al:Version wcs-cem471 02 Client : Savant Alaska Well : Red Wolf#2 SchInkrger String : 95/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 95/8 Surface(a) Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1950.0 1949.8 32 0.6 4550.0 4547.9 65 1.0 ft degF 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 o { -Geoth.Profile -Tubular Fluids -Annulus 0 O_ O 1 O O_ O N O O O M O O O O O l()— Temp. Profile At 194 min Page 4 red wolf 2 draft v2 12--12-2011.cfw,03-26-2012, LoadCase 9 5/9 Surface lal.Version wcs-cem471_02 Client : Savant Alaska Well : Red Wolf#2 Schlinkrgcr String : 9 5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9 5/8 Surface(a) Section 2: fluid sequence Original fluid Mud 8.60 lb/gal Pv:38.002 cP Tv:27.41 Ibf/100ft2 Displacement Volume 327.2 bbl Total Volume 1004.2 bbl TOC 0.O ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 Pv:25.000 cP Ty:35.00 Ibf/100ft2 Lead Slurry 527.0 4004.2 10.70 k:2.10E-1 lbf.s^n/ft2 n:0.273 Tv:1.47 Ibf/100ft2 Tail Slurry 50.0 545.8 4004.2 15.80 Pv:91.448 cP Tv:7.91 Ibf/100ft2 Mud 327.2 0.0 8.60 Pv:38.002 cP Ty:27.41 Ibf/100ft2 Static Security Checks: Frac 8 psi at 80.0 ft Pore 10 psi at 80.0 ft Collapse 3953 psi at 4470.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 71 ton Check Valve Diff Press 611 psi Page 5 red wolf 2 draft v2 12--12-2011.cfw:03-26-2012. LoadCase 9 5/8 Surface(a),Version wcs-cem471_02 Client : Savant Alaska Well : Red Wolf#2 Schliolierger String : 95/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 95/8 Surface(a) CemCADE Client :Savant Alaska Well :Red Wolf#2 String :95/8"Surface District : Prudhoe Bay,Alaska Country : USA ft lb/gal 7.5 10.0 12.5 15.0 o > J —Max.Dynamic Aon.Dynarnc Frac • Pore Hydrostatic 1Aon.Hydrostatic O O 8_ 0 3 N a o 0 w M m - U 3 O N (Al O _ L Fluid Sequence Dynamic Well Security ■MUDPUSH II 100.0 bbl 10.10 lb/gal Bingham:PJ=25.000 cP Ty=35.00 Ibf/100ft2 3 Lead Slurry 527.0 bbl 10.70 lb/gal Herschel:k =2.10E-1 Ibf.s^n/ft2 n =0.273 Ty=1.47 Ibf/100ft2 .Tail Slurry 50.0 bbl 15.80 lb/gal Bingham:R/=91.448 cP Ty=7.91 Ibf/100ft2 ■Mud 327.2 bbl 8.60 lb/gal Bingham:W=38.002 cP Ty=27.41 Ibf/100ft2 Total Depth = 4550.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger Y4h', aPpr Page 6 red wolf 2 draft v212-12-2011.cfw;03-26-2012; LoadCase 9 5/8 Surface(a),Version wcs-cem471_02 Client : Savant Alaska Well : Red Wolf#2 Schlwohrger String : 9 5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9 5/8 Surface(a) Section 3: pumping schedule Start Job: Circulate at least(1) BU, Ensure full returns Ramp up rates to -3 BPM, allow pressure to stabilize(you should notice a drop in pressue over-10 mins) then increase rate to-4BPM, allow pressure to stabilize again. Repeat to maximum rate. This method will help to ensure as much of the hole as possible is moving, and help to eliminate excessive channelling. Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH Il 5.0 20.0 4.0 20.0 80 Break Circulation MUDPUSH II 1.0 5.0 5.0 25.0 80 Pressure Test Head&Lines 5.0 0.0 80 Bleed Off MUDPUSH II 5.0 75.0 15.0 100.0 80 Cont.Spacer Ahead 5.0 0.0 80 Drop Bottom Plug Lead Slurry 6.0 327.0 54.5 327.0 80 Mix&Pump Lead Slurry Lead Slurry 3.0 1.0 0.3 328.0 80 Bottom Plug at Float Collar Lead Slurry 6.0 189.0 31.5 517.0 80 Cont. Lead until returns noted at Surface Lead Slurry 3.0 10.0 3.3 527.0 80 Suck Down Mix Tub Tail Slurry 2.0 10.0 5.0 10.0 80 Start Mixing Tail Slurry Tail Slurry 5.0 35.0 7.0 45.0 80 Mix&Pump Tail Slurry Tail Slurry 2.0 5.0 2.5 50.0 80 Suck Down Tub 5.0 0.0 80 Drop Top Plug Mud 8.0 10.0 1.3 10.0 80 Kick Out Plug w/Cement 3.0 0.0 80 Swap to Rig Pumps Mud 8.0 307.2 38.4 317.2 80 Rig To Displace Mud 5.0 9.0 1.8 326.2 80 Slow Rate Mud 3.0 1.0 0.3 327.2 80 Bump Plug Pause 0.0 0.0 3.0 0.0 80 Hold Pressure Shut-In 0.0 0.0 3.0 0.0 80 Bleed Off Total 03:10 hr:mn 1004.2 bbl End Job: Check that floats are holding, Dynamic Security Checks: Frac 7 psi at 80.0 ft Pore 1 psi at 80.0 ft Collapse 3953 psi at 4470.0 ft Burst 6026 psi at 0.0 ft Temperature Results BHCT 72 degF Simulated Max HCT 71 degF Simulated BHCT 71 degF Max HCT Depth 4550.0 ft CT at TOC 67 degF Max HCT Time 03:07:57 hr:mn:sc Static temperatures : At Time 1 (hr:mn) 00:03 hr:mn Geo.Temp. Top of Cement (degF) 67 degF 120 degF Bottom Hole (degF) 71 degF 65 degF Page 7 red wolf 2 draft v2 12--12-2011.cfw;03-26-2012: LoadCase 9 5/8 Surface(al,Version wcs-cem471 02 Client : Savant Alaska Well : Red Wolf#2 Schihrger String : 95/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 95/8 Surface(a) ECD Modeled at the Casing Shoe: Depth= 4550 ft -Hydrostatic -Dynamic Frac -Pore � � J C) N cn cna.r O_ co- co t 0 30 60 90 120 150 180 210 Time (min) Page 8 red wolf 2 draft v2 12--12-2011.cfw;03-26-2012, LoadCase 9 5/8 Surface lal;Version wcs-cem471_02 Client : Savant Alaska Well : Red Wolf#2 Schllinherger String : 9 5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9 5/8 Surface(a) ECD Modeled at the Conductor Casing Shoe: Depth= 80 ft Fluids at 4550 ft N— O CV Hydrostatic Dynamic u"? Frac Fore To O aT _ 7- -to u)O -O O) O O_ ao 0 30 60 90 120 150 180 210 Time (min) Page 9 red wolf 2draft v212--t2-20t1.cfw,03-26-2012; LoadCase95/8Surface(a);Version wcs-cem471_02 Client : Savant Alaska Well : Red Wolf#2 Schlmnberger String : 9 5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9 5/8 Surface(a) Slurry BHCT Model: O 00 First Sack Temp. dLast Sack Temp. 000 1 co- N I I gj O O o0 N cpti HI coo p Il o co c0 H 1 1 g1 I - T _. - -- ____.T 0 30 60 90 120 150 180 210 Time (min) Page 10 red wolf 2 draft V212-12-2011.cfw;03-26-2012; LoadCase 9 5/8 Surface(a);Version wcs-cem471_02 Client : Savant Alaska Well : Red Wolf#2 Schhiliberger String : 9 5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9 5/8 Surface(a) Surface Pressure Model: Calc.Pump Ress. Calc.CemHP O O a0 O N p 0 O O co in-Lod O _ O� \ N_ ci L C 0 30 60 90 120 150 180 210 Time (min) Page 11 red wolf 2 draft v2 12--12-2011 cfw;03-26-2012; LoadCase 9 5/8 Surface(a),Version wcs-cem471_02 Client : Savant Alaska Well : Red Wolf#2 ScIoberger String : 9 5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9 5/8 Surface(a) Section 4: fluid description Mud DESIGN Fluid No: 1 Density :8.60 lb/gal Rheo. Model : BINGHAM Pv :38.002 cP At temp. : 120 degF Ty :27.41 Ibf/100ft2 Gel Strength :36.29 Ibf/100ft2 MUD Mud Type :WBM Job volume :327.2 bbl Water Type : Fresh VOLUME FRACTION Solids :5.0% Oil :0.0% Water :95.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : BINGHAM Pv :25.000 cP At temp. :80 degF Ty :35.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) • Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No:3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k :2.10E-1 Ibf.s^n/ft2 At temp. :80 degF n : 0.273 Ty : 1.471bf/100ft2 Gel Strength : 16.51 lbf/100ft2 DESIGN BLEND SLURRY Name : B809 Mix Fluid : 11.513 gal/sk Job volume : 527.0 bbl Dry Density : 110.25 lb/ft3 Yield : 2.45 ft3/sk Quantity : 1209.65 sk Sack Weight : 100 lb Solid Fraction :37.1 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 11.513 gal/sk Page 12 red wolf 2 draft v212--12-2011.cfw;03-26-2012, LoadCase 9 5/8 Surface(al;Version wcs-cem471_02 Client : Savant Alaska Well : Red Wolf#2 Scblmnhrgcr String : 9 5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9 5/8 Surface(a) Tail Slurry DESIGN Fluid No:4 Density : 15.80 lb/gal Rheo. Model : BINGHAM Pv :91.448 cP At temp. :80 degF Ty :7.91 lbf/100ft2 Gel Strength :5.34 lbf/100ft2 DESIGN BLEND SLURRY Name : D907 Mix Fluid : 5.100 gal/sk Job volume :50.0 bbl Dry Density : 199.77 lb/ft3 Yield : 1.16 ft3/sk Quantity :241.12 sk Sack Weight :94 lb Solid Fraction :41.4% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.100 gal/sk Additives Code Conc. Function D046 0.200%BWOC Antifoam D065 0.300%BWOC Dispersant D167 0.350%BWOC Fluid loss S002 0.400%BWOC Accelerator Annulus ID: 9.625 in Flow Rate : 7.0 bbl/min O N —Tail Slurry Lead Slurry MUDPUSH II — Mud O O— 1 O O— O N CL CD CO rn a 0 »- o u_ O_ N 12.0 12.4 12.8 13.2 13.6 14.0 14.4 14.8 15.2 15.6 16.0 16.4 Annulus OD (in) Page 13 red wolf 2 draft v212--12-2011.cfw;03-26-2012, LoadCase 9 5/8 Surface(a);Version wcs-cem471_02 Client : Savant Alaska Well : Red Wolf#2 Schlumberger String : 9 5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9 5/8 Surface(a) Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :4540.0 ft Casing Shoe :4550.0 ft NB of Cent. Used :41 NB of Floating Cent. :41 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 1870.0 0 0/0 0.0 1905.9 4030.0 27 1/2 1502395-9 5/8-6-POSITIVE W051 61.9 3970.0 4510.0 12 1/1 1502395-9 5/8-6-POSITIVE W051 65.0 4470.0 4550.0 2 2/1 1502395-9 5/8-6-POSITIVE W051 65.2 4550.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) 1502395-9 5/8-6- W051 9 5/8 12.000 12.000 Yes Houma N.A. N.A. N A. POSITIVE ft 0 20 40 60 80 100 0- E- j, ■ — Between Cent. + +At Cent. O_ O 0 O O O_ O O O_ O O O O U)— Well Pipe Standoff Payr,1 red wolf 2 draft v212--12-2011.cfw;03-26-2012; LoadCase 9 5/8 Surface lal;Version wcs-cem411 02 Client : Savant Alaska Well : Red Wolf#2 Scalrger String : 95/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 95/8 Surface(a) Section 6: WELLCLEAN II ft 0 50 100 0 25 50 75 100 I J > - Std Betw.Cent. - Mud Contamination -Cement Coverage - Uncontaminated Slurry 1 ' 1 .1-- o V 1 -, Fluid Sequence Cement Coverage Uncontaminated Slu-ry Flak Cmcenhelms flak Mud m the Wee z° 3 z° 0 0 0 0 500- 500 500 500 1000- 1000 1000 1000 1500- 1500 1500 1500 2000 2000 = = 2000 2000 - L - L n 2500 2500 o n. 2500 2500 0- 0 0 0 0 3000 3000 3000 3000 3500 3500 3500 3500 4000 4000 4000 4000 4500 4500 4500 4500 1 1 a, ; a/ a> ; a, -o o -a -o o 0 3 3 0 z z ■ dS e, iiii M DPUSH II ■Meadm ■None Page 15 red wolf 2 draft v2 12--12-2011.cfw;03-26-2012; LoadCase 9 5/8 Surface la);Version wcs-cem471_02 Client : Savant Alaska Well : Red Wolf#2 S Schlumlierger String : 9 5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9 5/8 Surface(a) Section 7: operator summary TOTAL MATERIAL REQUIREMENTS Dead Volumes Additives Total Item Pack. Packaging Comments Quantity Quantity Name B809 120966 lb 1210 sack 100 lb Arctic Set Lite(ASL) D907 22666 lb 242 sack 94 lb Class G-Neat Cement D182 555 lb 23 sack 25 lb MUDPUSH II D031 9536 lb 87 sack 110 lb Barite D046 46 lb 1 sack 50 lb Anti-foam Dry D065 68 lb 2 sack 50 lb Dispersant D167 791b 4 sack 251b FLAC S002 91 lb 1 sack 100 lb Accellerator Mix Water Requirements : Fresh water 453 bbls MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density : 10.10 lb/gal Code Quantity Design Fresh water 92.517 bbl D182 555.103 lb 6.000 lb/bbl of base fluid D031 9535.661 lb 95.36 lb/bbl of spacer Lead Slurry Volume :527.0 bbl Density : 10.70 lb/gal Yield : 2.45 ft3/sk Dry Phase Liquid Phase Blend: 120965 lb Design Mix Water 331.6 bbl 10.0 bbl LAS Design B809 120965.406 Fresh water 331.582 bbl 10.001 bbl lb Tail Slurry Volume :50.0 bbl Density : 15.80 lb/gal Yield : 1.16 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 29.3 bbl 10.0 bbl LAS Design D907 22665.652 lb Fresh water 29.278 bbl 10.001 bbl D046 45.331 lb 0.200%BWOC D065 67.997 lb 0.300%BWOC D167 79.330 lb 0.350%BWOC S002 90.663 lb 0.400%BWOC Page 16 red wolf 2 draft v212-12-2011.cfw;03-26-2012, LoadCase 9 5/6 Surface(a):Version was-cem471_02 Schlumberger Laboratory Cement Test Report Nabors 2ES Red Wolf 2 Surface Lead Field Blend Signatures Fluid No :PAK 12sfc2004 Client :Savant Alaska Location/Rig : Nabors 2ES Date :Apr-06-2012 Well Name : Red Wolf 2 Field : Badami M.Schinnell Job Type 9 5/8"Surface Depth 4550.0 ft TVD 4548.0 ft BHST 65 degF BHCT 71 degF BHP 2034 psi Starting Temp. 80 degF Time to Temp. 00:30 hr:mn Heating Rate -0.30 degF/min Starting Pressure 500 psi Time to Pressure 00:30 hr:mn Schedule () Composition Slurry Density 10.70 lb/gal Yield 2.51 ft3/sk Mix Fluid 12.126 gal/sk Solid Vol. Fraction 35.413% Porosity 64.587% Slurry type Other Code Concentration Sack Reference Component Blend Density Lot Number B809 100.00 lb of BLEND Blend 112.51 Iblft3 ASL(0.84) Fresh water 12.126 gal/sk Base Fluid Rheology (R1-B5) Tem.erature 80de,F 71 detF (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 35.0 35.0 35.0 85.0 85.0 85.0 200 31.0 33.0 32.0 82.0 78.0 80.0 100 26.0 31.0 28.5 76.0 71.0 73.5 60 23.0 31.0 27.0 73.0 67.0 70.0 30 21.0 31.0 26.0 68.0 61.0 64.5 6 13.5 24.8 19.1 16.6 24.0 20.3 3 12.0 15.9 13.9 13.0 13.2 13.1 10 sec Gel 11.1 deg-13.18 Ibf/100ft2 10.2 deg-12.11 Ibf/100ft2 10 min Gel 26.1 deg-31.00 Ibf/100ft2 11.3 deg -13.42 Ibf/100ft2 Rheo.computed I Viscosity:21.123 cP Yield Point:26.44 Ibf/100ft2 l Viscosity:38.392 cP Yield Point:70.49 Ibf/100ft2 Thickenin Time 30 Bc 00:51 hr:mn 70 Bc >06:00 hr:mn Free Fluid 5.0 mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation: None Water Analysis Hot Water Plant Mar-28-2012 Chloride Calcium Magnesium 33 mg/L 80 mg/L 0 mg/L Page 1 Instrument 8240#3 Schlumberger Sampling Period:5 seconds Prudhoe Bay Well Services Laboratory . Telephone:+1 907 659 6155 Facsimile:+1 907 659 9221 250 12000— 100- 225 10800- 90 200 9600- 80- 175 8400- 70- `� 150 .y 7200- m 60 E n : > : 125 5 6000- `m 50- H - N d N - y - - g 101 a 4800— 8 40- 75CI ji 3600 30--- I1�`\ 1 :y T__ 0 50 2400- 20— �NJ"'�+��+�"� ❑ 25 1200- 10- - 0:00 1:00 2:00 3:00 4:00 5:00 6:00 7:00 Time(HH:MM) Location:Red Wolf 2 30 Bc: 1:53:40 File Name:pakl2sfc2004-1-ce113.tst Customer:Savant Alaska 50 Bc:N/A Supervisor:{Info:Supervisor} 70 Bc:N/A Test Started:4/6/2012 6:32:50 AM Density:10.7 Ibm/gal 100 Bc:N/A Test Stopped:4/6/2012 12:45:44 PM System:ASL BHCT:71 degF Printed:4/6/2012 1:01:35 PM BHST:65 degF Job Type:9 5/8"Surface Lead Rig Name:Nabors 2ES Page 1 1 Instrument:Twin Right Current Compressive Strength: 106 psi Schlumberger Sampling Period:30 seconds Final Compressive Strength: 106 psi at 25:13:00 Prudhoe Bay Well Services Laboratory Compressive strength type A(less than 14 lb/gal) Telephone:+1 907 659 6155 Facsimile:+1 907 659 9221 20— 100— 150- 18— 90— 135— . 16— 80— 120— • _ 14— 70— 105— — -.. ....-- IIIIIII11nIngI1IIIlmnmmlmllnn..,ni• S - n - ■ gi 0 12- ! 60- --F- 90- _.. . . _ E - - 10- m 50- d 75- E : E - - - - n - ' 8- 1- 40- o. 60- m o i— - - V - 6- 30— 45— 4-- 20-1" u 30- 2— 10— 15- 0 0 0 0:00 4:00 8:00 12:00 16:00 20:00 24:00 28:00 Time(HH:MM) Location:Red Wolf 2 50 psi: 17:30:30 File Name:pakl2sfc2004-UCA4.tst Customer:Savant Alaska 500 psi:N/A Supervisor:{Info:Supervisor} 1000 psi:N/A Test Started:4/6/2012 7:59:16 AM Density:10.7 Ibm/gal 2000 psi:N/A Test Stopped:4/7/2012 9:12:45 AM System:ASL BHCT:71 degF 12 hr: 1 psi Printed:4/7/20129:30:46 AM BHST:65 degF 24 hr:97 psi Job Type:9 5/8"Surface Lead Page 1 Rig Name:Nabors 2ES Schlumberger Laboratory Cement Test Report Nabors 2ES Red Wolf 2 Surface Tail Field Blend Signatures Fluid No : PAK 12sfc2005 Client :Savant Alaska Location/Rig : Nabors 2ES Date :Apr-06-2012 Well Name : Red Wolf 2 Field : Badami M. Schinnell Job Type 9 5/8"Surface Depth 4550.0 ft TVD 4548.0 ft BHST 65 degF BHCT 71 degF BHP 2034 psi Starting Temp. 80 degF Time to Temp. 00:30 hr:mn Heating Rate -0.30 degF/min Starting Pressure 500 psi Time to Pressure 00:30 hr:mn Schedule ( ) Composition Slurry Density 15.80 lb/gal Yield 1.16 ft3/sk Mix Fluid 5.100 gal/sk Solid Vol.Fraction 41.443°/u Porosity 58.557% Slurry type Conventional Code Concentration Sack Reference Component Blend Density Lot Number G 94.00 lb of CEMENT Blend 199.77 lb/ft3 Fresh water 5.100 gal/sk Base Fluid D046 0.200%BWOC Antifoam TU1H0300A0 D065 0.300%BWOC Dispersant ZA1917SC23 D167 0.350%BWOC Fluid loss DALA085543 S002 0.400%BWOC Accelerator ZD06CC11 Rheology Tem•erature 80 degF 71 de.F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 102.0 102.0 102.0 98.0 98.0 98.0 200 79.0 80.0 79.5 79.0 84.0 81.5 100 62.0 63.0 62.5 53.0 53.0 53.0 60 48.0 43.0 45.5 30.0 28.0 29.0 30 28.0 35.0 31.5 19.0 18.0 18.5 6 15.8 25.7 20.8 8.6 6.5 7.6 3 11.7 24.7 18.2 5.1 5.6 5.3 10 sec Gel 25.3 deg-27.00 Ibf/100ft2 5.9 deg-6.30 Ibf/100ft2 10 min Gel 71.7 deg-76.53 Ibf/100ft2 15.3 deg -16.33 Ibf/100ft2 Rheo.computed I Viscosity:76.758 cP Yield Point:29.24 Ibf/100ft2 I Viscosity:93.197 cP Yield Point: 13.30 Ibf/100ft2 Thickenin Time 30 Bc 02:49 hr:mn 70 Bc 03:32 hr:mn 100 Bc 03:46 hr:mn Free Fluid Trace mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation: None Fluid Loss ' API Fluid Loss 159 mL 48 mL in 11 min at 71 degF and 1000 psi Water Analysis Hot Water Plant Mar-28-2012 Chloride Calcium Magnesium 33 mg/L 80 mg/L 0 mg/L Page 1 Instrument:8240#4 Schlumberger Sampling Period:5 seconds Prudhoe Bay Well Services Laboratory Telephone:+1 907 659 6155 Facsimile:+1 907 659 9221 250 12000- 100- 225- 10800- 90- 200- 9600- 80- 175- 8400- 70- LL 150- .y 7200- m 60- E : a : > : _ - U _ 125- = 6000Y 50- d - - - 0 - N - .fA . 100- a 4800- 3 40- . 75- o 3600- 30- _ - o o - - - 507 2400-20- w 25- 1200- 10 0:00 0:30 1:00 1:30 2:00 2:30 3:00 3:30 4:00 Time(HH:MMI Location:Red Wolf 2 30 Bc:2:57:45 File Name:pakl2sfc2005-1-cell4.tst Customer:Savant Alaska 50 Bc:3:19:35 Supervisor:{Info:Supervisor) 70 Bc:3:32:20 Test Started:4/5/2012 7:37:46 PM Density: 15.8 Ibm/gal 100 Bc:3:47:05 Test Stopped:4/5/2012 11:24:51 PM System:G+.2%046+.3%065+.35%0167+.4%S002 BHCT:71 degF Printed:4/6/2012 8:03:15 AM BHST:65 degF Job Type:9 5/8"Surface Tail Rig Name: Nabors 2ES Page 1 Instrument:Twin Left Current Compressive Strength: 1855 psi Schlumberger Sampling Period:30 seconds Final Compressive Strength:1855 psi at 24:04:00 Prudhoe Bay Well Services Laboratory Compressive strength type B(more than 14 lb/gal) Telephone:+1 907 659 6155 Facsimile:+1 907 659 9221 20— 100- 2000- • 18— 90— 1800— . s---- 16— 80— 1600— 147 707 1400- - ,' V"""uV0^16 2 a Q• 12- —- 60- c 1200- - y - E d 10- E 50— y 1000- • - •E- H - '- 8- H 40- n 800 - F2 - o I— - = U 6— ri 30- 600- i, 4— 20— 7 400- 2— 10— 200— 0 0 0 1 ` 1 1 I , 0:00 4:00 8:00 12:00 16:00 20:00 24:00 28:00 Time(HH:MM) Location:Red Wolf 2 50 psi:5:40:30 File Name:pakl 2sf c2005-UCA3.tst Customer:Savant Alaska 500 psi:11:57:00 Supervisor:(Info:Supervisor) 1000 psi:16:04:00 Test Started:4/6/2012 9:21:27 AM Density:15.8 Ibm/gal 2000 psi:N/A Test Stopped:4/7/2012 9:25:40 AM System:G+.2%D46+.3%D65+.35%D167+.4%5002 BHCT:71 degF 12 hr:504 psi Printed:4/7/20129:32:01 AM BHST:65 degF 24 hr: 1847 psi Job Type:9 5/8'Surface Tail Page 1 Rig Name:Nabors 2ES Schlumberger Laboratory Cement Test Report Nabors 7ES Red Wolf 2 Surface Top Out Field Blend Signatures Fluid No : PAK 12cnd2003 Client :Savant Alaska Location/Rig : Nabors 7ES Date :Apr-10-2012 Well Name : Red Wolf 2 Field : Badami M. Schinnell Job Type Surface Top Out Depth 4550.0 ft TVD 4548.0 ft BHST 65 degF BHCT 71 degF BHP 2034 psi Starting Temp. 80 degF Time to Temp. 00:30 hr:mn Heating Rate -0.30 degF/min Starting Pressure 500 psi Time to Pressure 00:30 hr:mn Schedule () Composition Slurry Density 10.70 lb/gal Yield 2.49 ft3/sk Mix Fluid 11.928 gal/sk Solid Vol.Fraction 35.943% Porosity 64.057% Slurry type Other Code Concentration Sack Reference Component Blend Density Lot Number B809 100.00 lb of BLEND Blend 111.77 Ib/ft3 ASL(0.83) Fresh water 11.928 gal/sk Base Fluid Rheology(R1-B5) Tem.erature 80 de•F 71 de.F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 24.0 24.0 24.0 78.0 178.0 78.0 200 19.0 24.0 21.5 72.0 75.0 73.5 100 17.0 23.0 20.0 70.0 65.0 67.5 60 16.0 23.0 19.5 68.0 61.0 64.5 30 14.0 23.0 18.5 63.0 58.0 60.5 6 9.1 22.2 15.7 15.2 22.7 19.0 3 8.4 17.8 13.1 12.6 12.3 12.5 10 sec Gel 10.3 deg- 12.23 Ibf/100ft2 9.0 deg- 10.69 Ibf/100ft2 10 min Gel 30.5 deg-36.22 Ibf/100ft2 11.9 deg -14.13 Ibf/100ft2 Rheo.computed I Viscosity: 12.224 cP Yield Point: 18.96 Ibf/100ft2 I Viscosity:33.702 cP Yield Point:65.25 lbf/100ft2 Thickenin Time 30 Bc 02:06 hr:mn 70 Bc >06:00 hr:mn Free Fluid 6.0 mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation: None Water Analysis Hot Water Plant Apr-07-2012 Chloride Calcium Magnesium 107 mg/L 71 mg/L 18 mg/L Page 1 Instrument:7222-460#1 Schlumberger Sampling Period:5 seconds Prudhoe Bay Well Services Laboratory Telephone:+1907 659 6155 Facsimile:+1 907 659 9221 250— 12000— 1007 225— 10800— 907 200- 9600- 80- 175— 8400— 70— 1507 7200— m 60— 9 - N _ T _ g - m - - N 1257 g 60007 m 50- 0 = NN E N c y o I— 100— 4800— 0 407 75— ❑ 36007 7 30---- 507 2400— 20— ❑ 25— 12007 10 0 0 0 S I I 0:00 1:00 2:00 3:00 4:00 5:00 6:00 7:00 Time(HH:MM) Location:Red Wolf 2 30 Bc:2:19:40 File Name:pakl2cnd2003-1-cellt.tst Customer:Savant Alaska 50 Bc:N/A Supervisor:Hacker/Giafaglione 70 Bc:N/A Test Started:4/9/2012 9:57:16 PM Density:10.7lbm/gal 100 Bc:N/A Test Stopped:4/10/2012 4:04:17 AM System:ASL BHCT:71 degF Printed:4/10/2012 4:12:22 AM BHST:65 degF Job Type:Surface Top Out Rig Name:Nabors 7ES Page 1 Schlumberger Cementing Job 1.,:port CemCATv1.4 Well Red Wolf#2 Client Schlumberger Field Badami SIR No. Engineer Craig Sampsell/H Griggs/Joleen Oshiro Job Type 9 5/8"Surface Country United States Job Date 04-09-2012 Time 11 Cmt. Unit Pressu Tub Density — Pump Rate Well Head Press Messages 04/09/201205:22:17 11:26:58 1---_, J Batch up MudPush II Start pumping MudPush II t Ch ck tripsure test 11:47:00 1 Bleed Off Pressure Start pumping Mudpush 30 bbls away i60 bbl away 12:07:00 L.._ Reset Total,Vol=96.05 bbl Drop Bottom Plug Start pumping Lead 12:27:00 50 bbl away I 100 bbl away 12:47:00 150bbl away 200 bbl away 13:07:00 250 bbl away 300 bbl away 13:27:00 400 bbl away 13:47:00 JReset Total,Vol=477.47 bbl I ::b::: talslu 14:07:00 Reset Total,Vol=53.50 bbl r Drop Top Plug 14:27:00 Kick top plug Reset Total,Vol=10.08 bbl Swap to rig pump for displacemer Blow air back to cement unit 450 stks away at 70stk/min . H.. 1000 stk away 14:47:00 j 1700 stk away 2500 stk away 15:07:00 l'r Bump Top Plug 15:27:00 J 15:39:42 hh:mm:ss 0.00 400 600 1200 1600 2000 8.0 10.0 12.0 14.0 16.0 18.0 0.00 2.0 4.0 6.0 8.0 10.0 0.00 400 800 1200 1600 2000 04/10/201205:x:96 --._..---PSI LB/G B/M PSI 05/16/2012 13:52:21 Schlumberger Cementing Service Report Customer Job Number Schlumberger Well Location(legal) Schlumberger Location Job Start Red Wolf#2 Badami PAK Apr/09/2012 Field Formation Name/Type Deviation Bit Size Well MD Well TVD Badami Clean-Sandstone 3 deg 12.3 in 3872.0 ft ft County Beechy Point State/Province Alaska BHP BHST BHCT Pore Press.Gradient Well Master API/DWI Psi 65 degF 71 degF 8.44 lb/gal Rig Name Drilled For Service Via Casing/liner Nabors 7ES Oil&Gas Land Depth,ft Size,in Weight,lb/ft Grade Thread Offshore Zone Well Claw Well Type 80.0 20.0 94.0 New Exploration 3872.0 9.6 47.0 Drilling Fluid Type Max.Density Plastic Viscosity Tubing/Drip Pipe lb/gal CP T/D Depth,ft Size,in Weight,Ib/ft Grade Thread Service Line Job Type D 5.0 Cementing 9 5/8"Surface 0.0 Max.Allowed Tub.Press Max.Allowed Ann.P WH Connection Perforations/Open Hole 3500 psi psi Top,ft Bottom,ft shot/ft No.of Shots Total Interval Service Instructions ft ft ft 100 bbls MUDPUSH II'@ 10.1 ppg 472 bbls ASL lead @ 10.7 ppg ft ft Diameter 50 bbls tail @ 15.8 ppg ft ft in Treat Down Displacement Packer Type Packer Depth Casing bbl ft Tubing Vol. Casing VoL Annular Vol. Openhole Vol. bbl bbl bbl bbl Casing/Tubing Secured ❑ 1 Hole Vol.Circulated prior to Cement E Casing Tools Sq Job lift Pressure psi Shoe Type Sq Type Pipe Rotated ❑ Pipe Reciprocated ❑ Shoe Depth ft Tool Type No.Centralizers Top Plugs Bottom Plugs Stage Tool Type Tool Depth ft Cement Head Type Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Arrived on Location Leave Location Collar Type Tail Pipe Depth ft Apr/09/2012 02:00 Apr/09/2012 03:00 Apr/09/2012 Collar Depth ft Sqz.Total Vol. bbl Date Tbne Unit Flow Density Volume Wellhead Message 24 hr Pressure Rate LB/6 BBL Pressure dock PSI B/M PSI 04/09/2012 05:27:27 12 0.0 -0.60 0.0 293 Started Acquisition 04/09/2012 05:27:43 13 0.0 -0.60 0.0 293 Begin circulating bottoms up 04/09/2012 05:28:27 11 0.0 -0.61 0.0 288 04/09/2012 05:28:39 12 0.0 -0.60 0.0 299 Mud weight=9.3ppg 04/09/2012 05:29:23 12 0.0 -0.60 0.0 291 circulating @ 5 bpm 04/09/2012 07:13:54 13 0.0 -0.61 0.0 229 5 bpm,291 psi on rig pressure gauge 04/09/2012 08:59:24 13 0.0 -0.61 0.0 224 Pre-Job Safety meeting 04/09/2012 08:59:27 13 0.0 -0.61 0.0 225 04/09/2012 11:27:30 181 0.0 10.07 0.0 184 Batch up MudPush II 04/09/2012 11:36:46 15 0.0 10.12 0.0 -26 Start pumping MudPush II 04/09/2012 11:37:27 102 1.5 10.12 0.9 17 04/09/2012 11:39:06 49 0.0 10.12 5.2 3 Start pressure test 04/09/2012 11:41:33 716 0.0 11.04 5.2 674 Check trip 04/09/2012 11:42:27 672 0.0 11.24 5.2 619 04/09/2012 11:45:05 43 0.0 11.07 5.2 -14 Bleed Off Pressure 04/09/2012 11:46:32 45 0.0 10.60 5.2 -13 Start pumping Mudpush 04/09/2012 11:48:27 413 4.8 10.17 11.3 114 04/09/2012 11:49:27 407 4.8 9.49 16.1 110 04/09/2012 11:52:58 406 4.8 10.09 32.9 97 30 bbls away 04/09/2012 11:58:35 386 4.8 10.04 59.8 81 60 bbl away 04/09/2012 12:00:27 378 4.8 10.05 68.7 72 Page 1 of 9 Well Field Job Start Customer lob Number Red Wolf#2 Badami Apr/09/2012 Schlumberger Date Time Unit Flow Density Volume Wellhead Message 24-hr Pressure Rate LB/6 BBL Pressure dock PSI B/M PSI 04/09/2012 12:10:01 20 0.0 10.18 96.1 -23 Drop Bottom Plug 04/09/2012 12:19:53 100 1.8 10.91 96.2 -4 Start pumping Lead 04/09/2012 12:27:27 537 4.9 10.71 130.3 96 04/09/2012 12:28:27 538 4.8 10.68 135.1 97 04/09/2012 12:29:27 522 4.8 10.73 140.0 86 04/09/2012 12:30:27 511 4.9 10.59 144.8 81 04/09/2012 12:30:53 517 4.8 10.65 146.9 81 50 bbl away 04/09/2012 12:31:27 509 4.8 10.69 149.6 80 04/09/2012 12:33:27 521 4.8 10.43 159.3 77 04/09/2012 12:34:27 510 4.8 10.53 164.1 79 04/09/2012 12:35:27 511 4.8 10.67 169.0 77 04/09/2012 12:36:27 507 4.8 10.71 173.8 74 04/09/2012 i 12:37:27 512 4.9 10.53 178.7 78 1 04/09/2012 ; 12:38:27 508 4.9 10.72 183.5 73 04/09/2012 i 12:39:27 517 4.9 10.71 188.3 80 -1 04/09/2012 12:40:27 520 4.8 10.66 193.2 83 04/09/2012 12:41:27 508 4.8 10.65 198.0 78 04/09/2012 12:41:31 508 4.9 10.65 198.3 78 100 bbl away 04/09/2012 12:42:27 519 4.8 10.74 202.8 81 04/09/2012 12:43:27 518 4.8 10.60 207.7 83 04/09/2012 12:44:27 505 4.8 10.77 212.5 79 04/09/2012 12:45:27 523 4.9 10.68 217.3 84 04/09/2012 12:46:27 515 4.8 10.60 222.2 84 04/09/2012 12:47:27 518 4.8 10.73 227.0 85 04/09/2012 12:48:27 515 4.9 10.78 231.8 80 04/09/2012 12:49:27 513 4.8 10.70 236.7 83 04/09/2012 12:50:27 526 5.0 10.66 241.5 85 04/09/2012 12:51:27 524 4.9 10.66 246.3 83 04/09/2012 12:52:27 518 4.8 10.65 251.1 86 04/09/2012 12:53:01 504 4.9 10.65 253.9 82 150bbl away 04/09/2012 12:53:27 507 4.8 10.66 256.0 80 04/09/2012 12:54:27 514 4.9 10.65 260.8 85 04/09/2012 12:55:27 501 4.8 10.63 265.6 80 04/09/2012 12:56:27 509 4.8 10.72 270.5 85 04/09/2012 12:57:27 499 4.7 10.74 275.3 89 04/09/2012 12:58:27 528 5.0 10.62 280.3 88 04/09/2012 12:59:27 540 5.0 10.56 285.3 99 04/09/2012 13:00:27 563 5.0 10.72 290.2 102 04/09/2012 13:01:27 528 5.0 10.77 295.2 89 04/09/2012. 13:02:00 570 5.0 10.79 297.9 102 200 bbl away 04/09/2012 13:02:27 534 5.0 10.78 300.2 93 04/09/2012 13:03:27 556 5.0 10.72 305.1 93 04/09/2012 13:04:27 533 5.0 10.53 310.1 89 04/09/2012 13:05:27 544 5.0 10.45 315.1 94 04/09/2012 13:06:27 509 5.0 10.89 320.1 82 04/09/2012 13:07:27 530 5.0 10.93 325.0 88 04/09/2012 13:08:27 561 5.0 10.72 330.0 100 04/09/2012 13:09:27 534 5.0 10.48 335.0 90 04/09/2012 13:10:27 557 5.0 10.57 340.0 103 04/09/2012 13:11:27 536 5.0 10.76 345.0 97 04/09/2012 13:12:10 529 5.0 10.76 348.5 89 250 bbl away 04/09/2012 13:12:27 527 5.0 10.71 349.9 91 04/09/2012 13:13:27 558 5.0 10.70 354.9 103 04/09/2012 13:14:27 553 5.0 10.67 359.9 102 Page 2 of 9 Well Field lob Start Customer lob Number Red Wolf#2 Badaml Apr/09/2012 Schlumberger I i Data Time Unit Flow Density Volume Wellhead Message 24-hr Pressure Rate LB/6 BBL Pressure clock PSI B/R PSI 04/09/2012 13:16:27 582 5.0 10.78 369.8 105 04/09/2012 13:17:27 551 5.0 10.59 374.8 102 04/09/2012 13:18:27 567 5.0 10.65 379.8 108 04/09/2012 13:19:27 569 5.0 10.56 384.8 109 04/09/2012 13:20:27 557 5.0 10.96 389.7 118 04/09/2012 13:21:27 556 5.0 10.75 394.7 105 04/09/2012 13:22:04 595 5.0 10.67 397.8 117 300 bbl away 04/09/2012 13:22:27 573 5.0 10.65 399.7 131 04/09/2012 13:23:27 695 5.1 10.64 404.7 223 04/09/2012 13:24:27 702 5.0 10.63 409.8 219 04/09/2012 13:25:27 660 5.1 10.58 414.9 223 04/09/2012 13:26:27 705 5.0 10.90 419.9 242 04/09/2012 13:27:27 697 5.1 10.84 425.0 241 04/09/2012 13:28:27 701 5.1 10.59 430.1 241 04/09/2012 13:29:27 730 5.1 10.69 435.1 245 04/09/2012 13:30:27 711 5.2 10.69 440.3 268 04/09/2012 13:31:27 769 5.1 10.66 445.4 297 04/09/2012 13:32:27 781 5.1 10.64 450.6 299 04/09/2012 13:33:27 735 5.2 10.63 455.7 295 04/09/2012 13:34:27 780 5.1 10.71 460.8 308 04/09/2012 13:35:27 739 5.1 10.65 466.0 301 04/09/2012 13:36:27 786 5.1 10.57 471.1 327 04/09/2012 13:37:27 813 5.1 10.60 476.3 344 04/09/2012 13:38:27 739 5.1 10.67 481.5 324 04/09/2012 13:39:27 818 5.1 10.65 486.6 362 04/09/2012 13:40:27 775 5.1 10.62 491.8 340 04/09/2012 13:41:27 831 5.1 10.75 496.9 385 04/09/2012 13:41:48 811 5.2 10.76 498.7 358 400 bbl away 04/09/2012 13:42:27 846 5.2 10.78 502.1 374 04/09/2012 13:43:27 822 5.2 10.73 507.2 360 04/09/2012 13:44:27 826 5.2 10.68 512.4 385 04/09/2012 13:45:27 897 5.2 10.65 517.5 419 04/09/2012 13:46:27 821 5.1 10.66 522.7 384 04/09/2012 13:47:27 879 5.1 10.67 527.8 404 04/09/2012 13:48:27 883 5.1 10.70 533.0 404 04/09/2012 13:49:27 853 5.1 10.60 538.1 433 04/09/2012 13:50:27 859 5.2 10.70 543.3 427 04/09/2012 13:51:27 885 5.1 10.74 548.4 453 04/09/2012 13:52:27 932 5.2 10.70 553.6 461 04/09/2012 13:53:27 912 5.1 10.81 558.7 452 04/09/2012 13:54:27 539 3.3 10.88 562.6 312 04/09/2012 13:55:27 619 3.5 10.89 566.2 346 04/09/2012 13:56:27 721 4.0 10.95 570.1 405 04/09/2012 13:57:27 198 2.7 10.96 573.5 226 04/09/2012 13:57:36 201 0.0 10.89 573.5 170 Reset Total,Vol=477.47 bbl 04/09/2012 13:57:52 193 0.0 10.88 573.5 66 Start pumping tail slurry 04/09/2012 13:58:27 186 0.0 10.87 573.5 6 04/09/2012 13:59:27 178 0.0 8.47 573.5 5 04/09/2012 14:00:27 173 0.0 9.16 573.5 5 04/09/2012 14:01:27 169 0.0 10.49 573.5 5 04/09/2012 14:02:27 166 0.0 12.31 573.5 5 04/09/2012 14:03:27 163 0.0 14.56 573.5 5 04/09/2012 14:04:27 162 0.0 16.40 573.5 5 04/09/2012 14:05:27 160 0.0 15.63 573.5 5 Page 3 of 9 Well Field Job Start Customer Job Number Red Wolf#2 Badami Apr/09/2012 Schlumberger Date Time Unit Flow Density Volume WeNhead Message 24-hr Pressure Rate LB/G BBL Pressure dodo PSI B/M PSI 04/09/2012 14:07:27 683 3.4 15.91 574.7 96 04/09/2012 14:08:27 804 3.7 15.73 578.2 148 04/09/2012 14:09:27 935 3.7 15.68 582.0 302 04/09/2012 14:10:27 1085 3.7 15.41 585.7 441 04/09/2012 14:11:27 1175 4.0 15.75 589.5 472 04/09/2012 14:12:27 1234 4.2 15.85 593.5 467 04/09/2012 14:13:27 1437 4.6 15.65 598.0 555 04/09/2012 14:14:27 1547 4.7 15.67 602.8 571 04/09/2012 14:14:43 1558 4.7 15.71 604.1 568 30 bbl away 04/09/2012 14:15:27 1498 4.7 16.36 607.6 554 04/09/2012 14:16:27 1502 4.8 15.51 612.3 551 04/09/2012 14:17:27 1366 4.7 15.52 617.1 510 04/09/2012 14:18:27 1194 4.1 15.53 621.4 483 04/09/2012 14:19:27 1170 4.1 15.50 625.4 475 04/09/2012 14:20:27 70 0.0 15.53 627.0 28 04/09/2012 14:20:37 72 0.0 15.53 627.0 15 Reset Total,Vol=53.50 bbl 04/09/2012 14:21:04 73 0.0 15.53 627.0 14 Drop Top Plug 04/09/2012 14:21:27 73 0.0 15.53 627.0 13 04/09/2012 14:22:27 53 0.0 15.54 627.0 13 04/09/2012 14:22:40 1019 4.4 15.54 627.5 190 Kick top plug 04/09/2012 14:23:27 657 5.1 15.25 631.5 319 04/09/2012 14:24:27 426 3.0 13.02 636.5 320 04/09/2012 14:24:51 149 0.0 12.68 637.1 132 Reset Total,Vol=10.08 bbl 04/09/2012 14:25:27 130 0.0 11.72 637.1 4 04/09/2012 14:26:27 127 0.0 10.72 637.1 -0 04/09/2012 14:26:41 126 0.0 10.65 637.1 0 Swap to rig pump for displacement 04/09/2012 14:27:27 125 0.0 10.27 637.1 71 04/09/2012 14:28:27 122 0.0 10.01 637.1 404 04/09/2012 14:29:27 82 0.0 9.87 637.1 537 04/09/2012 14:30:00 93 0.0 9.81 637.1 561 Blow air back to cement unit 04/09/2012 14:30:27 81 0.0 9.79 637.1 583 04/09/2012 14:31:27 31 0.0 9.73 637.1 622 04/09/2012 14:32:27 13 0.0 9.69 637.1 649 04/09/2012 14:33:27 50 0.0 8.33 637.1 693 04/09/2012 14:33:55 51 0.0 8.49 637.1 711 450 stks away at 70stk/min 04/09/2012 14:34:27 50 0.0 8.57 637.1 734 04/09/2012 14:35:27 46 0.0 9.17 637.1 772 04/09/2012 14:36:27 49 0.0 10.36 637.1 802 04/09/2012 14:37:27 47 0.0 10.14 637.1 768 04/09/2012 14:38:27 39 0.0 9.96 637.1 842 04/09/2012 14:39:27 39 0.0 10.29 637.1 901 04/09/2012 14:40:27 35 0.0 12.81 637.1 951 04/09/2012 14:41:27 37 0.0 14.38 637.1 1026 04/09/2012 14:42:16 34 0.0 14.06 637.1 981 1000 stk away 04/09/2012 14:42:27 33 0.0 13.87 637.1 1006 04/09/2012 14:43:27 30 0.0 13.48 637.1 286 04/09/2012 14:44:27 23 0.0 13.57 637.1 227 04/09/2012 14:45:27 19 0.0 13.56 637.1 203 04/09/2012 14:46:27 18 0.0 8.93 637.1 196 04/09/2012 14:47:27 17 0.0 8.96 637.1 198 04/09/2012 14:48:27 17 0.0 8.97 637.1 197 04/09/2012 14:49:27 15 0.0 8.97 637.1 209 04/09/2012 14:50:21 15 0.0 8.68 637.1 207 1700 stk away 04/09/2012 14:50:27 16 0.0 8.67 637.1 217 Page 4 of 9 Well Field Job Start Customer Job Number Red Wolf#2 Badami Apr/09/2012 Schlumberger Date Time unit Flow Density Volume Wellhead Message 24-hr Pressure Rate LB/0 BBL Pressure dock PSI B/M PSI 04/09/2012 14:52:27 15 0.0 8.40 637.1 219 04/09/2012 14:53:27 14 0.0 8.36 637.1 230 04/09/2012 14:54:27 13 0.0 8.26 637.1 237 04/09/2012 14:55:27 13 0.0 8.25 637.1 238 04/09/2012 14:56:27 13 0.0 8.33 637.1 246 04/09/2012 14:57:27 13 0.0 8.24 637.1 248 04/09/2012 14:58:27 13 0.0 8.24 637.1 244 04/09/2012 14:59:27 13 0.0 8.19 637.1 243 04/09/2012 15:00:27 45 0.0 8.21 637.1 257 04/09/2012 15:01:27 322 0.0 8.31 637.1 279 04/09/2012 15:01:41 203 0.0 8.31 637.1 285 2500 stk away 04/09/2012 15:02:27 81 0.0 8.30 637.1 302 04/09/2012 15:03:27 18 0.0 8.31 637.1 339 04/09/2012 15:04:27 13 0.0 8.31 637.1 358 04/09/2012 15:05:27 14 0.0 8.31 637.1 376 04/09/2012 15:06:27 70 0.0 8.28 637.1 405 04/09/2012 15:07:27 95 0.0 8.30 637.1 423 04/09/2012 15:08:27 96 0.0 8.30 637.1 443 04/09/2012 15:09:27 18 0.0 8.31 637.1 458 04/09/2012 15:10:27 13 0.0 8.31 637.1 485 04/09/2012 15:11:27 24 0.0 8.31 637.1 507 04/09/2012 15:12:27 24 0.0 8.31 637.1 537 04/09/2012 15:13:27 22 0.0 8.31 637.1 564 04/09/2012 15:14:27 21 0.0 8.31 637.1 583 04/09/2012 15:15:27 143 0.0 8.31 637.1 621 04/09/2012 15:16:27 5 0.0 8.31 637.1 646 04/09/2012 15:17:27 34 0.0 8.30 637.1 668 04/09/2012 15:18:27 12 0.0 7.97 637.1 700 04/09/2012 15:19:27 23 0.0 8.31 637.1 616 04/09/2012 15:20:27 47 0.0 8.30 637.1 629 04/09/2012 15:21:27 47 0.0 8.30 637.1 643 04/09/2012 15:22:27 47 0.0 8.30 637.1 643 04/09/2012 15:23:19 13 0.0 8.31 637.1 1297 Bump Top Plug 04/09/2012 15:23:27 13 0.0 8.31 637.1 1293 04/09/2012 15:24:27 10 0.0 8.31 637.1 1281 04/09/2012 15:25:27 9 0.0 8.32 637.1 1276 04/09/2012 15:26:27 12 0.0 8.31 637.1 1273 04/09/2012 15:27:27 11 0.0 8.31 637.1 1232 04/09/2012 15:28:27 10 0.0 8.32 637.1 62 04/09/2012 15:29:27 10 0.0 8.32 637.1 -1 04/09/2012 15:30:27 11 0.0 8.32 637.1 -1 04/09/2012 15:31:27 10 0.0 8.31 637.1 -1 04/09/2012 15:32:27 9 0.0 8.32 637.1 -2 04/09/2012 15:33:27 10 0.0 8.32 637.1 -1 04/09/2012 15:34:27 9 0.0 8.32 637.1 -2 04/09/2012 15:35:27 9 0.0 8.32 637.1 -2 04/09/2012 15:36:27 9 0.0 8.32 637.1 -2 04/09/2012 15:37:27 9 0.0 8.32 637.1 -2 04/09/2012 15:38:27 8 0.0 8.32 637.1 -1 04/09/2012 15:39:27 9 0.0 8.32 637.1 6 04/09/2012 22:09:27 116 0.0 8.33 637.1 191 04/09/2012 22:09:48 116 0.0 8.33 637.1 199 Pressure test rig line for Top up Job 04/09/2012 22:10:27 116 0.0 8.33 637.1 198 04/09/2012 22:11:27 116 0.0 8.33 637.1 196 Page 5 of 9 Schlumberger Cementing Job _ .import CemCATv1.4 Well Red Wolf#2 Client Schlumberger Field Badami SIR No. Engineer Craig Sampsell/H Griggs/Joleen Oshiro Job Type 9 5/8"Surface Country United States Job Date 04-09-2012 Time Cmt. Unit Pressu Tub Density Pump Rate I Well Head Press Messages 04:01:23 Pump 10 bbl water ahead 04:11:00 Low Pressure stall ' " < High PT 2500 psi High PT good.Bleeding off pressu Reset Total,Vol=9.66 bbl Start batching up first tub of ASL Reset Total,Vol=0.00 bbl 04:21:00 lii. Cement to weight..10.7 ppg Start pumping cement seeing returns in cellar Lab called..cement tests are good 04:31:00 • Swapping water trucks 04:41:00 Swap silo 48 bbl mix water used 04:51:00 si 05:01:00 05:11:00 Sucking down big tub Reset Total.Vol=148.14 bbl Pumping 6 bbl water 05:21:00 Down on pump.Closing ported co Reset Total,Vol=5.94 bbl P Pressuring up collar to 1000 psi IBleeding pressure off l I ' Rotating collar , 05:31:00 PT to 1000 psi I Bleeding off pressure -i C . Pulling up PT to 250 l si Reset Total PVol=0.30 bbl Pumping 40 bbl water at 3 bpm Pumping 50 bbl water 05:41:00 05:51:00 05:58:06 Permission to rig down hh:mm:ss 0.00 400 800 1200 1600 2000 8.0 10.0 12.0 14.0 16.0 18.0 0.00 2.0 4.0 6.0 8.0 10.0 0.00 900 800 1200 1600 2000 00/10/2012 05:58:06 PSI LB/G B/M PSI 05/16/2012 13:54:40 Well Field lob Start Customer lob Number Red Wolf#2 Badami Apr/09/2012 Schlumberger Date Time Unit Flow Density Volume Wellhead Massage 24-hr Pressure Rate LB/6 BBL Pressure clock PSI B/M PSI 04/09/2012 22:13:27 116 0.0 8.33 637.1 30 04/09/2012 22:14:27 116 0.0 8.33 637.1 29 04/09/2012 22:15:27 115 0.0 8.33 637.1 29 04/09/2012 22:16:27 116 0.0 8.33 637.1 29 04/09/2012 22:17:27 115 0.0 8.33 637.1 29 04/09/2012 22:18:27 114 0.0 8.33 637.1 30 04/09/2012 22:19:27 114 0.0 8.33 637.1 29 04/09/2012 22:20:27 115 0.0 8.33 637.1 26 04/09/2012 22:21:27 114 0.0 8.33 637.1 25 04/10/2012 01:13:06 7 0.0 8.33 637.1 9 Change out with 3oleen,offloading ASL to silo 04/10/2012 03:42:27 7 0.0 8.33 637.1 7 04/10/2012 03:42:32 7 0.0 8.33 637.1 7 Blow air down hard line 04/10/2012 03:43:27 7 0.0 8.33 637.1 7 04/10/2012 03:44:27 8 0.0 8.33 637.1 7 04/10/2012 03:44:41 7 0.0 8.33 637.1 7 Trips set to 500 psi for prime up 04/10/2012 03:45:27 7 0.0 8.32 637.1 7 04/10/2012 03:46:27 8 0.0 8.33 637.1 7 04/10/2012 03:47:27 8 0.0 8.33 637.1 7 04/10/2012 03:48:27 -30 0.0 8.25 637.1 7 04/10/2012 03:49:27 -23 0.0 8.29 637.1 7 04/10/2012 03:50:27 141 0.0 8.32 637.1 7 04/10/2012 03:51:27 109 0.0 8.33 637.1 7 04/10/2012 03:52:27 115 0.0 8.33 637.1 7 04/10/2012 03:53:27 114 0.0 8.33 637.1 7 04/10/2012 03:54:27 135 0.0 8.33 637.1 7 04/10/2012 03:55:27 116 0.0 8.33 637.1 7 04/10/2012 03:56:27 9 0.0 8.33 637.1 7 04/10/2012 03:57:27 9 0.0 8.33 637.1 7 04/10/2012 03:58:27 1 0.0 8.33 637.1 7 04/10/2012 03:59:27 5 0.0 8.33 637.1 7 04/10/2012 04:00:27 5 0.0 8.33 637.1 7 04/10/2012 04:01:27 55 0.0 8.33 637.1 7 04/10/2012 04:02:27 9 0.0 8.33 637.1 7 04/10/2012 04:03:27 10 0.0 8.33 637.1 7 04/10/2012 04:04:27 10 0.0 8.33 637.1 7 04/10/2012 04:05:27 11 0.0 8.33 637.1 8 04/10/2012 04:05:28 11 0.0 8.33 637.1 8 Pump 10 bbl water ahead 04/10/2012 04:06:27 114 2.0 8.33 638.6 47 04/10/2012 04:07:27 157 2.5 8.33 641.0 56 04/10/2012 04:08:27 155 2.6 8.33 643.5 57 04/10/2012 04:09:27 163 2.5 8.33 646.0 61 04/10/2012 04:10:27 37 0.0 8.33 646.7 25 04/10/2012 04:11:10 38 0.0 8.33 646.7 24 Low Pressure stall 04/10/2012 04:11:27 826 0.0 8.33 646.7 849 04/10/2012 04:11:53 808 0.0 8.33 646.7 801 High PT 2500 psi 04/10/2012 04:12:27 1366 0.0 8.33 646.7 1362 04/10/2012 04:13:27 2391 0.0 8.33 646.7 2371 04/10/2012 04:13:55 2314 0.0 8.33 646.7 2298 High PT good.Bleeding off pressure 04/10/2012 04:14:00 2311 0.0 8.33 646.7 2288 Reset Total,Vol=9.66 bbl 04/10/2012 04:14:27 5 0.0 8.33 646.7 -1 04/10/2012 04:14:59 10 0.0 8.33 646.7 2 Start batching up first tub of ASL 04/10/2012 04:15:27 45 0.0 8.32 646.7 2 04/10/2012 04:16:27 209 0.0 8.30 646.7 1 04/10/2012 04:17:27 227 0.0 8.79 646.7 1 Page 6 of 9 Well Field lob Start Customer Job Number Red Wolf#2 Badami Apr/09/2012 Schlumberger Data Time Unit Flow Density Volume WeNhead Message 24-hr Pressure Rate LB/G BBL Pressure dock PSI B/M PSI 04/10/2012 04:19:27 253 0.0 9.95 646.7 1 04/10/2012 04:19:35 255 0.0 10.03 646.7 1 Reset Total,Vol=0.00 bbl 04/10/2012 04:20:27 267 0.0 10.34 646.7 1 04/10/2012 04:21:27 276 0.0 10.59 646.7 0 04/10/2012 04:22:27 553 0.0 10.74 646.7 1 04/10/2012 04:23:27 43 0.0 10.78 646.7 30 Cement to weight..10.7 ppg 04/10/2012 04:23:37 77 0.0 10.79 646.7 46 Start pumping cement 04/10/2012 04:24:27 154 2.0 10.80 647.8 55 04/10/2012 04:25:27 152 2.0 11.03 649.8 42 seeing returns in cellar 04/10/2012 04:26:27 141 1.9 10.89 651.8 31 04/10/2012 04:27:10 136 2.0 10.64 653.2 26 Lab called..cement tests are good 04/10/2012 04:27:27 134 2.0 10.71 653.8 23 04/10/2012 04:28:27 132 2.0 10.83 655.8 22 04/10/2012 04:29:27 131 2.0 10.78 657.7 22 04/10/2012 04:30:27 241 3.0 10.61 660.3 43 04/10/2012 04:31:27 242 3.0 10.57 663.3 42 04/10/2012 04:32:27 231 3.0 10.77 666.3 42 04/10/2012 04:33:27 237 3.0 10.75 669.3 42 04/10/2012 04:34:27 234 3.0 10.62 672.3 40 04/10/2012 04:35:27 265 3.3 10.61 675.4 48 04/10/2012 04:36:27 269 3.3 10.56 678.8 48 04/10/2012 04:37:27 368 3.9 10.58 682.6 67 04/10/2012 04:38:27 362 4.0 10.75 686.5 69 04/10/2012 04:38:54 366 3.9 10.62 688.3 69 Swapping water trucks 04/10/2012 04:39:27 365 3.9 10.70 690.4 69 04/10/2012 04:40:27 362 3.9 10.64 694.4 65 04/10/2012 04:41:27 362 3.9 10.48 698.3 67 04/10/2012 04:42:27 354 3.9 10.55 702.2 67 Swap silo 04/10/2012 04:43:27 356 3.9 10.73 706.1 67 04/10/2012 04:44:27 349 3.9 10.83 710.0 68 04/10/2012 04:44:42 360 3.9 10.75 711.0 71 48 bbl mix water used 04/10/2012 04:45:27 368 3.9 10.69 713.9 69 04/10/2012 04:46:27 371 4.0 10.69 717.9 71 04/10/2012 04:47:27 380 4.0 10.65 721.9 69 04/10/2012 04:48:27 406 4.2 10.64 726.0 78 04/10/2012 04:49:27 418 4.2 10.61 730.3 83 04/10/2012 04:50:27 419 4.3 10.58 734.5 82 04/10/2012 04:51:27 306 3.6 10.63 738.6 58 04/10/2012 04:52:27 225 3.1 10.57 741.9 42 04/10/2012 04:53:27 235 3.0 10.74 744.9 43 04/10/2012 04:54:27 238 3.0 10.67 747.9 45 04/10/2012 04:55:27 238 3.0 10.67 750.9 49 04/10/2012 04:56:27 123 1.9 10.58 753.0 22 04/10/2012 04:57:27 120 1.9 10.51 754.9 21 04/10/2012 04:58:27 118 1.9 10.49 756.8 23 04/10/2012 04:59:27 120 1.9 10.74 758.7 24 04/10/2012 05:00:27 117 1.9 10.79 760.6 25 04/10/2012 05:01:27 118 1.9 10.67 762.5 25 04/10/2012 05:02:27 123 1.9 10.53 764.4 26 04/10/2012 05:03:27 121 1.9 10.50 766.3 25 04/10/2012 05:04:27 118 1.9 10.56 768.2 23 04/10/2012 05:05:27 121 1.9 10.60 770.1 23 04/10/2012 05:06:27 118 1.9 10.53 772.0 21 04/10/2012 05:07:27 115 1.9 10.83 773.9 21 Page 7 of 9 Well Field Mob Start Customer 3ob Number Red Wolf#2 Badami Apr/09/2012 Schlumberger Date Time Unit Flow Density Volume Wellhead M go 24-hr Pressure Rab LB/G BBL Pressure dock PSI B/M PSI 04/10/2012 05:09:27 119 1.9 10.67 777.7 21 04/10/2012 05:10:27 116 1.9 10.71 779.6 21 04/10/2012 05:11:27 115 1.9 10.63 781.5 21 04/10/2012 05:12:27 115 1.9 10.59 783.4 21 04/10/2012 05:13:27 118 1.9 10.70 785.3 22 04/10/2012 05:14:10 166 2.3 10.73 786.7 31 Sucking down big tub 04/10/2012 05:14:27 162 2.3 10.74 787.4 31 04/10/2012 05:15:27 163 2.3 10.75 789.7 29 04/10/2012 05:16:27 163 2.3 10.77 792.1 32 04/10/2012 05:17:27 153 2.2 10.78 794.4 28 04/10/2012 05:18:01 23 0.0 10.79 794.9 7 Reset Total,Vol=148.14 bbl 04/10/2012 05:18:27 121 1.6 10.79 795.1 21 04/10/2012 05:19:14 103 2.0 10.80 796.6 21 Pumping 6 bbl water 04/10/2012 05:19:27 95 2.0 10.80 797.1 18 04/10/2012 05:20:27 106 2.1 10.80 799.1 29 04/10/2012 05:21:27 29 0.0 10.82 800.8 17 04/10/2012 05:21:39 30 0.0 10.82 800.8 16 Down on pump.Closing ported collar 04/10/2012 05:21:41 29 0.0 10.83 800.8 16 Reset Total,Vol=5.94 bbl 04/10/2012 05:22:27 29 0.0 10.82 800.8 13 04/10/2012 05:23:27 29 0.0 10.83 800.8 14 04/10/2012 05:23:48 29 0.0 10.83 800.8 15 Pressuring up collar to 1000 psi 04/10/2012 05:24:27 934 0.0 10.83 800.8 930 04/10/2012 05:25:27 773 0.0 10.84 800.8 758 04/10/2012 05:25:57 505 0.0 10.84 800.8 488 Bleeding pressure off 04/10/2012 05:26:27 20 0.0 10.84 800.8 1 04/10/2012 05:27:27 18 0.0 10.84 800.8 3 04/10/2012 05:28:27 17 0.0 10.84 800.8 5 04/10/2012 05:29:11 18 0.0 10.86 800.8 6 Rotating collar 04/10/2012 05:29:21 20 0.0 10.85 800.8 5 PT to 1000 psi 04/10/2012 05:29:27 21 0.0 10.85 800.8 6 04/10/2012 05:30:27 873 0.0 10.86 800.9 861 04/10/2012 i 05:31:00 13 0.0 10.85 800.9 1 Bleeding off pressure 04/10/2012 05:31:27 15 0.0 10.86 800.9 2 04/10/2012 05:32:27 14 0.0 10.86 800.9 1 04/10/2012 05:32:41 15 0.0 10.86 800.9 1 Pulling up 04/10/2012 05:32:50 14 0.0 10.86 800.9 1 Pito 2500 psi 04/10/2012 05:33:27 1595 0.1 10.86 801.0 1586 04/10/2012 05:34:16 21 0.0 10.86 801.1 9 Reset Total,Vol=0.30 bbl 04/10/2012 05:34:27 20 0.0 10.86 801.1 8 04/10/2012 05:34:42 20 0.0 10.86 801.1 7 Pumping 40 bbl water at 3 bpm 04/10/2012 05:35:27 186 2.9 10.86 - 802.9 70 04/10/2012 05:36:27 205 3.0 10.86 805.8 85 04/10/201.2 05:37:27 204 2.9 10.87 808.7 83 04/10/2012 05:38:27 197 2.9 10.74 811.6 79 04/10/2012 05:39:27 192 3.0 10.75 814.5 73 04/10/2012 05:39:33 194 2.9 10.75 814.8 75 Pumping 50 bbl water 04/10/2012 05:40:27 195 2.9 10.77 817.4 70 04/10/2012 05:41:27 188 2.9 10.78 820.3 67 04/10/2012 05:42:27 179 2.9 10.79 823.2 59 04/10/2012 05:43:27 180 2.9 10.80 826.1 57 `04/10/2012 05:44:27 168 2.9 10.81 828.9 53 04/10/2012 05:45:27 175 2.8 10.83 831.8 51 04/10/2012 05:46:27 164 2.9 10.83 834.6 50 04/10/2012 05:47:27 168 3.0 10.84 837.5 51 Page 8 of 9 Well !Field Job Start Customer Job Number Red wolf#2 Badami Apr/09/2012 Schlumberger Date Time I Unit Flow Density Volume Wellhead Message 24-hr I Pressure Rate LB/G BBL Pressure dock PSI BIM PSI 04/10/2012 05:49:27 172 2.9 10.85 843.3 49 04/10/2012 05:50:27 170 . 2.9 10.85 846.2 47 04/10/2012 05:51:27 166 2.9 10.86 849.2 52 04/10/2012 05:52:27 18 0.0 10.86 850.4 9 04/10/2012 05:53:27 21 0.0 10.86 850.4 9 04/10/2012 05:54:27 --� 22 0.0 10.86 850.4 8 ----- ----__- 04/10/2012 05:55:27 99 0.0 10.86 850.4 9 04/10/2012 05:56:27 107 0.0 10.86 850.4 9 04/10/2012 05:57:27 13 0.0 10.86 850.4 9 Post Job Summary Average Pump Rates,bbl/min Volume of Fluid Injected,bbl Slurry I N2 Mud Maximum Rate Total Slurry 1 Mud Spacer N2 3.9 5.5 850.4 I 0.0 0.0 I Treating Pressure Summary,psi Breakdown Fluid Maximum Final Average Bump Plug to Breakdown Type Volume Density 4626 12 118 bbl lb/gal Avg.N2 Percent Designed Slurry Volume Displacement Mix Water Temp Cement Circulated to Surface? ❑ Volume bbl % 0.0 bbl 0.0 bbl degF Washed Thru Perfs ❑ To ft Customer or Authorized Representative Schlumberger Supervisor Circulation Lost ❑ Job Completed J Lonnie Drollinger Craig Sampsell/H Griggs/Joleen Oshiro - Page 9 of 9 Schlumberger CemCAD E* well cementing recommendation for P&A Plug 1 (TD) Operator : Savant Well : Red Wolf#2 Country : USA Field : Badami State : AK Prepared for : Mr.Gary Hammon Location : Nabors 2ES • Proposal No. : Draft v2 Service Point : Prudhoe Bay,Alaska • Date Prepared : 04/21/2012 Business Phone : 907-659-2434 FAX No. : 907-659-2538 • Prepared by : Jeff Long Phone : 907-273-1778 E-Mail : JLong1@slb.com well description Configuration Plug Stage:Single Rig Type:Land Prev.String MD:3849.0 ft OD:9 5/8 in Weight:47.0 lb/ft Drill Pipe MD: 11859.0 ft OD:4 in Weight:14.0 lb/ft Casing/liner Shoe MD 11859.0 ft Mud Line 0.0 ft Total MD 11859.0 ft BHST 218 degF Bit Size 8 1/2 in Mean OH Diameter 8.500 in Mean Annular Excess 15.0% Mean OH Equivalent Diameter 8.983 in Qa Total OH Volume 627.8 bbl (including excess) 04 VATE Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others.limitations.computer models.measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations.or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA.INFORMATION PRESENTED.EFFECTIVENESS OF MATERIAL.PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. F;endorr.d'or in'ingemen:of any mtellnotual praperry rights of Schloroberoe,m o!hers is rot so be infe,'eb ono no ulellectuel property rights are granted hereby. • Mark of Schlumberger Page 1 red wolf 2 draft PnA v1 4-16-2012.cfw;04-21-2012; LoadCase PnA Plug 1;Version wco-cem471_02 Client : Savant Well : Red Wolf#2 Schlumberger String : P&A Plug 1 (TD) District : Prudhoe Bay,Alaska Country : USA Loadcase : PnA Plug 1 Section 1 : fluid sequence Original fluid Mud 9.60 lb/gal k : 1.02E-2 Ibf.s^n/ft2 n :0.614 Ty:3.46 lbf/100ft2 Displacement Volume 128.5 bbl Drill Pipe Volume 128.5 bbl Total Volume 172.1 bbl TOC 11339.1 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) HWP Water 12.0 191.0 11148.1 8.34 viscosity:5.000 cP Plug 1 slurry 32.7 519.9 11339.1 15.80 Pv:97.171 cP Ty:9.95 lbf/100ft2 Plug 1 slurry 7.3 11182.8 15.80 Pv:97.171 cP Ty:9.95 lbf/100ft2 HWP Water 2.1 10991.9 8.34 viscosity:5.000 cP Mud 118.0 103.1 9.60 k:1.02E-2 lbf.s^n/ft2 n:0.614 Ty:3.46 lbf/100ft2 Static Security Checks Frac 1080 psi at 3849.0 ft Pore 159 psi at 3849.0 ft Csg.Pump out 71 ton Check Valve Diff Press 1 psi Page 2 red wolf 2 draft PnA v1 4-16-2012 cfw:04-21-2012, LoadCase PnA Plug 1,Version wcs-cem471_02 Client : Savant Well : Red Wolf#2 ScMlberger String : P&A Plug 1 (TD) District : Prudhoe Bay,Alaska Country : USA Loadcase : PnA Plug 1 CemCADE Client :Savant Well : Red Wolf#2 String :P&A Plug 1 (TD) District : Prudhoe Bay,Alaska Country : USA ft lb/gal 0- E - _, 8 10 12 14 16 —Max.Dynamic —Mn.Dynamic — Frac —Pore —Hydrostatic —Mn.Hydrostatic '81 0 0— I U) m 3 a a` 0 m 0 00— U a lV 8 d Fluid Sequence Dynamic Well Security 3 ■HWP Water 14.1 bbl 8.34 lb/gal Newtonian:Visco.=5.000 cP 3 Rug 1 slurry 40.0 bbl 15.80 lb/gal Bingham:PV =97.171 cP Ty=9.95 Ibf/100ft2 ■Mud 118.0 bbl 9.60 lb/gal Herschel:k =1.02E-2 Ibf.s^n/ft2 n =0.614 Ty=3.46 Ibf/100ft2 Total Depth =11859.0 ft Top of Cement=11339.1 ft 'Mark of Schlumberger S"hlllllbarpr Page 3 red wolf 2 draft PnA v1 4-16-2012.cfw;04-21-2012, LoadCase PnA Plug 1,Version wcs-cem471_02 Client : Savant Well : Red Wolf#2 Schlinherger String : P&A Plug 1 (TD) District : Prudhoe Bay,Alaska Country : USA Loadcase : PnA Plug 1 Section 2: pumping schedule Start Job: Circulate bottoms up to cool the hole and condition the mud. Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) HWP Water 5.0 12.0 2.4 12.0 80 Water Ahead Pause 0.0 0.0 5.0 0.0 80 Weight Up Tub Plug 1 slurry 4.0 34.1 8.5 34.1 80 Mix&Pump Slurry Plug 1 slurry 2.0 5.9 2.9 40.0 80 Suck Down Tub Pause 0.0 0.0 2.0 0.0 80 Line Up Water HWP Water 2.0 2.1 1.0 2.1 80 Water Behind Pause 0.0 0.0 5.0 0.0 80 Line Up Mud Mud 5.0 118.0 23.6 118.0 80 Displace to Balance Total 00:50 hr:mn 172.1 bbl End Job: Pull out of plug slowly, drop wiper dart/or ball, and circulate one string volum Dynamic Security Checks : Frac 1032 psi at 3849.0 ft Pore 160 psi at 3849.0 ft Temperature Results BHCT 187 degF Simulated Max HCT 189 degF Simulated BHCT 178 degF Max HCT Depth 11132.9 ft CT at TOC 179 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time 1 (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 208 degF Bottom Hole (degF) (degF) 218 degF Page 4 red wolf 2 draft PnA v1 4-16-2012.cfw;04-21-2012: LoadCase PnA Plug 1:Version wcs-cem471_02 Client : Savant Well : Red Wolf#2 Schlumberger String : P&A Plug 1 (TD) District : Prudhoe Bay,Alaska Country : USA Loadcase : PnA Plug 1 Section 3: fluid description Mud DESIGN Fluid No: 1 Density :9.60 lb/gal Rheo. Model : HERSCHEL_B. k : 1.02E-2 Ibf.s^n/ft2 At temp. : 120 degF n :0.614 Ty :3.461bf/100ft2 Gel Strength :(lbf/100ft2) MUD Mud Type :WBM Job volume : 118.0 bbl Water Type : Fresh VOLUME FRACTION Solids : 6.0% Oil :0.0% Water : 94.0% Plug 1 slurry DESIGN Fluid No: 3 Density : 15.80 lb/gal Rheo. Model : BINGHAM Pv :97.171 cP At temp. : 180 degF Ty :9.95 Ibf/100ft2 Gel Strength :25.62 lbf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid : 5.103 gal/sk Job volume :40.0 bbl Dry Density : 199.77 lb/ft3 Yield : 1.16 ft3/sk Quantity : 193.11 sk Sack Weight : 94 lb Solid Fraction :41.3% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.083 gal/sk Additives Code Conc. Function D046 0.200%BWOC Antifoam D065 0.300%BWOC Dispersant D167 0.350%BWOC Fluid loss D177 0.020 gal/sk cement Retarder D153 0.200%BWOC Antisettling HWP Water DESIGN Fluid No:4 Density :8.34 lb/gal Rheo. Model : NEWTONIAN At temp. : (degF) Viscosity :5.000 cP Gel Strength : (Ibf/100ft2) Job volume : 14.1 bbl Page 5 red wolf 2 draft PnA v1 4-16-2012.cfw:04-21-2012, LoadCase PnA Plug 1:Version wcs-cem471_02 Client : Savant Well : Red Wolf#2 Schlumberger String : P&A Plug 1 (TD) District : Prudhoe Bay,Alaska Country : USA Loadcase : PnA Plug 1 Section 4: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name G 18152 lb 194 sack 941b D046 36 lb 1 sack 50 lb D065 54 lb 2 sack 50 lb D167 64 lb 3 sack 25 lb D153 361b 2 sack 251b D177 3.9 gal 1 drum 55.0 gal Mix Water Requirements : HWP Water 38 Bbls MIXING PREPARATION Plug 1 slurry Volume :40.0 bbl Density : 15.80 lb/gal Yield : 1.16 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 23.5 bbl 10.0 bbl LAS Design G 18151.971 lb Fresh water 23.368 bbl 9.962 bbl D046 36.304 lb 0.200%BWOC D177 3.862 gal 1.646 gal 0.020 gal/sk cement D065 54.456 lb 0.300%BWOC D167 63.532 lb 0.350%BWOC D153 36.304 lb 0.200%BWOC HWP Water Volume : 14.1 bbl Density:8.34 lb/gal Code Quantity Design HWP Water 14.069 bbl Page 6 red wolf 2 draft PnA v1 4-16-2012.cfw;04-21-2012, LoadCase PnA Plug 1,Version wcs-cem471_02 Schlumberger Laboratory Cement Test Report Nabors 7ES Red Wolf 2 Plug 1 Field Blend Signatures Fluid No : PAK 12pIg2050 Client : Savant Alaska Location/Rig : Nabors 7ES Date :Apr-21-2012 Well Name Red Wolf 2 Field : Badami Daniel Himel Job Type Abandonment Depth 11859.0 ft TVD 11859.0 ft BHST 198 degF BHCT 180 degF BHP 5551 psi Starting Temp. 80 degF Time to Temp. 00:30 hr:mn Heating Rate 3.33 degF/min Starting Pressure 500 psi Time to Pressure 00:30 hr:mn Schedule ( ) Composition Slurry Density 15.80 lb/gal Yield 1.16 ft3/sk Mix Fluid 5.102 gal/sk Solid Vol.Fraction 41.3% Porosity 58.7% Slurry type Conventional Code Concentration Sack Reference Component Blend Density Lot Number G 94 lb of CEMENT Blend 199.77 lb/ft3 Fresh water 5.082 gal/sk Base Fluid D046 0.200%BWOC Antifoam TU1J0187A0 D065 0.300%BWOC Dispersant YL2717SC21 D167 0.350%BWOC Fluid loss DALA083361 D153 0.200%BWOC Antisettling 092811-03 D177 0.020 gal/sk Retarder 2011222AC Rheology Tem.erature 80 de.F 180 de.F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 110.0 110.0 110.0 84.0 84.0 84.0 200 84.0 85.0 84.5 64.0 67.0 65.5 100 63.0 65.0 64.0 40.0 38.0 39.0 60 37.0 42.0 39.5 27.0 21.0 24.0 30 27.0 32.0 29.5 18.0 16.0 17.0 6 15.3 20.1 17.7 7.6 3.4 5.5 3 11.8 19.1 15.5 3.7 3.2 3.5 10 sec Gel25 deg-26.36 Ibf/100ft2 4 deg-4.06 Ibf/100ft2 10 min Gel 61 deg-65.11 Ibf/100ft2 3 deg -3.31 Ibf/100ft2 Rheo.computed I Viscosity:89.812 cP Yield Point:24.05 Ibf/100ft2 I Viscosity: 77.771 cP Yield Point: 10.03 Ibf/100ft2 Thickening Time 30 Bc 03:14 hr:mn 70 Bc 03:34 hr:mn 100 Bc 03:46 hr:mn Free Fluid Trace mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation: None Fluid Loss API Fluid Loss 68 mL 34 mL in 30 min at 180 degF and 1000 psi Water Analysis Chloride Calcium Magnesium 67.00 mg/I 45.00 mg/I 18.00 mg/I Page 1 Instrument:8240#5 Schlumberger Sampling Period:5 seconds Prudhoe Bay Well Services Laboratory Telephone:+1 907 659 6155 Facsimile:+1 907 659 9221 250 12000 100- • 225 10801 90— 200 9611 80- 175 8400 70- 15l -y 7200 -1 60- m n > c 125 = 6011 ' 50- •m N l� d N N g e, C 101 4801 �, 40— ji 75 CI 3600 30- o 50 2400 20— , - 25 1200 10 • 0 0 0 I , , I I , , 0:00 0:30 1:00 1:30 2:00 2:30 3:00 3:30 4:00 Time(HH:MM) Location:Red Wolf 2 30 Bc:3:15:35 File Name: pakl2plg2050-1-cell5.tst Customer:Savant Alaska 50 Bc:3:28:35 Supervisor:{Info:Supervisor) 70 Bc:3:34:05 Test Started:4/21/2012 10:03:39 PM Density:15.8 Ibm/gal 100 Bc:3:51:40 Test Stopped:4/22/2012 1:55:19 AM System:G+.2%D46+.3%D65+.35%D167+.2%D153+.02gpsD177 BHCT: 180 degF Printed:4/22/2012 2:01:39 AM BHST: 198 degF Job Type:Plug 1 Rig Name:Nabors 7ES Page 1 Instrument:Twin Right Current Compressive Strength:2594 psi Schlumberger Sampling Period:30 seconds Final Compressive Strength:2594 psi at 27:33:30 Prudhoe Bay Well Services Laboratory Compressive strength type B(more than 14 lb/gal) Telephone:+1 907 659 6155 Facsimile:+1 907 659 9221 20— 250— 3000— 18— 2500— 16— 200— - ❑ 14— - w 2000- - o. 12- µ 150— m m 10- e v 1500— E - - • ? - 100— $. - m - - E _ U 1000- 6- 4— 50- 500- 2— - 0 0 0 l I I ( l 0:00 5:00 10:00 15:00 20:00 25:00 30:00 Time(HH:MM) Location:Red Wolf 2 50 psi:4:52:00 File Name:pakl2plg2050-UCA4.tst Customer:Savant Alaska 500 psi:6:42:00 Supervisor.Bergonzini 1000 psi:8:22:30 Test Started:4/22/2012 2:59:24 AM Density:15.8lbm/gal 2000 psi:14:49:00 Test Stopped:4/23/2012 6:33:01 AM System:G+.2%D46+.3%D65+.35%0167+.2%0153+.02gpsD17 BHCT:180 degF 12 hr:1609 psi Printed:4/23/2012 7:12:50 AM BHST:198 degF 24 hr:2498 psi Job Type:Plug 1 Page 1 Rig Name:Nabors 7ES Schlumberger Cementing Job Report CemCATv1.4 Well Red Wolf 42 Client SAVANT Field Badami SIR No. bfgw-00030 Engineer Donny Bergonzini Job Type plug Country United States Job Date 04-22-2012 Time Pressure — Rate Density Messages 04/2:a01210:29:.e • 10:29:48 PRIME UP RATE CHECK i 1 Reset Total,Vol=3.09 bbl rate check h head Reset Total,Vol=3.06 bbl Reset Total,Vol=0.00 bbl 10:40:00 Reset Total,Vol=0.00 bbl water ahead 10:50:00 / pt 10 bbls water ahead of cement 11:00:00 Reset Total,Vol=1.97 bbl Reset Total,Vol=10.06 bbl batchcement weuD tub 11:10:00 11:20:00 ight Reset Total,Vol=40.16 bbl Drop Bottom Plug water behind 11:30:00 shut down load nert rig displace115 bbls Reset Total,Vol=4.02 bbl • 11:40:00 11:50:00 11:55:28 displacement done hh:mm:ss , 0.00 taco 2000 woo 4000 soon 0.00 2.0 0.0 6.0 8.0 10.0 5.0 10.0 15.0 20.0 25.0 03/12001111:55:29 -.. PSI —_—_._- B/M - 1.8/0 04/22/2012 12:02:18 Schlumberger Cementing Service Report Customer Job Number I SAVANT bfgw-00030 Well Location(legal) Schlumberger Location lob Start Red Wolf#2 Prudhoe Bay,AK Apr/22/2012 Field Formation Name/Type Deviation Bit Size Well MD Well TVD Badami 0 deg 8.5 in 11859.0 ft 11859.0 ft County USA State/Province Alaska BHP BUST BHCT Pore Press.Gradient Well Master API/UWI psi 198 degF 180 degF lb/gal Rig Name Drilled For Service Via Casing/Liner 7 ES Oil Land Depth,ft Size,in Weight,lb/ft Grade Thread Offshore Zone Well Class Well Type 3917.0 9.6 47.0 New Exploration 0.0 0.0 0.0 Drilling Fluid Type Max.Density Plastic Viscosity Tubing/Drill Pipe lb/gal cP T/D Depth,ft Size,in Weight,lb/ft Grade Thread Service Line Job Type D 11859.0 4.0 14.0 Cementing plug 0.0 0.0 0.0 Max.Allowed Tub.Press Max.Allowed Ann.Press WH Connection Perforations/Open Hole 2000 psi psi drill pin Top,ft Bottom,ft shot/ft No.of Shots Total Interval Service Instructions ft ft ft ft ft Diameter ft ft in Treat Down Displacement Packer Type Packer Depth 117.0 bbl ft Tubing Vol. Casing Vol. Annular Vol. Openhole Vol. 128.5 bbl bbl bbl bbl Casing/Tubing Secured ❑ 1 Hole Vol.Circulated prior to Cement El Casing Tools Squeeze Job Lift Pressure psi Shoe Type Sq Type Pipe Rotated ❑ Pipe Reciprocated LJ Shoe Depth ft Tool Type No.Centralizers Top Plugs Bottom Plugs Stage Tool Type Tool Depth ft Cement Head Type n/a Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Arrived on Location Leave Location Collar Type Tail Pipe Depth ft Apr/22/2012 Apr/22/2012 Apr/22/2012 Collar Depth ft Sqz.Total Vol. bbl Date Time Treating Flow Density Volume Message 24-hr Pressure Rate LB/G BBL dock PSI B/M 04/22/2012 10:29:48 220 0.0 8.38 0.0 Started Acquisition 04/22/2012 10:30:18 37 0.0 8.35 _0.0 04/22/2012 10:30:33 28 0.0 8.36 0.0 PRIME UP 04/22/2012 10:30:48 138 0.0 8.37 0.0 04/22/2012 10:31:18 37 0.0 8.38 0.0 04/22/2012 10:31:23 37 0.0 8.38 0.0 RATE CHECK 04/22/2012 10:31:48 65 0.0 8.38 0.0 04/22/2012 10:32:18 74 2.9 8.38 0.7 04/22/2012 10:32:48 74 2.9 8.38 2.1 04/22/2012 10:33:15 65 0.0 8.38 3.1 Reset Total,Vol=3.09 bbl 04/22/2012 10:33:18 60 0.0 8.38 3.1 04/22/2012 10:33:42 69 0.0 8.38 3.1 rate check h head 04/22/2012 10:33:48 69 0.0 8.38 3.1 04/22/2012 10:34:18 69 3.2 8.38 4.3 04/22/2012 10:34:48 65 3.1 8.38 5.8 04/22/2012 10:34:57 37 0.0 8.38 6.1 Reset Total,Vol=3.06 bbl 04/22/2012 10:35:03 33 0.0 8.38 6.1 Reset Total,Vol=0.00 bbl 04/22/2012 10:35:18 28 0.0 8.38 0.0 04/22/2012 10:35:48 28 0.0 8.38 0.0 04/22/2012 10:36:18 24 0.0 8.38 0.0 04/22/2012 10:36:48 28 0.0 8.38 0.0 Page 1 of 5 Well Field Job Start Customer Job Number Red Wolf#2 Badami Apr/22/2012 SAVANT bfgw-00030 Date Time Treating- Flow tensity Volume Message 24-hr Pressure Rate LN/S 811E dock PSI BIM 04/22/2012 10:37:48 --- __-- 24 0.0 8.38 0.0 -- ---- -_- - 04/22/2012 j 10:38:18 -_--_ -24-_-- 0.0 8.38 { --_ 0.0 -- - 04/22/2012 1 10:38:48 19 0.0 -_- 8.22 0.0 04/22/2012 10:39:18 19 0.0 8.38 0.0 04/22/2012 10:39:48 14 0.0 8.38 0.0 04/22/2012 10:40:18 -_--.--- 10 _ --- 0.0 8.38 0.0 -- - 04/22/2012 I 10:40:48 10 ! 0.0 8.38 I 0.0 1 04/22/2012 10:41:10 ! 10 0.0 8.38 0.0 Reset Total,Vol=0.00 bbl + -04/22/2012 } 10:41:18 ! 10 0.0 8.38 0.0 04/22/2012 I 10:41:25 5 0.0 8.38 0.0 j water ahead 04/22/2012 10:41:48 -_- 24 0.0 ----�- 8.38 0.0 ! j 04/22/2012 i 10:42:18 19 0.0 8.38 0.0 04/22/2012 10:42:48 14 0.0 8.38 0.0 04/22/2012 10:43:18 51 0.3 8.38 0.0 04/22/2012 10:43:48 56 0.0 8.38 , 0.1 04/22/2012 10:44:18 56 0.0 8.38 0.1 04/22/2012 10:44:48 51 0.0 8.38 0.1 II 04/22/2012 10:45:18 56 _.-- 0.0 8.38 0.1 04/22/2012 10:45:48 51 0.0 8.38 0.1 04/22/2012 10:46:18 51 0.0 8.38 0.1 04/22/2012 10:46:48 51 0.0 8.38 0.1 04/22/2012 10:47:18 56 0.0 8.38 0.1 04/22/2012 10:47:48 51 0.0 8.38 0.1 04/22/2012 10:48:18 51 0.0 8.38 0.1 04/22/2012 10:48:48 51 0.0 8.38 jl 0.1 - ---- ---- 04/22/2012 10:49:18 42 0.0 8.37 j 0.1 04/22/2012 10:49:48 92 0.4 8.37 0.2 04/22/2012 10:50:18 120 0.1 8.37 i 0.4 04/22/2012 10:50:48 321 0.8 8.38 0.7 04/22/2012 10:51:18 284 0.8 8.38 1.1 04/22/2012 10:51:48 316 0.8 8.38 1.5 04/22/2012 10:52:18 321 0.8 8.38 1.9 -_ --------_---- ---04/22/2012 10:52:48 111 0.0 8.38 1.9 04/22/2012 1 10:53:18 101 0.0 8.38 !I 1.9 04/22/2012 10:53:22 866 0.0 8.38 2.0 pt 04/22/2012 10:53:48 1360 0.0 8.38 2.0 04/22/2012 10:54:18--- -_--- 1749 0.0 r 8.38 2.0 -- 04/22/2012 10:54:48 3200 0.0 8.38 2.0 04/22/2012 10:55:18 3173 0.0 -_-. 8.38 __-- 2.0 -.-_- 04/22/2012 10:55:48 3155 j 0.0 8.38 2.0 04/22/2012 10:56:18-_----.--. 3132 0.0 8.38 ----.--_2.0_ 04/22/2012 10:56:48 14 0.0 8.38 2.0 04/22/2012 10:57:18 51 0.0 8.38 2.0 04/22/2012 10:57:34 51 0.0 8.38 2.0 10 bbls water ahead of cement 04/22/2012 10:57:36 46 0.0 8.38 2.0 Reset Total,Vol=1.97 bbl 04/22/2012 10:57:48 51 0.0 8.38 2.0 04/22/2012 _--10:58:18 ------ 46 0.0 2.0 04/22/2012 10:58:48 83 0.6 2.1 04/22/2012 10:59:18 582 2.4 8.37 3.0 04/22/2012 10:59:48 555 2.4 8.37 4.2 04/22/2012 11:00:18 568 2.4 8.37 ( 5.3 -- -- - - ----- ----. . _-----_..------ 04/22/2012 11:00:48 577 2.4 8.37 F 6.5 04/22/2012 11:01:18 577 2.4 8.38 7.7 04/22/2012 11:01:48 591 2.4 I 8.37 8.9 1 Page 2 of 5 Well Field Job Start Customer Job Number Red Wolf#2 Badami Apr/22/2012 SAVANT bfgw-00030 Date Time'. Treating Flow Density Volume Message 24-hr Pressure RataLB/G BBL dock' PSI B/M 04/22/2012 11:02:48 605 2.4 8.37 11.3 1 04/22/2012 11:03:18 56 0.0 8.37 12.0 Reset Total,Vol=10.06 bbl 04/22/2012 11:03:36 51 0.0 8.37 12.0 batch up tub 04/22/2012 11:03:48 51 0.0 8.37 12.0 04/22/2012 11:04:18 51 0.0 8.37 12.0 04/22/2012 11:04:48 51 0.0 8.37 12.0 04/22/2012 11:05:18 46 0.0 8.37 12.0 04/22/2012 11:05:48 46 0.0 8.22 12.0 04/22/2012 11:06:18 46 0.0 j 8.17 12.0 04/22/2012 11:06:48 46 0.0 8.89 12.0 04/22/2012 11:07:18 46 0.0 10.74 12.0 04/22/2012 11:07:48 46 0.0 12.90 12.0 04/22/2012 11:08:18 46 0.0 14.46 12.0 04/22/2012 11:08:48 42 0.0 15.55 12.0 04/22/2012 11:09:18 46 0.0 15.67 12.0 04/22/2012 11:09:48 46 0.0 j 15.86 12.0 04/22/2012 11:10:18 42 0.0 15.73 12.0 04/22/2012 11:10:48 46 0.0 15.79 12.0 ._-. I 04/22/2012 11:10:57 46 0.0 , 15.79 12.0 cement @ weight 04/22/2012 11:11:18 46 0.0 15.78 12.0 04/22/2012 11:11:48 106 0.0 15.78 12.0 04/22/2012 11:12:18 431 1.2 15.79 12.2 04/22/2012 11:12:48 596r 2.0 15.75 13.0 04/22/2012 11:13:18 660 2.0 15.59 14.0 - - --- ----- - ---- -t- ---- 1 04/22/2012 11:13:48 1131 3.5 j 15.58 I 15.3 04/22/2012 11:14:18 1392 4.0 15.65 ' 17.3 04/22/2012 11:14:48 1324 4.0 1 15.74 19.3 -- --- -i- 04/22/2012 04/22/2012 11:15:18 1282 -,- 4.0 15.74 t 21.3 I -04/22/2012 11:15:48 1241 4.1 15.69 23.3 04/22/2012 11:16:18 1163 4.1 15.70 25.4 04/22/2012 11:16:48 976 3.8 ! 15.66 I 27.4 04/22/2012 11:17:18 _--916 3.7 --.15_64 29.3 -_ - - -- 04/22/2012 11:17:48 852 3.7 15.62 li 31.1 04/22/2012 11:18:18 811 1 3.7 15.69 33.0 04/22/2012 11:18:48 ! 761 3.7 15.62 34.8 04/22/2012 11:19:18 04/22/2012 11:19:48 _ -719 - _.- 3.7 15.68 38.5 04/22/2012 11:20:18 751-t 3.7 15.67 40.4 04/22/2012 11:20:48 j 719 3.7 15.65 42.2 04/22/2012 11:21:18 04/22/2012 11:21:48 --- 715. 3.7 15.68 45.9 I - --- --- - - -----. 04/22/2012 11:22:18 733 3.7 15.75 47.7 -1 __-----_ 04/22/2012 11:22:48 220 1.8 16.11 49.1 04/22/2012 11:23:18 106 1.0 16.04 49.8 04/22/2012 11:23:48 97 1.0 16.00 50.3 04/22/2012 11:24:18 120 1.0 15.69 50.8 04/22/2012 11:24:48 115 i 1.0 15.68 51.3 04/22/2012 11:25:18 115 ' 1.0 15.69 51.8 li 04/22/2012 11:25:48 14 0.0 15.68 52.2 04/22/2012 11:26:02 24 0.0 15.68 52.2 Reset Total,Vol=40.16 bbl -- - 04/22/2012 11:26:18 24 0.0 15.68 52.2 04/22/2012 11:26:20 24 0.0 15.68 52.2 Drop Bottom Plug 04/22/2012 11:26:34 193 1.8 15.67 52.3 water behind 04/22/2012 11:26:48 248 2.1 10.78 52.8 1 Page 3 of 5 Well Field Job Start Customer Job Number Red Wolf#2 Badami Apr/22/2012 SAVANT bfgw-00030 Date Time` ---Treating Flow Density Volume---- Message 24-hr`.. Pressure Rate LB/B BBL dodrS. PSI B/S1 04/22/2012 11:27:48 129 2.4 8.47 55.0 04/22/2012 11:28:18 46 1.2 8.42 56.2 04/22/2012 11:28:20 19 0.3 8.42 56.2 shut down 04/22/2012 11:28:48 24 0.0 8.41 56.2 04/22/2012 11:29:11 24 0.0 8.40 56.2 load nerf 04/22/2012 11:29:18 _-.24 0.0 8.40 56.2 -_ 04/22/2012 11:29:48 19-_I 0.0 8.39 56.2 ----_-- ---- 04/22/2012 11:30:18 19 0.0 8.39 56.2 04/22/2012 11:30:48 19 0.0 8.40 56.2 04/22/2012 11:31:18 19 0.0 8.38 56.2 04/22/2012 11:31:48 19 0.0 8.39 56.2 04/22/2012 11:32:18 19 0.0 8.39 56.2 04/22/2012 11:32:47 14 0.0 8.39 56.2 rig displace115 bbls 04/22/2012 11:32:48 19 0.0 8.39 56.2 04/22/2012 11:32:58 14 0.0 8.39 56.2 Reset Total,Vol=4.02 bbl 04/22/2012 11:33:18 14 0.0 8.38 56.2 04/22/2012 11:33:48 14 0.0 8.39 56.2 04/22/2012 11:34:18 14 0.0 8.39 56.2 1 04/22/2012 11:34:48 10 0.0 8.38 56.2 f 04/22/2012 11:35:18 97 0.0 I 8.38 56.2 04/22/2012 11:35:48 60 0.0 _.-8_38 56.2 04/22/2012 I 11:36:18 60 0.0 8.38 56.2 04/22/2012 11:36:48 1 ! 0.0 8.38 56.2 - - - - 04/22/2012 56.2 11:37:18 5 0.0 1 8.39 1 04/22/2012 11:37:48 5 0.0 8.38 -------56.2 t- 04/22/2012 11:38: 0.0 8.38 56.2 04/22/2012 11:38:48 1 -------_. 0.0 ------ 8.49 +-- ---56.2- ------- - --- ---- -I J 04/22/2012 1 11:39:18 5 0.0 8.43 56.2 - -------- AI 04/22/2012 11:39:48 1 0.0 8.43 56.2 04/22/2012 11:40:18 74 0.0 8.67 56.2 04/22/2012 11:40:48 252 0.0 0 56.2 � 04/22/2012 11:41:18 --- -----z16 0.0 8.77 --- 56.2 - - -- _ _. -- --- 04/22/2012 11:41:48 252_1 0.0 8.80 56.2 04/22/2012 11:42:18 33 0.0 8.78 56.2 04/22/2012 11:42:48 37 SII 0.0 8.73 56.2 04/22/2012 1. 11:43:18 28 0.0 7.89 56.2 04/22/2012 11:43:48 24 0.0 8.38 56.2 04/22/2012 11:44:1824 0.0 8.40 56.2 i 04/22/2012 11:44:48 74 0.0 8.44 56.2 -I 04/22/2012 11:45:18 28 0.0 8.50 I 56.2 04/22/2012 1 11:45:48 78 0.0 8.46 56.2 04/22/2012 • 11:46:18 56 0.0 8.38 56.2 04/22/2012 11:46:48 ___---_220 0.0 1 8.46 56.2 04/22/2012 11:47:18 197 0.0 8.47 56.2 04/22/2012 11:47:48 ! 83 0.0 8.47 t 56.2 04/22/2012 11:48:18 19 0.0 8.45 56.2 04/22/2012 11:48:48 14 0.0 1 8.45 56.2 ir 04/22/2012 11:49:18 14 0.0 t 8.45 56.2 04/22/2012 11:49:48 19 0.0 8.45 56.2 04/22/2012 11:50:18 j 14 0.0 8.44 56.2 04/22/2012 11:50:48 10 0.0 8.43 56.2 04/22/2012 11:51:18 14 0.0 8.43 56.2 04/22/2012 11:51:48 10 0.0 8.44 56.2 04/22/2012 11:52:18 14 0.0 8.44 56.2 Page 4 of 5 I Well I Field Job Start Customer 3ob.144itraler ; Red Wolf#2 Badami Apr/22/2012 SAVANT .bgw-00030'' ;.:Date �.Time TreatingFlow' ,Density Volume Message 24-lir Pressure Rate", LB/G ':BBI- Nook' PSi B/M 04/22/2012 11:53:18 14 0.0 8.41 56.2 04/22/2012 11:53:48 10 , 0.0 8.41 56.2 04/22/2012 11:54:18 10 0.0 8.41 56.2 04/22/2012 11:54:48 10 0.0 8.44 56.2 04/22/2012 11:55:18 207 0.0 8.41 56.2 Post Job Summary Average Pump Rates,bbl/min Slurry N2 Mud I Maximum Rate Total Slurry I Mud Spacer N2 2.4 4.2 56.2 0.0 0.0 Treating Pressure Summary,pal Breakdown Fluid Maximum Final Average Bump Plug to Breakdown Type Volume Density 3219 0 284 bbl lb/gal Avg.N2 Percent Designed Slurry Volume Displacement Mix Water Temp I Cement Circulated to Surface? E Volume bbl 0.0 bbl 0.0 bbl 75 degF Washed Thru Perfs L J To ft Customer or Authorized Representative Schlumberger Supervisor Circulation Lost a Job Completed ❑X Gary Hammon Donny Bergonzini - - Page 5 of 5 Schlumberger CemCAD E* well cementing recommendation for Retainer Squeeze Operator : Savant Well : Red Wolf#2 Country : USA Field : Badami State : AK Prepared for : Mr.Gary Hammon Location : Nabors 7ES Proposal No. : Field v1 Service Point : Prudhoe Bay,Alaska Date Prepared : 04/21/2012 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by Jeff Long Phone 907-273-1778 E-Mail JLong1@slb.com well description Configuration Plug Stage:Single Rig Type:Land Prev.String MD:3849.0 ft OD:9 5/8 in Weight:47.0 lb/ft Drill Pipe MD:3779.0 ft OD:4 in Weight:14.0 lb/ft Casing/liner Shoe MD 3849.0 ft Mud Line 0.0 ft Total MD 11859.0 ft BHST 70 degF Bit Size 8 1/2 in Mean OH Diameter 8.500 in Mean Annular Excess 10.0% \{? riktv Mean OH Equivalent Diameter 8.504 in Q Total OH Volume 569.6 bbl (including excess) .A, l n G 0, G ATE � ... Disclaimer Notice: Schlumberger submits this document with the benefit o"its judgmentexperience and poop oilfield practices. This irf orrnati.2 provided in accordance with generally accepte industrypactice. lYng on facts rmaton provided by others ansa•ions compute'models measurements assumptions and inferences that are not infallible. Calculations are estimates based an provided information.All proposalsrecommendations or predictions are opinions only. NO WARRANT'IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA.INFORMATION PRESENTED.EFFECTIVENESS OF MATERIAL PRODUCTS OR SURPLIES.RECOMMENDATIONS MADE.OR RESULTS OF THE SERVICES RENDERED Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. a Mark of Schlumberger Page 1 red wolf 2 draft PnA v1 4-10-2012.cfw,04-21-2012, LoadCase Retainer Squeeze,Version wcs-cem471_02 Client : Savant Well : Red Wolf#2 Schlmkger String : Retainer Squeeze District : Prudhoe Bay,Alaska Country : USA Loadcase : Retainer Squeeze Section 1 : fluid sequence Original fluid Mud 9.60 lb/gal k: 1.29E-2 Ibf.s^n/ft2 n :0.553 Ty: 5.54 lbf/100ft2 Displacement Volume 42.8 bbl Drill Pipe Volume 42.8 bbl Total Volume 58.0 bbl TOC 3746.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) HWP Water 5.0 86.7 3659.3 8.34 viscosity:5.000 cP Plug Slurry 11.9 203.0 3746.0 15.80 Pv:57.980 cP Ty:75.01 lbf/100ft2 Plug Slurry 5.1 3482.8 15.80 Pv:57.980 cP Ty:75.01 lbf/100ft2 HWP Water 2.0 3298.3 8.34 viscosity:5.000 cP Mud 34.0 160.8 9.60 k:1.29E-2 lbf.s^n/ft2 n:0.553 Ty:5.54 lbf/100ft2 Static Security Checks: Frac 1048 psi at 3949.0 ft Pore 187 psi at 3849.0 ft Csg.Pump out 24 ton Check Valve Diff Press 2 psi Page 2 red wolf 2 draft PnA v1 4-16-2012.cfw,04-21-2012, LoadCase Retainer Squeeze;Version wcs-cem471_02 Client : Savant Well : Red Wolf#2 Moberg" String : Retainer Squeeze District : Prudhoe Bay,Alaska Country : USA Loadcase : Retainer Squeeze CemCADE Client :Savant Well : Red Wolf#2 String : Retainer Squeeze District : Prudhoe Bay,Alaska Country : USA lb/gal ft 8 10 12 14 16 o F > I -Max.Dynamic -Mn.Dynamic -Frac -Pore -Hydrostatic -Mn.Hydrostatic 211 Q V m 0 m 0 U o - 00 0 0 b r_ J Fluid Sequence Dynamic Well Security ■FiWP Water 7.0 bbl 8.34 lb/gal Newtonian:Visco.=5.000 cP 3 Rug Slurry 17.0 bbl 15.80 lb/gal Bingham:PV =57.980 cP Ty=75.01 Ibf/10Oft2 72 ■Mud 34.0 bbl 9.60 lb/gal Herschel:k =1.29E-2 Ibf.s^n/ft2 n =0.553 Ty=5.54 bf/100ft2 Total Depth =12100.0 ft Top of Cement= 3746.0 ft *Mark of Schlumberger SCMIMberiger Page 3 red wolf 2 draft PnA v1 4-16-2012.cfw,04-21-2012: LoadCase Retainer Squeeze:Version wcs-cem471_02 Client : Savant Well : Red Wolf#2 Sch berger String : Retainer Squeeze District : Prudhoe Bay,Alaska Country : USA Loadcase : Retainer Squeeze Section 2: pumping schedule Start Job: Set EZSV, Pres. Test, Sting-in, establish injection rates at 1-5 BPM Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) HWP Water 1.0 5.0 5.0 5.0 80 Water Ahead Pause 0.0 0.0 5.0 0.0 80 Weight up Tub Plug Slurry 3.0 14.3 4.8 14.3 80 Mix&Pump Slurry Plug Slurry 2.0 2.7 1.3 17.0 80 Suck Down Tub Pause 0.0 0.0 2.0 0.0 80 Line Up Water HWP Water 3.0 2.0 0.7 2.0 80 Water Behind Pause 0.0 0.0 5.0 0.0 80 Line up to Mud Mud 5.0 34.0 6.8 34.0 80 Displace-13.5 bbls slurry below EZSV Shut-In 0.0 0.0 10.0 0.0 80 Sting Out drop 3.5 bbls slurry on top Total 00:30 hr:mn 58.0 bbl End Job: Pull up -100', Drop wiper dart, and circulate string volume at max rate. Dynamic Security Checks: Frac 994 psi at 3949.0 ft Pore 156 psi at 3873.5 ft Temperature Results BHCT 64 degF Simulated Max HCT 70 degF Simulated BHCT 53 degF Max HCT Depth 3949.0 ft CT at TOC 53 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time 00:05 hr:mn 00:10 hr:mn Geo.Temp. Top of Cement 53 degF 53 degF 67 degF Bottom Hole 209 degF 53 degF 70 degF Page 4 red wolf 2 draft PnA v1 4-16-2012 cfw,04-21-2012, LoadCase Retainer Squeeze,Version wcs-cem471_02 Client : Savant Well : Red Wolf#2 ScMMinberger String : Retainer Squeeze District : Prudhoe Bay,Alaska Country : USA Loadcase : Retainer Squeeze kr)_ _ Depth= 3949 ft e`+ —Frac —Pore —Mythosldtit: — o---Dynamic M o I O r,[i IE tix csi Ea LXu� N c-4 I co III 0 Cl ate! cNl c I d kr) 1 r-- t 0 5 10 15 20 25 30 35 Time (min) Page 5 red wolf 2 draft PnA v1 4-16-2012.cfw,04-21-2012, LoadCase Retainer Squeeze,Version wcs-cem471_02 Client : Savant Well : Red Wolf#2 Schlumberger String : Retainer Squeeze District : Prudhoe Bay,Alaska Country : USA Loadcase : Retainer Squeeze Section 3: fluid description Mud DESIGN Fluid No: 1 Density :9.60 lb/gal Rheo. Model : HERSCHEL_B. k : 1.29E-2 Ibf.sAn/ft2 At temp. : 105 degF n :0.553 Ty :5.54Ibf/100ft2 Gel Strength : 13.88 Ibf/100ft2 MUD Mud Type :WBM Job volume :34.0 bbl Water Type : Fresh VOLUME FRACTION Solids : 6.0% Oil : 0.0% Water : 94.0 Plug Slurry DESIGN Fluid No: 3 Density : 15.80 lb/gal Rheo. Model : BINGHAM Pv : 57.980 cP At temp. : 54 degF Ty :75.01 Ibf/100ft2 Gel Strength :40.56 Ibf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid : 5.104 gal/sk Job volume : 17.0 bbl Dry Density : 199.77 Ib/ft3 Yield : 1.16 ft3/sk Quantity : 82.05 sk Sack Weight :94 lb Solid Fraction :41.3% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 5.094 gal/sk Additives Code Conc. Function D046 0.200%BWOC Antifoam D065 0.300%BWOC Dispersant D167 0.350%BWOC Fluid loss D153 0.200%BWOC Antisettling D186 0.010 gal/sk cement Accelerator HWP Water DESIGN Fluid No:4 Density :8.34 lb/gal Rheo. Model : NEWTONIAN At temp. : 80 degF Viscosity :5.000 cP Gel Strength :(Ibf/100ft2) Job volume :7.0 bbl Page 6 red wolf 2 draft PnA v1 4-16-2012.cfw,04-21-2012, LoadCase Retainer Squeeze;Version wcs-cern471 02 Client : Savant Well : Red Wolf#2 Schlumberger String : Retainer Squeeze District : Prudhoe Bay,Alaska Country : USA Loadcase : Retainer Squeeze Section 4: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name G 77131b 83 sack 941b D046 151b 1 sack 501b D065 23 lb 1 sack 50 lb D167 271b 2 sack 251b D153 151b 1 sack 251b D186 0.8 gal 1 can 5.0 gal Mix Water Requirements : HWP Water 17 Bbls MIXING PREPARATION Plug Slurry Volume : 17.0 bbl Density : 15.80 lb/gal Yield : 1.16 ft3/sk _ Dry Phase Liquid Phase Blend: (lb) Design Mix Water 10.0 bbl 10.0 bbl LAS Design G 7712.979 lb Fresh water 9.953 bbl 9.982 bbl D046 15.426 lb 0.200%BWOC D186 0.821 gal 0.823 gal 0.010 gal/sk cement D065 23.139 lb 0.300%BWOC D167 26.995 lb 0.350%BWOC D153 15.426 lb 0.200%BWOC HWP Water Volume :7.0 bbl Density:8.34 lb/gal Code Quantity Design HWP Water 7.000 bbl Page 7 red wolf 2 draft PnA v1 4-16-2012.cfw,04-21-2012, LoadCase Retainer Squeeze,Version wcs-cem471 02 f Schlumberger Laboratory Cement Test Report Nabors 7ES Red Wolf 2 Plug Field Blend Signatures _ Fluid No : PAK 12pIg2048 Client :Savant Alaska Location/Rig : Nabors 7ES Date :Apr-21-2012 Well Name : Red Wolf 2 Field : Badami Daniel Himel Job Type Abandonment Depth 3847.0 ft TVD 3847.0 ft BHST 71 degF BHCT 54 degF BHP 1976 psi Starting Temp. 80 degF Time to Temp. 00:30 hr:mn Heating Rate -0.87 degF/min Starting Pressure 500 psi Time to Pressure 00:30 hr:mn Schedule ( ) Composition Slurry Density 15.80 lb/gal Yield 1.17 ft3/sk Mix Fluid 5.159 gal/sk Solid Vol.Fraction 41.1 % Porosity 58.9% Slurry type Conventional Code Concentration Sack Reference Component Blend Density Lot Number G 94 lb of CEMENT Blend 199.77 lb/ft3 Fresh water 5.009 gal/sk Base Fluid D046 0.200%BWOC Antifoam TU1H0300A0 D065 0.300%BWOC Dispersant YL2717SC21 D167 0.350%BWOC Fluid loss DALA083361 D153 0.200°/°BWOC Antisettling 092811-03 D186 0.150 gal/sk Accelerator 102511-01 Rheology Tem.erature 80 degF 54 de.F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 100.0 100.0 100.0 124.0 124.0 124.0 200 85.0 83.0 84.0 93.0 92.0 92.5 100 58.0 67.0 62.5 65.0 63.0 64.0 60 34.0 56.0 45.0 38.0 37.0 37.5 30 23.0 34.0 28.5 26.0 24.0 25.0 6 12.3 25.1 18.7 14.6 10.0 12.3 3 10.0 24.9 17.4 10.4 9.4 9.9 10 sec Gel 27 deg-28.92 Ibf/100ft2 11 deg-12.17 Ibf/100ft2 10 min Gel 78 deg-83.57 Ibf/100ft2 39 deg -41.41 Ibf/100ft2 Rheo.computed I Viscosity:69.413 cP Yield Point:34.68 Ibf/100ft2 I Viscosity: 109.644 cP Yield Point: 18.02 lbf/100ft2 Thickenin Time 30 Bc 02:43 hr:mn 70 Bc 04:28 hr:mn 100 Bc 04:40 hr:mn Free Fluid 0.0 mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation: None Fluid Loss API Fluid Loss 188 mL 42 mL in 6 min at 54 degF and 1000 psi Water Analysis Chloride Calcium Magnesium 67.00 mg/I 45.00 mg/I 18.00 mg/I Page 1 Instrument:7222-461#2 Schlumberger Sampling Period:5 seconds Prudhoe Bay Well Services Laboratory Telephone:+1 907 659 6155 Facsimile:+1907 659 9221 250 12000- 100- 225 10800— 90- 200 9600— 80- 175 8400— 70— F. 151 7200- ii m 60— aN : T _ mV 72 125 = 6000— d 50- 1 m `0 Ed - - F 10 r o 4800— 0 40- 75 0 3600- p 30 _ ji • 50 2400- 20yi-i-/ ■ 25 1200- 10 0 0 0 ' ' ' ' I ' , ' , I , , , , I , , , ' I ' , , , 0:00 1:00 2:00 3:00 4:00 5:00 Time(HH:MM) Location:Red Wolf 2 30 Bc:2:50:00 File Name:pakl2plg2047-1-cell2.tst Customer:Savant Alaska 50 Bc:4:14:25 Supervisor:(Info:Supervisor) 70 Bc:4:28:40 Test Started:4/21/2012 5:12:53 PM Density:15.8 Ibm/gal 100 Bc:4:40:10 Test Stopped:4/21/2012 9:53:03 PM System:G+.2%D46+.3%065+.35%D167+.2%D153+.15gpsD186 BHCT:54 degF Printed:4/21/2012 10:15:27 PM BHST:71 degF Job Type:Plug Rig Name:Nabors 7ES Page 1 Instrument:PAK SGSA Current Compressive Strength:1209 psi Schlumberger Sampling Period:30 seconds Final Compressive Strength:1209 psi at 31:44:00 Prudhoe Bay Well Services Laboratory Compressive strength type B(more than 14 lb/gal) Telephone:+1 907 659 6155 Facsimile:+1 907 659 9221 70— 18— 1400 ::I ::_ :: - 12- i m - L m d 40 - V 10— a 800 J _ E : to S m g m 30- 8- w 600 c g m i— 6— a 0 20— _ 400 _ v 4— i ; 10- 200 2- 0 0 0 0:00 15:00 30:00 45:00 Time(HH:MM) Location:Red Wolf 2 50 psi:7:31:00 File Name:pakl2plg2048-SGSA.tst Customer:Savant Alaska 500 psi:16:16:00 Supervisor.(Info:Supervisor) 1000 psi:26:06:00 Test Started:4/21/2012 10:49:18 PM Density:15.8Ibm/gal 2000 psi:N/A Test Stopped:4/23/2012 6:33:32 AM System:G+.2%D46+.3%065+.35%D 167+.2%D 153+.15gpsD 1 86 BHCT:54 degF 12 hr.260 psi Printed:4/23/20127:21:09 AM BHST:71 degF 24 hr.910 psi Job Type:Plug Page 1 Rig Name:Nabors 7ES Static Gel Stregnth(1001bf/100ft2):4:21:30 Static Gel Strength(500 lbf/100ft2):4:36:30 Schlumberger Cementing Job Report CemCAT v1.4 Well Red Wolf.2 Client Savant Field Badami SIR No. 65892 Engineer Garric Job Type Retainer Sqz Country United States Job Date 04-23-2012 Time 04/23/2012 0 1935 Pressure -- - - Rate Density Messages 02:14:25 --,,..__ prime up 02:24:00 02:34:00 02:44:00 fluid pack lines 02:54:00 pt lines 03:04:00injection test Reset Total,Vol=2.53 bbl 03:14:00 shut down batch up cement Reset Total,Vol=14.79 bbl 03:24:00 .? Dump water behind 03:34:00 r Reset Total,Vol=15.97 bbl rig to displace 1 Reset Total,Vol=4.08 bbl 03:44:00 03:57:40 r hh:mm:ss 0.00 3000 2000 3000 4000 5000 0.00 2.0 4.0 6.0 8.0 10.0 5.0 10.0 15.0 20.0 25.0 04/23/2012 03:57.40 - PSI B/M LB/G 04/23/2012 03:59:21 Schlumberger Cementing Service Report Customer Job Number Savant 65892 Well Location(legal) Schlumberger Location Job Start Red Wolf#2 Red wolf#2 Nabors 7ES Prudhoe Bay,AK Apr/23/2012 Field Formation Name/Type Deviation Bit Size Well MD Well TVD Badami deg in ft ft County USA State/Province Alaska BHP BHST BHCT Pore Press.Gradient Well Master API/UWI psi 71 degF 54 degF lb/gal Rig Name Drilled For Service Via Casing/Liner Nabors 2ES exploration Land Depth,ft Size,in Weight,lb/ft Grade Thread Offshore Zone Well Class Well Type 3847.0 9.6 47.0 New Exploration 0.0 0.0 0.0 Drilling Fluid Type Max.Density Plastic Viscosity Tubing/Drill Pipe lb/gal cP T/D Depth,ft Size,in Weight,lb/ft Grade Thread Service Line Job Type D 3776.0 4.0 14.0 Cementing Retainer Sqz D 0.0 0.0 0.0 Max.Allowed Tub.Press Max.Allowed Ann.Press WH Connection Perforations/Open Hole 1500 psi • psi drill pin Top,ft Bottom,ft shot/ft No.of Shots Total Interval Service Instructions ft ft ft ft ft Diameter ft ft - - in Treat Down Displacement Packer Type Packer Depth Drill Pipe bbl Retainer 3776.0 ft Tubing Vol. Casing Vol. Annular Vol. Openhole Vol. 40.9 bbl bbl bbl bbl Casing/Tubing Secured El 1 Hole Vol.Circulated prior to Cement U Casing Tools Sq Job Lift Pressure psi Shoe Type Sq Type Pipe Rotated a Pipe Reciprocated ❑ Shoe Depth ft Tool Type No.Centralizers Top Plugs Bottom Plugs Stage Tool Type Tool Depth ft Cement Head Type Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Arrived on Location Leave Location Collar Type Tail Pipe Depth ft Apr/23/2012 Apr/23/2012 Apr/23/2012 Collar Depth p ft Sqz.Total Vol. bbl Date Time Treating Flow Density Volume Message 24-hr P Rate LB/G BBL dock PSI B/M 04/23/2012 02:14:25 48 0.0 6.00 0.0 Started Acquisition 04/23/2012 02:14:40 62 0.0 6.61 0.0 prime up 04/23/2012 02:14:55 76 0.0 6.83 0.0 04/23/2012 02:15:25 90 0.0 7.44 0.0 04/23/2012 02:15:55 158 0.0 8.40 0.0 04/23/2012 02:16:25 209 0.0 8.39 0.0 04/23/2012 02:16:55 71 0.0 3.73 0.0 04/23/2012 02:17:25 227 0.0 8.38 0.0 04/23/2012 02:17:55 204 0.0 8.39 0.0 04/23/2012 02:18:25 222 0.0 8.39 0.0 04/23/2012 02:18:55 190 0.0 8.41 0.0 04/23/2012 02:19:25 30 0.0 8.40 0.0 04/23/2012 02:19:55 21 0.0 8.40 0.0 04/23/2012 02:20:25 16 0.0 8.41 0.0 04/23/2012 02:20:55 12 0.0 8.40 0.0 04/23/2012 02:21:25 12 0.0 8.40 0.0 04/23/2012 02:21:55 12 0.0 8.40 0.0 04/23/2012 02:22:25 94 0.0 8.40 0.0 04/23/2012 02:22:55 85 0.0 8.40 0.0 04/23/2012 02:23:25 3 0.0 8.40 0.0 04/23/2012 02:23:55 3 0.0 8.40 0.0 Page 1 of 5 I T Well Field Job Start ,Customer lob Number 1 , Red Wolf#2 Red wolf#2 Badami 1 Apr/23/2012 Savant 65892 Date Time Treating Flow Density Volume Message 1 24-hr Pressure Rate Le/a BBL dock PSI 11/14 04/23/2012 02:24:55 3 0.0 8.40 0.0 04/23/2012 02:25:25 12 0.0 8.40 0.0 04/23/2012 02:25:55 16 0.0 8.40 0.0 04/23/2012 02:26:25 12 0.0 8.40 0.0 04/23/2012 02:26:55 12 0.0 8.39 0.0 04/23/2012 02:27:25 7 0.0 8.41 0.0 04/23/2012 02:27:55 7 0.0 8.35 0.0 04/23/2012 02:28:25 7 0.0 8.34 0.0 04/23/2012 02:28:55 7 0.0 8.33 0.0 04/23/2012 02:29:25 3 0.0 8.33 0.0 04/23/2012 02:29:55 7 0.0 8.34 0.0 04/23/2012 02:30:25 3 0.0 8.33 0.0 04/23/2012 02:30:553 0.0 , 8.33 0.0 - - ,- 04/23/2012 02:31:25 3 I 0.0 8.34 0.0 -4-- 4 -- 04/23/2012 02:31:55 7 0.0 8.34 0.0 H04/23/2012 0232:25 7 0.0 8.34 0.0 04/23/2012 02:32:55 3 0.0 8.34 0.0 04/23/2012 02:33:25 7 0.0 8.34 0.0 ._, 04/23/2012 02:33:55 3 0.0 8.34 0.0 04/23/2012 02:34:25 3 0.0 8.34 0.0 04/23/2012 02:34:55 1 3 0.0 8.32 0.0 1- 04/23/2012 02:35:25 1 3 0.0 8.33 0.0 04/23/2012 02:35:55 3 0.0 8.32 0.0 04/23/2012 02:36:25 I 3 0.0 8.33 0.0 I 1- 04/23/2012 02:36:55 , 3 0.0 8.32 0.0 04/23/2012 02:37:25 -2 0.0 8.33 0.0 04/23/2012 02:37:55 3 0.0 8.33 0.0 04/23/2012 02:38:25 3 0.0 8.33 0.0 04/23/2012 02:38:55 3 0.0 8.33 0.0 04/23/2012 02:39:25 3 0.0 8.33 0.0 04/23/2012 02:39:55 3 0.0 8.32 0.0 04/23/2012 02:40:25 3 0.0 8.33 0.0 04/23/2012 02:40:55 , 3 0.0 8.33 0.0 04/23/2012 02:41:25 3 0.0 ] 8.31 0.0 04/23/2012 02:41:55 3 0.0 8.33 0.0 04/23/2012 02:42:25 3 0.0 t 8.32 0.0 04/23/2012 02:42:55 7 0.0 8.32 0.0 04/23/2012 02:43:25 3 0.0 8.33 0.0 04/23/2012 02:43:55 3 0.0 8.32 0.0 04/23/2012 02:44:25 3 0.0 8.32 0.0 04/23/2012 02:44:55 7 0.0 8.33 0.0 04/23/2012 , 02:45:25 3- 0.0 8.33 0.0 -1- 04/23/2012 ' 02:45:38 ' 3 0.0 8.32 0.0 fluid pack lines 04/23/2012 02:45:55 3 0.0 8.33 0.0 04/23/2012 02:46:25 3 0.0 8.36 0.0 04/23/2012 02:46:55 3 0.0 8.35 0.0 04/23/2012 02:47:25 35 0.3 8.40 0.0 04/23/2012 02:47:55 71 0.5 8.40 0.3 _ 04/23/2012 02:48:25 94 0.4 8.39 0.5 04/23/2012 02:48:55 186 0.7 8.38 0.8 04/23/2012 02:49:25 -- 218 0.5 8.39 1.1 04/23/2012 02:49:55 264 0.3 8.39 1.3 04/23/2012 02:50:25 300 0.2 8.38 1.4 04/23/2012 02:50:55 369 0.4 8.38 1.6 Page 2 of 5 - , Well Field lob Start Customer Job Number Red Wolf#2 Red wolf#2 Badami Apr/23/2012 1_ Savant 65892 - . Date Time Treating Flow Density Volume Message 24-hr Pressure Rate LB/13 BBI. dock PSI 11/41 04/23/2012 02:51:55 492 0.6 8.38 2.2 04/23/2012 02:52:25 447 0.0 8.38 2.5 04/23/2012 02:52:55 424 0.0 8.39 2.5 04/23/2012 0253:23 419 0.0 8.39 2.5 pt lines 04/23/2012 02:53:25 415 0.0 J 8.40 2.5 04/23/2012 02:53:55 410 0.0 8.39 2.5 04/23/2012 02:54:25 2795 0.0 8.40 2.5 t i---- i 1 04/23/2012 02:54:55 3079 0.0 8.39 2.5 04/23/2012 02:55:25 2969 0.0 8.39 2.5 1- 04/23/2012 02:55:55 2896 0.0 J 8.39 2.5 04/23/2012 02:56:25 2836 0.0 8.39 -1- 2.5 04/23/2012 02:56:55 2781 0.0 8.39 2.5 04/23/2012 02:57:25 2763 0.0 8.40 2.5 04/23/2012 02:57:55 3138 0.0 8.39 2.5 04/23/2012 02:58:25 3111 0.0 8.40 2.5 04/23/2012 02:58:55 3093 0.0 I 8.39 2.5 04/23/2012 02:59:25 3074 0.0 8.40 2.5 04/23/2012 02:59:55 3051 0.0 8.39 2.5 04/23/2012 03:00:25 2850 0.0 8.39 2.5 04/23/2012 03:00:55 12 0.0 8.39 2.5 [ 04/23/2012 03:01:25 300 0.0 8.39 2.5 1 1---- 04/23/2012 03:01:55 268 0.0 8.39 2.5 -1 04/23/2012 03:02:25 268 0.0 8.39 2.5 , 04/23/2012 03:02:55 268 0.0 8.39 2.5 04/23/2012 03:03:14 264 0.0 8.39 2.5 injection test _L 04/23/2012 03:03:25 264 0.0 8.39 2.5 -f -1 04/23/2012 03:03:27 264 0.0 8.39 2.5 I Reset Total,Vol=2.53 bbl 04/23/2012 03:03:55 264 0.0 8.39 1 2.5 ---1 04/23/2012 03:04:25 264 0.0 8.40 2.5 1 , 04/23/2012 03:04:55 428 0.5 8.40 2.7 _L 1 -,- ! 04/23/2012 03:05:25 483 0.5 8.38 3.0 , 04/23/2012 03:05:55 570 0.5 8.38 3.2 , 04/23/2012 03:06:25 589 0.5 8.38 3.5 i 04/23/2012 03:06:55 621 0.5 8.39 3.7 , 4.1 1 04/23/2012 03:07:25 767 1.0 8.38 04/23/2012 03:07:55 845 1.0 8.38 4.6 1 04/23/2012 03:08:25 969 1.5 8.38 5.1 04/23/2012 03:08:55 1037 1.4 8.38 5.8 04/23/2012 03:09:25 1193 1.9 8.39 r-------- 6.6-4 04/23/2012 03:09:55 1294 1.9 8.39 7.6 . _ 04/23/2012 03:10:25 1458 2.4 8.39 8.6 04/23/2012 03:10:55 1536 2.5 8.38 9.8 04/23/2012 03:11:25 1303 2.5 8.38 11.1 1- 04/23/2012 03:11:55 1225 2.6 8.38 12.4 04/23/2012 03:12:25 1239 2.6 8.38 13.6 -1- 04/23/2012 03:12:55 1417 3.4 8.38 15.2 04/23/2012 03:13:25 1316 3.1 8.38 16.7 04/23/2012 03:13:55 854 0.0 8.39 17.3 04/23/2012 03:14:21 845 0.0 8.39 17.3 shut down batch up cement 04/23/2012 03:14:25 845 0.0 8.39 17.3 04/23/2012 03:14:55 836 0.0 8.39 17.3 -I- 04/23/2012 03:15:25 827 0.0 8.40 17.3 04/23/2012 03:15:55 822 0.0 8.40 17.3 04/23/2012 03:16:25 817 0.0 839 ,J 17.3 1 Page 3 of 5 PNell Field lob Start I Customer lob Number Red Wolf#2 Red wolf#2 Badami Apr/23/2012 li Savant 65892 Date Time Treating Flow Density Volume Message 24-hr Pressure Rate LB/6 BBL dock PSI B/M 04/23/2012 03:16:55 813 0.0 8.39 0.0 04/23/2012 03:17:25 808 0.0_, 8.40 0.0 04/23/2012 03:17:55 804 0.0 8.40 0.0 04/23/2012 03:18:25 799 0.0 8.39 0.0 04/23/2012 03:18:55 795 0.0 8.35 0.0 04/23/2012 03:19:25 790 0.0 8.47 0.0 04/23/2012 03:19:55 790 0.0 11.02 0.0 04/23/2012 03:20:25 785 0.0 12.93 0.0 04/23/2012 03:20:55 781 0.0 14.72 0.0 04/23/2012 03:21:25 781 0.0 15.84 0.0 04/23/2012 I 03:21:55 781 i 0.0 15.94 0.0 04/23/2012 1- 03:22:25 776 0.0 15.90 0.0 --- 04/23/2012 03:22:55 - 730 0.0 15.90 0.0 04/23/2012 03:23:25 776 0.2 1 15.88 0.1 04/23/2012 03:23:55 790 0.2 15.87 0.2 H 04/23/2012 03:24:25 900 0.9 15.86 0.4 04/23/2012 03:24:55 973 0.9 16.10 0.8 04/23/2012 03:25:25 969 0.9 15.41 1.3 04/23/2012 03:25:55 1161 1.9 16.35 2.2 04/23/2012 03:26:25 1381 2.5 15.78 3.2 04/23/2012 03:26:55 1307 2.5 15.93 4.4 04/23/2012 03:27:25 1326 2.5 15.87 5.7 04/23/2012 03:27:55 1284 2.6 -- --_ 15.83 _--7.0- - - 1I 04/23/2012 03:28 1239 2.7 15.78 8.3 04/23/2012 03:28:55 1202 I 2.6 15.95 9.6- ----- 04/23/2012 03:29:25 1033 2.2 15.92 I 10.9 04/23/2012 03:29:55 955 2.2 15.93 12.0 04/23/2012 03:30:25 914 2.0 15.74 13.0 04/23/2012 03:30:55 849 Iii 2.1 16.13 14.0 04/23/2012 03:31:25 827 2.1 16.04 15.1 04/23/2012 03:31:55 552 1.2 16.04 15.9 04/23/2012 03:32:19 369 0.0 16.00 16.0 pump water behind 04/23/2012 03:32:25 364 0.0 16.00 16.0 04/23/2012 03:32:37 355 0.0 16.00 16.0 Reset Total,Vol=15.97 bbl 04/23/2012 03:32:55 744 2.0 13.20 16.3 04/23/2012 03:33:25 648 2.3 8.99 17.4 04/23/2012 03:33:55 621 2.4 8.56 18.6 04/23/2012 03:34:25 621 ! 2.4 8.46 19.8 .04/23/2012 03:34:53 332 0.0 8.44 ! 20.1 rig to displace ----- --- -------- I -t- ------ ------- ---- -- 04/23/2012 03:34:55 332 0.0 ! 8.44 20.1 04/23/2012 03:34:59 332 0.0 8.44 20.1 Reset Total,Vol=4.08 bbl -.- 04/23/2012 -----03:35:25 328 --_--0.0 --- 8.43 20.1 04/23/2012 03:35:55 318 0.0 8.44 20.1 04/23/2012 03:36:25 318 0.0 8.40 20.1 04/23/2012 03:36:55 318 0.0 13.66 20.1 04/23/2012 03:37:25 314 0.0 12.97 20.1 04/23/2012 03:37:55 314 0.0 13.02 20.1 04/23/2012 03:38:25 309 0.0 12.82 20.1 04/23/2012 03:38:55 309 0.0 12.57 20.1 04/23/2012 03:39:25 305 0.0 12.86 20.1 04/23/2012 03:39:55 300 0.0 12.86 20.1 04/23/2012 03:40:25 305 0.0 12.88 20.1 04/23/2012 03:40:55 300 0.0 12.87 20.1 t I1 04/23/2012 03:41:25 300 0.0 i 12.86 20.1 1 -_- _- Page 4 of 5 Well Field Job Start Customer Job Number Red Wolf#2 Red wolf#2 Badami Apr/23/2012 Savant 65892 Date Time Treating Flow Density Volume Message 29-hr Pressure Rate LB/G BBL dock PSI Biel 04/23/2012 03:42:25 7 1 0.0 1 13.01 20.1 04/23/2012 03:42:55 2960.0 , 13.00 20.1 04/23/2012 03:43:25 12 0.0 13.02 20.1 04/23/2012 03:43:55 7 0.0 9.25 20.1 _I 04/23/2012 03:44:25 433 0.0 9.09 20.1 04/23/2012 03:44:55 428 0.0 9.08 20.1 04/23/2012 03:45:25 181 0.0 9.13 20.1 04/23/2012 03:45:55 30 0.0 9.08 20.1 04/23/2012 03:46:25 21 0.0 8.69 20.1 04/23/2012 03:46:55 21 0.0 8.77 20.1 04/23/2012 03:47:25 16 0.0 8.76 20.1 04/23/2012 03:47:55 12 0.0 8.73 20.1 04/23/2012 03:48:25 12 0.0 8.74 20.1 04/23/2012 03:48:55 12 0.0 8.85 20.1 04/23/2012 03:49:25 12 0.0 8.42 20.1 04/23/2012 03:49:55 12 I 0.0 8.64 20.1 r- _1 04/23/2012 03:50:25 12 0.0 8.63 20.1 04/23/2012 03:50:55 76 0.0 8.63 20.1 04/23/2012 03:51:25 48 0.0 8.621 20.1 04/23/2012 03:51:55 67 0.0 8.60 20.1 04/23/2012 03:52:25 -2 0.0 8.61 20.1 04/23/2012 03:52:55 7 0.0 8.72 20.1 04/23/2012 03:53:25 199 0.0 8.49 20.1 d 04/23/2012 03:53:55 58 0.0 8.53 20.1 04/23/2012 03:54:25 39 i 0.0 8.54 20.1 ! 04/23/2012 03:54:55 I 44 0.0 i 8.51 1 20.1 --i -'- 04/23/2012 03:55:25 1 48 0.0 8.52 20.1 i 04/23/2012 03:55:55 48 0.0 8.51 '1 20.1 04/23/2012 03:56:25 44 0.0 8.51 20.1 04/23/2012 03:56:55 48 0.0 8.50 20.1 -I Post Job Summary Average Pump Rates,bbl/min Volume of Fluid Injected,bbl ' Slurry N2 Mud Maximum Rate Total Slurry Mud Spacer N2 1.5 3.4 20.1 0.0 0.0 Treating Pressure Summary,psi Breakdown Fluid Maximum Final Average Bump Plug to Breakdown Type Volume Density 3180 0 533 bbl lb/gal I I I Avg.N2 Percent Designed Slurry Volume Displacement I Mix Water Temp Cement Circulated to Surface? D Volume bbl 0.0 bbl 0.0 bbl I 1 81 degF Washed Thru Perfs D To ft Customer or Authorized Representative Schlumberger Supervisor Circulation Lost D Job Completed X Gary Hammond Garric - - Page 5 of 5 Schlumberger CemCAD E* well cementing recommendation for Surface P&A Plug Operator : Savant Well : Red Wolf#2 Country : USA Field : Badami State : AK Prepared for : Mr.Gary Hammon Location : Nabors 7ES Proposal No. : Field v1 Service Point : Prudhoe Bay,Alaska Date Prepared : 04/21/2012 Business Phone : 907-659-2434 FAX No. 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 E-Mail : JLong1@slb.com well description Configuration Plug Stage:Single Rig Type:Land Prev.String MD:3849.0 ft OD:9 5/8 in Weight:47.0 lb/ft Drill Pipe MD:200.0 ft OD:4 in Weight:14.0 lb/ft Casing/liner Shoe MD 12100.0 ft Mud Line 0.0 ft Total MD 12100.0 ft BHST <32 degF Bit Size 8 1/2 in Mean OH Diameter 8.500 in otsi Mean Annular Excess 0.0% lC Mean OH Equivalent Diameter 8.500 in d Total OH Volume 579.1 bbl (including excess) C7 04, 9�&ATE Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements.assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL.PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be interred and no intellectual property rights are granted hereby. Mark of Schlumberger Page 1 red wolf 2 draft PnA v1 4-16-2012.cfw;04-21-2012; LoadCase Surface Plug;Version wcs-cem471_02 Client : Savant Well : Red Wolf#2 Schlumberger String : Surface P&A Plug District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Plug Section 1 : fluid sequence Original fluid Mud 9.60 lb/gal k: 1.29E-2 Ibf.s^n/ft2 n : 0.553 Ty: 5.54 lbf/100ft2 Displacement Volume 2.2 bbl Drill Pipe Volume 2.2 bbl Total Volume 15.5 bbl TOC 38.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) HWP Water 4.0 38.0 8.34 viscosity:5.000 cP AS1 9.3 162.0 38.0 15.70 k:1.21 E-3 lbf.s^n/ft2 n:1.057 Ty:2.76 lbf/100ft2 AS1 1.8 38.0 15.70 k:1.21 E-3 Ibf.s^n/ft2 n:1.057 Ty:2.76 lbf/100ft2 HWP Water 0.3 10.3 8.34 viscosity:5.000 cP HWP Water 0.1 0.0 8.34 viscosity:5.000 cP Static Security Checks: Frac 1032 psi at 3849.0 ft Pore 208 psi at 3849.0 ft Csg.Pump out 1 ton Check Valve Diff Press 0 psi Page 2 red wolf 2 draft PnA v1 4-16-2012.cfw,04-21-2012, LoadCase Surface Plug,Version wcs-cern471.02 F Client : Savant Well : Red Wolf#2 3chlamberger String : Surface P&A Plug District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Plug ft lb/gal 8 19 16 - _—Hydrostatic —I - . . ' —Nin.Hydrostatic —Nhx.Dynamic o- . —Mn.Dynamic - • Frac - : , Pore p - . o- N - o " o- o - • o- v .. 0 o- uo Fluid Sequence Dynamic Well Security Section 2: pumping schedule Start Job: Set EZSV, Pres. Test, establish circulation, Test lines Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) HWP Water 2.0 4.0 2.0 4.0 80 Water Ahead Pause 0.0 0.0 3.0 0.0 80 Weight Up Tub AS1 3.0 9.3 3.1 9.3 80 Mix&Pump Slurry AS1 1.0 1.8 1.8 11.1 80 Suck Down Tub Pause 0.0 0.0 1.0 0.0 80 Line Up Water HWP Water 1.0 0.4 0.4 0.4 80 Displace-40 feet Total 00:11 hr:mn 15.5 bbl End Job: Pull up and let cement plug balance Dynamic Security Checks: Frac 1030 psi at 3849.0 ft Pore 156 psi at 3849.0 ft Temperature Results BHCT 58 degF Simulated Max HCT 79 degF Simulated BHCT 79 degF Max HCT Depth 200.0 ft CT at TOC 77 degF Max HCT Time 00:11:17 hr:mn:sc Page 3 red wolf 2 draft PnA o1 4-16-2012 cfw,04-21-2012, LoadCase Surface Plug,Version wcs-cem471_02 I Client : Savant Well : Red Wolf#2 Schlumberger String : Surface P&A Plug District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Plug Section 3: fluid description HWP Water DESIGN Fluid No:4 Density :8.34 lb/gal Rheo. Model : NEWTONIAN At temp. :80 degF Viscosity : 5.000 cP Gel Strength : (Ibf/100ft2) Job volume :4.4 bbl AS1 DESIGN Fluid No: 5 Density : 15.70 lb/gal Rheo. Model : HERSCHEL_B. k : 1.21 E-3 Ibf.s^n/ft2 At temp. :48 degF n : 1.057 Ty :2.761bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name :ArcticSET1 Mix Fluid : 3.536 gal/sk Job volume : 11.1 bbl Dry Density : 174.56 Ib/ft3 Yield : 0.93 ft3/sk Quantity : 67.05 sk Sack Weight : 80 lb Solid Fraction :49.2 BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 3.536 gal/sk Page 4 red wolf 2 draft PnA v1 4-16-2012.cfw,04-21-2012, LoadCase Surface Plug,Version wcs-cem471_02 Client : Savant Well : Red Wolf#2 Schiemberger String : Surface P&A Plug District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Plug Section 4: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name AS 1 5347 lb 54 sack 100 lb Mix Water Requirements : HWP Water 11 Bbl MIXING PREPARATION HWP Water Volume :4.4 bbl Density:8.34 lb/gal Code Quantity Design HWP Water 4.411 bbl AS 1 Volume : 11.1 bbl Density : 15.70 lb/gal Yield : 0.93 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 5.6 bbl 10.0 bbl LAS Design ArcticSET1 5346.954 lb Fresh water 5.644 bbl 10.001 bbl Page 5 red wolf 2 draft PnA v1 4-16-2012.cfw;04-21-2012; LoadCase Surface Plug;Version wcs-cem471_02 Schlumberger Laboratory Cement Test Report Nabors 7ES Red Wolf 2 AS1 Field Blend Signatures Fluid No : PAK 12pIg2049 Client :Savant Location/Rig : Nabors 7ES Date :Apr-21-2012 Well Name : Red Wolf 2 Field : Badami Daniel Himel Job Type Plug Depth 200.0 ft TVD 200.0 ft BHST 32 degF BHCT 77 degF BHP 500 psi Starting Temp. 80 degF Time to Temp. 00:20 hr:mn Heating Rate -0.75 degF/min Starting Pressure 500 psi Time to Pressure 00:20 hr:mn Schedule ( ) Composition Slurry Density 15.70 lb/gal Yield 0.93 ft3/sk Mix Fluid 3.536 gal/sk Solid Vol. Fraction 49.1 % Porosity 50.9% Slurry type Other Blend AS1 Code Concentration Sack Reference Component Blend Density Lot Number D816 80 lb of BLEND Blend 174.59 lb/ft3 Fresh water 3.536 gal/sk Base Fluid Rheology Tem.erature 80 degF 48 de.F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 80.0 80.0 80.0 88.0 88.0 88.0 200 63.0 65.0 64.0 67.0 73.0 70.0 100 29.0 30.0 29.5 31.0 33.0 32.0 60 19.0 19.0 19.0 20.0 32.0 26.0 30 13.0 11.0 12.0 12.0 12.0 12.0 Cl) 6 9.9 4.4 7.1 5.4 5.5 5.4 7- 3 8.4 4.2 6.3 4.7 4.9 4.8 C 10 sec Gel 11 deg-11.74_Ibf/100ft2 10 deg- 11.10 Ibf/100ft2 a' 10 min Gel 92 deg-98.09 Ibf/100ft2 49 deg -52.19 Ibf/100ft2 ro Rheo.computed Viscosity:79.494 cP Yield Point:4.52 Ibf/100ft2 Viscosity:87.462 cP Yield Point:5.28 Ibf/100ft2 ro Thickenin Time <' °s 30 Bc 03:08 hr:mn 70 Bc 03:37 hr:mn 100 Bc 03:43 hr:mn Free Fluid 0.0 mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation: None Page 1 Instrument:8240#4 Schlumberger Sampling Period:5 seconds Prudhoe Bay Well Services Laboratory Telephone:+1 907 659 6155 Facsimile:+1 907 659 9221 250 12000— 100— - - • - 225 10800 90- 201 9600— 80- 175 8400— 70— Lt 151 = 7200- m 60- - E n = > _ E 4a 125 E 6000— d 50— d N y - a y _ •M _ 101 a 4800— 3 40- 75 ID 3600- 30� O 50 2400- 20- 25 1200- 10- r 0 0 0 , , , , I , , , , I , , , , I , , , , I , , , , I , , , , ` , , , , I , , , , I 0:00 0:30 1:00 1:30 2:00 2:30 3:00 3:30 4:00 Time(HH:MM) Location:Red Wolf 2 30 Bc:3:10:05 File Name:pak12plg2049-2-cell4.tst Customer:Savant Alaska 50 Bc:3:30:20 Supervisor.{Info:Supervisor} 70 Bc:3:37:55 Test Started:4/21/2012 10:15:13 PM Density:15.7Ibn gal 100 Bc:3:43:10 Test Stopped:4/22/2012 1:58:23 AM System:AS1 BHCT:77 degF Printed:4/22/2012 2:29:24 AM BHST:32 degF Job Type:Plug Rig Name:Nabors 7ES Page 1 Instrument:UCA#2 Current Compressive Strength:1075 psi Schlumberger Sampling Period:30 seconds Final Compressive Strength:1075 psi at 16:43:30 Prudhoe Bay Well Services Laboratory Compressive strength type B(more than 14 lb/gall Telephone:+1 907 659 6155 Facsimile:+1 907 659 9221 80— 16 1200— _ ` . ::', 14 1000 12 q 600— `y p 50— 5 11 ❑ E ` 40 8 T, 600— m _ E i - E ' w - - m 30— . 6 0 - ' F c� 400— t20Th 4 200- 10— 2 0 0 0 I � I , I 0:00 5:00 10:00 15:00 20:00 Time(HH:MMI Location:Red Wolf 2 50 psi: 1:35:00 File Name:pakl2plg2049-UCA2.tst Customer:Savant Alaska 500 psi:1:51:00 Supervisor:{Info:Supervisor} 1000 psi:2:11:30 Test Started:4/21/2012 9:10:09 PM Density:15.7 Ibm/gal 2000 psi:N/A Test Stopped:4/22/2012 1:54:02 PM System:AS1 BHCT:77 degF 12 hr. 1073 psi Printed:4/22/2012 1:57:07 PM BHST:32 degF 24 hr:N/A Job Type:Plug Page 1 Rig Name:Nabors 7ES Schlumberger Cementing Job Report CemCAT v1.4 Well RED WOLF#2 Client Savant Field Badami SIR No. 65892 Engineer Jeff Long lob Type PA Country United States lob Date 04-23-2012 Time Pressure Rate Density Messages 04/23/21.. n 10:07:13 r— priming up pump 10:17:00 10:27:00 fluid pack lines 10:37:00 Pressure Test Lines S pup water to displace d Rump water Vol=3.32 bbl 10:47:00 mmu batch up cement Reset Total,Vol=27.08 bbl 10:57:00 I--- Reset Total,Vol=13.21 bbl r wash Imes 11:07:00 Reset Total,Vol=4.22 bbl displace drill pipe pull drill pipe to 46' 11:17:00 Lpump water to clean hole Reset Total,Vol=0.39 bbl 11:27:00 1 11:35:45 1 hh:mm:ss 0.00 tow2000 3000 4000 5000 0.00 2.0 4.0 6.0 8.0 10.0 5.0 10.0 15.0 20.0 25.0 e4/23/2012/3:3s-as ----. --_ PSI B/M LB/G 04/23/2012 11:40:14 Schiumberger Cementing Service Report Customer Job Number Savant 65892 Well Location(legal) Schlumberger Location Job Start RED WOLF#2 Nabors 7ES Prudhoe Bay,AK Apr/23/2012 Field Formation Name/Type Deviation Bit Size Well MD Well TVD Badami deg in ft ft County USA State/Province Alaska BHP BHST BHCT Pore Press.Gradient Well Master API/UWI psi degF degF lb/gal Rig Name Drilled For Service Via Casing/Liner Depth,ft Size,in Weight,lb/ft Grade Thread Offshore Zone Well Class Well Type Drilling Fluid Type Max.Density Plastic Viscosity Tubing/Drill Pipe -- ------ -lb/gal cP T/D Depth,ft Size,in Weight,lb/ft Grade Thread Service Line Job Type Cementing P&A Max.Allowed Tub.Press Max.Allowed Ann.Press WH Connection Perforations/Open Hole psi psi Top,ft Bottom,ft shot/ft No.of Shots Total In 1 Service Instructions ft ft ft ft ft Diameter ft ft n Treat Down Displacement Packer Type Packer Depth bbl ft Tubing Vol. Casing Vol. Annular Vol. Openhole Vol. bbl bbl bbl bbl Casing/Tubing Secured E 1 Hole Vol.Circulated prior to Cement D Casing Tools Sq Job Lift Pressure psi Shoe Type Sq Type Pipe Rotated 0 Pipe Reciprocated 0 Shoe Depth ft Tool Type No.Centralizers Top Plugs Bottom Plugs Stage Tool Type Tool Depth ft Cement Head Type Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Arrived on Location Leave Location Collar Type Tail Pipe Depth ft Apr/23/2012 Apr/23/2012 Apr/23/2012 Collar Depth ft Sqz.Total Vol. bbl Date Time Treating Flow Density Volume Message 24-hr Rate - LB/G BBL clock PSI B/M 04/23/2012 10:07:13 591 0.0 8.38 0.0 Started Acquisition 04/23/2012 10:07:27 10 0.0 8.38 0.0 priming up pump 04/23/2012 10:07:43 _ 10 0.0 8.38 0.0 04/23/2012 10:08:13 5 0.0 8.38 0.0 04/23/2012 10:08:43 5 0.0 8.39 0.0 04/23/2012 10:09:13 5 0.0 8.39 0.0 04/23/2012 10:09:43 5 0.0 8.39 0.0 04/23/2012 10:10:13 60 0.0 8.38 0.0 04/23/2012 10:10:43 -9 0.0 8.38 0.0 04/23/2012 10:11:13 1 0.0 8.39 0.0 04/23/2012 10:11:43 1 0.0 8.38 0.0 04/23/2012 10:12:13 1 0.0 8.38 0.0 04/23/2012 10:12:43 1 0.0 8.39 0.0 04/23/2012 10:13:13 1 0.0 8.39 0.0 04/23/2012 10:13:43 1 0.0 8.39 0.0 04/23/2012 10:14:13 1 0.0 8.39 0.0 04/23/2012 10:14:43 1 0.0 8.39 0.0 04/23/2012 10:15:13 5 0.0 8.39 0.0 04/23/2012 10:15:43 1 0.0 8.38 0.0 04/23/2012 10:16:13 1 0.0 8.39 0.0 04/23/2012 10:16:43 5 0.0 8.39 0.0 Page 1 of 5 Well Field lob Start Customer Job Number RED WOLF#2 Badami Apr/23/2012 Savant 65892 Cete Time "iTreating: ! flow Density Volume Message 24-hr lPMeewre " Rate L8/6 BBL 04/23/2012 10:17:43 5 0.0 8.40 0.0 ----- ----------- 04/23/2012 10:18:13 1 0.0 8.38 0.0 04/23/2012 10:18:43 1 0.0 8.39 0.0 04/23/2012 10:19:13 1 0.0 8.39 0.0 04/23/2012 10:19:43 1 0.0 8.39 0.0 04/23/2012 10:20:13 1 0.0 8.39 0.0 -- -----_ -- - --- -- ----- - .--___ -------. 04/23/2012 10 20 43 0 1 0.0 8.39 0.0 04/23/2012 10:21:13 1 0.0 8.38 0.0 04/23/2012 10:21:43 1 0.0 8.39 0.0 04/23/2012 10:22:13 1 0.0 8.39 0.0 04/23/2012 10:22:43 1 0.0 8.39 0.0 04/23/2012 10:23:13 1 0.0 8.39 0.0 04/23/2012 10:23:43 1 0.0 8.39 0.0 04/23/2012 10:24:13 1 0.0 ! 8.38 0.0 04/23/2012 10:24:43 1 0.0 8.39 0.0 04/23/2012 10:25:13 1 0.0 8.39 0.0 04/23/2012 10:25:43 1 0.0 ! 8.38 0.0 04/23/2012 10:26:13 1 0.0 8.39 0.0 04/23/2012 10:26:43 1 0.0 8.39 0.0 04/23/2012 10:27:13 1 0.0 8.39 0.0 04/23/2012 10:27:43 -4 0.0 ]-. 8.39 0.0 04/23/2012 10:28:13 1 0.0 8.39 I 0.0 04/23/2012 10:28:43 1 0.0 8.390.0 __- __ . ..._----..--- ---4 Y __..------------ __-_._- --_ -------__. .. 04/23/2012 10:29:13 1 0.0 8.39 0.0 04/23/2012 10:29:43 1 �,l 0.0 8.39 0.0 04/23/2012 10:30:13 1 0.0 8.39 -0.0 04/23/2012 10:30:43 1 7 0.0 8.381 - 0.0 t -- � +------ ---- -- _...8.38 t- - 111 -- - - --04/23/2012 ( 10:31:13 1 0.0 8.39 0.0 ' 04/23/2012 j 10:31:32 1 0.0 8.39 0.0 fluid pack lines 04/23/2012 10:31:43 04/23/2012 10:32:13 ---- 1 0.0 8.39 0.0 0.0 8.38 0.0 1 I -{ --------- -- a - - -- -- - -------------- ---- 04/23/2012 10:32:43 69 1.4 8.38 0.2 04/23/2012 10:33:13 83 1.5 8.38 0.9 04/23/2012 10:33:43 78 1.5 8.38 1.7 04/23/2012 10:34:13 83 1.5 8.38 2.4 04/23/2012 1 10:34:43 78 1.6 8.38 3.2 04/23/2012 10:35:13 -------37 0.0 8.39 3.3 - - -- - 04/23/2012 10:35:43 33 0.0 8.38 3.3 04/23/2012 10:36:13 33 ( 0.0 8.39 3.3 04/23/2012 10:36:43_-- 33 0.0 8.38 3.3 - -- _- - ----- --04/23/2012 10:37:13 33 ! 0.0 8.39 3.3 04/23/2012 10:37:43 33 , 0.0 8.39 3.3 I-------._..__.- ------ -----._.__..---- --- 04/23/2012 10:38:13 1379 I 0.0 8.39 3.3 04/23/2012 10:38:16 1383f[ 0.0 8.39 3.3 Pressure Test Lines 04/23/2012 10:38:43 1346 I 0.0 8.38 3.3 04/23/2012 10:39:13 1324 0.0 8.38 3.3 r --1--- --r- -- - - 04/23/2012 ! 10:39:43 2843 j 0.2 8.39 3.3 04/23/2012 10:40:13 2880 I 0.0 8.38 3.3 I I 04/23/2012 10:40:43 2720 f 0.0 8.38 3.3 - _ .-- - 04/23/2012 I 10:41:13 3109 0.0 8.39 3.3 - - --- ---------04/23/2012 1 10:41:43 3081 0.0 8.39 3.3 H 04/23/2012 1 10:42:13 2656 I 0.0 8.38 3.3 04/23/2012 10:42:43 10 r 0.0 8.39 3.3 04/23/2012 j 10:43:12 33 0.0 8.39 3.3 pump water to displace mud Page 2 of 5 Dwell Field Job Start Customer Job Number 1 1 RED WOLF#2 i Badami Apr/23/2012 Savant 65892 I Date Time Treating Flow Density Volum* Message 24-hr Pressure Rate 1.11/6 BBL dock PSI BIN 04/23/2012 10:43:21 33 0.0 8.39 3.3 Reset Total,Vol=3.32 bbl 04/23/2012 10:43:43 74 1.4 8.39 3.5 04/23/2012 10:44:13 527 5.6 8.38 5.4 04/23/2012 10:44:43 655 6.4 8.38 8.5 04/23/2012 r 10:45:13 820 7.2 8.38 12.0 04/23/2012 10:45:43 811 7.3 8.38 15.7 04/23/2012 10:46:13 825 7.2 8.38 19.3 04/23/2012 10:46:43 806 7.3 8.38 22.9 04/23/2012 10:47:13 825 7.3 8.38 26.6 04/23/2012 10:47:43 568 6.2 8.38 30.2 04/23/2012 10:48:13 14 0.0 8.39 30.4 04/23/2012 10:48:22 14 0.0 8.39 30.4 batch up cement 04/23/2012 i 10:48:43 14 0.0 8.39 30.4 4-- --! 04/23/2012 i 10:48:44 i 14 0.0 8.39 30.4 Reset Total,Vol=27.08 bbl 04/23/2012 10:49:13 14 0.0 8.39 30.4 04/23/2012 10:49:43 14 0.0 8.39 30.4 04/23/2012 10:50:13 14 0.0 8.39 30.4 04/23/2012 10:50:43 10 0.0 8.39 30.4 04/23/2012 10:51:13 Il. 1 0.0 8.39 30.4 04/23/2012 10:51:43 14 0.0 8.39 30.4 04/23/2012 10:52:13 14 0.0 8.27 30.4 04/23/2012 10:52:43 14 0.0 8.12 30.4 04/23/2012 10:53:13 14 0.0 8.02 30.4 04/23/2012 i 10:53:43 14 0.0 9.10 30.4 I 04/23/2012 1 10:54:13 -i14 0.0 10.61 30.4 04/23/2012 ! 10:54:43 1 14 0.0 12.06 30.4 ! A_ 04/23/2012 10:55:13 14 0.0 13.26 30.4 1--- 04/23/2012 10:55:43 14 0.0 14.21 30.4 04/23/2012 10:56:13 14 0.0 15.06 30.4 04/23/2012 10:56:43 14 0.0 15.53 30.4 04/23/2012 10:57:13 10 0.0 15.58 30.4 04/23/2012 10:57:43 10 0.0 15.59 30.4 I 1 04/23/2012 i 10:58:13 , 106 2.2 _L 15.57 30.6 I I 04/23/2012 10:58:43 220 2.2 15.32 31.7 H 04/23/2012 10:59:13 266 2.2 15.64 32.8 04/23/2012 10:59:43 252 2.2 15.37 33.9 04/23/2012 11:00:13 417 2.9 15.69 35.3 04/23/2012 11:00:43 532 3.4 15.75 37.0 04/23/2012 11:01:13 541 3.4 15.75 38.7 04/23/2012 11:01:43 468 3.1 15.84 40.3 _i_ 04/23/2012 11:02:13 1 481 3.1 15.85 41.8 04/23/2012 11:02:43 490 3.1 15.84 43.3 04/23/2012 11:03:13 1 28 0.0 15.84 43.6 I 04/23/2012 11:03:40 i 24 0.0 15.84 43.6 Reset Total,Vol=13.21 bbl 04/23/2012 11:03:43 24 0.0 15.85 43.6 04/23/2012 11:03:54 133 1.4 14.56 43.8 wash lines 04/23/2012 11:04:13 381 3.0 9.50 44.6 04/23/2012 11:04:43 463 4.9 8.50 46.9 04/23/2012 11:05:13 19 0.0 8.44 47.8 04/23/2012 11:05:25 14 0.0 8.45 47.8 Reset Total,Vol=4.22 bbl 04/23/2012 11:05:43 60 1.6 8.63 48.0 04/23/2012 ' 11:05:48 65 1.6 8.63 48.1 displace drill pipe 04/23/2012 11:06:13 10 0.0 8.47 48.2 04/23/2012 11:06:43 14 0.0 8.47 48.2 Page 3 oft Well Field Job Start Customer Job Number RED WOLF#2 Badami Apr/23/2012 Savant 65892 Date Time Treating Flow Docility - Volume Message 24-br. Pressure Rate LB/6 BBL dock':. PSI B/N.' 04/23/2012 11:07:13 10 0.0 8.47 48.2 04/23/2012 11:07:43 10 0.0 8.45 48.2 ' 04/23/2012 11:08:13 10 0.0 8.45 48.2 H 04/23/2012 11:08:43 10 0.0 8.44 48.2 04/23/2012 11:09:13 10 0.0 8.45 48.2 04/23/2012 11:09:43 10 0.0 8.44 48.2 04/23/2012 11:10:13 10 0.0 8.50 48.2 04/23/2012 -_11:10:43 i 10 0.0 8.50 48.2 04/23/2012 I 11:11:13 10 0.0 8.44 48.2 04/23/2012 11:11:43 14 0.0 7.85 48.2 04/23/2012 11:12:13 14 0.0 8.02 48.2 ----- __- - _ - -- -- 04/23/2012 11:12:43 10 0.0 8.34 48.2 04/23/2012 11:13:13 10 0.0 8.38 48.2 04/23/2012 11:13:43 10 0.0 8.38 48.2 04/23/2012 11:14:13 10 0.0 8.38 48.2 04/23/2012 11:14:43 10 0.0 8.38 48.2 04/23/2012 11:15:13 10 0.0 8.37 48.2 04/23/2012 11:15:43 10 0.0 8.35 48.2 04/23/2012 11:16:13 10 0.0 8.35 48.2 04/23/2012 11:16:43 10 0.0 8.35 48.2 04/23/2012 11:17:13 10 0.0 8.34 48.2 04/23/2012 11:17:43 5 0.0 8.32 48.2 --_-__-_1 04/23/2012 11:18:13 5 0.0 8.33 48.2 04/23/2012 11:18:43 5 0.0 8.35 48.2 -I' 04/23/2012 11:19:13 5 0.0 8.35 48.2 04/23/2012 11:19:43 14 0.0 8.35 48.2 04/23/2012 11:20:13 5 0.0 8.47 48.2 04/23/2012 11:20:43 10 0.0 8.42 48.2 04/23/2012 11:21:13 5 0.0 _--- 8.44 48.2 --- 1 04/23/2012 11:21:28 5 0.0 8.44 --_--48.2 pump water to clean hole 04/23/2012 11:21:33 5 0.0 8.43 48.2 Reset Total,Vol=0.39 bbl 04/23/2012 11:21:43 14 0.0 8.44 48.2 04/23/2012 11:22:13 170 2.9 8.44 48.7 04/23/2012 11:22:43 I 861 7.5 8.39 51.5 04/23/2012 11:23:13 1031 8.3 8.39 55.3 04/23/2012 11:23:43 1053 8.6 8.38 59.6 1 04/23/2012 11:24:13 1067 8.5 8.39 63.8 I ! 04/23/2012 11:24:43 I 1053 8.6 8.39 68.1 - - 04/23/2012 11:25:13 I - 1058 8.6 8.39 1 72.4 ---t- ----- - -- ------ --._- 04/23/2012 11:25:43 I 1058 8.6 8.39 76.7 04/23/2012 11:26:13 { 10 1 0.0 8.40 78.8 04/23/2012 11:26:43 ! 10 0.0 8.39 78.8 ! ------ ---------..-------t 78.8 04/23/2012 11:27:43 5 -_-- 0.0 8.33 _---- --- ---� 04/23/2012 11:27:13 10 8.39 78.8 04/23/2012 11:28:13 ! 5 0.0 10.47 78.8 04/23/2012 11:28:43 5 0.0 13.63 78.8 04/23/2012 11:29:13 5 ! 0.0 15.3378.8 04/23/2012 11:29:43 5 -i 0.0 15.32 78.8 04/23/2012 11:30:13 5 -i-- - - 0.0 15.33 - - 78.8 -- -_ _ -- - ----_ 04/23/2012 11:30:43 5 0.0 15.28 78.8 04/23/2012 11:31:13 5 0.0 15.26 78.8 04/23/2012 11:31:43 60 0.0 15.26 78.8 04/23/2012 11:32:13 60 0.0 15.26 78.8 04/23/2012 11:32:43 74 0.0 1 15.26 78.8 Page 4 of 5 Well Field Job Start Customer Job Number RED WOLF#2 Badami 1 Apr/23/2012 Savant 65892 Doe Time ':.Treating Flow Density Volume — Message 24-hr Pressure Rate LB/B BBL clock PSI B/M 04/23/2012 11:33:43. ! 5 0.0 8.96 78.8 04/23/2012 11:34:13 5 0.0 8.51 78.8 04/23/2012 11:34:43 1 0.0 9.60 78.8 04/23/2012 11:35:13 1 0.0 9.65 78.8 Post Job Summary Average Pump Rates,bbl/min Volume of Fluid Infected,bbl Slurry N2 Mud Maximum Rate Total Slurry I Mud Spacer I N2 4.5 8.6 78.8 0.0 0.0 Treating Pressure Summary,Psi Breakdown Fluid ----- Maximum Final Average Bump Plug to Breakdown Type ! Volume I Density - 3173 0 228 1 bbl lb/gal Avg.N2 Percent Designed Slurry Volume Displacement Mix Water Temp I Cement Circulated to Surface? ❑I Volume bbl 0.0 bbl 0.0 bbl degF Washed Thru Perfs ❑ To ft Customer or Authorized Representative Schlumberger Supervisor Circulation Lost E Job Completed D Gary Hammon Jeff Long _ - Page 5 of 5 > LIBURTON Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Cover Letter Savant Alaska Redwolf #2 Drilling Fluid Recap To: Mr. Erik Opstad Savant General Manager Written by: Chris MacKinnon Tech. Professional Halliburton/Baroid Alaska 6900 Arctic Blvd Anchorage, AK. 99518 907-275-2617 Created: 05-01-2012 United States of America Badami Anchorage North Slope - Page 1 of 21 - 1 [ HALLIBURTON 1 Barr ` Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Personnel Register Local Account Rep: Chris MacKinnon(907)275-2617 Senior Engineer: Name From To Days Josh Hayes Apr.03,2012 Apr. 17,2012 13 Tom Burgin Apr. 17,2012 Apr.23,2012 08 Second Engineer: Name From To Days Ryan Noonan Apr.03,2012 Apr.09,2012 08 Steven Carter Apr. 10,2012 Apr.23,2012 13 Third Engineer: Name From To Days Kyle Lutz Apr 03,2012 Apr.09,2000 08 Rocky Garcia Apr. 10,2012 Apr.23,2012 13 III Created: 05-01-2012 United States of America Badami • Anchorage • North Slope - Page 2 of 21 - 1 1 J4! !. 1BURTON Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Conclusions And Recommendations Date: April 02,2012 thru April24,2012 Operator: Savant Alaska LLC Contractor: Nabors Alaska Well Name: Red Wolf 2 Field: Badami Rig Name: 7ES Net Well Cost: $263,068.02 USD Cost/Ft. = $ 14.44 Cost/bbl. = $25.27 SURFACE INTERVAL #1 SURFACE HOLE Grass Roots vertical well. Drilled 12.25" hole from 0' MD to 3872' MD. SPUD MUD Water .92 BBL Soda Ash .1 ppb AQUAGEL 30 ppb X-TEND II .125 ppb Caustic Soda .1 ppb DRIL-N-SLIDE .5% WELL DATA Hours Drilled -71.5 Avg. ROP-54.9 Cumulative Cost=$84,674.04 USD Created: 05-01-2012 United States of America • Badami Anchorage North Slope - Page 3 of 21 - HALLIBURTON 1 Baroid Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Conclusions And Recommendations Cost/Ft.=$ 14.84 Cost/bbl. =$ 12.40 INTERVAL DISCUSSION Received 9.0 ppg pre mixed Spud Mud from Baroid Mud Plant in Prudhoe Bay,AK. Additions of AQUAGEL, BARAZAN D PLUS, and EXTEND II required to raise fluid viscosity to 300+. Additions of Soda Ash as calcium buffer in preparation for drilling out conductor shoe. Additions of CON DET and DRIL N SLIDE to prevent shaker blinding. Drilled out conductor and rat hole to 497' MD in order to pick up smart tools BHA. Tested BHA and RIH. Drilled Ahead from 497' MD to 1402' MD. Freshwater additions of 20-30 bbl/hr for dilution, weight maintenance,solids control,and volume maintenance. Bit Trip @ 1402'MD Screened down to 84's on Shaker 2&Shaker 3 and on the back two screens of Shaker 1 and Shaker 4. Cuttings appeared to consist mainly of gravels in the .25"to 3" range. Occasionally encountered wood debris from downhole. Occasional clay stringers resulted in intermittent high rheological properties and required increased dilution rate. Increased Pump Rates increased ROP when required. Maintenance of 300+viscosity throughout the interval proved extremely effective at hole cleaning. Replaced Bit, RIH,drilled ahead to 2585' MD, 2585' MD POOH due to MWD Tool Failure. Tight spot experienced at 1720' MD. Washed and Reamed 1720' MD to 1770' MD. POOH, Replace MWD Tool, RIH Tagged bottom with 20'of fill (most assuredly due to the washing/reaming from 1720' MD to 1770' MD) Washed to bottom, Drilled Ahead to 3665' MD Gas Encountered at 3665' MD @ 10,000 Units. Gas dissipated Drilled Ahead to TD @ 3872' MD Circulated and Conditioned mud dropping vis to 240 in anticipation of upcoming 9 5/8"Casing Run 9 5/8" Casing Ran to bottom with no issues Cemented 9 5/8"casing with 522 bbls cement—saw no cement @ surface Returns minimal for approximately 30 mins during cement job Created:05-01-2012 United States of America • Badami • Anchorage • North Slope - Page 4 of 21 - HALLIBURTON 1 Ber•o'd Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Conclusions And Recommendations Top Job Cement Job via port collar at 507' MD. 150 bbl cement pumped, cement at surface. Maintaining proper flow rates and recommended drilling practices were the key to success on this surface hole interval. Flow rates were maintained at manageable parameters and ROP was held to less than 120 ft/hr. These practices, in addition to proper drilling fluid maintenance, resulted in a uniform wellbore,slick wall cake,and clean wellbore. INTERVAL ISSUES Screen Blinding,excessive overrun of shakers due to 300+viscosity parameters. -Additions of Water -Additions of DRIL N SLIDE,CON DET -Constant maintenance of shaker screens Occasional sloughing in permafrost areas. -Maintain 300+viscosity throughout entire surface interval -Limit time spent circulating, logging/surveying in open surface hole Excessive large gravel returns from 0—1800' MD. -Maintain 300+Vis coming out of hole in order to insure clean well bore Gravel Stringers of considerable size encountered at depths exceeding 3000' MD -Maintain 300+Vis coming out of hole through entire interval resulted in clean wellbore INTERMEDIATE INTERVAL #2 DISCUSSION 8%"Hole drilled from 3,872'to 11,859' After laying down the 5" drill pipe the rig picked up 4"drill pipe and BHA to drill out of the 9 5/8" casing. Created:05-01-2012 United States of America Badami • Anchorage • North Slope - Page 5 of 21 - HALLIBURTON I Baroid Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Conclusions And Recommendations Cement was cleaned out to within 10'of the shoe where the well was displaced with a new LSND system from the Baroid mud plant. 200'of rat hole was drilled and a formation integrity test was performed. After cleaning out and performing the FIT,the rig tripped out of the hole to pick up the drilling assembly with smart iron. Drilling commenced with penetration rates in the 120-180 ft/hr range. Fluid density at this point was 9.0 ppg. Drill N Slide was utilized to aid in addressing screen blinding.Additions of ConDet concentrated drilling detergent were initiated to prevent bit and stabilizer balling as heavy formation clays were present. Penetration rates were very good with 2,062' being drilled in one 24 hour period.At a depth of approximately 6,800'a gas bubble was circulated up with traces of crude oil present.The rig did not have to weight up for this event but did eventually increase density to 9.4 ppg at 7,800' To supplement hole cleaning capabilities of the fluid system weighted high viscosity sweeps were pumped every 500'with reported increased cuttings load of approximately 20%.At approximately 9,300' it was reported that connection gas was seen with slight traces of crude in the pits. At 9,375' a rig pump broke a cylinder which caused a temporary shut down of drilling.After repair the hole was circulated clean and the rig performed a BOPE test.After the test drilling resumed and continued to a depth of 9,431'where the rig pump experienced another failure,this time in a discharge screen pod.The rig tripped to the casing shoe to slip and cut drilling line while waiting on repairs. Once repairs were completed the rig ran back to bottom and drilling resumed with high viscosity sweeps being pumped at 500' intervals. The Killian marker was encountered at a depth of 11,600' but the formation was not fully developed. No significant gas was encountered and no loss of fluid was experienced. Drilling resumed after checking hole for losses/flow and continued into the Kekiktuk target formation. Log data indicated that the formation was wet so the decision was made to plug and abandon the well. INTERMEDIATE SECTION LSND 9.0 ppg Water = .96 bbl BARAZAN D PLUS= 1.5 ppb PACL =2ppb DEXTRID LT =2ppb Caustic =.1ppb(9-10 pH) BAROID 41 =28 ppb(9.0ppg-12.3ppg) ALDACIDE G =.2ppb Created:05-01-2012 United States of America • Badami • Anchorage North Slope - Page 6 of 21 - HALLIBURTON I Baroid Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Conclusions And Recommendations DRIL-N-SLIDE =.5% WELL DATA Hours Drilled - 122 Avg. ROP-65.5 ft/hr Cumulative Cost=$ 178,393.98 USD Cost/Ft.=$ 14.25 Cost/bbl.=$45.89 Displaced hole with 9.0 ppg LSND, Drilled 200' Rat Hole, POOH to L/D BHA, P/U BHA with smart tools, RIH Drilled ahead 3872' MD to 9065' MD Maintained Mud Properties per Mud Program Targets Vis=45-65 WT=9.0-9.8 YP= 15-25 Water loss<10 pH =9-10 Weighted up per Co. Man request at various depths coinciding with offset wells in area. High Level of gravel experienced in a couple stringers but majority of formation/cuttings are clay Pumping HI VIS Sweeps (165-200 Vis)and HI VIS Weighted Sweeps(+2ppg) as directed by Co. Man Short Trip to Shoe @ 6000' MD Tight Spot from 4750' MD to Shoe(3851' MD). Washed and Reamed on trip in hole. RIH,Tagged Bottom with no issues. INTERVAL ISSUES Torque issues in DS -Additions of DRIL N SLIDE,Condet seemed to alleviate when mixed in pill type (fast mixing)concentrations. Balling on Tool Joints -Additions of Condet Created: 05-01-2012 United States of America • Badami • Anchorage • North Slope - Page 7 of 21 - HALLIBURTON I Baroid Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Conclusions And Recommendations -Increased RPM of DP **Seems that the major cause of the Torque in the DS was a stabilizer above the drilling BHA. The stabilizer is 1/8" under gauge and seems to be hanging up or balling up from the clay formations. Recommend smaller stabilizer and regular additions of lubes, surfactants, HI VIS Sweeps, HI VIS/Walnut Sweeps. Created:05-01-2012 United States of America • Badami • Anchorage • North Slope - Page 8 of 21 - _IBURTON I ear' Red Wolf#2• SAVANT ALASKA LLC-EBUS•NABORS ALASKA• NAD 7ES•WSE API(Copy) Drilling Fluids-Fluid Property Recap:Water-Based Fluid Interval# 01 Top of Interval(MD/TVD) 0/0 ft From Date 04-03-2012 Bottom of Interval(MD/TVD) 3,872/3,872 ft To Date 04-11-2012 Avg Hole Size I Bit Size 15.117/12.250 in Report MD/TVD FL Density Funn Rheology 57°F Filtration Filtrate Analysis MBT Sand Retort Analysis Rheometer Dial Readings No Temp Visc PVIbk^n/1001!2 API HTHP Cake Cake Temp pH Pm Pt Mt Cl Total %by 001 600 300 200 100 6 3 API HTHP Hardness C ppg sacra cp YP 105 10M 30M mV30min mL/30min 32nd in °F mL mL mL mg,., mgrs ppb eq. %by SoYd LOS base Water 001 200/200 57 9.00 350 24 58 74 133 165 12.0 2 9.9 0.35 0.14 0.43 1,300 80 32.5 47 45 95.0 106.0 82 0 73 0 69 0 59 0 59.0 002 560/560 58 9.10 300 28 45 49 84 104 12.0 2 10.2 0.14 0.12 0.55 900 0 30.0 47 3.7 960 101.0 73.0 63.0 51.0 39.0 38.0 002 686/686 59 9.00 442 45 80 89 98 10.0 9.3 0.12 0.10 0.50 750 30.0 4 7 4.5 95.0 170.0 125.0 117.0 101.0 76.0 71.0 002 1,993/1,993 53 9.30 456 63 75 66 129 165 8.0 2 8.9 0.05 0.02 0.26 500 37.5 68 61 1.0 92.0 201.0 138.0 114.0 81.0 39.0 38.0 003 1.360/1,360 53 9.30 375 56 58 52 74 8.0 2 8.6 0.02 0.02 0.06 500 0 35.0 68 6.1 1.0 92.0 1740 114.0 94.0 67.0 32.0 31.0 003 1400/1400 9.25 352 57 64 64 82 12.0 2 89 0.03 0.03 0.05 400 35.0 6.8 6.6 0.5 925 1786 1216 96.0 70.0 350 320 003 1.711/1,711 48 930 315 43 56 62 106 127 8.0 2 9 0.02 0.02 005 400 0 35.0 6.8 6.2 0.5 92.5142.0 99.0 87.0 67.0 42.0 40.0 004 1.995/1,995 48 940 325 38 53 43 85 99 10.4 _ 9 0.02 0.05 0.30 400 0 35.0 7.3 6.4 0.5 92.0129.0 91.0 77.0 59.0 32.0 31.0 004 2,583/2,583 52 9 35 317 40 58 49 88 117 11.0 • 9 0 03 0 05 0.25 400 0 34.0 7.3 6.8 0.5 92.0 138 0 98.0 79.0 64.0 34 0 29 0 004 2,5852,585 54 9.20 301 42 52 41 103 126 10.4 2 8.6 0.02 0.02 0.34 500 40 37.5 250 6.3 59 0.5 93.01380 940 780 57.0 32.0 30.0 005 2,6712,671 48 9.30 354 34 66 63 108 129 10.4 _ 10 0 02 0.12 0.35 800 70 35.0 2.50 82 5.2 0.5 936 134.0 100.0 86.0 70.0 58.0 56.0 005 3,230/3,230 50 9.25 363 42 89 88 104 11.0 3 9.1 0.03 0.10 040 750 80 30.0 250 6.8 65 1.0 92.0 17a0 131.0 108.0 98.0 68.0 64.0 005 2,8022.802 53 9.35 306 37 48 49 97 120 8.6 2 9.1 0.02 0.08 0.31 1,400 80 35.0 2.50 7.2 6.8 0.5 926 1220 85.0 72.0 56.0 36.0 34.0 006 3,872/3,872 48 9.30 246 36 46 44 87 110 9.0 2 8.8 0.03 0.05 0.45 1,200 40 27.0 2.50 72 7.2 0.5 926 1180 82.0 74.0 586 28.0 26.0 006 3,872/3,872 48 9.30 205 36 33 15 45 67 8.0 2 9 0.02 0.08 0.45 1,200 40 30.0 2.50 7.2 7.2 0.5 92.0 105.0 69.0 54.0 36.0 14.0 12.0 007 3,872/3,872 48 9.10 80 22 23 26 47 54 10.0 2 9 0.02 0.08 0.45 1,200 40 27.5 5/ 5.7 0.5 93.5 67.0 45.0 40.0 36.0 12.0 10.0 008 0/0 62 9.00 70 22 26 8 12 15 7.2 9 0.10 0.10 0.26 1,000 120 3.7 2.4 0.5 965 706 48.0 39.0 27.0 8.0 6.0 009 3,872/3,872 9.00 70 23 27 9 13 15 7.0 _ 9 0.08 0.10 0.25 900 120 3.2 1.4 0.5 96.0 73.0 50.0 41.0 26.0 8.0 6.0 Created:05-01-2012 4:39:33PM United States of America Badami Anchorage North Slope -Page 9 of 21- Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Drilling Fluids-Fluid Property Recap:Water-Based Fluid-Additional Properties Intervalf7 01 Top of Interval(MD/TVD) 0/0 ft From Date 04-03-2012 Bottom of Interval(MD/TVD) 3,872/3,872 ft To Date 04-11-2012 Avg Hole Size/Bit Size 15.117/12.250 in Report Tart No lbs/10002 001 002 002 76 61 002 27 86 003 25 17 097 29 82 O73 3961 004 26 57 004 28 58 004 28 37 005 58 17 005 66.57 005 34 25 006 22.91 006 1017 007 7 57 008 306 009 3 07 Created,05-01-2012 4.39,33PM United States of America Badami Anchorage North Slope -Page 10 of 21- HALLIE TONT i ''" Red Wolf#2• SAVANT ALASKA LLC-EBUS• NABORS ALASKA • NAD 7ES • WSE API(Copy) Drilling Fluids-Fluid Property Recap:Water-Based Fluid Interval# 02 Top of Interval(MD/TVD) 3,872/3,872 ft From Date 04.12-2012 Bottom of Interval(MD/ND) 11,859/11,859 ft To Date 04-23-2012 Avg Hole Size/Bit Size 9.70018.500 in Rep, MD/TVD FL Density Flinn Rheology °F Filtration Filtrate Analysis MBT Sand Retort Analysis Rheometer Dial Readings Temp Viso PVIbis°n/100(12 API HTHP Cake Cake Temp pH Pm Pf Mf Cl Total %by Vol 600 300 200 100 6 3 API HTHP Hardness _ n °F ppg sec/qt cp yP 10S 10M 30M mV3Omin mlJ30min 0 r0 in °F mL mL mL mg0 mg/I ppb eq. %oy Solid LOS 6 se Wate 010 3872/3,872 52 9.00 70 24 27 10 13 16 74 9 0.06 0.15 0.24 1,000 80 60 3.2 1.4 05 96.0 75.0 51.0 42.0 25.0 8.0 6.0 010 3,887/3,887 52 9.00 75 27 33 10 14 15 74 _ 10.5 0.81 0.08 027 1,000 20 6.0 3.7 2.5 96.0 87.0 60.0 48.0 34.0 10.0 8.0 011 3.887/3,887 56 9.00 63 26 32 10 13 16 7.3 - 10.5 0.65 0.10 0.30 900 80 5.0 3.2 1.4 0.5 96.0 84.0 58.0 47.0 34.0 9.0 8.0 011 4,688/4,688 58 900 60 21 28 9 12 13 64 2 10.7 0.25 0.11 0.46 1,000 40 7.5 4.2 3.4 0.5 95.0 70.0 49.0 39.0 28.0 8.0 6.0 012 6,003/6.003 72 9.15 64 23 30 10 15 17 6.4 1 9.2 0.15 0.05 0.20 150 80 7.5 5.3 4.2 1.0 93.5 76.0 53.0 43.0 31.0 10.0 8.0 012 6,003/6.003 64 9.30 77 24 33 11 15 17 6.0 2 9.3 0.18 0.08 0.32 1,500 80 10.0 62 5.2 0.5 93.0 81.0 57.0 46.0 33.0 10.0 8.0 013 7,268/7,268 85 9.25 70 24 25 8 11 14 6.8 2 9.25 0.20 0.05 0.45 1.500 60 12.5 ,- 4.6 0.5 93.5 73.0 49.0 37.0 260 9.0 7.0 013 8,065/8,065 96 940 63 26 26 6 11 12 56 2 9.7 028 0.18 0.61 1,500 80 15.0 9 4.4 0.5 93.0 780 520 41.0 28.0 8.0 6.0 014 9,065/9,065 98 9.40 61 24 25 8 10 13 60 2 9.4 0.25 0.05 045 1,250 80 15.0 62 44 0.5 93.0 73.0 49.0 39.0 27.0 9.0 7.0 014 9,374/9,374 104 9.50 62 25 24 7 9 11 5.2 2 9.6 0.21 0.18 0.62 1,100 80 225 0.50 8.2 7.7 0.5 91.0 74.0 49.0 39.0 27.0 8.0 6.0 015 9.378/9.378 9.50 74 24 24 6 10 12 5.6 _ 9 0.20 0.15 0.35 1,500 80 12.5 0.20 5.7 2.5 2.0 92.0 72.0 480 38.0 26.0 7.0 5.0 015 4 9.378/9,378 9.50 76 25 23 7 10 11 5.6 7.8 2 2 200 9.1 0.24 0.12 0.59 1,100 80 125 0.10 5.7 2.6 1.0 930 73.0 48.0 39.0 26.0 8.0 6.0 016 9,378/9,378 75 9.55 77 22 25 7 12 14 5.0 10.8 2 3 200 8 0.04 002 0.45 1,200 80 125 0.20 6.7 4.3 1.0 92.0 69.0 47.0 36.0 25.0 8.0 6.0 "'7 9,431/9,431 75 955 69 23 25 6 11 13 62 98 2 3 200 9.6 0.27 0.05 0.58 1,100 80 12.5 0.20 5.7 2.3 1.0 93.0 71.0 48.0 38.0 27.0 8.0 6.0 017 10,257/10,257 99 9.50 58 18 18 6 11 14 5.8 12.2 2 3 200 9.3 0.25 0.15 0.60 1,200 60 11.3 0.20 7.2 5.6 1.5 91.0 54.0 36.0 29.0 21.0 7.0 5.0 017 10,762/10,759 104 9.50 62 19 25 7 11 13 54 13.1 2 2 200 9.1 0.15 0.09 0.58 1,200 40 125 0.20 7.7 6.7 1.0 91.0 63.0 44.0 36.0 26.0 8.0 7.0 018 11,563/11,563 117 9.60 58 19 24 8 13 16 5.2 9.8 2 3 200 9.5 0.40 0.20 0.65 1,200 40 12.5 0.20 8.7 7.9 1.0 90.0 62.0 43.0 36.0 27.0 9.0 8.0 018 11,731/11,731 108 9.60 62 20 25 8 11 13 56 9.9 2 3 200 94 0.28 0.11 0.68 900 80 12.5 0.30 8.8 7.9 1.0 90.0 65.0 45.0 37.0 27.0 10.0 8.0 019 11,859/11,859 117 9.60 60 20 23 8 12 16 5.4 104 2 3 200 94 0.45 0.20 0.70 1,100 60 12.5 0.15 8.7 7.9 1.0 900 63.0 43.0 36.0 270 90 80 019 11,859/11,859 90 9.55 64 0 0 0.0 0.0 020 11,859/11,859 108 9.50 62 0 0 0.0 0.0 020 11,859/11,859 108 9.50 62 0 0 0.0 0.0 • Created:05-01-2012 4:39:33PM United States of America Badami Anchorage North Slope -Page 11of21- N" ISURTON Red Wolf#2 • SAVANT ALASKA LLC-EBUS•NABORS ALASKA • NAD 7ES • WSE API(Copy) Drilling Fluids-Fluid Property Recap:Water-Based Fluid-Additional Properties Interval# 02 Top of Interval(MD/TVD) 3,872/3,872 ft From Date 04-12-2012 Bottom of Interval(MD/TVD) 11,859 111,859 ft To Date 04-23-2012 Avg Hole Size/Bit Size 9.700/8.500 in lbs/10002 329 409 271 011 2.47 012 455 012 367 013 558 013 362 014 5 10 014 3.98 015 266 015 4.13 016 4 08 016 364 017 385 017 3.39 018 469 018 587 019 512 019 000 020 0 00 020 Created:05-01-2012 4:39:33PM United States of America Badami Anchorage North Slope -Page 12 of 21- HALLIBURTON I Baroid Red Wolf#2•SAVANT ALASKA LLC-EBUS•NABORS ALASKA • NAD 7ES • WSE API(Copy) Drilling Fluids-Fluid Volume Record Report Additions Losses Volumes Report No Date • Inoial Heterved Mood Base Water Berle Chemicals Other Daly Total SCE Downhole Misr m,,,,. Returned Daly Total Hole Volume Active PC Reserve Final Volume' Volume Volume Volume bb: bbl bbl bbl bbl bbl bbl bbi bbl bit ON lad bit bbl bbl bbl bbl bbi bbl Interval# 01 Fluid Name: Spud Mud 001 04-03-2012 • 189.3 404 5600 789.7 1320 -:0 88.7 5690 657.7 002 04-04-2012 • 657.7 1,032.9 57.9 1,090.8 805.0 805.0 268.6 675.0 943.6 003 04-05-2012 • 943.6 660.8 228 683.6 576.0 576.0 386.2 665.0 1,0512 004 04-06-2012 • 1,051.2 606.1 1''4 622.5 5280 528.0 544.9 601.0 1,145.9 005 04-07-2012 • 1,145.9 1,149.0 420 1,191.0 912.0 9120 811.0 614.0 1,4260 006 04-08-2012 1,425.0 240.9 9.6 250.5 960 960 8206 759.0 1,579.5 007 04-09-2012 • 1,579.5 0.9 5.3 62 42C 1,181.9 286.8 117.0 403.8 008 04-10-2012 • 403.8 67.0 286.8 50.0 336.8 009 04-11-2012 • 336.8 ,• 8 50.0 336.8 Cumulative Volume 3,879.9 194.5 560.0 4,634.4 3,049.0 42.0 1,206.9 Fluid Name: LSND - 008 04-10-2012 190 0 190 0 1900 1900 009 04-11-2012 190.0 190.0 190.0 Cumulative Volume 190 0 i..c.' Indicates this is the primary active fluid set Created:05-01-2012 4:39:42PM United States of America Badami Anchorage North Slope -Page 13 of 21- HALLIBURTON 1 Baroid Red Wolf*2•SAVANT ALASKA LLC-EBBS•NABORS ALASKA•NAD 7ES•WSE API(Copy) Drilling Fluids-Fluid Volume Record Report Additions Losses Volumes Report No Date a Initial Received Mixed Base Water Dante Chemicals Other Oaty Total SCE Downhole M. Mwed Returned Daily Total Hole Volume Active Pit Reserve Final Volume Volume Volume Volume bbl bbl bbl bbl 801 bbl bbl bbl bbl bbl bbl bbl bbl bbl bbl bbl bbl bbl bbl Interval# 02 Fluid Name: Spud Mud 0101 04-12-2012 1 3368 01 0.3 0.4 337.2 337 2 Cumulative Volume 0.1 0.3 0.4 337.2 337.2 Fluid Name: LSND - 010 04-12-2012 • 190 0 580.0 0.9 580.9 2 9 2.9 243.0 235.0 290 0 768.0 011 04-13-2012 • 768.0 116.3 16.4 132.7 58.0 12.9 70.9 304.8 235.0 2900 829.8 012 04-14-2012 • 829.8 125 7 11.5 137.2 33.6 3.7 37.3 426 3 503.5 929.8 • 013 04-15-2012 • 929.8 314.0 4.2 7.0 325.2 720 10.6 82.6 577.9 594.6 1,172.5 014 04-16-2012 • 1,1725 1775 63 88 1925 96.0 10.1 106.1 683.7 575.2 1,258.9 015 04-17-2012 ' 1,258.9 89.5 3.1 0.5• 93.1 40.0 13.0 53.0 787.1 511.9 1,299.0 016 04-18-2012 1,299.0 20 0 0.7• 20.7 63.4 10.0 10 0 83.4 685.6 550.7 1.236 3 017 04-19-2012 1,236.3 200.0 8.7 208.7 66.0 6.0 72.0 793.3 579.7 1,373.0 018 04-20-2012 1.373.0 160.2 32.3 192.5 93.0 9.2 12 0 114.2 871.6 579.7 1.451.3 019 04-21-2012 • 1.451.3 58.0 6.3 64.3 105.0 6.0 111.0 8820 522.7 1,404.7 , 020 04-22-2012 1,404.7 0.2 02 2842 284.2 882.0 238.7 1,120.7 021 04-23-2012 • 1,120.7 4.9 4 9 1.125.5 1,125.5 Cumulative Volume 580.0 1,261.2 13.7 97.0• 0.9 1,952.9 627.0 84.4 1,431.7 2,143.1 a Indicates this is the prinran'ac•tire fluid set Created:05-01-2012 4:39:42PM United States of America Badami Anchorage North Slope -Page 14 o • f 21- HALLIBURTON ! - aroic! Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Drilling Fluids - Interval Cost Breakdown Interval# 01 Top of Interval(MD/TVD) 0/0 ft From Date 04-03-2012 Bottom of Interval(MD/TVD) 3,872/3,872 ft To Date 04-11-2012 Avg Hole Size/Bit Size 15.117/12.250 in Material Unit Size Quantity Total Cost Fluids/Products:Drilling Cost AQUAGEL 50 Ibm BAG 3.073 37.183.30 BARATHIN-PLUS 25 Ibm BAG 32 1,954.56 BARAZAN D PLUS 25 Ibm BAG 9 1,639.26 BAROFIBRE 25 Ibm BAG 46 1,287.08 BICARBONATE OF SODA 50 Ibm BAG 10 289.20 CON DET 55 Gal DRUM 5 5,498.45 • DRIL-N-SLIDE 55 Gal DRUM 8 8,727.92 Mixing:Charge EA 600 3,450.00 SODA ASH 50 Ibm BAG 8 238.96 • X-TEND II 2 Ibm BAG 23 300.15 SubTotal $ 60,568.88 Unknown CLEAN AND CRUSH EA 13 227.50 Engineer DAY 18 21,600.00 Rig Mud Lab DAY 9 585.00 rig pickup truck DAY 9 1,350.00 • SubTotal $ 23,762.50 Interval Total Cost $ 84,331.38 Charged To Other Interval $ 0.00 Charged From Other Interval $ 342.66 Net Interval Cost $ 84,674.04 Planned Cost $ 85,160.00 Variance $ -485.96 Created:05-01-2012 4:39:56PM United States of America Badami Anchorage North Slope - Page 15 of 21 - HALLIBURTON I -'' Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Drilling Fluids -Interval Cost Breakdown Interval# 02 Top of Interval(MD/TVD) 3,872/3,872 ft From Date 04-12-2012 Bottom of Interval(MD/TVD) 11,859/11,859 ft To Date 04-23-2012 Avg Hole Size/Bit Size 9.700/8.500 in Material Unit Size Quantity Total Cost Fluids/Products:Drilling Cost ALDACIDE G 5 Gal CAN 25 1,206.25 BARACARB 25 50 Ibm BAG 94 2,146.02 BARACARB 50 50 Ibm BAG 62 1,424.14 BARAZAN D PLUS 25 Ibm BAG 222 40,435.08 BAROFIBRE 25 Ibm BAG 30 839 40 •BAROID 41 50 Ibm BAG 990 12.691.80 BARO-TROL PLUS 50 Ibm BAG 112 9,246 72 BDF-515 50 Ibm BAG 93 7,477.20 BICARBONATE OF SODA 50 Ibm BAG 4 115.68 CAUSTIC SODA 50 Ibm BAG 40 1,910.80 CITRIC ACID ANHYDROUS 50 Ibm BAG 26 2,969.72 CON DET 55 Gal DRUM 3 3,299.07 DEXTRID LT 50 Ibm BAG 156 10,033.92 DRIL-N-SLIDE 55 Gal DRUM 15 16,364.85 EZ GLIDE 55 Gal DRUM 2 2.602.74 Mixing:Charge EA 870 5,002.50 N-VIS 25 Ibm BAG 7 1,478.47 PAC-L 50 Ibm BAG 160 25,824.00 SODA ASH 50 Ibm BAG 4 119.48 WALL-NUT MEDIUM 50 Ibm BAG 15 389.85 XC-207 6 Ibm JUG 13 1,438 45 SubTotal $ 147,016.14 Fluid/Product:Lost Damage AQUAGEL 50 Ibm BAG 5 60 50 SubTotal $ 60.50 Unknown CLEAN AND CRUSH EA 16 280 00 Engineer DAY 24 28.800.00 Rig Mud Lab DAY 12 780.00 rig pickup truck DAY 12 1.800.00 SubTotal $ 31,660.00 Interval Total Cost $ 178,736.64 Charged To Other Interval $ -342.66 Charged From Other Interval $ 0.00 Net Interval Cost $ 178,393.98 Planned Cost $ 272,560.00 Variance $ -94,166.02 Created:05-01-2012 4:39:56PM United States of America Badami Anchorage North Slope - Page 16 of 21 - HALLIBURTON ! Baroid Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Drilling Fluids -Operations Log Recap Interval# 01 Top of Interval(MD/TVD) 0/0 ft From Date 04-03-2012 Bottom of Interval(MD/TVD) 3,872/3,872 ft To Date 04-11-2012 Avg Hole Size/Bit Size 15.117/12.250 in For Report #001 On 04-03-2012 Operation at Depth(MD/TVD) 405/405 ft Rig Activity Nippled up/down diverter system Picked up 44 stands 5"DP Picked up 15 joints 5"HWDP Tested Diverter,tested gas alarms,fuction knife valve Picked up BHA Filled and Circulated spud mud in conductor casing Drilled ahead 110'MD to 405'MD Activity Drilling Fluid Treatment Made additions of: Aquagel to maintain Viscosity 300+ X-Tend 2 to maintain Viscosity 300+ Soda Ash for calcium buffer Run Water at 20-30 bbl/hour to maintain volume For Report #002 On 04-04-2012 Operation at Depth(MD/TVD) 1,272/1,272 ft Rig Activity Continued drilling from 405'to 497'MD POOH to pick up Smart Tool BHA and tested Continued drilling from 497'to 1272'MD Activity Drilling Fluid Treatment Made additions of: Aquagel to maintain Viscosity 300+ X-Tend 2 to maintain Viscosity 300+ Soda Ash for calcium buffer Run Water at 20-30 bbl/hour to maintain volume Drill-N-Slide to prevent shaker blinding Condet to prevent shaker blinding For Report #003 On 04-05-2012 Operation at Depth(MD I TVD) 1,815/1,815 ft Rig Activity Drilled ahead with 12.25"bit from 1272'to 1402'MD then circulated and conditioned. Tripped out of hole and installed new 12.25"bit. Picked up BHA and Smart Tools and serviced top drive. Rig on standby waiting on supersuckers to clean out cuttings box and have the OK to bring waste to G&I. Tripped into hole and continued drilling from 1402'to 1815'MD Activity Drilling 'Fluid Treatment Made additions of: Aquagel to maintain Viscosity 300+ X-Tend 2 to maintain Viscosity 300+ Barazan D+to maintain Viscosity 300+ Soda Ash for calcium buffer Run Water at 20-30 bbl/hour to maintain volume Created:05-01-2012 4:40:00PM United States of America Badami Anchorage North Slope - Page 17 of 21 - HALLIBURTON ! Parc ir` Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Drilling Fluids -Operations Log Recap Interval# 01 Top of Interval(MD/TVD) 0/0 ft From Date 04-03-2012 Bottom of Interval(MD/TVD) 3,872/3,872 ft To Date 04-11-2012 Avg Hole Size/Bit Size 15.117/12.250 in For Report #004 On 04-06-2012 Operation at Depth(MD/TVD) 2,585/2,585 ft Rig Activity Continued drilling from 1815 to 2585'MD. Tripped out of hole because of MWD failure. At 1720'MD torque was 20k-25k over pull. Back reamed and washed down to 1770'MD. Tripped out of hole and removed and replaced MWD unit. Picked up BHA and tripped back in hole. Activity Drilling Fluid Treatment Made additions of: Aquagel to maintain Viscosity 300+ X-Tend 2 to maintain Viscosity 300+ Barazan D+to maintain Viscosity 300+ Soda Ash for calcium buffer Drill-N-Slide and ConDet Premix to prevent shaker blinding Run Water at 20-30 bbl/hour to maintain volume For Report #005 On 04-07-2012 Operation at Depth(MD/TVD) 3,849/3,849 ft Rig Activity Had 14 hours of trouble time due to MWD failure. Finished Tripping into hole from 2235'to 2585'MD @ 1:30 AM,20'of fill. Drilled ahead from 2585'to 3849'MD. Gas bubble at 3665'MD @ 10,000 units,then dissipated Activity Drilling Fluid Treatment Made additions of: Aquagel to maintain Viscosity 300+ X-Tend 2 to maintain Viscosity 300+ Barazan D+to maintain Viscosity 300+ Soda Ash for calcium buffer Drill-N-Slide and ConDet Premix to prevent shaker blinding Run Water at 20-30 bbl/hour to maintain volume For Report #006 On 04-08-2012 Operation at Depth(MD/TVD) 3,872/3,872 ft Rig Activity Circulated and conditioned mud. POOH 15 stands,then tripped back to bottom. No Fill. Circulated and conditioned mud. Circulated Carbide Bomb Tripped out of hole from 3872'to 735'MD,no tight spots. Layed down BHA. Rigged up/down to run casing. Ran 9-5/8"casing to 2324'MD Circulated 5 bbls every 5 stands. Activity Run casing and cement Fluid Treatment Made additions of: Aquagel to maintain Viscosity 300+ X-Tend 2 to maintain Viscosity 300+ Barazan D+to maintain Viscosity 300+ Barofibre to seal up permeable sand zones ConDet Premix to prevent shaker blinding Run Water at 20-30 bbl/hour to maintain volume Created:05-01-2012 4:40:OOPM United States of America Badami Anchorage North Slope - Page 18 of 21 - HALLIBURTON ! Baroid Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Drilling Fluids -Operations Log Recap Interval# 01 Top of Interval(MD/TVD) 0/0 ft From Date 04-03-2012 Bottom of Interval(MD/TVD) 3,872/3,872 ft To Date 04-11-2012 Avg Hole Size/Bit Size 15.117/12.250 in For Report #007 On 04-09-2012 Operation at Depth(MD/TVD) 3,872/3,872 ft Rig Activity Finished running 9-5/8"casing from 2324'to 3847'MD.Circulated and conditioned mud.Pumped 100bbls 10.1 ppg mud push and dropped bottom plug.Pumped 472bb1s 10.7 ppg cement lead,50bbls 15.8 ppg cement tail, 1 Obbls H2O,and dropped top plug.Had 42bbls of mud loss while pumping cement.Displaced/chased cement with 276bb1s of mud.Ran 5 stands and TAM combo tool into hole,open TAM Collar.Top nent job:pumped 45bbls of 9.3 ppg mud,trace of mud push, no -ment returns. Prep for top cement job Activity Cementing Fluid Treatment Made additions of Barathin to thin mud to—80 vis Desco to thin mud to—80 vis Pre-treated pit 4 with Sodium Bicarbonate for drilling out cement. Made cement contam.pill with 50bbl H2O and ten sacks of citric acid for cementers. For Report #008 On 04-10-2012 Operation at Depth(MD/TVD) 3,872/3,872 ft Rig Activity Pumped 150bbls Top Job, 'len:seen at surface, R/D lines.R/D Diverter, R/U&N/U BOP's,Clean Pits, Receive LSND mud. Brought necessary inventory over from badami landing to rigsite. Ran mudcheck on LSND fluid currently in Pit#4. Activity N/U B.O.P. Fluid Treatment Received LSND from mudplant,offloaded 190bbls into pit#4.390bbls remained staged on vac trucks. For Report #009 On 04-11-2012 Operation at Depth(MD/TVD) 3,872/3,872 ft Rig Activity RIH 5"DP, L/D 5"DP.P/U 4, P/U Dumb BHA, RIH w/4",Drill Out cement to within 10'of shoe,displace hole, POOH,L/D BHA, P/U smart tools BHA,RIH,Drill 200'rat hole,FIT, Activity Tripping Fluid Treatment Completed mud check on current LSND sitting in pit.Continue bringing over inventory from Badami landing to rigsite. Created:05-01-2012 4:40:00PM United States of America Badami Anchorage North Slope - Page 19 of 21 - HALLIBURTON ! Baroid Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Drilling Fluids -Operations Log Recap Interval# 02 Top of Interval(MD/TVD) 3,872/3,872 ft From Date 04-12-2012 Bottom of Interval(MD/TVD) 11,859/11,859 ft To Date 04-23-2012 Avg Hole Size/Bit Size 9.700/8.500 in For Report #010 On 04-12-2012 Operation at Depth(MD/TVD) 3,872/3,872 ft Rig Activity Pumped spacer and chased with LSND. Displaced spud mud with LSND.2 casing pressure tests (2500psi/15min). Fit test to 13.2ppg.Tagged at 3656 drilled to 3872 to open hole,currently at 3887 Cleaned pits and prepping pits for standby LSND on vac truck. • Activity Drilling Fluid Treatment Added 5 sxs of citric acid to thin down spud mud. Displaced new mud into pits. For Report #011 On 04-13-2012 Operation at Depth(MD/TVD) 4,688/4,688 ft Rig Activity Drilled thru with dumb , POOH,P/U new BHA, RIH with Smart Drilling Ahead 120-180 ROP/hr Activity Drilling Fluid Treatment 20bbl H20/hour,2sxs/hr Barazan D Plus,2sxs/hr PAC-L,2sxs/hr Dextrid,Slowly letting the weight climb up to 9.2ppg from 9.0.Added 4 drums of DRILL N SLIDE.Screened up 165 on shakers. For Report #012 On 04-14-2012 Operation at Depth(MD/TVD) 6,190/6,190 ft Rig Activity Drilled from 4688'to 6003'.pumped Hi-VIS(185)sweep,<10%cuttings change observed. Short tripped to shoe.wash and ream back down to 4688. Drilling ahead at 225SPM,73RPM, -150ROP. Activity Drilling Fluid Treatment Running 25bbls/hr H2O,2sxs/hr BARAZAN D PLUS,2sxs/hr DEXTRID,2sxs/hr PAC-L. BARAZAN D PLUS for viscosifier, PAC-L/Dextrid for filtration control Condet Premix to prevent shaker blinding,BARACARB 25/50 as Bridging agents.X-Cide207/Aldacide G as microbiocides. For Report #013 On 04-15-2012 Operation at Depth(MD/TVD) 8,065/8,065 ft Rig Activity Drilled 2062'in a 24 hour period.Pump pressure 3200-3500psi.Currently at 80ROP/hr.with 90RPM top drive. Took a gas bubble around 6500'w/traces of crude.Will weight up to 9.8ppg at 8600'. Activity Drilling Fluid Treatment Increase in solids,turned on mud cleaner and centrifuge to deposit. Drill N Slide and Condet to prevent shaker blinding,Aldacide G and X-cide as Microbiocides,25bb1/hr H2O from 00:00 to 14:00,turned down H2O to 20bbl/hr at 14:00.PAC-L and Dextrid for filtration control,Barazan D for viscosity.Weighted up from 9.3 to 9.4 at 7800'. For Report #014 On 04-16-2012 Operation at Depth(MD/TVD) 9,374/9,374 ft Rig Activity Drilled 1293'in a 24 hour period.Running Hi Vis(180 vis)sweeps every 500'MD.Seeing a little connection gas and some slight accumulation of crude in pits.Pump Pressure 2500-3000 psi(10.67 bbl/min),225 SPM,80 ROP/hr. Activity Drilling Fluid Treatment Hi Vis(180vis) Hi Weight(11.Oppg)sweep at 8725'and 9330'.Drill N Slide to prevent shaker blinding,Aldacide G/X Cide 207 to prevent microbiocides, Pac-L/Dextrid for filtration control.Sweeps will continue every 500' MD. No plan for increasing MW as of right now.2sx/hr Barazan D+,Pac L 3 sxs/hr,Dextrid 4sxs/hr.Running mud cleaner/centrifuge periodically to reduce LGS's.Mud recently started containing 0.5%sand content. For Report #015 On 04-17-2012 Operation at Depth(MD/TVD) 9,378/9,378 ft Rig Activity Pumped the Sweep at 9375'as POOH and lost pump pressure on one of the pumps(broken cylinder). Continued pumping the sweep out with the remaining pump;both pumps currently operational now.BOP Testing at report time. Activity Testing B.O.P. Fluid Treatment Ran Hi weight(11.Oppg)Hi Vis(180 Vis)sweep at 9375 as POOH.Did not retain sweep and pumped away into cuttings box.PAC-L/Dextrid as filtration control,Barazan D as a viscosifier,BAROID 41 used to weight up sweep. Created:05-01-2012 4:40:00PM United States of America Badami Anchorage North Slope - Page 20 of 21 - HALLIBURTON I Baroir' Red Wolf#2 • SAVANT ALASKA LLC-EBUS • NABORS ALASKA • NAD 7ES • WSE API(Copy) Drilling Fluids -Operations Log Recap Interval# 02 Top of Interval(MD/TVD) 3,872/3,872 ft From Date 04-12-2012 Bottom of Interval(MD/TVD) 11,859/11,859 ft To Date 04-23-2012 Avg Hole Size/Bit Size 9.700/8.500 in For Report #016 On 04-18-2012 Operation at Depth(MD/TVD) 9,431/9,431 ft Rig Activity The pump had another malfunction and required additional parts from a rig in Deadhorse. Ran to the casing shoe,cut and slip drilling line,RTB to drill ahead.Going to break circulation every 12 stands while running back in. Activity Drilling Fluid Treatment Fluid has been sitting in pits/downhokle since last night,Treated with Aldacide G/X-Cide to remove microbiocides. Barazan D for viscosity, PAC-L/Dextrid for Filtration control. 17bbl/hr H2O.Caustic for Alaklinity For Report #017 On 04-19-2012 Operation at Depth(MD/TVD) 10,762/10,762 ft Rig Activity Drilled from 9431'to 10762'in a 24 hour period.WOB 20K,Pump 4000psi,SPM 204,JARS 63.64. Last sweep completed at 10,500'.Drill ahead. Activity Drilling Fluid Treatment 12bbls/hr H2O,2sxs/hr of Dextrid/PAC-L.Barazan D+added to maintain a Vis of 60,Caustic as an alkalinity source.Aldacide G/X-Clde 207 to maintain low levels of Microbiocides.Condet E/Drill N Slide to prevent shaker blinding.We will not be running sweeps anymore unless requested by Co Man. For Report #018 On 04-20-2012 Operation at Depth(MD/TVD) 11,731/11,731 ft Rig Activity Hit killian sands at 11,600'and drilled for 40'to bottom of Killian.At 11,650'Pulled off bottom and circulated to check for losses,no losses.Continuing to drill ahead at 29 ROP. Pumps at 4000psi. Activity Drilling Fluid Treatment Built a 50bbl(40ppb)LCM pill(Barofibre/Walnut/Baracarb 25)as a precautionary measure as drilling through the Killian sands.BARAZAN D+1 sx/hr as a viscosifier,PAC-L/Dextrid 2 sxs/hr for filtration control.Aldacide G and X-Cide 207 to reduce Microbiocides,caustic soda as an source.Currently running H2O 12bbls/hr. For Report #019 On 04-21-2012 Operation at Depth(MD/TVD) 11,859/11,859 ft Rig Activity Drilled to 11859'TD.We are RIH to prepare for cementing the bottom of the well and pull back to cement at the casing shoe to P&A. Activity Tripping Fluid Treatment Aldacide G/Xicde 207 used as a mirobiocide,Barazan D+as a viscosifier,Dextrid/Pac-L for filtration control, Caustic as an kalinity source. For Report #020 On 04-22-2012 Operation at Depth(MD/TVD) 11,859/11,859 ft Rig Activity Pumped ceme, ,pumped dry job POOH. Activity Cementing Fluid Treatment Weighted up a dry job. For Report #021 On 04-23-2012 Operation at Depth(MD/TVD) 11,859/11,859 ft Rig Activity Pumped for P&A.Cleaned pits,Rigging down. Activity Rigging down Fluid Treatment Added Citric to cement contaminant pills to lower pH before shipping.Barazan D+was taken to Ballmill to used to process cuttings from well. Created:05-01-2012 4:40:00PM United States of America Badami Anchorage North Slope - Page 21 of 21 - 2.\2_-019 Bit Performance Summary ReedHycalog Drill Bits Bit #2 — 7" SperryDrill 7/8 - 6.0 Stage 1.22°PDM Date: Apr 21, 2012 Customer: Savant Alaska RIG: Nabors #7ES Field: Badami Bit Size: 8.5" Bit Type: DTX619M-D6 Serial No: 127834 RB Well Name: Red Wolf#2 -... f ." i U., .,, if 1 ii*: ' iility ila IQ 8or44 lr et . ‘ lib* lialil _,If , , ‘4,,i,_ ., . steri BIT CONDITION Comments: This bit and BHA drilled the shale below the Written By: Marty Robertson Tuffs and into the Kekiktuk. The ROP slowed and TD was called. Pump issues were experienced while drilling, 2 IADC Dull Grade: nozzles were plugged with junk (photos below). The 3 8 WT S X I LT TD shoulder cutters are worn into the blades and the bit could no longer cut the formation. This was a backup bit for the TI TO MDC LOC B G ODC RP Tuffs and it did a decent job. We recommend a different bit Fit for Re-Run? Yes X No style for optimum performance in the Kekiktuk. Fit for Re-Build? Yes X No BIT RUN INFORMATION Nozzles 6-13's TFA .778 H.S.I. at Bit 2.43 PSI at Bit 434 IN OUT Total Ftg. 2,481 Drilling Parameters Min Max MD 9,378 11,860 Total Hrs 43 Mud Type LSND Mud Wt. 9.4 9.6 TVD 9,377 Avg. ROP 58 ft/hr FV 48 WOB 14 25 Inclination ° 0 Rotate Ftg. PV 20 Flow GPM 425 545 Azimuth 285° 48° Rotate Hrs. YP 25 Motor RPM 165 183 ECD Rotate ROP ft/hr Drive Type Top Drive Pipe RPM Avg. DLS .1° Slide Ftg. / % 0 / 0% Motor Type PDM SPP 3310 4150 Max. DLS .6° Slide Hrs / % 0 / 0% Motor Bend 1.22 ECD ppg Formations Drilled Slide ROP ft/hr Bit to Bend Ft Solids Sand, Shale; Killian, Hue, HRZ, Kekiktuk K Rev K Torque ft/lb 5.4 k 6.6 k 1 fin } .�a � . i _ ' •,,,4t„., . :14: ,,, ' ,',; ,.. ....., • %,,, „.„..,,,... ( ,._ ,• „. . .. ., _ . . „, ,.., . „.„ ,.., . r. .„, , . . i ... ''. '" 741t; ,' ., ,, T -.:,',:•„,-....„ r a j .4,;,''',. �0, - • ..,...., ,_ _ . .. .,... i.. S ,„,. t , „ • 4d • .... ... ,. . .....„ ,,.._ .., . . .. Y. t . ,._.. , .„ . .-.•..i,„„•,.: ' j ..-,'"`— .,. , , , ,. ,, . ,, „,,,,,....::„.!-,.....,!, ',,',.' ), . • Y •+Yr Y + 3 „r„... ,... ....,..r. .. r“ . lib, , . . . +4$g ti . ,.. .,,..,..L. • , ri ak' .A 4 3 Oar '111 ' - . - /•,. fir` 9f i 14. MI 5 •-0.k..-Itii• '1,,, '''',.----..p., ,- 110011NIMpt . . Bit Performance Summary ReedHycalog Drill Bifs Bit #1 - 7" SperryDrill 7/8 - 6.0 Stage 1.22°PDM Date: Apr 17, 2012 ' Customer: Savant Alaska RIG: Nabors #7ES Field: Badami Bit Size: 8.5" Bit Type: DTX619M-D6 Serial No: 130543 Well Name: Red Wolf#2 .: V ., 4 1 b ' e Sir.' 4."fin �t�'" I WWI �FN a r1N e RED Wolf2 , 8-2 ‘-jf 1.505 113 • , ,q ,,, \ l';'" .,. BIT CONDITION Comments: Bit and BHA drilled 5,415' until a washed fluid end was Written By: Marty Robertson reported from the rig and the decision was made to POOH IADC Dull Grade: and change BHA and test Bop's. Bit shows excessive wear on the shoulder. Broken and chipped cutters are typical dull 3 4 WT NT X I CT TD characteristics from drilling the Ugnu and the Tuffs. Stick- TI TO MDC LOC B G ODC RP slip/vibration issues were reported by the DD in the Ugnu Fit for Re-Run? Yes X No and Tuffs. Very good run for the formations drilled. Fit for Re-Build? Yes X No BIT RUN INFORMATION Nozzles 6-13's TFA .778 H.S.I. at Bit 2.43 PSI at Bit 434 IN OUT Total Ftg. 5,415 Drilling Parameters Min Max MD 3,964 9,379 Total Hrs 49.6 Mud Type LSND Mud Wt. 9.5 9.6 TVD 3,963 9,377 Avg. ROP 109 ft/hr FV 48 WOB 3 15 Inclination 1° 1.84° Rotate Ftg. 5,333 PV 20 Flow GPM 520 550 Azimuth 182° 285° Rotate Hrs. 47 YP 25 Motor RPM 172 182 ECD Rotate ROP 113 ft/hr Drive Type Top Drive Pipe RPM 70 100 Avg. DLS .04° Slide Ftg. / % 82 / 1.5% Motor Type PDM SPP 1900 4000 Max. DLS, 1.6° Slide Hrs / % 2.6 / 5.2% Motor Bend 1.22 ECD ppg Formations Drilled Slide ROP 32 ft/hr Bit to Bend Ft Solids % Ugnu, W.Sak., Colville, Tuffs K Rev K Torque ft/lb 3.2 k 5.3 k • t ,...1pip,... /. s . w : • 1.w£ ' a • z '•.' a to , ..,...... . ,.. ,.,.,, ...' • ,,f.lb ,,,,,.....,. .. , ,,,,,..:. ... ::., ... ., . . !744-; „,,,„„_ -, ''''''' , '4, ,''." i ii,1/4, 41,4 ViSi • ' -* f - , _ „.„..,....,...„ .,... ,.4_-.7' .i' ..'•':', ''''..'tf;• 10 i'..1.;:'''.."J'i:',',.:aiklf,•.4.i:iti7,:t '''' ..?''' tips . 111777: T.^ k� . ; II .r t *''''. ,::.',; .-„,..'' 4.i.-- -:.*:',-',. :'..'''''f., r ,....,. .. . , .... ...,„ ..,.. .. . .. . .. .. . . .. ,.,.,". . .,...:. . . . . _ ....„*„.,,,,..,.. .,„.....„,,,,.. ......,,,,...„..t.,.,:... . :__ ,.., . ...,,,. , , ... ,......„,4,,,*;...,..„.„.4. ..,•._...,..,,,,....„.,,,,..,..., . .. ..,.,, ,.,..._, , ii_ ,,„., . ..... .. ..,„. _ • ,•.„,,,i • ., „..,,,,.,--. ____,--- ''..-4,;.' • '- - , '-. .., „-, -,.. . ,..„. ` , Y s ro •sy' d., if t i-• - •,--,i,, , vim++ 5 6i f6 1010r1 , i,.. :,:-,. .— ...'0-....!, p HALLIBURTON Bit Run Recap Security DBS H.eEunon Energy ServKes Customer Savant Alaska Location Red Wolf#2 Rig Nabors 7ES Bit Size I Type 12 1/4"EQH12DRC Rerun Serial No 11966739 Date Run 4/8/2012 Summary of Bit Performance r% Depth In MD/TVD 2585'MD/2585'TVD *jR. Depth Out MD/TVD 3872'MD/3871'TVD y Footage(ft) 1287' r. Hours 19.16 , ,4 Run ROP(ft/hr) 67 ft/hr �`. WOB(Klb) _ 4/22.000 a sj Rotory RPM 105/110 4 i Motor RPM 109/112 . • Max DLS 1.05 Deg./100' Inclination In/Out 1.69/2.02 Azimuth In/Out 179.77/114.10 + 't. TFA 3-16,1-14(.7394 TFA) k Pressure (psi) 1220/1800x Flowrate (gpm) 415/430 Mud Weight (ppg) 8.6 : Motor Type 8"SperryDrill 4/5 5.3 Stq. 1.15 Deg.BH Slide Ftg 20' $ Slide / ROP _ .28/69 ft/hr ► IP* Rotate Ftg 1267' ..""'>f Rotate / ROP 18.63/67 ft/hr .-i„.- Krevsi Formation Dull Grade I 3-3-WT-A-E-I-NO-TD Objective 'Drill balance of 12 1/4"hole to TD from 2585'to 4550'MD Results (Formation ratty to 3220'MD Difficult to maintain consistent drilling parameters and ROP.Between 3048'to 3145'MD made a slide to knock down inclination from 2.43 Deg.to 1.53 Deg. Gas shows at bottom of gravel @ 3660'MD. From 3825'to 3845'MD ROP slowed. had to increase WOB to maintain ROP.Made a connection and MWD failed,but wasn't a problem as TD was called early @ 3872'MD HALLIBURTON Bit Run Recap Security DBS HeglburIon Energy Services Customer Savant Alaska •Location Red Wolf#2 Rig Nabors 7ES Bit Size/Type 12 1/4"QHC1GRC Rerun Serial No 11748199 Date Run 4/4/2012 Summary of Bit Performance Depth In MD/TVD 497'MD/497'TVD Depth Out MD/TVD 1402'MD/1402'TVD Footage(ft) 905' °`` ,Hours 15.78 ,1's ‘,,, ' _., . * - ' .7*.„; �: Run ROP(ft/hr) 57 ft/hr _ . ,, WOB(Klb) 8/15,000 s Rotory RPM 85/120 Motor RPM 105/117 ,.4 ' Max DLS t Inclination In/Out 0.09/.0.85 j h` "' u Azimuth In/Out 243.42/158.42 TFA _ 2-16,2-14(.6934 TFA) Pressure (psi) 1070/1225 _ '.; ; "'� Flowrate (gpm) 405/450 Mud Weight (ppg) a ' Motor Type 8"SperryDrill 4/5 5.3 Stq. 1.15 Deq.BH Slide Ft s.. • +�« .0004„,......9 Slide / ROP Rotate Ftg Rotate / ROP sr. Krevs Formation Dull Grade I 8-8-WT-A-8-4-ER-PR Objective 'Drill as much hole as possible,so that next bit makes it to TD. Results 'High solids content.kept flow rates below 425 GPM and avoid overloading solids control equipment.Torque spikes of 2-4K, and large rocks of 1-3"caused bit bounce.Mostly pea gravel and sand below large rocks POOH prior to reaching bottom of permafrost. ROP's were as high as 80-90 ft/hr,but dropped to 40 ft/hr,then 20 ft/hr after last connection.Bit was evenly worn down to the cones ALASKA Attn: Robert Haverfield Halliburton 6900 Arctic Blvd Anchorage Alaska 99518-2146 2 Sets Dry Savant Alaska LLC Attn: Erik Opstad 4720 Business Park Blvd. Suite G40, Anchorage, AK, 99503 Location: Red Wolf ( API 50-029-23465-00) Dry Sample Boxes Box Depth Envelopes ✓1 3872-4830 32 Wet Sample Boxes -' 2 4830-5670 28 Box Depth Bags /3 5670-6630 32 1 3900-11860 32 '' 4 6630-7470 28 5 7470 8460 33 TOTAL SAMPLE ENVELOPES 2023 i 6 8460-9360 30 TOTAL DRY SAMPLE BOXES 50 / 7 9360-10350 33 TOTAL WET SAMPLE BOXES 1 8 10350-11100 25 TOTAL WET SAMPLE BAGS 32 9 11100-11760 38 10 11760-11860 TD 10 77 °k 021a - Or MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg e7/0 '71)its DATE: April 26, 2012 P. I. Supervisor ( FROM: Lou Grimaldi SUBJECT: Surface Abandonment Petroleum Inspector Red Wolf#2 Savant LLC Badami Field PTD 2120190 Thursday, April 26th, 2012: I inspected the surface cutoff for Plug and Abandonment in Savant LLC's exploratory well Red Wolf#2. In earlier conversations with Gary Hammon (Savant Wellsite Lead) I had explained I would want to see the cutoff casing stub after the wellhead had been removed and the rig had left location. On 4/25/12 I received a call from Joe McInnis (Solsten) who had relieved Mr. Hammon. He called to have me come out for an inspection of the casing stub. Mr. McInnis also relayed that the cutoff casing stub had inadvertently been topped off without our opportunity to ensure cement to surface on all strings. I arrived location and spoke directly with Mr. McInnis about this at which time I was assured that he had physically verified the cement in the 9 5/8" casing as well as the 9 5/8" x 20" annulus. My experience with Mr. McInnis goes back to my beginnings as an AOGCC Inspector and I have always found him to be honest. The alternatives would be to make them drill out the hardened cement in the stub. I feel we can take his word for this but I explained to him that these are an important part of the P&A process at which I was assured he understood and it had been a matter of the rig hands being a bit too ambitious and trying to move things along. The cut off stub I observed appeared to possibly be too close to surface and I discussed with Mr. McInnis the minimum 3' below tundra level requirement. It was difficult to tell the depth as the cellar culvert was still in the hole making tundra depth impossible to verify at this time. I asked for pictures showing depth of cut when the culvert was removed or a window was cut in it. I checked the information that was bead-welded to the 1/4" marker plate that Mr. McInnis had in his possession which matched the drilling permit on-hand. I requested that pictures be taken of the final cutoff and marker plate welded on the stub as well as cleanliness of cellar and fill. I left location at this time. Saturday, April 28, 2012; I spoke with Mr. McInnis this morning to check on progress and requesting pictures. 2012-0426 Surface_Abandon_RedWolf-2 1g 1 of 5 Sunday, April 29, 2012; I received the pictures this morning of the final cutoff, plate being welded on, final welded appearance, and depth of cut. There was also a picture of the final mound of overburden placed at what appears to be the well site. All appeared to be within expected P&A guidelines. One situation that I am not sure may create problems is that it is unclear whether the "base plate" and attached "gussets" to the conductor were removed or not. This most likely will not be a problem but in my experience it is wise to remove all protruding surfaces from the casing to keep the "heaving" effect to a minimum. I sent an e-mail to Sonny Kula (Savant; Drilling & Wells) asking for clarification on this. I also explained that at that time I did not view this as non-compliance but more of a matter of interest as I had not previously seen the base plate left installed. To create a heaving problem the ice would have to force the conductor vertically to break the cement bond between the 20" and 9 5/8" casings and lift approximately 100' of 20" casing. Highly unlikely but in my opinion may be not worth the risk. Attachments: FW_ Savant Alaska RW2.pdf Red Wolf#2 original cutoff b.JPG Red Wolf#2 original cutoff.JPG Red Wolf#2 Overburden.jpg Red Wolf#2 plate.JPG Red Wolf 2 cutoff depth.jpg Red Wolf 2 final cutoff.jpg Red Wolf 2 final weld.jpg Red Wolf 2 Well sign.JPG Note (J. Regg; 5/3/12) 17' Spoke with Inspector Lou Grimaldi about the base plate issue on 4/30/2012. He indicated that the purpose of the base plate welded to the conductor is to provide additional support (against subsidence) while drilling. The base plate was estimated to be 10 sf. Removal at this point in time would disturb a large surface area since the well cellar (culvert) had already been removed (45 degree sloped walls to prevent sloughing into hole while workers cut, remove base plate). In lieu of removal, it was agreed that Savant should be directed to monitor the well location at least annually for evidence of upward movement of the well and base plate. A 5 year timeframe for monitoring was suggested. 2012-0426 Surface Abandon_RedWolf-2_1g 2 of 5 Surface Abandonment— Red Wolf#2 (Savant) PTD 2120190 e. f..-- -- � a 4 � t «� 4' ; .. - • 3 Original cutoff depth(photo by L.Grimaldi,AOGCC) AIL 411111111102.: 111166121110 TV disfes. Marker plate;notice the hole drilled in plate at 12 o'clock position(photo by L. Grimaldi, (AOGCC) - - -- .- - 2012-0426_Surface_Abandon_Red W olf-2_1g 3 of 5 r a SA ANT �/�I /SCK ARe d Wolf #2 Well Sign Location: 1350' FSL, 4363' FEL, SEC 36, T10, R19E API No: 50-029-23465-00 I'll): 212-019 Li.........immailiamommimminiNNMI • tri 11,...____41" onrim � a . s _� , f _�.�....,. e..atimer miumer - + .' Depth of casing '12 AP I. below tundra after Amer i tx.0 final cutoff(photo p. ai' ;. courtesy of Savant) vior.mielemo :1441100�$11:lZr_Ii t. 2eft 1 --1111111 . �^.�,�:. �.. ter, ori.. .. sip «.4 .,,,,N) 004..45 2012-0426_Surface_Abandon_RedWolf-2_lg 4 of 5 Final cut-off;cement to surface �* (photo courtesy of Savant) i Marker Plate installed;hole in plate welded closed(photo courtesy of Savant) Abandoned Red Wolf#2 buried and mounded to account for any subsidence in excavation(photo courtesy of Savant) RM tali !8 2012-0426_Surface_Abandon_RedW olf-2_lg 5 of 5 Red Wolf #2 - AOGCC Weekly Operations SReport #2 Week of 9 April through 15 April 2012 P7 0 6,2(2.-01-1 k. 1H10-4 � f .._e...._...... �. y30 k _. SAVANT ALASKA, LLC April 16, 2012 Erik Opstad, Drilling&Wells Manager t � \ Red Wolf #2 - AOGCC Weekly Operations Summary Report #2 Week of 9 April through 15 April 2012 Executive Overview Red Wolf #2 spudded on the afternoon of April 3, 2012 drilling a 12'/4" hole on diverter. The well is expected to delineation a Kekiktuk discovery made by Savant Alaska in April 2010. By report time at 0600 hours on Monday April 16, 2012 Nabors 7ES was drilling ahead at -100 feet/hour in the Intermediate Hole section at -8,445' MD/TVD. Recapping the 12'/4" surface hole, the section consisted largely of unconsolidated P-gravel with occasional cobble layers, inter-bedded with clay lenses and paleo-wood debris down to base gravel at 3,320' MD/TVD Between the base gravel and surface-hole TD the section was represented by graded layers of medium to fine grain sandstone with inter-bedded shale. A 10,000+ Unit gas show was observed at 3,630' MD/TVD, which was N o associated with a 10-foot thick coal seam LWD logged between 3,610' - 3,620' MD/TVD. Generally, the surface hole was in excellent condition when TD was called at 3,872' after cutting °`�� -,41P "' ' ! vieliquftlimmipor -50-feet of very hard shale 41,1111%Milinvi `" deemed to be suitable for setting the surface shoe. The trip out of s .., 2 the hole pulled cleanly and the • rt 95/8", 47# casing ran to bottom 13:. smoothly. For the Primary Q Cement Job we pumped 100- B b l s. 10.1 PPG mud push Figure 1. TAM Port Collar shifting tool used,for Top Job 8 followed by 472-Bbls 10.7 PPG o Lead and a 50-Bbl 15.8 PPG Tail. No cement returns were observed to N surface. The possibility of needing to conduct a top-job had been anticipated by placing a TAM Port Collar at N 500' MD in the 95/8" casing string. Once the -0 a) AOGCC Inspector was on location a shifting tool was RIH to open the Port cr Collar. After circulating out any gunk in the IA, cement was pumped and good returns observed at surface. After rigging-down the cement equipment and diverter, nippling-up and testing BOP equipment, the 5" DP was swapped for 4" HT pipe and a slick BHA RIH to wash and ream. After drilling a short section of new hole the shoe was tested to an equivalent mud weight of 13.2 PPG and the slick assembly POOH to surface and laid-down. A new drilling BHA complete with DD/LWD smart tools was picked-up and RIH to 3,965' MD/TVD where we commenced drilling ahead in the Intermediate Hole. As of report time, light gas shows had been reported at 5025', 5330', 6050, 6770' and 6990' MD/TVD. Crude oil was reported on pits while drilling sand at -6930' MD/TVD. None of these shows are viewed as significant. Daily Summary 9 April 2012 (Reports 0600-2400 hours) — Continue rigging up for surface cement job. Wait on vacuum truck to be replaced (2-hours). Primary Cementing: pump 5-Bbls. 10.1 PPG mud push & PT lines to 2,600 PSI. Continue to pump 100-Bbls total push; drop bottom plug. SLB continues pumping 472-Bbls 10.7 PPG Lead @ 4.8 BPM and 50-Bbls 15.8 PPG Tail. Drop top plug and chase with 10-Bbls water. Blow down cement lines, then Z laydown cement head and elevators. Primary cement job failed to return to surface. Notify AOGCC inspector of pending top-job. 10 April 2012 - Wait on additional cement and water for top job. PJSM. PT cement-lines to 2,600 PSI. Open Port Collar and circulate out IA gunk. Pump N 150-Bbls 10.7 PPG cement and observed good returns to surface. Pump 6- Bbls of water to close port and PT collar to 1,000 PSI (good). Release Q shifting tool, then pressure up to 2,500 PSI to blow choke clear. Pump 50- Bbls of water to flush out drill pipe and casing. Laydown drill pipe and port- collar shifting tool. ND Diverter System. NU BOPE. 0 11 April 2012 - Test BOP upper & lower rams/blinds at 250/4000 PSI for o 5-minutes. Test Annular Preventer at 250/2500 PSI for 5-minutes. Test witnessed by AOGCC Inspector John Crisp and TP Paul Yearout. BD manifold, o choke & kill-line, top drive & test pump. Pull test plug. Laydown 5" drill pipe; 7 clean rig floor. Pick-up 4" HT-40 drill pipe. c" 12 April 2012 - Continue to PU 4" DP. Cut & slip drilling line. Service top drive, drawworks and calibrate block height. Trip in hole to 3,656' MD/TVD; wash and ream 108-feet to 3,764' MD/TVD. Pressure test casing shoe to 2,500 PSI for 15-minutes. Drill FC & shoe tract to 3,840' MD/TVD. 13 April 2012 - Continue rotary drilling to 3,965' MD/TVD. Circulate and condition mud. POOH. Monitor well while laying down dumb BHA. PU smart BHA, ECO DD/LWD tools and make-up PCD Bit. Trip in hole to 3,965' MD/TVD. Commence rotary drilling and establish ECD based line. Rotary drill to 4,787' MD/TVD. 14 April 2012 - Rotary drill from 4,787' to 6002' MD (6002' TVD). Circulate and condition mud; pump high-vis sweep @520 GPM and 2,040 PSI. POOH short-trip back to surface casing shoe. Pulled 25k over at 4187', 4215', 4275' and 4460'. Worked through each tight spot. PU 9 additional joints of 4" HT drill pipe and service top drive. 15 April 2012- Finish rig service work. RIH to 6002' MD. Rotary drill ahead T/ 7,695' MD/TVD. While drilling ahead small gas shows were observed at 5025', 5330', 6050, 6770' and 6990'. Crude oil reported on pits while drilling sand at —6930' MD N c-i o 16 April 2012 (Reports 2400 - 0600 hours) — Continue rotary drilling from 7,695' to 8,445'. Mud motor showing I anomalous vibrations and could fail at any "' time! cr Expected Activities Next 7-Days (n Continue to rotary drill Intermediate Hole • • E to approximately -11,525' TVDss. Savant c_ '~ _ Q Geologist will make actual intermediate TD Awa , o pick based on real-time MWD/MWD data. - Circulate to condition mud. Pump high-VIS sweep; POOH to surface. Conduct BOPE Qtest and service rig. PU and RIH 7", 26#, 7. L-80, BTC casing. RU cementing equipment r V; and cement casing to 1,500' above 7" rib A - shoe. >END REPORT< Figure 2. Servicing 7ES Top Drive Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Saturday, April 21, 2012 6:52 PM pill z, - O/� To: Erik Opstad Cc: Davies, Stephen F (DOA) Subject: Re: Red Wolf#2 -Application for Sundry Approvals- Plug &Abandonment Erik , You have verbal approval to P & A well as proposed with the addition of adding a cement plug of sufficient length to cover the Kekiktuk zone plus an additional 100ft Guy Sent from my 'Phone • On Apr 21, 2012, at 11:24 AM, "Erik Opstad" <Erik.Opstad@savantalaska.com> wrote: > Guy, > Attached is our Application for Sundry Approvals to P&A Red Wolf #2. A very wet Kekiktuk section! > Please let me know if you have any questions relative to the proposed P&A program. > Regards, > Erik > 907-448-6010 > <RW2 Sundry 10-403 - P & A Program 04-21-2012.pdf> <Tripple Combo Logs > Shoe to 11564.pdf> 1 r [LnsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Erik A. Opstad Drilling & Wells Manager Savant Alaska, LLC P.O. Box 112212 `" ( 1Q Anchorage, AK 99511 Re: Badami Unit, Kekiktuk Formation, Red Wolf#2 Sundry Number: 312-173 Dear Mr. Opstad: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, e4t / /074/N- Cathy . Fo rster Chair DATED this 1(1 day of May, 2012. Encl. V1 `- V ��aOTC 5/��• RECEIVED // HA! 042012 • STATE OF ALASKA AOGCC ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon()• Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program❑ Suspend 0 Plug Perforations 0 Perforate❑ Pull Tubing 0 Time Extension D Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate 0 Alter Casing 0 Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Savant Alaska. LLC Development 0 Exploratory 12 • 212019 • 3.Address: Stratigraphic 0 Service ❑ 6.API Number: P.O. Box 112212 Anchorage, AK 99511 50-029-23465-00-00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ❑ No Red Woif#2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 367005 • Badami Unit/Kekiktuk Formation 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,859 11,857 11859 11857 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 20"91.1#H-40 110' 110' 1530 psi 520 psi Surface 3817' 9 5/8" 47#L-80 3847' 3847' 6870 psi 4750 psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program I] BOP Sketch 0 Exploratory 0 • Development 0 Service 0 14.Estimated Date for 15.Well Status after proposed work: 4/21/2012 OilGasWDSPL Commencing Operations: • 0 0 0 Suspended 0 16.Verbal Approval: Date: -2I-IL- WINJ ❑ GINJ 0 WAG 0 Abandoned ❑• Commission Representative: to Sc I -„t-- GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is que and correct to the best of my knowledge. Contact Erik Opstad or Gary Hammon Printed Name : S• Title Erik -d � Drilling&Wells Manager Signature "- • e Date ��/ ��/ 907 868-1258 March 21,2012 /J / COMMISSION USE ONLY �] Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 [._--i� 5[z/n I2 Plug Integrity IV BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: p/L,4 F��`."+-' ` ate-` I ct----eff ‹. „ , Subsequent Form Required: /6._L./() 7r' PAPPROVED BY Approved by: t/T/�c_� COMMISSIONER THE COMMISSION Date: s-!0 Z / 0R IGINABD141 S MAY I 1 2012 p) �✓ Form 10-403 Revised 1/2010 L Submit in Duplicate /\•• Red Wolf #2 - Request for Sundry Approval - Plug & Abandonment SUMMARY OF PROPOSAL Background Red Wolf #2 spudded on the afternoon of April 3, 2012 drilling a 121/4" hole on diverter. The well is expected to delineation a Kekiktuk discovery made by Savant Alaska in April 2010. By 1200 hours on Friday April 20, 2012 the well had reached total surface hole depth at 3,872' MD/TVD and was drilling ahead in the 81/2" hole at ''11, 370' MD toward a planned Intermediate TD of 11,525' MD. • Recapping drilling operations to date, the 12'/4" surface hole, consisted • largely of unconsolidated P-gravel with occasional cobble layers, inter- - bedded with clay lenses and paleo-wood debris down to base gravel at • 3,320' MD/TVD Between the base gravel and surface-hole TD the section o was represented by graded layers of medium to fine grain sandstone with inter-bedded shale. A 10,000+ Unit gas show was observed at 3,630' MD/TVD, which was associated with a 10-foot thick coal seam LWD logged 1 between 3,610' - 3,620' MD/TVD. 3 The surface hole was in excellent condition when TD was called at 3,872' • after cutting "50-feet of very hard shale deemed to be suitable for setting Q the surface shoe. For the Primary Cement Job we pumped 100-Bbls. 10.1 • PPG mud push followed by 472-Bbls 10.7 PPG Lead and a 50-Bbl 15.8 PPG • Tail. No cement returns were observed to surface. 0 8 The possibility of needing to conduct a top-job had been anticipated by 8 placing a TAM Port Collar at N 500' MD in the 95/s" casing string. After circulating out any gunk in the IA, cement was pumped and good returns • N observed at surface. The 9%" shoe was subsequently tested to 850 psi with a 9.0 PPG mud weight in the hole giving an FIT of 13.2 PPG EMW. I Drilling ahead in the Intermediate hole proceeded uneventfully to 9,378' MD. At 9,378 the BHA was pulled when a cylinder on the number 2 mud pump developed a hairline crack. While on surface conducting mandatory BOP testing and pump repairs, the BHA was also swapped-out adding porosity and sonic tools. After being out of the hole for nearly 2-days, the new BHA ran to bottom easily with no tight spots or bottom fill observed. As of noon on Friday April 20, 2012 7ES was drilling ahead uneventfully in the 8'/2" hole at 11,370' MD. Between the 9%" casing shoe and the present depth, we have not encounter any oil shows that flowed or required mud weight to be increased (see . attached mudlog). In order to facilitate ongoing development activities in the Badami Unit, Savant felt it would be advantageous to obtain FEL information through the Kekiktuk target this drilling season. Given the date, there was concern that Savant might not be able to achieve that goal, while at the same time adhering to the previously approved Red Wolf drilling program that called for setting 7" Intermediate casing before drilling out with a 6'h" bit through the Kekiktuk target. j Seeking sufficient time for a thorough evaluation of the Kekiktuk this ,f season, Savant requested Sundry Approvals from the AOGCC to continue ,drilling the 8%2" hole to TD at 12,100' MD. The AOGCC approve that request LI on Friday April 20, 2012. Drilling ahead, Savant crossed the LCU into the Kekiktuk at 11,650' MD and drilled to 11,859' MD where TD was called after analysis of LWD and • 1.0 mudlogging data showed that the prospect was wet. a a Q C O w a N 9— O CD a) DETAILED PLUG & ABANDONMENT PROCEDURE No significant hydrocarbon bearing strata, freshwater bearing sands or abnormally geo-pressured strata were encounter between the surface 9-5/8" 47# casing shoe at 3,847' MD and TD at 11,859' MD (see attached LWD • logs). 1. Lay down all 4" DP inside 9-5/8" casing except for 3800' needed for P&A. /) , 614- (,(.N 0 � 2. Using 4" DP, run & set 9 5/8" cement retainer approximately 70' above the 9 5/8" casing shoe (i.e. 3847'). PT 9-5/8" casing to 2000 psi. Cement squeeze sufficient sacks cement below retainer to fill casing to shoe plus 100' below shoe, sting out of retainer dumping 50' of cement on top of retainer. 0 N c\-I 3. POOH laying down DP except for 200'. Set 2nd 9 5/8" plugged cement retainer @ approximately 200'. Using DP, place balanced Arctic Set III cement from top of retainer up to 42'RKB (i.e. 10' below tundra level). o Pull up to 42' & circulate out cement. co 4. PU Baker mechanical knife cutter. Cut 9 5/8" casing @ 36' RKB (i.e. 5' below tundra level. Ice pad is 2' thick). o NOTE: The top of cement in 9 5/8"x 20"annulus has been measured v Q @ 5'below 9 5/8"hangar flukes. en5. ND BOPE. Remove both FMC wellhead spools. Use Baker spear to recover 9 5/8" casing hangar & pup. 6. Using torch, cut 20" conductor casing @ 3.5' below top of 20" conductor (i.e. 3' below tundra level). Use DRY SACK cement to fill up to top of 20". Weld on abandonment marker capping plate to top of 20" conductor bead-welded with the information as required by 20 AAC 25.120. i. 7. Using torch cut & recover 10' diameter culvert cellar to 3' below tundra level (i.e. 5' below top of cellar culvert pipe). Use steam hose if need be to help remove cellar culvert pipe. Remove scaffolding from cellar. 8. Release Nabors 7-ES for demobilization back to Deadhorse. • 9. Fill cellar hole with gravel to ice pad level. Clean location of all debris and ensure site clearance compliance with 20 AAC 25.170. (.1 r-1 0 N N Tt +C c a) E c O C co Q Q 06 to c EL To 0 0 0 C c 0 +, a) a) a C. m cc N 4- O 0 a) X 4 6�_ ger 11114 i Y e'frn 0 a S KJ N U B. t N 2 ... m / z I.% 1 0 z / aa 06ce o a a w U ccn N gg 1 g m a4 _ q$ r. 0 �i 7 Q 1§ Y - ! 0 a Z Udlil CC ;; A. di £ ■ s i ii ii A IV a 111111111111111111=I�I1� iI1i RI SII �I Ir •s11t, — - - IV III a n� * A ,/I,A v 'I' l' ■A 1-10-th- 'I 9 w 7 w Y a> o V 1 .zit u a .9/I of.9 .9/c 9,1 .,/c 01.1 .,/c 9.1 .9/c c.91 iso g Si4 E8° gg 3 LLI 11 1 ��z ii iiia,v g i go Li cpA O O �Z ZW� � �� R �n=�W '(r:0(./1z(- . Ha 0,7'Wyfi 00 �O cp Q ct L coo_ � W� QUO( ao�:"o QCs, Wm2 Q oQ� it "o\�.z- o ' I > =o`` =�nlQ—COQN- W' _ ^ O J OY' O N. 0 in I O O Ln in t. 1 i. 17 El 1 L1 L Q1 n 1 WO I Ir. rl L 0 rn N. . n O (CI! 2 —, U ? —J ! L —J L—J L—___, �C Z ,c4., 4 0 R - 1 . I- ,--7--)__c-- Q g C9 O0 F- V O (1) —I p i-LI LI u4X CL � m zJ Q Q J, W W c, = U O �I O O in I cep CD' -78.).. '..c2 ber a N ._ N I V nI,1- I ,III ADDITIONAL INFORMATION 1. MUD LEG I.D. 10" I.D. 2. TOTAL LENGTH OF U-TUBE PIPING 34 L.F. 3. TOTAL NUMBER OF BENDS IN U-TUBE 6 TOTAL 4. ANGLE OF BENDS IN U-TUBE (45,90,180) 5 ® 90' - 1 ® 45° 5. VENT LINE HEIGHT ABOVE GROUND LEVEL 43'-7 1/2" 6. VENT LINE I.D. 10" I.D. 17'-83" 0111 Nabors Alaska A NABORS INDUSTRIES Company NABORS RIG 7ES MUD GAS SEPARATOR PRODUCED BY: JOE ALSTON SEPTEMBER 6, 2005 H H.itc 8'-6'' 29.25" I.D. U—TUBE PIPING rt"� 90° 90° 90° - FROM CHOKE 777) 3.438" I.D. 45° 7'- 1014" 11 '- 1 " 90 P59 0 ° 2 L''L Cz O C O . Q) U C7 0 U y Vi as 2 a f' LL O N a _ 0 ' 1t � ©i . 1 it\ 11' Ill A w O 8 A 0 j �_ J0 1 CO Y e • O O • et \ iU C C III MIK ▪LEI 121 a) ; • A ne 6® ' 1 A Z B T 0 �►J)1 tio A l ® :I ii! ii 2111 Q 3 J > z � < o z 3 r kd ! 1 1 a 11 i a '' Qa �,— W w Q..3 a a s , x x ; .8 ^d . g 8 — N - - z ��q \ i i - i s z • a N V. 2 c,_ m o — I ). to ,0 ,g e n s s mN I. W ceD CC CO w x x w2CI CL m z I I I I I I 1 1 I ig 2 d d d `fl 3 V 1 7 7- - Z_ J J N 03 \- J i - 07 r4 ,..7,_ \ �Zm p N :NI i �Pa 3 ����, f� \ 1/ Q N P %'"..-'"C'?'mil-'" M J 21 CC W CO e }N} r / I.\, • Z N m J�el�—?,mc. N PJ z `I,iikO,�S C.3 W� W (n M o °-, zY w CC Wv me ▪ Imp - -41- 1 ® ' _- PJ a „ �R ! I 2 w/ i gJY #- _ Z. _ W u_,_� PJ n N 0 m 0 PJ a s N w 1 Q11 w� I� , J W J 're. ,~ wJ v, 41C.. \• C ( d C HH . 0 7.-,a IcAZ 1,1 ... �. 6m• `., l000,ll C a a, W J I* o00 o f Z 2 v. c �Ym s WO Y 0; M Qin N (� m c'7 %-J �. SII w • e Li- n L1 •-Pd-i�F �n b3 1Q ® 1000 (,^ n P 11/ 000�1 . am •:. 1 1 �� \r��, om a wo bt ot 1• 0 IP -O •® ..0 d CJ� RiN0 :12111 III . L_ _ ! T T L -8 Ad 9.1119=,01/I 40910'[00\0N0\M'•ui0-I\•f'!a°tl-l\fl[00 00\d"1'•^^.9\0K1V0 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, April 20, 2012 5:09 PM To: Schwartz, Guy L (DOA); 'Erik Opstad' Cc: 'Gary Hammon'; Davies, Stephen F (DOA) Subject: RE: Red Wolf#2 (PTD 212-019) Erik, Please amend step 2 below to read raise mud wt. from current weight 9.4 ppg to 10.1 ppg before drilling into the Kekiktuk fm. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L(DOA) Sent: Friday, April 20, 2012 4:49 PM To: 'Erik Opstad' Cc: Gary Hammon; Davies, Stephen F(DOA) Subject: RE: Red Wolf#2 Erik, Steve and I have reviewed the supplied mud log and OH log supplied. The Commission agrees you can proceed to TD of the well without setting intermediate casino. Further stipulations to your proposed procedure are as follows: 1. Perform FIT to 11.0 ppg before drilling into the Kekiktuk fm. 2. Weight up drilling mud from current 9.4 ppg to 10.4ppg before drilling into the Kekiktuk fm. .. this is based on offset wells B1-38 mud wt data at gas unit counts. 3. Pit watch manned at all times until well is TD'd Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Erik Opstad [mailto:Erik.Opstad@savantalaska.com] Sent: Friday, April 20, 2012 3:08 PM To: Schwartz, Guy L (DOA) Cc: Gary Hammon Subject: Red Wolf#2 Guy, We are currently drilling ahead in the 8-1/2" Intermediate hole on Red Wolf #2 and closing in on the top Kekiktuk (LCU). We have had no issues drilling • 4/20/2012 Page 2 of 2 this well and as I discussed with you earlier in the week we'd like to continue to TD with the 8-1/2" hole. As such, I've attached a FM 10-403 and related background information. Were requesting verbal approval from the AOGCC to proceed. Please give me a call at 907-448-6010 to discuss as required. Thanks, Erik 4/20/2012 a _ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 4/12'1,. DATE: 4/10/2012 P. I. Supervisor FROM: Bob Noble SUBJECT: Top Job Petroleum Inspector Red Wolf#2 PTD 2120190 - Savant Alaska LLC. 4/9/12 I received a call from Nabors 7ES tool Pusher telling me that they failed to get cement to surface and they would be doing a top job. I went out to location to find out they were hours from doing the top job. I got with the Savant representative Gary Hammond and went over details. On the initial surface cement job they pumped 473 bbls of lead and 72 bbls of tail and did not see any signs of cement at surface. Gary told me that they had a Tams collar at 508' and they were going to open it up and do the top job through it. 4/10/12 Finely everything got to location and they started the top job. They pumped about 100 bbls of Arctic Set Lite and we could see signs of cement back at surface. They shut down at 150 bbls total pumped on top job. It looked to be good, #10.7 cement back to surface. Top Job Red Wolf#2 noble Red Wolf # 2 - AOGCC Weekly Operations SReport # 1 1 pio Liz Week of 09 April 2012 fi 419 �® V _ ■ SAVANT ALASKA, LLC April 9, 2012 Erik Opstad, Drilling& Wells Manager \ \ Red Wolf #2 - AOGCC Weekly Operations Summary Report #1 Week of 09 April 2012 Executive Overview Red Wolf #2 spudded on the afternoon of April 3, 2012 drilling a 12'/4" hole on diverter. The well is expected to delineation a Kekiktuk discovery made by Savant Alaska in April 2010. By report time at 0600 hours on Monday April 9, 2012 the well had reached total surface holedepth at 3,872' MD/TVD and cementing operations were underway. The upper portion of the 12'/4" section from surface to approximately 1,630' MD/TVD consisted largely of unconsolidated P-gravel with occasional cobble layers, inter-bedded with clay lenses and paleo-wood debris. From 1,630' MD/TVD tobase gravel at 3,320' MD/TVD the section was characterized by coarse-grain sand, pebble layers and thin clay layers. Between the base gravel and surface hole TD the section was represented by graded layers of medium to fine grain sandstone with inter-bedded shale.Based on LWD logs base permafrost . is callout at kip s 4 1,950' MD/TVD.Except for a minor show at 3,630' MD/TVD, f. no gas was observed in the 121/4" surface hole. ' _ Using 300 viscosity mud averaging approximately 9.31b. 7 /gal, the section above 3,320' '*` /- MD/TVD was control-drilled at an 4 ROP of 100 ft. hr. with essentially 0-pounds weight on ,�.' # / bit. Bit #1, a Security Mill-Tooth, Figure 1.Mill-Tooth Bit Out @ 1,402'MD/TVD was pulled at 1,400' MD/TVD and graded as junk, confirming that mill-tooth bits were universally a poor choice for the surface hole within the Badami Unit.That bit was replaced with a medium-tooth insert bit custom built for Red Wolf #2. When pulled at TD that bit graded 2-3. Daily Summary 2 April 2012- MIRU Nabors 7ES and various support modules. Accept rig at 1300 hours. NU Starting Head, Diverter System and Riser. Install Diverter Lines and weight down with mud boxes. 3 April 2012 - Continue to NU Diverter System; install ground strap, post "on diverter" warning signs, test knife valves and FCO gas alarms. PU 5" Drill Pipe & HWDP. Rack back. Run full Diverter System Test per State Regulations. Test witnessed by AOGCC Inspector Lou Grimaldi. PU BHA; mill- tooth bit, motor, Flt Sub, XO STD, etc. Circulate and condition mud then fill hole. RIH and tag at 110' MD/TVD then commence rotary drilling. 4 April 2012-Drill to 479' MD/TVD! Circulate 850 STKs @ 355 GPM &456 PSI. Monitor well then POOH to surface. PU Sperry MWD/LWD tools and non- magnetic collars with5" HWDP.RIH shallow pulse test per Sperry coi MWD.Rotary drill from 479' to 1,275' MD/TVD. 5 April 2012 -Continue drilling to 1,402' MD/TVD; bit appeared worn out. 1 Circulate and condition mud while reciprocating pipe. POOH to surface lay down BHA and install new insert bit (#2). PU smart tools and upload per ., Sperry MWD. Service Top Drive. PU BHA, then RIH to 1,402'! Rotary drill E from 1,402' to 1,815' MD/TVD. cn 6 April 2012 - Rotary drilling from 1,815' to 2,582' MD/TVD. POOH from 2,582' to 2,428' to confirm erroneous MWD survey at 2,526' MD/TVD. RIH F/ 2,428' T/ 2,582' and commence rotary drilling. Continue drilling to 2,585' 3 MD/TVD. MWD tool accelerometer failure confirmed (probably Y & Z axis). • POOH F/ 2,585' MD/TVD T/ Surface; back-ream tight spot 1,770' to 8 1,675'.Stand-back BHA, download LWD/MWD data and swap out DD sub. PU Q BHA and RIH.Charge MWD with 14-hours trouble time. N 7 April 2012 - Continue to RIH T/ 2,585' MD/TVD. Rotary drill F/ 2,525' T/ 3 3,190'. Night tour continues rotary drilling F/ 3,190' T/ 3,849' MD/TVD. 2 8 April 2012 - Savant calls surface holeTD at 3,872' MD/TVD. Sperry Mud Pulse-Tool failed at 3,849'. Rotary drill F/ 3,849' T/ 3,872' MD/TVD.Add water while drilling to cut mud viscosity back from 300 to 200 and weight down to 9.2 lb./gal. Add fiber and circulate bottoms up. Place carbide bomb in mud and circulate. Hole diameter calculates out at 12.28 inches; appears in gauge. POOH F/ 3,872' T/ Surface.No tight spots. Lay down BHA, drain motor and break bit. Insert bit out grade 2-3.Rig up Schlumberger fill-up tool and cement lines.Run 9%", 47# Csg. To 2,324' MD/TVD 9 April 2O12(Reports only to 0600-hours) -Continue RIH with 9%", 47# Csg.& land.Casing ran slick to bottom with no tight spots! Circulate to condition mud. Ready to pump cement job; hold pre-job safety meeting. Expected Activities Next 7-Days Wait on cement. Lay down 5" drill pipe and PU 4" DP. ND 211/4" Diverter and lines, then NU 135/8" BOPS and PT to 4,000 psi.Notify AOGCC Inspector it , = to witness. RIH with 8'/2 BHA. PTi surface casing to 2,500 psi. Drill out ate` 9%" float shoe and 15-feet of new 4 :, hole. Conduct Formation Integrity Test to 12.8 ppg EMW. Rotary drill Intermediate Hole using Hycalog DTX619M-DT PDC bit to approximately -11,525' TVDss. Savant Geologist will make actual intermediate TD pick based on real- time eal- time MWD/MWD data. Figure 2.Preparing Red Wolf#2 Conductor rt,1 A Li-IA � � SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Erik A. Opstad Drilling & Wells Savant Alaska, LLC P.O. Box 112212 Anchorage, AK 99511-2212 Re: Badami Field, Kekiktuk Pool, Red Wolf#2 Savant Alaska, LLC Permit No: 212-019 Surface Location: 1350' FSL, 4363' FEL, SEC. 36, T1ON, R19E Bottomhole Location: 1350' FSL, 4363' FEL, SEC. 36, T1ON, R19E Dear Mr. Opstad: Enclosed is the approved application for permit to drill the above referenced exploration well. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. This permit to drill does not exempt you from obtaining additional permits or approvals 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 Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions Of this permit may result in the revocation or suspension of the permit. Sincerely, Cath P. Foerster Chair DATED this 11 day of March, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o end. (via e-mail) � ` r' Ir---A, LAG L SEAN PARNELL,GOVERNOR lin ,� L., ' ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Erik A. Opstad Drilling & Wells Manager Savant Alaska, LLC P.O. Box 112212 a © I g 1 Anchorage, AK 99511 Re: Badami Unit, Kekiktuk Formation, Red Wolf#2 Sundry Number: 312-172 Dear Mr. Opstad: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Asrovided in AS 31.05.080, within 20 days after written notice of this P decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, T a.qz,g,-)k—, Cathy . Foerster , � Chair /O DATED this day of May, 2012. Encl. 0 -TS 5 /io ! (_, `( ,,y- RECEIVED MAY 0 4 2012 . • STATE OF ALASKA AOGCC ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool 0 Repair Well❑ Change Approved Program I] • Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing❑ Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well 0 Stimulate 0 Alter Casing Cl Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Savant Alaska. LLC Development ❑ Exploratory O • 212019 • 3.Address: Stratigraphic 0 Service ❑ 6.API Number: P.O. Box 112212 Anchorage, AK 99511 50-029-23465-00-00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 Red Wolf#2 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 367005 ' Badami Unit/Kekiktuk Formation 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): Casing Length Size MD ND Burst Collapse Structural Conductor 73' 20"91.1#H-40 110' 110' 1530 psi 520 psi Surface 3817' 9 5/8" 47#L-80 3847' 3847' 6870 psi 4750 psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development ❑ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/21/2012 Oil I] • Gas ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: y'--20-IL— WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Ci;,,,'`- 5 _-./- GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing Is true and correct to the best of my knowledge. Contact Erik Opstad or Gary Hammon Printed Name Erik A. Opstad Title Drilling&Wells Manager Signature Pr- r Date ■A=:--- �,'/ � 907-868-1258 March 20,2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2 i 1 2 Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Subsequent Form Required: k>,....(../v r`7 (\ ç_ _i /l 0 > APPROVED BY Approved by:Q/1947 (�,, COMMISSIONER THE COMMISSION Date: 6^—/61— 12. sg- L RBDMS MAY 11201 ORIGINA1 Form 10-403 Revised 1/2010 Submit in Duplicate I Red Wolf #2 - Request for Sundry Approval - Program Change SUMMARY OF PROPOSAL Background Red Wolf #2 spudded on the afternoon of April 3, 2012 drilling a 121/4" hole on diverter. The well is expected to delineation a Kekiktuk discovery made by Savant Alaska in April 2010. By 1200 hours on Friday April 20, 2012 the well had reached total surface hole depth at 3,872' MD/TVD and was drilling ahead in the 8V2" hole at -11, 370' MD toward a planned Intermediate TD of 11,525' MD. Recapping drilling operations to date, the 121/4" surface hole, consisted largely of unconsolidated P-gravel with occasional cobble layers, inter- bedded with clay lenses and paleo-wood debris down to base gravel at 3,320' MD/TVD Between the base gravel and surface-hole TD the section o was represented by graded layers of medium to fine grain sandstone with inter-bedded shale. A 10,000+ Unit gas show was observed at 3,630' . MD/TVD, which was associated with a 10-foot thick coal seam LWD logged E between 3,610' - 3,620' MD/TVD. E a The surface hole was in excellent condition when TD was called at 3,872' a after cutting ''50-feet of very hard shale deemed to be suitable for setting the surface shoe. For the Primary Cement Job we pumped 100-Bbls. 10.1 a PPG mud push followed by 472-Bbls 10.7 PPG Lead and a 50-Bbl 15.8 PPG Tail. No cement returns were observed to surface. z v, The possibility of needing to conduct a top-job had been anticipated by placing a TAM Port Collar at N 500' MD in the 95/$" casing string. After s circulating out any gunk in the IA, cement was pumped and good returns 1 observed at surface. The 9%" shoe was subsequently tested to 850 psi with a N 9.0 PPG mud weight in the hole giving an FIT of 13.2 PPG EMW. Drilling ahead in the Intermediate hole proceeded uneventfully to 9,378' MD. • At 9,378 the BHA was pulled when a cylinder on the number 2 mud pump • I developed a hairline crack. While on surface conducting mandatory BOP testing and pump repairs, the BHA was also swapped-out adding porosity and sonic tools. After being out of the hole for nearly 2-days, the new BHA ran to bottom easily with no tight spots or bottom fill observed. As of noon on Friday April 20, 2012 7ES was drilling ahead uneventfully in the 8'/2" hole at 11,370' MD. Between the 9%" casing shoe and the present depth, we have not encounter . any oil shows that flowed or required mud weight to be increased (see attached mudlog). Program Modification Request To facilitate ongoing development activities in the Badami Unit, it would be advantageous for Savant to obtain FEL information through the Kekiktuk target this drilling season. Given the date, there is concern that we may be unable to achieve that goal, while at the same time adhering to the previously approved Red Wolf drilling program that calls for setting 7", Intermediate casing before drilling out with a 6/8" bit through the Kekiktuk 0 target. To provide a sufficient time window for a thorough evaluation of the 1,0 Kekiktuk this season, Savant proposes to continue drilling the 8'/2" hole now . underway to TD at 12,100' MD. We believe that this change in program can E be safely implemented for the following reasons: o c o_ 1. The surface shoe was successfully tested to 850 psi with a 9.0 PPG . a mud weight in the hole givingan FIT of 13.2 PPG EMW, well above the 9 maximum saltwater pressure gradient expected in the Kekiktuk of 8.3 • PPG EMW, 2. Hole conditions have been excellent while drilling the 8'/2" section and • are expected to remain so, 3. No significant hydrocarbon zones have been encounter that required . the mud weight to be raised. No sand development was observed in the Killian, so there are no over-pressured intervals to contend with I while drilling the Kekiktuk target, • 4. The Red Wolf 2 location is in an undeveloped area with virgin pressures so there is no threat of drilling out below the LCU into a • depleted zone and, 5. In B1-38 we put 12.2 PPG against the Kekiktuk to control Killian inflow above in order to trip out of the hole without losing circulation Proposed Forward Operations Program 1. Drill into Kekiktuk no more than 5-feet. Circulate bottoms up, monitor - well. 2. If any drilling fluid loss is observed after drilling into the Kekiktuk, the loss will be controlled with LCM and 7" casing run at this depth. N 0 3. If no fluid loss is observed, then drill ahead to TD; expected to be • ✓" N reached by Saturday April 21st, 4. Maintain good borehole stability with mud weights in a range from 8.6 . 03 to 10.5 PPG U EE txo 5. Make decision to run 7" casing, complete well and suspend for season ,r O • or P&A. 0 6. Complete well operations and commence 7ES demobilization to • Deadhorse by May 1st N O N N a' • E 6 Ili g C- IPgS LI 11 114 0 E o n A ri 611 ` ' / Iid Z 0 .r d / Z_ a a a U W3 N gt a g m 3c, eZ s 1 ail = T 7n F -- _J nn I Z Ulili cm a -.) 1 ii elr' '' 11 cc - IIUu1III1mI1iuiM ts o_ If T .A ' 1-114-.. s 53 I n I n h .z/i a., .2/i Di.0 .Ht o.1 .s/t at.1 .s/t s.1 .o/L t.01 a b f ti al 514.1 O Q jV=, �J�2 8 g B CO O>-c(Z - zWl� d 11 �i &� a o _CL 4.1 may/) b 6 o0�mm��— °p��'oo �—� � 22' a V Q II L 0 0 0W m W �Qz W\ ^U�0 `z� O F--Z ctJ mp, � =_z� �� C �io°p=gz� o ' �, oCt� gg 11 20 14-1 ^ 0 JI O Y 1 ZS Ln NI O, r7 O O in gs n n Q JLJL I A- •/InL tiF c7 = A OC 0 U i X ex a: r' ? <, —J L—J L Z CC CC Np la-1 Li 4 V J lV—1 T X C.) N Q CC Y I A\-1 r 1-111-11----/-N--\ m N u � N LJ ,Tr Z CO 1 '1 LL, JI WI O = U O Lo t ci, 8-)---q. o by -- � I I v N ._ N �N 1 d-. • ok L Or CaQ) c c ` 141/4 8 (4 II cn \ o U ct OL co 2 Q , )111 11 k` i O ' ;© 1 p -� !' y O 4` O ' .... , \,,,..C CO \ 0 1 ..... iv e _ % ‘ L - O 0 A 't a) Q_ 1 - J m r as E e\ „. YO O +f U Li V1 ■I.=MI 1 a) U Y > )) V O i a 0 its =CU a) c70 , Tz 47 co Q 0 �_ c > �/� J N Y ' ca c0 > -0 V/ LLO < s` xt > c Coa) C') L m e It -c * o O a) > O L o o (..) o 0 0 a a) > a) o o ocD 'a c 0 _ U Q- tf') �O, lt7 L(7 - (11 T C T N-M a 1- ,- J (b Z 0 O M M N - L O a) O Z a Z p AIIIIIIIIIIIIk E -1- rei ii-- ED OS a ADDITIONAL INFORMATION 1. MUD LEG I.D. 10" I.D. 2. TOTAL LENGTH OF U-TUBE PIPING 34 L.F. 3. TOTAL NUMBER OF BENDS IN U-TUBE 6 TOTAL 4. ANGLE OF BENDS IN U-TUBE (45,90,180) 5 @ 9°' - 1 @ 45° 5. VENT LINE HEIGHT ABOVE GROUND LEVEL 43'-7 1/2" 6. VENT LINE I.D. 10" I.D. 17'— ØIIINabors Alaska I A NABORS INDUSTRIES Company NABORS RIG 7ES MUD GAS SEPARATOR PRODUCED BY: JOE ALSTON SEPTEMBER 6, 2005 8'-6" 29.25" I.D. U—TUBE PIPING 90° 90° 90° FROM CHOKE 3.438" I.D. 45° 16 — 7,-10-" 11 '- 1 " 90° �90° 6 0g$ g I o Z g Qi r`J'1I���1 �� 3 ® $ I Ow' gAB XX 4 W Jy JJ k = = 02=W � o 68 _(� >^ Jill C� M �m� 3 3 = C d 2 d E n Z a Fa & a d 22 0_ W I `-^d O �p O O N 3 \ N ==O ==O m b PJ _ v V v V x i N � ci woW -4C ce g; ...- ..2 Lai o a8 a0 1-.4 b 1 N \ L...1 w 2 J m z �N o \ C¢m C j a PJ i- Nom] 00.1 fE I I ¢--I N r.'4'*-.-NNm W W CO N o�m M y. N� <vii� N��'�Sm� cn U. LaJ N M Y/ , 7= • ce — Z = ui 3 • m 1— w 02 Mwx I - W_� � PJ CC =� N O – Na r N LadY J� ~¢m� 1 w W C C tt " C � CC WI 61 Col a 0 �� X N N W , m ``' {q� {{.. / r I 1000 ilk Z i J }Pd Pd •b b ( l !Y 000 1 _. w VVV 8 U c. ® wo • D (41 ik Ii YY O] Z 1 d � �' `�) w / N 1d – Sed C `\ U " y �3.1 �: 61 f .PJ PJ i Q QY rdl c 1000,,,, 000 am I 0I- tri _' s N o coIto: Ij om �^ = o b1 a_...s, } vi– al_ LL �3Y i Al C - t lied„vier l l . t - - Ii� �ooe Mel C.IIOC/11/1 d.jg10.L00\9.0,...>-0641..tl-1\9[00 00\f mkr3V1N\-0 a o u o o m Country :USA xi c c w -a 0 0 0 0 0 a a 0 r cQ SD Field :Badaml 00000 Z co o r p ro 'O (Q 0 ( 0 m CO CO D) m 0 Location •Lat: 70°10'27.24"North co co____ a Q CD Long:147017 45.79"West PIOlNNNN .. .. .. .. o_ -n c (Ilimml OONNN IV -n o 3 Well :Red Wolf 2 J ,-.-.cri0 0 c.n0 0 O O O - 8 30000n, W -.. W 1 O .._.. Za >>' D .. D Company :SavantWm � = 0 0 g Rig :Nabors 7ES co WN-' ito -APO o N N . . CD • ccoo N c00n r o - 8 o T T v) LOCATION 00000 c o -- 0 0 00 o m D 0 _71 * 0 0000= = �- w = C C r r ===� R 0 D -I -i j a: - 0 co m cQ O c -0 < M K co. z m a — p cnWWN1A (D ZmQa c to C(DOD<TAV N N N 0 It O coOD O. s .. .. T�N(nN0-I 5 7 r V (p 00 ca m (0 A O -, 00000 r• 0 II V o O O = ? V01 WA N N C W 73 Z W N C •OZ 0 .. V Vinn "AJI A 0 co O (D O a1 a a t5 < N .. O (� N cc - o a CC O 0 p N -n 0 c 0 Li W * 0 cD 3 G N .Oi O N CO (p O a o, '' r v "4 2 a w � v T m N M 0 w V OCY) c o* fn N +� N V) os Ia 0 �, xi—I g, = a1 O cn a o o m � xj ln' Z " r" 0 73 73 TI v m m C < < _ O - a1 m3 3 o c C) D S a1 Pa 0 -0 m 611 o y 0 r „ Co cn .. r MI W ! O A W0 < ° (° r 7 I— O 0o c 8 00mt 0 0 , Or5. Z 1 o c tQ tQ C 3 .=' r. to LEGEND Abbreviations and Symbols Lithology Symbols Drilling Data Mud Data Sand Dolomite I BG Background Gas Cl- Chloride Ion Conc Rm Mud Resistivity BHT Bottom hole Temp FC Filter Cake Rmf Filtrate Resistivity I Sandstone C Carbide Test FL Filtrate Loss S Solids Content I Marl CB Core Bit G Gels Vis Funnel Viscosity CG Connection Gas pH Hydrogen Ion Content MW Mud Weight Silt CKF Check For Flow PV Plastic Viscosity YP Yield Point Mudstone CO Circulate Out ---- DB Diamond Bit Engineering Data Siltstone DC Depth CorrectionL Gumbo A.,,..,.,,,i 1- Core No. Water DS Direction Survey l Clay F DST Drillstem Test DST No. X Salt Water Chalk FLT Flowline Temp. LAT Logged After Trip Claystone NB New Bit _ Casing Seat + Fresh Water NR No Returns 4 Chert Side Wall Core 4 Hydrocarbons Smell PDC Polycrystalline Diamond Shale Compound Bit * Halite PR Partial Returns Gas Traces O H2S Smell RPM Revs Per Minute Lignite RRB Rerun Bit t t Gas IRFTI Interval Tester Anhydrite STG Short Trip Gas TB Turbo Drill "-lai I Oil' 's E-LOG J Wireline Log Run TG Trip Gas Gypsum U Gas Units WOB Weight On Bit Oil ILOTI Leakoff Test Limestone III Bitumen Integrity Gravel Bitumen 'PIT' Test I ROP = p Lagged Gas Hydrcbn Max o 300 ft/hr 0 a m 0 units Chromatograph r 13 Gas Analysis _. i_ithologiC n r� Gamma ^:C ^.-. -I Gas Avg (ppm) api 03 OC1 0fD = 0 units 1K Methane = Descriptions WOB O° o = MD Normalized Gas Ethane MW In = 0 klbs N csa co co (D units 1K Propane ppg 13 < Total Butane c� Remarks RPM Density ii 39in Phase Resistivity Total Pentane -- PWD Annular EMW N 0 rpm 200 1 g/cc3 m 0 - - ohms _ - 1 1 L •K 10K 1 Olm ppg 12 - vj I t Drill Floor 35'Above Permanent Datum Commenpe Rig-U$ 1 April 2012 ' SON. , Services Online ' 2 April 2012 Commenced 12.25"Su ace o Ca ib 800 TH4,Cl= CalibrateT Hole Section 1 13.000% Chromoatograph 8900 On Bot:21:00 3 April 20112 � Cl=1.00% — 18"Casing Set ---C2=0.501% I 1 0'MD,110'TVD C3=0.248% Bit#1 HDBS QCIGRC IC4=0.250% nC4=0.250% Jet,2A16,2A14 TFA 0.8934 iC5=O.lf 1% nCS=0.101% In 60'ND/60'TVD Out 497'MD/497'TVD Grade:2-2-WT-A-E-I-NO-BHA No geological samples taken for top hole section. Conn ' N i o MW9.0,yis3 0,PY24, YP k8,Fil 12, FC 2/.,pH 9.91 CI 1300 i I Conn I w . t , Conn — -— A Connection with Rig Watch o C.,cfnm 1 , 1 ( 444.93'MD. / Conn r 444.93'TVD __ -�_ 1 I _ _ _. —_INC 0.09°, AZI 182.97 Bit`s rr1,HDBS QHC1GRC r" Jet$:2216,2x14,TFA 0.6934 .l1449Z44D 149.2 - j - O41402'MD/1402'TVD z_ GGrrOe:b-8-ER-A-8-4-ER-PR �" 13_, GPM 300 cm S 3G-1 — o 74pQP RPM 61 0 ` i 501.22'MD. 4 rl 212('97'MD I 1 501.22'TVD 1. I - ' INC 0.09°, 5\ /i AZI 247.51 / •\ N ) C. I 5 ) ‹. -7 s � \ .nn f j 3 I r \ 4 i ( -, NMN 9.1.Vis 300, PV 45, 1I `' ,WI 45.Fil 12, FC 2/-,pH � J di 1�.2,CI900 < o -- _591.95'MD-.....-- ....--....., ....,--r--- - 591.94'TV L _TLLI j INC 0.25 -,1 1 1 AZI 235.81 It « . -- - — - N. ,_--- ---'---, I 11 • IM® l L 5 ) 1 --- MW 9.0,Vis 442, PV 45 ssa.2a'MD j YR 80,Fil 10, FC 3/-,pH 24'TV D INC 0.20', o INC 020 -> 0 9.3 CI 750 AZI 123.92 11 • t J r k `, 1 onn S 7 l i -, �: �.'‘-- { 1 I 777.79'MD. 1 777.79'TVD INC O.40°, co < AZI 68.51 o t,- -- - > Conn I Itt - MIN i 876.91'MD, c-- 876.91'TVD 5 ? INC 0.31', 'i oo AZI 39.69 �: I„,___,__. _,., 1nr.\ 101, 1 i 1 [ _• ., .: I A) — 7-- --/-=1--- i --t-------- --'--- 970.37'MD – – i I _ 4 _ I 970.37'TVD ' — / INC 0.45`.. 'sy=' I' AZI 55.23 9WOB GP,' 3590 J'.'., BG18 1 _R89 o i sI 2. - o I.__ i� { 065.90' MD —!' r-/ -- -- -. 1065.89' I —+- TVD i INC 0.64°, 1 AZI 63.97° ' 1 --- 0 \ - -- `= ' ( '3 • `J" � Conn I 4 I i I --t- --k- , { --- — --'t---- --„59.67' ac I _ MD, ( —.. —.— _ 1159.65' INC 0.41°, y TVD J AZI 108.42' N '.nn / 1.:, 11255.61 ( -> ( E – MD, 1 .1 111 1255.59' 17---' ( MW,•.3,/is 4 6,PV 63, TVD - INC 0.25, / YFl •,H 8, I- 2, AZI 0.25. ` 8.9, el 508 / w \ 5ArtI.2O12(1 0' . ..in o ' oI } I I 4, -°- _ I ` •( 1349.33 MD. 1349.30' s. Y MW •.3, is 3t5,Py 56, TVD i� 1 YP 5:,Fi 8, F�2/-,,pH INC 0.68°, 4 4 '\ 8.6, 'I 500 AZI 146.07 -c--- 1 1 I t -- . LI-112D , 0 Bit #2- EQ DBS H12D• 'I Jets: 16,1x14TFA 6. 394 Hrri 4A13/#d9V T•-a Out,2585'MD/2535' D ,1 Gra*1-1-NO-A-0°S-N O-DT F 1 r`; ( / 1439.27' cI �_ MD, ,' 1439.24' i I i —TVD INC 0.98°, ei AZI 164.46' 3 + F ) 9 WOB GPM ,'{'61 I BG 1 56ROP 106 o \ o ,\ I '�__'__._..I -F--', — - '( _1' - — i \ -I--- , _..,, I i \ ---- . / - - I - -,.., c t\ onn O / I � `` • L- 1633.92' ' 1 -- H - Mp <,' i I 1633.87' ;,. ; TVD -- a - -- - 1--- - — - INC 1.16°, i‘.,1 -- - AZI 156.33 '.:7"---- ' ) 1 :N --- -- l p i O I 1 - -- \ 3is3Wm" i —VP' iL • C-2/;,,l-pH- ‘, ',4-- i IP.. t� _9.0,�i 1 1728.23' -1--- '4____ i MD, -- S ---AI { 1728.15' TVD ` % 1 INC 1.44°, e ---{ ---�---AZI 173.03 r, i i 4 _ i ►Conn — – --- \ —+---- rI t o __.....-- ....-- ..... 1 1 1822.94' Z1- ' MD, .> It1822.83' --- — i-- - -- --- TVD �A iKIT2D1; 3�1ADj- ( -- INC 1.73 i I AZI 162.90 `Lam--- _.- - l i-- ---- - - --- --- ` -----.....I---:i "c-,„'Vr - I - - --1916.86' a'--, MD, 11::::c,....1 111916.71' TVD S - --, - INC 1.43°, BaseP frogt AZI 169.63` _ = -� - ,, ' - onn -- - -- r I 8W _ 'M42_1 0 BG 16 „ 4 . , • ,s_YlA 67E P 'PM 120 0 YP 53,Fil 1 0.4 FC /-, 3. :! pH .0,C1:00 2011.33' - - - - - MD, / 1 2011.15' ) TVD - _J — INC 1.64 - - -- - �— - AZI 165.75' { I I I { 1— — . r--_ 1 1 t/ p 2105.12' . i 1 MD, l —1--. r i -. _2104.89' TVD lI INC 1.91°, '..A. AZI 148.38' I i - 1 I Conn 1 i r � � N 1. :::-.2 j__' N.) 2199.93' •-' MD, \ 2199.65' TVD 7.:.::.4....., 1 INC 1.72, s AZI 148.53 I E 2::' 1 N 2293.56' _--1'i_s / 0 MD, =<-- 2293.23' := �� 1 TVD : I _INC 2.09 AZI 176.87 ' Chroma ogra h Flameout r I 2387.03' "--1,- N MD, ,..r--- ---- 0 2386.67' ::' < O TVD ;..� INC 1.10°, AZI 186.77 onn :,f_‘..Z } i-- I ` Chroma ograph Flameout ".? 2482.04' -, % MD, 3-V'003 )PM 431 al E3G 42 2481.53' g4t4i 1-'1M 125 0 I -- INC 1.5a`, r AZI 179.84 I. -Conn si_ — J_ 1 - --1 �- _7 - -- ----4 --'----L----• 2576.33' 7•ApriI2012( 85' • MW 9.2, s 301 PV 42, MD, s ! 2575.90' F601151lue to D t•• allure N) YP 52,Fi 10.4 FC 2/-, TVD fat#rr2414BS QH1 a_ pry t{•b, CI •U� -----------INC 1.68.. 7�c_qk+a 1 ie T . 90A AZI 180.25 FSrade� 3-W / fn▪ 258&'-MD7 25 �3 NlD- nn — —----- Ty--` e I :k?. `_k MW 9.3,Vis 354,PV 34, 2670.53' • '1 800 MD, f• pH 0O ert but TVD .06' _ ND ,i J ------- Jo INC 1.79, _--.....,-- .... AZI 175.33 o 1 Conn — — <_r I • -c 2764.75' i' j MD, 2764.24' 7.7 t TVD /�� Croma lo.raI h Flameout INC 1.46`, � Co AZI 173.39 o O Conn : .....f II 2860.14' i�MD, -?_ _ l 2859.60' TVDI INC 1A9°, = �; ' N AZI 183.63' C Conn 8 i__ i --- .1..„ __ i 1/4I • Ct ; I : 2954.21' �.? I C-4 MD, -t I2963.64 2953.64 __::..-- ND - I — ; — --i INC 1.31*, r� AZI 174.41 t a ,c.s B PM 418 co o $G 17 7.5-i,'-- _7t c) IJ -1— .:,':-.1-11 .- --< ' I . 3048.60' _r.� MD, ,, z, ---` -- — I— ;.-.,. — 3048.01' N I I INC 1Al°, z I_. -.---_ AZI 148.79 l _ corm co I o ' I • sI r I MD5.50' TVD 'I' INC 2.43`, AZ1 148.88` I -..7_ /? w ---!---- -- j4. MW 9 25,+Vi• 63, }-r� (� — - I H 9. I 50 1 MD0.86' A' j - — ' 3240.15'.15' --TVD- + i INC 1.53°, .- I j 1 j AZI 143.87' I1 I 1 ...` C.) ` i CO � t !- Base G,av 333 ` i M r __==-17.1.--E ---j, 3331.66' -- MDI 3330.91' <) 1 I I TVD }� I ! INC 1.72°, 3 AZI 143.12' s_ eca Gas system — ca L/ 1 C 0 r j I \+;. t _� 1 -' MD, t 3428.63' -s ._ —r---- I �ii -3427.85' - ', TVD INC 1.74°, s I — - -..� AZ1123.69° c -c-11 /-- I 6 W OB; I 436 BG 34 72ROP = 1) -' 1030 1 o CI roma ograph Flameout iI .-- 3522.00' — -- I I 3521.18' TVD mit. INC 1.42°, j AZI 140.75` 1 I `- ---- -_ P 744 U i 1 I w rn o 1 3615.80' 1 � E 3614.95' TVD E --- - t- - - — INC 1.48°, AZI 147.06` _ _ -11- I 1 __JI , - -1 I ` , -st ., f --- J ` _ O ,vZ_ Ir j ! 3709.29' MD, --"� -- --I----- ----+- — 3708.40' : --1- -t 1 --- .A_ -- i 4267.77' -- y MD, c- --.. -1 -r-- ---- -4266.82' Iii - TVD i INC 0.75°, CLYST:med-It gy,dk gy,occ `P;' t w ---____ _... I __.....---......--_..... AZI 183.11° brn gy,pred frm,r sft,sm-grty, �1 0 pred n Calc,tr sst. Conn I I Il I I _ CLYST:med-It gy,dk gy,occ -— _ - I-- I-- _.. �____ brn gy,pred frm,r sft,sm-grty, 4360.76' pred n calc,tr sst. MD, �-- ! , 435 .80' • - - - — ; 1-- — I. I- TVD I `. INC 0.90°, ,= ) AZI 189.54° A < k ------ p --_....-__.....____...-___..� 1 Conn 0 CLYST:med It gy,dk gy,occ — k--_ --- till .____.__— --_ � brn gy,pred frm,r sit,sm-grty, -f-- . n Calc. • 11111 T 4456.16' ) 4455. y l TVD 19 CLYST:dk gy,med gy,occ `? ® __ _T_ brn gy,pred frm,r sft,sm-rthy, INC 0.96°, '' 1 AZI 176.00° n calc,tr slt. 3_WOB` ) o I BG 10 -r 143Rt►P' _,i RPM 89 0 �� CLYST:dk gy,med gy,occ l I 01 i--5 I -_ ____ brn gy,pred frm,r sft,sm-rthy, ,; I amor,n calc,tr slt. __ I 4549.27' MD, P 1 1 4548.29' TVD 1111INC 0.96°, i - - I AZI 183.12` -- ------ Sgnn CLYST:med gy,occ brn gy, f r o __ pred frm,r sft,sm-rthy,amor,n 0 1 Calc,it grvi,tr pyr. � ' ) r i CLYST:med gy,dk gy,occ : ., ___ __ brn gy,pred frm,r sft,sm-rthy, L� 4644.12' _ amor,n Calc,tr grvi. MD, S i 4643.13' TVD Conn MW 9.c Vis 60PV 21, INC 0.750, i L v YP?ff Fi t6 4.FC 9,-, AZI 192.10° — ,1 r 1 o pH 10.7 1 1000 , CLYST:dk gy,occ brn gy, (.,-,tpred frm,sm-rthy,amor,n calc,abun grvi. S' 4738.04' _ MD, y I 1 4737.04' t TVD Ili :1-'- , INC 0.76°, AZI 181.52° —� IP. CLYST:med gy,dk gy,occ _ r brn gy,pred frm,r sft,sm-rthy. r — n amor,n calc. h4 Apr�I fi312 4786' 1• 1 A I� i I I ,, , 14832.50' CLYST:med brn gy,dk gy, i'—'— — -- -- MD, cc dk brn gy,pred frm,r sft,sm —t o i I 4831.50' rthy,amor,n calc,abun grvl. • �� ! �:••: TVD 1— INC 0.96°, L I AZI 310.10 ? I--'; ---r---_ -- — r---r - •'.-.----- -- 1 1 I CLYST:dk gy,med gy,occ dk ___ brn gy,pred frm,rr sft,sm-rthy. Iamor,n talc. e{ , ® ® 1 _ �_ _�__ 5396.62' /' op __. MD, 11111 5395.56' TVD ,s _ f INC 0.83 _ AZI 281.56' '; CLYST:pred med gy,occ dk brn gy,pred sft,sm-rthy,amor, nn n cal,sl tr sit i/p. ii 1 2f- glIl IIII 5 WO � GPM 549 /I t G 18 / 5491.12' CLYST:pred med gy,occ dk MD, gy-gy blk,pred sft,sm-rthy, 128RW RPM 79 0 5490.06' amor,SL cal. S I TVD `-sY �� INC 0.70°, �� �� AZI 278.77° -_ -_ Conn a CLYST:pred med gy,occ dk _) < - �' gy-gy blk,pred sft,sm-rthy, Z-, I ® �,,,1, amor,SL cal. 1 : MD, I . rn __ _ 5582.75' I r p ND r\ ` I,( INCAZI 1.11308.11°,° CLYST:pred med gy,occ dk gy-gy blk,pred sft,sm-rthy, Conn amor,SL cal. -.4t......-2>,-t, CLYST:pred med gy,occ dk II :678.34' 679.45' gY-9Y blk,pred sft,sm rthy. D, amor,SL cal. r I 1 o i VD 1r I p INC 1.27 1 t , IIIl31323 ' —Conn 1CLYST �.,��„�� :pred med 9Y,occ dk gy-gy blk,pred sft,rr frm,sm- I plst,amor,occ cal. I c� 111111111111111111 I1 ` IIIII!IRII5773.04' i MD 1 z 111 5771.92' TVD CLYST:med gy,occ dk gy-gy _ oo INC 1.19°, blu,pred sft,rr frm,sm-plst, N I _ p I AZI 305.28° amor,occ cal. Conn -••1 111111111 1 J ( u!ihI!11 ! amor,occ cal. 1 t conn . - I _ —� CLYST:med gy,occ dk gy-gy 1 + ____ blu,pred sft,rr frm,sm-plst, `-, - amor,occ cal. • f I t- - -- I - 5958.51' `� MD, ' 5957.34' CLYST:med gy,occ dk gy-gy I --r- TVD blu,pred sft,rr frm,sm-past, INC 120°, amor,occ cal. \r — AZI305.92° 4'WO i_ PM 546 o BG 9 imparp ocas g snoPMd o MW 9.1' Vis 4,PV 23, YP0,F 6.4, C 1 -, --r I-- pH 0.2, 1 150 CLYST:med gy,occ dk gy, r pred sft,rr frm,sm-plst,occ rthy,amor,v sl cal. ___ 6056.79' t i 4MD, 6055.57' `-tTVD , - i INC 1.08°, + AZ1298.09° -____ CLYST:It gy,med gy,occ dk _CBB,1 - __ gy,pred sft,rr frm,sm-plst, O amor,v sl cal. 1 ,.f 6150.00' CLYST:med gy,occ dk gy,rr I . ' + MD, dk brn gy,pred sft,occ frm, I NU.77 blky,sm-plst,amor,occ cal. sZ - INC 1.06°, -} - -- AZI 296.39° 15'Ap ,-• • ' ' onn cn o I COR 1 621+"Mi CLYST:med gy,occ dk gy,rr dk brn gy,pred sft,rr frm,sm- plst,amor,v sl cal. ' H ' 6244.05' 1� 1� ' MD, 6242.80' INC 1.19°, A21303.71° CLYST:med gy,occ dk brn 1--.s ► gy,rr sft,pred frm,sm-plst. - amor,occ cal. t s onn =_:;_ rn LC coO O _ , C IL jr________ It CLYST:dk gy,med gy,occ dk _ brn gy,pred sft,rr frm,sm-plst, I ,,--, Mp8'46 amor,occ cal. ` 6337.19' - TVD INC 1.30°, i c A21303.71° = , ,)-- 01111 1- - 1 ,, I i CLYST:med-It gy,occ med frm, 1 , o __.. plst,grthycamor,preocccal. sm I - 1 II ' - •. 't6431.25' I MD, 1 6429.96' '‘• 1 t. _ 1 1 /I I TVD CLYST:med-It gy,occ med INC 1.29`, wn ,, ,h .o a+. ° ' +- --- ___ -t AZI 306.57° ..,,,W''.,.. ,, 1 rthy,amor,occ cal. Conn i— 1 7WOB I- • .'• 14,11547ccr) BG14' 125ROP4. . RM 74 0 . 0 \ CLYST:medgy, --,:. --1- < -- - gy,occ pr df — _ occ med brn gy,rr sft,pred frm, �� ! 6525.92' sm-rthy,amor,rr cal. , MD, - - - 6524.60' Z ! TVD i INC 1.08', CLYST:dk gy,tr med gy,occ I �k I �1 I AZI 302.30 Conn _�, _ I- - sft,pred frm-hd,sm-plst, amor,v sl cal. 1 a, a, > CD 7 i —T- I ; 6620.53' MD,// -J 6619.20' CLYST:med gy,occ dk,pred ` - I - TVD sft,occ frm,sm-plst,amor,occ I ` t INC 0.92°, cal. I ` I ! AZI 297.70° \ 1 f; `= onn SKS \I ' r- 4_ � CLYST:med gy,occ dk,pred v I , sft,occ frm,sm-plst,amor,occ C p 1 cal. t, le k Cas t ine._J MD2.21' i 'MK2 6720' 6710.87' i \ 1 TVD S_- t - i INC 0.78°, \--,....__,I • ; ! AZI 299.14' T I I SST:pred brn yel-off wh,occ >'- _ Conn 1 clr,med f,occ v f gr,sb elg,sb _ R t I ang,mo-ply,srt,Ise,qtz.. ' I L \ GP209U ) I a 0o I 1 ,t - - Mp7 '6 CLYST:med gy,occ dk,pred 1 > II 6806.53' sa,.occ frm,sm-plst,amor,occ I TVD } 134U 1ii 1 INC 0.90°, AZI 293.99° UGINU 685 A I Conn f SST:pred brn yel-off wh,occ <1 �. 1 clr,med-f,occ v f gr,sb elg,sb ang,mo-ply,srt,Ise,qtz.. e.,1_c a) _ D -, _I -- o -- I 6901.88' / ! MD, ,'cr 6900.52' t I CII -- — TVD __ / -mai-\ III. INC 0.80°, AZI 309.80° SST:pred clr-yel brn,occ off -__ _ ----. -- wh,f-v f,occ med gr,mo,occ `', I- U.E. - w srt,Ise qtz. Conn e 1 4<< ! SST:pred clr-yel brn,occ off 6 WOB GPM 547 0G 92 I 6995.57' wh,f-v f,occ med gr,mo,occ 119ROP RPM 74 MD, w srt,Ise qtz. , 1 I Cele•nit, F !y- 2 GI.392 U / TVD .V I -- INC 0.74°, - I AZI310.58° - `_ ,onn - t - - -i i SST:pred clr-yel brn,occ off wh,f-v f,occ med gr,w srt, i _ I - ....r-- �— . occ w srt,Ise qtz. v •. 7091.25' - �- ' ` __..... MD, o f 7089.88' - TVD SLTST:It gy-med gy,occ bl INC 0.82', gy,pred frm-sft,amor-plst, i I An 310.08° hytd,grding v f sst i/p. onn t , ) C - f --4--- i 1 SLTST:It gy-med gy,occ bl \ gy,pred frm-sft,amor-plst, ,-- 7185.01' hygtd,grding v f sst i/p. t� s MD, W LAK i 19:L-MP No J , 7183.61' o TVD I t INc1301.878.704, 0.88°, AZI 317.74° c 1 Conn r__L 1 SLTST:It gy-med gy,occ bl gy,pred frm-sft,amor-plst, `_ ;� hygtd,grding v f sst i/p. I ;-i I I 1 MW 9.25,;Vis 0, PV 24, -� 1075,Fi 6.8,E C 21-, pH 0.3,CI � 150 1 7279.51'` MD, moi t , 7278.11' SLTST:It med w L i gy- gy,occ bl TVD gy,pred frm-sft,amor-plst, r <I, o INC 0.68°, hygtd,grding v f sst i/p,occ GD 2r AZI 307.66° TR CHT. _ -t I -__-:. onn _\ 1 l ' `''�1144-- SLTST:It gy-med gy,occ bl ` gy,pred frm-sft,amor-plst, -- hygtd,grding v f sst i/p,occ GD I ->I , ' 7369.74' TR CHT. <-I _ _ MD, 7368 r•�-' y TVD.33' v INC 0.93, ,—.,,,L----_______ -- - - �'p AZI 311.00° o t �t SLTST:It gy-med gy,occ bl 1 J con gy,pred frm-sft,amor-plst, 1, f hygtd,grding v f sst i/p,occ GD <<...r- _/ , TR CHT. �- r- �I }E _ y « _ SGait i stem _� _� __ I c'_'F 7467.40' I1'-` ! MD, SST:pred It gy-clr,occ yel 7465.99' brn,occ off wh,rr blk,f-v f,occ TVD med gr,rr crs,mo srt,prly srt CI-- INC 0.97°, i/p,Ise,qtz,n cmnt. 5,k03-,----� G= co BG 79. II AZI 311.23° ,99ROD > •PM 90 0 li==1'�� '�Conn `_ -- T - Gk125 U i ' SLTST:It gy-med gy,occ brn _ _+___ - __ gy,pred sft,occ frm,amor-plst, T. hygtd,grding v f sst i/p. I ‘-_-, I ' I � 1 - 7CgC 07. --LL - - ---- -- —__ 7555.44' i — TVD INC 0.97-, AZI 306.27° r }_ -=P SLTST:It gy-med gy,occ blu _�c.� o __-.....h.._...__._ ..._---.....---- I. � gy,pred sft,occ frm,amor-plst. - Conn O hygtd,rr grding v f sst i/p,dk gy 4_ � ` clyst i/p,n calc. • , L ` . `' j -- SLTST:It gy med gy,occ dk �_�_ 7656.43' gy,pred sft,tr frm,amor-plst, MD, dk gy sm clyst i/p,n calc. 7654.98' _ TVD — - I - INC 1.06°, AZI 314.14° -• I ---- ems} _......'_......,i_.....' —- SLTST:med gy,occ dk gy, _ pred sft,occ frm,amor-plst,dk L _ gy sm clyst i/p,grdng vr f sst i/p, _ `i�/ sl talc. + — --- j --�- - �-- ---- 1 7750.51' --.c, — ---- 7749.05' I TVD I INC 0.86°, SLTST:It-med gy,occ dk gy, ----__4�4�� - --- !- L_ - - AZI 318.53° pred sft,occ frm,amor-plst,dk MD gy sm clyst i/p,occ calc. lakirill- 5' Corn p +132Ui - %_ .- / SLTST:It-med gy,occ wh It ___I__ ----"1 gy,pred frm,occ sft,amor,sm, dk gy sm clyst i/p,grding v f sst - 7844.09' i/p occ calc. MD, 7842.62' l` TVD - �� 4 INC 1.09°, _ `yI ....•'''' AZI 316.28° -.nn SLTST:It-med gy,occ frm, 2 pred sft,amor,sm,med gy sm J o f clyst Up,occ Calc. v 7938.66' MD, 7937.17' CLYST:dk-med gy,pred frm, .' TVD occ sft,sm-plst,amor-rthy, — INC 1.10°, occ med gy sltst,v occ cal. _-` AZI 303.95° =s= .nn ,I 1 W OB--1 g--M 551 o BG 58 ' ,10gROP I RPM 94 0 — SLTST:It-med gy,occ gy blu, - ___ pred sft,rr frm,sm-rthy,med gy sm clyst Up,occ calc. ' 8032.03' <L. _ ' MD, • 16;Apr 120128046' D) - 8030.53' TVD s----1--\ INC0.96°, i I`- AZI 307.93° Z -MW 9.4,Vis 6 , PV6, �� onn -VP 46,Fil 5. FC 2I-, CLYST:dk-med gy,pred frm, L occ sft,sm-plst,amor-rthy, pH y./,CI 15 occ med gy sltst,occ cal. f 1 O - I I - �-- �-- ----T _ .... 1 8125.54' 2 MD, SST:trnsp-clr,occ dk gy- J - -- _8124.02' blk,f-v f gr,occ med gr,mo M85_ 'MD TVD srt,sb rnd-rnd,qtz,n cmnt,occ `` - _ -INC 0.97°,10.4 calc. AZI31O.43° J �- �_`1 Coriri ' �z --I - -- 8 --- -I-- - S Lx 11 SLTST:It-med .9....... gy,occ gy blu, co `t pred sft,rr frm,sm-rthy,med ,' I 0 1 gy sm clyst lip occ calc. 1 I - - — -- 1 8219.47' _ MD, 8218.26' -- .•- - +---.... __ND I - -- --- r-- INC 1.12°, 1- I AZI 299.81° ct CLYST:dk-med gy,occ brn _ r _ _--y...� gy,pred sft,occ frm,sm-plst, \ Conn \\I �- amor-rthy,tr med gy sltst,sl 1 I I \ cal. i I Ir o 1 1 CLYST:Itgy,med gy,occ brn ++ 1 8313.48 _ 1_ �- I __ -. -�. --+_ gy,pred sft,rr frm,sm,amor,tr 88 93, med gy sltst,sl occ cal. I- - --- I INC 122, ______7)_ TVD ---- I -t I AZI 285.32' II \ \ I SLTST:Med dk gy-med gy, _ __ \_ 1 t occ It bl gy,pred frm,occ sft, '1 / I amor-plst,hygtd,n calc. , •! _ 7. IJ 1 -_s 1 8407.63' 4-:- __,TI--) MD, !( _ T- I - — 8406.05' F. I ' INC1 f TVD I 1.23°, SLTST:Med dk gy-med gy, -_ V-__^___ AZI 279.10° occ It bl gy,pred frm,occ sft, __" s 1 amor-plst,hygtd,n calc. (, • onn 1 It - - - 1 ' --- SLTST:Med dk gy-med gy, 6 W B _ .PM 551 co cn BG 53 9Xocc It bl pred frm,occ sft, 91 P '�'M 92 o I 8502.56' amor-plst,hygtd,n calc. I I/': I ` 1 1 I j I i I SLTST:med gy,occ It bl gy, s ___ ___- —_ pred frm,occ sft,amor-plst, I _ hygtd,n caic. 8685.23' ? / i MD ✓ 18683.56' o ,I 1 1 ; __ __TVD I INC 1.73-, I I I, AZI 276.16° I --t 1 -r--- >L J i I i Conn �� 1 SLTST:med gy,occ It bl gy, _ pred frm,occ sft,amor-plst, \ jhygtd,n calc. IN ` 1I' +i+ I, - `� 1�� •- i I I i 1 1 k� 1 • I -F --i ---- ---- 8779.71' It- 1- t _,1_I MD,778.01' I ;o co I ` \ TVD SLTST:med gy,occ It bl gy, t oo I I INC 1.58`, pred frm,occ sft,amor-plst, i o ', 1 I AZI 284.33° hygtd,n calc,TR MICA,TR II PYR. .,' 1 I� 1 1 1 Conn (' i' I \ `\ 11lI _ — 11 1 '1 SLTST:med gy,occ It bl gy, i j ( 1 pred frm,occ sft,amor-plst, `'�l�\ hygtd,n calc,TR MICA,TR __ l j PYR. << _ ( .J 8875.83' ._�. B o :k Gas Line MD, I8874.83' oo �1'la TVD \ o (''i INC 1.43-, 1 + AZI 280.40° I;* l� 4 SwhT-Ityelgy,vf-fgrrsbmdoff ' I> onn . sb ang,n calc,n cmnt,v wk yel f`��j flor,slow wh dl yel cut,faint yel Ic '0)1 j I1 brn st. t r, '" 1I1 L� I l 1 '" 1 1 fo \ >1\ c-- *Ir':".-'::::-..,-.: B►owba;k Gas Line 8873 06, SST:transl-transp,rr opq,off _ I wh-It yel gy,v f-f gr,sb rnd, �c I MD' sb ang,n calc,n cmnt,No ' \ 8971,29' Show. ` I I TVD 8 WOB 1 _ G 543 0 BG 61 i INC 1.35°, 95RQP PM 90 o ! ► - AZI 278.18° __ Conn -r- ' ' 1k k-\---r—) , ; l'R/(1; /� j 1 SST:transl-transp,rr opq,off _ _ 1 wh-It yel gy,v f-f gr,sb rnd, - I -� sb ang,n calc,n cmnt,No •...;----•:::_"--24� t-- -� Show. ____� ! jSlovri It culatin Rate —9064.13' • s .4,Yis'6', PV 24, MD, I YJ�-��'j Fil R X21,---- 9062.34 _=�-` `�_ 5p -- TVD �1 INC 1.38 • co 1 AZI 284.60° SLTST:med-dk gy,occ It bl _i __ o i 1 I I 1 _ gy,rr blk,ooc frm,occ sft,amor )` o I -plst,hygtd,occ calc,tr mica. i Crohn ��� �� 51I,-. • I I I1 j- - SST:transl-transp,off-wh- __ _ �__.. __ ... _—___ —_ It yel gy,v f-f gr,sb rnd-rnd, • �� i id j r- 9160.95' sb ang,sl calc,n cmnt,No MD, Show. 9159.13' -- ------ - 1 �__�.- --TVD �_/� ( 11 INC 1.71', • AZI 295.11° • N_ I 1 Conn O _, �11\\ '�' (--' I ' ') ) 1 ) i SST:trans!-transp,It yel gy,rr __ _-- s- . .t _ blk,v f gr,sb rnd-rnd,sb sph, -, T) occ talc,n cmnt,No Show. I I1 — -- -- -.3_ l }-1 -- - 9255.18' —r -\ MD \ I 9253.31' , I I TVD SST:trans!,It gy,occ It brn,rr j____-_—__ blk,v f r,sb rnd-rnd,sb sph, — — 1 INC 1.79°, 9 P I AZI 293.34° occ calc,n cmnt,slty,No Show. I I I t11 w �. I (SI 7--T� Iji' • 1 1 r , ild Low flow rate SST:trans!,It yel gy,occ blk,v —^ f-f gr,sb rnd-rnd,sb sph-sb Conn • \ I j ang,sl talc,n cmnt,slty,No MW 9,4,*is 605 PV 25, 93447.08' Show. f< - - ---SEP-24,-ri . 5r 2/-, 9345.17' � pH, tC!11 r ( TVD : — INC 1.96°, €trvutifrwhit, •r." • pump ) / AZI 283.85° rate 6800 TH4,C1= ,� C librate Gas 17AprU12012 378' 1 D) 10.000% ( \ r4matograph POOH for MWD' -.•F n•e \ /t SST:It yet gy,occ trnsl,It brn t _ o \\ ‘� 9396.49' gy,rr blk,v f gr,shy,sb rnd- liN#5 NOV D-Q<61•l' 56 0 MD, rnd,sb sph,mo-w srt,n cmnt, Jets:6x13,TFA5).7 77 \ \,\\ 9394.55' v occ calc,No Show. In 9379'MD/V.176 TVD / TVD Out'MtE1/' 60+, 1 ) f — INC 1.78', Grade: xxxxx GP 177 U j I AZI 286.27° \, )5:55;Vis •,Py 23, d ' , i1. onn Q0-1C11,�2.3 — C t 1 t 1 SST:It gy,occ trnsl,It yel gy, J occ blk,v f gr,shy,sb rnd rnd, 19 Apr�12012 9463'M ; 1, I sb sph,mo srt,n cmnt,occ calc, No Show. f1 I — JJ I 4 W03 GP 535 BG 66 9490.19' D'19 `2RO R M 62 p iE( ; 9488.19' \ t• 1 INC 1.89°, SST:It brn gy,occ trnsl,It yel 0‘ r 1 -- AZI 296.31° gy,rr blk,v f gr,shy,sb rnd- r� 7 I t rnd,sb sph,mo-w srt,n cmnt, j / rr calc,rr pyr,No Show. Conn 1 \ ' I 1 l • I I I • ! 1 1 1 ✓ i I l I 1 f I C SST:It brn gy,occ trnsl,It blu gy,rr brn blk,v f-f gr,shy,sb j 9583.67' rnd-rnd,sb sph,mo srt,n G I 1 MD, cmnt,sl talc,tr pyr,No Show. \ -- 0 I 9581.63' i o fl I TVD a` o I I I) INC 1.79', I — -- ' t I I AZI 311.67° Conn I 1 \ I `1 I .1I f SST:It brn gy,It gy,trnsl,It blu gy,rr brn blk,v f-f gr,shy,sb <?-) • I rj rnd-rnd,sb sph,mo-w srt,n • I f cmnt,sl calc,rr pyr,No Show. I f i i —1-- - t , ...� 9677.88' J ? II 1 MD, I co1 9675.80' SST:It brn gy,It gy,It blu gy,rr I I TVD brn blk,v f gr,shy,sb rnd-rnd, 0 1 INC 1. 56', sb sph,mo-w srt,n cmnt,s1 ... I I 1 AZI 317.60° talc,rr pyr,No Show. l I — Conn -- -- > I ` ` I�l -- — I > i 1 I i )1, . 1 1 1 I 1 — - ? II 1 11 1 1 I t 1 SST:It brn gy,It gy,It blu gy,rr Li I ���. ! I re 1,14 „f nr If,' oFt mei-mil -t— c - - y ._ t__ ,___--.—___ V,1, . „„ , ° I y,,ally,0. -,, , I rl I I 1 sb sph,mo-w srt,n cmnt,sl ' I I I calc,rr pyr,No Show. c' 'I ! 9772.23' + -- =1 — . r - MD, I ,- II i 9770.12' I 1 1 • TVD co OD '' I) I _ INC 1.39°, r ---- 00 AZI 310.97° 1 t 1 R I • n j/ (, SST:pred clr-It gy,occ blk __ brn-ye brn, -transp,occ - -- ----i - - -- -----T-- I rn t , p T) - opq,v f-f gr,rr med gr,sb rnd- rnd,sb sph,pred Ise,occ calc r ( < I I I cmnt,NO SHOW. ri ( I 1' 1 1!' � 2 4 1 II -- — 1 J ,__ ., 7 — 9865.90' I ( f' MD, SST:pred clr-It gy,occ blk • ____ _ _ __� __.dL I_ _. 9863.75' brn-yel brn,transl-trans ,occ 7 �' ' .1) �; j— I— TVD opq,v f-f gr,rr med gr,sb rnd- 1 1 I INC 1.62°, rnd,sb sph,pred Ise,occ calc ti j I AZI 309.49° cmnt,TR LAM,NO SHOW. upJ �\ '- Conn I, If i - f e- -- -- ` II 1 r > t SST:pred clr-It gy,occ blk -`1- '11 .I 1 . —_ brn-yel brn,transl-transp,occ ( ( opq,v f-f gr,rr med gr,sb rnd- ` 1 rnd,sb sph,pred Ise,occ calc � /l 1 cmnt,TR LAM,NO SHOW. e Il T1— 1— —__ "'9959.71' 1i1MD, \` i 1 9957.53' j \ TVD ' il 1 INC 1.57°, i .? i‘ 1 AZI 316.84° SST:pred clr-It gy,occ blk 7 WOB G' 514 oo BG 33 I I) brnrnd,-yelsb brn,pred translIse,-traocc nspCalc,occ 79 ROFr c •"\rr o74 0 y 1 opq,v f-f gr,rr med gr,sb rnd- 0 I J sph, i I I cmnt,TR LAM,TR MIC NO t �— - - - jt --i- - SHOW. - 1 I 1 -- 1 ( 10053.83' SST:pred clr-It gy,occ blk c- --Fit"-T—— MD, brn-yel brn,transl-transp,occ 1 10051.61' \ opq,v f-f gr,rr med gr,sb rnd- c ` 1 ;l rnd,sb sph,pred Ise,occ Calc </ 1 1 TVD cmnt,TR LAM,TR MIC NO �r +}_..1 INC 1.77°, SHOW. t' —11 I/ AZI 316.63° i5-- 1 11 r ()nilo fI I� 0 \l hl 1 j� I � SST:It gy-med It gy,occ clr, _ 7 t I occ blk brn-yel brn,transl- ,1 transp,rr opq,v f gr,rr f gr,sb f / rnd-rnd,sb sph,pred Ise qtz, { �1 occ Calc cmnt,grding slt, /p,TR ` 1_ I .d LAM,TR MIC NO SHOW. C� ; 10148.52' �� !) i MD, T ti < 10146.26' si TVD I(1 • �� I INC 1.96°, SST:It med It gy gy,occ clr, 1 I AZI 298.32° occ blk brn-yel brn,transl- r 'q I transp,rr opq,v f gr,rr f gr,sb • :nn < rnd-rnd,sb sph,pred Ise qtz, I , �__ --- 0 1 occ calc cmnt,grding slt,i/p,TR 1 No 1 I I I LAM,TR MIC NO SHOW. L O E 1 1 --- --- I � I , � _ 1 - i A1I 1 L1 I SST:It gy-med It gy,occ clr, occ blk brn-yel brn,transl- i 1 I � 10241.70' transp,rr opq,o f gr,rr f gr,sb ,- i) MD, rnd-rnd,sb sph,pred Ise qtz, Ii 10239.38' occ calc cmnt,grding slt,i/p,TR ` - M - 12 P' 48;-- --- TVD LAM,TR MIC NO SHOW. , T 'Y �'1 'Fir 5. 1IFC 213, INCA1.8276°, ° -- I --SIn 1- 1 1 I I 1 SST:It gy-med It gy,occ clr, - --- o ) 1 9 _ _�_ occ blk brn-yel brn,transl- O I,i I transp,rr opq,v f gr,rr f gr,sb II ma-ma,so spn,prea Ise qtz, I r �, --- I I occ calc cmnt,grding slt,i/p,TR --_T- - i — --ii 4:; LAM,TR MIC,NO SHOW. 1 _t. I �, - - -J) - 10337.17 I "'-^ h MD, I •t i i I I ! 1 TVD 4.80' SST:It gy-med It gy,occ clr, —�—_—}f_)I INC 2.10.°, occ blk brn-yel brn,transl- v_ I --- transp,rr opq,v f gr,rr f gr,sb I I I AZI 276.19° rnd-rnd,sb sph,pred Ise qtz, 4 i occ calc cmnt,grding slt,i/p,TR — : n � + --�-- ',l ;- f- --- - —LAM,TR MIC,NO SHOW. l. 0 I rjo 1 3 I I j SST:It gy-med It gy,occ clr, -- _-_+-- — 1f / ' 1occ blk brn-yel brn,transl- 1`1 transp,v f gr,rr f gr,sb rnd- i i I I j 10429.66' rnd,sb sph,pred Ise qtz,v sl I I MD, calc cmnt,grding slt i/p,tr lam, T---T--_ -_�7 __-- -__...___-�__--. f + � I I I 10427.22' No Show. �c 1 ! j/ Il TVD INC 2.09°, ` t 1 ---- ---��. --------- - AZI 266.52° I � I t onn I SST:II gy-med gy,occ blk —_)..-- — i T______ brn-yel brn,transl-transp,v f ? I I gr,v hd-frm,rr f gr,sb rnd- `� _. rnd,sb sph,pred Ise qtz,v sl b WO3 GP' 509 0 EG 47 Icalc cmnt,grding slt i/p,it lam,tr I76ROD R•M 17 0 l mic ,No Show. r� o i ..>. ) ? / ?•ri 10521.56' MD, — I 10519.07' SST:dk-med gy,occ blk brn, I TVD occ transl,v f gr,v hd-frm,rr f jINC 1.76°, gr,sb rnd-rnd,sb sph,mo-w I AZI 264.36° srt,n talc cmnt,grding sh i/p, r- I occ lam,tr mic,tr pyr,No Show. jonn 1 1 1 i I 3` I 1 iI j SST:dk-med Ifgy,blk brn,occ �' _ C:-7:-:) ��J I transl,occ wh-clr,blk,v f gr,v r' hd-frm,rr f gr,sb rnd-rnd,sb /� ' I I sph,w srt,n talc cmnt,v calc I 10614.75' i/p,occ lam,tr mic,tr pyr,No 1 > I I MD Show. I 'I 10612.22' rl j TVD \ � 1 I (f INC 1.49-, 1 � I I AZI 266.51° si t I 1SST:dk-med gy,blk brn,occ i"' onn \\ , transl,occ wh-clr,blk,v f gr,rr \I i f gr,v hd-hd,sb rnd-rnd,sb sph,w srt,occ talc,abun lam, III _ I occ mic,No Show. r\ `r� h --t r - __ 1 i -4 o j 1 'NV1 10709.18' SST:dk-med gy,blk brn,occ Jt j UMDQ transl,occ wh-clr,blk,f-m gr, r� jqt TVD 10706.63' v hd-hd,sb rnd-rnd,sb sph,w srt,s1 calc,abun lam,tr mic,No L, l - , I INC 1.05°, Show. i I I AZI 252.31° / , I I i c, on m 1�r\1 I - I MV'q. �Vis 6 PV 19, �� YP-2$,Fil 5.4, C 2 2, SST:dk-med gy,blk brn,occ 'z'' - 911bu20 I __ transl,occ wh-clr,blk,f-m gr, I L ) I I I rr c gr,v hd-hd,sb rnd-rnd,sb 1 sph,mo-w srt,occ talc,occ • o - lam,occ mit,No Show. f r 0 ` I 1 I t 10806.49' i 1 � I ( 1 1_ -- --- -- - 10803.92' I = N\\\1 A TVD ` I I INC 0.98°, SST:med gy,occ blk brn,occ I s LLT-____. AZI 231.26° transl,rr wh-clr,blk,v f lint, gr, I P GP 157 U I l hd frm,sb rnd rnd,sb sph, 0 A r 12012�1 48' "' 1 1 mo-w srt,n talc,sl talc i/p,tr j I lam,tr mic,No Show. - i- - Il -� T I l i- o ` �� SST:dk-med gy,blk brn,occ 1 `_ I trans!,blk,v f-f gr,rr m-c gr, _ ' o 1�� 70901.00' hd frm,sb rnd rnd,sb sph, i MD, mo srt,n calc,tr lam,tr mic,No 1 I I 10898.43' Show. t -- — I - --- - TVD INC 0.57', II 3- ! I I I I AZI 221.52 +- - r-- -- --+ r_ - onn i I i � SST:dk-med gy,blk brn,ooc _-�-_— blk,v f-f gr,hd-frm,sb rnd- I ,-- - 11 I -- rnd, sph,mo w srt,n Calc, s , IR I ` ,�i I grdng sit i/p,rr lam,No Show. I- ,,..> -t— h2 WOB__I\' G' 506 0 1111 $G 81 .W 1111 , 10994.71' (76R6p _-v 5 0o I ---MD, I i 10992.14' +, t, 1 I I TVD SST:med gy,occ It gy,blk ��_ -T— 4-___, ' t_ r___ -__ INC 0.20', brn,ooc blk,v f-f gr,rr m gr,v �) I AZI141.64' hd-hd,sbrnd-rnd,sbsph,mo ` -w srt,n calc,tr lam,tr mic,No ,< -onn — -i - I t Show. < I ( if `� fI t .c- JI \- ! t 1 f 11088.97' 1 f-- ------- -7 -) 11086.40' - i o 1 TVD INC 0.44 , 1 )I j AZI 225.29 :on , 1f n Chromatograph ROP 5 p Lagged Gas Hydrcbn Max Gas Analysis p 300 ft hr 0 N m 0 units (ppm) 0 Lithologic I-0 r-� 13 Methane - �• —' — -I Gas ----- Gamma -*� �� Avg Ethane 0 api 150 0� 0 — I 0 units 1K Propane — = Descriptions p- p MD Total Butane ------ MW In w WOBNormalized Gas C 0 klbs 40c42 Cl) � (1,-. . 0 units 1K Total Pentane --- 7 ppg 13 < 10100 1K 10K100KM Remarks RPM Density a 39in Phase Resistivity PWD Annular EMW N 0 rpm 200 -g cc:' fD 0 ohms 1R 9 ppg 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 other 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. 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. _ A ill HALLIBURTON INSITE DIRECTIONAL SURVEY REPORT Savant Red Wolf 2 Badami AK USA AK-XX-0009110182 All depths reference the drfller's pipe tally. Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 220.69 0.12 106.15 220.69 0.07 S 0.23 E -0.07 0.06 444.93 0.09 182.97 444.93 0.30 S 0.45 E -0.30 0.06 501.22 0.09 247.51 501.22 0.36 S 0.41 E -0.36 0.17 591.95 0.25 235.81 591.94 0.50 S 0.18 E -0.50 0.19 684.24 0.20 123.92 684.24 0.71 S 0.14 E -0.71 0.41 777.79 0.40 68.51 777.79 0.68 S 0.57 E -0.68 0.35 876.91 0.31 39.69 876.91 0.34 S 1.07 E -0.34 0.19 970.37 0.45 55.23 970.37 0.06 N 1.53 E 0.06 0.18 1065.90 0.64 63.97 1065.89 0.51 N 2.31 E 0.51 0.22 1159.67 0.41 108.42 1159.65 0.63 N 3.10E 0.63 0.48 1255.61 0.25 107.44 1255.59 0.46 N 3.63E 0.46 0.17 1349.33 0.68 146.07 1349.31 0.07 S 4.14 E -0.07 0.54 1439.27 0.98 164.46 1439.24 1.25 S 4.64 E -1.25 0.44 1538.19 0.79 153.96 1538.15 2.67 S 5.17 E -2.67 0.25 1633.92 1.16 156.33 1633.87 4.16 S 5.85 E -4.16 0.39 1728.23 1.44 173.03 1728.15 6.21 S 6.38 E -6.21 0.49 1822.94 1.73 162.90 1822.83 8.76 S 6.94 E -8.76 0.43 1916.86 1.43 169.63 1916.71 11.26 S 7.57 E -11.26 0.37 2011.33 1.64 165.75 2011.15 13.74 S 8.11 E -13.74 0.25 2105.68 1.73 160.28 2105.45 16.39 S 8.93 E -16.39 0.19 2200.42 1.76 163.63 2200.15 19.13 S 9.82 E -19.13 0.11 2294.55 1.80 168.48 2294.24 21.97 S 10.52 E -21.97 0.16 2388.22 1.60 175.15 2387.86 24.71 S 10.93 E -24.71 0.29 2482.04 1.54 179.84 2481.65 27.28 S 11.04 E -27.28 0.15 2576.33 1.68 180.25 2575.90 29.93 S 11.04 E -29.93 0.15 2670.53 1.79 175.33 2670.06 32.78 S 11.15 E -32.78 0.19 2764.75 1.46 173.39 2764.24 35.44 S 11.41 E -35.44 0.35 2860.14 1.49 183.63 2859.60 37.89 S 11.47 E -37.89 0.28 2954.21 1.31 174.41 2953.64 40.18 S 11.50 E -40.18 0.31 3048.60 1.41 148.79 3048.01 42.24 S 12.20 E -42.24 0.65 3145.50 2.43 148.88 3144.85 45.01 S 13.88 E -45.01 1.05 3240.86 1.53 143.87 3240.15 47.77 S 15.68 E -47.77 0.96 3331.66 1.72 143.12 3330.91 49.84 S 17.21 E -49.84 0.21 3428.63 1.74 123.69 3427.85 51.82 S 19.31 E -51.82 0.60 3522.00 1.42 140.75 3521.18 53.50 S 21.22 E -53.50 0.60 3615.80 1.48 147.06 3614.95 55.42 S 22.61 E -55.42 0.18 3709.29 1.61 132.62 3708.40 57.33 S 24.24 E -57.33 0.44 3894.01 1.03 176.53 3893.08 60.74 S 26.24 E -60.74 0.61 3985.16 1.00 183.68 3984.21 62.34 S 26.24 E -62.34 0.14 4079.58 0.79 190.18 4078.63 63.80 S 26.07 E -63.80 0.24 4171.88 0.83 185.50 4170.91 65.09 S 25.90 E -65.09 0.08 4267.77 0.75 183.11 4266.79 66.41 S 25.80 E -66.41 0.09 4360.76 0.90 189.54 4359.77 67.73 S 25.64 E -67.73 0.19 4456.16 0.96 176.00 4455.16 69.26 S 25.58 E -69.26 0.24 4549.27 0.96 183.12 4548.26 70.82 S 25.59 E -70.82 0.13 4644.12 0.75 192.10 4643.10 72.21 S 25.41 E -72.21 0.26 4738.04 0.76 181.52 4737.01 73.43 S 25.27 E -73.43 0.15 4832.50 0.96 310.10 4831.47 73.55 S 24.65 E -73.55 1.65 4'JLO.`JJ u./9 JUU_J`J 9`JL9.tJ`J IZ.(J J L - -/L./J U.LC 5021.04 0.74 s, 5019.99 72.08 S 22.48 E -72.08 0.05 5114.95 0.92 302.86 5113.89 71.33 S 21.35 E -71.33 0.18 5209.01 0.83 285.28 5207.94 70.74 S 20.06 E -70.74 0.30 5302.27 0.64 276.49 5301.19 70.50 S 18.89 E -70.50 0.23 5396.62 0.83 281.56 5395.54 70.31 S 17.70 E -70.31 0.21 5491.12 0.70 278.77 5490.03 70.08 S 16.46 E -70.08 0.14 5583.84 1.11 308.11 5582.73 69.44 S 15.19 E -69.44 0.66 5679.45 1.27 313.23 5678.32 68.14 S 13.69 E -68.14 0.20 5773.04 1.19 305.28 5771.89 66.87 S 12.14 E -66.87 0.20 5868.19 1.29 309.96 5867.02 65.61 S 10.52 E -65.61 0.16 5958.51 1.20 305.92 5957.31 64.40 S 8.97 E -64.40 0.15 6056.79 1.08 298.08 6055.57 63.37 S 7.32 E -63.37 0.20 6150.00 1.06 296.39 6148.77 62.57 S 5.78 E -62.57 0.04 6244.05 1.19 303.71 6242.80 61.64 S 4.18 E -61.64 0.20 6338.46 1.30 303.71 6337.19 60.50 S 2.47 E -60.50 0.12 6431.25 1.29 306.57 6429.96 59.29 S 0.76 E -59.29 0.07 6525.92 1.08 302.30 6524.60 58.19 S 0.85 W -58.19 0.24 6620.53 0.92 297.70 6619.20 57.36 S 2.27 W -57.36 0.19 6712.21 0.78 299.14 6710.87 56.71 S 3.46 W -56.71 0.15 6807.88 0.90 293.99 6806.53 56.09 S 4.72 W -56.09 0.15 6901.88 0.80 309.80 6900.52 55.37 S 5.90 W -55.37 0.27 6995.57 0.74 310.58 6994.20 54.56 S 6.86 W -54.56 0.06 7091.25 0.82 310.08 7089.88 53.71 S 7.86 W -53.71 0.08 7185.01 0.88 317.74 7183.62 52.75 S 8.85 W -52.75 0.13 7279.51 0.68 307.66 7278.11 51.87 S 9.78 W -51.87 0.25 7369.74 0.93 311.00 7368.33 51.06 S 10.76 W -51.06 0.28 7467.40 0.97 311.23 7465.99 49.99 S 11.98 W -49.99 0.04 7556.87 0.97 306.27 7555.44 49.04 S 13.17 W -49.04 0.09 7656.43 1.06 314.14 7654.98 47.90 S 14.51 W -47.90 0.16 7750.51 0.86 318.53 7749.05 46.77 S 15.60 W -46.77 0.23 7844.09 1.09 316.28 7842.62 45.60 S 16.68 W -45.60 0.26 7938.66 1.10 303.95 7937.17 44.44 S 18.05 W -44.44 0.25 8032.03 0.96 307.93 8030.53 43.46 S 19.41 W -43.46 0.16 8125.54 0.97 310.43 8124.02 42.47 S 20.64 W -42.47 0.05 8219.79 1.12 299.81 8218.26 41.49 S 22.04 W -41.49 0.25 8313.48 1.22 285.32 8311.93 40.77 S 23.80 W -40.77 0.33 8407.63 1.23 279.10 8406.05 40.35 S 25.77 W -40.35 0.14 8502.56 1.27 273.96 8500.97 40.11 S 27.83 W -40.11 0.12 8594.76 1.52 275.02 8593.13 39.93 S 30.07 W -39.93 0.28 8685.23 1.73 276.16 8683.56 39.68 S 32.62 W -39.68 0.23 8779.71 1.58 284.33 8778.01 39.21 S 35.31 W -39.21 0.29 8875.83 1.43 280.40 8874.09 38.66 S 37.77 W -38.66 0.19 8973.06 1.35 278.18 8971.29 38.28 S 40.10 W -38.28 0.10 9064.13 1.38 284.60 9062.34 37.85 S 42.22 W -37.85 0.17 9160.95 1.71 295.11 9159.13 36.94 S 44.66 W -36.94 0.44 9255.18 1.79 293.34 9253.31 35.76 S 47.29 W -35.76 0.10 9347.08 1.96 283.85 9345.17 34.82 S 50.13 W -34.82 0.38 9396.49 1.78 286.27 9394.55 34.40 S 51.69 W -34.40 0.40 9490.19 1.89 296.31 9488.19 33.31 S 54.47 W -33.31 0.36 9583.67 1.79 311.67 9581.63 31.65 S 56.94 W -31.65 0.54 9677.88 1.56 317.60 9675.80 29.73 S 58.91 W -29.73 0.31 9772.23 1.39 310.97 9770.12 28.03 S 60.64 W -28.03 0.26 9865.90 1.62 309.49 9863.75 26.44 S 62.52 W -26.44 0.25 9959.71 1.57 316.84 9957.53 24.66 S 64.42 W -24.66 0.22 10053.83 1.77 316.63 10051.61 22.66 S 66.30 W -22.66 0.21 10148.52 1.96 298.32 10146.26 20.83 S 68.73 W -20.83 0.66 10241.70 1.86 279.41 10239.38 19.83 S 71.62 W -19.83 0.68 10337.17 2.10 276.19 10334.80 19.39 S 74.89 W -19.39 0.28 10429.66 2.09 266.52 10427.22 19.31 S 78.26 W -19.31 0.38 10521.56 1.76 264.36 10519.07 19.55 S 81.33 W -19.55 0.37 10614.75 1.49 266.51 10612.22 19.76 S 83.96 W -19.76 0.30 10709.18 1.05 252.31 10706.63 20.10 S 86.01 W -20.10 0.57 10806.49 0.98 231.26 10803.92 20.89 S 87.50 W -20.89 0.39 10901.00 0.57 221.52 10898.43 21.74 S 88.44 W -21.74 0.45 10994.71 0.20 141.64 10992.14 22.22 S 88.65 W -22.22 0.61 11088.97 0.44 225.29 11086.40 22.60 S 88.81 W -22.60 0.49 • CALCULATION BASED ON MINIMUM CURVATURE METHOD 'UKVLY UUUKUINAItS KtLAIIVt IU WtLL SYSItM KtttI1t I'OINI TVD VALUIVEN RELATIVE TO DRILLING MEASUREMEN' INT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES(TRUE) A TOTAL CORRECTION OF 21.68 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE)AT 11088.97 FEET IS 91.64 FEET ALONG 255.72 DEGREES(TRUE) Date Printed:20 April 2012 STATE OF ALASKA AL, .A OIL AND GAS CONSERVATION COMMi. .ON o.?-Q,-R PERMIT TO DRILL 20 MC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ lc.Specify if well is proposed for: Drill ❑✓ Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory 111 Service- WAG 0 Service-Disp 0 Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: Savant Alaska, LLC Bond No. LPM8945440 Red Wolf#2 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P. O. Box 112212,Anchorage, Alaska 99511-2212 MD: 12,100' TVD: 12,100' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Badami Field- Kekiktuk Pool Surface: 1350'FSL,4363'FEL,Sec.36,T1ON,R19E ADL 367005 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1350'FSL,4363'FEL,Sec.36,T1ON,R19E N/A 3/6/2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1350'FSL,4363'FEL,Sec.36,T1ON,R19E 3,840 1,350' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 30.5' 15.Distance to Nearest Well Open Surface: x=349,352.23' y- 5,914,756.19' Zone-3 GL Elevation above MSL: 2 to Same Pool: N/A 16.Deviated wells: Kickoff depth: N/A feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) z/ts/; Vertical Well Maximum Hole Angle: N/A degrees Downhole: d.,t Surface: . e$rr 3903 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) 24" Conductor." 91.1# H-40 welded 80' 30' 30' 110' 110' 260 sxs Arctic Set 12 1/4" Surface eltZ 47# L-80 BTC 4522' 28' 28' 4550' 4550' 707 sxs Arctic Set III,205sx"G" , 8 1/2" Intermediate/" 26# L-80 BTC 11499' 26' 26' 11525' 11525' 155 sxs"G" . ..4•56A, Liner Li,5" 12.6# L-80 IBTM 720' 11350' 11350' 12070' 12070' 67 sxs"G" . 19. "It PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat LIBOP Sketch Q Drilling Program ❑✓ Time v.Depth Plot Q Shallow Hazard Analysis Diverter Sketch❑✓ Seabed Report E Drilling Fluid Program Q 20 MC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name Erik A. •.stad Title Drilling &Wells /�Signature Phone 907-244-5210 Date 8-Feb-12 401111117,:/7 Commission Use Only Permit to Drill / API Number: Permit Approval See cover letter for other Number: O,va e - 50.0a? .A34145-0. 04 Date: 5\`G�\k. requirements. Conditions of approval: If box is checked,well ma not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in sh es: Other: _ 11t/00 /05t. 13a/ Samples req'd: Yes No Mud log req'd: Yes No 0 r G -L H2S measures: Yes No❑ Directional svy req'd: Yes No❑ Sep"t x—2.- S—u-.-24.7 re-8,...,..tj in, Fro C.) 11-441. er.„..9 re..4. S:t;1,......toLebh • APPROVED BY THE COMMISSION DATE: 3 /'7/Z ale,ti ---__ ,COMMISSIONER Z/x 1P2- 0(2- V ORIGINAL Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate RECEIVED Savant Alaska, LLC FEB 0 8 1017 SAVANT P.O. Box 112212 Anchorage,AK 99511-2212 Alaska Oil &Cas Cons. Commission ALASKA Tel: 907-868-1258 A�.� orae Fax: 907-868-1455 N February 8, 2012 Dan Seamount, Commissioner Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Submittal of Savant Alaska LLC. - Permit to Drill Application— Red Wolf#2 Badami Unit Mr. Seamount: Savant Alaska, LLC has obtained all other federal, state and local permits and authorizations required to drill its Red Wolf#2 Exploration/Delineation well located within the Badami Unit. We now seek to complete the permitting process for that project through its Permit to Drill (PTD) application to the Alaska Oil & Gas Conservation Commission (AOGCC). To that end and in accordance with 20 AAC 25.005, Savant Alaska hereby submits Form 10-401 and 10-402A with their respective attachments for consideration and approval to the AOGCC. Savant expects to start drilling operations on or about March 6th, 2012 drilling from a 500' x 500' ice pad located approximately 3.5 miles west northwest of the main Badami CPF Pad. Please call me at (907) 244-5210 should you or your staff need any additional supporting materials for this application or wish to discuss any aspects of this submittal. Sincerely, SAVANT ALASKA, LLC Erik A. Opstad Drilling&Wells Group Cc: Greg Vigil,President Savant Alaska LLC Gary Hammon,Savant Drilling Manager Steve Rog,HSE Manager Savant Zane Henning,Badami Facilities Manager NOTES: PROJECT 1. COORDINATE DATUM IS NAD27, ALASKA STATE PLANE ZONE 3. BEAUFORT SEA AREA 2. ELEVATION DATUM IS M.S.L. HARRISON BEECHEY 3. HORIZONTAL AND VERTICAL CONTROL IS BASED ON THE BADAMI BAY alfusdho.! POINT FLAXMAN - _ —BARTER OY - ISLAND ISLAND PIPELINE R.O.W. MONUMENTATION. PRIMARY MONUMENT #54. NPRA _ Koktov 4. THE ENTIRE COASTLINE, SAGAVANIRKTOK, PUTILIGAYUK, KUPARUK 'I : " i ,104 RIVERS AND ALL MAN MADE FEATURES FROM TOWNSHIP 10N TO n/i.t / - THE NORTH AND FROM RANGE 20 TO THE WEST WERE DRAWN T fox` c FROM THE UNIT OPERATOR'S 1:6000 MAPS, 1973PHOTOGRAPHY 5 t u MOUNT DEMARCATIONS WITH PERIODIC UPDATES THROUGH 1993. UMIAT SAGAVANIRKTOK tMICHELSON— POINT 5. ALL SECTION LINE ARE UNSURVEYED AND UNMARKED LOCATIONS , I In.\ PLOTTED FROM B.L.M. DATA. > 6. DATE OF SURVEY: FEBRUARY 05, 2012. il / I ANWR 7. FIELD BOOK: MI12-01 PGS. 55-57. ' ,. LEGEND VICINITY MAP N.T.S. 4- AS-STAKED WELL LOCATION LION PI'INT I 8 9 10 12 I 7 8 9 I WEST 'IKKELSEN 17 16 15 14 13 in.-S 'TE 2' 18 17 QJ GOOSE ISLA!,D TIC •DIAK 16 WEST ISL D ',ITEM': BAY 4 RELIANCE FOINT 20 21 22 2324 - 19 20 21 C E WEST 0 VTT ELcc" BAY 3 Wmw .- N 29 28 225 �I� 30 29 28 RAlli FRED •WOLF #2 — IIIII — l// // / /// // MIKKELSEN BAY 32 '\ 33 A„,.. /4( 38 31 32 33 . A� ,1 r J !j// / 5 4 b. 2 1I 6 5 4 44t16 �I��, �,--„.. , :ADAMI 8 � _ I� „ I N, � GRAPHIC SCALE \\ I (� 0 4,000 8,000 16,000 17 16 ��l NI/ MIKKEL BO STATE 1 17 16 ' • 1 inch 8,00Ht. LOCATED WITHIN PROTRACTED SEC. 36, T. 10 N., R. 19 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC TUN SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEV. OFFSETS Y= 5,914,756.19 N N/A 70'10'27.238" 70.1742328' 1,350' FSL RW #2 X= 349,352.23 E N/A 147'12'45.791" 147.2127197' 4'S 4,363' FEL F. Robert-- , DRAWN: KWH WANT �` CHECKED: jj F j t DATE: /� /� `' )> DRAWING 12 L"A FRB12 RW2 01 SAVANT ALASKA SHEET: o assoc1 oe NC, AS—STAKED WELL LOCATION 1 OF 1 x .x x SCALE: 00 2/06/12 ISSUED FOR INFORMATION KVM JJ wc�cws.xo� ow .ws RED WOLF #2 .VEST fIREVEE0 LANE NO. DATE REVISION BY CHK xwaMAa. uww. ,,,, 1 = 8000" 27 ,l r y 711.1�TN• ,I • Sb• c � • ttN. 0 I ei i J RW-#2 Ice Pad I 31 \ • ..111"11H.:-.1...")' Location 500' x 500' I 1 �'`-�' f I �� • SEE FIG.6c �� As-Staked Ice Road BURP TWRT1OE j I `r,�- 4 ► - '- --1-t?-)-- - TO9E • T10E6 _ -1 '`j---‘.-- - — ,`j - �� ., ' • TO9E i) �'� I fi• • \1 )( 111 • -, Shaviovik(Shell) Pit 4, { A2008-177 6 f 1 2 1 3i •/,? Y 1 1, . ',-7 ' , ,Shaviovik k. 1 , ),% Mine Site I : ' Badami Ice Road i k N . • %., 11 • -. Unnamed Lake 18 ' . A2008-178 11 , - , ..? \' L. It \ /19,...../, '''' 1.1..* -''. . , ' • , , _ - --- -"O-•- Alternate Ice Road BURP TWR -- SA ANT I Proposed Ice Pad ALASKA s As-Staked Ice RoadBURP TWR BADAMI UNIT -a - Alternate Ice Road BURP TWR REDEVELOPMENT PROJECT (BURP) I I Permitted or Amended Water Source RED WOLF - #2 2011-2112 �, PROJECT LOCATION MAP 0 1,000 2,000 4,000 DATE: SCALE. FIGUREMINI : t Feet November 2011 1"=2000' 6b I Iti\ 'i 1p16005 mxd OIL DISCHARGE PREVENTION AND CONTINGENCY PLAN -_-----•NOP.TN ———- • J J___ ' WET MI • • • r 10D 70 UTH c WIND SPEED(m/s) I Figure 1.6-4 _ SA ANT Mean Badami Wind Rose for February ALASKA 10/18/09 Rev.2 Part 1-65 SA ANT I ALASKA BADAMI UNIT ' REDEVELOPMENT PROJECT (BURP) II RED WOLF #2 ADL367005 PROPOSED ICE PAD LAYOUT 0.3 i DATE: SCALE: FIGURE: February 2012 1" =200' 6c PROPOSED 500'x 500'ICE PAD FACILITIES SHOWN ARE APPROXIMATE LOCATIONS AND SIZES. 0.4 0 200 400 Feet I i I I x I 2.1 N \\ 2__\ . 11.2 • 4.9 _ g5„,0?4 8 MEoN & ',._ Wind Mean Badami nd Rose.' 2.5 O 4F NOP S for February X _ O\r�\s I \-----111101- v DIVERTER ,_� LINE ops S - _ \ ZC WELL ' '\ \\\ LP 1 N \ oyG SNP�B‘NS \\ 2.1:- 4° \Ts SPNNEX \ / G0 xl 3.4 1.2 x 0 • -0 1.4 N C. 73 0 v ----\_ _ D.8 -0.4 x ip 16005p_fig6c_rev2.mxd gg g E i it 11 g s Z gieh W % .- Z / a_ a a R w a ce g4 E E' S 1 i 1 gI g w, '11 ri a3� x - J,� Z UllI '! : 1 ■A a illi o tL A A-,..vK cri A a == A _ woe 11110Nkomo 1 .0 .1,/1 „..., .0 .0 1 _ „,,,. == . • v V -.. �_��, A \_ �IH1''r� 1/ 1111 Lg > g 3 .Z/l 9 4 .9/1 0l.9 .9/c 9.i .9/[9l.1 .9/0 0.l .9/0 C.91 V_ 1 -PIC.., i_ vT N • cam., I I2 C) Im r a I111 rri m I II JAL AnLJ � L A MI • . a y X ', nt __, 0 a r m Oy a1CO —_� I— 1 I __ ___'_.-1 ' r - n can ["---- C 23 a v • E 0 HRI ".41 t2T �u � -1 I--IL Z '� S ' � `" C) o I c-, N Cr a Ir- o rrl rr I I o 0 rCoA. 3P2r-- „„......1— 111 �W��rZ cn S g 8 if iir. CM rinacn „n0o\o =��� � 'V2 P$ z0 m O `0, it C1z`='O0 m-0=cn O � p -<o �� i 2n�cr C)�p p0 1� v /\ Q CO y a __ Kip 0 -P 111111111111111111 Z z * w O m O - n� w w p w p Z co 2 a 3 — r D � co - v v m m -1 m m C m CD C _ -' , Q X 'Z5- v a - CP CrUi cp cylC) -a N c7 p O Q. U1 O O a 0 _. t 0 O O O O C) O O -, O (On c vv O — 0 0,.) Ct . CO 6 o Q 0 m m 0. v .41 =MN cQ „ = a ii O CO O m � 6-7-^ W r 1 • m 4 4 y -♦` ® 8 o rn ® 1. 1 t Cl) ,4 8 11 W .11-1j \ ,, 1i►1 "p ie �' s. 11, A0 �� 0. i I ‘co N O II a \itt , cn H H\ . [1 5" 0 ---I Ce94 ' - v � N C YU Q @ C7 O 00 CD 0O a \ cD 0 r O O Q LI) O • ADDITIONAL INFORMATION 1. MUD LEG I.D. 10„ I.D. 2. TOTAL LENGTH OF U-TUBE PIPING 34 L.F. 3. TOTAL NUMBER OF BENDS IN U-TUBE 6 TOTAL 4. ANGLE OF BENDS IN U-TUBE (45,90,180) 5 @ 90° - 1 @ 45' 5. VENT LINE HEIGHT ABOVE GROUND LEVEL 43'-7 1/2" 6. VENT LINE I.D. 10" I.D. 17'-8i" 0,,111 Nabors Alaska A NABORS INDUSTRIES Company NABORS RIG 7ES MUD GAS SEPARATOR PRODUCED BY: JOE ALSTON SEPTEMBER 6, 2005 8'-6" 29.25" I.D. U-TUBE PIPING 90° 90° 90° FROM CHOKE , 3.438" 1.D. - 45° .D. J45° 7'-10-" 11 '- 1 " 90 90 G.WOC(.y...00 mfl*I-o..n,r\1-O.,.R\1/Ver:Pl.OIGa.y 1/14/1011 1:43 n. 1 (1U ME ,"0zi II a 71"7"1' z m m $ N 0-g `ii CI / ias gy /, ". -pbo 44, . PN Pd- V 3- . om l'.a tom A� \ W 2-V)1 C ,0 C Z I�F��� ii Li CD 2 Ni \ mi;— • i' + -N-. 23 O O 1•I • H \ ) N 0', N gm• MI Sl \ ti,TI _ �"_ 01` PJ l \ .,, co 'RI rri .1 N _�P7, rn 7. N`'i), N 03°r°of'a J J Li)Z Pd M CO rn ©moN""—Q3 v r Z� 1 r L„ „.:,,_.-.1,..1-- ..... I LI. ,..; -_, .r.)--,,..., (tt+ 7o ° p N 2 Z mM 1 / Z) N -I1 V CO UAW,0 V T N 1 m1 1 1 1 11 1 1 1 01�� GGGS55% 11 : -12 " 11 m -1 2 = O i i C fTl s 0 A WI _ z 3 D 0 0 v r 1, in � w w w U 4 , . o 4. . m “ - L. QPJ ( d�/`� 0. • p• er — E O C S o§ $ O O -Q 'O i•1 i i T, iii r.", -,r, = = i..5-1Z lc = 1 ,9 rPl C$Ac• In n N o 1s� a 8 71 i 0 0,..k. tab cd 1 0 1 X Z 1kfikt 8r4'`'Tnil ....0 `► ti 1 Drill Floor to Sea Level 32.6' Referenced to Nabors Rig 9ES Drill Floor to Tubing Hanger 24.0' Referenced to Nabors Rig 9ES OD ID Weight Length MD TVD Ground Level to Sea Level 2.0' Wellhead 11"/5,000 psi- FMC inch inch Lbs/ft ft DF(ft) DF(ft) J L Tree 4-1/16"/5,000 psi-FMC Conductor 20.000 19.124 91.1 80 110 110 '4-TAM 9-5/8"Port Collar 11.250 2.250 40 3.32 500 500 7 4-1/2"TRM-4PE-CF 5K SCSSSV (New Vam Thread) 6.000 3.813 6.99 2200 2200 9-5/8"Surface Casing 47#L-80 BTC @.0732 bpf 9.625 8.681 47 4523 4550 4550 4 4-1/2"12.6#L-80 IBT-M Tubing @.0152 bpf 4.500 3.958 12.6 I/ I HES 4-1/2"x 7"TNT Packer 5.875 3.850 7.15 11280 11280 HES"X"Nipple 4-1/2"12.6#9CR IBT-M w13.813 PKG Bore 5.010 3.813 1.26 11299 11299 ' HES"XN"Nipple 4-1/2"12.6#9CR IBT-M w/3.725"No Go 5.010 3.725 1.26 11310 11310 WLEG(EOT) 4.93 3.958 1.36 11322 11322 B e 7"x 4-1/2"Liner Hanger Packer(TOL) 6.055 4.408" 11350 11350 4 7"26#,L-80 BTC Casing @.0382 bpf 7.000 6.276 26 11500 7"26# L-80 BTC Casing Shoe 7.000 6.276 11525 11525 4 4-1/2"12.6#L-80 IBT-M Liner @.0152 bpf 4.5 3.958 12.6 720 IPerforations(To Be Determined) PBTD (Expected) 11990 11990 4-1/2"12.6#L-80 IBT-M Liner Shoe 4.500 3.958" 12.6 12100 12100 No. Rev.by Comments/Date Red Woff#2 1 Erik Opstad Well Design for Drilling Plan in March 2012 Badami Unit API No. 50-029- Permit to Drill#2012- 01-30-2012 SAVANT ALASKA Red Wolf#2 Marker Top Prognosis Zone Abbreviation Depth TVDss Correlation Marker 1 Cort 6,140 Seismic Marker 2 MK2 6,620 Ugnu UGNU 6,765 West Sak WSAK 7,130 Seismic Marker 3 MK3 7,725 M85 M85 8,060 Killian Marker KMKR 10,705 i Hue Shale HUE 11,190 Top HRZ THRZ 11,320 Base HRZ BHRZ 11,490 LCU LCU 11,555 Kekiktuk Zone 1 KEK1 11,905 PTD 12,100 Proposed TD SAVANT ALASKA RED WOLF #2 Synoptic Drilling/Completion erations Operations 1. Construct 500' x 500' x 2' ice pad. 2. Install 10' diameter cellar. Set & cement 20" conductor @ 110' RKB with dry hole auger. (zte kr:) 3. Weld the FMC starting head on 20" conductor. n/of:4, 2 7/0e-•fig- 6J, -....est 4. MIRU Nabors 9ES. NU 21 1/4" 2K diverter & diverter line. Build spud mud. T;,r- 5. PU 12 1/4" BHA & drill surface hole to 4550'. M/LWD will be in use from surface to TD. NOTE: Planned vertical well from surface to Final TD 6. Have FOSV on rig floor for 9 5/8" casing prior to starting to run casing. Run & cement 9 5/8" surface casing back to surface.� �,cal T'"s1e 7. ND 21 1/4" 2K diverter system. NU FMC wellhead & 1315/8" 5K W.hkcss BOPE. Pressure test BOPE to 4000 psi. Upper Ram will be 2. 7/8' x 5" VBR. Lower Ram will be a 3 1/2" x 6" VBR. 8. RIH with 8 1/2" BHA. Test surface casing to 2500 psi. Drill out float shoe + 15' new hole. Perform FIT to 12.8 ppg EMW. The FIT/LOT will be performed by closing hydril & pressuring formation m @ /4 BPM pump plotting volume vs pressure up to an EMW of 12.8 ppg or LOT whichever comes first. 9. Drill 8 1/2" hole to 11550' with M/LWD. Change BOP ram to 7" & test. Have FOSV on rig floor for 7"casing prior to starting to run ✓ casing. Run & cement 7" intermediate casing (1000' min. cement above shoe). Test BOPE to 4000 psi. 10. Remove 7" ram & replace with original VBR. Test BOP. 11. RIH with 6 1/8" BHA with M/LWD. Test casing to 3000 psi. Drill out float shoe + 15' new hole. Perform FIT/LOT to 10.1 ppg EMW. The FIT/LOT will be performed by closing hydril & pressuring formation @ 1/4 BPM pump rate, plotting volume vs pressure up to an EMW of 10.1 ppg or LOT whichever comes first. 12. Drill 6 1/8" hole to planned TD of 12100'. Run open hole E-line logs. v13. If needed, run & cement 4 1/2" liner compete w/hangar & liner top packer assembly from TD to 175' above 7" casing shoe. 14. RIH w/6 1/8" cleanout BHA & cleanout to TOL. Test 7" casing & liner lap to 3000 psi. POH. / 15. RIH w/3 3/4" cleanout BHA & cleanout to 4 1/2" liner float collar. Test liner to 3000 psi. Displace mud from hole with completion fluid. POH. 16. Run & land 4 1/2" 12.6# L-80 IBTM tubing completion string. Install BPV in tubing hangar. SET pAcr 4 . j 5,t- to z 71/2 17. ND 13 5/8" BOPE. NU 4 1/16" 5K TREE & test to 5000 psi. Retrieve BPV 18. Using diesel, freeze protect tubing & IA down to 2200' TVD. 19. Set permanent completion packer. Test tubing first, then IA to 3000 psi to assure pressure integrity of packer. Install BPV. 20. Release Nabors 9.ESIor rig move. DETAILED DRILLING & COMPLETION PROGRAM 446 'ANT ALASKA • A J Red Wolf #2 Confirmation Well ADL#367005 CONFIDENTIAL SAVANT RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 General Information Permit to Drill#: To be Assigned API#: To be Assigned Geometry: 20"@±80' Conductor 9-5/8"@ 4.550' Surface casino k 3 7"@ 11,525' Intermediate casing 4-1/2" liner @ 11,350' to TD 4-1/2" liner to be run only if production @—12,100' testing and GOC or OWC is encountered. Objectives: No Accidents! No Spills! Drill 12 1/4"surface wellbore to planned TD with LWD/DD Maintain vertical hole not to exceed 3 degrees drift angle to TD • Run 9 5/8"surface casing and cement to surface • Drill 8 1/2"wellbore to base of HRZ with LWD/DD Run intermediate E-line log package if called for(see program) - Run 7" Intermediate casing Obtain a minimum of 1000'of cement above 7" shoe II, Drill 6-1/8"wellbore with LWD/DD and evaluate with WL logs • Take sidewall cores and collect optional MDT samples&P/T data • Run 4-1/2"production liner to well TD if GOC or OWC confirmed by WL logs Obtain good cement job across objective pay • Complete Well per Plan NOTES: 1. Geologists will pick the top of the HRZ so as to TD the intermediate hole above the base HRZ without penetrating the target Kekiktuk sands. Avoiding the possibility of causing formation damage or losing circulation to the target horizon is one of the principal goals for this Well Plan! Page 2 of 24 GMH/EAO SAN' RW#2 Confirmation Test /y ADL#367011 ALASKA Drilling Well Plan-March 2012 Well Plan Summary Surface Location (as-staked): 4363' FEL 1350' FSL Sec 36 T1ON R19E Top of Productive Horizon: 4363' FEL 1350' FSL Sec 36 T1ON R19E TD: 4363' FEL 1350' FSL Sec 36 T1ON R19E AFE Number: AK 520 Rig: Nabors 9ES Estimated Start Date: I 3/20/12 I Operating days: I 33 MD: 12100' TVD: 12100' KB to 31.0' GL GL to 4.5' SL Type of Well Confirmation Test Well Design Vertical, 2-Casing Strings w/4W Liner Formation Markers: (all depths RKB Referenced to Nabors 9ES) Measured True Vertical Comments Formation Tops Depth,ft Depth,ft Base Permafrost 1920 Vertical Well for all depths Base Gravel 3666 Seismic Marker 2 6650 Ugnu 6795 Top Middle Brookian v West Sak 7160 M85 8090 Base West Sak Killian Marker 10735 Possible Mud Wt. Increase Needed Killian Sand 10865 Hue Shale 11220 Top HRZ 11350 Base HRZ 11520 _ Kekiktuk Zone 2 11587 Possible oil/gas Kekiktuk Zone 1 11935 Possible oil/gas TD 12135 Casing/Tubing Program: (all depths feet RKB) Hole Size Csg/Tbg Wt/Ft Grade Conn. Length Top Btm OD (ft) MD/TVD MD/TVD 12-1/4" 9 5/8" 47# L-80 BTC-M 4550 GL 4550 8-1/2" 7" 26# ' L-80 BTC-M 11525 GL 11525 6-1/8" 4-1/2" . 12.6# . L-80 IBT-M 720 11350 12100 Logging/Formation Evaluation Program: 12-1/4"Open Hole: MWD&LWD GR/Res—No E-line Logging Planned (Surface) No E-line logging planned 8-1/2" Open Hole: MWD&LWD GR/Res—Plus Tri-axial Induction/Den/Neu/FMI/Sonic/Cal/Ten (Intermediate) Page 3 of 24 GMH/EAO SA.AN-r RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 6-1/8" Open Hole: MWD& LWD: GR/Res/Den/Neu/PWD Wireline Logs planned: GR/TriaxRes/PEX/Dipole Sonic/CMR/MDT w/TLC (Contingency work: MDT/RSWC) GR/CBL/CCL from PBTD to TOC inside 7" Casing Cased Hole: USIT inside the 7"(if desired) Mud Logging/Gas Sampling: See Geological Prognosis in well plan for sampling details Cores None Planned Mud Program: 12-1/4" Surface Casing Interval; 0—4550'TVD(soda ash/gel) Density Viscosity YP Plastic pH Fluid Loss (ppg) (seconds) Viscosity m1/30 min Initial 8.6/9.3 Maintain 30-50 20—40 8.0-9.0 <8 30. 0+ Below Permafrost 8.6/9.3 _ 30-50 20—40 8.0-9.0 <8 Final-for cement 8.6/9.3 / " 30-50 20-40 8.0-9.0 <8 8-1/2" Intermediate Interval—Base Surface Casing to Base HRZ; 4550' TVD to 11525' TVD LSNU) Density YP PV LGS MBT pH API Fluid Loss (ppg) (mg/I) ml/30 min Initial 8.8-10.7 15-25 10-24 <6.0 <25.0 8.5-9.5 4-7 6-1/8" Exploration Interval—Base HRZ through Kekiktuk; 11525'TVD to12070'TVD(LSND) Density YP PV LSRV pH APIFIuid (ppg) Low Shear Rate Vis. Loss (cP) ml/30 min Final 8.6-10.5 15- 10 - NC 8.5- <4 ✓ 25 25 9.5 Cementing Program: Category Casing Volume Type of Cement Properties Size/Depth (TVD) Surface 9-5/8"/4550' 707 sx. Arctic Set Lite III 10.9 ppg; 50%excess w/additives 15.8 ppg; 35%excess 205 sx. Class G w/additives *Intermediate 7"/11525' 155 sx. Class G w/additives 15.8 ppg; 35%excess Production Liner 4-1/2"/11350' 67 sx. Class G w/additives 15.8 ppg; 15%excess Page 4 of 24 GMH/EAO SAVANT RW#2 Confirmation Test ADL#367011 ALASKA Drilling Well Plan-March 2012 to 12100' *NOTE: Cement volume on 7"job may have to be increased if any hydrocarbon bearing zones are encountered prior to reaching planned 7"casing TD. Tubular Pressure Ratings: OD Wt Grade Conn Cplg OD ID Drift Collapse Burst Tensile (in) (PPf) Type (in) (in) (in) (psi) (psi) Yield (kips) _ 9-518" 40 L-80 BTC 10.625 8.835 8.679 3090 • 5750 • 916 7" 29 L-80 BTC 7.656 6.184 6.059 7020 ' 8160 676 4-1/2" 12.6 L-80 IBT 5.563 3.958 3.833 7500 8430 • 288 Drill String Dimensions and Strengths: Drill Wt(ppf) Grade Conn TJ OD TJ ID Tube ID Max MU TJ Recommended Pipe Type (in) (in) (in) Torque Torsional Max Pull (ft-lb) Yield w/new pipe (ft-lb) (kips) 5"DP 19.5 S-135 4-1/21F 6 1/2" 3 1/4" 3.0" 26800 46500 560 5" 49.3 HVYWATE 4-1/21F 6 1/2" 3 1/8" 3.0" 29200 56300 691 HWDP 4"DP 15.7 S-135 HT-40 5.125" 2.688" 3.24" 14100 to 37200 583 20200 4" 29.7 HVYWATE HT-40 5.125" 2.68" 2.56" 12900 32800 407 HWDP to 19300 Contacts: Individual Title Name Office Home Pager/Cell Drilling Manager Gary Hammon 907-868-1258 425-868-3001 206-963-6151 ext.105/fax 1455 NS CELL 907- 448-6011 General Manager Erik Opstad 907-868-1258 907-345-6346 907-244-5210 ext.101/fax 1455 NS CELL 907- 448-6010 HSE Manager Steve Rog 907-868-1258 907-345-0022 907-250-1734 ext 106/fax 1455 Drilling Supervisor TBD 907-868-1258 NS CELL 907- 448-6011 Logistics Coordinator Mary Rush 907-868-1258 907-830-8233 ext 103/fax 1455 Completions Engineer Greg Vigil 720-328-7184 303-660-6532 720-363-1041 Exploration Manager Greg Vigil 720-328-7184 303-660-6532 720-363-1041 Page 5 of 24 GMH/EAO SA.ANT RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 Well Objectives and Area History The primary objective of this well is to confirm the presence and quality of the Kekiktuk sands on the crest of the Red Wolf structure and complete the well for testing to ascertain the fluid type,flow rates and reservoir pressures/temps. The well may be cased with a 4-1/2"liner if gas/oil is present. The permeability of the formation should be sufficient to perform a production test without stimulation. The well will be production tested as needed to ascertain key reservoir parameters. If the production rate is not sufficient for adequate reservoir testing,fracture stimulation�may�be performed. rG � A majorgoal of this drillingseason is to collect data from the rebervoirtinterval so that commerciality can be declared. Drilling Fluids Disposal Incidental fluids developed from drilling operations will be hauled to the Prudhoe Bay permitted Class II disposal well. (Note that cement rinseate will not be infected down the dedicated disposal well but will be recycled.) Where isolation over significant hydrocarbons is required per regulations, then sufficient cement volume will be pumped during the intermediate cement job to cover those formations. Surface casing will be set in the Cretaceous shales 100' above the K3. These 300-500'thick shales ,V..., are partof the Colville Group and are known to provide vertical barriers to fluid flow. This setting depth will insure any potential fresh water intervals are isolated behind casing. H2S Contingency Measure This location is not classified as a Hydrogen Sulfide however;the Hydrogen Sulfide contingency measures remain in effect during the drilling of this well. The key points of these requirements are as follows: 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 all regulatory H2S monitoring requirements. Manual detectors 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 II and the use of personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. Nabors Drilling has developed an H2S contingency plan for North Slope drilling operations. 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 for exploration drilling operations, the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. Page 6 of 24 GMH/EAO SAYANT RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 If it becomes necessary to notify the regulatory agencies of an H2S encounter, drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures, full regulatory and applicable referenced sections of API RP49 compliance, and approval of the regulatory agencies. 16 NABORS SEVRIG WORK Vertically Drilled Surface Hole: 12-1/4"Hole/9-5/8"Casing to 4550' TVD Interval Risks: a) Heavy clay section and bit balling—elevated mud viscosity from spud;Hi dens sweeps b) Shaker/Trough Overflow—controlled ROP c) Lost Circulation—Add LCM;reduced pump rates&mud rheology;controlled running speeds d) Washouts&Hole Sloughing-Cool mud temperatures and minimize circulating time when possible. NOTE: The RW#2 20"conductor is to be cut-off at 12"below ground level. Weld on the FMC 9 5/8"landing ring to top of conductor. Weld 180 degrees apart two 4"threaded weld- o-lets 12"below cutoff top of 20"conductor. Screw 4"ball/butterfly valve onto threaded nipple in order to be able to drain out from diverter/wellhead cement returns from surface cement job into cellar. 1. Be sure all containment spill liners for rig footprint are in place. MIRU Nabors 9ES. Record move distance and RKB distances to top ice pad and sea level on morning and IADC reports. Sea level to top of conductor is -- 5.5'. Post AOGCC drilling permits and SPCC plan in the Doghouse • Notify AOGCC prior to spudding well and 48 hours prior to performing diverter function test. AOGCC notifications remain the same as development drilling requirements. • A complete copy of the AOGCC permit must be on location. • The following notifications should be made: • Notify AOGCC Slope Inspector @ 659-2714 or 659-3607 (pgr#) at least 48 hours in advance. 2. Install 21 1/4" 2K diverter system on FMC starting head and function test. Verify that two welded 4" threaded nipples and ball valves have been installed below the 20" FMC starting head on opposite sides of the conductor. These will be used to drain cement returns down below the 20" starter head. • Prior to spud, a safety meeting should be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: Page 7 of 24 GMH/EAO SAVANT RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 - Hole fill calculations with various sizes of pipe and tubing - Well control procedures - Proper tripping practices-incl. complete&accurate trip sheets for all trips! - Flow rates and hole cleaning - Correct and accurate documentation of all BOP tests, LOT's, and safety drills - Conductor Broach contingency • A 'Diverting Shallow Gas' drill should be discussed with rig crews prior to spud. Document ,,.y<'" 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. • Trip sheets must be competed and submitted to the Savant Drilling Supervisor after each trip. • The trip tank system should be checked for leaks prior to spud. Confirm that all trip tank gauges are calibrated and working properly. Make sure that all crews understand how to utilize and interpret the trip tank system on Nabors 9ES. ▪ All drills shall be performed and documented as per the written procedures listed in the current'Drill Expectations and Procedures'. Type of Drill Minimum Frequency* Additional Guidelines Kick While Drilling Once per week per crew Kick While Tripping Once per week per crew Well Kill Twice per year per crew Prior to drilling out casing and/or immediately after Stripping Drill. Stripping Twice per year per crew Prior to drilling out casing,particularly just before drilling production hole. Diverting Shallow Gas Twice per year per crew Prior to spud in conjunction with diverter function test Accumulator Drill Prior to spud on each well In conjunction with AOGCC BOP test (see details in written procedures) Fire Once per two week tour per crew Spill Once per two week tour per crew H2S (Hydrogen Sulfide) Once per quarter per crew Confined Space Entry Once per quarter per crew 3. Build spud mud(Using COLD make-up water) keeping funnel viscosities between—300 sec/qt I to drill from spud to 12 '/" hole TD. No changes to the mud system should be attempted without the prior consent of the Savant representative on location. Use all available solids control equipment to control solids buildup and maintain mud weight. Refer to the detailed Mud Program (attached)for mud weight and rheology schedule for the interval. NOTE: Keepspud mud as cool aspossible throughout the drillingof the surface hole. P 9 4. Vertically drill the 12-1/4" hole from spud to surface casing TD at+/-4550'TVD(drill hole to fit the casing). One bit run, a 12-1/4" HES EQHI2DRC (jetted w/3-18, 1-16) is planned for this borehole section. Use 4" HT-40 DP . Page 8 of 24 GMH/EAO S/y vANT RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 NOTE: This well is being drilled as a vertical hole with a 500'diameter target.ALL drill cuttings/gravel/mud from 12 '/"surface hole to be hauled to holding pit on Badami CPF pad. Limit ROP in 12'/" hole to max. ROP of 100 FPH! In the unlikely event of a conductor pipe BROACH while drilling the 12 '/"hole, proceed to Contingency BROACH Plan on page 19. 5. Make a wiper trip to conductor shoe for each 800' of new hole drilled. If no tight spots encountered or reaming required then the amount of new drilled hole before next wiper trip can be increased. Bit will be jetted with 3-24s & 1-20 (1.632 in2 TFA) to provide maximum flow rate rather than hydraulic impact force (keep HIS low<_ 1.0). Use welded straight blade stabilizers to minimize clay balling and swabbing. Poor borehole cleaning may result in marginal wellbore conditions. • Recommend maintaining flow rate between 650&750 GPM in the 12 1/4" hole. • Monitor returns closely for signs of gas and circulate out all gas-cut mud before continuing to drill. 6. The mud loggers will be mud logging & taking formation samples starting below the base of gravels at +/-3655'TVD. Cutting samples should be taken every 30'. The AOGCC requests 30' cuttings sat les below the permafrost or as close to 30' intervals as possible. The following drilling practices will maintain good borehole conditions for the casing and cementing operations to follow: • If borehole instability problems are encountered, increase mud weights to +/- 10.2 ppg. Do X-- not change mud weight without the prior consent of the Savant company man on location. • Use high density sweeps (>2 ppg above existing mud weight throughout the interval to monitor hole cleaning. If sloughing and hole cleaning problems occur, retain high viscosity (300 Vis) until casing is on bottom. • After landing casing on bottom, circulate and condition mud system prior to pumping surface cement job. • Proper hole cleaning should be emphasized while drilling surface hole. Wiper trips should be optimized to clean up tight spots. Make wiper trip to conductor shoe for each 800'of hole drilled. If no tight spots are encountered then drilled footage can be increased somewhat 9 p 9 until next wiper trip. • Control drilling may be necessary through this hole section in order to keep from overloading the hole/shakers with cuttings and/or clay balling. • The mud should be kept as clean & cool as possible. Use barite to keep the weight at an appropriate level rather than drill solids. • Remember that surface hole stability may degrade rapidly with time. • Keep mud and mix water as cold as possible to reduce potential borehole washout. • Circulate weighted sweeps (>2 ppg > MW) at TD as needed to insure proper borehole cleaning for running surface casing. Short trip to the HWDP or to the previous trip point. • Reciprocate drill pipe slowly while circulating to avoid excessive surge and swab. Prior to POOH at 12 1/4" hole TD have mud loggers put a TAG in mud and circulate bottoms up in order to calculate an average hole size using pump strokes. Use this average hole size determination to adjust amount of Arctic Set Lite III cement to have on location for 9 5/8" surface casing cement job. 7. POOH and lay down BHA. Check hole fill up volume while POOH and avoid swabbing. Make certain that hole is in good shape prior to running casing. Short trip as warranted. 8. Inspect, tally and drift surface casing. Casing type is 9 5/8"47#L-80 BTC. 9. Run surface casing to TD as follows: Page 9 of 24 GMH/EAO SA.AN, RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 Float shoe(Weatherford) Two(2)joints 9-5/8"47# L-80 BTC-M casing Float collar(Weatherford non-rotating type) 9-5/8"47#L-80 BTC-M to approx. 500' Install 9 5/8" Ported Collar NOTE: The Port Collar is to be made up between 9 5/8" pup Jts. prior to running csg. Do not place casing tongs on the 9-5/8" Port Collar 9 5/8"47#L-80 BTC-M casing to surface FMC 9 5/8" mandrel hanger 9 5/8"47#L-80 BTC-M casing back to rig floor NOTE: Baker-loc all connections from FS to top FC. Have 9 5/8" BTC circulating swage on location prior to starting to run casing. Have Weatherford service man on location w/tools in case use of Ported Collar is necessary. Emergency casing slips are available in event of getting stuck off bottom. • Run one 9-5/8" bow-spring centralizer per joint of casing on bottom 10 joints. Run centralizers on stop collars in the middle of the bottom 3 joints. • Control casing running speed to minimize surge pressures. LAND CASING. Install HES cementing head &lines. Pressure test cement lines&head to 2000 psi. • Carefully review the cement plan with the HES supervisor & mud engineer prior to start of cement job. DO not deviate from this plan without prior approval from Savant Co. man. • After casing is landed, circulate & condition mud. Reduce mud viscosity back to — 80 sec. v prior to pumping cement. This will increase the chances for a successful cement job. ➢ Prior to beginning the surface casing cement job, make sure that the mud properties meet the following target criteria to help ensure effective mud removal: Mud Wt. 8.8 to 9.5 ppg Pv<20 YP< 15 Note: Be sure that the two (2) 4" drain valves on 20" casing in cellar are thawed & operable prior to beginning cement job. • Any packing off while running casing, and especially while above the base permafrost, should be treated as a very serious problem if major returns are lost. Run 4" lines from side outlets on the conductor to a Vacuum Truck/Supersucker to help reduce pack-off problems and to minimize the chance of a spill. It is preferable to pull casing out until circulation can be re-established rather than risk not getting cement to surface. Contact the Savant company man onsite if the casing packs off up high for discussion of the options. • Keep the shut down time periods as short as possible. Page 10 of 24 GMH/EAO SAYAIVT RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 10. Pump surface cement job as follows: NOTE: See attached SLB cementing details. Cement mix water to come to rig (a. 80 to 90°F. LEAD 10 bbls. Water followed by50 bbls. 10.1MUDPUSH II followed ppg by ✓707sx(308 bbls)or as needed (see NOTE: below)Arctic Set Lite III @10.7 ppg. Yield is 2.45 cu.ft/sx ✓ TAIL 205 sx(42.3 bbls)Class G w/.2% D46, .3%D65, .2% D167, .2%CaCl2 @15.8 ppg 1.16 ft3/sx yield NOTE: Cement volumes are based on 30% excess below the permafrost and 30% excess through the Permafrost. In the event cement is not circulated to surface, then proceed immediately with secondary cement job using DP&the 9-5/8" Ported Collar with Arctic Set Lite III cement as needed to get cement to surface(see attached Ported Collar use procedure). AOGCC must be contacted prior to beginning Ported Collar job. Do not proceed with Ported Collar iob without AOGCC approval. 11. Drain cement down from diverter & wellhead. Flush diverter, wellhead & all lines. ND diverter assembly. 12. Orient, NU &test FMC casing head assembly. The FMC Gen 5 wellhead system will be used on this well. NOTE: Remove the two 4" threaded valves & nipples used for draining down cement from conductor. Install &Baker-Loc 4"threaded bull plug in each 4"weld-o-let. Page 11 of 24 GMH/EAO SAvANT RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 Vertically Drilled Intermediate Hole: 8-1/2"Hole; 4550'— 11525' TVD The objective of the 8-1/2" intermediate hole is to drill to the base of the HRZ as quickly as possible yet maintain good borehole cleaning and condition, without risking shale deterioration from prolonged exposure. The wellsite Geologist shall pick casing point within 50-feet of the base HRZ ,'f-' since the setting depth of the 7" casing shoe is a critical step in the success of thi ws ell plan!The 7" intermediate casing will isolate any geo-pressured shale. Interval Risks: a) Stability in Pebble Shale — control with higher MW and proper drilling practices (see program) b) Directional control in Pebble Shale—BHA design to provide efficient corrective slides c) Lost circulation associated with overbalanced fluids for shale stability—have 40 ppb LCM pill mixed and ready prior to reaching casing point above the J4. d) Differential sticking if the J4 is accidently drilled with the 11.3 ppg mud-minimize drilled solids and maintain thin tough wall cake! 13. NU FMC 7" casing &tubing wellhead spools &test same. Using 11" 5K x 13 5/8" 5K DSA, NU 13 5/8" 5K BOP Stack & pressure test wellhead spools, all BOP equipment and choke manifolds per AOGCC. Insure a 2" ID (minimum) check valve is installed in the kill line and is purged and clear at all times. Record on IADC tour sheet the distance from DF to both tubing head& 7"casing landing flanges. • Notify AOGCC 48 hours prior to performing BOP test • Per AOGCC requirement, all stack tests will have a low 250 psi and a high 5000 psi test (against test plug). Each test will be held 10 minutes. • The AOGCC requires a BOPE test every 7days. The AOGCC has indicated that they will be somewhat flexible with this requirement, but the Slope Inspector must be contacted and consulted regarding the seven day test 48 hours before testing. • A'Stripping'drill should be discussed with rig crews prior to drill out. Document drill and record on IADC report. • A'Well Kill'drill should be held with rig crews prior to drill out. Document drill and record on morning& IADC report. • A well kill sheet shall be posted in the doghouse and updated each tour. Take SPR each drilling tour. Record on IADC&Kill Sheet. • All drills shall be performed and documented. 14. Install FMC wellhead bowl protector. The 8 1/2"hole section will be drilled using 4" HT-40 DP. Change BOPE rams to 4"and test if VBR does not cover 4". NOTE: This well is being drilled as a vertical hole with a maximum 500'diameter radius target! 15. RIH w/SSDC recommended BHA #2 w/Hycalog 8W DSX619M-D6 drill bit jetted w/6-13 nozzles (TFA .7776 sq.in.). Using mud motor only, clean out to the top of the float collar. Pressure test casing to 2500 psi for 30 minutes and record on chart as per AOGCC Page 12 of 24 GMH/EAO SAVANT RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 requirements. Verify that the test indicates a linear line by plotting on the LOT/FIT form. Repeat casing pressure test if needed. 16. Drill out FC & clean out cement to 10' above 9-5/8" shoe & repeat pressure test (as above in step 15) of casing. Drill out the 9-5/8" shoe, and 15' of new hole. Displace spud mud from hole with new 9.0 ppg LSND mud system. Pull into shoe. Perform LOT per AOGCC regulations. If pressure rises to 12.6 ppg EMW, shut down and conduct a FIT test at that point. Based upon 01. kick tolerance calculations against pore pressure estimates, a 12.6 ppg FIT is more than adequate for this wellbore. • Based upon results of FIT/LOT, calculate current kick tolerance based on LOT/FIT outcome and communicate results to rig personnel and Savant company man prior to drilling ahead. • Calculate new kick tolerance data whenever losses or mud weights changes occur. 17. Drill additional hole as needed in order to have sufficient hole to bury SSDC BHA#2 before any rotating of DP. Drill 8-1/2"vertical intermediate hole to 7"casing point. NOTE: It will be most critical to identify the HRZ on top of the Kekiktuk sand without actually drilling into the production interval.The following issues and guidelines are targeted for successfully drilling this interval: Flowrate: 550 -600 gpm Nozzle Flow Area (TFA) .777 sq. in Pressure Drop @ Bit 419 psi Nozzle Velocity 227 fps AVdp—4" 137 fpm AVdC -4" 202 fpm > Optimized nozzles and flow rate improve hole cleaning and reduced washout. ➢ Optimized hole cleaning occurs during periods of high rotary rpm's(>90 rpm's or as fast as possible)and high flow rates. ➢ ECD's should be maintained between 11.0 & 12.0 ppg EMW during drilling and pipe movement. When reaming a stand, pump rate should be reduced to 50—60% of normal pump rate during the downstroke of the string. ➢ For proper wellbore cleaning, it is recommended to rely upon PWD and torque and drag data to determine required circulating duration for cleaning the hole prior to drilling ahead. Excessive circulating times across the shaly intervals below the HRZ have a tendency to aggravate the shales in this interval. Drilling and casing this interval in minimal time will be essential! Hole cleaning conditions can be monitored by pump pressure and PWD spikes, torque, drag, etc. and practices modified to improve hole conditions. Adherence to these guidelines throughout this interval will reduce trouble time. 18. Drill enough new hole to bury the 8-1/2" BHA. Perform a PWD Baseline Test (see attached V form) to evaluate clean hole/clean fluid conditions. Targeted hard line should be the lesser of 1/2 ppg above clean fluid tests or the LOT value. NOTE: ALL drill cuttings & mud from both 8%2"&6-1/8" hole to be hauled to disposal facilities at Prudhoe Bay 19. Mud logging and mud-gas sampling required every 30' except thru hydrocarbon zones where 10' sampling is required. Bag samples at 250' intervals from 9 5/8" to TD plus samples across all shows. See Geological Prognosis for details. 20. Mud weight should be maintained at 8.6 to10.7 ppg to 100'-150' above the Base of the HRZ in order to maximize ROP (See attached detailed Mud Program for proper procedure). Maintain all solids control equipment in optimum condition. Be vigilant regarding formation pore pressures as drilling approaches the Killian Marker formation estimated to be (a, 10735'. MW increases up to 11.9 ppq may be required. Page 13 of 24 GMH/EAO SAYAN T RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 21. Continually monitor PWD for adequate hole cleaning, torque, drag and cuttings characteristics for shale stability. Pump high density sweeps as needed for supplemental hole cleaning. Sweeps must be accompanied by maximum rotation until sweep is seen at surface. NOTE: See discussion in mud section regarding surge & swab pressures while drilling this interval. The recommendation is to attempt to maintain ECD's between 11.0& 12.0 ppg to avoid breaking down the shales. Trip speeds need to be controlled to avoid aggravating the shales. 22. The wellsite Geologist will attempt to pick a 7" casing point with offset well data and without <1) excessive circulation time. Attempt to drill hole to fit the casing if at all possible. The Driller will be a key part of this decision and will work closely with the Geologist to help determine when a drilling rate is indicative of having encountered the HRZ. Monitor PWD, torque, drag, surface pump pressures, etc for wellbore condition. 23. At 7" casing point, pull wiper trip(s)as necessary per wellbore conditions. Circ. &condition hole for casing. POOH and stand back BHA and download LWD logs. Make sure adequate LWD log quality has been obtained prior to running 7"casing. 24. Inspect, tally and drift 7"casing. NOTE: Be sure 7"casing circulating swage is on location prior to running casing. 25. No E-Logs are planned for the 8 1/2" hole. 26. Pull wellhead bowl protector. RU and run 11,525' of 7" 29# L-80 BTC casing. Slow running speeds are recommended to avoid imparting high surge pressures on the shales. At TD, CCM run and cement casing as follows: 7" CASING RUNNING DETAILS: Float Shoe(Weatherford) 2 Jts. 7"26#L-80 BTC-M Float Collar(Weatherford non-rotating type) V/ 7"26#L-80 BTC-M casing to surface FMC 7"mandrel hanger& 7"BTC-M landing Jt NOTE: Emergency casing slips are available in the event of getting stuck off bottom. ' SEE ATTACHED SLB CEMENTING DETAILS. Cement mix water to come to rig @ 80 to 90°F 10 bbls water tl 30 bbls MUDPUSH II (10.5 ppg) cil.„ 155 sx(42 bbl)Class G w/.02 gal/sx D177, .2% D46, .3% D65, .2%D167, 35% D66 15.8 ppq, 1.53 ft3/sx yield NOTE: Cement is calculated to give 1500' fill. The possibility exist that should any hydrocarbon zones be encountered above 7" casing shoe depth that additional cement and centralizers may be required. D Inspect and drift all casing and components in pipe shed prior to RIH D Run float shoe, 2 joints of casing and float collar. Baker- loc all connections from FS to top FC. Page 14 of 24 GMH/EAO SAVANT RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 ➢ Run one bow spring centralizer every other joint (except shoe joints) from TD to 500' above the shoe. Centralizers on shoe joints should be installed mid-joint on stop rings. ➢ Bow spring centralizers will be run across any identified hydrocarbon intervals. ➢ Casing setting depth is crucial on this interval. If casing does not go to bottom, POOH and make cleanout run to TD. Any cleanout run MUST INCLUDE PWD. ➢ It will be very critical to set the 7" casing thru the shale and just shy of the base HRZ. Excessive rathole below the shoe could be detracting from the pay interval. Page 15 of 24 GMH/EAO SAVANT RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 Production Hole: 6-1/8"Hole/4-1/2"liner; 11,550'-12,100'TVD Interval Risks: 1) Lost Circulation—Low probability due to reduced mud weights. NOTE: Approximately 12 hours after 7" CIP freeze protect the 9-5/8" x 7" annulus with 70 bbls diesel (via bullhead) to well below the permafrost (2500' MD). Bullhead flush annulus with a minimum of 100 bbls CaCl2 water before bullheading diesel. • Prior to freeze protecting the 9 5/8"x 7"annulus, perform a LOT or FIT on annulus with water. Do not exceed 14.5 ppg EMW at shoe without discussing with Savant Alaska Management. Perform and record like casing shoe test. Information to be used for future annular injections if needed. 27. Install&test 7" FMC hangar pack-off assembly. Install wellhead bowl protector. 28. LD 8-1/2" hole size BHA. PU 6 1/8" HES FMF3643Z PDC drill bit jetted w/3-10 & 3-12 nozzles (.5614 TFA)w/SSDC recommended BHA#3 and RIH. Using mud motor only, clean out to FC and pressure test 7"casing to 2500 psi per AOGCC regulations. Clean out cement to 10'above FS & retest 7" casing to 2500 psi. Circulate & reduce MW back to 8.8 ppg prior to drilling out FS. i,Y 444;,1ti 29. Drill 6-1/8" new hole to),5''below 7" shoe. Pull above shoe. Circulate & condition mud back to 8.8 ppg. Perform FIT-to 10.1 prx (approx. 6000psi BHP) EMW. The expected maximum Kekiktuk reservoir pressure to be encountered is approximately 5230psi or 8.6 ppg EMW. 30. Inspect, tally and drift 41/2" liner casing in pipe shed. 31. Drill sufficient hole w/mud motor to bury the BHA before starting any rotation of DP. Drill 6-1/8" vertical hole to TD. Plpnned TD is approximately 12100'TVD. The onsite geologist will determine actual FINAL TD. NOTE: Drill bit hydraulic parameters: ➢ Nozzle velocity— 143 FPS ➢ Pressure drop @ bit- 168 psi ➢ Recommended GPM-250 ➢ Recommended WOB-5 to 20K 32. Mud logging and mud gas sampling required every 30' except thru hydrocarbon zones where 10' sampling is required. Bag samples at 250' intervals from 7"shoe to TD plus samples across all shows. See Geological Prognosis for details. 33. At final TD condition the wellbore for E-line logs. POOH and lay down mud motor/MWD/LWD. Download logs from MWD/LWD to assure of quality. 34. RU SWS and log well as directed by well site logging Engineer • Suite of logs to include GR/Res/Dipole Sonic/CMR/MDT • USIT across the 7"approx.1000'from TD • CBL/CCL/GR inside 7" casing will be run in combination with CBL run on 4'/z" liner • Contingency logs may be run 35. RIH with clean out assembly and condition the wellbore for 4-1/2" production liner if liner is to be run. Short trip as needed. CCM for liner. POOH 36. If 6 1/8"open hole is to be abandoned a P&A procedure for this will be provided at that time. Page 16 of 24 GMH/EAO SA/MT RW#2 Confirmation Test ADL#367011 ALASKA Drilling Well Plan-March 2012 NO OPEN HOLE or CASED HOLE DST PROCEDURE IS PLANNED WITH RIG ON WELL Make sure that hole is in good shape prior to running liner. Continue to circulate and short trip as necessary until the Savant Rig Supervisor is comfortable with hole conditions. Do not POOH without therior consent of the Savant RiaSupervisor on location. p P 37. Hold safety meeting prior to running liner. Rig up casing running equipment and check calibration of casing tongs. Insure tieback line is installed on power tongs and is level and secured at right angle for accurate torque measurement. Have at least one backup for power tongs, hydraulic unit and spider/elevator on location. Run the 4-1/2" 12.6# L-80 IBT to TD. Centralizer (Straight Blade Rigid, 4-1/2" x 6-1/8") placement will be provided based upon targeted perforation intervals for optimum cementing. Prnrii ictinn liner will hP run as follows,. —Baker 4-1/2" IBT Guide Shoe 2 jts.4-1/2" 12.6#/ft L-80 IBTM liner Baker 4-1/2" IBT float collar 1 jt. 4-1/2" 12.6#/ft L-80 IBTM liner Landing collar 4-1/2" 12.6 #/ft L-80 IBTM liner to TD at 12070' (175' liner lap above 7"shoe) Baker 4'/" liner hanger/packer assembly&running tool Note: Two 10' marker joints to be run at approx. mid-point of liner. Baker-Loc landing hanger with ZXP liner packer(15'liner top PBR) ➢ The hydraulic hanger should be pinned for +2200 psi and the HR running tool for the hanger should be pinned for +3150 psi. The wiper plug should be pinned with 3 brass shear screws for+870 psi. SEE LINER HANGER SETTING PROCEDURE ➢ The recommended Max/Min makeup torque for liner is 3975 ft/lbs. ➢ Baker-loc float equipment to liner joints at warehouse. ➢ Run 4 '/"x 6-1/8" rigid centralizers on all joints ➢ Do not over dope liner connections when running. ➢ With liner on bottom, circulate the wellbore and condition the mud for a PV<15&YP<15 range as directed by Mud Engineer. ➢ Break circulation after liner is fully made up and note weight of liner in mud. ➢ Use Best-O-Life 2000 thread compound. Apply thread compound with paint brush. Insure all excess thread compound is cleaned off the casing prior to make up. ➢ Always bring blocks to a complete stop prior to setting slips ➢ Keep liner full while running in hole. ➢ Monitor PU and SO weights while running in hole. Record hanging weight, PU weight and SO weights with liner at TD ➢ Maximum pull at the liner is 80%of connection or pipe yield,whichever is less. ➢ Monitor mud flow while running in hole. Reduce running speed if decrease or loss of flow. 38. Make up DP running string on top of liner setting tool. Run one stand DP and break circulation to ensure liner is free of obstructions. Install drill pipe wiper on setting string to prevent foreign objects from falling into wellbore during TIH. Page 17 of 24 GMH/EAO SvANT RW#2 Confirmation Test /�"� ADL# 367011 ALASKA Drilling Well Plan-March 2012 ➢ Maximum running speed is 90 seconds minute per stand ➢ Fill setting string every 5—10 stands and check displacement on TIH ➢ Break circulation prior to entering open hole (do not exceed 1500 psi at surface. Make up plug manifold and stand back for easy pick up. Manifold is required to function quickly when washing up cement lines and switching between cement pump truck and rig pumps 39. Record up and down weights of the liner before entering open hole and at TD. Use DP pups Jts. in order to have DP cementing head as near rig floor as possible. 40. The hanger should be set approx. 175' above the 7" shoe depth. Avoid 7"float collar with liner hanger/packer assembly. 41. Circulate with mud at the maximum possible rate until returns are clean, monitoring loss rate vs. circulation rate. Circulate 2-3 annular volumes. Reciprocate while conditioning and cementing as borehole conditions permit. 42. RU SLB cementers and insure the rig-up configuration permits a seamless transition between fluid types. Test cementing lines with water to 3500 psi and flush with mud to overflow(slop) tank. 43. SLB will pump the entire job, including displacement, until the liner top packer is set. The rig will be used to displace above the liner after un-stinging from liner hanger. 44. Pump 5 bbls. water followed by 20 bbls of 10.5 ppg MUDPUSH II, followed immediately by cement as follows: 67 sxs(18.2 bbls)Class G w/.02 gal/sx D17., .2% D46, .3% D65, .4% D167, 35% D66 15.8 ppq density, 1.53 CF/sx yield NOTE: Cement mix water to come to rig @ 80 to 90°F. Cement should be batch mixed for this job. Kick out the 4" DP wiper plug with drilling mud (DP displacement volume should be approx. 113 bbls) and displace at 5 bpm while maintaining pressure below the liner hanger setting pressure. Slow rate to 2-3 bpm to pick up the liner wiper plug (-900 psi "bump"). Position the liner shoe on bottom when lead MUDPUSH II spacer reaches the shoe. 45. At 10 bbls prior to calculated plug bump (i.e. 123 bbls total displacement), reduce pump rate to 1/2 bpm. Pump until plug bumps but do not over displace more than 50% of the shoe track volume. 46. Upon bumping the plug, increase pressure to —1700 psi to set the liner hanger. Slack off to 20,000#to validate the hanger setting. Increase the pressure to 2200 -2500 psi to release the HR running tool. NOTE: Verify liner running procedure all hanger/packer setting pressures & weights with Baker rep. before running liner. 47. Once hanger is set and the HR running tool is released maintain 1000 psi and pull the liner running tool while maintaining the 1000 psi. Prepare the rig to initiate circulation as the running tool seals disengage—rotate allowing the dog subs to be exposed. NOTE: If mechanical problems occur and circulation is not possible, POOH in stands to clear green cement ASAP and prepare for a cleanout run. 48. Circulate 5 to 10 bbls at maximum rate at the top of the liner. Set back down with 40,000#to set the packer. 49. PU 15'to 20', and reverse circulate excess cement out. 50. Watch for cement returns and estimate the volume returned on the morning report. Page 18 of 24 GMH/EAO SAYANT RW#2 Confirmation Test ADL# 367011 ALASKA Drilling Well Plan-March 2012 51. POOH w/DP&liner running tool. 52. RIH with 6-1/8" mill tooth bit. Wash down and clean out to top of liner. DO NOT ROTATE ON LINER TOP. Pr-ssure test 7" casino & liner Ia. to 3000•si for 30 minutes on chart recorder. Bleed off pressure. POOH. 53. RIH w/ 3-3/4" mill, six (6) 3-1/8" DC plus 700' of 2-7/8" HT PAC DP on bottom of 4" DP. Take care not to damage liner top when RIH. Clean nut 4 '6" liner to float rnllar. Circulate and clean up hole. NOTE: If additional rathole is needed for pens then drill out FC&cement to NO MORE than 10' above 4'/"float shoe. 54. Pressure test liner and casing to 3000 psi for 30 minutes on chart recorder. If test is good, then proceed to displace mud from hole with 40 bbls viscous water spacer followed by 380 bbls 8.4# NACL water until clean NACL returns are observed at surface. Monitor well for any flow for 30 minutes. 55. If hole is static, POOH laying down drill string. It will take 55 bbls to fill hole while POOH. COMPLETION PROCEDURE 56. RU E-line. Run CBUGR/CCL from PBTD in 4-'/2"liner to TOC in 7"casing. RD E-line. 57. h n BOPE B O E rams to 4/ if not covered by VBR &test. Pull wellhead bowl protector. Run 4%" Range 3 IBTM tubing completion string as follows: NOTE: Typically new tubing does not require any dope when run as that it comes pre-doped from mill, but check as run and dope as necessary. Check all coupling seal rings with tubing in pipe shed. Replace seal rings as needed. See attached chart for Max/Min recommended make up torque for tubing in ft/lbs. Assure that RHC-Plug is installed in XN nipple below packer prior to RIH with tubing completion string. p 9 FOLLOW ATTACHED COMPLETION PROCEDURE FOR RUNNING PRODUCTION TUBING STRING,SETTING PACKER& FREEZE PROTECTING i_tA;v{1- 58.Release Nabors 7E5 NOTE: Be sure all Savant Alaska owned or rented crossover subs & tubing pups are removed from rig&put into Savant inventory or returned to applicable vendors prior to rig's demob back to Deadhorse. Attach the well sign to TREE in a secure manner such that only Savant can remove it as necessary. Submit AOGCC Forms 403/407 within 7 days of rig release. Page 19 of 24 GMH/EAO Red Wolf#2 RUNNING COMPLETION/TNT PACKER SETTING PROCEDURE Pre-Job Checklist Tally all pipe as it is loaded onto the pipe rack. Remove all thread protectors and visually inspect the threads for damage. Clean only if needed and visually inspect the threads. Drift tubing with Teflon drift. If the tubing fails the drift test,have the ends of the drift checked for OD. Normal wear on the drifts can enlarge the ends so that they will not pass through the tubing. Check and strap all space out pups. Drift all pups. Check all tubing,crossover,combination couplings and pup joint for proper threads. Drift tubing hanger and pup joint. Strap all accessories. Record length of all pup joints,GLM's,SSSV and landing nipples and all other completion jewelry on the Completion Detail form. Purge SSSV control line with hydraulic fluid and test to 5000 PSI. Baker-Loc all connections in tailpipe assembly. Prior to Running Completion a) Make slickline 6"gauge ring/junk basket run to top of 4'/2"liner. Gauge ring minimum OD = .06"over TNT Packer running OD of 5.875". b) Pull wellhead wear sleeve protector. c) Be sure XMAS Tree, tubing hanger&hanger pack-off are on location&tubing hanger has 4'/2" IBTM pin down. Be sure that one(1)of the tubing hanger's dual control line ports has been plugged off. The new 4-1/2"TRMAXX-5e SCSSSV requires only one(1)control line port. d) Be sure to have connection needed to get pump line onto tubing wing valve on tree& IA valve on wellhead. e) While tubing is in pipe shed, remove tubing thread protectors. Check all IBTM couplings to be sure seal ring is install & in good condition. f) Have complete tailpipe assembly&TNT packer with 10' pup jt. on top all made up& in pipe shed ready to be RIH. g) Stainless steel control lines bands will be used on'/" SSSV control line. h) The tubing hangar has TC-II thread in top. FMC will furnish 4'A" IBTM box x TC-Il pin crossover sub for landing hangar Running Procedure for Completion Tubing String with 4 1/2" x 7" TNT Production Packer NOTE: See attached Completion Tubing String Detailed running order. • No GLMs are being run in this well • Tubing tail WLEG is to be landed some 20' above TOL • Nipples, Packer&SSSV are all to come to location pressure tested with properly torqued pups Jts. installed top& bottom. • Fill Tubing with NACL water every 20 joints while RIH (if needed). The RHC plug in XN Nipple should allow tubing to fill as RIH. • The borehole will be filled with 8.4#NaCI brine when the completion string is run. 1. PU & RIH with 4 1/2" tubing completion string as per attached detailed running order. Limit RIH speed to NO MORE than 60 ft/min. Optimum make up torque is 3975 ft. lbs. After installing ScSSSV & 1/." SS control line test ScSSSV for proper operation Maintain 5,500 psi on control line while RIH. Secure control line to tubing using stainless steel bands. 2. RIH until tubing tail WLEG is —20' above TOL. Lightly tag TOL. Pull up & figure space out tubing pups needed to land tubing tail WLEG at—20' above TOL. 3. Pick up the required amount of tubing and/or pup joints with tubing hanger/pack-off assembly in order to space out as needed. Make up control line to tubing hangar& pressure test same. The top thread on tubing hangar is TC-II. MU a joint of 4'A" IBTM tubing with 4 '/2" IBTM box x TC-II pin onto tubing hanger with TIW &needed crossovers on top landing jt. NOTE: Be sure 1/4"control line is properly attached to tubing hanger&pressure tested. The FMC tubing hangar&pack-off is a single unit. Be sure to drift TIW&crossovers with Rod/ball assembly before MU on landing jt. 4. Land tubing hanger/pack-off assembly. Run in lock down screws on tubing head flange for tubing hanger. Pressure-test the tubing hangar pack-off. 5. Hook up pump lines & chart recorder to both tubing & IA. Using diesel, pressure test lines to 4000 psi. NOTE: Using the 4-'/%" IF box x 4-1h" IBTM crossover sub, RU two (2) 4-'/2" IF TIW valves between an 8' 4-1/2" IF DP pup jt between TIW valves. This will be needed in order to be able to drop rod/ball assembly in step 11 below with pressure on tubing. Also have 4'/2" IF side- door pump-in sub w/2" 1502 WECO union if available to hook up pump line. These items are available from Baker in Deadhorse. 6. Ensure tubing & IA are full of NACL water. Be sure IA is open. Using reverse circulation, displace entire well volume (i.e. 371 bbls) to WLEG using maximum pump rate of one (1) BPM until clean diesel returns from tubing are obtained. Pump displacement as follows: a. 172 bbls of diesel followed by b. 170 bbls of 2% KCL water followed by c. 41 bbls of diesel d. Shut down pumping. This will leave a surface pressure on tubing of 730 psi 7. Drop rod/ball assembly for packer setting down tubing. RU chart recorder on both tubing & IA. Allow sufficient time for Rod/ball assembly to fall to seat on RHC plug. When Rod/ball assembly is on seat, pressure tubing using diesel with an additional 500 psi bringing tubing pressure to 1230 psi &hold for 3 to 5 minutes. 8. Continue to increase tubing pressure to 3730 csi in order to set TNT packer. Monitor IA for any returns. Monitor pressure on tubing for 30 minutes using chart recorder. NOTE: Expect minimal returns from IA initially due to tubing expansion 9. Bleed tubing pressure back to 1230 psi. Using diesel, pressure IA to 3000 psi. Monitor both IA&tubing pressure for 30 minutes on chart recorder. 10. If both tubing & IA pressure tests are successful, bleed IA & tubing to "ZERO". RD pump lines. 11. Back out landing jt. &lay down. 12. Install BPV. Close SSSV. ND BOPE. 13. NU XMAS Tree&test tree with diesel to 4000 psi. Install control line fittings on tree flange& test same to 6000 psi. Ensure proper operation of SSSV. Retrieve BPV. Open SSSV. 14. Release Nabors 9ES for rig move. 15. After Nabors 9ES is off well, retrieve BPV. 16. RU Slickline Unit&lubricator. Pressure test lubricator to 2000P si. Retrieve Rod/ball assembly from top of RHC plug. Retrieve RHC plug from XN nipple. Bleed any IA pressure to "ZERO"psi. 17. RD Slickline Unit. Close SSSV. NOTE: If Savant Management decides the well is to be perforated &flow tested in 2012 ,/ winter season, a Plan for this will be prepared at that time. (el- End of Procedure - SA PJr RW#2 Confirmation Test ADL#367011 ALASKA Drilling Well Plan-March 2012 CONDUCTOR BROACH—CONTINGENCY CEMENTING PLAN In the event of a broach to surface of drilling fluids during the drilling of the 12-1/4" surface interval, the following contingency contin enc plan is recommended to remediate the situation. Conductor Hole Diameter: 24" Conductor Casing Size: 20" Setting Depth: 80' Conductor Annular Volume: 80' *.9599 ft3/ft = 76.8 ft3 (13.6 Bbls) Conductor Pipe Volume: 80' *1.9947 ft3/ft = 159.6ft3 (28.4 Bbls) 12-1/4" Open Hole Capacity: .8185 ft3/ft (.1458 bbls/ft) 1. Upon establishing that a broach of the conductor casing has occurred, POOH and stand back BHA. 2. RIH with open-ended drill pipe to 20' below the base of the conductor pipe. 3. Establish circulation with mud at normal drilling rate. Begin circulating and establish rate of flow through broach with drilling fluid. 4. Circulate up to 120 bbls of water or until water returns are seen from the broach. 5. RIH to 200' below the base of the conductor. Spot a 150' pill of 150K cp polymer (xanvis) to 50' below the conductor. POOH to 20' inside the conductor. 6. Mix and displace 25 bbls of Permafrost cement at 10.9 ppg. Displace cement to within 5 bbls of the end of drill pipe. Cement may U-tube with no ability to obtain squeeze. Do not over displace. Monitor and gauge all returns. 7. POOH and WOC for 8 hours. 8. PU 12-1/4" bit and BHA and RIH to clean out cement to 40' below conductor. Establish normal circulating rate and evaluate broaching. If no broaching is seen, continue with plan operations. If additional broaching occurs, repeat steps 6, 7 and 8. Page 20 of 24 GMH/EAO SAVANT RW#2 Confirmation Test ADL#367011 ALASKA Drilling Well Plan-March 2012 PWD Baseline Testing In order to ascertain the wellbore cleaning efficiency of the circulating system, it is necessary to establish baseline ECD parameters with a "clean" fluid prior to drilling ahead and contaminating the system with drilled solids. The following steps are the basis for obtaining usable baseline ECD parameters. 1. Prior to drilling out of both the surface and intermediate casings, or in the case of a sidetrack, after the sidetrack has been initiated, condition or displace the drilling fluid per the well plan. 2. Once the "drill-ahead" fluid has been conditioned, drill enough rat-hole to prevent casing wear from rotating BHA. Circulate clean and establish ECD values at the following rates and rotary rpm's. Complete the chart for each value 3. Well Name: Red Wolf#2 DP OD: 4" Normal Flowrate= gpm DC OD: 8 1/2" Normal RPM = BHA Length: MD=4550' Casing ID: 8.835" Mud Weight= 9.2ppq PV/YP: RPM @ 95% Normal Normal RPM RPM @ 105%Normal Flowrate @ 95% ECD= ECD= ECD= Normal Torque= Torque= Torque= Normal Flowrate ECD= ECD= ECD= Torque= Torque= Torque= Flowrate @ 105% ECD= ECD= ECD= 7 Norman ==Tor ueTorque= Torque= Torque= q q 3. ECD and torque values for each setting should be recorded only when values have reached stabilized condition. 4. Upon completion of the baseline testing, email or fax the results to the Operations Drilling Engineer. 5. Using Excel, graph "ECD vs. Flow-rate" for each rotary speed (Sperry Engineer) for use in correlating actual ECD's to baseline generated values when drilling operations proceed. Graphs should be available for reference in the doghouse and in the Company Man's office. p 9 p Y NOTE: In a 6-1/8" wellbore, with no solids removal, drilled solids alone will add 1.03 ppg/1000' drilled to a 750 bbl active system. In a 8 1/2"wellbore, with no solids removal, drilled solids alone will add nearly 2 ppg/1000' drilled to a 750 bbl active system. Page 21 of 24 GMH/EAO /� RW#2 Confirmation Test SAvANT ADL# 367011 ALASKA Drilling Well Plan-March 2012 Red Wolf#2 Drilling Hazards Summary (Post in Rig Floor Doghouse Prior to Spud) 12-1/4" Hole / 9-5/8"Casing_Interval Event Risk Level Mitigation Strategy Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, managed fluid rheology, decreased circulating times, controlled drilling rates, low mud temperatures Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Lost Circulation Medium Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled running speeds. Washouts, High Cool mud temperatures & minimize circulating Hole Sloughing time when possible. 8 1/2" Hole / 7"Casing Interval Event Risk Level Mitigation Strategy Lost circulation High Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre-planned LCM pills, lost circulation material. Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Directional Control Medium BHA design, on-sight geologic review and _ advisement of potential slump blocks. Sloughing Shale, Tight High Increased mud density and fluid composition Hole according to plan, controlled trip speeds, sweeps, ECD monitoring. Abnormal Reservoir Low Well control drills, increased mud weight, Pressure contingencies for top set casing string. Hydrogen Sulfide gas Low H25 drills, detection systems, alarms, standard Page 22 of 24 GMH/EAO Surface Casing Cementing Y Company: Savant Well Name: Red Wolf#2 Field: Badami State: AK Date: 12/12/2011 Well Location: Nabors 2-ES Proposal Number: V1 Contact: Mr. Erik Opstad Made By: Jeff Long Service from District: Prudhoe Bay, Ak District Phone: 907-659-2434 Objective: Cement to Surface in Permafrost and a competent shoe for drilling ahead. Disclaimer Notice Schlumberger submits this document with the benefit of As judgment,experience,and good oilfield practices. a iuremtsis providedmpis inferences swith generally noinalibled industry practice,relying on facts or information provided by others,limitations.computer models, berger measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES, RECOMMENDATIONS MADE.OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. 4 WELL DATA rt Well Data ,, .. . ,ii, Job Type: Casing Cementing Total Depth(Measured): 4550.0 ft True Vertical Depth(TVD): 4547.9 ft BHST(Tubular Bottom Static Temperature): 89 degF BHCT(Tubular Bottom Circulating Temperature): 69 degF Open Hole Mean Diameter without Excess Bottom Depth Annular Excess 12.250 in 4550.0 ft 30.0 Previous Casing OD Weight Grade Thread Inner Capacity Bottom Depth 20 in 133.0 lb/ft K-55 STC 1.91 ft3/ft 80.0 ft ` Casing 31 OD Weight Grade Thread Inner Capacity Bottom Depth wen Fluid sequence 9 5/8 in 40.0 lb/ft L-80 BTC 0.43 ft3/ft 4550.0 ft IMPORTANT: Annular Capacity(without Excess):Casing Bottom/Open Hole :0.31 ft3/ft The well data shown on this page is based on information available when this Annular Capacity(without Excess):Previous Casing Bottom/Casing :1.41 ft3/ft treatment program was prepared.This data must be confirmed on location with the wellsite supervisor prior to the treatment.Any changes in the well data need to be reviewed for their impact on the treatment design. Fluid Placement Fluid Name Volume Density Top of Fluid bbl _ lb/gal ft MUDPUSH II 100.0 _ 10.10 0.0 Lead Slurry 308.0 10.70 0.0 Tail Slurry 42.3 _ 15.80 4050.0 Mud 338.9 8.60 0.0 Total Liquid Volume:789.2 bbl 3 of 5 Schlumberger FLUID SYSTEMS MUDPUSH II System MUDPUSH II Density 10.10 lb/gal Total Volume 100.0 bbl Additives Code Description Concentration D031 Weighting Agent 2270.4 Ib/mgal Lead Slurry(707 sacks,100 lb per sack of Blend) System Conventional Density 10.70 lb/gal V Yield 2.45 ft3/sk 1� Mixed Water 11.515 gal/sk Mixed Fluid 11.515 gal/sk Total Volume 308.0 bbl Additives Code Description Concentration B809 ARCTICSET Lite III Cement B809 100 lb/sk WBWOB Tail Slurry(205 sacks,94 lb per sack of Blend) System Conventional Density 15.80 lb/gal 4/ Yield 1.16 ft3/sk I/ Mixed Water 5.103 gal/sk Mixed Fluid 5.103 gal/sk Total Volume 42.3 bbl Code Description Concentration D907 Cement 94 lb/sk WBWOB Additives D046 Anti Foam 0.2%BWOB D065 Dispersant 0.3%BWOB D167 Fluid loss 0.2%BWOB S002 CaCl2 0.2%BWOB Some of the chemicals specified in this program may have toxic properties. All personnel should be familiar with the inherent dangers and appropriate safeguards to prevent accidental injury.Use of the chemicals may be governed by certain laws and regulations and should only be used in accordance with such.Please refer to the MSDS sheets for the recommended safety precautions and required minimum personal protective equipment. 4of5 Schlumberger Intermediate Casing Cementing .y rte `., - 'ate d M i - wYY 1b 1"' `4*,.,, ',yL . , .. , Company: Savant .i _. Well Name: Red Wolf#2 Field: Badami State: AK Date: 12/12/2011 Well Location: Nabors 2-ES Proposal Number: V1 Contact: Mr. Erik Opstad Made By: Jeff Long Service from District: Prudhoe Bay, Ak District Phone: 907-659-2434 Objective: To provide casing support and a competent shoe for drilling ahead. Disclaimer Notice Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models. Schlumberger measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided mformatiwr All proposals,recommendations.or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA.INFORMATION PRESENTED.EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES, RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. r te,f, .IPTIPPliks, ' "N. .. `mss. WELL DATA ft Well Data o - - Job Type: Casing Cementing Total Depth(Measured): 11525.0 ft True Vertical Depth(TVD): 11519.7 ft BHST(Tubular Bottom Static Temperature): 243 degF BHCT(Tubular Bottom Circulating Temperature): 181 degF S 2 Open Hole Mean Diameter without Excess Bottom Depth Annular Excess 8.500 in 11525.0 ft 15.0% S Previous Casing OD Weight Grade Thread Inner Capacity Bottom Depth 9 5/8 in 40.0 lb/ft L-80 BTC 0.43 ft3/ft 4550.0 ft 1 Casing OD Weight Grade Thread Inner Capacity Bottom Depth Well Fluid Sequence 7 in 29.0 lb/ft L-80 BTC 0.21 ft3/ft 11525.0 ft IMPORTANT Annular Capacity(without Excess):Casing Bottom/Open Hole :0.13 ft3/ft The well data shown on this page is based on information available when this Annular Capacity(without Excess):Previous Casing Bottom/Casing :0.16 ft3/ft treatment program was prepared.This data must be confirmed on location with the wellsite supervisor prior to the treatment.Any changes in the well data need to be reviewed for their impact on the treatment design. Fluid Placement Fluid Name Volume Density Top of Fluid bbl lb/gal _ ft MUDPUSH II 30.0 10.50 _ 8870.0 Tail Slurry 41.9 15.80 10025.0 Mud 425.2 9.00 0.0 Total Liquid Volume:497.1 bbl 3 of 5 Schlumberger 116. 146, FLUID SYSTEMS MUDPUSH II System MUDPUSH II Density 10.50 lb/gal Total Volume 30.0 bbl Additives Code Description Concentration D031 Weighting Agent 2790.7 Ib/mgal Tail Slurry(155 sacks,94 lb per sack of Blend) System Conventional Density 15.80 lb/gal j Yield 1.53 ft3/sk j Mixed Water 6.339 gal/sk Mixed Fluid 6.359 gal/sk Total Volume 41.9 bbl Code Description Concentration D907 Cement 94 lb/sk WBWOB D177 Retarder 0.020 gal/sk VBWOC Additives D046 Anti Foam 0.2%BWOB D065 Dispersant 0.3%BWOB D167 Fluid loss 0.2%BWOB D066 Silica 35.0%BWOB Some of the chemicals specified in this program may have toxic properties.All personnel should be familiar with the inherent dangers and appropriate safeguards to prevent accidental injury.Use of the chemicals may be governed by certain laws and regulations and should only be used in accordance with such.Please refer to the MSDS sheets for the recommended safety precautions and required minimum personal protective equipment. 4 of 5 Schlumberger Production Liner Cementing f'4 1r4t4„ • � A L Company: Savant Well Name: Red Wolf#2 Field: Badami State: AK Date: 12/12/2011 Well Location: Nabors 2-ES Proposal Number: V1 Contact: Mr. Erik Opstad Made By: Jeff Long Service from District: Prudhoe Bay, Ak District Phone: 907-659-2434 Objective: To provide zonal isolation Disclaimer Notice Schlumberger submits this document with the benefit of its judgment.experience,and good oilfield practices. This information isprovidedkaccordance with tgenerally noinccebled industry practice,relying on facts or information provided by others,limitations,computer models, Schluniberger measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES, RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. s „A„ .ik— o WELL DATA ft Well Data — - - Job Type: Liner Cementing Total Depth(Measured): 12000.0 ft True Vertical Depth(TVD): 11994.5 ft BHST(Tubular Bottom Static Temperature): 253 degF BHCT(Tubular Bottom Circulating Temperature): 221 degF Open Hole Mean Diameter without Excess Bottom Depth Annular Excess 6.125 in 12000.0 ft 15.0% Previous Casing OD Weight Grade Thread Inner Capacity Bottom Depth 7 in 29.0 lb/ft L-80 BTC 0.21 ft3/ft 11525.0 ft 1 Drill Pipe OD Weight Grade Thread Inner Capacity Bottom Depth wen Fluid Sequence 4 in 15.5 lb/ft S-135 0.06 ft3/ft 11325.0 ft IMPORTANT Ceasing The well data shown on this page is based on information available when this treatment program was prepared.This data must be confirmed on location OD Weight Grade Thread Inner Capacity Bottom Depth with the wellsite supervisor prior to the treatment.Any changes in the well 4 1/2 in 12.6 lb/ft L-80 BTC 0.09 ft3/ft 12000.0 ft data need to be reviewed for their impact on the treatment design. Annular Capacity(without Excess):Casing Bottom/Open Hole :0.09 ft3/ft Fluid Placement Annular Capacity(without Excess):Previous Casing Bottom/Casing :0.10 ft3/ft Fluid Name Volume Density Top of Fluid bbl lb/gal ft MUDPUSH II 20.0 10.50 , 10199.3 Tail Slurry 18.2 15.80 11125.0 Mud 131.8 9.20 0.0 Total Liquid Volume:170.0 bbl 3 of 5 Schlumberger . ilk- FLUID SYSTEMS MUDPUSH II System MUDPUSH II Density 10.50 lb/gal Total Volume 20.0 bbl Additives Code Description Concentration D031 Weighting Agent 2790.7 lb/mgal Tail Slurry(67 sacks,94 lb per sack of Blend) System Conventional Density 15.80 lb/gal t/ Yield 1.53 ft3/sk / Mixed Water 6.331 gal/sk Mixed Fluid 6.351 gal/sk Total Volume 18.2 bbl Code Description _, Concentration D907 Cement 94 lb/sk WBWOB D177 Retarder 0.020 gal/sk VBWOC Additives D046 Anti Foam 0.2%BWOB D065 Dispersant 0.3%BWOB D167 Fluid loss 0.4%BWOB D066 Silica 35.0%BWOB Some of the chemicals specified in this program may have toxic properties.All personnel should be familiar with the inherent dangers and appropriate safeguards to prevent accidental injury.Use of the chemicals may be governed by certain laws and regulations and should only be used in accordance with such.Please refer to the MSDS sheets for the recommended safety precautions and required minimum personal protective equipment. 4 of 5 Schlumberger riliklik PRICE ESTIMATE Equipment and Services Code Standard Description Quantity Unit List Total List Discount Discounted Price Price Rate Price S S 49100000 Cement Service Charge 116 CF 3.93 455.88 35% 296.32 49102000 Cement Transport 193 TMile 2.90 559.70 35% 363.80 58498000 Day Rate: 1 EA 20,000.00 20,000.00 0% 20,000.00 Includes,Crew,Double-Pump cement unit,Plug Container,CemCAT job monitor,lab testing,cement storage.Crew on location after rig callout begins 24 hr. day.Crew off location ends time.1-day minimum Beyond 24 hrs.6 hr.increments at$5000.00 apply. Subtotals: $21,015.58 $20,660.12 Materials Code Standard Description Quantity Unit List Total List Discount Discounted Price Price Rate Price $ $ D031 Weighting Agent 24 CW 63.90 1,533.60 35% 996.84 D046 Anti Foam 13 LB 8.63 112.19 35% 72.92 D065 Dispersant 19 LB 13.28 252.32 35% 164.01 D066 Silica 2200 LB 0.51 1,122.00 35% 729.30 D167 Fluid loss 26 LB 77.48 2,014.48 35% 1,309.41 D177 Retarder 2 GA 49.88 99.76 35% 64.84 D907 Cement 67 CF 74.25 4,974.75 35% 3,233.59 D970 MUDPUSH II 20 BBL 209.33 4,186.60 35% 2,721.29 Subtotals: $14,295.70 $9,292.20 Total Discount: $ 5,358.95 Job Price Estimate*: $ 29,952.33 5 of 5 Schlumberger DRILLING FLUIDS PROGRAM Prudhoe Bay Unit Well Name: RedWolf#2 Grassroots Version #1.2 February 15,2012 Prepared for Mr.Erik Opstad General Manager Savant Alaska 4720 Business Park Blvd. Suite G40 Anchorage,Alaska 99503 Erik.Opstad(sav-antalaska.com 907-868-1258 Prepared by Mr.Chris MacKinnon Principle Technical Professional 6900 Arctic Blvd. Anchorage,AK.99518 907-275-2617 Chris.MacKinnon(a,Halliburton.com HALLIBURTON Baroid Fluid Services Operator Savant Alaska Well Name RedWolf#2 ver 1.2 Program Briefing Enclosed is our recommended procedure for Drilling Fluid Services in the referenced well. The information in this proposal includes well data,calculations,and cost estimates. This proposal is based on information from our field personnel,customer information and previous services in the area. If you require any additional information or additional designs,please feel free to contact myself or our field representatives. Prepared and Submitted by: Chris MacKinnon Technical Professional 40, Reviewed by: David Higbie Operations Leader Customer Approval: Erik Opstad General manager Baroid Fluid Services Page 2 of 20 HALLIBURTON I Fluid Systems Savant Alaska HALLIBURTON RedWolf#2 ver. 1.2 eal old Badami AK/U.S.A. Table of Contents 1.0 Program Briefing 1.0.1 Well Data Provided by Savant 1.0.2 Well Data 1.0.3 Deviation Data 1.0.4 Potential Problems and Solutions 1.0.5 Baroid Project Support team 2.0 Well Design 2.0.1 Proposed Casing Design 2.0.2 Drilling Fluid Target Properties 2.0.3 Drilling Fluid Objectives 2.0.4 Primary Products 3.0 Interval Discussions Surface Interval 3.0.1 Surface Interval Depths 3.0.2 Surface Interval Goals 3.0.3 Mud Maintenance and Operations Discussion Intermediate interval 3.1.1 Intermediate Interval Depths 3.1.2 Intermediate Interval Goals 3.1.3 Mud Maintenance and Operations Discussion Production Interval 3.2.1 Production Interval Depths 3.2.2 Production Interval Goals 3.2.3 Mud Maintenance and Operations Discussion 4.0 Well Volumes/Cost 4.0.1 Surface Interval Cost 4.0.2 Production Interval Cost 4.0.3 Total Well Cost 5.0 Appendixes 5.0.1 DFG Hydraulics 5.0.2 LCM Decision Tree 5.0.3 Sweeps Discussion 5.0.4 Testing at the Well site 5.0.5 Routine Sampling 5.0.6 Supporting Lab Data 3 HALLIBURTON Savant Alaska RedWolf#2 ver. 1.2 x . , .,;,a Badami AK/U.S.A. 1.0 Program Briefing RedWolf#2 is a Grassroots Exploration well,with the Kekiktuk zone 2 formation being the primary target. After the rig moves over the preinstalled 20"a 12 '/"surface hole will be drilled to 4550 ft MD using bland spud mud. 9 5/8"casing will be run and cemented. An 8 '/"intermediate hole will then be drilled to 11,525 ft and 7"casing run and cemented,this section will be drilled with+/-9.0 ppg LSND fluid. The hole section into the reservoir will be 6 1/8",and drilled through the anticipated target depth of 11,555 ft MD to 12,100 ft,using the same type LSND as the intermediate hole section. A 4 'h"liner will be run and cemented with 150 ft liner lap back into the 7"casing. A 4 'h"completion string will be run to surface to finish off the well. 1.0.1 Well Data Provided by Savant Data Provided Y/N Initial Comments Offset Wells Referenced for Y CM B1-21, B l-28 Data 1.0.2 Well Data Operator Savant Alaska Well No. RedWolf#2 Field/Block Badami Location Alaska/U.S.A Well Type Development/Grassroots Max. Well Deviation 0 deg Maximum Expected Mud Density 9.8 ppg Anticipated BHST at Total Depth of well 235°F Primary Target#1 Kekiktuk Formation, Zone 2 Primary Target#1 Depth 11,555'MD 11,555' TVD Estimated Mud Weight for Target#1 9.2 ppg Proposed TD Depth 12,100' MD 12,100' TVD 4 HALLIBURTON Savant Alaska RedWolf#2 ver. 1.2 earoid Badami AK/U.S.A. 1.0.4 Potential Problems and Solutions Pgm. Potential Depth Mud Type Mud Drilling Baroid Solutions Weight Hazard -Unconsolidated • Maintain hi funnel vis to carry sloughing pea` Gravel gravel. 0'--4,550' 8.6-9.5 -Solids Buildup v,"/MD Spud Mud ppg -Max 70 deg • Use cold lake water to maintain solids and / Temp temp<70 deg F. 4,550' 11,525' 9.0-9.8 • Always beware of kick detection and have MD LSND ppg Well Control products available to increase weight 2.0 lb/gal. 11,525'— 12,100' 9.2-9.3 • Always beware of kick detection and have MD LSND Well Control ppg products available to increase weight 2.0 lb/gal. 1.0.5 Baroid Project Support Team Baroid Support Team Title Name Cell Number Office Number Email address Chris Technical Professional MacKinnon (907) 227-5045 (907) 275-2617 Operations Leader David Higbie (907)242-7105 (907)275-2631 David.Hi2biecr I lalliburton.com Lead Mud Eng. Lead Mud Eng. Night Mud Eng. Night Mud Eng. John ,lohn..lessupvr Halliburion.com Stock-point Manager Jessup/Brent (907) 943-1028 (907) 659-2422 Brent.Edmunds(crllalliburton.com Edmunds Mud Engineer Positional Email • 5 HALLIBURTON Savant Alaska RedWolf#2 ver. 1.2 Baroid Badami AK/U.S.A. 2.0 Well Design 2.0.1 Proposed Casing/Completion Design Hole Size Casing/Liner Fluid Tops Bottom Size Density 12.25" 9 5/8" 40# 0' MD 4,550' MD 8.6-9.5 ppg Spud V 8.5" 7" 29# 0' MD 11,525' MD 9.0-9.8 ppg LSND 6.125" 4.5" 12.6# 11,375' MD 12,100' MD 9.2 ppg LSND ✓ 2.0.2 Drilling Fluid Properties 12.25" SURFACE: 8.6-9.5 ppg Spud Mud MD Mud Plastic Yield API H Gels Fluid MBT Weight Viscosity Point Vis ml p Temp 0-4,550' 8.6-9.5 10-30 25-55 300 <14 8.5-9.5 >22-30 `70 deg F 30-35 8.5"INTERMEDIATE: 9.0 ppg LSND Mud Plastic Yield HTHP MD Weight Vis Visy sit Point MBT API m1/30 min pH LGS l 4,550'—11,525' 9.0-9.8 40-60 9-24 15-25 <18 <8 <10 9.0-10 6.5 6.125"PRODUCTION: 9.2 ppg LSND Mud Plastic Yield HTHP MD Weight Vis Visy sit Point MBT API ml/30 min pH LGS l 11,525' — 12,100' 9.2 40-60 9-24 15-25 <18 <8 <10 9.0-10 6.5 2.0.3 Drilling Fluid Objectives Primary Objective: Drill the well safely,both with respect to personnel and the environment. 1) Well Control 2) Maintain borehole stability 3) Optimize Hole Cleaning through the use of DFG Hydraulics 4) Prevent Differentially Stuck Pipe 5) Prevent Balling on Drilling Assembly 6 Savant Alaska HALLI B URTO N RedWolf#2 ver. 1.2 (Darold Badami AK/U.S.A. 2.0.4 Primary Products Suface Hole PRODUCTS Product Description Product Function AQUAGEL Premium Bentonite Viscosifier Soda Ash Calcium Buffer Calcium Buffer DRIL-N-SLIDE Fatty Acid ester Lubricant/Clay Dispersant Caustic Soda Sodium Hydroxide pH Source X-TEND II Bentonite extender Polymer Intermediate/Production Holes PRODUCTS Product Description Product Function BAROID BULK Ground Barium Sulfate Weighting agent BARAZAN D PLUS Xanthan Gum Polymer Primary Viscosifier PAC L Cellulose Derivative Filtration Control Agent DEXTRID Modified Starch Filtration Control Agent CAUSTIC SODA Sodium Hydroxide pH Source ALDACIDE G Glutaraldehyde Biocide X-CIDE 207 Microbiocide Biocide NXS LUBE Sulfurized Olefin Lubricity DRIL-N-SLIDE Fatty Acid Ester Lubricity BDF-515 Modified Lignin Shale Inhibitor BAROTROL PLUS Sulfonated Asphalt Shale Inhibitor 3.0 Surface Interval Discussions 3.0.1 Surface Interval Depths: 0—4,550' MD 3.0.2 Interval Goals • Well Control • Control unconsolidated pea gravel beds • Land and cement 9 5/8"casing 3.0.3 Mud Maintenance and Operations Discussion Mud Type: SPUD MUD MD Mud Plastic Yield API pH Gels Fluid MBT Weight Viscosity Point Vis ml Temp 0-4,550' 8.6-9.5 10-30 25-55 300 <14 8.5-9.5 >22-30 70 deg F 30-35 Mix: Product Concentration Water 0.92 bbl Soda Ash 0.1 lb/bbl AQUAGEL 25 ppb (300 Vis) X-TEND II 0.125 lb/bbl(10 sx Gel- 1 sx X-TEND) CAUSTIC SODA 0.1 ppb (8.5-9.5 pH) DRIL-N-SLIDE 0.5 % 7 HALLI B LJ RTO N Savant Alaska RedWolf#Z ver. 1.2 Baroid Badami AK/U.S.A. Special Mixing Instructions: • Mix in order as listed Mud Type: SPUD MUD 1.Mud weight: Maintain the density at 8.6-9.5 ppg. to TD. Keep in mind the trip out will stir up more solids, raising the mud weight beyond the weight at TD. The use of solids control and dilution must be employed to maintain this mud weight. 2.Rheology: While drilling through any heavy gravel, maintain the funnel Vis at 300 sec/qt. This area has pea gravel down to +/- 4,000 ft and tends to run. Use X-TEND II to stretch the Bentonite and add viscosity, 1 sack of X-TEND should be used along with every 10 sacks of AQUAGEL. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this wellbore. Maximize pipe rotation(ideally> 100 RPM). 3. Temperature: Maintain mud temperature below 70 deg F to keep from thawing the permafrost. Ensure all dilution water and make up water for the Spud Mud system is cold lake water. 4. Solids Control: Maximize solids control usage. Check the shaker screens for holes on connections and replace as needed. The centrifuge/mud cleaner should be run at all times once through the any heavy gravel. Operations Summary: Once 9ES is spotted over the well,begin building the+/- 600 bbl of Spud Mud in the pits. The mud will be formulated with AQUAGEL and Soda Ash.The remaining products will be added once the rig is drilling ahead. Check the funnel vis and maintain at 300 until gravel disappears from the shakers.Other wells in the area indicate pea gravel beds run deep,if the fluid is too thin,it will wash out the pea gravel zones and make pipe running impossible. Maintain good thick spud mud. If runnning gravel is seen, STOP drilling and increase the viscosity. If airation or gas hydrates are seen,add DRIL-N-SLIDE to help the entrained air-gas break out. Suggested Drilling Parameters Pump rate and fluid rheology should be optimized through the real-time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue in this interval. Maximum Acceptable ROP in fph at Specified GPM and RPM *Calculated using 4%maximum cuttings load GPM* 600 650 700 80 rpm 97 100 103 100 rpm 130 135 143 120 rpm 148 160 170 Rheology and pump rate are the most critical factors in cleaning this wellbore. Maximize rpms when possible. ROPs above these levels or with no rotation (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: • extended periods of circulation(with maximum pipe rpm,targeting> 100 rpm) • hole cleaning sweeps (change flow regime of base mud by using density or rheology for carrying capacity) 8 HALLIBURTON Savant A RedWolf#2 verr.. 11.2 .2 Baroid Badami AK/U.S.A. • connection practices-employing extended gpm,rpm and back reaming,prior to the connection 3.1 Intermediate Interval Discussions 3.1.1 Interval Depths: 4,550'—11,525' MD 3.1.2 Interval Goals • Well Control ■ Mainatin Borehole Stability ■ Prevent balling on drilling assembly • Efficient hole cleaning • Land casing on bottom and cement 3.1.4 Mud Maintenance and Operations Discussion 8.5"INTERMEDIATE:9.0 ppg LSND Mud Plastic Yield HTHP MD Weight Vis Viscosit Point MBT API m1130 min pH LGS y 4,550' — 11,525' 9.0-9.8 40-60 9-24 15-25 <18 <8 <10 9.0-10 6.5 System Formulation: 9.0 LSND Product Concentration Water 0.96 bbl BARAZAN D+ 1.5 lb/bbl (as required 15-25 YP) PAC L 2 lb/bbl DEXRID LT 2 lb/bbl Caustic 0.1 ppb (9.0-10.0 pH) BAROID 41 28 ppb ALDACIDE G 0.2 ppb DRIL-N-SLIDE 0.5 %v/v Addition for Shale penetration+1-11,190 ft MD BDF-515 4.0 lb/bbl BAROTROL+ 4.01b/bbl BAROID 41 76 ppb(Raise MW to 9.8 ppg) Special Mixing Instructions: • Mix in order as listed • Add polymers slowly to minimize fisheyes • Add lubricants as needed from the rig site Mud Type: 9.0 ppg LSND 1.Mud weight: Begin drilling with the density at 9.0 ppg, adjust as well conditions dictate. The use of solids control and dilution must be employed to maintain this mud weight. 2.Rheology: While drilling, maintain the YP between 15 and 25. Pump high weight sweeps throughout the interval as needed,particularly prior to POOH for casing. Optimized mud rheology and flow rate 9 Savant Alaska HALLIBURTON RedWolf#2 ver. 1.2 Baroid Badami AK/U.S.A. will be the primary mechanisms for achieving good hole cleaning in this wellbore. Maximize pipe rotation when possible(ideally> 100 RPM). 3. Well Control: A weight up is required through the shale sections in the intermediate hole. Above the HUE shale increase the MW to 9.8 ppg. Always pay close attention to kick indicators while drilling. Maintain enough weight material on location to raise the mud weight of the circulating system by 2.0 ppg. Operations Summary: Displace the well to 9.0 ppg LSND fluid after drilling the surface casing float equipment. Use a 50 bbl 9.0 ppg low viscosity sweep followed by a 50 bbl Hi viscosity sweep prior to pumping the new mud to ensure a clean displacement to the LSND. Make sure pipe rotation and pump rates are at the maximum during the displacement. Maintain the product concentrations when dilution water is added. Maintain the mud as clean as possible while drilling. Should sweeps be required, a High vis sweep is recommended in this straight wellbore. Raise the mud weight to 9.8 ppg prior to drilling through HUE shale,prognosed at 11,190 ft MD. Utilize DFG prior to pumping any sweeps to determine ECD calculations across the shoe with a sweep in the hole. Casing running preparation: Prepare to use moderately heavy dilution, especially when cleaning the hole up for casing running. Sweep Formulation: Hi Vis sweep, 30 bbl of mud with—2 sx BARAZAN D+added. Suggested Drilling Parameters Watch the ECD if available while drilling and shaker loading to determine whether the hole is being cleaned or not. Run DFG+ realtime to assist in hole cleaning determination and strategies. Pump rate and rheology should be optimized through the real-time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue in this interval. Maximum Acceptable ROP in fph at Specified GPM and RPM *Calculated using 3%maximum cuttings load GPM* 500 550 600 80 rpm 300 344 368 100 rpm 313 351 380 120 rpm 317 352 381 Rheology,pipe rotation and pump rate are all critical factors in cleaning this deviated wellbore. Maximize rpms at all times. ROPs above these levels or with no rotation (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: • extended periods of circulation(with maximum pipe rpm,targeting> 100 rpm) • hole cleaning sweeps(change flow regime of base mud by using density or rheology for carrying capacity) • connection practices- employing extended gpm,rpm and back reaming,prior to the connection Hazards/Concerns—Intermediate Interval: • Well Control • Wellbore Stability 10 HALLIBURTON Savant Alaska RedWolf#2 ver. 1.2 Baroid Badami AK/U.S.A. • Failure to get casing to bottom 3.2 Production Interval Discussions 3.2.1 Interval Depths: 11,525' MD-12,100' MD 3.2.2 Interval Goals • Well Control • Run and land 4 'h"liner 3.2.4 Mud Maintenance and Operations Discussion 6 1/8" Production Hole: 9.2 ppg LSND Mud Plastic Yield HTHP MD Vis. Viscosit MBT API pH LGS % Weight Point ml/30 min v ml 11,525' 12,100' 6.93„./ 40-60 9-24 15-25 <18 <8 <10 9.0-10 ;6.5 System Formulation: 9.2 LSND Product _ Concentration Water 0.955 bbl BARAZAN D+ 1.5 lb/bbl (as required 15-25 YP) PAC L 2 lb/bbl DEXRID LT 2 lb/bbl Caustic 0.1 ppb (9.0-10.0 pH) BAROID 41 40 ppb ALDACIDE G 0.2 ppb DRIL-N-SLIDE 0.5 %v/v Special Mixing Instructions: • Mix in order as listed • Add polymers slowly to minimize fisheyes • Add lubricants as needed from the rig site Mud Type: 9.2 ppg LSND 1.Mud weight: Begin drilling with the density at 9.2 ppg, adjust as well conditions dictate. The use of solids control and dilution must be employed to maintain this mud weight. 2. Rheology: While drilling, maintain the YP between 15 and 25. Pump high weight sweeps throughout the interval as needed,particularly prior to POOH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving good hole cleaning in this wellbore. Maximize pipe rotation when possible(ideally> 100 RPM). 3. Well Control: Always pay close attention to kick indicators while drilling. Maintain enough weight material on location to raise the mud weight of the circulating system by 2.0 ppg. 11 HALLIBURTON Savant Alaska RedWolf#2 ver. 1.2 earoid Badami AK/ U.S.A. Operations Summary: Displace the well to new 9.2 ppg LSND fluid for drilling the reservoir,after drilling up the float equipment on the 7" casing. Use a 50 bbl 9.2 ppg low viscosity sweep followed by a 50 bbl 9.2 ppg Hi viscosity sweep prior to pumping the new mud to ensure a clean displacement to the LSND.Make sure pipe rotation and pump rates are at the maximum during the displacement. Maintain the product concentrations when dilution water is added.Maintain the mud as clean as possible while drilling. Should sweeps be required,a High vis sweep is recommended in this straight wellbore. Utilize DFG prior to pumping any sweeps to determine ECD calculations across the shoe with a sweep in the hole. Sweep Formulation: Hi Vis sweep,30 bbl of mud with—2 sx BARAZAN D+added. Suggested Drilling Parameters Watch the ECD if available while drilling and shaker loading to determine whether the hole is being cleaned or not. Run DFG+ realtime to assist in hole cleaning determination and strategies. Pump rate and rheology should be optimized through the real-time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue in this interval. Maximum Acceptable ROP in fph at Specified GPM and RPM *Calculated using 3%maximum cuttings load GPM• 200 250 300 80 rpm 163 201 238 100 rpm 164 201 240 Rheology,pipe rotation and pump rate are all critical factors in cleaning this deviated wellbore. Maximize rpms at all times. ROPs above these levels or with no rotation (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: • extended periods of circulation(with maximum pipe rpm,targeting> 100 rpm) • hole cleaning sweeps(change flow regime of base mud by using density or rheology for carrying capacity) • connection practices-employing extended gpm,rpm and back reaming,prior to the connection Hazards/ Concerns—Production Interval: • Well Control • Wellbore Stability • Failure to get liner to bottom 12 HALLI B URTO N Savant Alaska RedWolf#2 ver. 1.2 Baroid Badami AK/U.S.A. 4.0 Well Volumes/Cost Estimated Fluid Volumes: P10 P50 P90 12.25"Surface 4,012 4,695 8,562 8.5"Intermediate 3,710 5,105 7,198 6.125"Production 1,070 1,117 1,350 Completion 580 870 1,160 Total 9,372 11,787 18,270 Estimated Drill Solids Disposal Volumes: P10 P50 P90 Wellbore Cuttings Volume 1170 1537 2087 Mud on Cuttings 990 1908 3954 Total 2160 3445 6041 4.0.3 Total Well Cost: Fluid Costs: P10 P50 P90 Surface $ 58,415 $ 68,360 $ 124,663 Intermediate $ 215,218 $278,511 $ 365,841 Production $ 64,713 $ 86,555 $ 113,412 Engineering $ 62,400 $ 72,000 $ 84,000 Total $400,746 $505,426 $687,916 13 HALLIBURTON Savant Alaska RedWolf#2 ver. 1.2 Baroid Badami AK/U.S.A. 5.0 Appendixes 5.0.1 DFG Hydraulics Surface Interval 'Jpoetor.Saved Alaska Bleck Badarti Court:USA Spud Mud 3.406XCultiogTdal vie!:BM 02 ODE:ErkOpsladTech:Chi!Madmnen fbwRale=650goUm0 01P=1111hr 3401%ClingEff Diligc Tramporf Average Hole ECD Mud Wei¢4=9.5Ngal Cu16gDia=.25h LoadX EDavgX V,Min Angle bfgal R10 135flM100gel/HD1001pmdm/C4m/ 2.20 J bmlin 200 A F k _ ® fwik 80.OpOIft U614/9.803 NO 1000— — 14.o924x37300ftl 2000— 3000 3.53 II 1 II 4000 I \ L \I4.x3.34x500011 , 1 12250 13.75x2.25x200.0NI 4801:_1 '111 Q 101'3/1.5'1 hal B75x225x12QONI i i i s 4739.0 5 10 15 0 25 0 50 100 0 108 217 30 60 90 9.50 10.50 1150 1.2fiCUT Pme 14 HALLIBURTON Savant Alaska RedWolf#2 ver. 1.2 Garold Badami AK/U.S.A. Intermediate Interval Jp5a(arSeal Alaska 81ock8adami Carey.USA SpudMud 2894%Cdtirgldd Wd:Rekl42 ODE:Eri;OpsladTech Chris Mairnon RowRale=500gd+mn ROP 051111rr 289MultingEff Cuttigt Transport Average I Hole ECD MadWeg1:92b/gd keg 15.t Load,$ EH erg V,It/sig Angle 61ga1 R1s@ 11Ui100rpm IHG100rpm-4mlC4nI 3.05 -- �oCd1 20n Cut 60..0[80E'14 9241/9.413 b/gd 1000-- 2000 4000- 8.935a 33] 101455u�1ft 5000_ 9466/9.6E2 b/gd — 324 10105011 6000= 7000- 1 9000 10000-- L4, 331x5000 11000 00 85n a I 6.75 u 2.25 w 2000N � E ` 11525111192311 a 6.75 2.25 x 1200111HI 11:.4.4 9. 19.924 bled 5 10 15 325 0 50 100 0 230 459 3) 60 90 9.15 9R 1010 1.Qh CUT hoc 15 r HALLIBIJRTON Savant Alaska RedWolf#2 ver. 1.2 ea,.(,;,_, Badami AK/U.S.A. Production interval gator.Save Alia DaBadayi Cw.USAry, Spud Mud 266dXCultrgid� etRedwd#2 ODE:EolDphadiecht}naMa Tran EbwRae=250gaVen ROP=3230hr 2.56BtiCdigEH WingsImpel AvexagHak ECD MudWeghl=90blgd Cu06gDa=056 load,t EHavgZ V,Win bfgal R1 s@33NM10D�m1HG100pr4/C�m! �a 211 3.29 p,� 25 in J W0 wire 80.0 1ft I 9.03719.455 6/gal 1000 2000 3000. 4000= - 8.8956 1 27d111111 4550.01E01 5000•_ 9224/9.577 Ngh d.x 324 a 1118000 6000- 7000 6000-- I i 1 9000•_ _ II i1 t 1 ^ 1 1 \ \ III H 11000 ...... .... ,, I . .00 6.2766 4.x3.34x500.00 115250(11525.0)0 h. .00 .� I +� � f i 6.1256 0.15 x 2.25 x 200000 12000 LC— I 12E01120)45 I � r i i r X12387.6 PRMall- 9.718110.0'1, biga! 4.75 x 2.25 x 12000 5 10 15 20 25 0 50 100 0 2(6 410 ;0 ou 90 900 1000 11.00 1.41ICU1 hoe 16 HALLIBURTON Savant Alaska RedWolf#2 ver. 1.2 Baroid Badami AK/U.S.A. 5.0.2 LCM Decision Tree Losses Lost Circulation Decision Tree fl Intermediate Hole Sections + + + Seepage Partial Severe Total 5-20 bblihr Static 20 0 bbllhr 60.200 bbllhr Static >200 bbllhr Static Static Treat AdNe System Treat Active System + I + - 5 Sctiv Barofibre with 10 sxlhr 60.150 bbl/lir Static 150-200 bbVhr Static Drill Across Fault withBAROFIBRE j i Drill Across Fault Drill Across Fault Contact Drilling I nami + + Engineer or Engineer on call Losses<15 Yes1 namic 1W ppb LCMIMud Pill: bbl/hr Losses<25 Yes 20 ppb BarosealF Contact Drilling Engineer 4, bbllhr 1 20 ppb Baroseal M 30 ppb Barc fibre or Engineer on call. Drill Ahead Drill Ahead 20 ppb Wallnut M • No 10 ppb Wallrwt F V No Increase Treatment to 1 • POOH,PIU dumb iron BHA 5 sxlhr Barofibre 70 ppb LCM/Mud Pill: Contact Drilling Engineer or 5 sxlhr Baracarb 50 i Engineer"On Call". 20 ppb Baroseal F 20 ppb Baroseal M Consider spotting EZ SQUEEZE pill. 20 ppb Barofibre • namic 10 ppb Wallnut M Consider spotting EZ Losses<15 Yes SQUEEZE pilllcementl bbl/hr plugback contingency Drill Ahead No rpp. rrrLi. •i : Dynamic Losses<15 Yes 10 ppb Baroseal F bbVhr 10 ppb Baroseal M Drill Ahead 10 ppb Barofibre r 10 s pb Wallnut M No t Notes: Contact Drilling 1)Drill across fault a loss zone 1.5-2.0 times the length of the throw ng before spotting LCM pills. Engineer or Engineer 2)Ciro Sub should be run in BHA to spot pills if"Partial Loss'cases I namic on call to determine if or above ore antidpated prior to drilling,to allow the spotting of LCM Losses<15 Yes pills. additional LCM bbl/hr treatments are to be 3)LCM pill volume=300-600'cdumn based upon actual hde diameter. Drill Ahead made. 4)PRIOR TO ANY LCM PILL,APPROPRIATE DISCUSSIONS AT THE RIG SITE MUST BE MADE TO MINIMIZE THE POTENTIAL No FOR PLUGGING THE DRILL STRING. CONTACT THE MWD V ENGINEER FOR SIZING AND PPB MAXIMUM QUANTITIES Proceed to'Partial ALLOWABLE THROUGH BHA. Losses'Pill J 17 Savant Alaska HALLIBURTON RedWolf#2 ver. 1.2 Baroid Badami AK/U.S.A. Losses Lost Circulation Decision Tree fl Pa one Mud Systems Yz • i Seepage Partial Severe Total 2040 bbllhr 5-20 bblihr Static Static 60-200 bbllhr Static >200 bbllhr Static i i I Treat Active System Treat Active System + + w with 5 sx/hr Baracarb with 10 szlhr Baracarb 60-150 bbVhr Static 150-200 bblThr Static Drill Across Fault 501150 150 + • Drill Across Fault Drill Across Fault Contact Drilling • i Engineer or Engineer nami Inamic 10o ppb LCM!Mud Pill: Contact Drilling Engineer on call Losses<15 Yes bbVhr Losses<15 Yes 20 ppb Baroseal f or Engineer on call. bbVhr 20 ppb Baracarb 50 30 ppb Barofibre Consider drill ahead wl 20 ppb StedSeal seawater v No Drill Ahead Drill Ahead 10 ppb Baracarb 150 Consider drilling ahead i No without returns Increase Treatment to V 10 sxlhr Baracarb 50/ 50 ppb LCMIMud Pill: Contact Drilling Engineer or 150 i 20 bbls Base mud Engineer"On CaIP'. Consider drill ahead wl 10 ppb Baracarb 25 seawater 20 ppb Baracarb 50 - I namic 20 ppb Baracarb 150 Losses<15 Yes bbVhr Drill Ahead No v I 20 ppb LCMIMud Pill: mic Losseess<20 Yes 20 bbls base mud bbVhr 10 ppb Baracarb 50 Drill Ahead 10 ppb Baracarb 150 No i 1)ODE must approve any steps past PARTIAL losses. Contact the Engineer 2)Drill across fault or loss zone 1.5-2.0 times the length of the I namic on call to determine if throw before spotting LCM pills. additional LCM 3)PBL sub should be run in BHA to spot pills if'Partial Loss'cases or Losses<15 Yes above are anticipated priorto drilling to allow the spotting of LCM bbllhr treatments are to be pills. made 4)LCM pill vdume=300'-600'column based upon actual hole Drill Ahead diameter. 5)PRIOR TO ANY LCM PILL,APPROPRIATE DISCUSSIONS AT No THE RIG MUST BE MADE TO MINIMIZE THE POTENTIAL FOR i PLUGGING THE DRILL STRING. Proceed to'Partial Losses'Pill 18 Savant Alaska HALLIBURTON RedWolf#2 ver. 1.2 Badami AK/U.S.A. 5.0.3 SWEEPS While using sweeps, we need to keep several things in mind. They are neither a miracle nor a cure-all. They are a specific tool and have a specific application. Sweeps have been proven effective in increasing ability to clean the hole when using the proper sweep for the appropriate scenario. If not properly used,there will be little,if any, benefit. Dos: • Calculate the height of the sweep in the vertical part of the annulus and calculate the added hydrostatic head in the annulus. Always pump a minimum of 500' annular volume • Check ECD/FIT parameters before deciding to use a weighted sweep. • Pump the sweep while rotating at maximum allowable rotating speed. • Schedule the sweeps to allow for both time and footage minimums. Since barite/silt build-ups are dependent on both,we recommend every 6-8 hours or 300-500 feet,whichever comes first unless the hole dictates greater frequency. • When the sweep clears the bit, keep pumping and rotating until the sweep is well into the vertical part of the hole. If the pumps are stopped while the sweep is in the deviated hole it will fall out of the "flow path" and redeposit much of the fines it captured. • Consider all factors when deciding on a sweep strategy,including ROP,hole angle, are you sliding or rotating ahead. Answering these questions will help to decide which sweep to pump and the pumping frequency. Don'ts: • Do not viscosify weighted sweeps. Dilution may be used to ensure sweep viscosity is held to a minimum. • Do not allow more than one weighted sweep in the annulus at a time. • Do not check for flow or close the Hydril with the weighted sweep in the drill pipe. • Do not look on a shaker screen coarser than 210 mesh for the full effect of the weighted sweep. 175's may show 10— 15 %of the fines removed. • Do not count on major benefit from a single sweep. Sometimes three or four sweeps are necessary to achieve desired results. • Do not count on benefiting from a sweep that is pumped while sliding. The lower side of the annulus under the drill pipe cannot be properly cleaned while sliding. 5.0.4 Testing at the Well sight • During normal drilling operations one complete mud check should be run every 6 hours with a lagged sample tested. This is a total of four complete checks made over a 24-hour period. Timing for mud checks and cost cut-off should be worked out with the drilling foreman. Unusual circumstances and/or non-circulating periods should dictate deviations from this schedule. • All rheological properties (i.e. 6-speed readings and gel strengths, including 30-minute gels) should be taken at the standard 120°F. 5.0.5 Routine Samplinz • Mud samples (1 QT) should be sent in any time the need arises, i.e. hole problems, lubricant problems or shaker blinding. • Samples of the mud plant built fluids, will be tested prior to shipment to the rig site and saved until the well is completed. • Samples of new mud delivered to the rig site, will be checked for weight and rheology at a minimum, prior to offloading into the rig pits. 19 HALLI B U RTO N Savant Alaska RedWolf#2 ver. 1.2 Badami AK/U.S.A. 5.0.6 Supporting Lab Data • These systems have been run numerous times with similar properties. Lab testing has been done for all of these mud systems on offset wells. Houston Lab test#64051/64046/87937/70720 • Offset wells and pad data collected in this mud program were from the following sources: Badami#5,B1-38. 20 f 'a I t Savant Red Wolf Red Wolf Red Wolf 2 G" Red Wolf 2 A, 4 .a rra I 7! Pi- $ Plan: Red Wolf 2 Wp 2.0 ,i Standard Proposal Report 44 4 15 February, 2012 g m'x spm yam, MEI HALLIBURTON rt Sperry Drilling Services aK HALLIBUI-tTON Project: Red Wolf Site: Red Wolf \ Well: Red Wolf 2 Sperry Drilling Wellbore: Red Wolf 2 Red Wolf 2 Wp 2.0 SURVEY PROGRAM REFERENCE INFORMATION Date:2012-02-15T00:00:00 Validated:Yes Version: Co-ordinate(N/E)Reference: Well Red Wolf 2,True North Depth From Depth To Survey/Plan Tool Vertical(TVD)Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) 33.50 4550.00 Red Wolf 2 Wp 2.0(Red Wolf 2) MWD Measured Depth Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) 4550.00 10025.00 Red Wolf 2 Wp 2.0(Red Wolf 2) MWD Calculation Method: Minimum Curvature 10025.00 12040.00 Red Wolf 2 Wp 2.0(Red Wolf 2) MWD WELL DETAILS: Red Wolf 2 Ground Level: 2.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5910479.00 356686.00 70°9'46.577 N 151°9'10.97 W Vertical Section at 0.00°(2000 ft/in) -4000 -3000 -2000 -1000 0 1000 2000 3000 4000 FORMATION TOP DETAILS 1000 iiiiliiiiiiII IiiiiIiiiiiiiiiIiiiiliiii -1000 TVDPath MDPath Formation 6175.50 6175.50 COR1 W 6655.50 6655.50 MK2 �1� 6800.50 6800.50 Ugnu 0 -0 7165.50 7165.50 West Sak - 7760.50 7760.50 MK3 20" 8095.50 8095.50 M 85 - 10740.50 10740.50 KMKR _ 10870.50 10870.50 KSND 1000- -1000 11225.50 11225.50 Hue Shale 11355.50 11355.50 Top HRZ 11525.50 11525.50 Base HRZ - - 11590.50 11590.50 LCU - - 11940.50 11940.50 Kek 1 2000- -2000 - - CASING DETAILS 3000- -3000 - ND MD Name Size 80.00 80.00 20" 20 _ 4550.00 4550.00 9 5/8" 9-5/8 _ 11525.00 11525.00 7" 8-1/2 4000- -4000 12040.00 12040.00 4 1/2" 4-1/2 9 5/8" COMPANY DETAILS: Savant c 5000- COR1 -- 5000 2 Calculation Method: Minimum Curvature 4= _ CD Error System: ISCWSA 0 _ < Scan Method: Tray.Cylinder North o - - Error Surface: Elliptical Conic N 6000- -6000 n Warning Method: Rules Based L _ G1 a - Ugnu = 0 (D 0 - - 13 West Sak - s To 0 7000- --7000 N f MK3 - 0CD 0 _ 0 C M 85 - g 1_8000- -8000 9000- -9000 KMKR - 10000- KSND -10000 Hue Shale 11000- Top HRZ -- 11000 Base HRZ JL. 7" - 12000- LCU ) L 4 1/2" -12000 - Kek 1 - TD at 12040.00'MD;12040'TVD _ 13000- -13000 Red Wolf 2 Wp 2.0 - 14000 i i i -I i i i i I i i i I I I I I I I I i i i i I I i i i I I I I I I r-14000 -4000 -3000 -2000 -1000 0 1000 2000 3000 4000 Vertical Section at 0.00°(2000 ft/in) 1 Halliburton Company HALLIBURTON Standard Proposal Report Database: .AK Compass PRD.16 Local Co-ordinate Reference: Well Red Wolf 2 Company: Savant TVD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Project: Red Wolf MD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Site: Red Wolf North Reference: True Well: Red Wolf 2 Survey Calculation Method: Minimum Curvature Wellbore: Red Wolf 2 Design: Red Wolf 2 Wp 2.0 Project Red Wolf Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Red Wolf Site Position: Northing: 5,913,400.00ft Latitude: 70° 10'14.327 N From: Map Easting: 351,540.00ft Longitude: 151° 11'41.64 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.12 ° Well Red Wolf 2 Well Position +N/-S 0.00 ft Northing: 5,910,479.00 ft Latitude: 70°9'46.577 N +E/-W 0.00 ft Easting: 356,686.00 ft Longitude: 151°9'10.97 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 2.00 ft Wellbore Red Wolf 2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2011 3/31/2012 19.93 80.67 57,582 Design Red Wolf 2 Wp 2.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 33.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 33.50 0.00 0.00 0.00 2/15/2012 2:35:56PM Page 2 COMPASS 2003.16 Build 73 Halliburton Company HALLIBURTON Standard Proposal Report Database: .AK Compass PRD.16 Local Co-ordinate Reference: Well Red Wolf 2 Company: Savant TVD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Project: Red Wolf MD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Site: Red Wolf North Reference: True Well: Red Wolf 2 Survey Calculation Method: Minimum Curvature Wellbore: Red Wolf 2 Design: Red Wolf 2 Wp 2.0 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 33.50 0.00 0.00 33.50 -2.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 64.50 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 164.50 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 264.50 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 364.50 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 464.50 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 564.50 0.00 0.00 0.00 0.00 0.00 0.00 700.00 0.00 0.00 700.00 664.50 0.00 0.00 0.00 0.00 0.00 0.00 800.00 0.00 0.00 800.00 764.50 0.00 0.00 0.00 0.00 0.00 0.00 900.00 0.00 0.00 900.00 864.50 0.00 0.00 0.00 0.00 0.00 0.00 ' 1,000.00 0.00 0.00 1,000.00 964.50 0.00 0.00 0.00 0.00 0.00 0.00 1,100.00 0.00 0.00 1,100.00 1,064.50 0.00 0.00 0.00 0.00 0.00 0.00 1,200.00 0.00 0.00 1,200.00 1,164.50 0.00 0.00 0.00 0.00 0.00 0.00 1,300.00 0.00 0.00 1,300.00 1,264.50 0.00 0.00 0.00 0.00 0.00 0.00 1,400.00 0.00 0.00 1,400.00 1,364.50 0.00 0.00 0.00 0.00 0.00 0.00 1,500.00 0.00 0.00 1,500.00 1,464.50 0.00 0.00 0.00 0.00 0.00 0.00 1,600.00 0.00 0.00 1,600.00 1,564.50 0.00 0.00 0.00 0.00 0.00 0.00 1,700.00 0.00 0.00 1,700.00 1,664.50 0.00 0.00 0.00 0.00 0.00 0.00 1,800.00 0.00 0.00 1,800.00 1,764.50 0.00 0.00 0.00 0.00 0.00 0.00 1,900.00 0.00 0.00 1,900.00 1,864.50 0.00 0.00 0.00 0.00 0.00 0.00 I 2,000.00 0.00 0.00 2,000.00 1,964.50 0.00 0.00 0.00 0.00 0.00 0.00 2,100.00 0.00 0.00 2,100.00 2,064.50 0.00 0.00 0.00 0.00 0.00 0.00 2,200.00 0.00 0.00 2,200.00 2,164.50 0.00 0.00 0.00 0.00 0.00 0.00 2,300.00 0.00 0.00 2,300.00 2,264.50 0.00 0.00 0.00 0.00 0.00 0.00 2,400.00 0.00 0.00 2,400.00 2,364.50 0.00 0.00 0.00 0.00 0.00 0.00 2,500.00 0.00 0.00 2,500.00 2,464.50 0.00 0.00 0.00 0.00 0.00 0.00 2,600.00 0.00 0.00 2,600.00 2,564.50 0.00 0.00 0.00 0.00 0.00 0.00 2,700.00 0.00 0.00 2,700.00 2,664.50 0.00 0.00 0.00 0.00 0.00 0.00 2,800.00 0.00 0.00 2,800.00 2,764.50 0.00 0.00 0.00 0.00 0.00 0.00 2,900.00 0.00 0.00 2,900.00 2,864.50 0.00 0.00 0.00 0.00 0.00 0.00 ' 3,000.00 0.00 0.00 3,000.00 2,964.50 0.00 0.00 0.00 0.00 0.00 0.00 3,100.00 0.00 0.00 3,100.00 3,064.50 0.00 0.00 0.00 0.00 0.00 0.00 3,200.00 0.00 0.00 3,200.00 3,164.50 0.00 0.00 0.00 0.00 0.00 0.00 3,300.00 0.00 0.00 3,300.00 3,264.50 0.00 0.00 0.00 0.00 0.00 0.00 3,400.00 0.00 0.00 3,400.00 3,364.50 0.00 0.00 0.00 0.00 0.00 0.00 3,500.00 0.00 0.00 3,500.00 3,464.50 0.00 0.00 0.00 0.00 0.00 0.00 3,600.00 0.00 0.00 3,600.00 3,564.50 0.00 0.00 0.00 0.00 0.00 0.00 3,700.00 0.00 0.00 3,700.00 3,664.50 0.00 0.00 0.00 0.00 0.00 0.00 3,800.00 0.00 0.00 3,800.00 3,764.50 0.00 0.00 0.00 0.00 0.00 0.00 3,900.00 0.00 0.00 3,900.00 3,864.50 0.00 0.00 0.00 0.00 0.00 0.00 4,000.00 0.00 0.00 4,000.00 3,964.50 0.00 0.00 0.00 0.00 0.00 0.00 4,100.00 0.00 0.00 4,100.00 4,064.50 0.00 0.00 0.00 0.00 0.00 0.00 4,200.00 0.00 0.00 4,200.00 4,164.50 0.00 0.00 0.00 0.00 0.00 0.00 4,300.00 0.00 0.00 4,300.00 4,264.50 0.00 0.00 0.00 0.00 0.00 0.00 4,400.00 0.00 0.00 4,400.00 4,364.50 0.00 0.00 0.00 0.00 0.00 0.00 4,500.00 0.00 0.00 4,500.00 4,464.50 0.00 0.00 0.00 0.00 0.00 0.00 4,600.00 0.00 0.00 4,600.00 4,564.50 0.00 0.00 0.00 0.00 0.00 0.00 4,700.00 0.00 0.00 4,700.00 4,664.50 0.00 0.00 0.00 0.00 0.00 0.00 2/15/2012 2:35:56PM Page 3 COMPASS 2003.16 Build 73 Halliburton Company HALLIBURTON Standard Proposal Report Database: .AK Compass PRD.16 Local Co-ordinate Reference: Well Red Wolf 2 Company: Savant TVD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Project: Red Wolf MD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Site: Red Wolf North Reference: True Well: Red Wolf 2 Survey Calculation Method: Minimum Curvature Wellbore: Red Wolf 2 Design: Red Wolf 2 Wp 2.0 4,800.00 0.00 0.00 4,800.00 4,764.50 0.00 0.00 0.00 0.00 0.00 0.00 4,900.00 0.00 0.00 4,900.00 4,864.50 0.00 0.00 0.00 0.00 0.00 0.00 5,000.00 0.00 0.00 5,000.00 4,964.50 0.00 0.00 0.00 0.00 0.00 0.00 5,100.00 0.00 0.00 5,100.00 5,064.50 0.00 0.00 0.00 0.00 0.00 0.00 5,200.00 0.00 0.00 5,200.00 5,164.50 0.00 0.00 0.00 0.00 0.00 0.00 5,300.00 0.00 0.00 5,300.00 5,264.50 0.00 0.00 0.00 0.00 0.00 0.00 5,400.00 0.00 0.00 5,400.00 5,364.50 0.00 0.00 0.00 0.00 0.00 0.00 5,500.00 0.00 0.00 5,500.00 5,464.50 0.00 0.00 0.00 0.00 0.00 0.00 ' 5,600.00 0.00 0.00 5,600.00 5,564.50 0.00 0.00 0.00 0.00 0.00 0.00 5,700.00 0.00 0.00 5,700.00 5,664.50 0.00 0.00 0.00 0.00 0.00 0.00 5,800.00 0.00 0.00 5,800.00 5,764.50 0.00 0.00 0.00 0.00 0.00 0.00 5,900.00 0.00 0.00 5,900.00 5,864.50 0.00 0.00 0.00 0.00 0.00 0.00 6,000.00 0.00 0.00 6,000.00 5,964.50 0.00 0.00 0.00 0.00 0.00 0.00 6,100.00 0.00 0.00 6,100.00 6,064.50 0.00 0.00 0.00 0.00 0.00 0.00 6,200.00 0.00 0.00 6,200.00 6,164.50 0.00 0.00 0.00 0.00 0.00 0.00 6,300.00 0.00 0.00 6,300.00 6,264.50 0.00 0.00 0.00 0.00 0.00 0.00 6,400.00 0.00 0.00 6,400.00 6,364.50 0.00 0.00 0.00 0.00 0.00 0.00 6,500.00 0.00 0.00 6,500.00 6,464.50 0.00 0.00 0.00 0.00 0.00 0.00 6,600.00 0.00 0.00 6,600.00 6,564.50 0.00 0.00 0.00 0.00 0.00 0.00 6,700.00 0.00 0.00 6,700.00 6,664.50 0.00 0.00 0.00 0.00 0.00 0.00 6,800.00 0.00 0.00 6,800.00 6,764.50 0.00 0.00 0.00 0.00 0.00 0.00 6,900.00 0.00 0.00 6,900.00 6,864.50 0.00 0.00 0.00 0.00 0.00 0.00 7,000.00 0.00 0.00 7,000.00 6,964.50 0.00 0.00 0.00 0.00 0.00 0.00 7,100.00 0.00 0.00 7,100.00 7,064.50 0.00 0.00 0.00 0.00 0.00 0.00 7,200.00 0.00 0.00 7,200.00 7,164.50 0.00 0.00 0.00 0.00 0.00 0.00 7,300.00 0.00 0.00 7,300.00 7,264.50 0.00 0.00 0.00 0.00 0.00 0.00 7,400.00 0.00 0.00 7,400.00 7,364.50 0.00 0.00 0.00 0.00 0.00 0.00 7,500.00 0.00 0.00 7,500.00 7,464.50 0.00 0.00 0.00 0.00 0.00 0.00 7,600.00 0.00 0.00 7,600.00 7,564.50 0.00 0.00 0.00 0.00 0.00 0.00 7,700.00 0.00 0.00 7,700.00 7,664.50 0.00 0.00 0.00 0.00 0.00 0.00 7,800.00 0.00 0.00 7,800.00 7,764.50 0.00 0.00 0.00 0.00 0.00 0.00 7,900.00 0.00 0.00 7,900.00 7,864.50 0.00 0.00 0.00 0.00 0.00 0.00 8,000.00 0.00 0.00 8,000.00 7,964.50 0.00 0.00 0.00 0.00 0.00 0.00 8,100.00 0.00 0.00 8,100.00 8,064.50 0.00 0.00 0.00 0.00 0.00 0.00 8,200.00 0.00 0.00 8,200.00 8,164.50 0.00 0.00 0.00 0.00 0.00 0.00 8,300.00 0.00 0.00 8,300.00 8,264.50 0.00 0.00 0.00 0.00 0.00 0.00 8,400.00 0.00 0.00 8,400.00 8,364.50 0.00 0.00 0.00 0.00 0.00 0.00 8,500.00 0.00 0.00 8,500.00 8,464.50 0.00 0.00 0.00 0.00 0.00 0.00 8,600.00 0.00 0.00 8,600.00 8,564.50 0.00 0.00 0.00 0.00 0.00 0.00 8,700.00 0.00 0.00 8,700.00 8,664.50 0.00 0.00 0.00 0.00 0.00 0.00 8,800.00 0.00 0.00 8,800.00 8,764.50 0.00 0.00 0.00 0.00 0.00 0.00 8,900.00 0.00 0.00 8,900.00 8,864.50 0.00 0.00 0.00 0.00 0.00 0.00 9,000.00 0.00 0.00 9,000.00 8,964.50 0.00 0.00 0.00 0.00 0.00 0.00 9,100.00 0.00 0.00 9,100.00 9,064.50 0.00 0.00 0.00 0.00 0.00 0.00 9,200.00 0.00 0.00 9,200.00 9,164.50 0.00 0.00 0.00 0.00 0.00 0.00 9,300.00 0.00 0.00 9,300.00 9,264.50 0.00 0.00 0.00 0.00 0.00 0.00 9,400.00 0.00 0.00 9,400.00 9,364.50 0.00 0.00 0.00 0.00 0.00 0.00 9,500.00 0.00 0.00 9,500.00 9,464.50 0.00 0.00 0.00 0.00 0.00 0.00 9,600.00 0.00 0.00 9,600.00 9,564.50 0.00 0.00 0.00 0.00 0.00 0.00 9,700.00 0.00 0.00 9,700.00 9,664.50 0.00 0.00 0.00 0.00 0.00 0.00 9,800.00 0.00 0.00 9,800.00 9,764.50 0.00 0.00 0.00 0.00 0.00 0.00 9,900.00 0.00 0.00 9,900.00 9,864.50 0.00 0.00 0.00 0.00 0.00 0.00 10,000.00 0.00 0.00 10,000.00 9,964.50 0.00 0.00 0.00 0.00 0.00 0.00 2/15/2012 2:35:56PM Page 4 COMPASS 2003.16 Build 73 Halliburton Company HALLI BU RTON Standard Proposal Report Database: .AK Compass PRD.16 Local Co-ordinate Reference: Well Red Wolf 2 Company: Savant TVD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Project: Red Wolf MD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Site: Red Wolf North Reference: True Well: Red Wolf 2 Survey Calculation Method: Minimum Curvature Wellbore: Red Wolf 2 Design: Red Wolf 2 Wp 2.0 10,100.00 0.00 0.00 10,100.00 10,064.50 0.00 0.00 0.00 0.00 0.00 0.00 10,200.00 0.00 0.00 10,200.00 10,164.50 0.00 0.00 0.00 0.00 0.00 0.00 10,300.00 0.00 0.00 10,300.00 10,264.50 0.00 0.00 0.00 0.00 0.00 0.00 10,400.00 0.00 0.00 10,400.00 10,364.50 0.00 0.00 0.00 0.00 0.00 0.00 10,500.00 0.00 0.00 10,500.00 10,464.50 0.00 0.00 0.00 0.00 0.00 0.00 10,600.00 0.00 0.00 10,600.00 10,564.50 0.00 0.00 0.00 0.00 0.00 0.00 10,700.00 0.00 0.00 10,700.00 10,664.50 0.00 0.00 0.00 0.00 0.00 0.00 10,800.00 0.00 0.00 10,800.00 10,764.50 0.00 0.00 0.00 0.00 0.00 0.00 10,900.00 0.00 0.00 10,900.00 10,864.50 0.00 0.00 0.00 0.00 0.00 0.00 11,000.00 0.00 0.00 11,000.00 10,964.50 0.00 0.00 0.00 0.00 0.00 0.00 11,100.00 0.00 0.00 11,100.00 11,064.50 0.00 0.00 0.00 0.00 0.00 0.00 11,200.00 0.00 0.00 11,200.00 11,164.50 0.00 0.00 0.00 0.00 0.00 0.00 11,300.00 0.00 0.00 11,300.00 11,264.50 0.00 0.00 0.00 0.00 0.00 0.00 11,400.00 0.00 0.00 11,400.00 11,364.50 0.00 0.00 0.00 0.00 0.00 0.00 11,500.00 0.00 0.00 11,500.00 11,464.50 0.00 0.00 0.00 0.00 0.00 0.00 11,600.00 0.00 0.00 11,600.00 11,564.50 0.00 0.00 0.00 0.00 0.00 0.00 11,700.00 0.00 0.00 11,700.00 11,664.50 0.00 0.00 0.00 0.00 0.00 0.00 11,800.00 0.00 0.00 11,800.00 11,764.50 0.00 0.00 0.00 0.00 0.00 0.00 11,900.00 0.00 0.00 11,900.00 11,864.50 0.00 0.00 0.00 0.00 0.00 0.00 12,000.00 0.00 0.00 12,000.00 11,964.50 0.00 0.00 0.00 0.00 0.00 0.00 12,040.00 0.00 0.00 12,040.00 12,004.50 0.00 0.00 0.00 0.00 0.00 0.00 2/15/2012 2:35:56PM Page 5 COMPASS 2003.16 Build 73 Halliburton Company HALLIBURTON Standard Proposal Report Database: .AK Compass PRD.16 Local Co-ordinate Reference: Well Red Wolf 2 Company: Savant TVD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Project: Red Wolf MD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Site: Red Wolf North Reference: True Well: Red Wolf 2 Survey Calculation Method: Minimum Curvature Wellbore: Red Wolf 2 Design: Red Wolf 2 Wp 2.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (0) (ft) ft (ft) (ft) (ft) (ft) -2.00 33.50 0.00 0.00 33.50 -2.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 80.00 0.00 0.00 80.00 44.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 20" 100.00 0.00 0.00 100.00 64.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 200.00 0.00 0.00 200.00 164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 300.00 0.00 0.00 300.00 264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 400.00 0.00 0.00 400.00 364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 500.00 0.00 0.00 500.00 464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 600.00 0.00 0.00 600.00 564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 700.00 0.00 0.00 700.00 664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 800.00 0.00 0.00 800.00 764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 900.00 0.00 0.00 900.00 864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 1,000.00 0.00 0.00 1,000.00 964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 1,100.00 0.00 0.00 1,100.00 1,064.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 1,200.00 0.00 0.00 1,200.00 1,164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 1,300.00 0.00 0.00 1,300.00 1,264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 1,400.00 0.00 0.00 1,400.00 1,364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 1,500.00 0.00 0.00 1,500.00 1,464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 1,600.00 0.00 0.00 1,600.00 1,564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 1,700.00 0.00 0.00 1,700.00 1,664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 1,800.00 0.00 0.00 1,800.00 1,764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 1,900.00 0.00 0.00 1,900.00 1,864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2,000.00 0.00 0.00 2,000.00 1,964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2,100.00 0.00 0.00 2,100.00 2,064.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2,200.00 0.00 0.00 2,200.00 2,164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2,300.00 0.00 0.00 2,300.00 2,264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2,400.00 0.00 0.00 2,400.00 2,364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2,500.00 0.00 0.00 2,500.00 2,464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2,600.00 0.00 0.00 2,600.00 2,564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2,700.00 0.00 0.00 2,700.00 2,664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2,800.00 0.00 0.00 2,800.00 2,764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2,900.00 0.00 0.00 2,900.00 2,864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 3,000.00 0.00 0.00 3,000.00 2,964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 3,100.00 0.00 0.00 3,100.00 3,064.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 3,200.00 0.00 0.00 3,200.00 3,164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 3,300.00 0.00 0.00 3,300.00 3,264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 3,400.00 0.00 0.00 3,400.00 3,364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 3,500.00 0.00 0.00 3,500.00 3,464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 3,600.00 0.00 0.00 3,600.00 3,564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 3,700.00 0.00 0.00 3,700.00 3,664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 3,800.00 0.00 0.00 3,800.00 3,764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 3,900.00 0.00 0.00 3,900.00 3,864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 4,000.00 0.00 0.00 4,000.00 3,964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 4,100.00 0.00 0.00 4,100.00 4,064.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 4,200.00 0.00 0.00 4,200.00 4,164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2/15/2012 2:35:56PM Page 6 COMPASS 2003.16 Build 73 Halliburton Company HALLIBURTON Standard Proposal Report Database: .AK Compass PRD.16 Local Co-ordinate Reference: Well Red Wolf 2 Company: Savant TVD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Project: Red Wolf MD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Site: Red Wolf North Reference: True Well: Red Wolf 2 Survey Calculation Method: Minimum Curvature Wellbore: Red Wolf 2 Design: Red Wolf 2 Wp 2.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 4,264.50 4,300.00 0.00 0.00 4,300.00 4,264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 4,400.00 0.00 0.00 4,400.00 4,364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 4,500.00 0.00 0.00 4,500.00 4,464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 4,550.00 0.00 0.00 4,550.00 4,514.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 9 5/8" 1 4,600.00 0.00 0.00 4,600.00 4,564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 4,700.00 0.00 0.00 4,700.00 4,664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 4,800.00 0.00 0.00 4,800.00 4,764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 4,900.00 0.00 0.00 4,900.00 4,864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 5,000.00 0.00 0.00 5,000.00 4,964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 5,100.00 0.00 0.00 5,100.00 5,064.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 5,200.00 0.00 0.00 5,200.00 5,164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 5,300.00 0.00 0.00 5,300.00 5,264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 5,400.00 0.00 0.00 5,400.00 5,364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 5,500.00 0.00 0.00 5,500.00 5,464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 5,600.00 0.00 0.00 5,600.00 5,564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 5,700.00 0.00 0.00 5,700.00 5,664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 5,800.00 0.00 0.00 5,800.00 5,764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 5,900.00 0.00 0.00 5,900.00 5,864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 6,000.00 0.00 0.00 6,000.00 5,964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 6,100.00 0.00 0.00 6,100.00 6,064.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 6,175.50 0.00 0.00 6,175.50 6,140.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 COR1 6,200.00 0.00 0.00 6,200.00 6,164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 6,300.00 0.00 0.00 6,300.00 6,264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 6,400.00 0.00 0.00 6,400.00 6,364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 6,500.00 0.00 0.00 6,500.00 6,464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 6,600.00 0.00 0.00 6,600.00 6,564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 6,655.50 0.00 0.00 6,655.50 6,620.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 MK2 6,700.00 0.00 0.00 6,700.00 6,664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 6,800.00 0.00 0.00 6,800.00 6,764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 6,800.50 0.00 0.00 6,800.50 6,765.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 Ugnu 6,900.00 0.00 0.00 6,900.00 6,864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 7,000.00 0.00 0.00 7,000.00 6,964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 7,100.00 0.00 0.00 7,100.00 7,064.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 7,165.50 0.00 0.00 7,165.50 7,130.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 West Sak 7,200.00 0.00 0.00 7,200.00 7,164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 7,300.00 0.00 0.00 7,300.00 7,264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 7,400.00 0.00 0.00 7,400.00 7,364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 7,500.00 0.00 0.00 7,500.00 7,464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 7,600.00 0.00 0.00 7,600.00 7,564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 7,700.00 0.00 0.00 7,700.00 7,664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 2/15/2012 2:35:56PM Page 7 COMPASS 2003.16 Build 73 Halliburton Company HALLI BURTON Standard Proposal Report Database: .AK Compass PRD.16 Local Co-ordinate Reference: Well Red Wolf 2 Company: Savant TVD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Project: Red Wolf MD Reference: Assumed KBE©35.50ft(9ES@33.5+GL@2.0) Site: Red Wolf North Reference: True Well: Red Wolf 2 Survey Calculation Method: Minimum Curvature Wellbore: Red Wolf 2 Design: Red Wolf 2 Wp 2.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 7,725.00 7,760.50 0.00 0.00 7,760.50 7,725.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 MK3 7,800.00 0.00 0.00 7,800.00 7,764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 7,900.00 0.00 0.00 7,900.00 7,864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 8,000.00 0.00 0.00 8,000.00 7,964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 8,095.50 0.00 0.00 8,095.50 8,060.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 M 85 8,100.00 0.00 0.00 8,100.00 8,064.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 8,200.00 0.00 0.00 8,200.00 8,164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 8,300.00 0.00 0.00 8,300.00 8,264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 8,400.00 0.00 0.00 8,400.00 8,364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 8,500.00 0.00 0.00 8,500.00 8,464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 8,600.00 0.00 0.00 8,600.00 8,564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 8,700.00 0.00 0.00 8,700.00 8,664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 8,800.00 0.00 0.00 8,800.00 8,764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 8,900.00 0.00 0.00 8,900.00 8,864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 9,000.00 0.00 0.00 9,000.00 8,964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 9,100.00 0.00 0.00 9,100.00 9,064.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 9,200.00 0.00 0.00 9,200.00 9,164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 9,300.00 0.00 0.00 9,300.00 9,264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 9,400.00 0.00 0.00 9,400.00 9,364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 9,500.00 0.00 0.00 9,500.00 9,464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 9,600.00 0.00 0.00 9,600.00 9,564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 9,700.00 0.00 0.00 9,700.00 9,664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 9,800.00 0.00 0.00 9,800.00 9,764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 9,900.00 0.00 0.00 9,900.00 9,864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 10,000.00 0.00 0.00 10,000.00 9,964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 10,100.00 0.00 0.00 10,100.00 10,064.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 10,200.00 0.00 0.00 10,200.00 10,164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 10,300.00 0.00 0.00 10,300.00 10,264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 10,400.00 0.00 0.00 10,400.00 10,364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 10,500.00 0.00 0.00 10,500.00 10,464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 10,600.00 0.00 0.00 10,600.00 10,564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 10,700.00 0.00 0.00 10,700.00 10,664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 10,740.50 0.00 0.00 10,740.50 10,705.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 KMKR 10,800.00 0.00 0.00 10,800.00 10,764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 10,870.50 0.00 0.00 10,870.50 10,835.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 KSND 10,900.00 0.00 0.00 10,900.00 10,864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 11,000.00 0.00 0.00 11,000.00 10,964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 11,100.00 0.00 0.00 11,100.00 11,064.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 11,200.00 0.00 0.00 11,200.00 11,164.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 11,225.50 0.00 0.00 11,225.50 11,190.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 Hue Shale 2/15/2012 2:35:56PM Page 8 COMPASS 2003.16 Build 73 Halliburton Company HALLIBURTON Standard Proposal Report Database: .AK Compass PRD.16 Local Co-ordinate Reference: Well Red Wolf 2 Company: Savant TVD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Project: Red Wolf MD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Site: Red Wolf North Reference: True Well: Red Wolf 2 Survey Calculation Method: Minimum Curvature Wellbore: Red Wolf 2 Design: Red Wolf 2 Wp 2.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 11,264.50 11,300.00 0.00 0.00 11,300.00 11,264.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 11,355.50 0.00 0.00 11,355.50 11,320.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 Top HRZ 11,400.00 0.00 0.00 11,400.00 11,364.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 11,500.00 0.00 0.00 11,500.00 11,464.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 11,525.00 0.00 0.00 11,525.00 11,489.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 7.. 11,525.50 0.00 0.00 11,525.50 11,490.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 Base HRZ 11,590.50 0.00 0.00 11,590.50 11,555.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 LCU 11,600.00 0.00 0.00 11,600.00 11,564.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 11,700.00 0.00 0.00 11,700.00 11,664.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 11,800.00 0.00 0.00 11,800.00 11,764.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 11,900.00 0.00 0.00 11,900.00 11,864.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 11,940.50 0.00 0.00 11,940.50 11,905.00 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 Kek 1 12,000.00 0.00 0.00 12,000.00 11,964.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 12,040.00 0.00 0.00 12,040.00 12,004.50 0.00 0.00 5,910,479.00 356,686.00 0.00 0.00 TD at 12040.00'MD;12040'TVD-4 1/2" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (0) (0) (ft) (ft) (ft) (ft) (ft) 0.00 0.00 12,040.00 0 00 0.00 5,910,479.00 356,686.00 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 4,550.00 4,550.00 9 5/8" 9-5/8 12-1/4 12,040.00 12,040.00 4 1/2" 4-1/2 6-1/8 80.00 80.00 20" 20 26 11,525.00 11,525.00 7" 8-1/2 8-1/2 2/15/2012 2.35:56PM Page 9 COMPASS 2003.16 Build 73 Halliburton Company HALLIBLiRTON Standard Proposal Report Database: .AK Compass PRD.16 Local Co-ordinate Reference: Well Red Wolf 2 Company: Savant TVD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Project: Red Wolf MD Reference: Assumed KBE @ 35.50ft(9ES@33.5+GL@2.0) Site: Red Wolf North Reference: True Well: Red Wolf 2 Survey Calculation Method: Minimum Curvature Wellbore: Red Wolf 2 Design: Red Wolf 2 Wp 2.0 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (0) (0) 6,800.50 6,800.50 Ugnu 0.00 10,870.50 10,870.50 KSND 0.00 7,760.50 7,760.50 MK3 0.00 10,740.50 10,740.50 KMKR 0.00 6,175.50 6,175.50 COR1 0.00 11,525.50 11,525.50 Base HRZ 0.00 11,940.50 11,940.50 Kek 1 0.00 8,095.50 8,095.50 M 85 0.00 11,590.50 11,590.50 LCU 0.00 6,655.50 6,655.50 MK2 0.00 11,225.50 11,225.50 Hue Shale 0.00 7,165.50 7,165.50 West Sak 0.00 11,355.50 11,355.50 Top HRZ 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 12,040.00 12,040.00 0.00 0.00 TD at 12040.00'MD; 12040'TVD 2/15/2012 2:35:56PM Page 10 COMPASS 2003.16 Build 73 a 1 m i o m M N c f,N'1 Om m _. 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Eax o a300i p2.i< F a. . mNo03lO x cc $ pp ao c p cm r Z co � u3 . ^ - 2 4 B. ac al 3Qtar Eva, p g ti-8 '.; ,2- 0 ;tc ar - 5 _ iLOopp 'pn W t of z jouixa aO0xaip CO QdtiMV , c E v Xuritimm _ = ov .,,, w a0 E Q't W •e a s a3« C m t; Q c p u �� r o u= XU .,3 nY, '3i e. = � pao S G ? C O m 2 3 0 c rc Y W E is c, a 'a 2• o'Pa m N y = 2VGv « V• ~ N dIL c �3 �I mm K 4 I K N 2 § 7.12a N p xl..0. 2. .v 8 O O O O O O O o N N R W c071 0 N laad ui gldaa easqns ieDwan anal STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SURETY BOND BOND NUMBER LPM8945440 PENAL SUM$ 200,000.00 KNOW ALL PERSONS BY THESE PRESENTS, That we, Savant Alaska LLC of the City of Denver State of Colorado as principal,and Fidelity and Deposit Company of Maryland of Schaumburg,IL ,as surety,an authorized insurer under AS whose certificate of authority is in good standing,are held firmly bound unto the Alaska Oil and Gas Conservation Commission in the penal sum as indicated above, lawful money of the United States of America, for which payment, well and truly to be made, we bind ourselves and each of us, and each of our heirs, executors, administrators, successors, and assigns,jointly and severally, firmly by these presents. WHEREAS the above bounden principal proposes to engage in the drilling or operating of a well or wells subject to regulation by the Alaska Oil and Gas Conservation Commission at a location described as follows: ❑ SINGLE WELL BOND -minimum penal sum$100,000(except as otherwise allowed by the Commission under 20 AAC 25.025(b)) Unit or Lease Name Well Number Area of State Surface Well Location-Sec.,Twp.,Rng. and Mer. Surface Well Location-Alaska State Plane Coordinate System coordinates 0 BLANKET BOND -minimum penal sum$200,000 Any and all wells drilled or operated by the principal in the State of Alaska. NOW, THEREFORE, the above bounden principal shall comply with all of the provisions of the laws of the State of Alaska and the regulations, rules, and orders of the Alaska Oil and Gas Conservation Commission in the drilling, operation, maintenance, repair, and abandonment of each well and the clearance of each location, and shall file with the Alaska Oil and Gas Conservation Commission all notices and records required by said Commission. Form 10-402A Rev.10/2003 Page 1 of 2 Submit in Duplicate BOND NUMBER LPM8945440 (continued)PENAL SUM$ 200,000.00 This obligation shall remain in full force and effect until released by the Alaska Oil and Gas Conservation Commission at the request of principal or surety. Witness our hand and seal this 13th day of November 2008 Savant Alaska LLC By: 2 i Principal Signature /'y 1 S U P Printeand title Witness our hand and seal this 13th day of November 2008 Fidelity and Deposit Company of Maryland By: Surety Sign-ai".164-1 Jana M. Forrest,Attorney-in-Fact Printed name and title n/a Countersigned (Resident Agent if necessary) Official Use Only Below Line ALASKA OIL AND GAS CONSERVATION COMMISSION Approved: Commissioner Date Approved: Commissioner Date Approved: Commissioner Date (Requires approval by two Commissioners) Form 10-402A Rev.10/2003 Page 2 of 2 Submit in Duplicate Power of Attorney • FIDELITY AND DEPOSIT COMPANY OF MARYLAND COLONIAL AMERICAN CASUALTY AND SURETY COMPANY KNOW ALL MEN BY THESE PRESENTS:That the FIDELITY AND DEPOSIT COMPANY OF MARYLAND,and the COLONIAL AMERICAN CASUALTY AND SURETY COMPANY,corporations of the S . aryland,by WILLIAM • J.MILLS,Vice President,and ERIC D.BARNES,Assistant Secretary,in pursua e . evis'_nted by Article VI, Section 2,of the By-Laws of said Companies,which are set forth on t o n41�reby certified to he in full force and effect on the date hereof,does hereby nomina •!r t.�t � .•po i� �Z''t , ret S.BURTON, Jana M.FORREST,Tim H.HEFFEL,Erica � ,� j' t+�+`i:► • 0,,, ,t`sf. LAND and Kathleen A. SNYDER,all of Wichita,Kansas, E• 4t yr. ..: fu Te t.. n y-in-Fact,to make,execute,seal and deliver,for,and on its beha s.. t� :li s a . • y ,n. all bonds and undertakings,and the execution of such bonds or unde • ���,Sou ane- e t '•!:=1 s all be as binding upon said Companies,as fully and amply,to all intents and pure• s, .. ire• :�!•-• •texecuted and acknowledged by the regularly elected officers of the Company at its offic*/`!'' rwre, •.,in their own proper persons. This power of attorney revokes that issued on behalf of W.C.COHEN,JR, 17;4 . 'OST,Richard K.STONE;Bret S.BURTON,Jana M.FORREST,Sandra J.SHRYACK,Tim H.HEFFEL,Erica M.PLUMMER,Desiree E.WESTMORELAND,Kathleen A.SNYDER,dated May 15,2007. The said Assistant Secretary does hereby certify that the extract set forth on the reverse side hereof is a true copy of Article VI, Section 2,of the By-Laws of said Companies,and is now in force. IN WITNESS WHEREOF, the said Vice-President and Assistant Secretary have hereunto subscribed their names and affixed the Corporate Seals of the said FIDELITY AND DEPOSIT COMPANY OF MARYLAND, and the COLONIAL AMERICAN CASUALTY AND SURETY COMPANY,this 19th day of June,A.D.2008. ATTEST: FIDELITY AND DEPOSIT COMPANY OF MARYLAND COLONIAL AMERICAN CASUALTY AND SURETY COMPANY 'gyp otoos., C }y ow" 14 ; 81AL ; Uig u !�.t r i/f'of 4nYli' Ji By: Eric D.Barnes Assistant Secretary William J.Mills Vice President State of Maryland l ss: City of Baltimore On this 19th day of June, A.D. 2008, before the subscriber, a Notary Public of the State of Maryland, duly commissioned and qualified,came WILLIAM J.MILLS, Vice President,and ERIC D.BARNES,Assistant Secretary of the FIDELITY AND DEPOSIT COMPANY OF MARYLAND, and the COLONIAL AMERICAN CASUALTY AND SURETY COMPANY, to me personally known to be the individuals and officers described in and who executed the preceding instrument, and they each acknowledged the execution of the same, and being by me duly sworn, severally and each for himself deposeth and saith,that they are the said officers of the Companies aforesaid,and that the seals affixed to the preceding instrument is the Corporate Seals of said Companies,and that the said Corporate Seals and their signatures as such officers were duly affixed and subscribed to the said instrument by the authority and direction of the said Corporations. IN TESTIMONY WHEREOF, I have hereunto set my hand and affixed my Official Seal the day and year first above written. edit ktir•rAA' Dennis R.Hayden Notary Public My Commission Expires: February 1,2009 POA-F 076-6692A EXTRACT FROM BY-LAWS OF FIDELITY AND DEPOSIT COMPANY OF MARYLAND "Article VI,Section 2.The Chairman of the Board, or the President,or any Executive Vice-President,or any of the Senior Vice-Presidents or Vice-Presidents specially authorized so to do by the Board of Directors or by the Executive Committee, shall have power, by and with the concurrence of the Secretary or any one of the Assistant Secretaries,to appoint Resident Vice-Presidents, Assistant Vice-Presidents and Attorneys-in-Fact as the business of the Company may require, or to authorize any person or persons to execute on behalf of the Company any bonds, undertaking, recognizances, stipulations, policies, contracts, agreements, deeds, and releases and assignments of.judgements, decrees, mortgages and instruments in the nature of mortgages,...and to affix the seal of the Company thereto." EXTRACT FROM BY-LAWS OF COLONIAL AMERICAN CASUALTY AND SURETY COMPANY "Article VI,Sactinn 2.The Chairman.of the Board,or the President,or any Executive Vice-President,or any of the Senior Vice-Presidents or Vice-Presidents specially authorized so to do by the Board of Directors or by the Executive Committee, shall have power,by and with the concurrence of the Secretary or any one of the Assistant Secretaries,to appoint Resident Vice-Presidents, Assistant Vice-Presidents and Attorneys-in-Fact as the business of the Company may require, or to authorize any person or persons to execute on behalf of the Company any bonds, undertaking, recognizances, stipulations, policies, contracts, agreements, deeds, and releases and assignments of judgements, decrees, mortgages and instruments in the nature of mortgages,...and to affix the seal of the Company thereto." CERTIFICATE I, the undersigned, Assistant Secretary of the FIDELITY AND DEPOSIT COMPANY OF MARYLAND, and the COLONIAL AMERICAN CASUALTY AND SURETY COMPANY, do hereby certify that the foregoing Power of Attorney is still in full force and effect on the date of this certificate; and I do further certify that the Vice-President who executed the said Power of Attorney was one of the additional Vice-Presidents specially authorized by the Board of Directors to appoint any Attorney-in-Fact as provided in Article VI, Section 2, of the respective By-Laws of the FIDELITY AND DEPOSIT COMPANY OF MARYLAND,and the COLONIAL AMERICAN CASUALTY AND SURETY COMPANY. This Power of Attorney and Certificate may be signed by facsimile under and by authority of the following resolution of the Board of Directors of the FIDELITY AND DEPOSIT COMPANY OF MARYLAND at a meeting duly called and held on the 10th day of May, 1990 and of the Board of Directors of the COLONIAL AMERICAN CASUALTY AND SURETY COMPANY at a meeting duly called and held on the 5th day of May,1994. RESOLVED: "That the facsimile or mechanically reproduced seal of the company and facsimile or mechanically reproduced signature of any Vice-President, Secretary, or Assistant Secretary of the Company, whether made heretofore or hereafter, wherever appearing upon a certified copy of any power of attorney issued by the Company, shall be valid and binding upon the Company with the same force and effect as though manually affixed." 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I i CU 4 M 7 n v H, < n 0 - N 1 I • .. ii•� N NYG ,y o ,< m . �▪ ry 0 f a M I ' N0 , i J • .A -. 4 'r'v I - At 1 jv '� O :, ^...., Zo:2, r., e., ,.. ,..... /._ ,. _ , . f„,.,._ i _ , „ , - .:, , .,..., : ,.., ^ .. 4 .. , .: ill 1 ., 1 I L - n M M n 7. - -- 1 ,. .: I ., r - 1..., :::. a I - Q OP Resource Solutions, ',Lc _„ . 1600 Stout Street,Suite 1900 • Denver,CO 80202 • 303-446-8566 • FAX 303-446-0698 U February 3, 2012 C/( VeaCf-e�f. M- C.A./JA I S/y /i1 Mr. Erik Opstad, General Manager Savant Alaska, LLC P.O. Box 112212 Anchorage, Alaska 99511 Re: Shallow Gas Hazard Evaluation for the Red Wolf Prospect Dear Mr. Opstad: Pursuant to your request, we have evaluated the Badami 3D seismic data volume for potential shallow gas hazards at, and in the vicinity of, the proposed location on Savant Alaska's Red Wolf Prospect. Based on our analysis of the data, there is no seismic evidence for the presence of shallow gas hazards in the area of the proposed wellbore. For your review, I have attached a summary that depicts the shallow seismic response at the proposed location. The summary includes seismic transects at, and adjacent to, the proposed wellbore in increments of approximately 800 feet. You will note that the displays do not exhibit any seismic amplitude response that would be indicative of a shallow gas hazard. In our opinion, these displays are representative of the shallow section that the proposed well will encounter. If you have any questions, please do not li hesitate to contact me at 303-446-8566. Sincerely, / 1V7' Jeffrey C. Hemphill Principal Geophysicist Resource Solutions, LLC Davies, Stephen F (DOA) From: Erik Opstad [Erik.Opstad@savantalaska.com] Sent: Friday, March 16, 2012 2:23 PM To: Schwartz, Guy L (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: Red Wolf 2 - Proposed Drilling Fluid Program -Additional Question Guy, The cold weather has work on B1-16 on hold; no e-line work until the temperature gets above -35°F. It's currently -40°F so it looks like nothing will get done today either. It's difficult to see how Red Wolf #2 could spud before the first week of April. The mud weight range of 8.6 to 10.5 listed on page 4 of the Detailed Drilling & Completions Program is a typo, which should read 9.6 to 10.5 ppg. Erik From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, March 16, 2012 11:18 AM To: Erik Opstad Cc: Davies, Stephen F (DOA) Subject: FW: Red Wolf 2 - Proposed Drilling Fluid Program -Additional Question Erik , One more question for you in regards to the production hole drilling mud. See below question on page 4 of Red Wolf procedure.... Can you also give me an update on how the workover is going on B1-16? Estimated spud dated for Red Wolf? On page 4 of the Detailed Drilling and Completion Program, for the 6-1/8" exploration interval the mud weight range is listed as 8.6—10.5 ppg. Even with the overall 0.5 ppg weight increase proposed by Savant on March 13th, a mud weight of 9.1 ppg while drilling in the Hue Shale/ HRZ interval is still at least 1 ppg lower than the mud weights used to drill the same geologic section in nearby wells. Is the value of 8.6 ppg listed in the program a typo? Should the range listed on that page have been 9.6—10.5 instead? (Which means the current proposed weights for the exploration interval would be 10.1-11.0 ppg.) Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Davies, Stephen F (DOA) Sent: Friday, March 16, 2012 10:29 AM To: Schwartz, Guy L (DOA) Subject: RE: Red Wolf 2 - Proposed Drilling Fluid Program -Additional Question 1 Guy, Once again, since you've been point-of-contact with Savant on this well, I thought it best to send this through you. I have one final question for Savant concerning the drilling fluid program. On page 4 of the Detailed Drilling and Completion Program, for the 6-1/8" exploration interval the mud weight range is listed as 8.6—10.5 ppg. Even with the overall 0.5 ppg weight increase proposed by Savant on March 13th, a mud weight of 9.1 ppg while drilling in the Hue Shale/HRZ interval is still at least 1 ppg lower than the mud weights used to drill the same geologic section in nearby wells. Is the value of 8.6 ppg listed in the program a typo? Should the range listed on that page have been 9.6—10.5 instead? (Which means the current proposed weights for the exploration interval would be 10.1—11.0 ppg.) Thanks, Steve Davies From: Schwartz, Guy L(DOA) Sent: Thursday, March 15, 2012 4:10 PM To: Davies, Stephen F (DOA) Subject: FW: Red Wolf 2 - Proposed Drilling Fluid Program -Additional Question FYI Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Erik Opstad [mailto:Erik.Opstad@savantalaska.com] Sent: Thursday, March 15, 2012 4:01 PM To: Schwartz, Guy L(DOA) Subject: RE: Red Wolf 2 - Proposed Drilling Fluid Program -Additional Question Afternoon Guy, Savant has no problem bumping the proposed surface hole spud mud weight up to range 9.5 - 10.0 ppg to add some additional overbalance margin. As for the casing shoe depth, it has always been my intent to land the casing in the shallowest section that will insure a competent shoe, so we are quite flexible in that regard. As to the "gas levels" encountered in the lower portion of B1-38, that contribution mostly came from the Killian Sand, which we've demonstrated to you and Art Saltmarsh will not be present at the RW#2 location. That said, we don't have any objection to bumping the mud weight range for the intermediate and production hole up by 0.5 ppg as well. Let me know if you have any additional concerns. Erik Erik A. Opstad, Manager Savant Alaska,LLC:Drilling&Wells Group 2 4720 Business Park Blvd. Suite G40, Anchorage,AK 99503 (C)907-244-5210•(0)907-868-1258•(NS)907-448-6010 E-Mail:Erik.Opstad@SavantAlaska.com From: Schwartz, Guy L(DOA) [mailto:guy.schwartz(a)alaska.gov] Sent: Thursday, March 15, 2012 12:10 PM To: Erik Opstad Subject: FW: Red Wolf 2 - Proposed Drilling Fluid Program -Additional Question Erik, Steve Davies is taking over the Geotechnical review for Red Wolf. He has some questions regarding proposed mud weights as mentioned below. I know you and I already discussed bumping MW up slightly but if you can address the question below in writing that would be helpful to getting the PTD closer to approval. We also discussed the surface casing shoe depth would be somewhat flexible depending on when the running gravels stop and competent section is penetrated in order to land the casing. Please address that in writing too. Thanks. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Davies, Stephen F (DOA) Sent: Thursday, March 15, 2012 11:48 AM To: Schwartz, Guy L (DOA) Subject: Red Wolf 2 - Proposed Drilling Fluid Program -Additional Question Guy, Since you've been point-of-contact with Savant on this well, I thought it best to send this through you. The text references B1-38, which is still confidential. After review of the proposed drilling fluid program for the Red Wolf 2 exploratory well with respect to offset well control, the proposed weights appear to be somewhat low(light). Please justify your choice of proposed fluid weights for the entire well with respect to offset wells, especially in light of the gas levels encountered in the lower portions of B1-38. Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Steve's phone: 907-793-1224 AOGCC's receptionist: 907-793-1223 AOGCC's fax: 907-276-7542 3 Drill Floor to Ground Level 41.5 referenced to Doyon Rig 15 Drill Floor to Tubing Hanger 22.0 referenced to Doyon Rig 15 OD ID Weight Length MD TVD Ground Level to Sea Level 19.5 Wellhead 13-5/8"/10,000 psi-Manufactured by FMC inch inch Lbs/ft ft DF ft J L Tree 4-1/16"/10,000 psi-CIW Conductor 20.000 19.124 91.1 80 118 118 2-7/8"6.5#L-80 EUE Tubing 2.875 2.441 6.5 10143 10143 8870 0 TMAXX-5e SCSSSV 4.750 2.313 N/A 4.19 2215 2201 4 L 13-3/8"68#L-80 BTC 13.375 12.415 45.5 4518 4554 4505 GL Station 1 II I GLM CAMCO KBMG 1"LGLV Model BK w/1/4"Port 4.750 2.313 6.98 4562 4512 GL Station 2 II I GLM CAMCO KBMG 1"LGLV Model BK w/1/4"Port 4.750 2.313 6.96 7819 6995 GL Station 3 II I GLM CAMCO KBMG w/Dummy GLV 2-7/8"x 1" 4.750 2.313 6.97 9886 8641 GL Station 4 li ) GLM CAMCO KBMG 1"LGLV Model BK w/1/4"Port S/O 4.750 2.313 6.99 10009 8749 HES 2-7/8"x 7"PHL Packer 5.980 2.360 23-29 0.35 10063 8798 il Hp HES"X"Nipple 2-7/8"6.5#9CR EUE w/2.313 PKG Bore 3.680 2.313 6.5 1.26 10083 8816 HES"XN"Nipple 2-7/8"6.5#9CR EUE w12.313 PKG Bore 3.680 2.205 6.5 1.30 10097 8828 Top of cutoff tubing strub 10101 8832 4 Baker Permanent Packer 3.900 3.875 10141 8865 B Wireline Entry Guide(WLEG)2-7/8"9.2#9CR IBT-M Box(EOT) 10142 8866 Tubing Tail perforations 10146'-10158' I HES X-Nipple 9CR ID 3.813"(Plug Set) 3.900 3.813 10164 8914 HI Bottom of-8 original 41/2"edia tubing Casing T) Shoe 9-5/8"L-80 Intermediate Casing Shoe 10176 8926 A , Brookian Perforations 11700-11860'-Open 9.625 40 10211 10244 8964 7"x 4-1/2"Liner Hanger Packer I I HES X-Nipple 9CR ID 3.813"(Plug Set) 12338 10575 7"29#/ft P110 BTC Casing Shoe 7.625 3.813 12384 10615 Killian Peforations 13840-13890-Plugged 7.000 29 12403 12433 10593 ii►-4111 Baker CIBP set at 14,060' 14060 11450 ' Kekiktuk Peforations 14896-14936-Plugged - 4-1/2"17#L-80 BTC-M Liner 15540 13723 No. Rev.by Comments/Date B1-36 1 G.Vigil Initial configuration(5/11/2010) Badami Unit 2 E.Opstad Edit GLM graphic&add TVD values to schematic(05-14-10) API No. 50-029-22933 3 E.Opstad Add top 45"tubing stub at 10,101'MD&bottom(EOT)at 10,176'MD(06-24-10) Permit to Drill#98-232 4 E.Opstad Static Survey Data:SBHP 2,445 psi,SBHT 151°F @ 8,830'TVD(Run 8/31/10) 5 E.Opstad Add WLEG depth @ 10,142'MD&EOT of original tubing @ 10,164'MD(8/13/10) SAYMT ALASKA__. Page 1 of 3 Schwartz, Guy L (DOA) From: Erik Opstad [Erik.Opstad@savantalaska.com] Sent: Tuesday, February 28, 2012 10:00 AM To: Schwartz, Guy L (DOA) Subject: RE: Red Wolf#2 ( PTD 212-019) Attachments: Red Wolf#2 Marker Top Prognosis.pdf; Brookian Overpressured Seismic Analysis.pdf; Savant Brookian Overpressure Analysis BMP2.pdf; B1-38 Mud Program (2).pdf; B1-18A Completion Diagram Pre-Startup-GLV Installation Revision October 16 2010.pdf; B1-36 SALLC Completion Wellbore Diagram Rev. 10-15-10.pdf Guy, In questions, our res onse to P Y 1. As cited in Savant Alaska's PTD Application for the proposed Red Wolf #2 confirmation well, the only target is the Kekiktuk Formation at -11,555 TVDss (see attached marker top prognosis). No other zones containing movable hydrocarbons of any kind are anticipated to be encountered at this location. 2. As attested to by the Shallow Hazard Analysis submitted with our PTD Application, no shallow gas zones are anticipated at this location. This assertion is further supported bythe numerous Badami wells drilled PP immediatelyto the east of the Red Wolf #2 location, none of which have encountered shallow9 as. These wells include: a. B1-01 b. B1-11 c. B1-14 d. B1-15 e. B1-16 f. B1-18 g. B1-21 h. B1-25 i. B1-28 j. B1-36 k. B1-38 I. Badami-01 m. Badami-02 n. Badami-03 o. Badami-04 p. Badami-05 In addition to the above, we can also point to the "West Mikkelsen" well series (1-4) located immediately west and north of the proposed Red Wolf #2 location. None of these wells encountered any shallow gas either, so the Red Wolf #2 location is more-or-less surrounded by offset wells, none of which have encountered shallow gas. 2/28/2012 Page 2 of 3 3. No over pressured zones are anticipated at the Red Wolf #2 location. Over pressure zones within the Badami Unit are common within several turbidite fan complexes in the upper Brookian and, as most recently identified by Badami B1-38, in well- developed, but relatively tight sands in the lower Brookian Killian Formation. We have analyzed the 3D seismic data volume with in the Brookian stratigraphic interval for similar occurrences at the Red Wolf #2 location and found none (see attached letter and montage). Additionally the Red Wolf #2 LWD/MWD plan calls for pressure while drilling (PWD) instrumentation to be run from surface to final TD, so we'll have real-time borehole pressure monitoring for the entire program. 4. The Red Wolf #2 drilling fluid program as submitted with the PDT Application is essentially identical to that previously employed by previous Badami wells (see the most recent 81-38 mud program as attached). 5. Surface casing points in the Badami Unit tend to cluster around 4,500' TVDss (by way of example see 81-18A & 81-36 schematics as attached) because area surface stratigraphy is dominated by 3 to 4 thousand feet of unconsolidated or poorly cemented gravels. There is simply no place shallow to obtain a competent surface casing shoe. Let me know if you have any additional questions. Thanks, Erik A. Opstad BS,MS,PG Savant Alaska,LLC:Drilling&Wells Group 4720 Business Park Blvd. Suite G40, Anchorage,AK 99503 (C)907-244-5210•(0)907-868-1258•(NS)907-448-6010 E-Mail:Erik.Opstad@SavantAlaska.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, February 24, 2012 11:37 AM To: Erik Opstad Cc: Saltmarsh, Arthur C (DOA); Regg, James B (DOA) Subject: Red Wolf#2 ( PTD 212-019) Erik, As follow up to our phone call a couple of days ago.... I need the below items in writing from you. In light of the events at the Qugruk 2 exploratory well, the AOGCC is re-examining shallow hazards, drilling fluids, and casing and cementing programs for all proposed wells, especially exploratory wells. Specific approval by AOGCC must be obtained prior to spudding any proposed well, even those with approved Permits to Drill. Accordingly, please provide the following information for the Red Wolf#2 exploratory well: 2/28/2012 Page 3 of 3 1. List and provide depths for all target formation(s). List and provide depths for all other likely hydrocarbon bearing formations, including those that may contain shallow gas accumulations. 2. Will shallow gas zones be encountered? Provide evidence of conformance with regulation 20 AAC 25.061. 3. Will over-pressured zones be encountered? For all wells, provide evidence from nearest existing wells. For exploratory or stratigraphic test wells, provide evidence from seismic data. 4. Provide evidence that the proposed drilling fluid program conforms to programs used in the nearest existing wells. 5. Provide evidence that the proposed surface casing point, and the casing and cementing programs conform to programs used in the nearest existing wells. AOGCC appreciates your concern and cooperation_ Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) 2/28/2012 Page 1 of 2 Schwartz, Guy L (DOA) From: Erik Opstad [Erik.Opstad@savantalaska.com] Sent: Friday, February 17, 2012 3:47 PM To: Schwartz, Guy L (DOA) Cc: Saltmarsh, Arthur C (DOA) Subject: RE: Red Wolf#2 (PTD 212-019) Attachments: Red Wolf#2 PTD FM 10-401 - Executed -with Attachments-As Submitted - 17FEB2012.pdf Guy, I've expanded the details attached to Fm. 10-401, which should provide the additional information you're looking for. As to the MASP, the targeted Kekiktuk production interval is predicted @ —11,587' TVD rkb. This zone is expected to have a normal salt water gradient of .4368 psi/ft giving an expected formation pressure of 5061 psi. This Kekiktuk gradient was confirmed with drilling of the B1-38 which was the discovery well for the Red Wolf structure. Assuming a worst case MASP by using a gas gradient of .1 psi/ft, a full head of gas from surface to 11587' would yield 1158 psi. Therefore, the expected MASP would be: 5061 psi minus 1158 psi= 3903 psi MASP. Lastly, given the late start this year, it is very unlikely that Savant will do anything other than complete or P&A Red Wolf #2. As always, we will seek the appropriate AOGCC approvals prior to undertaking any work requiring such approvals. Let me know if you need anything else. Thanks, Erik From: Erik Opstad Sent: Thursday, February 16, 2012 3:38 PM To: 'Schwartz, Guy L(DOA)' Cc: Saltmarsh, Arthur C (DOA) Subject: RE: Red Wolf #2 (PTD 212-019) Guy, Please standby. I'll pull up some more details and shoot them over tomorrow. Erik 2/22/2012 Page 2 of 2 From: Schwartz, Guy L (DOA) fmailto:quy.schwartz@alaska.govl Sent: Wednesday, February 15, 2012 10:00 AM To: Erik Opstad Cc: Saltmarsh, Arthur C (DOA) Subject: Red Wolf#2 (PTD 212-019) Erik, There are some things missing from the PTD application. 1) MASP and reservoir pressure information. ( how did you come up with the numbers you have) 2) Formation tops for the expected zones you are drilling through. ( do you have a better page instead of the rig days vs. TVD?) 3) Procedure in place to perform the FITs (20 AAC 25.005 (5) 4) Cementing details are missing for the casing strings. Do you have more detail than what is on the timeline. Mud data: There also appears to be some typo's on page 4 of the mud report ref Kekiktuk md/TVD. 5) BOP configuration for the initial BOP test.(what ram pipe sizes are being installed and where) 6) In general the drilling summary procedure doesn't have enough detail. Nothing on changing out rams for casing runs , need safety joint with FOSV. Etc. 7)As built for the diverter setup showing all whole ice pad. 8)What are the plans for the well after completed?? Flow test? stimulate? P &A? I see some comments on the time line page ( Rig days vs. TVD). May need a separate sundry to flow test and stimulate and P&A . Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 2/22/2012 Land Administration System Page 1 of 3 Alaska DNR Case Summary File Type:ADL File Number: 367005 See Township,Range,Section and Acreage? ° Yes No New Search File: ADL 367005 Search for Status Plat Updates As of 02/10/2012 Customer: 000047539 SAVANT ALASKA,LLC 7501 VILLAGE SQUARE DRIVE SUITE 102 CASTLE ROCK CO 80108 Case Type:784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status:35 ISSUED Status Date: 04/23/1986 Total Acres: 3200.000 Date Initiated:01/16/1986 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date:01/31/2012 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: moN Range: 019E Section: 25 Section Acres:64o Search Plats Meridian: U Township: owoN Range: 019E Section: 26 Section Acres:640 Meridian: U Township: owoN Range: 019E Section: 34 Section Acres:64o Meridian: U Township: oloN Range: 019E Section: 35 Section Acres:640 Meridian: U Township: moN Range: o19E Section: 36 Section Acres:640 Legal Description 01-16-1986***SALE NOTICE LEGAL DESCRIPTION*** TRACT 48 A-05 T. 10 N.,R. 19 E.,UMIAT MERIDIAN,ALASKA SECTION 25,PROTRACTED,ALL,640 ACRES; SECTION 26,UNSURVEYED,ALL TIDE AND SUBMERGED LANDS,258 ACRES; SECTION 27,UNSURVEYED,ALL TIDE AND SUBMERGED LANDS,207 ACRES; SECTION 34,UNSURVEYED,ALL TIDE AND SUBMERGED LANDS,171 ACRES; SECTION 35,UNSURVEYED,ALL TIDE AND SUBMERGED LANDS, 110 ACRES; SECTION 36,UNSURVEYED,ALL TIDE AND SUBMERGED LANDS,523 ACRES. T. 10 N.,R. 19 E.,TRACT A,UMIAT MERIDIAN,ALASKA SECTION 26,UNSURVEYED,FRACTIONAL,ALL 382 ACRES; SECTION 27,UNSURVEYED,FRACTIONAL,ALL 433 ACRES; SECTION 34,UNSURVEYED,FRACTIONAL,ALL 469 ACRES; SECTION 35,UNSURVEYED,FRACTIONAL,ALL 530 ACRES; SECTION 36,UNSURVEYED,FRACTIONAL,ALL 117 ACRES. THIS TRACT CONTAINS 3840 ACRES MORE OR LESS. ********************************************************************** MARCH 17,1995***LEASE COMM'11'LD TO THE BADAMI UNIT AGREEMENT*** THE ENTIRE LEASE WAS COMMITTED TO THE BADAMI UNIT AGREEMENT EFFECTIVE MARCH 13,1995. THE LEGAL DESCRIPTION OF TRACT 3 OF THE BADAMI UNIT IS THE SAME AS THE SALE NOTICE LEGAL DESCRIPTION ABOVE. BADAMI UNIT TRACT 3 T. 10 N.,R. 19 E.,UMIAT MERIDIAN,ALASKA http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=3 670... 2/10/201 2 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 .ems 1,144 - '4v7 PTD# Vo?0/9 Development Service ✓ Exploratory Stratigraphic Test Non-Conventional Well • FIELD: ..4644/1/ POOL: , €.7'/A'7 '4 ©/G Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter ADD-ONS CHECK (OPTIONS) WHAT TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in i Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 n o � � CO n b 3 0 m C? � � a o cn � 9' a '• r ° ; r C) 3.O N N 7' j .197+ O m ocon_ O 0 N c° o a b' co X7 o ND CD 0 0 0 CD ° —1 N N N _ -. 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O CD co CD 7 .Q : rtiO CO CD Ei OD fD O 7• �3 �O 0 N O :v (D .0) 7 : 0 0 m 0 '� n- A- 3 o -13r c a a A • w O CC] 7 CD D 7 CD C — ciT o 0 0 yy o co v ❑❑ Well History File APPENDIX I nfoi r n ration of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Date Date Client: Savant Alaska LLC Field: Badami/Exploration Rig: Nabors 7ES Date: April 25th, 2012 Surface Data Logging End of Well Report Red Wolf 2 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Formation Tops 7. Survey Report 8. Days vs. Depth Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer EOW Report PDF Version ADI Backup GENERAL WELL INFORMATION Company: Savant Alaska LLC Rig: Nabors 7ES Well: Red Wolf 2 Field: Badami Borough: North Slope Borough State: Alaska Country: United States API Number: 50-029-23465-00 Sperry Job Number: AK-AM-0009110182 Job Start Date: 1 April 2012 Spud Date: 3 April 2012 Total Depth: 11860’ MD, 11857’ TVD SDL Release Date: 24 April 2012 North Reference: True Declination: 21.6837° Dip Angle: 81.099° Total Field Strength: 57693 nT Date Of Magnetic Data: 3 April 2012 Wellhead Coordinates N: North 70° 10’ 27.24” Wellhead Coordinates W: West 147° 12’ 45.79“ Drill Floor Elevation 35.00’ Ground Elevation: 4.50’ Permanent Datum: Mean Sea Level SDL Engineers: Craig Amos, Jessica Munsell SDL Sample Catchers: Herman Lilgreen, Joshua Cloyd Company Geologist: Eric Opstad Company Representatives: Gary Hammon, Lonnie Drollinger SSDS Unit Number: 121 DAILY SUMMARY 04/01/2012 SDL and MWD arrived on location. 04/02/2012 Spot and set MWD and mudlogging shacks. Had electrician plug in the units. Rigged up the CVE gas system and ran lines while waiting on unit to warm up. Rigged up Legacy gas trap, ran gas line to the unit, and set up gas equipment in the unit. 04/03/2012 Rigged up network connection with MWD and WITS to Canrig. Troubleshoot and set up computers and finished setting up gas equipment. Calibrated the 8800 gas analyzer and the 8900 gas chromatograph. Troubleshoot issues with the gas analyzer sending data to the computer. Nippled up and tested diverter system. Tested gas alarms. Picked up drill pipe, heavy weight drill pipe, and BHA. Filled and circulated spud mud in conductor casing. Drilled ahead from 110’ MD to 405’ MD. No samples will be caught through the surface section of this well. 04/04/2012 Tripped out of the hole to surface and picked up the rest of the BHA. Tripped back into the hole and continued to drill ahead. Heavy gravel coming over the shakers. Gas: The max gas was 115 units at 975’ MD and the average background gas was 17 units. Fluids: No losses seen. 04/05/2012 Drill ahead to 1402’ MD. Pulled out of the hole for a bit change. Heavy gravels still coming over the shakers. Large pebbles are getting inside the Legacy gas trap causing the impellers to break and gas readings were staying around one to two units. It was decided to turn on the CVE to see what kind of gas we are getting from it, and gas immediately went up to 18-20 units. Tested CVE and Legacy gas trap, both working correctly. Switched between the two gas systems periodically to compare gas readings. Both gas systems are reading around the same number of units. After bit change, ran back into the hole, and continued to drilled ahead. Gas: The max gas was 80 units at 1405’ MD and the average background gas was 22 units. A max trip gas of 79 units was seen. Fluids: No losses seen. 04/06/2012 Continued to drill ahead to 2585’ MD. One of the directional tools failed to work properly and it was decided to trip out of the hole to change the tool. Tripped out of the hole. At 1750’ MD, torque was 20k-25k over pull. Back reamed and washed down to 1770’ MD. Continued to trip out of the hole. Changed the failed directional tool and ran back into the hole. Gas: The max gas was 57 units at 2690’ MD and the average background gas was 20 units. A max trip gas of 23 units was seen. Fluids: No losses seen. 04/07/2012 Continued to run into the hole to 2585’ MD. Continued to drill ahead. Samples taken every 100’ as per request of the owner to help in deciding where to call TD. Gas: The max gas was 10012 units at 3872’ MD and the average background gas was 165 units. Fluids: No losses seen. 04/08/2012 Continued to drill ahead to 3872’ MD TD. Short wiper trip to 2423’ MD. Ran back into the hole to 3849’ MD and dropped carbide to calculate hole size. Circulated surface to surface. After the carbide test, a 12.28” hole size was calculated. Pulled out of the hole to surface. Laid down BHA. Rigged up to run casing. Began running in with 9 5/8” casing. Gas: The max gas was 70 units at 3859’ MD and the average background gas was 46 units. Fluids: No losses seen. 04/09/2012 Continued to run in with 9 5/8” casing to 3849’ MD. Circulated and conditioned mud. Rigged up and pumped cement. Displaced/chased cement with 276 barrels of mud. Ran five stands and TAM combo tool into hole, opened TAM collar. Prepped for top cement job. Gas: No gas data. Fluids: There was 42 barrels of mud loss down hole while pumping cement. 04/10/2012 Waited on cement trucks to come to location. Pre job and rigged up for top job. Pumped 150 barrels top job, cement seen at surface. Rigged down cement lines and diverter. Rigged up and nippled down BOP, clean pits. Gas: No gas data. Fluids: No losses seen. 04/11/2012 Continued to nipple down BOP and clean pits. Ran in the hole with 5” drill pipe and laid down 5” drill pipe. Began picking up 4” drill pipe. Sample catchers arrived on location. Gas: No gas data. Fluids: No losses seen. 04/12/2012 Finished picking up 4” drill pipe. Picked up dumb iron BHA and ran in the hole to bottom. Pumped spacer and chased with LSND. Displaced spud mud with LSND. Pressure tested the casing twice. Tagged cement at 3656’ MD and drilled to open hole at 3872’ MD. Drilled ahead. Cleaned pits for LSND. Geology: Dark gray, dark gray brown, soft, smooth to gritty, and slightly calcareous claystone. Gas: The max gas was 185 units at 3946’ MD with an average background gas of 54 units. Fluids: No losses seen. 04/13/2012 Continued to drill ahead to 3964’ MD. Pulled out of the hole to surface. Laid down dumb iron BHA and picked up smart tools BHA. Ran in to the hole and continued to drill ahead. Geology: Medium to light gray, predominantly firm, sticky, smooth to earthy, amorphous, non calcareous claystone. Gas: The max gas was 70 units at 5172’ MD and the average background gas was 16 units. Fluids: There was 12.9 barrels of LSND lost down hole. 04/14/2012 Continued to drill ahead to 6003’ MD. Pumped high-vis sweep. Pulled out of the hole to the shoe for a wiper trip. Reamed back down to 4688’ MD and then tripped back into the hole to bottom. Blew down the top drive. Continued to drill ahead. Geology: Dark gray, medium brown gray, predominantly soft, smooth, amorphous, slightly calcareous claystone. Gas: The max gas was 101 units at 6513’ MD and the average background gas was 14 units. Fluids: There was 7.7 barrels of LSND lost down hole. 04/15/2012 Continued to drill ahead. At 6900’ MD, 1000 units of gas were seen as well as traces of oil at the shakers and on the samples. Geology: Medium to light gray, predominantly soft, rarely firm, smooth to earthy siltstone, with a small percentage of claystone and sandstone. Gas: The max gas was 1003 units at 6941’ MD and the average background gas was 78 units. Fluids: There was 10.6 barrels of LSND lost down hole. 04/16/2012 Continued to drill ahead. Ran high-vis sweeps every 500’ MD. Drilled ahead to 9378’ MD. Pump went out; circulated while repairing pump. Geology: Translucent, light yellow gray with occasional black, very fine grained, sub-round, sub-spherical, partially calcareous sandstone with small percentage of siltstone; no show was present. Gas: The max gas was 123 units at 8890’ MD and the average background gas was 63 units. Fluids: There was 10.1 barrels of LSND lost down hole. 04/17/2012 Continued to circulate while repairing pump. It was decided to pull out of the hole on elevators to surface for an MWD tool change. Continued to work on the pump. Finished pulling out of the hole to surface. Fixed pump and tested BOPs. Geology: No geology. Gas: No gas data. Fluids: There was 13 barrels of LSND lost down hole. 04/18/2012 Finished testing BOPs. Ran in the hole with RTTS to 1535’ MD. Ran out of the hole to surface. Picked up BHA. Ran in the hole to casing shoe, cut and slip drill line. Ran in the hole to bottom. Continued to drill ahead. Geology: Light brown gray, translucent, light gray, very fine grained, silty, sub-round, moderately well sorted no cement, slightly calcareous sandstone. No shows present. Gas: A max trip gas of 280 units was seen. The max gas was 177 units at 9424’ MD and the average background gas was 61 units. Fluids: There was 7.6 barrels of LSND lost down hole. 04/19/2012 Continued to drill ahead. Geology: Dark to medium gray, occasional brown black, very hard to firm, sub-round to round, moderately sorted, rare laminations, non calcareous sandstone, with grading siltstone in part. Gas: The max gas was 159 units at 10844’ MD and the average background gas was 58 units. Fluids: There was 6 barrels of LSND lost down hole. 04/20/2012 Continued to drill ahead. At 11647’ MD, pulled off bottom and circulated to check for losses. No losses seen. Geology: Dark to medium gray, tan, translucent to white, occasional black, firm to slightly hard, fine to medium grained, unconsolidated, sub-angular to sub-round, moderately sorted, occasional pyrite, non calcareous sandstone with pinpoint yellow fluorescence and a cloudy fast streaming cut. Gas: The max gas was 591 units at 11678’ MD and the average background gas was 197 units. Fluids: There was 9.2 barrels of LSND lost down hole. 04/21/2012 Continued to drill ahead to 11860’ MD TD. Circulated bottoms up and pulled out of the hole to surface. Laid down BHA. Picked up cementing assembly. Started to run in the hole to bottom. Geology: Right before TDing the samples were black, very hard, blocky coal. Gas: The max gas was 515 units at 11756’ MD and the average background gas was 105 units. Fluids: There was 6 barrels of LSND lost down hole. 04/22/2012 Continued to run in the hole to bottom to begin cementing the hole. Cemented the bottom of the hole. Pulled out of the hole, laying down singles to surface. Ran in the hole to the shoe at 3849’ MD. Began rigging down CVE and gas equipment associated with the CVE. Geology: No geology. Gas: No gas data. Fluids: No losses seen. 04/23/2012 Continued to run in the hole to the casing shoe at 3849’ MD. Set packer and tested cement lines. Cemented hole at the casing shoe. Pulled out of the hole to XXXX’ MD and cemented the hole. Continued to rig down Legacy gas trap, gas equipment, and unit. Geology: No geology. Gas: No gas data. Fluids: No losses seen. Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) Ann Corr Cor Solids (lb/100ft 2) 500 24 hr Max YP mg/l Avg Sst API Filt 8.90 75 Sh Sd 8.0 Lst 110' 200 Silt Siltst Clyst Tuff Gas Summary Chromatograph (ppm) Cht 63 9.30 9.30 456 PV Size MBT 37.5 HDBS QHC1GRC 993' 1 5-Apr-12 1402' Nabors 7ES $2,180.00 AK-AM-0009110182 ml/30min 6.8 41.1 106.0 Savant Alaska LLC Red Wolf 2 Badami 12.25 0.693 (ppb Eq) cP Gvl Coal Min Avg pH Chlorides % Min Max Max 1 2.9090 $15,400.00 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 905' POOH Lonnie Drollinger Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg Current R.O.P. (ft/hr) 495' Depth 1402'15.77 PWD Drilling All Circ Avg Diam 0.0 Max @ ft Hole Condition On Bot Hrs * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell C-5n 7 Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i Maximum 115 975'12379 5031 2487 2515 2577 1037 1026 Minimum 1 497'0 0 0 0 0 0 0 Average 17 162 33 7 7 3 3 Background 8 Trip (current) (max) 24 hr Recap: Continued to drill ahead to 1402’ MD. Currently pulling out of the hole to change the bit. Heavy gravels still coming over the shakers before beginning to trip out of the hole. The max gas was 115 units at 975’ MD and the average background gas was 17 units. No samples will be caught through the surface section of this well. No losses seen. Craig Amos / Jessica Munsell Jessica Munsell Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 104.4 Max @ ft Hole Condition On Bot Hrs Current R.O.P. (ft/hr) 2087' Depth 2086'10.12 684' Drilling Ahead Lonnie Drollinger Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg $17,580.00 425 80 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Min Max Max 1039 2.9090 Min Avg pH Chlorides % 12.25 Gvl Coal 0.693 33.9 181.1 Savant Alaska LLC Red Wolf 2 Badami 12.25 0.739 (ppb Eq) cP HDBS EQH12DRC 1711' 2 6-Apr-12 2086' Nabors 7ES $2,180.00 AK-AM-0009110182 ml/30min 6.8 9.35 9.45 315 PV Size MBT 35.0 Cht 14.42 1292'110' 1402' 43 Gas Summary Chromatograph (ppm) 15 Tuff Sd 8.0 Lst 1402' 300 200 HDBS QHC1GRC Silt Siltst Clyst Sst API Filt 9.00 120 56 Sh Ann Corr Cor Solids (lb/100ft 2) 400 24 hr Max YP mg/l Avg * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell 24 hr Recap: After bit change, ran back into the hole, and continued to drilled ahead. The max gas was 80 units at 1405’ MD and the average background gas was 22 units. A max trip gas of 79 units was seen. No losses seen. Craig Amos / Jessica Munsell Jessica Munsell (current) (max) Background 16 Trip 79 0 0 0 0 0 0 0 0 Average 22 1091 0 0 0Minimum 1 1654'0 37 48 59 34 45 C-5i Maximum 80 1405'4231 56 C-2 C-3 C-4i C-4n Units* Depth C-1 0 C-5n Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 134.9 Max @ ft Hole Condition On Bot Hrs Current R.O.P. (ft/hr) 2734' Depth 2734'18.7 648' Drilling Ahead Lonnie Drollinger Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg $19,760.00 418 71 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Min Max Max 1342 2.9090 Min Avg pH Chlorides % 12.25 Gvl Coal 0.693 16.4 215.2 Savant Alaska LLC Red Wolf 2 Badami 12.25 0.739 (ppb Eq) cP HDBS EQH12DRC 2585' 3 7-Apr-12 2734' Nabors 7ES $2,180.00 AK-AM-0009110182 ml/30min 6.3 9.30 9.30 301 PV Size MBT 37.5 Cht 14.42 1292'110' 1402' 42 Gas Summary Chromatograph (ppm) 15 Tuff Sd 10.4 Lst 1402' 300 200 HDBS QHC1GRC Silt Siltst Clyst Sst API Filt 8.60 120 52 Sh Ann Corr Cor Solids (lb/100ft 2) 500 24 hr Max YP mg/l Avg * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell 24 hr Recap: Continued to drill ahead to 2585’ MD. One of the directional tools failed to work properly and it was decided to trip out of the hole to change the tool. Tripped out of the hole. At 1750’ MD, torque was 20k-25k over pull. Back reamed and washed down to 1770’ MD. Continued to trip out of the hole. Changed the failed directional tool and ran back into the hole. Continued to drill ahead. The max gas was 57 units at 2690’ MD and the average background gas was 20 units. A max trip gas of 23 units was seen. No losses seen. Craig Amos / Jessica Munsell Jessica Munsell (current) (max) Background 11 Trip 23 10 3 3 0 0 0 0 0 Average 20 974 0 0 0Minimum 1 2585'0 21 21 22 4 2 C-5i Maximum 57 2690'4934 51 C-2 C-3 C-4i C-4n Units* Depth C-1 3 C-5n Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) Ann Corr Cor Solids (lb/100ft 2) 1,400 24 hr Max YP mg/l Avg Sst API Filt 9.10 120 48 Sh Sd 8.6 Lst 1402' 300 200 HDBS QHC1GRC Silt Siltst Clyst 15 Tuff Gas Summary Chromatograph (ppm) Cht 14.42 1292'110' 1402' 37 9.30 9.35 306 PV Size MBT 35.0 HDBS EQH12DRC 2802' 4 8-Apr-12 3872' Nabors 7ES $2,180.00 AK-AM-0009110182 ml/30min 7.2 0.693 47.9 379.7 Savant Alaska LLC Red Wolf 2 Badami 12.25 0.739 (ppb Eq) cP 12.25 Gvl Coal Min Avg pH Chlorides % Min Max Max 0 2.9090 $21,940.00 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 1138' Drilling Ahead Lonnie Drollinger Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg Current R.O.P. (ft/hr) 3872' Depth 2734'18.7 PWD Drilling All Circ Avg Diam 0.0 Max @ ft Hole Condition On Bot Hrs * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell C-5n 24 Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i Maximum 10012 3872'90430 4781 2390 2425 2451 1008 1022 Minimum 1 2691'0 0 0 0 0 0 0 Average 165 5621 49 25 24 10 10 Background 0 Trip (current) (max) 24 hr Recap: Continued to run into the hole to 2585’ MD. Continued to drill ahead. Samples taken every 100’ as per request of the owner to help in deciding where to call TD. Continued to drill ahead to 3872’ MD TD. Short wiper trip to 2423’ MD. Began running back into the hole. The max gas was 10012 units at 3872’ MD and the average background gas was 165 units. No losses seen. Craig Amos / Jessica Munsell Jessica Munsell Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) Ann Corr Cor Solids (lb/100ft 2) 1,200 24 hr Max YP mg/l Avg Sst API Filt 9.00 120 130 33 Sh Sd 8.0 Lst 1402' 300 200 HDBS QHC1GRC Silt Siltst Clyst 15 13 Tuff Gas Summary Chromatograph (ppm) Cht 14.42 1292'110' 1402' 36 15.39 3872' 2470' 9.30 9.30 205 PV Size MBT 30.0 HDBS EQH12DRC 3872' 5 9-Apr-12 3872' Nabors 7ES $2,180.00 AK-AM-0009110182 ml/30min 7.2 0.693 9.0 36.0 Savant Alaska LLC Red Wolf 2 Badami 12.25 0.739 (ppb Eq) cP 12.25 Gvl Coal Min Avg pH Chlorides % Min Max Max 0 2.9090 $24,120.00 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' RIH w/ casing Lonnie Drollinger Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg Current R.O.P. (ft/hr) 3872' Depth 2734'18.7 PWD Drilling All Circ Avg Diam 0.0 Max @ ft Hole Condition On Bot Hrs * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell C-5n 6145 Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i Maximum 70 3859'9182 9441 9309 0 0 0 0 Minimum 30 3853'3760 3803 3781 0 0 0 0 Average 46 5956 6339 0 0 0 0 Background Trip (current) (max) 24 hr Recap: Continued to drill ahead to 3872’ MD TD. Short wiper trip to 2423’ MD. Ran back into the hole to 3849’ MD and dropped carbide to calculate hole size. Circulated surface to surface. After the carbide test, a 12.28” hole size was calculated. Pulled out of the hole to surface. Laid down BHA. Rigged up to run casing. Began running in with 9 5/8” casing. The max gas was 70 units at 3859’ MD and the average background gas was 46 units. No losses seen. Craig Amos / Jessica Munsell Jessica Munsell Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) Ann Corr Cor Solids (lb/100ft 2) 1,200 24 hr Max YP mg/l Avg Sst API Filt 9.00 120 130 33 Sh Sd 8.0 Lst 1402' 300 200 HDBS QHC1GRC Silt Siltst Clyst 15 13 Tuff Gas Summary Chromatograph (ppm) Cht 14.42 1292'110' 1402' 36 15.39 3872' 2470' 9.30 9.30 205 PV Size MBT 30.0 HDBS EQH12DRC 3872' 6 10-Apr-12 3872' Nabors 7ES $2,180.00 AK-AM-0009110182 ml/30min 7.2 0.693 Savant Alaska LLC Red Wolf 2 Badami 12.25 0.739 (ppb Eq) cP 12.25 Gvl Coal Min Avg pH Chlorides % Min Max Max 0 2.9090 $26,300.00 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Rig up to cement Lonnie Drollinger Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg Current R.O.P. (ft/hr) Depth PWD Drilling All Circ Avg Diam Max @ ft Hole Condition On Bot Hrs * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell C-5n Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i Maximum Minimum Average Background Trip (current) (max) 24 hr Recap: Continued to run in with 9 5/8” casing to 3849’ MD. Circulated and conditioned mud. Rigged up and pumped cement. Displaced/chased cement with 276 barrels of mud. Ran five stands and TAM combo tool into hole, opened TAM collar. Prepped for top cement job. Waited on cement trucks to come to location. There was 42 barrels of mud loss down hole while pumping cement. No gas data. Craig Amos / Jessica Munsell Jessica Munsell Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam Max @ ft Hole Condition On Bot Hrs Current R.O.P. (ft/hr) Depth 0' N/D BOP Lonnie Drollinger Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg $31,480.00 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Min Max Max 0 2.9090 Min Avg pH Chlorides % Gvl Coal Savant Alaska LLC Red Wolf 2 Badami 12.25 0.739 (ppb Eq) cP HDBS EQH12DRC 3872' 11 11-Apr-12 3872' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 3.7 9.00 9.00 70 PV Size MBT - Cht 22 3872' 2470' Gas Summary Chromatograph (ppm) Tuff Sd 7.2 Lst 1402' 400 Silt Siltst Clyst Sst API Filt 9.00 26 Sh Ann Corr Cor Solids (lb/100ft 2) 1,000 24 hr Max YP mg/l Avg * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell 24 hr Recap: Waited on cement trucks to come to location. Pre job and rigged up for top job. Pumped 150 barrels top job, cement seen at surface. Rigged down cement lines and diverter. Rigged up and nippled down BOP, clean pits. Craig Amos / Jessica Munsell Jessica Munsell (current) (max) Background Trip Average Minimum C-5i Maximum C-2 C-3 C-4i C-4n Units* Depth C-1 C-5n Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) Ann Corr Cor Solids (lb/100ft 2) 900 24 hr Max YP mg/l Avg Sst API Filt 9.00 27 Sh Sd 7.0 Lst 1402' 400 Silt Siltst Clyst Tuff Gas Summary Chromatograph (ppm) Cht 23 3872' 2470' 9.00 9.00 70 PV Size MBT - HDBS EQH12DRC 3872' 12 12-Apr-12 3872' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 3.2 Savant Alaska LLC Red Wolf 2 Badami 12.25 0.739 (ppb Eq) cP Gvl Coal Min Avg pH Chlorides % Min Max Max 0 2.9090 $34,480.00 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' P/U 4" DP Lonnie Drollinger Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg Current R.O.P. (ft/hr) Depth PWD Drilling All Circ Avg Diam Max @ ft Hole Condition On Bot Hrs * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell C-5n Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i Maximum Minimum Average Background Trip (current) (max) 24 hr Recap: Ran in the hole with 5” drill pipe and laid down 5” drill pipe. Began picking up 4” drill pipe. Sample catchers arrived on location. Craig Amos / Jessica Munsell Jessica Munsell Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 0.0 Max @ ft Hole Condition On Bot Hrs Current R.O.P. (ft/hr) 3938' Depth 3964'3.53 92' POOH Lonnie Drollinger Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg $37,480.00 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Min Max Max 0 2.9090 Min Avg pH Chlorides % Gvl Coal 21.1 101.6 Savant Alaska LLC Red Wolf 2 Badami 12.25 0.739 (ppb Eq) cP HDBS EQH12DRC 3887' 13 13-Apr-12 3964' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 3.7 9.00 9.00 75 PV Size MBT 6.0 Cht 27 3872' 2470' Gas Summary Chromatograph (ppm) Tuff Sd 7.4 Lst 1402' 400 Silt Siltst Clyst Sst API Filt 10.50 33 100 Sh Ann Corr Cor Solids (lb/100ft 2) 1,000 24 hr Max YP mg/l Avg * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell 24 hr Recap: Finished picking up 4” drill pipe. Picked up dumb iron BHA and ran in the hole to bottom. Pumped spacer and chased with LSND. Displaced spud mud with LSND. Pressure tested the casing twice. Tagged cement at 3656’ MD and drilled to open hole at 3872’ MD. Drilled ahead. Cleaned pits for LSND. Continued to drill ahead to 3964’ MD. Circulated bottoms up and began to pull out of the hole. The samples have been dark gray, dark gray brown, soft, smooth to gritty, and slightly calcareous claystone. The max gas was 185 units at 3946’ MD with an average background gas of 54 units. No losses have been seen. Craig Amos / Jessica Munsell Jessica Munsell (current) (max) Background 0 Trip 23 0 0 0 0 0 0 0 Average 54 41 0 0 0Minimum 1 3872'0 393 0 0 0 0 C-5i Maximum 185 3946'1910 621 C-2 C-3 C-4i C-4n Units* Depth C-1 5 C-5n Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 112.6 Max @ ft Hole Condition On Bot Hrs Current R.O.P. (ft/hr) 4245' Depth 5221'8.98 1257' Drill Ahead Lonnie Drollinger Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg $40,480.00 544 114 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Min Max Max 2271 2.9090 Min Avg pH Chlorides % Gvl Coal 57.9 252.9 Savant Alaska LLC Red Wolf 2 Badami 8.5 0.778 (ppb Eq) cP NOV DTX619M-D6 4688' 14 14-Apr-12 5221' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 4.2 9.00 9.00 60 PV Size MBT 7.5 Cht 21 Gas Summary Chromatograph (ppm) Tuff Sd 6.4 Lst 3964' 600 Silt Siltst Clyst Sst API Filt 10.70 28 100 Sh Ann Corr Cor Solids (lb/100ft 2) 1,000 24 hr Max YP mg/l Avg * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell 24 hr Recap: Continued to drill ahead to 3964’ MD. Pulled out of the hole to surface. Laid down dumb iron BHA and picked up smart tools BHA. Ran in to the hole and continued to drill ahead. The max gas was 70 units at 5172’ MD and the average background gas was 16 units. The samples have been medium to light gray, predominantly firm, sticky, smooth to earthy, amorphous, non calcareous claystone. There was 12.9 barrels of LSND lost down hole. Craig Amos / Jessica Munsell Jessica Munsell (current) (max) Background 11 Trip 0 0 0 0 0 0 0 0 Average 16 1409 0 0 0Minimum 1 3964'0 0 0 0 0 0 C-5i Maximum 70 5172'2509 5 C-2 C-3 C-4i C-4n Units* Depth C-1 0 C-5n Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) Ann Corr Cor Solids (lb/100ft 2) 1,500 24 hr Max YP mg/l Avg Sst API Filt 9.30 33 100 Sh Sd 6.0 Lst 3964' 600 Silt Siltst Clyst Tuff Gas Summary Chromatograph (ppm) Cht 24 9.20 9.20 77 PV Size MBT 10.0 NOV DTX619M-D6 6003' 11 15-Apr-12 6554' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 6.2 55.6 225.4 Savant Alaska LLC Red Wolf 2 Badami 8.5 0.778 (ppb Eq) cP Gvl Coal Min Avg pH Chlorides % Min Max Max 2737 2.9090 $41,300.00 547 112 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 1333' Drilling Ahead Gary Hammon Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg Current R.O.P. (ft/hr) 6193' Depth 6554'19.6 PWD Drilling All Circ Avg Diam 76.6 Max @ ft Hole Condition On Bot Hrs * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell C-5n 0 Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i Maximum 101 6513'43851 5088 2516 0 0 0 0 Minimum 4 5173'0 0 0 0 0 0 0 Average 14 1600 79 0 0 0 0 Background 32 Trip (current) (max) 24 hr Recap: Continued to drill ahead to 6003’ MD. Pumped high-vis sweep. Pulled out of the hole to the shoe for a wiper trip. Reamed back down to 4688’ MD and then tripped back into the hole to bottom. Blew down the top drive. Continued to drill ahead. The max gas was 101 units at 6513’ MD and the average background gas was 14 units. The samples have been dark gray, medium brown gray, predominantly soft, smooth, amorphous, slightly calcareous claystone. There was 7.7 barrels of LSND lost down hole. Craig Amos / Jessica Munsell Jessica Munsell Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 75.3 Max @ ft Hole Condition On Bot Hrs Current R.O.P. (ft/hr) 7138' Depth 8298'36.62 1744' Drilling Ahead Gary Hammon Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg $44,300.00 551 118 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Min Max Max 3519 2.9090 Min Avg pH Chlorides % Gvl Coal 72.8 198.2 Savant Alaska LLC Red Wolf 2 Badami 8.5 0.778 (ppb Eq) cP NOV DTX619M-D6 8065' 12 16-Apr-12 8298' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 6.2 9.40 9.40 63 PV Size MBT 15.0 Cht 26 20 70 Gas Summary Chromatograph (ppm) Tuff Sd 5.6 Lst 3964' 600 Silt Siltst Clyst Sst API Filt 9.70 26 10 Sh Ann Corr Cor Solids (lb/100ft 2) 1,500 24 hr Max YP mg/l Avg * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell 24 hr Recap: Continued to drill ahead. At 6500’ MD, 1000 units of gas were seen as well as traces of oil at the shakers and on the samples. The max gas was 1003 units at 6941’ MD and the average background gas was 78 units. The samples have been medium to light gray, predominantly soft, rarely firm, smooth to earthy siltstone, with a small percentage of claystone and sandstone. There was 10.6 barrels of LSND lost down hole. Craig Amos / Jessica Munsell Jessica Munsell (current) (max) Background 55 Trip 14 0 0 0 0 0 0 0 Average 78 3892 0 0 0Minimum 8 6514'0 12 8 7 0 0 C-5i Maximum 1003 6941'75134 276 C-2 C-3 C-4i C-4n Units* Depth C-1 0 C-5n Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 0.0 Max @ ft Hole Condition On Bot Hrs Current R.O.P. (ft/hr) 8384' Depth 9378'49.61 1080' POOH Gary Hammon Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg $47,300.00 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Min Max Max 0 2.9090 Min Avg pH Chlorides % Gvl Coal 45.2 140.3 Savant Alaska LLC Red Wolf 2 Badami 8.5 0.778 (ppb Eq) cP NOV DTX619M-D6 9374' 13 17-Apr-12 9378' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 8.2 9.50 9.50 62 PV Size MBT 22.5 Cht 25 70 30 Gas Summary Chromatograph (ppm) Tuff Sd 5.2 Lst 3964' 600 Silt Siltst Clyst Sst API Filt 9.60 24 Sh Ann Corr Cor Solids (lb/100ft 2) 1,100 24 hr Max YP mg/l Avg * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell 24 hr Recap: Continued to drill ahead. Ran high-vis sweeps every 500’ MD. Drilled ahead to 9378’ MD. Pump went out; circulated while repairing pump. It was decided to pull out of the hole on elevators to surface for an MWD tool change. Continued to work on the pump. The max gas was 123 units at 8890’ MD and the average background gas was 63 units. The sample before pulling out of the whole was translucent, light yellow gray with occasional black, very fine grained, sub-round, sub-spherical, partially calcareous sandstone with small percentage of siltstone; no show was present. There was 10.1 barrels of LSND lost down hole. Craig Amos / Jessica Munsell Jessica Munsell (current) (max) Background Trip 186 16 33 8 7 0 0 0 Average 63 5054 0 0 0Minimum 9 8787'60 565 102 184 54 49 C-5i Maximum 123 8890'14530 804 C-2 C-3 C-4i C-4n Units* Depth C-1 95 C-5n Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) Ann Corr Cor Solids (lb/100ft 2) 1,100 24 hr Max YP mg/l Avg Sst API Filt 9.10 23 Sh Sd 5.6 Lst 3964' 600 Silt Siltst Clyst Tuff Gas Summary Chromatograph (ppm) Cht 25 9378' 5414' 9.50 9.50 76 PV Size MBT 12.5 NOV DTX619M-D6 9378' 14 18-Apr-12 9378' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 5.7 Savant Alaska LLC Red Wolf 2 Badami 8.5 0.778 (ppb Eq) cP Gvl Coal Min Avg pH Chlorides % Min Max Max 0 2.9090 $50,300.00 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' POOH Gary Hammon Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg Current R.O.P. (ft/hr) Depth 9378'49.61 PWD Drilling All Circ Avg Diam 0.0 Max @ ft Hole Condition On Bot Hrs * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell C-5n Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i Maximum Minimum Average Background Trip (current) (max) 24 hr Recap: Pulled out of the hole on elevators to surface while repairing pump. Repaired pump and tested BOPs. Ran in the hole with RTTS to 1535' MD and pulled out of the hole to surface. No gas data. There was 13 barrels of LSND lost down hole. Craig Amos / Jessica Munsell Jessica Munsell Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) Ann Corr Cor Solids (lb/100ft 2) 1,100 24 hr Max YP mg/l Avg Sst API Filt 9.60 25 Sh Sd 6.2 Lst 9378' 700 Silt Siltst Clyst Tuff 80 20 Gas Summary Chromatograph (ppm) Cht 23 9.60 9.70 69 PV Size MBT 12.5 NOV DTX619M-D6 9431' 15 19-Apr-12 9719' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 5.7 14.9 136.3 Savant Alaska LLC Red Wolf 2 Badami 8.5 0.778 (ppb Eq) cP Gvl Coal Min Avg pH Chlorides % Min Max Max 2462 2.9090 $53,300.00 79 409 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 341' Drilling Ahead Gary Hammon Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg Current R.O.P. (ft/hr) 9672' Depth 9719'4.23 PWD Drilling All Circ Avg Diam 61.7 Max @ ft Hole Condition On Bot Hrs * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell C-5n 55 Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i Maximum 177 9424'19376 717 308 52 88 29 26 Minimum 7 9378'2946 105 62 12 25 8 7 Average 61 3296 114 10 20 4 3 Background 37 Trip 280 (current) (max) 24 hr Recap: Picked up BHA. Ran in the hole to casing shoe, cut and slip drill line. Ran in the hole to bottom. Continued to drill ahead. A max trip gas of 280 units was seen. The max gas was 177 units at 9424’ MD and the average background gas was 61 units. The samples have been light brown gray, translucent, light gray, very fine grained, silty, sub-round, moderately well sorted no cement, slightly calcareous sandstone. No shows present. There was 7.6 barrels of LSND lost down hole. Craig Amos / Jessica Munsell Jessica Munsell Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 87.8 Max @ ft Hole Condition On Bot Hrs Current R.O.P. (ft/hr) 10096' Depth 11052'22.49 1333' Drilling Ahead Gary Hammon Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg $56,300.00 103 504 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Min Max Max 3778 2.9090 Min Avg pH Chlorides % Gvl Coal 55.6 114.2 Savant Alaska LLC Red Wolf 2 Badami 8.5 0.778 (ppb Eq) cP NOV DTX619M-D6 10762' 16 20-Apr-12 11052' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 7.7 9.55 9.55 62 PV Size MBT 12.5 Cht 19 90 10 Gas Summary Chromatograph (ppm) Tuff Sd 5.4 Lst 9378' 700 Silt Siltst Clyst Sst API Filt 9.10 25 Sh Ann Corr Cor Solids (lb/100ft 2) 1,200 24 hr Max YP mg/l Avg * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell 24 hr Recap: Continued to drill ahead. The max gas was 159 units at 10844’ MD and the average background gas was 58 units. The samples have been dark to medium gray, occasional brown black, very hard to firm, sub-round to round, moderately sorted, rare laminations, non calcareous sandstone, with grading siltstone in part. There was 6 barrels of LSND lost down hole. Craig Amos / Jessica Munsell Jessica Munsell (current) (max) Background 72 Trip 183 24 37 13 9 0 0 0 Average 58 5248 41 21 3Minimum 14 10604'1225 475 103 188 73 68 C-5i Maximum 159 10844'14933 661 C-2 C-3 C-4i C-4n Units* Depth C-1 103 C-5n Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) Ann Corr Cor Solids (lb/100ft 2) 900 24 hr Max YP mg/l Avg Sst API Filt 9.40 25 Sh Sd 5.6 Lst 9378' 700 Silt Siltst Clyst Tuff 100 Gas Summary Chromatograph (ppm) Cht 20 9.60 9.60 62 PV Size MBT 12.5 NOV DTX619M-D6 11731' 17 21-Apr-12 11830' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 8.8 32.3 108.7 Savant Alaska LLC Red Wolf 2 Badami 8.5 0.778 (ppb Eq) cP Gvl Coal Min Avg pH Chlorides % Min Max Max 4003 2.9090 $59,300.00 492 103 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 778' Drilling Ahead Gary Hammon Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg Current R.O.P. (ft/hr) 11679' Depth 11830'41 PWD Drilling All Circ Avg Diam 10.2 Max @ ft Hole Condition On Bot Hrs * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell C-5n 519 Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i Maximum 591 11678'64791 2861 863 104 318 72 78 Minimum 5 11016'7309 297 209 39 66 25 25 Average 197 13781 892 59 175 37 43 Background 88 Trip (current) (max) 24 hr Recap: Continued to drill ahead. At 11647’ MD, pulled off bottom and circulated to check for losses. No losses seen. The max gas was 591 units at 11678’ MD and the average background gas was 197 units. The samples have been dark to medium gray, tan, translucent to white, occasional black, firm to slightly hard, fine to medium grained, unconsolidated, sub-angular to sub-round, moderately sorted, occasional pyrite, non calcareous sandstone with pinpoint yellow fluorescence and a cloudy fast streaming cut. There was 9.2 barrels of LSND lost down hole. Craig Amos / Jessica Munsell Jessica Munsell Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam Max @ ft Hole Condition On Bot Hrs Current R.O.P. (ft/hr) 11854' Depth 11860'43.13 30' Drilling Ahead Gary Hammon Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg $62,300.00 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Min Max Max 0 2.9090 Min Avg pH Chlorides % Gvl Coal 1.4 32.6 Savant Alaska LLC Red Wolf 2 Badami 8.5 0.778 (ppb Eq) cP NOV DTX619M-D6 11859' 18 22-Apr-12 11860' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min 8.7 9.50 9.50 60 PV Size MBT 12.5 Cht 20 11860' 2482' Gas Summary Chromatograph (ppm) Tuff Sd 5.4 Lst 9378' 700 Silt Siltst Clyst Sst API Filt 9.40 23 Sh Ann Corr Cor Solids (lb/100ft 2) 1,100 24 hr Max YP mg/l Avg * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell 24 hr Recap: Continued to drill ahead to 11860’ MD TD. Circulated bottoms up and pulled out of the hole to surface. Laid down BHA. Picked up cementing assembly. Started to run in the hole to bottom to begin cementing the hole. The max gas was 515 units at 11756’ MD and the average background gas was 105 units. The samples before TDing the samples were black, very hard, blocky coal. There was 6 barrels of LSND lost down hole. Craig Amos / Jessica Munsell Jessica Munsell (current) (max) Background 4 Trip 113 9 27 8 10 157 41 48 Average 105 1276 710 333 51 Minimum 52 11774'8470 1236 149 368 89 98 C-5i Maximum 515 11756'47893 3631 C-2 C-3 C-4i C-4n Units* Depth C-1 54 C-5n Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) Ann Corr Cor Solids (lb/100ft 2) - 24 hr Max YP mg/l Avg Sst API Filt - 90 - Sh Sd - Lst 9378' 700 Silt Siltst Clyst 25 Tuff Gas Summary Chromatograph (ppm) Cht - 43.14 11860' 2482' 9.50 9.50 62 PV Size MBT - NOV DTX619M-D6 11859' 19 23-Apr-12 11860' Nabors 7ES $3,000.00 AK-AM-0009110182 ml/30min - Savant Alaska LLC Red Wolf 2 Badami 8.5 0.778 (ppb Eq) cP Gvl Coal Min Avg pH Chlorides % Min Max Max 0 2.9090 $65,300.00 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Test Cement Lines Gary Hammon Flow In (gpm) Current Pump & Flow Data: North Slope Daily Charges Avg Current R.O.P. (ft/hr) Depth PWD Drilling All Circ Avg Diam Max @ ft Hole Condition On Bot Hrs * 10000 units = 100% Gas In Air Logging Engineer: Report By: Jessica Munsell C-5n Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i Maximum Minimum Average Background Trip (current) (max) 24 hr Recap: Continued to run in the hole to bottom to begin cementing the hole. Cemented the bottom of the hole. Pulled out of the hole, laying down singles to surface. Ran in the hole to the shoe at 3849’ MD. No geology. No gas data. No losses seen. Craig Amos / Jessica Munsell Jessica Munsell WELL NAME:Red Wolf 2 LOCATION:Badami OPERATOR:Savant Alaska LLC AREA:North Slope MUD CO:Baroid STATE:Alaska RIG:Nabors 7ES SPUD:3-Apr-12 SPERRY JOB:AK-AM-0009110182 TD:21-Apr-12 BIT RECORD 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 Remarks 1 200 1 HDBS QHC1GRC 12.25 60 497 437 8.27 0.6934 53 6 45 475 350 2-2-WT-A-E-I-NO-BHA 2 200 rr1 HDBS QHC1GRC 12.25 497 1402 905 15.78 0.6934 57 15 120 1225 450 8-8-ER-A-8-4-ER-PR 3 300 2 HDBS EQH12DRC 12.25 1402 2585 1183 15.60 0.7394 76 13.0 130 1230 440 1-1-NO-A-0-0-NO-DTF 4 400 rr2 HDBS EQH12DRC 12.25 2585 3872 1287 19.16 0.7394 67 22 110 1800 430 3-3-WT-A-E-I-NO-TD 5 500 3 HDBS QHC1D2R 8.50 3872 3964 92 3.02 0.7455 30 13 110 1300 530 1-1-WT-A-E-I-NO-BHA 6 600 4 NOV DTX619M-D6 8.50 3964 9379 5415 49.62 0.7777 109 15 100 4000 550 6-4-WT-NT-X-I-CT-BHA 7 700 5 NOV DTX619M-D6 8.50 9379 11860 2481 43.14 0.7777 571 25 90 4150 545 6-8-CT-A-X-I-MT-TD WELL NAME:Red Wolf 2 LOCATION:Badami OPERATOR:Savant Alaska LLC AREA:North Slope MUD CO:Baroid STATE:Alaska RIG:Nabors 7ES SPUD:3-Apr-12 SPERRY JOB:AK-AM-0009110182 TD:21-Apr-12 Water- and Oil-Based Mud Record Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pf/Mf pH Pm MBT Chlorides Hardness Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%lb/gal mg/L Ca++ 3-Apr 405 9.00 350 24 58 74/133/165 12.0 106/82/73/69/59/59 2/-4.7 -/95 -0.14/0.43 9.9 0.35 32.5 1300 80 Drilling 4-Apr 1272 9.30 456 63 75 66/129/165 8.0 201/138/114/81/39/38 2/-6.8 1/92 -0.02/0.26 8.9 0.05 37.5 500 -Drilling 5-Apr 1711 9.30 315 43 56 62/106/127 8.0 142/99/87/67/42/40 2/-6.8 0.5/95.5 -0.02/0.05 9.0 0.02 35.0 400 -Drilling 6-Apr 2585 9.20 301 42 52 41/103/126 10.4 136/94/78/57/32/30 2/-6.3 0.5/93 2.50 0.02/0.34 8.6 0.02 37.5 500 40 Drilling 7-Apr 3802 9.35 306 37 48 49/97/120 8.6 122/85/72/56/36/34 2/-7.2 0.5/92 2.50 0.08/0.31 9.1 0.02 35.0 1400 80 Drilling 8-Apr 3872 9.30 205 36 33 15/45/67 8.0 105/69/54/36/14/12 2/-7.2 0.5/92 2.50 0.08/0.45 9.0 0.02 30.0 1200 40 Run casing and cement 9-Apr ------------------Cementing 10-Apr 3872 9.00 70 22 26 8/12/15 7.2 70/48/39/27/8/6 -3.7 0.5/95.5 -0.10/0.26 9.0 0.10 -1000 120 N/U BOP 11-Apr 3872 9.00 70 23 27 9/13/15 7.0 73/50/41/26/8/6 2/-3.2 0.5/96 -0.10/0.25 9.0 0.08 -900 120 Tripping 12-Apr 3887 9.00 75 27 33 10/13/16 7.4 87/60/48/34/10/8 2/-3.7 0.0/96 -0.08/0.27 10.5 0.81 6.0 1000 20 Drilling 13-Apr 4688 9.00 60 21 28 9/12/13 6.4 70/49/39/28/8/6 2/-4.2 0.5/95 -0.11/0.46 10.7 0.25 7.5 1000 40 Drilling 14-Apr 6003 9.30 77 24 33 11/15/17 6.0 81/57/46/33/10/8 2/-6.2 0.8/93 -0.08/0.32 9.3 0.02 10.0 150 80 Drilling 15-Apr 8065 9.40 63 26 26 6/11/12 5.6 78/52/41/28/8/6 2/-6.2 0.5/93 -0.18/0.61 9.7 0.28 15.0 1500 80 Drilling 16-Apr 9374 9.50 62 25 24 7/9/11 5.2 74/49/39/27/8/6 2/-8.2 0.5/91 0.50 0.18/0.62 9.6 0.21 22.5 1100 80 Drilling 17-Apr 9378 9.50 46 25 23 7/10/11 5.6 73/48/39/26/8/6 2/2 5.7 1.0/93 0.10 0.12/0.59 9.1 0.24 12.5 1100 80 Test BOP 18-Apr 9431 9.55 69 23 25 6/11/13 6.2 71/48/38/27/8/6 2/3 5.7 1.0/93 0.20 0.05/0.58 9.6 0.27 12.5 1100 80 Drilling 19-Apr 10762 9.50 62 19 25 7/11/13 5.4 63/44/36/26/8/7 2/2 7.7 1.0/91 0.20 0.09/0.58 9.1 0.15 12.5 1200 40 Drilling 20-Apr 11731 9.60 62 20 25 8/11/13 5.6 65/45/37/27/10/8 2/3 8.8 1.0/90 0.30 ;0.11/0.68 9.4 0.28 12.5 900 80 Drilling 21-Apr 11860 9.60 60 20 23 8/12/16 5.4 63/43/36/27/9/8 2/3 8.7 1.0/90 0.15 0.20/0.70 9.4 0.45 13 1100 60 Tripping 22-Apr 11860 9.50 62 ---------------Cementing Casing Record 16" Conductor @ 110' 9 5/8" Surface @ 3851' Red Wolf 2 Formation/Unit MD TVD TVDss Base Permafrost 1950 1950 Base Gravel 3330 3330 Correlation Marker 1 6210 6209 -6175 Sesimic Marker 2 6720 6719 -6685 Ugnu 6850 6849 -6815 West Sak 7195 7194 -7160 Seismic Marker 3 7785 7783 -7750 M 85 8140 8138 -8105 Hue Shale 11246 9376 -9343 HRZ 11375 11372 -11337 Top LCU Kekiktuk 11610 11607 -11572 Top Kekiktuk 11650 11647 -11612 TD 11860 11857 -11822 Formation Tops Definitive Survey Report 03 May, 2012 Savant Red Wolf Exploration Red Wolf #2 API: 50-029-23465-00 / PTD: 212-019 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Savant Red Wolf Exploration Halliburton Company Definitive Survey Report Well: Wellbore: Red Wolf 2 Red Wolf #2 Survey Calculation Method:Minimum Curvature Red Wolf #2 Actual @ 35.50ft (7-ES 29.1 KB - ICE/ 1.9' ICE - GL / 4.5 GL - MSL) Design:Red Wolf #2 Database:.AK_PRD16 MD Reference:Red Wolf #2 Actual @ 35.50ft (7-ES 29.1 KB - ICE/ 1.9' ICE - GL / 4.5 GL - MSL) North Reference: Well Red Wolf 2 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Red Wolf Alaska Zone 03 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: Red Wolf 2 ft ft 0.00 0.00 5,914,755.67 349,352.14 4.50Wellhead Elevation:ft0.00 70.174 -147.21 Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) Red Wolf #2 Model NameMagnetics BGGM2011 4/9/2012 21.67 81.10 57,692 Phase:Version: Audit Notes: Design Red Wolf #2 1.0 ACTUAL Vertical Section:Depth From (TVD) (ft) +N/-S (ft) Direction (°) +E/-W (ft) Tie On Depth:31.00 90.760.000.0031.00 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 5/3/2012 Survey Start Date MWD+SC Fixed:v2:standard dec & axial correction220.69 11,860.00 MWD+SC (Red Wolf #2)03/30/2012 MWD+SC Fixed:v2:standard dec & axial correction3,851.00 11,790.62 MWD+SC (Red Wolf #2)03/30/2012 MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 31.00 0.00 0.00 31.00 0.00 0.00-4.50 5,914,755.67 349,352.14 0.00 0.00 UNDEFINED 220.69 0.12 106.15 220.69 -0.06 0.19185.19 5,914,755.61 349,352.33 0.06 0.19 MWD+SC (1) 444.93 0.09 182.97 444.93 -0.30 0.41409.43 5,914,755.37 349,352.54 0.06 0.41 MWD+SC (1) 501.22 0.09 247.51 501.22 -0.36 0.36465.72 5,914,755.31 349,352.50 0.17 0.37 MWD+SC (1) 591.95 0.25 235.81 591.95 -0.50 0.13556.45 5,914,755.17 349,352.26 0.18 0.14 MWD+SC (1) 684.24 0.20 123.92 684.24 -0.70 0.10648.74 5,914,754.97 349,352.23 0.41 0.11 MWD+SC (1) 777.79 0.40 68.51 777.79 -0.67 0.54742.29 5,914,754.99 349,352.67 0.35 0.55 MWD+SC (1) 876.91 0.31 39.69 876.91 -0.34 1.03841.41 5,914,755.31 349,353.17 0.20 1.04 MWD+SC (1) 970.37 0.45 55.23 970.36 0.07 1.50934.86 5,914,755.71 349,353.64 0.18 1.50 MWD+SC (1) 1,065.90 0.64 63.97 1,065.89 0.51 2.281,030.39 5,914,756.14 349,354.43 0.22 2.28 MWD+SC (1) 1,159.67 0.41 108.42 1,159.66 0.64 3.071,124.16 5,914,756.25 349,355.23 0.48 3.06 MWD+SC (1) 1,255.61 0.25 107.44 1,255.59 0.47 3.601,220.09 5,914,756.07 349,355.75 0.17 3.59 MWD+SC (1) 1,349.33 0.68 146.07 1,349.31 -0.06 4.101,313.81 5,914,755.53 349,356.24 0.54 4.10 MWD+SC (1) 5/3/2012 2:27:50PM COMPASS 2003.16 Build 73 Page 2 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Savant Red Wolf Exploration Halliburton Company Definitive Survey Report Well: Wellbore: Red Wolf 2 Red Wolf #2 Survey Calculation Method:Minimum Curvature Red Wolf #2 Actual @ 35.50ft (7-ES 29.1 KB - ICE/ 1.9' ICE - GL / 4.5 GL - MSL) Design:Red Wolf #2 Database:.AK_PRD16 MD Reference:Red Wolf #2 Actual @ 35.50ft (7-ES 29.1 KB - ICE/ 1.9' ICE - GL / 4.5 GL - MSL) North Reference: Well Red Wolf 2 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 1,439.27 0.98 164.46 1,439.24 -1.24 4.611,403.74 5,914,754.34 349,356.72 0.44 4.62 MWD+SC (1) 1,538.19 0.79 153.96 1,538.15 -2.67 5.131,502.65 5,914,752.90 349,357.22 0.25 5.17 MWD+SC (1) 1,633.92 1.16 156.33 1,633.87 -4.15 5.811,598.37 5,914,751.41 349,357.87 0.39 5.87 MWD+SC (1) 1,728.23 1.44 173.03 1,728.15 -6.20 6.341,692.65 5,914,749.35 349,358.36 0.50 6.42 MWD+SC (1) 1,822.94 1.73 162.90 1,822.83 -8.75 6.901,787.33 5,914,746.79 349,358.87 0.42 7.02 MWD+SC (1) 1,916.86 1.43 169.63 1,916.71 -11.25 7.531,881.21 5,914,744.27 349,359.45 0.38 7.68 MWD+SC (1) 2,011.33 1.64 165.75 2,011.15 -13.72 8.081,975.65 5,914,741.79 349,359.94 0.25 8.26 MWD+SC (1) 2,105.68 1.73 160.28 2,105.46 -16.37 8.892,069.96 5,914,739.12 349,360.70 0.20 9.11 MWD+SC (1) 2,200.42 1.76 163.63 2,200.15 -19.11 9.782,164.65 5,914,736.37 349,361.54 0.11 10.04 MWD+SC (1) 2,294.55 1.80 168.48 2,294.24 -21.95 10.492,258.74 5,914,733.52 349,362.19 0.17 10.78 MWD+SC (1) 2,388.22 1.60 175.15 2,387.86 -24.69 10.892,352.36 5,914,730.77 349,362.54 0.30 11.22 MWD+SC (1) 2,482.04 1.54 179.84 2,481.65 -27.26 11.002,446.15 5,914,728.20 349,362.60 0.15 11.37 MWD+SC (1) 2,576.33 1.68 180.25 2,575.90 -29.91 11.002,540.40 5,914,725.55 349,362.54 0.15 11.40 MWD+SC (1) 2,670.53 1.79 175.33 2,670.06 -32.76 11.122,634.56 5,914,722.70 349,362.60 0.20 11.55 MWD+SC (1) 2,764.75 1.46 173.39 2,764.24 -35.42 11.372,728.74 5,914,720.04 349,362.81 0.36 11.84 MWD+SC (1) 2,860.14 1.49 183.63 2,859.60 -37.86 11.442,824.10 5,914,717.59 349,362.82 0.28 11.94 MWD+SC (1) 2,954.21 1.31 174.41 2,953.64 -40.15 11.462,918.14 5,914,715.30 349,362.80 0.31 12.00 MWD+SC (1) 3,048.60 1.41 148.79 3,048.01 -42.22 12.173,012.51 5,914,713.22 349,363.47 0.65 12.73 MWD+SC (1) 3,145.50 2.43 148.88 3,144.85 -45.00 13.853,109.35 5,914,710.41 349,365.09 1.05 14.45 MWD+SC (1) 3,240.86 1.53 143.87 3,240.15 -47.76 15.643,204.65 5,914,707.62 349,366.83 0.96 16.28 MWD+SC (1) 3,331.66 1.72 143.12 3,330.92 -49.83 17.183,295.42 5,914,705.52 349,368.32 0.21 17.84 MWD+SC (1) 3,428.63 1.74 123.69 3,427.84 -51.81 19.283,392.34 5,914,703.49 349,370.38 0.60 19.96 MWD+SC (1) 3,522.00 1.42 140.75 3,521.18 -53.49 21.193,485.68 5,914,701.77 349,372.26 0.61 21.90 MWD+SC (1) 3,615.80 1.48 147.06 3,614.95 -55.40 22.583,579.45 5,914,699.83 349,373.61 0.18 23.32 MWD+SC (1) 3,709.29 1.61 132.62 3,708.40 -57.31 24.203,672.90 5,914,697.90 349,375.20 0.44 24.96 MWD+SC (1) 3,894.01 1.03 176.53 3,893.08 -60.72 26.213,857.58 5,914,694.44 349,377.14 0.61 27.02 MWD+SC (2) 3,985.16 1.00 183.68 3,984.21 -62.33 26.213,948.71 5,914,692.83 349,377.10 0.14 27.04 MWD+SC (2) 4,079.58 0.79 190.18 4,078.62 -63.80 26.044,043.12 5,914,691.37 349,376.91 0.25 26.89 MWD+SC (2) 4,171.88 0.83 185.50 4,170.91 -65.09 25.874,135.41 5,914,690.08 349,376.70 0.08 26.73 MWD+SC (2) 4,267.77 0.75 183.11 4,266.79 -66.41 25.774,231.29 5,914,688.77 349,376.58 0.09 26.65 MWD+SC (2) 4,360.76 0.90 189.54 4,359.77 -67.73 25.614,324.27 5,914,687.44 349,376.40 0.19 26.51 MWD+SC (2) 4,456.16 0.96 176.00 4,455.16 -69.27 25.544,419.66 5,914,685.91 349,376.30 0.24 26.46 MWD+SC (2) 4,549.27 0.96 183.12 4,548.26 -70.83 25.564,512.76 5,914,684.35 349,376.28 0.13 26.50 MWD+SC (2) 4,644.12 0.75 192.10 4,643.10 -72.23 25.384,607.60 5,914,682.96 349,376.08 0.26 26.34 MWD+SC (2) 4,738.04 0.76 181.52 4,737.01 -73.45 25.244,701.51 5,914,681.74 349,375.91 0.15 26.21 MWD+SC (2) 4,832.50 0.96 310.10 4,831.47 -73.57 24.624,795.97 5,914,681.63 349,375.28 1.64 25.59 MWD+SC (2) 4,926.93 0.74 300.39 4,925.88 -72.75 23.484,890.38 5,914,682.47 349,374.17 0.28 24.45 MWD+SC (2) 5,021.04 0.74 304.22 5,019.99 -72.10 22.464,984.49 5,914,683.14 349,373.16 0.05 23.42 MWD+SC (2) 5,114.95 0.92 302.86 5,113.89 -71.35 21.325,078.39 5,914,683.91 349,372.04 0.19 22.27 MWD+SC (2) 5,209.01 0.83 285.28 5,207.94 -70.76 20.035,172.44 5,914,684.53 349,370.76 0.30 20.97 MWD+SC (2) 5/3/2012 2:27:50PM COMPASS 2003.16 Build 73 Page 3 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Savant Red Wolf Exploration Halliburton Company Definitive Survey Report Well: Wellbore: Red Wolf 2 Red Wolf #2 Survey Calculation Method:Minimum Curvature Red Wolf #2 Actual @ 35.50ft (7-ES 29.1 KB - ICE/ 1.9' ICE - GL / 4.5 GL - MSL) Design:Red Wolf #2 Database:.AK_PRD16 MD Reference:Red Wolf #2 Actual @ 35.50ft (7-ES 29.1 KB - ICE/ 1.9' ICE - GL / 4.5 GL - MSL) North Reference: Well Red Wolf 2 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,302.27 0.64 276.49 5,301.19 -70.52 18.865,265.69 5,914,684.79 349,369.59 0.24 19.80 MWD+SC (2) 5,396.62 0.83 281.56 5,395.53 -70.33 17.675,360.03 5,914,685.01 349,368.40 0.21 18.60 MWD+SC (2) 5,491.12 0.70 278.77 5,490.02 -70.10 16.435,454.52 5,914,685.26 349,367.17 0.14 17.36 MWD+SC (2) 5,583.84 1.11 308.11 5,582.73 -69.46 15.165,547.23 5,914,685.93 349,365.92 0.65 16.09 MWD+SC (2) 5,679.45 1.27 313.23 5,678.32 -68.16 13.665,642.82 5,914,687.25 349,364.44 0.20 14.57 MWD+SC (2) 5,773.04 1.19 305.28 5,771.89 -66.89 12.115,736.39 5,914,688.55 349,362.92 0.20 13.00 MWD+SC (2) 5,868.19 1.29 309.96 5,867.02 -65.63 10.485,831.52 5,914,689.85 349,361.32 0.15 11.36 MWD+SC (2) 5,958.51 1.20 305.92 5,957.32 -64.43 8.945,921.82 5,914,691.08 349,359.79 0.14 9.80 MWD+SC (2) 6,056.79 1.08 298.08 6,055.58 -63.39 7.296,020.08 5,914,692.16 349,358.17 0.20 8.13 MWD+SC (2) 6,150.00 1.06 296.39 6,148.77 -62.59 5.746,113.27 5,914,692.98 349,356.63 0.04 6.57 MWD+SC (2) 6,244.05 1.19 303.71 6,242.80 -61.66 4.156,207.30 5,914,693.94 349,355.06 0.21 4.97 MWD+SC (2) 6,338.46 1.30 303.71 6,337.19 -60.52 2.446,301.69 5,914,695.12 349,353.38 0.12 3.25 MWD+SC (2) 6,431.25 1.29 306.57 6,429.96 -59.32 0.736,394.46 5,914,696.36 349,351.69 0.07 1.52 MWD+SC (2) 6,525.92 1.08 302.30 6,524.61 -58.20 -0.886,489.11 5,914,697.50 349,350.10 0.24 -0.11 MWD+SC (2) 6,620.53 0.92 297.70 6,619.20 -57.38 -2.316,583.70 5,914,698.36 349,348.69 0.19 -1.54 MWD+SC (2) 6,712.21 0.78 299.14 6,710.87 -56.73 -3.506,675.37 5,914,699.03 349,347.51 0.15 -2.75 MWD+SC (2) 6,807.88 0.90 293.99 6,806.53 -56.11 -4.766,771.03 5,914,699.67 349,346.27 0.15 -4.01 MWD+SC (2) 6,901.88 0.80 309.80 6,900.52 -55.39 -5.946,865.02 5,914,700.42 349,345.10 0.27 -5.20 MWD+SC (2) 6,995.57 0.74 310.58 6,994.20 -54.57 -6.906,958.70 5,914,701.25 349,344.16 0.07 -6.17 MWD+SC (2) 7,091.25 0.82 310.08 7,089.87 -53.73 -7.897,054.37 5,914,702.11 349,343.18 0.08 -7.18 MWD+SC (2) 7,185.01 0.88 317.74 7,183.62 -52.77 -8.897,148.12 5,914,703.09 349,342.20 0.14 -8.19 MWD+SC (2) 7,279.51 0.68 307.66 7,278.11 -51.89 -9.827,242.61 5,914,703.99 349,341.29 0.26 -9.13 MWD+SC (2) 7,369.74 0.93 311.00 7,368.33 -51.08 -10.807,332.83 5,914,704.82 349,340.33 0.28 -10.12 MWD+SC (2) 7,467.40 0.97 311.23 7,465.98 -50.01 -12.027,430.48 5,914,705.91 349,339.13 0.04 -11.35 MWD+SC (2) 7,556.87 0.97 306.27 7,555.44 -49.07 -13.207,519.94 5,914,706.88 349,337.97 0.09 -12.54 MWD+SC (2) 7,656.43 1.06 314.14 7,654.98 -47.93 -14.547,619.48 5,914,708.05 349,336.65 0.17 -13.90 MWD+SC (2) 7,750.51 0.86 318.53 7,749.05 -46.79 -15.637,713.55 5,914,709.20 349,335.58 0.23 -15.01 MWD+SC (2) 7,844.09 1.09 316.28 7,842.62 -45.62 -16.717,807.12 5,914,710.39 349,334.53 0.25 -16.10 MWD+SC (2) 7,938.66 1.10 303.95 7,937.17 -44.47 -18.097,901.67 5,914,711.58 349,333.17 0.25 -17.49 MWD+SC (2) 8,032.03 0.96 307.93 8,030.52 -43.48 -19.457,995.02 5,914,712.58 349,331.83 0.17 -18.87 MWD+SC (2) 8,125.54 0.97 310.43 8,124.02 -42.49 -20.678,088.52 5,914,713.60 349,330.63 0.05 -20.10 MWD+SC (2) 8,219.79 1.12 299.81 8,218.26 -41.51 -22.078,182.76 5,914,714.61 349,329.25 0.26 -21.52 MWD+SC (2) 8,313.48 1.22 285.32 8,311.93 -40.80 -23.838,276.43 5,914,715.36 349,327.50 0.33 -23.28 MWD+SC (2) 8,407.63 1.23 279.10 8,406.05 -40.37 -25.798,370.55 5,914,715.82 349,325.55 0.14 -25.25 MWD+SC (2) 8,502.56 1.27 273.96 8,500.96 -40.14 -27.858,465.46 5,914,716.10 349,323.50 0.13 -27.31 MWD+SC (2) 8,594.76 1.52 275.02 8,593.13 -39.96 -30.098,557.63 5,914,716.32 349,321.27 0.27 -29.55 MWD+SC (2) 8,685.23 1.73 276.16 8,683.57 -39.71 -32.648,648.07 5,914,716.62 349,318.72 0.23 -32.11 MWD+SC (2) 8,779.71 1.58 284.33 8,778.01 -39.23 -35.328,742.51 5,914,717.15 349,316.05 0.30 -34.79 MWD+SC (2) 8,875.83 1.43 280.40 8,874.10 -38.69 -37.788,838.60 5,914,717.74 349,313.60 0.19 -37.27 MWD+SC (2) 8,973.06 1.35 278.18 8,971.30 -38.31 -40.118,935.80 5,914,718.17 349,311.28 0.10 -39.60 MWD+SC (2) 5/3/2012 2:27:50PM COMPASS 2003.16 Build 73 Page 4 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: Savant Red Wolf Exploration Halliburton Company Definitive Survey Report Well: Wellbore: Red Wolf 2 Red Wolf #2 Survey Calculation Method:Minimum Curvature Red Wolf #2 Actual @ 35.50ft (7-ES 29.1 KB - ICE/ 1.9' ICE - GL / 4.5 GL - MSL) Design:Red Wolf #2 Database:.AK_PRD16 MD Reference:Red Wolf #2 Actual @ 35.50ft (7-ES 29.1 KB - ICE/ 1.9' ICE - GL / 4.5 GL - MSL) North Reference: Well Red Wolf 2 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 9,064.13 1.38 284.60 9,062.34 -37.88 -42.239,026.84 5,914,718.64 349,309.16 0.17 -41.73 MWD+SC (2) 9,160.95 1.71 295.11 9,159.13 -36.97 -44.679,123.63 5,914,719.60 349,306.75 0.45 -44.17 MWD+SC (2) 9,255.18 1.79 293.34 9,253.31 -35.79 -47.299,217.81 5,914,720.83 349,304.15 0.10 -46.81 MWD+SC (2) 9,347.08 1.96 283.85 9,345.16 -34.85 -50.149,309.66 5,914,721.83 349,301.32 0.38 -49.67 MWD+SC (2) 9,396.49 1.78 286.27 9,394.55 -34.43 -51.709,359.05 5,914,722.28 349,299.77 0.40 -51.23 MWD+SC (2) 9,490.19 1.89 296.31 9,488.20 -33.34 -54.489,452.70 5,914,723.43 349,297.01 0.36 -54.03 MWD+SC (2) 9,583.67 1.79 311.67 9,581.63 -31.68 -56.959,546.13 5,914,725.13 349,294.58 0.54 -56.52 MWD+SC (2) 9,677.88 1.56 317.60 9,675.80 -29.76 -58.919,640.30 5,914,727.09 349,292.65 0.31 -58.51 MWD+SC (2) 9,772.23 1.39 310.97 9,770.12 -28.06 -60.649,734.62 5,914,728.83 349,290.95 0.26 -60.26 MWD+SC (2) 9,865.90 1.62 309.49 9,863.76 -26.47 -62.529,828.26 5,914,730.45 349,289.11 0.25 -62.17 MWD+SC (2) 9,959.71 1.57 316.84 9,957.53 -24.69 -64.439,922.03 5,914,732.27 349,287.24 0.22 -64.09 MWD+SC (2) 10,053.83 1.77 316.63 10,051.61 -22.69 -66.3110,016.11 5,914,734.30 349,285.40 0.21 -66.00 MWD+SC (2) 10,148.52 1.96 298.32 10,146.25 -20.86 -68.7410,110.75 5,914,736.18 349,283.01 0.66 -68.45 MWD+SC (2) 10,241.70 1.86 279.41 10,239.38 -19.86 -71.6310,203.88 5,914,737.24 349,280.13 0.68 -71.36 MWD+SC (2) 10,337.17 2.10 276.19 10,334.79 -19.42 -74.9010,299.29 5,914,737.75 349,276.88 0.28 -74.63 MWD+SC (2) 10,429.66 2.09 266.52 10,427.22 -19.34 -78.2710,391.72 5,914,737.90 349,273.51 0.38 -78.00 MWD+SC (2) 10,521.56 1.76 264.36 10,519.07 -19.58 -81.3410,483.57 5,914,737.72 349,270.43 0.37 -81.07 MWD+SC (2) 10,614.75 1.49 266.51 10,612.22 -19.79 -83.9810,576.72 5,914,737.56 349,267.79 0.30 -83.71 MWD+SC (2) 10,709.18 1.05 252.31 10,706.63 -20.13 -86.0310,671.13 5,914,737.26 349,265.74 0.57 -85.75 MWD+SC (2) 10,806.49 0.98 231.26 10,803.92 -20.92 -87.5210,768.42 5,914,736.50 349,264.22 0.39 -87.24 MWD+SC (2) 10,901.00 0.57 221.52 10,898.43 -21.78 -88.4710,862.93 5,914,735.66 349,263.26 0.45 -88.17 MWD+SC (2) 10,994.71 0.20 141.64 10,992.13 -22.26 -88.6710,956.63 5,914,735.19 349,263.05 0.61 -88.37 MWD+SC (2) 11,088.97 0.44 225.29 11,086.39 -22.64 -88.8311,050.89 5,914,734.81 349,262.88 0.49 -88.52 MWD+SC (2) 11,182.16 0.66 205.32 11,179.58 -23.38 -89.3111,144.08 5,914,734.08 349,262.39 0.31 -88.99 MWD+SC (2) 11,274.77 0.83 209.48 11,272.18 -24.44 -89.8711,236.68 5,914,733.02 349,261.81 0.19 -89.54 MWD+SC (2) 11,368.85 0.25 221.93 11,366.26 -25.19 -90.3411,330.76 5,914,732.29 349,261.32 0.63 -90.00 MWD+SC (2) 11,465.18 0.25 266.13 11,462.59 -25.36 -90.6911,427.09 5,914,732.12 349,260.97 0.20 -90.35 MWD+SC (2) 11,554.26 0.26 30.73 11,551.66 -25.20 -90.7811,516.16 5,914,732.29 349,260.88 0.51 -90.44 MWD+SC (2) 11,650.79 0.47 13.06 11,648.19 -24.62 -90.5811,612.69 5,914,732.86 349,261.09 0.24 -90.25 MWD+SC (2) 11,745.74 0.97 55.03 11,743.14 -23.78 -89.8411,707.64 5,914,733.68 349,261.85 0.73 -89.51 MWD+SC (2) 11,790.12 1.11 48.93 11,787.51 -23.29 -89.2011,752.01 5,914,734.17 349,262.50 0.40 -88.89 MWD+SC (2) 11,860.00 1.11 48.93 11,857.38 -22.40 -88.1811,821.88 5,914,735.03 349,263.53 0.00 -87.88 PROJECTED to TD 5/3/2012 2:27:50PM COMPASS 2003.16 Build 73 Page 5 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 0 4 8 12 16 20 24 28 32 Me a s u r e d D e p t h Rig Days Prognosed Actual Red Wolf 2 Days vs. Depth Sperry SDL Released 24 April 2012 01 Apr il 2012 Sperry SDL Arrive on Location Set 9 5/8" Casing 3849' MD, 3848' TVD 09 April 2012 Commence 12.25" Surface Hole Section On Bot: 21:00 03 April 2012 POOH due to MWD tool failure 2585' MD 06 Apr 2012 TD 12.25" Surface Hole Section 3872' MD, 3871' TVD Off Bot: 00:40 08 April 2012 TD 8 1/2" Hole Section Off Bot: 07:10 AM 11860' MD 11857' TVD 21 April 2012 POOH for bit change 1402' MD 05 April 2012. Resume Drilling 8 1/2" Hole Section On Bot: : 22:20 18 April 2012 Commence 8.5" Intermediate Hole Section On Bot: 21:50 12 April 2012 Wiper Trip to Shoe 6005' MD 15 Apr 2012 Pump down - POOH for MWD tool change 9379' MD 17 Apr 2012 Surface Data Logging After Action Review Employee Name: Craig Amos Date: 04/21/12 Well: Red Wolf 2 Hole Section: Production What went as, or better than, planned: Using two pieces of gas equipment, on site and having 2 sets of gas analysis components running parallel to each other prevented any LTI caused by malfunctioning equipment. The wits system worked very well with only minor interruptions not caused by SDL, the exchange of data back and forth was consistently good. Difficulties experienced: The use of wireless connections throughout the camp made connecting and sending data more difficult with computers dropping out regularly and require constant vigilance to check they have not dropped out. Power regulator problems from fluctuations in power supply provided by the rig caused minor issues at the start of the section. Recommendations: Power regulation was cured by turning off some equipment and adjusting the power regulation in the back of the battery back up systems. Have better power regulation from the rig to the unit would help cure any issues. Running cables to company mans unit would help cure the wireless communication issues, although it has been noted the issues were with the wireless service provider. Innovations and/or cost savings: Using two pieces of gas equipment, both the CVE and Legacy systems, prevented any down time if the CVE became blocked or flow was to low to be registered in the Legacy gas system.
