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Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 4.: 71 I_ - I Go Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed 7RE AN: OVERSIZED: NOTES: C for Items: ❑ Maps: 1 rayscale Items: ❑ Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: EMS-- Date: i a /s/ niP Project Proofing BY: C Maria) Date: Z latel/L Is! Ade 1 Scanning Preparation I x 30 = 3 0 + ' , = TOTAL PAGES 30 (Count does not include cover sheet) MID BY: - Date: 7/01/ , /s/ fld aProduction Scanning Stage 1 Page Count from Scanned File: 37 (Count does include cover eet) Page Count Matches Number in Scanning Pre aration: YES NO BY: (Maria'S) Date: �isi al. /s/ yyp Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 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 o I a o c O N 9 Z Z Z N C N o Z c >- >- >- ,=i N c rs UN _ }aNil 2 ai 9 a a >, o in 0 m c 2 O aa O _r L .c p EC U a`> U a m Q Tau) N a) c co 0 co o 2 0 U o O 2 XI c UJ ° ° a)� w U) a E a z z i a H E E rn ° E >- >- >- co � U O m �/ U (1)IL y E 0 iE O w m U 171.ma @ m co W O A m N N Z CL us Qc_ CO LL E _ N CO W N co m 0 °Z d 0. co Z u U) a, Q o a 0 o co p o c m I �o N D E 5 J a m = 0 c O ) o :: c U U a. 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N � C U 2 ._o cC) .a O E E d a a 2 ci __, , 1 7 1 , , -crr \ ir IT-, , - ' s E Li, , W Aii-A, LA SEAN PARNELL,GOVERNOR LE ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION / ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Michael Cook Engineer North Slope Borough 1689 Okpik Street Barrow, AK 99723 Re: Walakpa Field, Walakpa Gas Pool, Walakpa #14 North Slope Borough Permit No: 211-160 Surface Location: 1744' FSL, 1636' FEL, SEC. 23, T2ON, R2OW, UM Bottomhole Location: 1360' FSL, 2373' FWL, SEC. 24, T2ON, R2OW, UM Dear Mr. Cook: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the 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, Daniel T. Seamount, Jr. Chair DATED this22 day of December, 2011. cc: Department of Fish 85 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ALA._ .OIL AND GAS CONSERVATION COMM{, iN PERMIT TO DRILL 20 AAC 25.005 1a.Type of Work: 1b.Current Well Class: Exploratory 0 Development Oil 0 1c.Specify if well is proposed for: Drill O✓ Redrill O Stratigraphic Test 0 Service 0 Development Gas Q Coalbed Methane 0 Cas Hydrates 0 Re-entry 0 Multiple Zone 0 Single Zone 0 Shale Gas 0 2.Operator Name: 5. Bond: Blanket Q Single Well 0 11 Well Name and Number: North Slope Borough-Barrow,Alaska Bond No. CD 17430 Walakpa#14 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): Dept.Public Works, 1689 Okpik St.,Barrow,AK 99723 MD: 5371 ` TVD: 2323. WALAKPA f a-'3 S ? 4a. Location of Well(Governmental Section): 7.Property Designation: Surface: 1744'FSL, 1636'FEL,UM Section 23,T 20 N,R 20 W . WALAKPA ,, , f Top of Productive Horizon: 8.Land Use Permit: NSB Development 13.Approximate Spud Date: 1544'FSL,885'FWL,UM Section 24,T 20 N,R 20 W UIC Private Land Permit No.10-252 9-Mar-12 Total Depth: 9.Acres in Property: 14.Distance to Nearest 1360'FSL,2373'FWL,UM Section 24,T 20 N,R 20 W 21,120 Property: 17,160 4b.Location of Well(State Base Plane Coordinates): 10.KB Elevation 15.Distance to Nearest Well Surface: x- 612912 - y- 6241863 • Zone- 6(NAD 27) (Height above GL): 21.5 feet Within Pool: 14 ft.-Walakpa#13 16.Deviated wells: Kickoff depth: 250 feet 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 90 degrees Downhole: sig /co Y_,/_ Surface: 780 psig 18.Casing Program: Specifications Top(rkb) - Setting Depth�- Bottom(rkb) Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 26 16" 84# L80 Weld 80 21 21 101 101 Single Stage:265 sxs. 12 1/4" 9 5/8" 40# L80 BTC-M 1154 20 20 1174 1153 Lead:92 sxs,Tail:285 sxs 8 1/2" 7" 26# L80 BTC-M 3823 19 19 3842 2278 Single Stage:114 sxs. 6 1/8" 4 1/2" 12.6# L80 BTC 1679 3692 2242 5371 2323 production-slotted liner 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface RECEIVE Intermediate Production DEC 1 4 2011 Liner Ale k Perforation Depth MD(ft): Perforation Depth TVD(ft): Alaska-Un Goo Cons, Co 15fl 20. Attachments: Filing Fee O✓ BOP Sketch Q Drilling Program 0 Time v.Depth Plot Q Shallow Hazard Analysis Q Property Plat O✓ Diverter Sketch Q Seabed Report El Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact ts Printed Name \i'L-6:511‘.1, Title (= nt' r Signature �/1 Phone I qDa) L<T'53172)-3 Date 1 Z , 12. , IL Commission Use Only Permit to Drill / /j API Number: ^- t/ rT Permit Approval See cover letter for other Number: / 50-02.0 I LC bate: 174�_ _I f I requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane, as hydrates,or gas contained in shat Other: 40 3 500 p$';, sol 1 GS Samples req'd: Yes No Mud log req'd: Yeo Nc011if ^� (r /_ ,.-7–e--;71( )I-12S measures: YesO No[v Directional svy req'd: Y12" CL i s do t. Ail 114 1Wl l ----. f .. ,,,m1,51c ,,,m1,51 , 6v' 9 6z� ari.",-55.;eSe-L to 7 i go p APPROVED BY THE COMMISSION DATE: `,�� ,COMMISSIONER • RIGINAL /� '? `r " Form 10 401 Revised 12/2005 Sub it in Duplicate �,1� �r/ 1� PRA 3601 C Street Suite 1424 Anchorage, AK 99503 907-272-1232(voice) 907-272-1344(fax) info@petroak.corn Pct�olu/M:ucl Qua•�cu Ats+k� Memorandum RIV0 STATE OF ALASKA ®E 'C 4 2011 OIL & GAS CONSERVATION COMMISSION �R�katiN 333 W. 7`h Ave. Suite 100 AnNIO P �� ���� Anchorage, AK 99501 To: Guy Schwartz-Petroleum Engineer CC: Joe Ramirez- Project Administrator/ Barrow Gas Fields Well Drilling Program From: Mike Cook- PetroTechnical Resources Alaska Date: 12/12/2011 Re: Permit to Drill : Walakpa#14 Dear Sir, Petrotechnical Resources Alaska (PRA), providing well design engineering support for the North Slope Borough's - Barrow Gas Fields Well Drilling Program submits for your review : • Permit to Drill (Form 10-401), Well : Walakpa#14 The Walakpa #14 Permit to Drill application provides well construction design information for the Walakpa gas field wells drilling program, where in a total, four horizontal gas development wells will be drilled and completed beginning in January 2012 and concluding in April 2012. egards,1 (,%."t -. ./r.D.1. )--aje--- Michael R. Cook ( ,\/ Petrotechnical Resources Alaska Office : (907) 677-5103 Cell : (907) 444-8822 Email : mcook@petroak.com DATE: 4-26-11 SCALE: 1" = 1 On SHEET: 1 OF 1 �111du PROPOSED 11111 REV DATE DESCRIPTION BARROW Amin* 1 11-12-10 WELL COORDINATES SIGNIFICANT FIGURES sulmir,.- _ WELLS 2 4-22-11 WELL COORDINATES DGPS �1P° i 111 NOTES: is►� rl�rr7�, ! �� •''F' 1. COORDINATES SHOWN HEREON BASED UPON DIFFERENTIALLY ��'��+�■IRi�I� ■� ■1/'-Jr -J V ■ CORRECTED GPS OBSERVATIONS. AWA 1 1n L•r �`�U ''+ ■�■;' /errs IUellivri t•Plt ilte■fit C1 rl;// 1t1M�t• v'r�•U I,Jr�� 2. AS-STAKED SURVEY CONDUCTED AUG.30,2010&APR.22,2011. a eArlj,.AlliM� ll 1 7■^� '1 I Haar r/�Ya IL 1 irin, ism lr 3. ALL DISTANCES ARE IN U.S.SURVEY FEET. t it11 NT%Q I 14:J1, '11 _ _el i, f OWN4. PROTRACTED SECTION LINES SHOWN HEREON ARE r,, l . . 6�'t�� 1 ■_ taa� �� ■� J�F1 APPROXIMATE AND FOR REFERENCE ONLY. VICINITY MAP-NOT TO SCALE AS-STAKED "WALAKPA LEGEND PROPOSED S "WALAKPA 13"WELL LOCATED WITHIN 13/14" DRILL PAD A RPTOEWDL WELL SECTION 230 W.,U.M., 0 0 NAD 27,ZONE 6 WELL RP DISTANCE TABLE WAL-14 RP2 WAL-13 RP2 WAL-13 WAL-14 LAT:71'04'10.5640"N N .-LONG:157°02'59.6924"W RP1 202.33' 201.05' N=6.241.862.91 0 RP2 310.98' 311.21' F G E=612,898.83 RP1 C.) 0 NI L39"1 i. ., j,;LI• N u'''i NAD 83,ZONE 6* s m LAT:71°04'09.0139"N PO. 3 3 LONG:157°03'12.0863"W 0 o N=6,241,550.30 4�� 4s11: ` N N E=1,752,903.91 cc c p' PROPOSED z z PROPOSED s° MIL ` /PAD t-, 0N 0 "WALAKPA 14"WELL N r r LOCATED WITHIN IRIfi T.20 N.,R.20 W.,U.M., y.p eta 1643*'---N---.-- SECTION 23 —7.0' WAD 27,ZONE 6 0 0 SCALESN FEET 100 PROPOSED i PROPOSED LAT:O71157*0259.2 N ,/ LONG:157°02'59.2655'W N=6,241,863.86 ' "WALAKPA 13" "WALAKPA 14" i. E=612,912.91 WELL WELL ,,' NAD 83,ZONE 6* • '" LAT:71°04'09.0204"N cn a •' LONG:157°03'11.6594"W w • N=6.241.551.19 c E=1,752,917.99 caw d •CONVERTED BY NAD CON N I 0 o ;510' C' °1 l [' . or 3 F �\ NT 20 N, R 20 W, UM SECTION 23 L���i O• • �! ts% k 0 vWj T 20 N. R 20 W. UM SECTION 26 /�CO.* • ,`,••.-r �T SURVEYORS CERTIFICATE C. % *.' 49 TH )\ '•*Ti .p I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE 4-2?-I I STATE OF ALASKA AND THAT THIS AS-STAKED EXHIBIT REPRESENTS A SURVEY MADE BY ME OR UNDER MY I 0 DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF APRIL 22,2011. / '.KENNETH J.PINARD 11�.• No.11545 /� o �_� PETROTECHNICAL � F ,<<LO �`��P�afEssroNa��a�°�� 1 RESOURCES ,.� °,nenr"•vz.ueaw,er°u.".wn.w„",. �� Jan Ukpeagvik InupIat Corporation Company \\"1-` ALASKA o DRAWN BY:LHH I CHECKED BY: KJP 1 W.O. Na: 2009-214-A 4,,77..,--4:14., Walakpa#14 : Horizontal Engineer: MA'oak Field:CL=31.7 ft.above Sea Level Gas Development Weill Rig: Kuukpik#5 RKB elee.:21.5 ft(pad level) OII FORM DEPTH-Irkld HOLE SIZE CASING SPECS MUD INFO CEM INFO INFO DIWLWD SIWD LOGS MD ' TVD NONE NONE Permafrost 100 100I_.- -:. 26" 16 in,84 IMO Om Well Head:Vetco Gray, Jwelded MB230,2.1/16"5M KOP:incl.-0deg. 250 250 Spud Mud DLS:2.00 deg/100 SRO-GYRO 0 SO() Lead Cement-"L" BOC:500 fl. Density:10.7 ppg MWD/GR/RES Cement Excess:50% Tail Cement-"C" t TOC:500 ft. Freeze Protection:Annuli Density:15.6 ppg 7"x 9-5/8" Base of Cement Excess:50% w/diesel Permafrost: 962 ' 900 us Surface Casing 9-5/8"40 lbs/ft L80 BTC-M humid Yidd:5,750 psi C011apsc:3,I90 psi Casing Test:2500 psi EOB:incl.=22.0 deg. Casing Point 1174 1153 12-1/4" KOP:incl._•22.0 deg. 1204 1181 PHPA:LSND Leak Off Test(1.0T1 Production Tubing 2-7/8"6.5 lbs/ft MWD/GR/RES L80 EUE humin Yidd:10.570 psi Collapse:11,170116i ROB: incl.:70.6.deg. 190(1 1640 DLS:7 deg./100 Intermediate Casing s a o 7"26 lbs/fl L80 BTC-M Intend!Yield:7.240 psi Collapse:6,1100 psi Tail Cement Casing Test:2500 psi KOP:incl.=70.6 3626 2221 - - Type:Premium Cement L iHr Density:15.6 ppg Cement Excess:30% Liner Hanger/Packer EOB: incl.:80.00 Casing Point 3842 - 2278 /TB.Est:BHI Model: deg. DLS:4 I op:Walakpa I SLZXP Liner Lap:150 It degJ100 Sand 3869 2283 8-1/2" KOP/Build:80.0 deg. 3887 2326 I I BARADRILL- FIT:13.00 ppg EMW EOB:89.9 deg. 4137 2347 I DIS:4 deg/100 I MWD/GR/R13S II II II II Production Liner- I I Slotted 4-1/2"12.6 lbs/ft 1.80 BTC I II TD-Walakpa 5371 2323 Aiwa. 6-1/8" Target (Toe) Date Rev by Comments 4/02011 M.Cook Well Planning Preparation 12/11/2011 M.Cook Well Planning Preparation a) a E m H L11 To U Q IIIE C 0 E 0 a i • U i:t15 C v L O.a V Ln ' 0 A c CL 0 v, s � � R C . o Lnr; CI 0 CU ► I 0 0 lit 0 0 0 0 0 0`z' L11 k. CI a a ;.+ t 2 0 Rig Floor 21" Bottom of Rota Table 12' 14" ". .n. ..r :'.0 72" 50 5" 21 1/4"2 M Annular F-- ;4 40 L 11" Diverter opening center line 72" —1_ Diverter Line Opening Diverter Spool — 3' _ t 36"Sub Base Skid 1 92" 66" I 96" 1 24"skid base 8'long Spacer Spool J 6_Rig Mat Ground/Pad Level 1 21 1/4"Starting F ange 9'OD Cellar 6'Deep KUUKPIK DRILLING RIG 5 ✓ 21 1/4"Divener System With 8'Spacer Spool 6/11/2011 Rig Floor 21" Bottom of Rotary Table 8ottom.0LROtateas 14" y Bm 49" fipple I 49' 11"Annular 175" r I O 34' 11"Double Gate o v:i 1 ui O N N L J 23" � j 11"Mud Cross J _, + r 20" 11'Single Gale 11"5,000 Flange 6" -No- ...,:44.2:,:s.==j � 1 !fic 36"Sub Base Skid %is.";;; fieri 8 long Spacer Spool Sub Skid !'� " Level �.AM 24"Skid Base ` y' !+1i; iiPtit 6"Rig Mal .:1e.,;„,,,...4,1 l ..�i}Y'i.,1 I , Ground/Pad Level 11"5 M Top of 11"5M flange©Ground Level ..tea. 9 5/8"Casing 9'OD Cellar 6'Deep 11"BOP Stack Kuukpik Drilling Rig 5 Choke Manifold Valves 2 " 3" To Shaker 3" Panic To Gasbuster 3 1/8"L.I El 2 1/16„O `SEEn O 2 1/16„ LI T . .E-?_ =. Q 1 j n. �O 2 1/1�� 2 1/16” io &I 'k- --, 31/`E Q ,� 1N 1 Lk_p_ _p J \ i 21/16" 0 21/16" t Manual Choke 1 Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE =2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold Drawn By: L Ross Date: 8/1/04 ., fv<4 'wok : . - , ., , A ir . . , , - ..., ,, .„,,, , ro ,,,. 4.-,,,,,0 :_. , ,,, # . , ,, .. . „ F ,iii : p 1 , , , = _ _. 16+ t;5 p2 W .• 17 - 1 + X151 � _ 4,4 ...; lee •kuuk k Drf6I RI 6 Choke Manifold P1 Mama A d OPE$��O PltA �a"'rr+aurcJ Iu1M '� pduox 44t Ieasog4a4&AA Walakpa #14 Horizontal Development Well Walakpa Gas Field Barrow Gas Fields Well Drilling Program CIPM : 68-090 Rig : Kuukpik #5 AFE Number: AFE Amount: Days: 23 10-0012 PRA Drilling Supervisor PRA Principle in Charge Prepared by: Reviewed by: PRA HSE Manager PRA Petroleum Engineer Manager Reviewed by: Reviewed by: Distribution: 19 Copies, 1 original Kuupik #5 8 copies Matt Dunn 1 copy Joe Ramirez 1 copy Jack Laasch 1 copy Tom Walsh 1 copy Mike Cook 1 copy Pete Stokes 1 copy Chantal Walsh 1 copy Steve Chronic 1 copy John Amundsen 1 copy HSE Field 1 copy Matt Coullahan 1 copy 1 DAF 4-21--11 SCALL' _ 100 SHEET: I OF , I .- PROPOSED 1 11-12—I0 WELL COORDINATE'S SIGNIFICANT FICW-t`. '4.-0.- WELLS 2 4-22-11 WEL'.. COORDINATES DGPS NOTES: n I---1;L • t `j + 1- COORDINATES SHOWN HEREON BASED UPON DIFFERENTIALLY r.�;'j I,' ,-.L.--,.."--•� _ - � j CORRECTED GPS OBSERVATIONS 111 13 .4 Or 4 . �1 + .'t �1!-{`'111 ,Pr2 AS-STAKED SURVEY CONDUCTED AUG.30,2010 d APR.22,2011. I`� 1 rI�i1A1 � "1 3 ALL DISTANCES ARE IN U.S.SURVEY FEET. ` Li ti 1 . I, 4 PROTRACTED SECTION LINES SHOWN HEREON ARE S,'y L i, �� , -t �y' t,,,-� 'np APPROXIMATE AND FOR REFERENCE ONLY VICINITY MAP-NOT TO SCALE L AS-STAKED "WALAKPA LEGEND PROOSED "WAPLAKPA13"WELL LSE PROPOSED WELT. T.13114 N R 20 W U.M„ DRILL PAD RP TO WELL SECTION 23 WELL RP DISTANCE TARI Fv I NAD 27,TONE B WAL 14 NP2 NlAL•19 RP: I WAL•13 WAL-14 LAT 71•04'1Q5640.14 r. +., 44,e o 1Y02':+H.6974"W RP1 202.33' 201.06' 6.74t Sai 97 RP2 310.98' 311.21' RP 6 A E.61,733843_____ ___ __ ' NAD 63,ZONF 6' __ _.—_.._-.. i ! _-_. LAT 71'000 OW N yri 1t is L ONO 167'03'120993-W g g N.6,241,540 30 E.1.752.90391 IN a v -` PROPOSED A` Z PROPOSED st- ::., ! pA0 ; 2 g "WALAKPA 14'WELL tNI: 1 If I OCATEO WRt1M1 � / T.20N-,R.20W.,U1.1 .0"",r. ,.+ `; 1 1... —76431.16431 ..,.—T,t;._ «• SECTION 23 ., A* NAO 21,ZONE A C ea 1m �.. i L A1:71604'30SM'N ;® PROPOSED PROPOSED I.CJPKI 1671N'6A 7E45'1.1 11a824/1193AS ";AIALAKPA 13" 'WALAKPA 14' I E+612,9'26*. WELL WELL NAD 113,ZONE 6' LAT'711341000204'N O LOW 157'05116644•W T' ,.i N-6.241.55119 Z E"1,752417.96 -03+ 1 I 'COWER TEO 13Y 4141'CON OA !.v_ ____. a t) A1 20 N, R 20 13, UM SECTION 23 , Q A�'QS�� j T 20 N. R 20 A. UN SECTION lir ��P I li8URVEYORS CERTIFICATE fr4f*• Qg TH *.tY Tk�j c + ITA14EfHY CFRIP V 1 H)11 AU PNCN'CR.Y HLOISLt41RU AI L/ ENSW 10 PRACTICE LAND SONVEYNLE W THE i {/ 4_27-11 / ry STATE OF MAW ANO'OAT DNS ASS-STAKFD EAHIBT HE VRESENT9 A$CINVIW 914110 ON I e OR UHLER 4YY '�Y��•-��"'�G���� I1r 091CC1 SLIY'E11MY31ON AM)THAT ALL 1IIMEI4SIC905 AM)0THE44 OVALS ARE CC$REz:I AS OF MR*2Y,/grt1 KENNETH J.PINARD : / ti �`':, No 11545 '• ' PETROTECHNICAL tit �..f { +i,,$2,''• •• 'g'„- ivy ' RESOURCES _ kESSIONALIR�► ...... hit 1 is l44C�LiN Ia4�.Wl I:Y}Yil[tt 1:p.4"'4 \\\\`1`` ALASKA { PAWN t?.,..i••' 1 L-n:h 11y x;r 105,0 v. ,r„. .'4 A 2 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la.Type of Work lb.Current Well Class: Exploratory 0 Development Oil 0 1c.Specify If w ells proposed for: Dill o Redrii D Stratigraphic Test El Service 0 Development Gas Q Coalbed Methane 0 Gas Hydrates 0 Re-entry 0 Multiple Zone❑ Single Zone 0 Shale Gas 0 2.Operator Name: 5. Bond: Blanket Q Single Well 0 11.Well Name and Number: North Slope Borough-Barrow,Alaska Bond No. CD 17430 Walakpa#14 3.Address: 6.Proposed Depth: 12.Field/Fbol(s): Dept.Public Works,1689 Okpik St.,Barrow,AK 99723 M? 5371 TVD: 2323 WALAKPA 4a. Location of Well(Governmental Section): 7.Property Designation: Surface: 1744'FSL,1636'FEL,UM Section 23,T 20 N,R20 W WALAKPA Top of Productive Horizon: 8.Land Use Permit: NSB Development 13.Approximate Spud Date: 1544'FSL,885'FWL,UM Section 24,T 20 N,R 20 W UIC Private Land Permit No.10-252 9-Mar-12 Total Depth: 9.Acres in Pfioperty: 14.Distance to Nearest 1360'FSL,2373'FWL,UM Section 24,T20 N,R 20 W 21,120 Property: 17,160 4b.Location of Well(State Base Rene Coordinates): 10.KB Bevation 15.Distance to Nearest Well Surface: x 612912 y- 6241863 Zone- 6(NAD 27)(Height above GL): 21.5 feet Within Fool: 14 ft.-Walakpa#13 16.Deviated w ells: Kickoff depth: 250 feet 17.!Auburn Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Dow nhole: 962 psig Surface: 780 psig 18.Casing Program Specifications Top(rkb) - Setting Depth - Bottom(rkb) Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (incl a stage data) 26 16" 84# L80 Weld 80 21 21 101 101 Sint •,<:265 sxs. 121/4" 9 5/8" 40# L80 BTC-M 1154 20 20 1174 1153 ead:92 sxs,Tail:285 sxs 8 1/2" 7" 26# L80 BTC-M 3823 19 19 3842 �: Single Stage:114 sxs. 6 1/8" 4 1/2" 12.6# L80 BTC 1679 3692 2242 5371 '2323 production-slotted liner 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Rugs(measured): Effect.Depth , II(ft): Effect.Depth TVD(ft): Junk(measured): / Casing Length Size C t Volume MD TVD Conductor/Structural f� Surface (}) Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Filing Fee El BOP Sketch © Drilling Program 0 Time v.Depth Rot 0 Shallow Hazard Analysis Q Property Rat 0 Diverter Sketch r,,' Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Con-mission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name Title Signature Phone Date Commission Use Only Pernit to Dill AR Number: Permit Approval See cover letter for other Minter: 50- Date: requirements. Conditions of apilfrtreal's checked,w ell my not be used to explore for,test,or produce coated methane,gas hydrates,or gas contained in shale° Other: Sarrples req'd: Yes D No 0 Mud log req'd: Yeses No0 H2S measures: Yes 0 No 0 Directional svy req'd: Yeo NJ APPROVED BY THE COMMISSION DATE ,COMMISSIONER 3 „ ,::;,,,:...„.. . PM .. . i„,,,, itit a.13 _ P�w.rM/IL,4 Walakpa#14:Horizontal Gas Engineer: M.Cank held:CL=31.7 ft.above Sea Level Development WeW Rig: Kuukpik#5 RKB elev.:213 R(pdklel) OR FORM DW'Ul-(rkb) HO IE SIZE CASING SPECS MUD INTO CHM INFO 1810 DIR/LWD MWD LOGS MD TVD Al NONE NONE Pemnfrosl 100 100 26„ 16 m.84 dfl LOUL8U Well Fkad:Vetco bay, o ' Welded M131230,2-1/16"5M KOP:incl.=0 deg, 250 250 Spud Mrd DIS:2.00 deg/100 >l it SRO-GYRO 0 500 ', lead Cement-"l? BOC:50011. Density:10.7 ppg Cement MWD/CR/RES E ess:50 Tail Cement-"C" 'FOC:500 ft. Freeze Protection:Annuli Tx of Density:15.6ppg Cement 9-518" Base of Excess:51P4 w/diesel Penenfost: 962 900 ss Surface Caving 9-5/8”40 lbs/ti L80 BTC-M hisses!Yield:5,750 psi Collapse:1,090 psi Casing Tes1:2500 pi KM:incL=22.0 deg. Casing Point 1174 1153 12-1/4" KO?:incl.=MAL deg. 1201 1181 PUPA:ISND Leak Oiliest(WI) Production Tubing 2-7/8"6.5 lbs/ft MWD/GR/RES 1201 WE Menial Yield:10,570 psi Collapse:11,170 psi 11)B:incl.:70.6.deg. 1900 1648 DLS:7 deg/100 Inleravediale Cav ins 7"26 lbs/ft L80 BTC-M Internal Yield:7,240 psi _ Collapse:6,000 psi Tail Conical Caving Teat:2500 pi MP:incl=70.6 3626 M21 Type:PreniumCement Density:15.6 ppg Cement Excess:30% Liner Ilanger/Packer Casing Point 3842 2278 /TB.Ext:8111 Model:SLZXP BOB:incl.:80.00 deg. lop:Walakpa UIS:4 deg/100 Sand 3869 '2283 Liner lap:150 ft. s-1n" KOP/Build 80.0 deg. 3887 2326 BARADRBL-N/KCL FH':13.00ppg I/MW WB:89.9 deg. 4137 2347 DIS:4 deg/100 MWD/CR/RES I � Prpknetioa liner- I I Slatted 4-1/2'12.61bs/ft L80 HTC II TD-Walakpa 5371 2323 w 6-1/8" Target(Toe) Oak) Rev by Comments 4/8/2011 MCook 856114anni1g Reparation 12/11/2011 MCook Wel Panning Repaealan 4 Well Name: Walakpa #14 Drill & Evaluate Summary Type of Well (service/ producer/ injector): Horizontal Gas Producer Surface Location: Located within : : 1744' FSL 1636' FEL T.20 N., R. 20 W., U.M. Section 23 - NAD 27 ZONE 6 : N= 6,241,863 E= 612,912 Target Walakpa T1 —(Heel) 1544' FSL 885' FWL T.20 N., R. 20 W., U.M. Section 24 Top Walakpa Gas Sand NAD 27 ZONE 6 : N= 6,241,702 E= 615,436 TVD/SS: 2230 -ft Target Walakpa T2 —(Toe) 1360' FSL 2373' FWL T.20 N., R. 20 W., U.M. Section 24 Base Walakpa Gas Sand NAD 27 ZONE 6 : N=6,241,542 E= 616,926 TVD/SS:2250 -ft AFE Number: 10-0012 Rig: Kuukpik#5 Estimated Start Date: March 9, 2012 - Operating days to complete: _ 23 MI): 5371 TVD: 2323 Max Inc: 90 KOP: 250 KBE(GL): 21.5 ft. (rkb) . (rkb) • SS - GL 31.7 ft. Well Design (conventional, slimhole, etc.): Slimhole— Development/ Horizontal Gas Producer Objective: Drill and complete slimhole horizontal well—targeting the Walakpa gas sand interval. Drilling Fluid Program: • 12-1/4-in Surface Hole Fluid Properties: Spud — LSND Freshwater Mud Density (ppg) Funnel Vis YP HTHP pH API Filtrate LG Solids 8.6- 9.2 60- 80 25 - 60 N/A 9.0-9.5 < 12 < 6.5 8-1/2" Intermediate Hole Fluid Properties: Polymer/ LSND/Barazan D+ Density (ppg) PV YP I-ITHP pH API Filtrate LG Solids 9.5 - 10.5 10- 20 25 - 30 10 - 11 9.0- 9.5 < 6 < 6 6-1/8" Production Hole Fluid Properties: Drill in Fluid : Baradril—N / KCL D, sity '_ PV YP HTHP pH API Filtrate LG Solids C. 10.0- 10.2 . 10- 12 ; 15 - 18 10 - 11 9.0-9.8 < 6 < 4 5 Waste Disposal: RCRA Exempt—Class II Wastes Drilling fluid : Option#1: EB-15 UIC II well. Drill Cuttings disposal : Option #1 : Barrow Municipal Landfill Option#2 : stored/barged to G&I Facility( PRB ) disposal site. Waste Disposal: RCRA Exempt—Class I Wastes Option#1 : disposed of locally- Barrow Municipality Casing/Tubing Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Bottom Tbg O.D. MD/TVDrkb MD/TVDrkb 26 0-in 16 -in* 84# L-80 Welded 80-ft 21-ft 101-ft 12.25-in 9.625-in 40# L-80 BTC-M 1154-ft 20-ft 1174/1153-ft 8.5-in 7.0-in 26# L-80 BTC-M 3823-ft 19-ft 3842/2278-ft 6.125-in 4.5-in 12.6# L-80 BTC 1679-ft 3692/2242-ft 5371/2323-ft Cement Program: Casing Size 9-5/8", 40 ppf, L-80 BTC-M Type: Surface Casing to 1190/1153' md/tvd Basis for Calculation 80-ft. shoe joints, 50% excess in permafrost (12-1/4"hole), and cement to surface. Cement Volume: Spacer 10 bbl of water(test lines) , 40 bbls—HES Spacer Lead Halliburton Type"L" : Density: 10.7, Yield: 4.15 cu_.ft/sk, Mix (Surface to Water: 19.5 gal/sk BOC @ 690' md/rkb) SXS : 92 Tail Halliburton Type"C" : Density: 15.6, Yield: 0.95 cu.ft/sk, Mix (9-5/8"shoe— Water:3.83 gal/sk 500 It above shoe depth) SXS : 285 Temp 36 deg. F @ 1190/1153ft. md/tvd Casing Size 7", 26 ppf, L-80 BTC-M Type: Production Casing(long string) : 3761/2308 ft. md/tvd (rkb) Basis for Calculation 80-ft. shoe joints, 30% excess in open hole. Top of cement (TOC) located 500 ft. above Upper Barrow Gas sand. Cement Volume: Wash 10 bbl water(test lines) Spacer 40 bbls—HES Spacer Tail Premium cement + 3% BWOW KCL, 1.5% CalSeal, 0.6% (7"shoe—500 LAP 1 tt.above shoe depth) Density: 15.6 ppg, Yield : 095 cu.ft./sxs, Water : 5.39 gal/sxs Thickening Time : +/- 4:00 hrs @ 60 deg. F. crITO—scs. Temp 57deg. F @ 3761/2308 ft. md/tvd 6 Evaluation Program 12.250-in Surface Hole: Open Hole Logs: • L/MWD Directional/Gamma/Resistivit Y • SRO—GYRO : 0— 500 ft and-rkb 8.5-in Intermediate Hole: Open Hole Logs: • LWD Directional/Gamma/Resistivity 6.125 Production Hole: Open Hole Logs: • LWD Directional/Gamma/Resistivity Cased Hole Logs: • not required • Formation Markers : Walakpa #14 Commercial Est.Formation Hydrocarbon Tops Uncertainty Bearing Formation (TVDss) (feet) (Yes/No) Surface Hole: Base of Permafrost 900 +/- 100' no 9-5/8 csg pt 1000 +/-25' n/a Intermediate Hole: Top HRZ 1860 +/-50' no Base HRZ 1890 +/-50' no Hydrate Stability Zone 1980 +/- 100' n/a Top Walakpa SS (at Heel) 2230 +/-25' yes Intermediate csg pt 2238 +/-25' n/a Base Walakpa SS (at heel) 2260 +/-25' n/a Production Hole: Top Walakpa SS (at toe) 2250 +/-25' yes Base Walakpa SS (at toe) 2280 +/-25' yes LCU/Kingak Shale 2280 +/-25' no 7 Recommended Bit Program BHA Hole Size Depth (MD) Bit Type Nozzle #100 12.5-in 0-ft— 1174-ft QHC1GRC-Tooth Bit 3-15 & (IADC Code-117W) 1-10 #200 8.5-in 1174-ft—3842-ft FX65-Fixed Cutter 3-15 & (IADC Code: M323) 1-10 #300 6.125-in 3842-ft —5371-ft TD FMF3543ZZ-Fixed Cutter 3-12 IADC Code: M433 Well Control Surface Interval— 12.25" BOPE—Surface Interval— 12.25" 21 '/ " 2M MSP Maximum anticipated BHP 540-psi (8.65-1b/gal @ 1200-ft TVD/ss) Maximum surface pressure 420-psi (0.1-psi/ft gas gradient to surface) Casing Test Pressure : 2500-psi 9 5/8"40# L80 BTC-M BOPE—Intermediate/Production—8.5"/6.125" 11", 5M, Double ram with annular(Hydril - GL) Maximum anticipated BHP 1008-psi (8.65-1b/gal @ 2230-ft TVD/SS — top ,/ Walakpa Sandstone) Maximum surface pressure 785-psi (0.1-psi/ft gas gradient to surface) - Planned BOP test pressure Rams test to 3,500-psi/250-psi. Annular test to 2,500-psi/250-psi Casing Test Pressure : 7" 26# L80 BTC-M 2500-psi Planned drilling fluid: Intermediate : LSND/Barazan Polymer Production : Baradril "N"/KCL(6%) Drilling Hazards & Contingencies: • Sticky clays may be present from the lower permafrost on down to intermediate casing point @ 3815/2313 and/tvd. • Intermediate hole section KOP is planned under surface 9-5/8"40# L80 casing. DLS will range in the 7 deg/100— initial well inclination to be built to 70 deg. Manage drilling ROP's and hole cleaning requirements as needed. 8 Expected Pressures • The Walakpa Gas gas sands are normally pressured with an anticipated reservoir pressure of 1008psi @ 2230 ft./tvdss. Hydrocarbons: VI • Significant hydrocarbon producing intervals are not expected to be encountered before reaching the top of the Walakpa sandstone in the well,prognosed at 3869/2283 and/tvd-rkb. Faults • No fault intersections are expected. Hydrogen Sulphide • The Walakpa Gas Field is not designated as H2S area. H2S is not expected. Anti-Collision Issues • Walakpa#13: 14 ft. to 275 ft. Reference anti-collision (travelling cylinder) report included in Well Data Package. Distance to Nearest Well: • The Walakpa#13 well— 14 ft. at surface. Conductor to conductor separation distance. 9 Walakpa #14 Drilling, Evaluation & Complete: 1. Skid the Kuukpik #5 drilling rig +/- 14 ft, center rotary over the pre-installed Walakpa #14 , 16" conductor/cellar . MB 230 Vetco Gray landing ring will be pre-installed on 16" conductor. Reference the conductor installation procedure for wellhead orientation requirements. 2. NU and function test 21-1/4" 2M MSP Diverter System. Notify AOGCC representative 48 hrs prior to diverter system function test. —' 3. Take on fresh water and build spud mud to noted rheology. 4. PU 12-1/4" ( BHA #100 ) : QHC1GRC drill bit on HES performance motor (8"Sperry Drill lobe 4/5 – 5.3 stage) assembly w/ MWD/GR/RES. Function test L/MWD collars and performance motor. 5. Drill to surface KOP @ 250 ft tvd/md. Orient HES performance motor w/ toolface and azimuthal control. Perform SRO Gyro surveys to 500 ft md. 6. Drill 12-1/4" hole section to surface 9-5/8" 40# L80 BTC-M csg. point @ 1174 ft. and/1153 ft . tvd.with 2.5 deg/100 DLS. Surface 9-5/8" casing point is at end of build (EOB) at 21.86 deg well inclination. 7. Manage drilling fluid (spud mud) rheology, funnel viscosity to be maintained in the 60-80 sec. /qt. . range.. Adjust funnel viscosity as needed to ensure annular drill cuttings removal. 8. Circulate and condition 12-1/4" surface hole for surface 9 5/8' 40# L80 BTC-M casing running. 9. Run 9-5/8", 40#, L-80 BTC-M surface casing to hole section total depth: 1174 ft. and/ 1153 ft tvd. 10. Cement 9-5/8", 40#, L-80 BTC-M casing w/ HES Type "L" (10.7 ppg lead) and Type "C" (15.6 ppg tail) cement blends. ✓ Use 50% annular excess factor for cement "sxs" calculation. Confirm cement returns to surface. Perform top job if cement returns are not confirmed at slM. fihrk 11. HES cementing van rinsate to be collected in Peak vac truck. Rinsate fluids (estimate: 30-40 bbls) to be injected at EB-15 disposal well per HES EB-15 Injection procedure. 12. Surface excess cement returns captured via 16" divert line to be collected in 2 ea. Peak 20 cu yd / 100 bbl cutting boxes. Do not add cement retarder(Sodim Citrate) to Peak cutting boxes. Use L162 or Hyster to position cutting boxes. Allow cement to harden (48 hrs). Transport cuttings boxes to Municipal landfill–dispose of"solidified" cement.y13. ND 21-1/4" 2M MSP, install Vetco Gray 5MCZad , NU DSA and Shaffer 11" 5M BOPE–test BOPE, choke manifold, stand pipe & surface IBOP's and safety valves. Test Shaffer 11" 5M BOPE see./ to 3500 psi/high – 250 psi low. Annular preventer to be tested to 2500 psi/high – 250 psi low. let Position HES Geospan unit in sub-base on BOPE trolley, MU hydraulic connections to Geospan unit, test Geospan connections/manifolding per HES DD service supervisor. -��f <<-f°'‘ p 0 Awl pro,v 14. Vetco Gray/Conam Tigiak on-site personnel to align starting head orientation to for wellhouse installation/access requirements. 10 15. Dispose of surface hole section "spud" drilling fluid via Peak 150,100 bbl vac trucks — transport to EB-15 tank farm for "temporary" storage prior to injection. 16. Build intermediate hole section drilling fluid volume : LSND/Barazan D+ (Pits: #1- #4) . Initial mud weight to be built to 9.5 ppg. 17. PU 8-1/2" ( BHA #200) : 8-1/2" FX65 drill bit on HES performance motor(7" SperryDrill Lobe 7/8—6.0 stage) assembly w/ MWD/GR/RES collars — test MWD collars while RIH. RIH to 9-5/8" 40# L80 BTC-M float collar. Test 9-5/8" 40# L80 BTC-M surface casing to 2500 psi. Record/chart casing test on Barton recorder and tabular format ( Pressure vs. BBIs (.5 bbl increments)), submit with daily IADCC report. 18. Displace spud drilling fluid to LSND/Barazain D . 19. Drill out float collar shoe track, float shoe and 20-ft of formation to 1194/1172-ft and/tvd rkb. 20. POOH to 1174-ft and-rkb and perform Leak Off Test (LOT) : 14.5 ppg equivalent. Reference attached LOT form for pressure/bbls data presentation. 21. RIH - drill 8 1/2" hole section with BHA #200 (MWD/GR/RES). Directionally drill , building wellbore inclination angle to "end directional" point at 1900/1648 ft and/tvd @ 70 deg well inclination (DLS = 7 deg./100 ft). 22. Manage cased and open hole friction factor(s)/drag with additions of NXS lubricants — range (3-6% by volume/as required). ✓ Be prepared for HRZ borehole stability problems. ✓ HRZ top : 2698 and / 1913 tvd (rkb) ✓ HRZ base : 2788 and / 1943 tvd (rkb) 23. Drill 8-1/2" tangent section and build sections to 7" 26# L80 BTC-M casing point at 3842/2278 ft. and/tvd (rkb). Note : PU,SO and off bottom rotating weights while drilling 8-1/2" intermediate hole section. 24. Circulate 8-1/2" wellbore, minimum 2x bottoms up, short trip to 9-5/8" 40#L80 BTC-M shoe. Back ream as required w/Tesco top drive through HRZ interval. POOH 25. Prep rig for running 7" 26#L80 BTC-M intermediate casing. 26. Pre-mix 6-1/8" production hole "drill in" fluid : Baradril N / KCL (6%). Clean pits : #1 - #4 1;;1- 7,, k4MS 27. Run & cement 7" 26# L80 BTC-M intermediate casing with HES with premium blend (15.6 ppg) single stage. Land 7" 26# L80 BTC-M casing hanger in casing head of Vetco Gray MB230 11" 5M well head. RILDS - energize packoff assembly and test to 5000 psi. Test Vetco Gray 11" 5M wellhead to 5000 psi. 28. HES cementing van rinsate to be pumped to Peak Vac truck for collection and transport to EB-15 disposal well. Do not comingle cement rinsate w/ drilling fluids in tank farm upright tanks. Peak Vac truck to pump rinsate directly to HES cementing unit for displace downhole in EB-15 well. 29. Vetco Gray to install lateral "sweeps" manifolding via 5M flange outlet to MB 230 5M wellhead— for inner annuli ( 7"int.csg x 2-7/8" production tubing) access. Note: Each"sweep" to have 1 ea. 2- 11 1/16" 5M gate valve installed on upper end of"sweep" section. Valves to provide upper annuli access for well freeze protection requirements. 30. PU 6-1/8" ( BHA #300) : 6-1/8" FMF3543ZZ-Fixed Cutter drill bit on HES GP 5200 Rotary Steerable (ABI) assembly w/ MWD/GR/RES — test MWD collars while RIH. RIH to 7" 26# L80 BTC-M float collar. 31. Test 7" 26# L80 BTC-M intermediate casing to 2500 psi. Record/chart casing test on Barton recorder and submit with daily IADCC report. 32. Drill out float collar shoe track, float shoe and 20-ft of formation to 3862/2282-ft md/tvd rkb. 33. POOH to 3842 and /2278 tvd-rkb / 7" 26# L80 shoe placement, and perform FIT to 0.68 psi/ft equivalent (13.00 ppg). 34. Circulate Baradril N/KCL drilling fluid to cased and open hole. 35. RIH - drill 6-1/8" production hole section with BHA #300 to interval total measured depth at 5371/2323 md/tvd rkb. Manage cased and open hole friction factor(s)/drag with additions of NXS lubricants—range (3-6%by volume/as required). 36. Circulate annulus 2x/short trip 6 1/8" horizontal hole section back to 7" intermediate casing shoe every 1000 ft and of new hole section drilled or every 24 hrs (rotating) - which occurs first. Back ream as required through tight hole sections. ✓ Savik #1, 6-1/8" production hole, experienced severe tight hole conditions. Probable cause : 5-7/8" (OD) non-rotating stabilizer. 37. POOH w/ BHA #300. LD flex, L/MWD and GP 5200 rotary steerable collars. PU BHA #400 / Bullnose (Holefinder), RIH to perform clean out run to TD. POOH ✓ After POOH w/ BHA # 300 : HES — Sperry Sun, smart iron collars to be removed from location and transported to appropriate service center(s) for collar inspection and operations assurance calibration checks. 38. Prep rig to run 4 Y" 12.6# L80 BTC slotted liner with BHI SLZXP liner top packer/hanger/tie-back extension assembly. Rabbit 4" 14# S135 XT39 dp w/ 2" ball prior to RIH w/ 4-1/2" 12.6# L80 BTC production liner. Ensure that crossover's (XO's) 4-1/2" BTC pin x XT-39 box, as well as full opening valve (FOV) w/joint are stationed near or on the rig floor when PU slotted liner — in the event that the well needs to be circulated. 39. RIH w/ 4 Y2" 12.6# L80 BTC slotted liner on 4" 14 # S135 XT39 dp. Displace production hole section wellbore through 2-7/8" 6.5 # inner string assembly/guide shoe with weighted NACL/NABR completion brine. Adjust completion brine fluid density to 0.1 ppg increase over Baradrill N/KCL fluid density. Expected displacement rate : Q = 4.0—4.5 bpm. 40. Manage completion brine open hole loss/gain volumes via PASON unit. Do not exceed surface pressure circulation limits that could initiate setting sequence of SLZXP system. BHI service technician to provide surface circulation pressure limitations. 12 41. Drop (2") setting ball for SLZXP liner top packer/hanger assembly. Top of SLZXP liner top packer/hanger assembly @ 3665/2277' and/tvd. ( positioned with 150 ft. liner lap inside 7" 26# L80 BTC-M int csg ). BHI technician to instruct/provide pressure setting schedule for setting SLZXP system. Confirm setting of SLZXP system. 42. RU to run 2-7/8" 6.5 # L80 EUE completion string. RIH w/ completion string, space out 2-7/8" 6.5# WLEG at 100 ft above top of 4-1/2" 12.6# L80 liner tie back extension. Circulate 2-7/8" x 7" annulus. 43. Land 2-7/8" tubing hanger in Vetco Gray MB 230 tubing head, RILDS— energize tubing hanger packoffs. Test tubing hanger/head assembly/ to 5000 psi. L/D 2-7/8" completion running equipment. Clear KD #5 rig floor. 44. Install mechanical isolation barrier (TWC) in Vetco Gray MB230 11" 5 M tubing hanger profile — test to 2500 psi. ND Shaffer 11" 5M BOPE &DSA. NU Vetco Gray 2-9/16" 5 tubing head adapter with I ea. 2-9/16" Vetco Gray isolation valve. 45. Test production adapter to 5000 psi. Record/chart casing test on Barton recorder and submit with daily IADCC report. 46. Pull TWC with lubricator. 47. Freeze protect 2-7/8" 6.5 ppf tubing and 2-7/8" 6.5 ppf tubing x 7" 26# production casing annuli to 1200-ft. (Base Permafrost) + 200 ft. 48. Freeze protect (diesel) the 7-in x 9 5/8"-in casing down to 1200-ft MD. Set BPV. 49. Complete a post-rig inspection with the WH Pacific Operation representative prior to the rig moving off the well. 13 Petrotechnical Resources of Alaska Walakpa Zone 6 Walakpa Walakpa 14 Plan Walakpa #14 Plan: Walakpa #14 WP 5.1 Standard Proposal Report 09 May, 2011 HALLIBURTON Sperry Drilling Services UI — — — I H Q O 4J m 03- O [o c ` N 40 NN U pVI J oO (`FiJ N Q ' RN Zm g - n no < U � 8" mm Nv- ^� rt, 10 m ` �Q �_ maio tiUm ?ooa monm�v�" Z uj o t _Eotmr > m7 � ` vo0omwwrmciw, m� Q. 3 pomnjol-V r-Or `nn a -m-=-5 - '.? 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'a CO 0 CI o e m 0 g o C. -� f1 f1 fl RI!/1) ooc)(+)LUZON/(-)I l s Sperry Drilling L L I B U R T O I"J Standard Proposal Report Database: Sperry EDM.16 PRD Local Co-ordinate Reference: Well Walakpa 14 Plan Company: Petroteclinical Resources of Alaska TVD Reference: AS-Staked©53.20ft(31.7 GL-MSL/21.5 KB) Project: Walakpa Lone 6 MD Reference: AS-Staked @ 53.20ft(31.7 GL-MSL/21.5 KB) Site: Walakpa North Reference: True Well: Walakpa 14 Plan Survey Calculation Method: Minimum Curvature Wellbore: Walakpa#14 Design: Walakpa#14 WP 5 1 Project Walakpa Zone 6 Map System: IIS State Plane 1927(Exact solution) System Datum: Mean Sea Level Gen Datum: NAL)1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 06 Using geodetic scale factor Site Walakpa Site Position: Northing: 6,243,272.00 ft Latitude: 71.07 From: Map Easting: 631,535.00 ft Longitude: -156.89 Position Uncertainty: 0 00 ft Slot Radius: Grid Convergence: 1.05 ° Well Walakpa 14 Plan Well Position +N/-S 0.00 ft Northing: 6,241,863.86 ft Latitude: 71.07 +EI-W 0.00 ft Easting: 612,912.91 ft Longitude: -157.05 Position Uncertainty 0 00 ft Wellhead Elevation: ft Ground Level: 31.70ft Wellhore Walakpa#14 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (-) 11 (nT) BGGM2009 1/25/2010 18 54 80.65 57,521 Design Walakpa#14 WP 5 1 Audit Notes: Version: Phase: PLAN Tie On Depth: 21.50 Vertical Section: Depth From(TVD) +NI-S +EI-W Direction VII In) (ft) 11 21.50 0.00 0.00 95.47 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (ft) (°I 1°I (ft) ft (ft) (ft) (°1100ft) (°1100ft) (°I100ft) (°) 21 50 0 00 0 00 21.50 -31.70 0 00 0.00 0.00 0.00 0.00 0.00 750 00 0 00 0 00 250.00 196 80 0.00 0.00 0.00 0.00 0.00 0.00 500 00 5 00 94 00 499 68 446.48 -0.76 10.87 2.00 2.00 0.00 94.00 1 174 32 21 86 94 00 1,153.20 1,100.00 -11 65 166.53 2.50 2.50 0.00 0.00 1 204.32 21 86 94 00 1,181.04 1,127.84 -1242 177.68 0.00 0.00 0.00 0.00 1 900 67 70 60 94.50 1,648.36 1,595.16 -49 49 664.08 7.00 7.00 0.07 0.63 3 626 80 70 60 94.50 2221.68 2,168.48 -177.21 2,287.20 0.00 0.00 0.00 0.00 3(169 48 80 00 97 01 2,283.20 2,230 00 -200 84 2,520.47 4.00 3.87 1.04 14.84 3.014 48 80 00 97 01 2,291.01 2,237.81 -206.25 2,564.45 0.00 0.00 0.00 0.00 4,102 17 89 51 97.01 2,312.72 2,259.52 -235.11 2,799.10 4.00 4.00 0.00 0.00 0.371 03 89 51 97 01 2,323.20 2,270.00 -383.92 4,008.80 0.00 0.00 0.00 0.00 5/9/2011 2:14..59PM Page 2 COMPASS 2003.16 Build 73 Sperry Drilling LL I B Li RTO N Standard Proposal Report Database: .Sperry EDM.16 PRD Local Co-ordinate Reference: Well Walakpa 14 Plan Company: Petrotechnical Resources of Alaska TVD Reference: AS-Staked @ 53.206(31.7 GL-MSL/21.5 KB) Project: Walakpa Zone 6 MD Reference: AS-Staked @ 53.206(31.7 GL-MSL/21.5 KB) Site: Walakpa North Reference: True Well: Walakpa 14 Plan Survey Calculation Method: Minimum Curvature Wellbore: VValakpa#14 Design: Walakpa#14 WP 5 1 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Veil Section (ft) 11 (°I (ft) ft (ft) (ft) (ft) (ft) -31.70 71 50 0 00 0.00 21.50 -31.70 0.00 0.00 6,241,863,86 612,912.91 0.00 0.00 100 00 0 00 0 00 100 00 46.80 0.00 0.00 6,241,863.86 612,912.91 0.00 0.00 20(1 00 0.00 0.00 200 00 146.80 0.00 0.00 6,241,863.86 612,912.91 0.00 0.00 250 00 0 00 000 250 00 196 80 0.00 0.00 6,241,863.86 612,912.91 0.00 0.00 KOP DLS 2.00 250.00'MD 300 00 1.00 94 00 300 00 246.80 -0.03 0.44 6,241,863.84 612,913.35 2.00 0.44 400 00 3 00 94.00 399.93 346.73 -0.27 3.92 6,241,863.65 612,916.83 2.00 3.92 500 00 5.00 94 00 499.68 446 48 -0.76 10 87 6,241,863.27 612,923.79 2.00 10.90 Increase Directional 2.50 500.00'MD 600 00 7 50 94 00 599 08 545.88 -1,52 21,73 6,241,862.68 612,934.66 2,50 21.78 700 00 10 00 94 00 697.91 644.71 -2 58 36.91 6,241,861,86 612,949.85 2.50 36.99 800 00 12 50 94 00 795 98 742 78 -3.94 56.37 6,241,860.80 612,969.33 2.50 56.49 900 00 15.00 94 00 893.11 839.91 -5.60 80.08 6,241,859.52 612,993.06 2.50 80.25 967 45 16 56 94.00 953.20 900.00 -6.78 97.02 6,241,858.60 613,010.01 2.50 97.22 Base of Permafrost 1.000 00 17 50 94 00 989 10 935 90 -7.55 107.99 6,241,858,00 613,021.00 2.50 108,22 1,100 00 20 00 94 00 1,083 79 1,030 59 -9.79 140.05 6,241,856.27 613,053.09 2.50 140,35 I 114 32 21 86 94 00 1,153.20 1,100 00 -11.65 166.53 6,241,854.83 613,079.59 2 50 166.89 End Directional 1174.32'MD-9 5/8" 1,200 I)0 21.86 94.00 1,17704 1,123.84 -12.31 176.07 6,241,854.31 613,089.14 0.00 176.44 1 204 32 21 86 94.00 1,181.04 1,127.84 -12.42 17768 6,241,854.23 613,090.74 0.00 178.05 Begin Directional DLS 7.00 1204.32'MD 1,300 00 28.56 94.15 1,267.57 1,214 37 -15.33 218.30 6,241,851,96 613,131.40 7.00 218.77 1,400 00 35 56 94.26 1,352.27 1,299 07 -19.22 271.20 6,241,848.90 613,184.35 7.00 271.79 1,500 00 42 56 94 33 1,429.87 1,376 67 -23.93 333,99 6,241,845.17 613,247.20 7.00 334.75 1,600 00 49 55 94 38 1,499.23 1,446 03 -2940 405.74 6,241,840.83 613,319.02 7.00 406.69 1,70000 56.55 9443 1,559.29 1,50609 -35.54 485.37 6,241,835.95 613,398.74 7,00 486.55 1,800 00 63 55 94 47 1,609.18 1,555.98 -42.25 571.71 6,241,830.59 613,485.16 7.00 573.13 1,900 00 70 55 94 50 1,648 14 1,594 94 -49,44 663.46 6,241,824.83 613,577.00 7.00 665,15 1,000 67 70 60 94.50 1,648.36 1,595.16 -49.49 664 08 6,241,824.79 613,577.63 7.00 665.77 End Directional 1900.67'MD 2,00000 70.60 94.50 1,681.35 1,62815 -5684 757.49 6,241,818.91 613,671.13 0.00 759.46 2,100 00 70 60 94 50 1,714.57 1,661.37 -64 24 851.52 6,241,812.99 613,765.26 0,00 853.77 2,200 00 70 60 94 50 1,747.78 1,694.58 -71.64 945.55 6,241,807.07 613,859.39 0.00 948.08 2,300 00 70.60 94 50 1,781.00 1,727 80 -79,04 1,039.58 6,241,801.14 613,953.52 0.00 1,042.38 2.4110 00 70 60 94.50 1,814.21 1,761.01 -86.44 1,133.62 6,241,795.22 614,047,65 0.00 1,136.69 7,500 00 70 60 94 50 1,847.42 1,794 22 -93.84 1,227.65 6,241,789.30 614,141.78 0.00 1,231.00 2,600 00 70 60 94.50 1,880 64 1,827 44 -101.24 1,321.68 6,241,783.38 614,235.90 0.00 1,325,31 2,698 03 70 60 94 50 1,913 2(1 1,860 00 -108 49 1,413 87 6,241,777.57 614,328.18 0.00 1,417.77 Top HRZ 2.790 00 70 60 94 50 1,913.85 1,860 65 -108 64 1,415.71 6,241,777.45 614,330.03 0.00 1,419.62 2,788 36 70 60 94 50 1,943.20 1,890 00 -115 17 1,498 80 6,241,772.22 614,413.20 0.00 1,502.95 Base HRZ 2,800 00 70 60 94 50 1,947.07 1,893 87 -116.04 1,509.75 6,241,771.53 614,424.16 0.00 1,513.93 2.900 00 70 60 94 50 1,980 28 1,927 08 -123.44 1,603.78 6,241,765.61 614,518.29 0.00 1,608.24 5/9/2011 2.14:59PM Page 3 COMPASS 2003.16 Build 73 Sperry Drilling BALLI BURTON Standard Proposal Report Database: Sperry EDM.16 PRD Local Co-ordinate Reference: Well Walakpa 14 Plan Company: Pelmtechnical Resources of Alaska ND Reference: AS-Staked @ 53.20ft(31.7 GL-MSL/21.5 KB) Project: Walakpa Zone 6 MD Reference: AS-Staked @ 53.20ft(31.7 GL-MSL/21.5 KB) Site: Walakpa North Reference: True Well: Walakpa 14 Plan Survey Calculation Method: Minimum Curvature Wellbore: Walakpa#14 Design: Walakpa#14 WP 5.1 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +EI-W Northing Easting DLS Vert Section (tt) (1 1°) (ft) ft (ft) (ft) (ft) (R) 1,960.30 3.000 00 70 60 94 50 2,013 50 1,960 30 -130 83 1,697.81 6,241,759.68 614,612.42 0.00 1,702.55 3 059 33 7(1 60 94 50 2,033.20 1,980 00 -135.22 1,753.60 6,241,756.17 614,668.26 0.00 1,758.50 Hydrate Stability Zone :3,100 00 70160 94.50 2,046 71 1,993.51 -138.23 1,791.84 6,241,753.76 614,706.55 0.00 1,796.86 3.2110 00 70 60 94.50 2,079.92 2,026.72 -145.63 1,885.88 6.241,747.84 614,800.68 0.00 1,891.17 3,300 00 70 60 94 50 2,113 14 2,059 94 -153.03 1,979.91 6,241,741.92 614,894.81 0.00 1,985.48 3,400 00 70 60 94.50 2,146 35 2,093 15 -160.43 2,073.94 6,241,735.99 614,988.93 0.00 2,079.79 3.500 00 /0 60 94 50 2,179 57 2,126 37 -167 83 2,167.97 6,241,730.07 615,083.06 0.00 2,174.10 .4,600 00 7(1 60 94.50 2,212 78 2,159 58 -175.23 2,262.01 6,241,724.15 615,177.19 0.00 2,268.41 3 626 80 /0 60 94 50 2,221 68 2,168 48 -177.21 2,287.20 6,241,722.56 615,202.42 0.00 2,293.68 Begin Directional DLS 4.00 3626.80'MD 3,700 00 73 43 95.28 2,244 28 2,191.08 -183.15 2,356 57 6,241,717.71 615,271.86 4.00 2,363.30 3.800 00 77 31 96 31 2,269.53 2,216 33 -192.93 2,452.81 6,241,709.44 615,368.24 4.00 2,460.03 3.842 12 78 94 96 74 2,278.20 2,225 00 -197.62 2,493.76 6,241,705.40 615,409.25 4.00 2,501.24 7" 3,869 48 80 00 91.01 2,283.20 2,230.00 -200.84 2,520.47 6,241,702 60 615,436.00 4.00 2,528.13 End Directional 3869.48'MD-Top Walakpa SS(at Heel)-Walakpa#14-Heel 3,1100 00 80 00 97.01 2,288.50 2,235.30 -204.51 2,550.30 6,241,699.40 615,465.88 0.00 2,558.18 014 48 80 00 97.01 2,291.01 2.237 81 -206.25 2,564.45 6,241,697.88 615,480.06 0.00 2,572.43 Begin Directional OLS 4.00 3914.48'MD 3.998 76 83 37 97 01 2,303.20 2,250 00 -216.43 2,647.21 6,241,689.00 615,562.96 4.00 2,655.79 Top Walakpa SS(at toe) 4 000 00 83 42 97 01 2,303.34 2,250.14 -216.58 2,648 43 6,241,688.87 615,564.19 4.00 2,657.02 4.100 00 87 42 97 01 2,311.32 2,258 12 -228.75 2,747.35 6,241,678.26 615,663.27 4.00 2,756.64 4,152 17 89 51 97.01 2,312.72 2.259 52 -235.11 2,799.10 6,241,672.70 615,715.12 4.00 2,808.77 End Directional 4152.17'2?D 4.200 00 89 51 97.01 2,313 13 2,259.93 -240.95 2,846.57 6,241,667.61 615,762.67 0.00 2,856.58 -4,207 71 89.51 97.01 2,313.20 2,260 00 -241.89 2,854.23 6,241,666.79 615,770.34 0.00 2,864.29 Base Walakpa SS(at heel) 4,300 1)0 89 51 97 01 2,313.99 2,260 79 -253.16 2,945.82 6,241,656 96 615,862.09 0.00 2,956.54 4,400 00 89 51 97 01 2,314.85 2,261 65 -265.37 3,045.07 6,241,646.31 615,961,51 0.00 3,056.50 4,500 00 1)9 51 97 01 2,315 71 2,262 51 -277.58 3,144 32 6,241,635.66 616,060.93 0.00 3,156.46 4,600 00 8)1.51 97 01 2,316.57 2,263.37 -289.79 3,243.57 6,241,625.01 616,160.35 0 00 3,256.42 4,700 011 89.51 97.01 2,317 43 2,264.23 -302.00 3,342.82 6,241,614.36 616,259.77 0.00 3,356.38 4 2100 00 89.51 97 01 2,318 29 2,265 09 -314.20 3,442.06 6,241,603.71 616,359.18 0.00 3,456.34 4,900 00 89 51 97 01 2,319,15 2,265.95 -326.41 3,541.31 6,241,593 06 616,458.60 0.00 3,556.30 5.000 00 89.51 97 01 2.320.01 2,266 81 -338.62 3,640.56 6,241,582.41 616,558.02 0.00 3,656.26 5,100 00 89 51 97.01 2,320.87 2,267.67 -350 83 3,739.81 6,241,571.76 616,657.44 0.00 3,756.22 5,200 00 89.51 97.01 2,321.73 2,268.53 -363.04 3,839.06 6,241,561.11 616,756.86 0.00 3,856.18 5.300 00 89 51 97 01 2,322.59 2,269.39 -375.25 3,938.31 6,241,550.46 616,856.28 0.00 3,956.14 5.371 (13 89 51 97.01 2,323.20 2,270.00 -383.92 4,008.80 6,241,542.90 616,926.90 0.00 4,027.14 TD at 5371.03'MD-6 1/8 OH-Walakpa#14-Toe 5/9/2011 2:14.59PM Page 4 COMPASS 2003.16 Build 73 Sperry Drilling F4ALLI B U P-r o 1 V Standard Proposal Report Database: Sperry EDM 16 PRD Local Co-ordinate Reference: Well Walakpa 14 Plan Company: Peiroiecnnical Resources of Alaska TVD Reference: AS-Staked @ 53 208(31.7 GL-MSL/21.5 KB) Protect: Walakpa Lone 6 MD Reference: AS-Staked @ 53.20f(31.7 GL-MSL/21.5 KB) Site: Walakpa North Reference: True Well: Walakpa 14 Plan Survey Calculation Method: Minimum Curvature Wellbore: Walakpa#14 Design: Walakpa#14 WP 5.1 Targets Tar tet Name -hithniss target Dip Angle Dip Dir. TVD +NI-S +EI-W Northing Easting -Shape (1 (1 (ft) (ft) (ft) (ft) (ft) Walakpa#14-Heel 0 00 0.00 2,283 20 -200.84 2,520.47 6,241,702,60 615,436.00 -plrin hds lar gel cei 4er -Point Walakpa#14-Toe 0 00 0.00 2,323.20 -383.92 4,008.80 6,241,542.90 616,926.90 plan tuts target center Pi a if Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name r) (") 5,371 03 2,323.20 61/8 OH 6-1/8 6-1/8 '3 842 12 2,278 20 7" 7 8-1/2 1,174 32 1,153.20 9 5/8" 9-5/8 12-1/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology I') (l 3,059 33 2.033 20 Hydrate Stability Zone 2,698 03 1.913 20 Top HRZ 3,869 48 2,283 20 Top Walakpa SS(at Heel) 962 45 953.20 Base of Permafrost 2.788 36 1,943.20 Base HRZ 4,207 71 2,313 20 Base Walakpa SS(at heel) 3,998 76 2,303 20 Top Walakpa SS(at toe) Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-s +El-W MI (ft) (ft) (ft) Comment 250 00 250 00 0 00 0 00 KOP DLS 2.00 250 00'MD 500 00 499 68 -0.76 10.87 Increase Directional 2.50 500 00'MD 1 174 32 1.153.20 -11.65 166 53 End Directional 1174.32'MD 1 204 32 1,181 04 -12.42 177 68 Begin Directional DLS 7.00 1204.32'MD 1.900 67 1,648 36 -49.49 664.08 End Directional 1900 67'MD 3,626 8)1 2,221.68 -177.21 2,287.20 Begin Directional DLS 4.00 3626.80'MD 3 869 48 2,283.20 -200 84 2,520 47 End Directional 3869 48'MD .1,914 48 2,291.01 -2(16.25 2,564.45 Begin Directional DLS 4.00 3914.48'MD 4.152 17 2,312.72 -235 11 2,799.10 End Directional 4152.17'MD 5,371 03 2,323.20 -383.92 4,008.80 TD at 5371.03'MD 5/9;201 12:14:59PM Page 5 COMPASS 2003 16 Build 73 -- -7 N N N I I-- v n 0) k N 7 a 0 n n N N• ', N f D > 0 fY N l"1 00 U.3 f > Q _ IA II oL‘14) I Ir' N ff S 9 f, NF U O d0000i�Gr10 V r� . n - N j::::.66:,-::::- :TI�I Pi'a. N 2F O:!,,.8 er- Fr-i—. ooin - •tn12uorIy, E w ucor' F. m 0 0 011 °;13,...1 1 Ir)lii A V O 1"` I,1 m00000000000 4 ,• I I 1N, .Ir, N OOOONN OOO v0 O 02, 7 N � I ' �OOf�lO mm Ou100 O O m N m O N V m .„ Ill" ' "- 0 __ 1 p Woo ou'i r-vroomW 1 I.'I . 1. ft \>,ti aua fil (�; / __ O N O m ON O M m I V O v N J F-•'OQI c).-W_C) NCJ IIS ? - ,/�j �\ Nul..W-m QNmO,�N m N N N m M / � • \ CJNryNCJ • / .,7,8,20....-___m I c. ��r' ((/ �� � �� oo ou��n0000 0.V Doom...-___ f11Fr `F) u U N K -000.mmm OOYIN �`'� (', >:9� � ry � u o i•I � n � ;O unOi $ OOu7N Nrr m�2m Y f A M r O 1- «LN.r Wil: r- 0000,",__ _w,„, 000ly Nn o m m r fo I.; 22 Orl lnmmaa�o u, - ' cio..6r,-..6.-Inn U u', N e , N m N 0,m m O, f7 Z :5;A()6 � .-.-.-00m.„.,, • N 0 E N -N C')O Nm I'-4)00, n RLL0W LL r nk � 8 � S � � e � � n E - s m d -J clm m6,6 ? OI J N •N- •- ry c• ry ry n I- §7 E„' 1n J N = ) Qa. O O u CJ I- m _ w 43 0 u • - - o T `m v 80,,N . m c -....„:, , -.. , A 1 n r 0 Q I J' I �" n 0000 . I ul o' l0 a DI a, In V Of 10 r�l p 12) nnc.ii r U. -=•- ;Mt - O no i � �� �; v mwxir« Asr4 n n 0 I� no 1� In 1 1> 'M„ U 411 40, n r ; tn • 4 N .-.1y 0 J a_ NL 4 N L T dr Sperry Drilling Anticoifision Report Company: Petrotechnical Resources of Alaska Local Co-ordinate Reference: Well Walakpa 14 Plan Project: Walakpa Zone 6 TVD Reference: AS-Staked @ 53.20ft(31.7 GL-MSL/21.5 KB) Reference Site: Walakpa MD Reference: AS-Staked©53.20ft(31.7 GL-MSL/21.5 KB) Site Error: 0 00ft North Reference: True Reference Well: Walakpa 14 Plan Survey Calculation Method: Minimum Curvature Well Error: 0 0011 Output errors are at 1.00 sigma Reference Wellbore Walakpa#14 Database: Sperry EDM.16 PRD Reference Design: Walakpa#14 WP 5.1 Offset TVD Reference: Offset Datum Reference Walakpa#14 WP 5 1 Filler type: GLOBAL FILTER APPLIED All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: IJnlinuled Scan Method: Tray.Cylinder North Results Limited hy: Maximum center-center distance of 734 95ft Error Surface: Elliptical Conic Survey Tool Program Date 5/9/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 21150 500.00 Walakpa#14 WP 5.1 (Walakpa#14) SRG-GYRO-SS Conventional SRG single shots 500 00 1.174.32 Walakpa#14 WP 5.1 (Walakpa#14) MWD+SAG MWD+Sag correction 1,174 32 3,842 12 Walakpa#14 WP 5 1 (Walakpa#14) MWD+SAG MWD+Sag correction .1.842 12 5,371 03 Walakpa#14 WP 5.1 (Walakpa#14) MWD+SAG MWD+Sag correction Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (n) from Plan Offset Well-Wellbore-Design (tit (ft) (tt) (ft) Walakpa Walakpa 13 Plan-Walakpa#13-Walakpa#13 W 274.88 275.00 14.33 5.26 9.07 Pass-Major Risk 5.'0/201 12.07:40PM Page 2 of 3 COMPASS 2003.16 Build 73 Sperry Drilling Anticollision Report Company: Petrotechnical Resources of Alaska Local Co-ordinate Reference: Well Walakpa 14 Plan Project: Walakpa Zone 6 ND Reference: AS-Staked @ 53.2011(31.7 GL-MSL/21.5 KB) Reference Site: Walakpa MD Reference: AS-Staked @ 53.208(31.7 GL-MSL/21.5 KB) Site Error: 0.00ff North Reference: True Reference Well: Walakpa 14 Plan Survey Calculation Method: Minimum Curvature Well Error: 0 0011 Output errors are at 1.00 sigma Reference Wellbore Walakpa#14 Database: .Sperry EDM.16 PRD Reference Design: Walakpa#14 WP 5.1 Offset TVD Reference: Offset Datum Reference Depths are relative to AS-Staked @ 53.20ft(31.7 GL-MSL/ Coordinates are relative to:Walakpa 14 Plan Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 06 Central Meridian is-158 00" Grid Convergence at Surface is:0.90° Ladder Plot 1 1 I 000— I 1 I I • I • I I I 1 1 I I I I I 1 I ' 1 I I I _I__ __ J __ -1 _ _. __I___ _ _ ..J I I 1 C I I I I I I 1 I , 4- 600-- I I 1 C_) I 1 C) I 1 1 . 01 1 C 1 1 ' -1- - - - _ "' _ - - -I - - -- - - - -- - -- N I 1 iiii1 i1 1 I 2 1 I I a) rn 400— a) I C I QI I I 1 0 O . 1 I 1 11' I 1 I 1 C , 1 m 200-- 1 o ' 1 I I 1 J J J J -_ 1 1 • 0 J I 1 I I 1 1 0 250 500 750 1000 1250 1500 Measured Depth(250 ft/in) LEGEND 13 flan.Walakpa#13,Walakpa#13 WP 5.1 VO - 3- Walakpa#14 WP 5.1 5/9/2011 2:07:40PM Page 3 of 3 COMPASS 2003.16 Otrrld 73 Page 1 of 2 Schwartz, Guy L (DOA) From: Michael Cook(mcook@petroak.com) Sent: Monday, December 19, 2011 4:22 PM To: Schwartz, Guy L (DOA) Subject: RE: Walakpa 13 PTD 211-157 k/ALAK I'f p ( ) Importance: High p7-b Zd(— /(oo Guy, In response to your email this afternoon. Question#1 : The first BOPE test for the Shaffer 11" 5 M will have : Upper ram assembly :4" Middle ram assembly : blind/shear Drilling Spool Lower ram assembly:4" rams Question#2 : Affirmative.The 7" rams would be installed and tested prior to running the 7" 26#L80 BTC casing. Question#3 : The BOPE ram setup in Step#13 of the procedure is : Upper ram assembly :4" Middle ram assembly : blind/shear Drilling Spool Lower ram assembly:4" rams Question#4 : The drill pipe size that is programed for the 8-1/2" and 6-1/8" production hole is 4" 14.0#S-135 XT-39 drill pipe. Please let me know if you should have additional questions. Regards, Mike Cook From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, December 19, 2011 3:02 PM To: Michael Cook Subject: Walakpa 13 ( PTD 211-157) Mike, I was looking at the procedure and you don't mention which RAM size you are installing for the first BOP test I am assuming that the 7" RAMs are already installed and tested before you run casing.... Can you detail what the BOPE ram set up is in Step 13? Also what drillpipe sizes are you utilizing for the intermediate and production hole? 12/19/2011 Page 2 of 2 This question would apply to all the wells. I missed asking this earlier. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) Click here to report this email as spam. 12/19/2011 TRANSMITTAL LETTER CHECKLIST WELL NAME V./4-4-f kr 4- PTD# 2--1 / / 6 0 Development Service Exploratory Stratigraphic Test Non-Conventional Well QP FIELD: �, �Q 4---r) POOL: Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in 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 p m D v 1 mD o r0- CO T -0 3p 0 0 O , 7 0 - k r .0 N N 7 N N p _ _ c0 rmi 0 m 5eiW.CO rn °' co a) m y o 0 3 7 n N .r N g• N .r 7 m o m o m o W W () W W W CO CO W CO N N N) N) N) N) N N N) N — — (O CO -.1 0) (T A G) N — o CD 00 -.1 0) (T A W N — 0 CD 00 -.1 0) (T A CO N) --, O CO CO O) (T A CO N --s. O -.4 3 Z 000015 o v o > 0 a 0 c 7m m o C 0 ' 0 Opa 0- d a m zc 0oi0 0 -0 a 0 0 0 0 » w3m _ - 0c? v c- CD m cfD 0 N (o c * ` 0 C o O O o0o m OsN. 7F a oo m O -' d _ C 3N 0) (D -'I7 ( /1 0 ( N N f c 0 O7 0)CD O7yO. a F ID CD O (/ O aO 0. 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