Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
212-029
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, May 14, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC SI20-N04 NIKAITCHUQ SI20-N04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/14/2025 SI20-N04 50-629-23466-00-00 212-029-0 W SPT 3900 2120290 1500 690 692 692 692 200 390 390 390 4YRTST P Sully Sullivan 4/15/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NIKAITCHUQ SI20-N04 Inspection Date: Tubing OA Packer Depth 3 1725 1662 1647IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250416120614 BBL Pumped:5.1 BBL Returned:4.1 Wednesday, May 14, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.14 12:38:44 -08'00' MEMORANDUM State of Alaska ' Alaska Oil and Gas Conservation Commission Initial DATE: Wednesday, May 5, 2021 TO: Jim Regg � Supervisor 1`Lf �¢� SUBJECT: Mechanical Integrity Tests P.I. Eni US Operating Company Inc. Eni US ((L Tubing! 321 - 321 5120-1404 FROM: Guy Cook NIKAITCHUQ S120 -N04 Petroleum Inspector __ - Sre: Inspector Reviewed By: P.J. Supry -R�2— NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ S120 -N04 Insp Num: mitGDC210501113034 Rel Insp Num: API Well Number 50-629-23466-00-00 Inspector Name: Guy Cook Permit Number: 212-029-0 Inspection Date: 4/30/2021 Notes: Testing done with a triplex pump, calibrated gauges and a bleed trailer. Te4J—G�c e be -C W 0 Wednesday, May 5, 2021 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S120 -N04 - ;Type Inj W ITVD 3900 Tubing! 321 - 321 - 321 321 --- --- _ _ __ - PTD 1 2120290 Type Test SPT, Test psi' 15001- IA 327 1"Is1 1746 1736 - - . - 60 40 - o -r BBL — — — — - Pumped 1.2 BBL Returned: Ir 14OA 40 - - -I Interval 4YRTST IP/F P— Notes: Testing done with a triplex pump, calibrated gauges and a bleed trailer. Te4J—G�c e be -C W 0 Wednesday, May 5, 2021 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,December 28,2016 Jim Regg !� P.I.Supervisor IReri IZ Liv SUBJECT: Mechanical Integrity Tests L ENI US OPERATING CO INC S120-N04 FROM: Jeff Jones NIKAITCHUQ S120-N04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ S120-N04 API Well Number 50-629-23466-00-00 Inspector Name: Jeff Jones Permit Number: 212-029-0 Inspection Date: 12/10/2016 Insp Num: mitJJl61212171223 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S120-N04 Type In,l W TVD 3900 . Tubing 366 367 367 367 PTD 2120290 Type Test SPT Test psi 1500 IA 535 1656 - 1631 - 1626 Interval 14YRTST PAF P ✓ OA 520 620 • 620 620 - Notes: 1.5 barrels diesel pumped. 1 well inspected,no exceptions noted. SCANNED APR 0 5 17 Wednesday,December 28,2016 Page 1 of I 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 b direct inspection of the file. _ La -- OS9 Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed RES OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: I BY: Maria Date: /8/ VI Project Proofing BY: AIM Date: i `Li /s/ VII f Scanning Preparation x 30 =cc + a 1p =TOTAL PAGES (Count does not include cover sheet) pll va, (0 BY: Date: ( sfri ` /s/ Production Scanning Stage 1 Page Count from Scanned File:6 (Count does include cover sheet) 7 Page Count Matches Number in Scanning Preparation: IXES NO BY: AgglIP Date: Q' 1l� /s/ jIVJP qI I1 OO i 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 o • • o O O • • N o .) O X o a)co co et CO N J N } X > N ® • Q 0 X •• • N co X Trn U NIg d• Ca q T > Nco N N(oD coL > md d X • oo co ti) N ac v v v v C aa) a) rn y CD Lr cc 0 ` 0 0 0 0 0 0) • Z > o W X LY .0 6 N N N N J 0 0) c 'O 0 Z Z Z Z • •• • , d C O F. Cl) w C d O O 0 0 0f o) 12 to V) u) u) u) o o f Q W N m fa O) w C Ca O) O. (1) CO > > J 0 J J0 +LL Ln L!1- LO CO O CO C O 5 a a LL Ca a) Z O N O J 0 0 O O O N O ( JO a H H H L- W LL C J C 0 0 w 2 D D E a E a a:c CD 0 4) CD o C o o d@ O 0 0 0 0 o m ii it it i� .� ..4.2, W CO N Q. E m a) a) a) a) (") U U U O.N U U U U E N C m ? coO V 0 2 .1' 2 2 2 2 12 R U 0 O O O O u_ l0 -JCI 0 o f 0 0 0 o 12 >j pp 2 aa) a) aa)) aa)) j a a a ce v E co• ii co a E. a 'a 1- 2 1- 2 w W W w w L- 2 2 2 z• to Z C 'O N_ N_ N_ N_ N_ N N N N N N NNNNNNNN a o j 1�.O O O O O co O O O O O O O O f0 •�L N N N N N N N N N N N N N N N N N N N WN wll CO r- r r r co--- c0 00 --co --co n r N COCO co co Ce 0 tY v v :if. v v u> to to to co v v v v Ln Ln )n Ln u) W = C C C C C C C C C C C C C C C _ '� a) a) a) a) a) a) N N N a) Cl.) a) a) a) m V Z Z O 0 0. 0. 0 0 0 0 0 0 0 0 0 O O O O W Z 8r CO n O co CO CO CO Q co cn op N.CO C O coo coo coo coo CO ono oro N z N !o co V . V N N N N N CO J 0. c ? z Ow 0CO C Q t O O O O O O O co O co OV (OO COOCOO COO c O .0 N r r r r �- O N E 0 1 E a ✓ O E 0.0 U to o c o m o Q L1' z D co a I— o o)`a Z o d' 0 0 0 0 0 0 0 0 0 0 0 0 6 U J U U U U U U U U 0 U 0 0 2 CV N N O COV (n L) co = CO IJ y N O N C1') LO N N N N N N M 2 Z 0 w W Cn oI D E gI Z a) N QO a I �I v) Q z oo �_ w w > l0 2' y V) N N y Z 7 co a) a) a) a) a) d N -a -a -a N N co co a) OS CD CO CO is is co m W C E O O O O O O O O O O O O O CO co (= Z U U U U U Z Z Z Z Z (a (a la To J J J J 7 7 7 7 co a) v 'O 'O V 'O a) a) a) N a) O co) 0I o) 7 3 3 3 L) C C C C C u) co co co co 0 0 0 0 2 2 2 2 0 o Z O Z. co vvv 4I- c o v v 10 10 10 10 LO LO N Q Z t m o a in •c— 22 Q W o z (� N N N N NN N N N N S NN N N N N IX e. Q O To tV 45 w u.N W p) 2 0 U rc o 0 U U U U U E 5 Q N J - 0 O 0 0 0 ~ O. ) La:° O. a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 IZ 0 IT 3 J 0 H LY W J J J J J J J J W W W W W J J J J o - o 0 O co N O co O cn et a) • • • • • .p o Q N 0 0) a a 00. 00. a a s a a cc) U a) . o ai ai ai o ai ai csi • ce •N - • N N N c N N N N o C) N 0) O) O) O) O) O) O) O) O) a) 0) a) O) a) CA a) 0 a) a a) a a) i • 00 0 4, a a a a a a a n n cc n cr n Et a cc a cc a cc a c F? J @ 0 0 0 0 0 0 0 0 0 (fl 0 o 0 0 0 0 0 0 0 o 0 0 0 Z 5 o) o o ui ori N- ri o) ui N- ri o N- r- ri ri of of rri (ri N- N- ri co O O I,- a0 00 0) 0 0 N — — N N N N co) M 'V a C NC U) — o C (0 • C `.. 0 0) 0 0) 0) 0) 0 0 0 0 Q N w E M M M M M M 1- 1- vt 1- I' 1- Ii Ii 1- 1- 1- 1- 1. Y 1- 'T 1- os a) (a 0 0, O O O O O O O O O O O O O O O O O O O O O O O C O C a0 a0 N. C') 0) U) N. M '- N- N- r) r) 0) 0) U) N a1 'C w J U) � N- n a0 a0 0) O O N N N N M M V 7 Za) C C 0 p0)((0 0 0) 0 0) 0) 0) 0) O O O _ a) w O •— p co co co M co co co �Y V V V V V V R a V V V 7 U m C N a N N N N N N N N N N N N N N N N N N a) N N N N O 1 CF U a, co LL LL LL LL LL LL LL LL IL LL LL LL LL LL LL LL LL Il 11 11 LL LL LL co CO 0 IL (9 0 0 0 a 0 v o o v v 0 0 0 0 0 0 0 0 0 o c) 0 0 Z m a 2 2 2 o a o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a LL LL co ED_0 0 0 0 =0 v) o 0 a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 IX ►- 2 M 2 cn + w w w w w w w w w w w w w w w w w w w w w w w • t /� Er U N N N N N V d' V 7 7 V V 7 V V 'V' V V' CL O O O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W w N N N N N NNNN NNNNNNNNN N NNNNN NNNN 0 0 0 co 0 co (o co co 0 0 0 co co co (0 (o co co co cO 0 0 c0 c0 0 c0 c0 Ce aN N N N N N N N N N N N N N N N N N N N N N N O In to lf) In In M CO CO co) M M CO CO CO co) Co) CO co) co) CO M co) M co) co) co) M CO W to C C C C C —) a) a) a) a) a) C.) w Z0 O O O O z `o 0 0 0 N U) U) U) Q os 4f 7 vv v O J o as Om � 0 2 00000 O N a o co V 0 o J cv < to li H a H z TD Z N 0 0 0 0 1500 2 Nco N CO ' LONNNN COa) Q Y 0 Z O a) Q O a Z o G £ Tii o z o c M CO CO m m (0 CO CO m CO o) m CO CO m CO CO CO CO CO CO a) 3 m co co CO m CO CO m CD �v CO CD m CO m CO CO CO CO a) m O 1 0 0 0 CO0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 co ,J J J J 0 CO (6 CO (0 CO CO 0) CO (0 (0 (0 () (0 (0 CO (0 (0 (0 (0 CO CO (0 a) O 0 2 2 d' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 co > co co aJ co co N N N N N N N N N N N N N N N N N N N N N N N N I— N- n n r r N- r` r r` r` r` N- N- r` N- I` n n n N- r` r N- r N- N- n 10 U) U) U) U) U) 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N v v v v v v v v v v v v v v v v v v v v v NI- v N N N N N N N N N N N N N N N N N N N N N N N N N N N N N E. 00 w 0 NI J o NU "„ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O E• 0 ' 0 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d a 2 1J J J J w LU w LU w LU LU LU w LU LU w w w w LU w LU w w w LU LU w o e v 9 N • () to • O O o o o r` tv N o _ 9 O O O C r' O co co a > m rn () dl al al • ch �I •• LL N a. N a a 2; U U U U O O x I O v o E os _U a a) -o -o 'C 0)1 o r` co x Z N(D D O N • 'N • N • W W W a _D c0 a • a E. J1 co a N o) N m N o) I oi a M V' v C •C Q 'n a Et a ct a a �1 NI Ml I I N a .E U O O O O O W W O O O N d < Q Q O o I IYI Z ri ai ai iri ui o 0 0 0 0 =I a a d m = O M M CO CO r` U U U N d -J1 -11 -II Q 0EL co a- Q I1. 1. .1 v I v v �I �I CI Zvi =1 �I �I �I �I �I Z1 �I 0 0 0 0 0 0 0 CO CO a a Z Z Z Z m a� I Z r- U) ri of of ui rri _y )T w E 0< o 0 0 0 0 a o 0 V O O O O O O I I I L N I N N N N N I - N N Z V V V V V V a a a ~ fn V (n (n (n (n (n j f (n (n ai N ai ai ai ai N a)(n N u) ai CO hi N NI a) a) hi N a) hi hi di I.L ILL it I.L LL it 11 lL @I 11 Nl LL m1 It it O LE it N it N ii: y it -1 it it it y l U U_ U U_ U_ U U o U y U y U U 0 U U X U X U X _U Q U_ U U O 7 C C C C C C C C N C N C N C C I C Ed Ed Ed C(n C C C Z o O O O O O O OQ OOO 02 O . O • OIOOO OxO ° • Ja1 i n U O TiU • U 0 1 ..- o x o x ) N a) a) N N N NZo azo NZV N CD.,r NN NE, N N CD,T N NM NN IX 0 'W w W LU W W W W W 4 W W 4 W W 4 W W Z W.- ED Tr W- G3;7- WZ w wT- WT- 0 zv v v v v v v v v a a s a a a a v v . v EL U '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W I N N N N N N (N (N N N N N N N N N N N N N W I(0 (O CO (O (D CD O O 0 CO CO O CO CO CO CO CO CO O CO IX 0. N N N N N N N N N N N N N N N N N N N N o ,M M M M M M M M M CO M M M M M M M M M M W CI) 7 � V ZZ W Z Q to co N a ° � � O N a o 00 V 0 o -I C Q a. Ho ,_Z N O C N O c fn N CO a M Tr 1.0 N I- (0 Q Z C O N Q c a Z E 0 • 0 co Z (s @ (0 (0 CO (6 CO CO CO CO M M CO CO CO (9 (o CO (4 (o a) CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO N CO CO 03 CO CO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 oo m CO m m CO m m CO CO CO CO CO CO CO CO (v CO CO CO m To O m 0) 5 O m 0m om oa a rn rn m rn a rn 0 0 0 0 0 0 0 0 0 ' 0 0 0 0 0 0 0 0 0 0 0 0 0 O) N N N N N N N N N N N N N N N N N N N N N o O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N V V V' V .7 V .7 (N (N V (N .1 Tr Tr 7 V V R V T- N N N N N N N N N N N N N N N N (N N N N N N E c D O r-. U U U U w U U U U U 0 0 0 0 0 0 0 0 0 0 0 0 0 E O O 0 a N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0. 111.1 W W W W W W W W 111 W LU LU LU LU LU W W W LU o z o • • • • . . • • c rn • I • I • . c c c c N o cV p • X W W x N N I17 N ._: (o to a co n n a O0 a R 2I gl 2I 2I o1 173. o et to0 CO G N } 0 E E v m o o Z Z m1 ml ml m1 • o Q CO _U O co D o NI H U <n co a. a 0a a O 00 �I 2I CSI y 0 0 1 c4-ID I -j o o co 0 '.—�� U) fl. X co c c O co O 0 O O U) F �I m E I I ai I 1 iL LE LU w w w z Z hi> > o I o a'� g 2 E.� a s v1 a1 v10 0l o o E u, w d w d m._ w5. co u) c o C cd c N N min 'v, Z1 0 o w cn I c y m .N Q Q m m m m co c a) a) z �I �$ z m� to v v °° w �o w O O CD 1-.tcC O I - a12• ~I N •LL cI r- O cI O O O'.? CN O'.« O'---..N- O•5_ _ = LL Z O z -) N W y N N N N N to N to N to N M N_ N Z U) U)I W�I W U) N 0 01 U)0 () U) (/) 3 01 � N LL ( N OI � N, , 1— @ l!) U)u) hi hi p hi E hi hi m(_nO oU) to hi hi aiCC0o hiCC0 aia0o hiCC0 Q Q m�I —6 5I LE Ltd it `i it it o 5 O it 5 'O it it LL z10 it zl . LL zl0 it zl . Y Y 0 0 N it 0 0 3 c c I c aI c c c DINI 'Ea —Ic c E — o E-J E- o E-J O O E-, c Z w o X co o Q o 2 o o o Q o --) o o 17, o U)J o' I o u)J o N 1 21-1-1,., 0)1-).4 o 1 0 1 412 O co o X• o o _N 17,d1 17,N N N J1 JI N jz JI01 0 _o _o>I0 N>I> o X101 N 5a 61-1 1> N<Lu N< y n. p N d Ce 0 0 W - LI,- WZ W W W ZEC WZC4 W W W ILUZ IWZ Z�1 WZ ~I N2 N2 WZv1 WZ N O Z V V' a V V a d' -4- ,- 7 .4- 13. a ▪ � 0 0 0 000 0 000 0 0 0 0 WN N N N N N N N N N N N N N N LU co co co co co N- N- n n r; N- N a. N N N N N N N N N N N N N N N ce 0 M M M M M M M CO CO M M M M M co coW U Z Z W Z g N0 N 0 J o co a u � � o — 0 0 CV O � N o- E V 40 o °- U o J a '° C6 Het o Z N O C N O c (n N COW a v M Lc) CON V/ t] 'CC o Z O Tio Q ci o 0 m U o c E m m co U U z co co OS CO m m CO CO m m CO CO Of CO CO N N m m o CO m co co CO to to CO CO m m m co -o y m m op 0 0 0 0 0 0 0 0 0 0 0 0 0 ami ami 0 0 M To m m m m m m m m m m m m 2 2 m m 0) p_) 0) p_) 0) -0) 0) -0) 'p_) 'p_) rn_ p_) 0) 0) 0) 0 0) o 0 O 0 0 0 J J 0 0 N N N N N t() In In In In In to to to (0 CD Co N F N- N- n I N- N- N. N. N- I N- N N. N- n N- n o 0 0 0 0 0 o 0 0 0 0 o O o 0 0 0 0 N v v v v v v v v v v v v . v v v v C7.1 N N N N N N N N N N N N N N N N (N N F. co co p U .~. I• 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U L7 E a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o rn Q Zr) w w a. w w w w LU w w w w w _1 J 0 0 Z c v w OI OI o a 0 a a c t a > 8 0 0 0 Z z o CO co vi c N >- p z _ 01 01 01 DI } 0 d �I r �co � c1 c1 c1 c1 a O I it LL N N i!7 iF) Ca a7 N . a LL I I I I li cc Q E-� > CO u) I E- a .N a s CC 2 a o Z Z ( i I w 1 D a m Y. v v > > > > Q 1 Z Z coN N N o Io 0 0 0U) 0U) 0.(n 0U) O O co 0 0 _J -) N O N N N N N a) N a) N N Z I co N co ( co 0I c d'I Fn. w c W1 ui> hi ui aiZ giZ NZ NZ O O O O y - ILL0 LL LL LL - LL- LL - LL- � C O O' a a I '. w '', 0 0 0 gra ow o�v �w = 211'1 Z Z O w ' EJ E 'c 'E >d E> .E >LL .c> Z :2 ', 0i1 0 0 o=Ic- o=I p=I,- p=I E o 2'I r CI I— V In I,,CD N� N N 15 � � N� 1-411.•-- �.1, a-Vi� 0 'd U- O co IX c• W Z W W W Z O W Z W Z O W Z - O d `a) 0 it Z O V V V V V C p.r+ � 'N Nco 0.. -4- ▪ c..) •-• 000 0 o N0 eye 0 W N N N N N N N �0 7 0 N N N r-- r-- r-- r-- .C.F.) co Z O) Ce0 M M CO CO CO M M CD @ W N N it E N W v N N O W N co v w y - co E o E as Z o v v CD Ui :? c Q .. o0) o p” _ in _i a c O "6 2 U U O. /). a) 2 vo C) r 0 O • N o- E o cc U Ti 0 Q o 0 } e Q O O O V otoa m 0 o M (NJ E I— Z• N _ O (13 C N O Ca - z' c m o v «' a`ni E CO a o I- E 'M^ V a) in 0 c m C _O Q f0 O N E a) c U a Q C a 47-1 g m 0 Z ov > co z a7 a7 co a7 a) a) co N N m COCO 0 0 0 0 0 0 0 C Z N N co To To To To To To To o 0 0 0 0 0 0 0 € o rc 0 0 N > co N. CO CO N. N. N C LU> C d o ✓ N N N N N N N Cr)- Cr) W O O N N a 0 c c CC O c c I- ui £ E a ( 00' O ` OQ 0 u, cG Z Q m p d o 2o O D U .£ 0 a "O O 0 a N Cn 0 o a`) 00 0 0 0 0 0 0 d LL o o a) 0 o .) °� Q a 2 W W W W W W W 3 0 a 0 0 0 CL o w Oi co a) c a) -0 O 0 " -O T-_- O cv c M w E o o w_ 2 > o U a C E ° Q cco 0 V) N co t7p ---�ppp°' co 0 O Q° CD O to co . .N Q` C co U O (0 ° C 0, Q a).a co .••• m 7 Q U c a) 0 0 co c oIs— U o Q C U 7 v m T N N Z a m o ` '°O N E C •.'O co e d v• N -o U o = < oNE cI) - o-0m- dO.as : oa) a° ° c �i -Cu c m m 7 Z v 0 m o N N .L•, O O d t N 7 3.7 L oi5 H CO ° .-. 0_ N ° rrs °co a'0 co z C F Z 9 N .B t °o al • 0 ° U ° N O y .� �0"0 a) E co al 0 U.- cn a O C > 01 Q C O O o t o O O L N >._'O o 0 0 Q ° O 0 O 1.6 C N °. N N cA F- °•y o O O N a s O d'O N m- w > w °'x E o o_ o ��O` U c w-O o U O.- C O z a m U o a o .L..L. 0 CO 0 co.co p a co 0 7 @ ° C L Y €y 5 O Q *.1-; ° 'p c 0 C C_v m c c0 0-a e. 7 U 0 7 m t zE oco yon y�� E cno ° Ev) c°l° cicnm om y N o N p m - U N L_ 3 o 0 �i 7 0 a U 7 7 7 0 V N 43C V 7 N C.0 o"N •C 0 co.N m a o °11j 0)U -0 a) a)"0 L m - .as QO oLE NoN a?U!� ° ° >Z N .m, C ° C ° �. yU .O I . O U) 70 .� co o 0 c ° ° OU o >mU o�� CO o a`°i >� Lo 7 ° rec)U E mQ Ear - m 0o d c 0- c IX V c w� rn m aTi 0 c �p o L 0 °a c E a m 15- c m O O ° v mm ° o c Z c o QU a� Z.1— 7 - m - 0 z Y M O c 7 co L'0 Q) .L.. ° m :_�H N fA C Zi CES � ^O« m N^.N-. 3 N Z N f0 U° ° E L 0- w w cu N M O v H en Y >Q. W w0 U N m-E •c CcU U E co E 3 :E Z Uma `o f6 E c(i o M aTo o Z N co o) a _ = o 0 CZ CO U) U 'F.) d l0 ° ° N L 0 0 ° f0 .7� O U 0 N> .L° COM @ o LO L. c.� 'j U z z � 2 z CQ pQ-w co wNOO h- 0) cc) mCmc.N0 Q >Q, Om0 ccyv lL cn p Z .2 ° irj 0-c W > 5 cO c Q o m m > y m CD-0 `) ° 7 Z Q c) O�.g_ c c Z Qua Q= � � 3 V 2 >() � N3 �� ° 0 � N ° -ac4 w D o c O m v o ch : � c ca , .... o000 ,- y�a E•c m U m y ��� Q 7 N °p a In y= p ° o O co m L N E ° U ° CO,moo c0.• N CO Ja co o -PLL E ca Qg ° •�. am m e °<n `'�M e' m o`�v U cv a 7 m O. O �o.• o w o ° a °. mo E O E m o E oo > o ccr° L a)y 0 cu ° w o e > '0_� O U v° Q O t° `O m Z Lao m m C V 0 7 L 0) _ .c N m. to 7 N ° C -0- m w o 2)0 0 E 7 6 V N (0 U) a) m V" o 2 m m QC U u) E c..)-0 ma a;a °a-0H -o I la-0 O �_N 2 x a� -c ca O D' a) E a)-2 ° go x a)a v c 7 °2ch ° •5 ° m o E N ° 2 QUQ c mm � E ° ,1 76 a ° 000 °) "aIUcao a) �U Ncrnc) :0 I' E ° -0Ow o Ui ti rnwQ c o . om > O L m Q fn d• 0.'o y T _ °_ 7= Q •C C o C N .... a)'O O C O 7.) o0 V U �j� w •• E@ --- ,„ 0 U.-Uo 0 m oc‘i– $2 E 30 c ,- °- 0 0.,-0 ,,..,7.. a� • o LL = m U O7 u) (n z m a) (..) C 7 N co cn O C ° v J rnp ° UO m•. 0 Q °Q �!�q o E >U .. 0))rno) 0 Tc N > a'c`o a) Q Ea) mo W > CI O ° c c m o T° m m mac c v°:E o )< a a) O U 7 N ° C C N N a_cn1-Ucn 0 _ o < 3 a aaac) < CRN a) E Ew .To..=E o co Li.To U U a __�r� a. co a I— o Z N O 2 N N W ▪ ,_ V ° co N o co Q C Z O r ° Q C Z E o G U m Z a a) m o • co DCO 0 ° CO rt0 C j c N I— O C N m N a E 0 F.▪ m 'U o ( 'IZ U a) c7 E a 0 'I- a. o _ o ° m NN o T O o t0 a) LL O 0 ` C lI C t0 N o N o O n. W U-p N Q 01 U -c O V Q 7 c co C T tN0 E Z i• �° a) O 'b o in ° 0 �0O. y : z w C N T u)a F- N U ... a7 •._ Z E �' o •-• a) NEal y C Q 0) E a) N >,• .(0 y rn3c Wa) ° o a•• 1cno • O u) Uw < O a CO 'Z 0 O — ° y CD E £ m >- 2,_ .9E•A a) u) Di7o a.0 7 co Z 47.E > o �ZN .o ca 0 co v �' Z = 'o`°U u)-o O w 3 O y E Q a7 a) O N Cc) O Z N H a 0 o co-0o0 °.N c ai ° 3 N• O° C ca E i° E N O W W E N w c�o To 'm 5 o. E E .N Ce 0- O ti co W N - Off. N E Z moo t0 c >.�+ o 0 V Z Z U U U w ' C a)' y O U U a) C C O O N a) N a) C Z W O d LL 4- O m-° O co N O 'I. 11 Q n `ui �° Z ON Q E O• a co TO To d�(NI E ° a O- �° Z a O C N C O) D N -U E -O O) w a7 N 0 0 u) 0 C N C 0) J CO •O u) O as l0 D.0 N LL m N a) M U a) O u) O Lo 1 Cl. v) in QUYM w E ac c o.9 �`` .0 C)' . o)o -' o <0-co N >,u) u)� co O.Nt C a) :°Ol0 C a) Nr C o 0)m f° �� v°'iL ° _ 0 o o� V E ° 0)(0 CO C a� o0 al co a) m aa) a) -- E T co .cg�M ?, o —°oO( OG c '°fin C7 w-ce - 3 " O o 0� 2 E a) c v- r` N �° 7 7 U' m D n N•c U W as `� ° m t_r` c I Q -° c m �� m 0 > O C7 - o)o .0 m cocT 2 c m 2 > >cfl .§W C o•- a) C7 -_ rn 00 V U co Tw w aOww U3t 7 .. o :a a) ° u_ (° a)0_1-u E aw m uiw gO2rn o _c JJ o F- co a7 U fl \kJ D M N . u! ,o a) "O'0 'p 4)o E � D� @ aN U ornrn o mo moT Q O p U 7 N N c V @@ T N O a) N i LL<nE Ucn D Fco MWD- E E �2 2aQ ED a a r O Z N O C N O (� N N COv_ a .1 o M = N U) N Q C Z O a) Q 0 o E CI IIS Zo E U co Z -o _ a) o w • co o- ao a) co LL. O 0 0 c Of > — N I- 0 c N a) e- N . E o E o 0 D o o NZ U U .. m C7 E 0 D a O m• 9 CD- 0 N O -- to O 10N ra N >- Q o> 0_ >; 06 In F C 2 Z IV U co Z co o I— 0 LL 0 • L) O Z L Om 2 W a Et 0 U) W n V ZZ W Z 0 ▪ . t6 Co d7 _I o 0 a. co -J- O C e-1. a .,.,.'": U4 o o0 J 00 Q0 0 P. r Z 44, N1 5� G N O\ /� N N LO D Cl) I• a '.. V ~ 0 a o a S Q Z E CI iii ov co . 3 0. o vM rn o m N N ✓ N N 5 N rt C r- H t) .2 C C U p, L, VIII E II E O • o a 2 1 C) 1 <1 RECEIVED MAR 2 7 2014 Schiumberger AOGCC Transmittal#: 6690 Drilling&Measurements MWD/LWD Log Product Delivery DTA�QGGED :x /2014 M K BENDER Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No S120-N4/S120-N4PH Date Dispatched: 26-Mar-14 Installation/Rig Doyon 15 Dispatched By: Stephanie Pacillo Data No Of Prints No of CDs Survey Report VISION Resistivity,EcoScope Service LWD LOGS N/A 2 in MD 2inTVD 5 in MD 5inTVD Survey *REVISED* 1+1 ASP FINAL SURVEY X EOW CD *REVISED' 1+1 ASCII DATA X SURVEY X DLIS DATA X LOG DATA X Received By: 044,077 Please sign and return one copy to: c D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 hecheto@slb.com Hector Echeto Fax:907-561-8317 r Bender, Makana K (DOA) From: Stephanie Pacillo <SPacillo@slb.com> Sent: Friday, March 28, 2014 2:48 PM To: Bender, Makana K (DOA) Subject: RE: missing logs - SI20-N4 &SI20-N4PH Hi Makana, I should have enclosed an explanation, my apologies. There was an email request generated from AOGCC this week regarding the missing survey reports for both wells.There were no changes to the logs and therefore I created just a CD to have an electronic copy of the survey as well as the hard copy. I'll be sure to include some sort of explanation should something like this arise again. Let me know if you have any further questions I can answer. Happy Friday, Stephanie Pacillo From: Bender, Makana K(DOA) [mailto:makana.benderOalaska.gov] Sent: Friday, March 28, 2014 1:28 PM To: Stephanie Pacillo Subject: missing logs - SI20-N4 &SI20-N4PH Stephanie— Got a delivery in late yesterday that I'm looking at now—most of the data is fine, but 2 wells (5120-N4 &S120-N4PH) have physical logs listed on their transmittals that are not present in the delivery. Wanted to know if perhaps there were perhaps multiple shipments, if the logs will be in another delivery? Let me know what if any additional information you need to look up the shipping info. Happy Friday! _ Makana K Bender Natural Resources Technician 11 3 I l de",sk.::.`f z] a. Ga ri (A?sse Tv atI(.:n ..,-$m ' issiOTl. 1 ' 2A2- 0Z-� 2i1O''15 RECEIVED MAR 2 7 2014 AOGCC ScItlemlnrier eni S120-N4 ASP Final Survey Report (Def Survey) 'Report Date: May 04,2012-09:32 AM Survey/DLS Computation: Minimum Curvature/Lubinekl Client: Ell Petroleum Vertical Section Azimuth: 315.000•(True North) Field: Nlketehuq Vertical Section Origin: 0.000 0.0000 R Structure/Slot: Spy Island/SP20 TVD Reference Datum: Rotary Table Well: 5120414 TVD Reference Elevation: 53.9908 above MSL Borehole: S120.N4 Ground Elevation: 13.1000 above MSL APl4: 50-629-23466-00 Magnetic Declination: 20.812• Survey Name: 5120-N4 Total Field Strength: 57648.627 nT Survey Date: April 25,2012 Magnetic Dip Angle: 81.074• Tort/AHD/501/ERD Ratio: 334.929°/10033.7160/7.035/2.532 Declination Date: April 01,2012 Coordinate Reference System: NAD27 Alaska State Plane,Zone 04,U5 Feet Magnetic Declination Model: BGGM 2011 Location Lat/Long: N 70.33'27.9041r,W 149°54'18.6922r North Reference: True North Location Grid N/E Y/X: N 6053638.060 1055.5 511559.210(WS Grid Convergence Used: 0.000• CRS Grid Convergence Angle: 0.08940154• Total Corr Mag North-sTrue North: 20.612• Grid Scale Factor: 0.99990015 Local Coord Referenced To: Wall Heed CommentsMD Incl Aare True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Eaating Latitude Longitude 101 r) PI l5) Ire (OI 181 I5) 721 101 r/1005) MUS) MUM r) rl RTE 0.00 0.00 0.00 53.99 0.00 0.00 0.00 0.00 000 0.00 N/A 8053636.06 511559.21 70.55775114 -149.90519230 93.50 0.30 348.22 39.51 93.50 0.20 0.24 0.24 0.24 -0.05 0.32 6053636.30 511559.16 70.55775180 -149.90519271 187.20 1.82 82.27 133.20 187.19 -0.60 1.57 1.02 -1.01 -0.16 225 6053635.05 511559.05 70.55774839 -149.90519360 283.30 4.54 72.37 229.14 283.13 4.66 6.89 6.31 5.30 0.29 2.88 605362976 511559.51 70.55773393 -149.90518996 377.40 8.97 66.50 322.56 376.55 -13.88 17.95 17.31 -17.13 2.49 4.76 6053618.93 511561.73 70.55770434 -149.90517185 469.40 13.76 80.44 412.74 466.73 -29.88 36.05 35.31 -34.43 7.83 536 6053501.65 511567.10 70.55765709 -149.90512805 563.30 16.92 56.40 50328 557.27 -52.70 60.88 59.95 57.48 17.05 3.55 605357861 511576.34 70.55759412 -149.90505250 654.80 17.16 53.80 590.58 644.57 -77.82 87.63 86.50 51.74 28.31 0.87 6053554.37 511587.65 70.55752785 -149.90496011 748.90 17.15 56.39 680.68 734.67 -103.93 115.44 114.20 -106.96 40.02 0.81 6053529.17 511599.40 70.55745895 -149.90486408 773.03 16.54 56.60 703.78 757.77 -110.44 122.44 121.19 -113.37 42.81 2.54 6053522.77 511602.19 70.55744143 -149.90484120 868.41 16.66 59.77 795.18 849.17 -135.49 149.69 148.44 -138.68 52.94 0.96 6053497.48 511612.36 70.5737230 -14990475817 962.12 16.89 58.03 884.90 938.89 -160.23 176.75 175.50 -163.92 62.68 0.58 6053472.25 511622.14 70.55730334 -14990467827 1054.75 18.48 54.64 973.15 1027.14 -186.43 204.87 203.56 -189.85 74.00 203 6053446.54 511633.49 70.55723304 -149.90458546 1147.99 22.44 54.55 1060.50 1114.49 -217.11 237.44 236.08 -219.07 87.97 4.27 6053417.15 511647.51 70.55715267 -149.90447086 1241.84 23.87 56.26 1146.79 1200.78 -251.69 274.34 272.94 -252.63 103.31 1.68 6053383.62 511662.91 70.55706099 -149.90434503 1335.22 27.10 55.89 1231.07 1285.06 -289.18 314.51 313.10 -269.35 119.61 3.46 6053346.93 511679.26 70.55696068 -149.90421137 1427.91 28.48 56.92 1313.07 1367.06 -329.41 357.73 356.30 428.95 136.90 1.58 8053307.35 511696.61 70.55685249 -149.90406960 1522.14 26.60 80.94 1395.82 1449.81 -370.59 40279 401.34 471.00 153.10 2.05 8053265.34 511712.87 70.55673763 -149.90393682 1615.42 27.46 60.00 1478.13 1532.12 -410.21 446.68 445.18 -412.37 167.76 1.39 6053224.00 511727.60 70.55662462 -149.90381655 1708.56 25.55 57.73 1561.48 1615.47 -448.20 488.24 486.74 -451.14 182.72 2.32 6053185.25 511742.61 70.55651870 -149.90369389 1802.73 22.48 55.37 1647.49 1701.48 -483.82 528.56 525.04 486.30 197.92 3.42 8053150.11 511757.87 70.55642263 -149.90356923 1695.07 21.58 52.14 1733.09 1787.08 -516.60 561.19 559.58 -517.37 213.22 1.63 6053119.08 511773.21 70.55633777 -149.90344382 1988.54 2019 47.38 1820.28 1874.27 -549.16 594.87 592.96 546.47 230.15 2.07 8053090.00 511790.19 70.55625825 -149.90330495 2082.38 19.82 50.07 1908.37 1962.36 -580.56 827.20 824.95 574.09 246.95 1.51 6053062.41 511807.03 70.55618260 -149.90316720 2175.53 14.84 48.37 1997.36 2051.35 -607.13 654.82 652.16 597.68 260.93 5.37 6053038.85 511821.05 70.55611835 -149.90305252 • 2268.90 13.31 48.05 2087.97 2141.96 -629.16 677.17 674.43 518.65 273.13 1.55 6053019.90 511833.27 70.55606655 -149.90285256 2362.47 7.97 47.86 2179.90 2233.89 -646.07 694.44 691.47 531.08 282.60 5.72 6053005.48 511842.76 70.55602711 -149.90287488 2455.07 4.08 48.62 2271.97 2325.86 -655.54 704.16 701.10 539.34 287.73 4.20 8052997.24 511847.91 70.55600456 -149.90283280 2548.72 2.65 36.73 2365.45 2419.44 -660.94 709.83 706.45 -643.78 290.95 1.69 6052992.82 511851.13 70.55599249 -149.90280640 2576.60 2.26 34.28 2393.31 2447.30 -682.13 710.83 707.57 -644.81 291.79 1.45 6052991.97 511851.97 70.55599018 -149.90279955 13.3007 Cesing 2636.00 1.81 99.10 2452.87 2506.66 -864.13 712.83 708.43 -646.00 293.23 1.10 6052990.59 511853.42 70.55598837 -149.90278769 Tie-In Survey 2673.89 • 1.19 31.69 2490.55 2544.54 -665.06 713.76 710.28 548.82 293.91 1.10 6052989.97 511854.10 7055598466 -149.90278210 2731.85 0.58 25.31 2548.51 2602.50 -665.94 714.84 711.06 -047.18 294.59 1.10 6052989.40 511854.78 70.55598312 -149.90277652 2824.28 5.39 324.76 2640.81 2694.80 -662.10 718.66 707.20 543.90 292.46 8.41 6052992.89 511852.64 70.55599210 -149.90279405 2922.82 12.48 311.35 2738.10 2792.09 -846.89 733.89 692.94 533.07 281.78 7.45 6053003.50 511841.95 70.55602169 -149.90288161 3011.76 14.99 316.79 2824.50 2878.49 -625.80 754.99 673.39 -618.33 26669 3.17 6053016.21 511826.83 70.55606194 -149.90300537 3100.52 19.83 314.82 2909.17 2963.16 -599.28 781.54 646.68 -599.34 248.14 5.49 6053037.17 511808.26 70.55611382 -149.90315747 3198.21 24.02 315.39 2999.77 3053.76 -562.79 818.01 815.11 573.50 222.41 4.29 6053062.97 511782.49 70.55618443 -149.90336845 3291.50 28.32 311.94 3083.48 3137.47 -521.69 859.13 578.20 545.18 19260 4.89 6053091.24 511752.64 70.55628180 -149.90361290 3384.91 32.51 310.21 3164.02 3218.01 -47452 906.41 537.56 -514.15 156.93 4.58 6053122.21 511716.93 70.55634657 -149.90390538 3478.39 35.05 307.11 3241.72 3295.71 -422.89 958.37 495.57 481.73 116.33 3.26 6053154.56 511676.28 70.55643514 -149.90423831 3571.24 36.44 303.86 3317.08 3371.07 369.42 1012.60 456.02 450.27 72.16 2.53 6053185.95 511632.07 70.55652107 -149.90460050 3662.33 39.68 300.38 3388.80 3442.79 314.72 1068.74 421.20 420.48 2459 426 6053215.66 511584.46 7055660245 -149.90499061 3758.02 43.19 300.18 3460.53 3514.52 -253.48 1132.06 389.72 388.56 30.08 3.67 6053247.49 511529.74 70.55668966 -149.90543901 3852.23 48.83 297.75 3527.13 3581.12 -189.48 1198.67 367.14 356.34 -88.38 4.27 6053279.62 511471.39 70.55677767 -149.90591709 Drilling Office 2.5.1100.0 Nikaitchuq\Spy Islanc8S120-N4\S120-N41SI20-N4 3/13/2014 3:18 PM Page 1 of 3 • Comments IVO Inel Axlm True TVDSS TVD VSEC AND Closure NS EW DLS Northing Eaabp Latitude Longitude IRI 1'1 P1 (6) IRI RD (6) IRI (6) (ft) 0(1o06) (MS) (RUst 0) PI 3945.43 49.66 299.75 3589.19 3843.18 -122.73 1268.18 355.74 -322.66 -149.31 3.43 6053312.98 511410.42 70.55886907 -149.90641877 4038.53 53.29 301.34 3647.17 3701.16 52.21 1341.01 355.90 -285.85 -212.01 4.12 6053349.90 511347.86 70.55697023 -149.90693097 413173 57.11 301.35 3700.35 3754.34 2214 1417.52 370.77 -248.05 -277.36 4.10 6053389.60 511282.26 70.55707896 -149.90746690 4224.61 62.02 301.40 3747.39 3801.38 99.95 1497.58 401.60 -204.37 -345.71 5.29 8053431.17 511213.85 70.55719282 -149.90802745 4318.57 67.02 302.43 3787.80 3841.79 182.54 1582.37 447.11 -159.53 417.68 5.41 6053475.90 511141.82 70.55731530 -149.90861765 4417.11 72.01 304.52 3822.28 3876.27 272.96 1874.65 506.42 -108.61 -494.63 5.44 6053526.69 511064.80 70.55745439 -149.90924876 4504.69 78.80 305.35 3844.33 3898.32 356.36 175936 587.28 -00.10 584.07 7.81 6053575.09 510995.29 70.55758691 -149.90981522 4598.24 83.82 305.11 3858.46 391245 447.47 1851.80 639.62 -677 -839.58 5.37 6053528.29 510919.70 70.55773257 -149.91043756 4691.72 84.59 304.22 3867.90 3921.89 538.96 1944.60 71756 46.13 -716.07 1.26 605358106 510843.14 70.55787706 -14991106492 4785.91 84.68 305.42 3876.71 3930.70 631.26 2038.58 799.30 99.67 -793.06 1.27 6053734.48 510768.08 70.55802331 -149.91169633 4885.77 85.66 306.31 3885.12 3939.11 729.50 2138.09 887.86 157.97 -873.70 1.32 6053792.65 510685.36 7055818255 -149.91235771 9-5/8'Casing 4937.50 87.02 308.17 3888.42 3942.41 780.85 2189.71 934.15 189.21 -914.79 4.45 6053823.82 510844.22 70.55826788 -149.91269476 4970.51 8769 309.36 3889.89 3943.88 813.43 2222.69 963.63 209.86 -940.50 4.45 6053844.43 510618.48 70.55832428 -149.91290566 5063.64 91.56 311.07 389033 3044.32 908.21 2315.80 1047.01 269.97 -1011.60 4.35 6053904.43 510547.29 70.55848848 -149.91348884 5157.30 91.07 311.06 388818 3942.17 999.63 2409.43 1131.83 331.48 -1082.20 0.52 6053985.82 510476.60 70.55885649 -149.91406791 5250.97 90.55 312.16 3886.88 3940.85 1093.12 2503.09 1217.83 393.68 -1152.23 1.30 5054027.90 510406.49 70.55882637 -149.91484232 5343.53 90.33 311.44 3886.15 3940.14 1185.53 2595.65 1303.36 455.37 -1221.23 0.81 8054089.48 510337.40 70.55899487 -149.91520829 5437.71 89.72 313.69 3886.11 3940.10 1279.62 2689.83 1391.06 519.07 -1290.59 2.48 6054153.07 510267.95 70.55916886 -149.91577725 5531.18 89.69 316.78 3886.59 394058 137308 2783.30 1477.34 585.43 -1356.40 3.31 5054219.31 510202.04 70.55935010 -149.91631712 5624.84 89.97 317.88 3886.87 3940.86 1466.66 2876.96 1583.39 654.28 -1419.89 1.19 6054288.06 510138.44 70.55953816 -149.91683798 5718.05 90.91 317.55 3888.15 3940.14 1559.76 2970.17 164961 723.22 -1482.61 1.08 6054356.90 510075.82 70.55972647 -149.91735252 5812.06 89.59 313.88 3885.74 3939.73 1553.75 3064.17 1738.43 790.39 -1548.36 4.35 8054423.96 510009.78 70.55990994 -149.91789185 5904.74 89.56 314.88 3886.43 3940.42 1746.42 3155.85 1827.15 855.10 -1614.71 130 6054488.55 509943.34 70.66008685 -149.91843517 5997.99 90.90 317.31 3888.05 3940.04 1839.64 3250.10 1915.95 922.28 -1679.37 298 8054555.62 509878.58 70.56027014 -149.91896662 6091.52 90.19 316.48 3885.16 3939.15 1933.11 3343.62 2005.05 990.56 -1743.27 1.17 6054823.80 509814.57 70.56045663 -149.91949094 6183.19 90.87 317.11 3884.32 3938.31 2024.73 3435.29 2092.79 1057.37 -1806.03 1.01 6054690.51 509751.72 70.56063912 -149.92000580 6278.74 86.86 316.31 388621 3940.20 2120.20 3530.80 218460 1126.90 -1871.52 4.28 874759.92 509686.12 70.56082900 -149.92054312 6371.41 85.61 315.69 3892.29 3946.28 2212.7 362327 227407 1193.41 -1935.75 1.51 874825.33 509621.79 70.56101067 -149.92107012 6465.40 88.83 316.34 3896.85 3950.84 2306.51 3717.14 2355.11 1260.95 -2000.94 3.49 6054893.76 509556.51 70.56119513 -149.92160496 6557.81 90.49 317.72 3897.40 3951.69 2398.85 3809.54 2454.56 1328.58 -2063.92 2.34 6054961.27 509493.43 70.56137979 -149.92212173 6651.67 90.99 317.52 3896.19 3950.18 2492.60 390339 2545.69 1397.89 -2127.18 0.57 6055030.49 509430.06 70.58156913 -149.92264079 6744.53 89.64 316.7 389568 3949.67 2585.41 3996.25 2635.78 1465.56 -2190.76 2.15 6055098.7 509366.38 70.58175394 -149.92316248 883825 89.99 315.28 3895.98 3949.97 2679.13 4089.97 2727.56 1532.60 -2256.26 0.90 6055164.98 509300.79 70.56193702 -149.92389989 6931.7 89.81 315.51 3896.14 3950.13 2771.87 4182.72 2818.59 1598.63 -2321.39 0.31 6055230.90 509235.56 70.56211736 -149.92423431 7024.89 90.04 315.28 3896.26 3950.25 2865.76 4276.61 2910.86 1665.48 -2387.32 0.35 6055297.64 509169.54 70.56229991 -149.82477531 7118.04 88.61 312.34 3897.36 395135 2958.87 4369.75 3002.90 1729.95 -2454.53 3.51 6055362.00 509102.24 70.58247596 -149.92532678 7210.97 89.20 311.98 3899.14 3953.13 3051.87 4462.66 309515 1792.31 -252340 0.74 6055424.25 509033.27 70.5626467 -149.92589192 7304.09 88.98 313.68 397.62 3954.61 3144.71 4555.77 3187.49 1855.61 -2591.68 1.84 6055487.43 508984.90 70.56281913 -149.92645221 7398.13 88.93 314.46 3902.33 3856.32 3238.72 4649.79 3280.52 1921.00 -2659.24 0.83 6055552.72 508897.25 70.56299772 -149.92700657 7491.17 88.90 313.26 3904.09 3958.7 3331.72 474282 337266 1985.46 -2728.31 1.29 6055817.7 508830.08 7056317373 -149.92755697 7581.84 88.63 313.95 3906.05 3960.04 3422.34 4833.47 346254 2047.98 -2791.95 0.82 6055679.47 508764.35 70.56334446 -149.92809582 7678.48 88.98 314.77 3908.06 3962.05 3518.98 4930.09 3558.22 2115.53 -2661.03 0.92 6055746.91 506695.18 7056352893 -149.92866250 7771.04 92.50 315.7 3906.87 3980.86 3611.49 5022.62 3649.78 2180.88 -2926.55 3.82 6055812.15 508829.56 70.56370738 -149.92920020 7884.17 93.96 315.20 3901.82 3955.61 3704.47 5115.60 3741.78 2246.78 -2992.13 1.57 675877.94 508563.88 70.56388735 -149.92973845 7958.07 94.97 317.63 3894.31 3948.30 3798.05 5209.22 3834.13 2314.59 3056.67 2.80 6055945.64 508499.25 70.56407251 -149.93026811 870.89 9207 315.64 368861 3942.60 3890.64 5301.85 3925.52 2381.93 -312027 3.79 876012.87 508435.54 70.56425640 -149.93079014 8144.21 9276 316.09 3884.68 3938.67 3983.87 5395.09 4017.75 2448.84 3185.20 0.88 678079.88 508370.52 70.55443913 -149.93132300 8237.49 91.86 318.21 3880.92 3934.91 4077.05 548829 4109.93 251506 3249.77 0.97 6056146.79 50837.85 7056462267 -149.93185295 833136 94.55 317.23 3875.67 3929.66 4170.72 5582.01 4202.52 2584.28 3314.01 3.06 6056214.90 508241.50 70.56450897 -149.93238028 8424.42 94.14 316.00 386862 3922.61 4263.48 5674.80 4294.28 2651.72 -337775 139 6058282.23 508177.67 7056499311 -149.93290343 8518.42 91.79 314.57 3863.78 3917.75 435734 5768.67 4387.43 2718.42 -3443.80 2.93 6056348.82 508111.53 70.58517524 -149.93344550 561574 91.29 314.69 386128 3915.27 4449.63 5860.95 4479.16 2783.25 -350947 0.56 6056413.55 508045.76 70.56535228 -149.93398457 8704.35 92.89 315.86 3857.86 3911.85 4543.17 5954.50 4572.05 2849.71 -357530 2.12 6058479.90 507979.83 70.56553375 -149.93452489 8797.33 90.12 315.23 385542 3909.41 4636.10 6047.44 4664.31 2916.05 -364039 3.06 6058548.13 507914.65 70.56571489 -149.93505916 889142 90.08 315.38 385526 3909.25 4730.19 6141.53 475779 2982.94 3706.56 0.16 6056612.91 507848.37 70.56589752 -149.93560237 898424 89.78 314.88 3855.37 3909.36 4823.01 6234.35 4850.7 3048.72 3772.05 0.63 676678.58 507782.79 70.58607714 -149.93613990 9077.86 91.04 315.86 385470 3908.69 4916.42 6327.78 4942.89 3115.20 -383768 1.71 6056744.95 507717.07 70.56625866 -149.93657861 9170.97 90.60 315.32 3853.37 3907.36 5009.72 6421.7 5035.60 3181.85 -390297 0.75 8056811.49 507851.68 70.56644064 -149.93721458 9264.14 88.02 312.54 3854.49 3908.48 5102.85 6514.22 5128.43 3246.47 3970.05 4.07 6056876.00 507584.51 70.5666177 -149.9377724 9357.86 89.57 312.56 3856.46 3910.45 5196.26 6607.71 5221.78 3309.69 -4038.93 1.69 6056939.11 507515.54 70.56678970 -149.93833065 9450.97 91.54 313.47 3855.55 397.54 5289.50 6701.01 5314.89 3373.34 -4107.14 2.33 6057002.7 50744723 70.56698347 -149.93889065 9544.67 94.02 314.59 3851.01 3905.00 5383.07 6794.60 5408.17 3438.38 4174.43 290 6057067.58 507379.85 70.5671417 -149.93944300 9637.68 93.02 313.99 3845.30 3899.29 547590 6887.43 5500.68 3503.21 -4240.88 1.25 677132.29 507313.30 70.56731804 -149.93998853 9731.32 92.13 311.42 3841.09 3895.7 5569.36 6980.97 559408 3566.65 -4309.61 2.90 6057195.82 507244.47 70.56749124 -149.94055281 9824.55 92.71 312.56 3837.15 3891.14 5662.37 707412 5687.15 3628.96 4378.85 1.37 677257.81 507175.15 70.58768138 -149.94112116 9917.86 92.70 313.62 3832.75 3886.74 5755.53 716733 5780.19 3692.63 -4446.91 113 677321.37 507107.00 70.56783519 -149.94167998 10011.28 91.28 31228 3829.50 388349 5848.83 7280.69 5873.40 375524 4515.25 2.09 6057384.87 507038.57 70.56800885 -14994224097 Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S120-N4\S120-N4\S120-N4 3/13/2014 3:18 PM Page 2 of 3 Covenants MI Intl A2kn True TVDSS TVD VSEC AHD Closure NS EW DLS Northing EsatN9 Latitude Longitude IRI PI 0) IRI (R1 (RI IRI Int (R) (R) 0/100ft) MUS) (RUST PI PI 10105.31 91.07 311.12 3827.58 3881.57 5942.88 7354.70 5967.35 3815.78 -4585.44 1.25 6057447.29 506968.29 70.56817957 -149.94281722 10198.45 89.49 308.82 3827.12 3881.11 6035.45 744783 6060.48 3878.61 -4656.81 3.00 6057507.00 506896.83 70.56834289 -149.94340316 10291.46 90.05 307.32 3827.48 3881.48 6127.78 754084 6153.45 3935.96 -4730.03 1.72 6057584.23 506823.53 70.58849943 -149.94400426 10384.48 90.13 308.96 3827.35 3881.34 6220.13 7633.86 6246.43 3993.41 -4803.18 1.79 6057621.57 506750.30 70.56865627 -149.94460478 10478.16 90.00 307.71 3827.24 3881.23 8313.18 7727.54 6340.08 4051.53 -4876.85 1.36 6057679.57 506676.74 70.58881490 -149.94520795 10571.68 84.64 305.73 3831.45 3885.44 8405.59 7820.94 6433.34 4107.37 -4951.50 5.91 605773528 508601.81 70.56896732 -149.94582249 10684.37 86.68 304.18 3838.30 3892.29 6496.60 7913.37 6525.46 4180.33 5027.26 2.59 6057788.11 508525.98 70.56911184 -149.94644441 10757.21 89.30 305.12 3841.56 389555 6587.87 8006.14 6617.89 4213.08 -5103.58 3.00 6057840.74 506449.58 70.56925580 -149.94707096 10851.85 90.13 307.03 384203 389602 6881.36 5100.78 6712.36 4268.80 5160.07 220 6057898.34 506373.02 70.56940788 -149.94769892 10945.42 90.90 308.18 3841.19 3895.18 6774.14 8194.35 6805.87 4325.89 -5254.19 1.48 8057953.31 506298.81 70.56958371 -149.94830750 11038.12 91.38 310.05 3839.34 389333 6866.33 8287.03 6898.55 4384.36 -5326.10 208 6058011.66 506226.82 70.56972330 -149.94889790 11131.17 93.15 311.88 3835.65 3889.64 6959.07 838000 6991.48 4445.31 5396.30 2.73 605807249 506158.53 70.56988966 -149.94947435 11225.31 92.11 313.25 3831.33 3885.32 7053.02 8474.04 7085.39 4508.92 5465.56 1.83 6058135.99 506087.16 70.57006329 -149.95004307 11318.31 93.63 31233 3826.67 3880.68 7145.83 8566.92 7178.12 457202 5533.72 1.91 6058198.97 506018.93 70.57023552 -149.95060278 11411.75 91.24 313.02 3822.71 387670 7239.10 866027 7271.33 4635.29 5602.35 2.66 6056262.13 505950.21 70.57040824 -149.95116636 11504.98 89.73 31270 3821.92 3875.91 733226 8753.49 7364.41 4898.70 5670.68 1.666 6058325.43 505881.78 70.57058133 -149.95172753 11598.38 89.62 314.48 3822.45 3876.44 7425.63 8846.89 7457.58 4763.10 -5738.33 1.91 6058389.71 505814.04 70.57075710 -149.95228305 11692.73 90.68 313.47 3522.20 3876.19 7519.96 8941.24 7551.67 4828.61 -5806.22 1.55 6058455.11 505746.06 70.57093592 -149.95284066 11785.28 92.23 313.51 3519.85 3873.84 7012.45 9033.76 764399 4892.25 5873.35 1.68 6055518.67 505678.84 70.57110972 -149.95339189 11878.57 92.45 315.40 3816.04 3870.03 7705.65 9126.97 7736.89 4957.56 5939.88 2.04 6058583.84 505612.21 70.57128790 -149.95393832 11972.08 89.05 315.83 3814.82 3868.81 7799.14 9220.46 7829.93 5024.26 -6005.39 3.64 6058650.43 505546.60 70.57146996 -149.95447637 12065.03 87.24 311.73 3517.83 3871.82 7691.99 9313.36 7922.81 5058.40 -6072.56 4.62 6058714.46 505479.34 70.57164505 -149.95502804 12158.31 86.94 310.35 3822.56 3876.55 7954.93 9406.52 8015.75 5149.57 -6142.82 1.51 605877551 505408.99 70.57181199 -149.95560509 12252.10 91.44 313.98 3823.89 3877.88 5078.55 9500.27 8109.43 5212.49 5212.30 6.16 605883833 505339.42 70.57198374 -149.95617574 12344.82 89.11 315.22 3823.44 387743 8171.26 9592.98 8201.84 5277.59 -6278.31 2.85 6058903.31 505273.31 70.57216142 -149.95671795 12437.83 92.76 318.50 3821.92 3875.91 8264.18 9685.97 8294.16 5345.43 -6341.89 5.28 6058971.04 505209.64 70.57234659 -149.95724015 12531.83 88.26 316.02 3821.09 3875.08 8358.07 9779.94 8387.41 5414.44 -6405.66 5.47 6059039.95 505145.76 70.57253497 -149.95776402 12625.08 85.49 310.69 3826.17 3880.16 8451.10 9873.04 8480.34 5478.34 5473.33 6.43 6059103.73 505078.00 70.57270937 -149.95831983 1271928 87.50 309.91 3831.93 388592 8544.60 996706 8574.36 5539.15 -6545.03 2.29 6059164.42 505006.21 70.57287532 -149.95890876 5.5.liner 12746.00 97.50 309.91 3833.10 3887.09 8571.39 8993.75 8601.05 5558.27 -6565.51 0.00 6059181.52 504985.71 70.57292205 -149.95807694 1278600 87.50 309.91 3834.84 3888.83 8611.20 10033.72 8641.01 5581.91 -8596.16 0.00 6059207.11 504955.02 70.5/%5202 -149.88832870 Survey Error Model: ISCWSA Rev 0"'3-D 95.000%Confidence 2.7955 sigma Survey Program: Description MD From MD To 806 Froq Survey Tool Type Borehole/Survey (ft) (ft) IRI 0.000 40.890 Act Stns SLB_NSG+SSHOT-Depth Only S120N4PH/5120-N4PH 40.890 748.900 AO Stne SLB NSG+SSHOT 5120-N4PH/5120-N4PH 748.900 2578.600 Act Stn. SLB MWD+GMAG 5120-N4PH/5120-N4PH 2576.600 2673.890 Act Stns SLB MWD-STD 5120-N4PH/0120N4PH 2673.890 12719.280 Act Stns SLB MWD+GMAG 5120-N4/5120-N4 12719280 12786.000 Act Stns SLB BLIND+TREND 5120-N4/5120-N4 Legal Description: Northing(7) Misting(S) 04629e:4454.3 FSL 1350.8 FEL 519 T1 4N R9E UM 6053636060 511559.210 9-5/8"Csg Pt:4643 FSL 2285 FEL 19 11414 R9EUM 6053823.820 510644.220 8HL:4753 FSL 2868 FEL 13114N R8EUM 6059207.110 504955.020 Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Oyes 0 No I have checked to the best of my ability that the following data is correct: ❑+ Surface Coordinates ❑+ Declination&Convergence ❑+ GRS Survey Corrections ❑+ Survey Tool Codes SLB DE: _.._.- Client Representative: ci2.:P 12/46"/:0 lZ Date: Drilling Office 2.5.1100.0 Nikaitchuq\Spy island\S120-N4\S120-N4\S120-N4 3/13/2014 3:18 PM Page 3 of 3 z. 26V01Ca REED MAR 27CEIV2014 $cblumberger ACC Transmittal#: 6690 Drilling&Measurements DATA LOGGED MWD/LWD Log Product Delivery 3 i2Yi2ot4 M K BENDER Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No S120-N4/S120-N4PH Date Dispatched: 26-Mar-14 Installation/Rig Doyon 15 Dispatched By: Stephanie Pacillo Data No Of Prints No of CDs Survey Report VISION Resistivity,EcoScope Service LWD LOGS N/A 2 in MD 2inTVD 5 in MD 5 in ND Survey *REVISED* 1+1 ASP FINAL SURVEY X EOW CD *REVISED* 1+1 ASCII DATA X SURVEY X DLIS DATA X LOG DATA X Received By: Please sign and return one copy to:\12)% at'4— Andrew Buchanan 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503 andrew.buchanan@enipetroleum.com Bender, Makana K (DOA) From: Stephanie Pacillo <SPacillo@slb.com> Sent: Friday, March 28, 2014 2:48 PM To: Bender, Makana K (DOA) Subject: RE: missing logs - SI20-N4 &SI20-N4PH Hi Makana, I should have enclosed an explanation, my apologies. There was an email request generated from AOGCC this week regarding the missing survey reports for both wells.There were no changes to the logs and therefore I created just a CD to have an electronic copy of the survey as well as the hard copy. I'll be sure to include some sort of explanation should something like this arise again. Let me know if you have any further questions I can answer. Happy Friday, Stephanie Pacillo From: Bender, Makana K(DOA) [mailto:makana.bender(aalaska.gov] Sent: Friday, March 28, 2014 1:28 PM To: Stephanie Pacillo Subject: missing logs - SI20-N4 &SI20-N4PH Stephanie— Got a delivery in late yesterday that I'm looking at now—most of the data is fine, but 2 wells (S120-N4&5120-N4PH) have physical logs listed on their transmittals that are not present in the delivery.Wanted to know if perhaps there were perhaps multiple shipments, if the logs will be in another delivery? Let me know what if any additional information you need to look up the shipping info. Happy Friday! /MakanaKBender Natural Resources Technician 11 Alaska i] e.t. Gas ;c,r s ;.rvatian C smm ssii.;n ,.1 � i 1 1 Z\,Z'0251 2.2-k01 QD RECEIVE® MAR 2 7 2014 AOGCC Schlumberger en ii S120-N4PH ASP Final Survey Report (Def Survey) Report Date: Apol12.2012-02:02 PM Survey/DLS Computation: Minimum Curvature/Lubinakl Client: Enl Petroleum Vertical Section Azimuth: 155.000°(True North) Field: Nikatohuq Vertical Section Origin: 0.000 R 0.000 ft Structure/Slot: Spy Island/SP20 TVD Reference Datum: Rotary Table Well: S120-N4 TVD Reference Elevation: 53.990 ft above MSL Borehole: 5120-N4PH Ground Elevation: 13.100 ft above MSL APW: 50529-23486-70 Magnetic Declination: 20.612° Survey Name: S120-N4PH Total Field Strength: 57648.627 nT Survey Date: Aprl 07.2012 Magnetic Dip Angle: 81.074• Tort I AHD I DDI I ERD Ratio: 88.092•/715.97311/4.701/0.170 Declination Date: April 01.2012 Coordinate Reference System: NAD27 Alaska State Plane,Zone 04.US Feet Magnetic Declination Model: BGGM 2011 Location Lal/Long: 14 701 33'27.90412',W 149°54 18.6922r North Reference: True North Location Grid NE y/X: N 6053636.000 1105,E 511559.210 RUS Grid Convergence Used: 0.000° CRS Grid Convergence Angle: 0.08940154° Total Corr Mag North.cTrue North: 20.812° Grid Seale Factor 0.99990015 Local Coord Referenced To: Well Head Comments MD Inel Azim True TVDSS TVD VSEC MD Closure NS EW DLS Northing Easting Latitude Longitude 181 7) P) (81 (ft) (ft) Int (ft) (M (ft) (1/100ft) IROS) (RUS) P) 1°1 RTE 0.00 0.00 0.00 53.99 0.00 0.00 0.00 0.00 0.00 0.00 N/A 6053836.06 511559.21 70.55775114 -149.90519230 93.50 0.30 348.22 39.51 93.50 -0.24 0.24 0.24 0.24 -0.05 0.32 6053036.30 511559.16 70.5577518 -149.80519271 18720 1.82 182.27 133.20 187.19 0.85 157 1.02 -1.01 -0.16 2.25 6053835.05 511559.05 70.55774839 -149.90519360 28330 4.54 172.37 229.14 283.13 5.83 6.69 631 5.30 0.29 2.88 6053629.76 511559.51 70.55773393 -149.90518996 377.40 8.97 166.50 322.56 376.55 18.58 1795 17.31 47.13 249 4.76 6053618.93 511561.73 70.55770434 -149.90517185 469.40 13.78 160.44 412.74 466.73 34.51 36.05 35.31 -34.43 7.83 5.36 6053601.85 511567.10 70.55765709 -149.90512805 563.30 16.92 158.40 503.28 557.27 59.30 8588 59.95 -57.48 17.05 355 6053578.61 511576.34 70.55759412 -149.90505250 854.60 17.16 153.80 590.58 644.57 86.04 87.83 86.50 51.74 28.31 0.87 6053554.37 511587.85 70.55752785 -149.90496011 748.90 17.15 156.39 880.88 734.67 113.85 115.44 114.20 -106.98 40.02 0.81 6053529.17 511599.40 70.55745895 -149.90486408 773.03 16.54 156.60 703.78 757.77 120.84 122.44 121.19 -113.37 42.81 2.54 6053522.77 511602.19 70.55744143 -149.90484120 868.41 16.68 159.77 795.18 849.17 148.08 149.89 148.44 -138.68 52.94 0.96 6053497.48 511812.38 70.55737230 -149.90475817 962.12 16.89 158.03 884.90 938.89 175.05 176.75 175.50 -183.92 82.68 0.58 6053472.25 511622.14 70.55730334 -149.90467827 1054.75 18.46 154.64 973.15 1027.14 203.16 204.87 203.58 -189.65 74.00 2.03 6053448.54 511633.49 70.55723304 -149.90458548 1147.99 22.44 154.55 1080.50 1114.49 235.73 237.44 236.08 -21907 87.97 4.27 8053417.15 511647.51 70.55715287 -149.90447086 1241.84 23.87 158.26 1148.79 1200.78 272.82 274.34 272.94 -252.83 103.31 1.68 6053383.62 511862.91 70.55706099 -149.90434503 1335.22 27.10 155.89 1231.07 1285.06 312.79 314.51 313.10 -289.35 119.61 3.46 6053346.93 511879.26 70.55896068 -149.90421137 1427.91 28.48 156.92 1313.07 1387.06 355.99 357.73 356.30 428.95 136.90 1.58 6063307.35 511696.61 70.55885249 -149.90406960 1522.14 28.88 16094 1395.82 1449.81 400.94 402.79 401.34 471.00 153.10 2.05 6053265.34 511712.87 70.55673763 -149.90393682 1615.42 27.46 160.00 1478.13 1532.12 444.63 446.68 445.18 -412.37 167.76 1.39 8053224.00 511727.60 70.55662462 -149.90381855 1708.58 25.55 157.73 1561.48 1815.47 486.09 488.24 486.74 -451.14 182.72 2.32 6053185.25 511742.61 70.55651870 -149.90369389 1802.73 22.48 155.37 1847.49 1701.48 524.39 526.56 525.04 -488.30 197.92 3.42 6053150.11 511757.87 70.55642263 -149.90358923 1895.07 21.58 152.14 1733.09 1787.08 55990 561.19 559.58 -517.37 213.22 1.83 6053119.08 511773.21 70.55633777 -149.90344382 1988.54 20.69 147.38 182028 1874.27 59254 594.87 592.96 -546.47 230.15 2.07 6053090.00 511790.19 70.55625825 -149.90330495 2082.38 19.62 150.07 1908.37 1962.36 624.67 627.20 824.95 -574.09 246.95 151 6053062.41 511807.03 70.55818280 -149.90316720 2175.53 14.64 148.37 1997.38 2051.35 651.98 654.62 852.18 -597.88 260.93 5.37 8053038.85 511821.05 70.55611835 -149.90305252 2288.90 13.31 146.05 2087.97 2141.98 874.30 677.17 674.43 516.65 273.13 1.55 8053019.90 511833.27 70.55606855 -149.90295256 2362.47 7.97 147.88 2179.90 2233.89 691.39 894.44 891.47 531.08 282.60 5.72 6053005.48 511842.76 70.55602711 -149.90287488 2455.07 4.08 148.62 2271.97 2325.96 701.04 704.16 701.10 539.34 287.73 420 8052997.24 511847.91 70.55600458 -149.90283280 2548.72 2.85 136.73 2365.45 2419.44 706.40 709.83 706.45 543.78 290.95 1.69 6052992.82 511851.13 70.55599249 -149.90280640 2576.60 2.28 13426 2393.31 2447.30 707.53 710.83 707.57 544.61 291.79 1.45 8052991.97 511851.97 70.55599016 -149.90279955 13-32- 2636.00 1.61 133.10 2452.67 2506.66 709.40 712.83 709.43 -646.00 293.23 1.10 8052990.59 511953.42 70.55598837 -149.90278769 2673.80 1.19 131.69 2490.55 2544.51 710.25 713.76 710.28 446.62 293.91 1.10 6052989.97 511854.10 70.55598466 -149.90278210 2732.02 0.19 90.04 2548.68 2602.67 710.85 714.44 710.88 447.02 294.46 1.82 8052989.56 511854.80 70.55598358 -149.90277761 2826.44 0.09 109.77 2842.10 2696.09 710.96 714.67 710.99 547.05 294.69 0.12 6052989.54 511854.87 70.55598350 -149.90277577 2918.61 0.08 110.86 2735.27 2789.26 711.05 714.79 711.08 547.09 294.80 0.03 8052989.50 511854.99 70.55598338 -149.90277484 3012.23 0.08 56.78 2828.89 2882.88 711.08 714.88 711.10 447.08 294.89 0.06 6052989.51 511855.08 70.55598341 -149.90277412 3108.34 0.04 76.99 2923.00 2976.99 711.08 714.98 711.10 547.04 294.96 0.03 6052989.54 511855.15 70.55598350 -149.90277352 3197.15 0.06 339.32 3013.81. 3067.80 711.04 715.02 711.06 546.99 294.97 0.08 6052989.59 511855.18 70.55598384 -149.90277341 3292.44 0.03 77.62 3109.10 3163.09 710.99 715.08 711.02 -646.94 294.98 0.07 8052989.65 511855.17 70.55598378 -149.90277335 3385.15 0.08 94.54 3201.81 3255.80 711.02 715.18 711.05 -646.94 295.05 0.04 8052989.65 511855.24 70.55598379 -149.90277276 Drilling Office 2.5.1100.0 Nikailchuq\Spy Island1S120-N4\S120-N4PH\S120-N4PH 3/13/2014 3:18 PM Page 1 of 2 11 Comments MD Inst Asim Northing TVDSS TVD VSEC AND Closure NS EW DLS Norng Misting Latitude Longitude (R) P) In (h) (ft) (81 (n) (n) (n) Inl (1/100ft) (MAI ANSI PI (9 3478.63 0.04 216.65 3295.29 3349.28 711.06 715.21 711.09 -646.97 295.08 0.09 6052989.62 511855.27 70.55598371 -149.90277252 3572.58 0.09 325.33 3389.24 3443.23 711.00 715.29 711.03 4846.94 295.02 0.12 6052989.65 511855.21 70.55598380 -149.90277303 3666.02 0.12 156.69 3482.68 3536.67 711.03 715.38 711.05 -646.97 295.02 0.22 6052989.62 511855.21 70.55595372 -149.90277305 3759.48 0.04 136.88 3576.14 3630.13 711.16 715.51 711.18 -647.08 295.08 0.09 6052989.51 511855.27 70.55598341 -149.90277255 3852.25 0.08 221.67 3668.91 3722.90 711.21 715.60 711.24 -647.15 295.06 0.09 6052989.44 511855.25 70.55598321 -149.90277272 3946.18 0.06 277.03 3762.84 3816.83 711.21 715.70 71124 -647.19 294.96 0.07 6052989.39 511855.15 70.55598309 -149.90277348 4038.44 0.04 147.85 3855.10 3909.09 711.22 715.76 71125 -647.22 294.93 0.10 6052989.37 511855.12 70.55598304 -149.90277373 4350.00 0.04 147.85 416666 4220.65 711.44 715.97 711.48 647.40 295.05 0.00 6052989.19 511855.24 70.55596253 -149.90277278 Survey Error Model: ISCWSA Rev 0"'3-0 95.000%Confidence 2.7955 sigma Survey Program: Description MD From MD To EOU Frcq Spy Tool Type Borehole/Survey (ft) (n) (R) 0000 40.890 1/40.890 SLB_NSG_SSHOT-Depth Only 0120.54PH/5120-N4PH 4%890 746.900 1/708610 SLB NSG•SSHOT 5120-54PH/5120-N4PH 748.900 2576.600 1/1827.700 SLB MWD0GMAG 5120-N4PH/6120-N4PH 2576.600 4038.440 1/1461.840 SLB MWD-ST0 5120-N4PH/6120-N4PH 4038.440 4350.000 1/311.560 SLS JITIND.TREND S120-N4PH/SI20-N4PH 4350.000 4350.000 Ad Stns SLB BLIND+TREND 0120414PH/0120-541,1-1 Legal Description: Northing CO Easting(%) Surface:4454.3 FSL 1350.6 FEL 519 774N R9E UM 6053636 060 511559.210 BHL:3807 FOL 1058 FEL 19 T14N R9EUM 6052989.190 511855.240 Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. ID yes p NB I have checked to the best of my ability that the following data is comsat O Surface Coordinates 9 Declination&Convergence O ORS Survey Corrections O Survey Tool Codes SLB DE: Client Representative: (2.2.R_Z .... Date. 12/0 672 0/Z. Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S120-N4\S120-N4PH\S120-N4PH 3/13/2014 3:18 PM Page 2of2 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Thursday, March 27, 2014 11:04 AM To: 'Maugeri Giuseppe' Cc: Davies, Stephen F (DOA) Subject: RE: Reporting Compliance Nikaitchuq S120-N04 Dear Mr. Maugeri: Thank you for the information provided on 3/26/14.At this time the following items from the initial request are still required: 1. Please resubmit a digital PDF of the final definitive survey as the API number is incorrect on the version currently on file. 2. A PDF version of the final definitive survey for the pilot hole is also required for S120-N04 PH,API 50-629-23466- 70-00. 3. In reviewing the digital files provided,the LAS file titled "LWD_VISION_Resistivity& EcoSCOPE_RM_00-12787" does not contain the Thermal Neutron Porosity data (TNPH).As required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.071 (6)a sepia and a reproduced copy of all logs run, including common derivative formats such as tadpole plots of dipmeter data and borehole images produced from sonic or resistivity data, and including composite log formats... an electronic image file in a format acceptable to the commission may be substituted for the sepia; If you have any questions, please contact me. Regards, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 From: Maugeri Giuseppe [mailto:Giuseppe.Maugeri@enipetroleum.com] Sent: Tuesday, March 25, 2014 10:40 AM To: Guhl, Meredith D (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: Reporting Compliance Nikaitchuq SI20-N04 Dear Mrs. Guhl, I'll provide for all requested data and documents today. Best regards, 1 Giuseppe Maugeri Completion Engineer Eni Petroleum Office: (907) 865-3328 Cell: (907) 947-9110 Email: giuseppe.maugeri(ahenipetroleum.com 3800 Centerpoint Drive, Anchorage, AK, USA From: Guhl, Meredith D (DOA) [mailto:meredith.guhlftalaska.gov] Sent: Friday, March 07, 2014 1:55 PM To: Maugeri Giuseppe Cc: Davies, Stephen F (DOA) Subject: Reporting Compliance Nikaitchuq SI20-N04 Dear Mr. Maugeri: I am completing the final compliance review for Nikaitchuq 5120-N04, PTD 212-029,API 50-629-23466-00-00, and associated Pilot Hole (API 50-629-23466-70-00), completed on 5/4/2012. As required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.050(d)the operator shall file with the Commission (d)... a complete digital copy of each inclination and directional survey not previously filed must be filed with the commission in a format acceptable to the commission. • An ASCII or Excel version of the final definitive survey is required for S120-N04. Please also resubmit a PDF of the final definitive survey as the API number is incorrect on the version currently on file. • An ASCII/Excel and a PDF version of the final definitive survey for the pilot hole is also required for 5120-N04 PH, API 50-629-23466-70-00. Also, as submitted,the form 10-407 "Well Completion Report" is incomplete because it does not include a list of all formations and geologic markers encountered in Box 29.The purpose of form 10-407 is to provide a concise,two-page summary for AOGCC's well records.As required by Regulation 20 AAC 25.071(b)(5)the operator shall file with the Commission (5)a list of the geologic markers encountered and the measured and true vertical depths of each marker. The list should include,at the minimum, Ugnu Top, Schrader Bluff Top, N Top and OA Top. In reviewing the digital files provided,the LAS file titled "LWD_VISION_Resistivity& EcoSCOPE_RM_00-12787" does not contain the Thermal Neutron Porosity data (TNPH).As required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.071 (6)a sepia and a reproduced copy of all lops run, including common derivative formats such as tadpole plots of dipmeter data and borehole images produced from sonic or resistivity data, and including composite log formats... an electronic image file in a format acceptable to the commission may be substituted for the sepia; In addition, as required by Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.070 (2)the operator is required to file a survey plat showing the precise surface location of the well. Please submit an asbuilt for 5120-N04. Finally, as required by Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071(b)(3)and (4)and also noted in box 28 on form 10-407,the operator is required to "Submit detailed descriptions, core chips, photographs and laboratory analytical results" of each core taken. Please submit all data from conventional cores acquired during drilling of this well. Please provide the requested definitive survey files,an updated form 10-407, an updated composite LAS file including all logs run, an asbuilt/survey plat, and all data related to conventional cores by April 7, 2014. If you have any questions, please contact me. 2 Sincerely, Meredith Guhl Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 This message may contain information that is confidential, and,is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 3 �., .< 4 1,t577--- / , „ , / 1 4... \ S 1 1_ 0 N lA \ ,,_ . ‘ i , _ . \ ' ' ., to,001.. ......„, I , , ' ' 4 ''7.c.,..:-.. .49::::L. 's -02C1 4c \ 21(2 % ) ay c•72 MAR 2 6 2014 kill, AOGOC i i Guhl, Meredith D (DOA) From: Maugeri Giuseppe [Giuseppe.Maugeri@enipetroleum.com] Sent: Tuesday, March 25, 2014 10:40 AM To: Guhl, Meredith D (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: Reporting Compliance Nikaitchuq S120-N04 Dear Mrs. Guhl, I'll provide for all requested data and documents today. Best regards, Giuseppe Maugeri Completion Engineer Eni Petroleum Office: (907) 865-3328 Cell: (907) 947-9110 Email: giuseppe.maugeri@aienipetroleum.com 3800 Centerpoint Drive, Anchorage, AK, USA From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Friday, March 07, 2014 1:55 PM To: Maugeri Giuseppe Cc: Davies, Stephen F (DOA) Subject: Reporting Compliance Nikaitchuq SI20-N04 Dear Mr. Maugeri: I am completing the final compliance review for Nikaitchuq 5120-N04, PTD 212-029, API 50-629-23466-00-00, and associated Pilot Hole (API 50-629-23466-70-00), completed on 5/4/2012. As required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.050(d)the operator shall file with the Commission (d)... a complete digital copy of each inclination and directional survey not previously filed must be filed with the commission in a format acceptable to the commission. • An ASCII or Excel version of the final definitive survey is required for 5120-N04. Please also resubmit a PDF of the final definitive survey as the API number is incorrect on the version currently on file. • An ASCII/Excel and a PDF version of the final definitive survey for the pilot hole is also required for 5120-N04 PH, API 50-629-23466-70-00. Also, as submitted,the form 10-407 "Well Completion Report" is incomplete because it does not include a list of all formations and geologic markers encountered in Box 29.The purpose of form 10-407 is to provide a concise,two-page summary for AOGCC's well records.As required by Regulation 20 AAC 25.071(b)(5)the operator shall file with the Commission (5)a list of the geologic markers encountered and the measured and true vertical depths of each marker. The list should include,at the minimum, Ugnu Top, Schrader Bluff Top, N Top and OA Top. In reviewing the digital files provided,the LAS file titled "LWD_VISION_Resistivity& EcoSCOPE_RM_00-12787" does not contain the Thermal Neutron Porosity data (TNPH). As required by Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 1 25.071 (6) a sepia and a reproduced copy of all lops run, including common derivative formats such as tadpole plots of dipmeter data and borehole images produced from sonic or resistivity data, and including composite log formats... an electronic image file in a format acceptable to the commission may be substituted for the sepia; In addition, as required by Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.070 (2)the operator is required to file a survey plat showing the precise surface location of the well. Please submit an asbuilt for 5120-N04. Finally, as required by Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071(b)(3)and (4)and also noted in box 28 on form 10-407,the operator is required to"Submit detailed descriptions, core chips, photographs and laboratory analytical results" of each core taken. Please submit all data from conventional cores acquired during drilling of this well. Please provide the requested definitive survey files, an updated form 10-407, an updated composite LAS file including all logs run, an asbuilt/survey plat, and all data related to conventional cores by April 7, 2014. If you have any questions, please contact me. Sincerely, Meredith Guhl Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ Q WAG ❑ WDSPL❑ No.of Completions: Service ❑✓ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 5/4/2012 212-029 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 3/3/2012 50-629-23466-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4454.3 FSL 1350.6 FEL 19 T14N R9E UM 4/25/2012 S120-N4 Top of Productive Horizon: 8.KB(ft above MSL): 53.9 15.Field/Pool(s): 4643 FSL 2265 FEL 19 T14N R9EUM GL(ft above MSL): 13.1 Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool 4753 FSL 2868 FEL 13 T14N R8EUM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 511559.21 y-6053636.06 Zone- 4 12786'MD/3888'TVD ADL 0388583,0388574,0391283 TPI: - x- 6053823.82 y-6053823.82 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 6059207.11 y-6059207.11 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes ❑✓ No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 13.1 (ft MSL) 1875 MD/1768'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES/NEU/Den/Sonic/USIT N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20 178.89 X-65 37 160 37 160 Driven N/A N/A 13.375 68 L-80 36.95 2648 36 2401 16 10.7 ppg ASL: 410 bbls N/A 12.5 ppg LiteCRETE:63 bbls 9.625 40 L-80 35.63 4937 35 3688 12.25 15.8 ppg Cement G:111bb N/A 17 ppg Cement G:120bb1s 5.5 15.5 L-80 4662 12746 3926 3887 8.75 Slotted Liner with Swelling Packer N/A 24.Open to production or injection? Yes❑ No Q 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) 4.5 4582 12479'MD/3832'TVD 3.5 12746 RECEIVED 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED MAR 2 6 2014 A0000 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period -N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes Q No❑ Sidewall Cores Acquired? Yes ❑ No Q 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. Core 1:Formations:Schrader Bluff N sand Lithology:sand,silstone+shale Top 3955'MD/3825'TVD Bottom 3958'MD/3828'TVD,oil Core 2:Formations:Schrader Bluff N sand Lithology:sand,silstone+shale Top 3971'MD/3841'TVD Bottom 4022'MD/3892'TVD,oil Core 3:Formations:Schrader Bluff OA sand Lithology:sand,silstone+shale Top 4111'MD/3981'TVD Bottom 4171'MD/4041'TVD,oil Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑Yes aJo If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1875 1768 Top Ugnu 2389 2260 Top Lower Ugnu 3700 3472 Top Schrader Bluff 4116 3746 Top N sand 4250 3813 Top OA sand 4900 3940 Formation at total depth: OA sand 12786 3889 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Giuseppe Maugeri Printed Name: Marc Kuck Title: Production Optimization Coordinator Signature�, ,z��_ , Phone: (907)865-3328 Date: 3/24/2014 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 12/2009 REV DATE BY CI( APP DESCRIPTION REV: DATE BY CI( APP i DESCRIPTION 10/: 10 D-IS CC CC Irt,C1 ,'''...:v‘, g VICINITY MAP SCALE: 1" --- 2 \Ores N ; -— — .11 ... 2-' 4 , /1 z_ 'A 19 2J 2, . . • THIS , _ ,, , .. SURVEY .) ,, ..,, 2.5 30 , )15 5 , I,,.,kiw A S P n,:AA3, 74 -3"..; Ili -1:1 31 32 3.: !,4 !ito ‘' 8 31 3; ..,, 12 1 I T14N I T14N T13N T13N 1 , .11 ) .. 5 . • . . k3 ----.------;912 I\.; I 4. 17`n,AS-LR -\\ . ' ) r...' I 12 k •1 ck \\s -)_ 1_1- — 41- - 20 * r, c, - .,., - - i ' 0 DS-3G _i ' • tts- PeC, iiiii......_,..„.....„:-olio's.' ' r ;IN • -, L.-,, , \ ij 1 I - 2:v ,2 V % ' 4 •-'\ D _ _ 3, ___ _ (); ' ' '... ...— _., __ __ 21 1 < 1 -* c), l'i, e SI ,. '4:4 ...... .14.....) A. yl . ,...,, I FJ, ' 0 "--1 - 1 ,t_ ...2i ... Ili , I 1 2 c , CaPP PAD ., QA Jr - 5 27 : os•J-3N . 1 1/4"--..,,, ,l, , JP 18 r .- k.....r, I I% ,,_ y, u „Li 1PAO .) -pi I 14 1 P , . . rI CA' '-.. G P ' , - —--- — ---r'-law —'d - (-- -- ,4-TO — ,, 1.1 h I'Ll ..---... .., '• i'al DRAWING NOTES: 1. GRID COORDINATES SHOWN ARE ALAK A STATE PLANE, ZONE 4, NAD83. DISTANCES SHOWN ARE TRUE. HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD83. 3. BASIS OF LOCATION DERIVED FROM CPS STATIC OBS. PROCESSED INTO OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TOWINISHIP 14 NORTH, RANGE 9 EAST. UMIAT MERIDIAN. 5. ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM, 6. ALL SECTIONS SHOWN AND/OR REFERENCED IN THIS DRAWING ARE 'PROTRACTED SECTIONS'. 7. REFERENCE LOUNSBURY DOCUMENT E-087 =OR COORDINATE VALUES IN NAD27. 1 16.001011.111111kilik, e,v:S.................... 14 Are9N; a, SURVEYORS CERTIFICATE • .0.i •-. * • 49th I x' t 0 • "•,.. 1.....0 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND 0 r- • , LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF oil, i :1-Ass-^-,... ...11 ALASKA AND THAT THIS PLAT REPRESENTS A SUR VE Y 'r,,-a. : ri r 1 FRANCIS J CORNING i I ii DONE BY ME OR UNDER MY DIRECT SUPERVISION AND v.G.:- % $ • THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT . ks,',.•... Ls-10605 . AS OF OCTOBER 01. 2010 ...er 47 414:spe.N..10/i../z44.9.- . lir . 0 '•..... ........ pp Ablir -fib:'-tSS 0 Nro-k-iv" -411111111,1001111". 4s* 01&Agra SPY ISLAND DRILL SITE WELL CONDUCTORS s .. • \ i AS-BUILT LOCATIONS c2M1 11 -40.0- CAD FILE:E1I3543D9 LAS operailling DATE' DRAWING NO: PART: REV: 10/01/2010 Eni-3543—d9 1 OF 3 0 - REV DATE BY CK : APE, DESCRIPTION ,REV DATE BY CK APP DESCRIPTION (j 'CA /IC '3"S CC CC '''' C i)rt"...Vo ' c N ..... , 101., 4 Cr \3* . ... —. CM"; 20 .... CP 4-'1 A S P. 1.4 AL) . P. ....1 01:0000 1,3 —.; 0000°°—' 01 IV ..„.1.0 0000Cy) , 03 ti? t).1 161) 0t1400°C ..... 10 0 000000 co DETAIL A. SCALE: 1%--80. __ ___-------------...,\\ 7 Gilp.IEL it" "1 4:4'c'fr '7'1' 495013 \ ec+4 ullat Itii* " \ s '11 * DETA 1 A C.,_,____. ---•,_.-- 4°'6 1-4.-- -r--- SPY ISLAND DRILL SITE \ (SID) 1 ‘ \ , .._..... — //--- ---- ----Y./ / 1 sAI40°' LEGENC SCALE 1 , 00 200 0 = WELL CONDUCTOR AS—BUILT NM SURVEY —1111H—° _JUNI 1' 200' iffitiis el&440.0 SPY ISLAND DRILL SITE a" !! tAn WELL CONDUCTORS 40, AS-BUILT LOCATIONS 1 @con . s. i 'frying, CAD ril F'FAI1354309 Lis operating, DA-E,„0 /2010. DRAWING NO: Eni-3543-d9 PART: 1 REV: i 2 oF 30 REV i DATT BY CK APP DESCRIPTIONK Y jq,4 DALE i B CK APP [lES'JZIf=TION Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian Alaska State Plane,NAD83 GRID NAD83 Geographic Section Line Offset Pad Well No. 'Y' 'X' _atitude N) Longitude(W F,N.L F.E.L Elev. (US ft.) (US ft.) 1 6053423.20 1651769.82 70°33'27.209" 149°54'24.765" 797 1171 12,4 2 6053421.65 1651761.87 70°33127.194" 149°54'25.000" 798 1179 12,4 3 6053420.07 1651754.10 70°33'27.179" 149°54'25.229" 800 1186 12,4 4 6053418.56 . 1651746.17 70°33'27.164" , 149°54'25.463" 801 1194 12.4 5 6053417.03 1651738.44 70033'27.149" 149°54'25.692" 803 1202 12.4 6 6053415.54 1651730.54 70°33'27.134" 149°54'25.925" 804 1210 12,4__ 7 6053412.44 1651714.77 70°33'27.104" 149°54'26.391" 807 1226 12,4 8 6053410.91 1651706.96 70°33'27.089" 149°54'26.622" 809 1234 12.4 9 6053409.39 1651699.11 70°33'27.074" 149°54'26.853" 810 1241 12.4 10 6053407.94 1651691.31 70°33'27.060" 149°54'27.084" 812 1249 12.4 11 6053406.32 1651683.39 70°33'27.044" 149°54'27.318" 813 1257 12.4 12 6053404.80 1651675.51 70°33'27.029" 149°54'27.551" 815 1265 12.4 13 6053400.38 1651652.80 70°33'26.986" 149°54'28.221" 819 1288 12.4 14 6053398.83 1651644.95 70°33'26.971" 149°54'28.453" 821 1296 12.4 15 6053397.31 1651637.12 70°33'26.956" 149°54'28.685" 822 1304 12.4 16 6053395.82 1651629.26 70°33'26.942" 149°54'28.917" 824 1311 12.4 17 6053394.32 1651621.47 70°33'26.927" 149°54'29.147" 825 1319 12.4 18 6053392.78 1651613.58 70°33'26.912" 149°54'29.380" 827 1327 12.4 19 6053389.63 1651597.90 70°33'26.881" 149°54'29.843" 830 1343 12.4 20 6053388.17 1651590.00 70°33'26.867" 149°54'30.076" 831 1351 12.4 21 6053386.60 1651582.24 70°33'26.852" 149°54'30.306" 833 1358 12.4 22 6053385.19 1651574.35 70°33'26.838" 149°54'30.538" 834 1356 12.4 23 6053383.64 1651566.41 70°33'2.6.823" 149°54'30.773" 836 1374 12.4 24 6053382.12 1651558.61 70°33'26.808" 1.49°54'31.003" 837 1382 12.4 25 6053377.65 1651535.94 70°33'26.764" 149°54'31.673" 842 1405 12.4 26 6053376.14 1651528.13 70°33'26.750" 149°54'31,904" 843 1413 12.4 27 6053374.53 1651520.23 70°33'26.734'' 149°54'32.137" 845 1421 12.4 28 6053373.11 1651512.46 70°33'26.720" 149°54'32.366'" 846 1428 12.4 29 6053371.56 1651504.49 70°33'26.705" 149°54'32.602' 848 1436 12.4 30 6053370.06 1651496.66 70°33'26.690" 149°54'32,833" 849 1444 12.4 31 6053367.05 1651480.97 70°33'26.661" 149°54'33.296" 852 1460 12.4 32 6053365.47 1651473.16 70°33'26.646' 149°54'33.527' 854 1468 12.4 33 6053363.93 1651465.22 70°33'26.631" 149°54'33.762" 855 1476 12.4 34 6053362.44 1651457.37 70°33'26.616" 149"54'33.993" 857 1483 12.4 35 6053360.91 1651449.52 70°33'26.601" 149054'34.225" 858 1491 12.4 36 6053359.33 1651441.62 70°33'26.586" 149°54134.459'' 850 1499 12.4 37 6053356.19 1651425.30 70°33'26.555" 149°54'34.941" 863 1516 12.4 38 6053354.74 1651417.32 70033'26.541" 149°54'35.177" 864 1524 12.4 %ill A0i.& s4, SPY ISLAND DRILL SITE WELL CONDUCTORS • , „ AS-BUILT LOCATIONS @no , GAD FILE:EK13543n us operatim 0Ar;:o,01 j o,o DRAWING NO. Eni-3543-d9 (PA3; 1REa 1 N W0 0 r Cr N }' rLO > 0 'o =V u -pj ferer eereeera erer e LLA', y i41 NNNNNNNNNNNNNNNNNNNNNNNNNNG NNNNNNNNNNNNNNNNNNNNN ,1NNN ,1NN N QZO .-I oil i ' w 3 1 H C a .� �.i N M to e< N O to N M N M 0 t0 a N M N M N 00 tD N N. mN 00 N N 00 01 O N N N er er N tD 00 M O N .-I N v In In to N 00 O rI N N 3 w w to N N N N N N N N N N N N N N M M M M M M M M M M .0 •0V -I O LL O . . . . . N N N N N 'i N N N N N N N N N N N N N .-1 N N N a) C _ J C 0 J '— p aa to z N M M 8 0 0 0 0 0 N 'i N N N N N N N N m m M M M to M a er v er In LI. O N N CO CO CO CO 00 00 00 00 00 00 00 00 00 00 CO CO 00 CO CO CO CO CO 00 00 00 00 1 i M 00 na N 0 M 00 M N N M 0 M N N er er M O o N tD M N M N 10 er M tto W CO M Inn O N er N Cl .O-I 00 O m vm) N CMl v tto C1 .-I M tto N INA N 001 . . . . . . . . . . . . . . . . . . . . . . . . . . cu - ,- M Q i1 tf1 M to N to to to n n n n n 0 0 0 01 M 01 N O N N N N N N N . . . . . N N N N N N N N N N N N N N N N N N _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ er v v a v v er er er er er er er er er er er er er er er er v v a v v v L 00 ton Iof1 ton In Ien M M N M M M M an N oA M 0 M M 0 0 0 l000 en ton 0 Ion M to rbe M M M M M M M M M M M M M M M M M M M M M M M M M M M M ° ercvvverererererererererererererererererervavvv M r-1 ,41-1 ,1 ,1 ,1 ,4 ,11-11-1 ,1 ,1r4 ,1 ,1 ,1 ,1 ,1 ,1 ,11-11-1 ,4 NNNNN 0 v N --. io I1 Io ;1 Io epi e-I to :1 N N IN in 0o in M v 01 M .0 01 IA O In N N :1 00 0 Z a CO N 0 co N C N N M 00 tO N 0 M N to er 1 0 CO N to 9Ir 0 00 N 10 Q -- NN N N N N N N N 0 0 0 O O M M M M M M 00 co co c000rs. r, N Z 41 CO 00 00'.'00 00 00 00 00 00 00 00 00 00 00 N N N N N N N N N N N N N N 16 N N N N N N N N N N N N N N N N N N N N N N N N N N N N M M M fr1 M M M M M M M M M M M M M M M M M M M M M M M M ryM M m;M M M Men en en en cn en en en en en a en mfn M M M M en en Co a o 0 0 0 0 0 0 0 0 0 0 0 J 000000000000000000000000O O O O n N N n n N n n N n n n N n n n n N n N n n n N n n n N N. (V pp ee}r I— '. M o L.0 m t0A IIIII n N '0.1 m INA to ID 0 'Mi m y ID N 'Ni N ar 101 ID W '-i M V LO Z6 .4 N M CO N .NI 0 M CO N to to In N '-i O 001 01 coNtotoInInM .0 M N 00100 CO N 0� N - N N IN IN IN to to to to to to LO to LO to In In to v1 In In to In In IA a er er 0 N N N N N N N N N N N H N N N .ti 'i .ti 4 .-i .-i 'i '-i '-i N '-i . .ti _1 M < N N . . . . . . N N N N N N N N N N N N N N N N N N N N J M OD Z In In In In In In in to In In In m In N 1n In In In IA IA IA IA In 1n 1n In to m — m a;'CM a Q c CI Q Z v O In M 01 01 M 000 CO 00 N W N N N N N t^o INn O er O In 0 1�A O er 0 u- 0 0 = ra .-I M n to a 00 n M er N 00 to M M N O P to a Hf .-1 O to er N 'i 0 I� to tD to l0 to to In m In In In .. ' s' er M M M M M M N N N N 'i Z V C j N - o o o o o o o o o o o o o o o o D tOo to0 o o o o o o o D D ' ' ' ' d MmfnCr1mmmmm' M' mM' fnennMmmMMMmmmmMMm In1AAN0InIANInMANNInnNnan1nInN1nMNNnNto ra OOOOOOOOOOOOOOOOOOOOOOOOOOOO y Q tooto0Dt0D0t0tot0totDtoo6. t0 totot0t0tot0t0t0t0= (/) V 88 p O. N N O N tMo ON1 M (No O'no O M v`A). N v COtoo 0? .e-1 M CO O M um) N 0 t^o Oi, 'Mi m N N N N N N N N N N N N N N N N N N N M M M M M M M M M Q L .p0 In In 1n In 1n 1n IIA Ion IA 1e.11 LA en In to in In in In In In en 1n IA 1A In In M In eeeeeeeeeeeeec0000 Q CM M M M M M M M M M M M M M M M M M M M M M M M M M M M ,_ _J C - - ' - er er er er � er er er er er � d' a � � V 1-11.4 NNNNNNNN N N N N N N N N N N N N N N N N 'i N CIO0 ai— — CD Co aa aa aa a Z O 01 n l0 er M 0 CO N to er N CO N In er N 'Ni 00 ttoo io M N O to In M N < — N N N N N N N 0 0 0 0 0 M M M M M M 00 00 00 0 0 0 N n N N Z a1 I-Z N N N N N N N t\ N N N to to to to to to to to to to to tD to to 10 tD a N N N N N N N N N N N N N N N N N N N N N N N N N N N N 0 en M in in in in in en m.M M M in R1 -en M -en -en -en -en M fn M M in en m Co M M M M m m M M M m M M m M m M M M M M M M M M M M M m O O O O O O O O O O O O O O O O O O O O O O O O O O O O N N N N N N N N N N N N N N N N N N f\ N N N N N N N f\ N 0 N N O N er er N to N N M N 0 In N to N CO 0 0 a 1A N N 1, M M to Fc 0 0 N N Cr. In N M N M M M 00 M N N 91' M M O N M 91* N N a LA M Na LO co O er to M N M In N N M N Co N O N to CO In CO O N X to to IA et M en N 0 M M co N In en N N N M M 00 N to If1 CO N N N M Co X IN N N N N N N N to to to to to ID to to to IA IA M M IA In In in M In 0 Co - e-i 'i 'i ri ri .-I 'i '-i .-i '-i .-i .-i 'i .-i .-i 444. . .i .-i 'i 'i 'i 'i 'i 'i 'i 0 0 1n In IA IA IA In In to 1n In In IA IA IA IA IA to In N In N 1n to 1n N N 1n In < Q to to to to to to o to to to to to to tD to to tD tD to to to to to to to to to to Z Z 'i 'i 'i 'i 'i .-i '-i '-i 4 ri .i ri ri 4 ri ri '-i '-i 'i 'i 'i 'i .-i 'i 'i - 'i .-i I Ili NN C 0 ra Q 0 IA N to en M .0N 0 CO M N N CON CO N 0 M aa N IA Cr Co N Z Y N to O N O M -w N M M M M 00 M 00 m o m I. tD N to N to N to N M N no CO N O 00 N In N O M N tD O 00 N In V N M 00 tD IA M N N to er M = N N N N N N N N 0 0 0 0 0 M M M M M CO CO CO 00 00 00 N. N N N = y tr v .0 .0 a v a v v er er er er M m M M M M M M M M M M M M M .n co m rrm rrim m Mn mn Cn fffn cn fn m crifri fri m crim m m tri M' cr er m Q In In In In In In In In In In In u1 1n 1n In In in u1 1n In In In In In IA In In In 000000 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a e e t0 t0 a t0 td tc tc to to to t0 t0 t0 t0 to to t0 t0 to e t t0 to t6 to to u N 0010 -0 0 m \ Z N ,r CO N N r. In lD N 0 M _ 'N-, 'N-, 'Mi 'moi 'M-I '0.1 '^-1 sI 'M.I N N N N N N N N N O G Y Eli a1 ✓ U 0 r0 r0 0 0 0 0 0 0 0 oo 0 L0 CT IN 0 o a) c to L Ot 5 o ON � W s• -a j a v `Cr a a a a a v a N y uo a) N N N N N N N N N N 0 in Z o w ,-1 .--I .--I ei ei .--I e-I '-I e-1 ei ey -i ST• W 3 U, H c J M t00 t0 I0 00 T 01 N N 7 N IL O U a a a V V V a a tro o JO a) C _ J C O a+ J• 00 01 N er in N 00 0 M V U Z < a in in M in in t0 40 LO V) U- ''-'' 00 CO 00 00 00 00 00 00 co 00 3 -1 in N a N -1 N g o N V 0, ei M t0 00 0 in N a) N N N N N N N M M m 3 N N N N N N N N Al N ✓ 0' a V1 01 in "a Cr Cr Cr Cr Cr Cr Cr a a In to en to N toll In t^ m01 T T T T T T 01 01 01 T I.- et JO .-1 ,-1 ,-I< '�-I '�-I .a-I .moi .L-1 .,-1 -I-1 O a)— l7 N N N 00 00 M CO M 00 M N 00 mev GIN Q Z N N t0 t0 t0 lN 71 CO 40 �0 40 t0 in to z (1) n f\ n n n n n n n N 3 N N N N N N N N N N ' M M M M M in in in M M M m M M M m m m M M J 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N Fs N W 0 0 0 N N N m Co M M a-I v Q iz N 00 ,-I m Cr. to N co in to Z (7 N tit) ton N M N ode-I 0 0a1 CO INI vca aavamm N X J 2 °5 0 .--i ri c-i '-i '-i '-i .-i ri �-i N ch a C-1 r-I .-1 ri 'i ,-1 .1 J = co z in in in in in to in in in in 0 ai 1 Q (C 0 N Q Z t1 to t0 to N m m .-1 m T V N L y 1J v T T M ao M CO N O t0 Qc `co of I- v IMI .-i o 0o I: v ni o 0 0 .-1 ,1 .-1 ei N N 0 0 0 0 N } lD l0 lD l0 LO l0 l0 l0 lD t0 Q � a � LAinininLAinininin Lo 0 0 0 0 0 0 0 0 0 0 J a; a atcvsto � tetctctelc U) 0 - O 0 CU >> N M t0 n N m in T N n /� I.i v O 2 T N t0 T N to V N N llOO 00 N V1 1� T N cf T .-i O N N m re; n'l l.'1 en a V to _ 3 en M M en M en M M en en Q avvv 'avvvv 'v E .� to to to to to to to to to to O- CC 01 01 01 a1 0101 01 01 o1 01 cc J ,l Yr R CY V .1 V .7 V ,1 N N H .-i .-i N .-i .-i H N O a) M N O :.- -i t0 N t0 N t0 to L-1 O Z O T t0 M .i O CO to V a IN t0 t0 40 t0 t0 t0 to to to ZN t0 l0 iit; tD l0 t0 t0 to t0 3 N N Al N NN N N NN N N M M M M M M M M M M a.+ M M M M M M M M M M 0 0 0 0 0 0 0 0 0 0 N N N N IN N IN N N N 0 T l0 N t0 N IN N N O Al X — '- t0 T .-I N en in 40 M en ,n 0 rei ri T CO N l.0 in yr V N .n-1 X X to a a a a a a a a a m m 00 0 0 .-i in in in in in N in LA in in N ill in 0 < t0 t0 t0 t0 t.0 t0 t0 t0 LD t0 a Z Z .-i' .-i .-i .-i .-i .-i .i e-i .-i N. aiN c _ 0 ra 0 a a a) t0 t0 LA N m V ri M T V Z to O O Q T V T M N IN v, ec .-i O N to M N O T t0 V — N _ n n t0 t0 t0 l0 t0 in in in 7 as } M M M m M M M Cr) M M .Q m In m CA cn m CA en ,n M `' LA in to to to in to in in to a @ 0 0 0 0 0 0 0 0 0 0 0 to to to to to tD to to to t6 U U O O OTs T e\-I M O to 0 03 0 a 0 y 0 'O O z T 0 vi N M nr M t0 IN CO W .-1 a) .-i N M M M M CO M en en M 0 G. - w N m shi U O fo .0 to 0 0 0 0 0 . __.. ... _.._b. - 0 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Friday, March 07, 2014 1:55 PM To: 'giuseppe.maugeri@enipetroleum.com' Cc: Davies, Stephen F (DOA) Subject: Reporting Compliance Nikaitchuq S120-N04 Dear Mr. Maugeri: I am completing the final compliance review for Nikaitchuq SI20-N04, PTD 212-029,API 50-629-23466-00-00, and associated Pilot Hole (API 50-629-23466-70-00),completed on 5/4/2012. As required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.050(d)the operator shall file with the Commission (d)... a complete digital copy of each inclination and directional survey not previously filed must be filed with the commission in a format acceptable to the commission. • An ASCII or Excel version of the final definitive survey is required for S120-N04. Please also resubmit a PDF of the final definitive survey as the API number is incorrect on the version currently on file. • An ASCII/Excel and a PDF version of the final definitive survey for the pilot hole is also required for S120-N04 PH, API 50-629-23466-70-00. Also, as submitted,the form 10-407 "Well Completion Report" is incomplete because it does not include a list of all formations and geologic markers encountered in Box 29.The purpose of form 10-407 is to provide a concise,two-page summary for AOGCC's well records.As required by Regulation 20 AAC 25.071(b)(5)the operator shall file with the Commission (5)a list of the geologic markers encountered and the measured and true vertical depths of each marker. The list should include,at the minimum, Ugnu Top, Schrader Bluff Top, N Top and OA Top. In reviewing the digital files provided,the LAS file titled "LWD_VISION_Resistivity& EcoSCOPE_RM_00-12787" does not contain the Thermal Neutron Porosity data (TNPH).As required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.071 (6)a sepia and a reproduced copy of all logs run, including common derivative formats such as tadpole plots of dipmeter data and borehole images produced from sonic or resistivity data, and including composite log formats... an electronic image file in a format acceptable to the commission may be substituted for the sepia; In addition, as required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.070 (2)the operator is required to file a survey plat showing the precise surface location of the well. Please submit an asbuilt for 5120-N04. Finally, as required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.071(b)(3)and (4)and also noted in box 28 on form 10-407,the operator is required to"Submit detailed descriptions, core chips, photographs and laboratory analytical results" of each core taken. Please submit all data from conventional cores acquired during drilling of this well. Please provide the requested definitive survey files, an updated form 10-407, an updated composite LAS file including all logs run, an asbuilt/survey plat, and all data related to conventional cores by April 7, 2014. If you have any questions, please contact me. Sincerely, Meredith Guhl Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 1 STATE OF ALASKA NOV 13 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANtSU6 G la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ[] WAG ❑ WDSPL❑ No.of Completions: Service Q Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co. Inc. Aband.: 5/4/2012 212-029 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 3/3/2012 50-629-23466-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4454.3 FSL 1350.6 FEL 19 T14N R9E UM 4/25/2012 S120-N4 Top of Productive Horizon: 8.KB(ft above MSL): 53.9 15.Field/Pool(s): 4643 FSL 2265 FEL 19 T14N R9EUM GL(ft above MSL): 13.1 Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool 4753 FSL 2868 FEL 13 T14N R8EUM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 511559.21 y-6053636.06 Zone- 4 12786'MD/3888'TVD ADL 0388583,0388574,0391283 TPI: x- 6053823.82 y-6053823.82 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 6059207.11 y-6059207.11 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes U No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 13.1 (ft MSL) 1875 MD/1768'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES/NEU/Den/Sonic/USIT I N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 178.89 X-65 37 160 37 160 Driven N/A N/A 13.375 68 L-80 36.95 2648 362401 16 10.7 ppg ASL: 410 bbls N/A 12.5 ooa LiteCRETE:63 bbls 9.625 40 L-80 35.63 4937 35 3688 12.25 15.8 ppg Cement G:111bb N/A 17 ppg Cement G:120bb1s 5.5 15.5 L-80 4662 12746 3926 3887 8.75 Slotted Liner with Swelling Packer N/A 24.Open to production or injection? Yes❑ No 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) 4.5 4582 12479'MD/3832'TVD 3.5 12746 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period -N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate - N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes❑., No❑ Sidewall Cores Acquired? Yes ❑ No❑., If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. Core 1:Formations:Schrader Bluff N sand Lithology:sand,silstone+shale Top 3955'MD/3825'TVD Bottom 3958'MD/3828'TVD Core 2:Formations:Schrader Bluff N sand Lithology:sand,silstone+shale Top 3971'MD/3841'TVD Bottom 4022'MD/3892'TVD Core 3:Formations:Schrader Bluff N sand Lithology:sand,silstone+shale Top 4111'MD/3981'TVD Bottom 4171'MD/4041'TVD 1 RB MS MAY 2 2 20.4 143441 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only ✓G N r 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD _ Well tested? H Yes .1 Vo If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1875 1768 Top Ugnu 2389 2260 Top Lower Ugnu 3700 3472 Top Schrader Bluff 4116 3746 Top N Sand 4250 3813 Top OA Sand 4900 3940 Formation at total depth: OA sand 12786 3888 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Giuseppe Maugeri Printed Name: Marc Kuck Title: Production Optimization Coordinator Signature:�� Phone: (907)865-3328 Date: 11/11/2013 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 • OF T1j RECD OCT 2013 0,�����yy-s THE STATE Alaska Oil and Gas -: _ == ALASI�:A Conservation Commission Witt - GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0,p, y.P Anchorage,Main:Alaska907.279.1433 99501-3572 ALAS Fax: 907.276.7542 October 30, 2013 CERTIFIED MAIL– RETURN RECEIPT REQUESTED 7012 3050 0001 4812 5658 Davide Simeone Well Operations Project Manager ENI US Operating Co. Inc. 3800 Center Point Drive, Suite 300 Anchorage, AK 99503 Subject: Incomplete 10-407 Well Completion Report for Nikaitchuq SI20-N4(PTD No.212-029) Dear Mr. Simeone: The Alaska Oil and Gas Conservation Commission (AOGCC) received on June 20, 2012 the Form 10-407 "Well Completion Report" for the Nikaitchuq SI20-N4 well. As submitted, the report is incomplete, see 20 AAC 25.071. The purpose of Form 10-407 is to provide a concise, two-page summary for AOGCC's well records. Entries such as "Not available" or "To be sent under subsequent report" or "N/A" defeat the purpose of the form; they are not acceptable. In order to complete the Form 10-407 for Nikaitchuq SI20-N4, please submit—within 15 days of receipt of this letter—a revised copy of this Form 10-407 that contains the following data: Box 29: A list of all formations and geologic markers encountered and the measured and true vertical depths of each formation and/or geologic marker. The AOGCC's reporting requirements are found in statute AS 31.05.030 and regulations 20 AAC 25.070 and 20 AAC 25.071. These requirements can be accessed online eat: Statute AS 31.05.030: http://www.legis.state.ak.us/basis/folioproxy.asp?url=http://wwwj nuO l.legi s.state.ak.us/c gi-bin/folioisa.dll/stattx07/query=31!2E05!2E030/doc/{t13554}. Regulations 20 AAC 25.070 and 20 AAC 25.071: 1 http://www.legis.state.ak.us/basis/folioproxy.asp?url=http://wwwjnu0l.legis.state.ak.us/c gi-bin/folioisa.dll/aac/query=(JUMP:'20+aac+25!2E070']/doc/{(a 11?firsthit. 1 If you have any questions concerning the matter, please do not hesitate to contact me at (907) 793-1238 or at patricia.bettis@alaska.gov. Sincerely, A/ Patricia Bettis Senior Petroleum Geologist 2 U.S. Postal Service,., CERTIFIED MAILTr., RECEIPT u7 (Domestic Mail Only;No Insurance Coverage Provided) -n LJ) For delivery information visit our website at www.usps.com® ft.i Postage $ Certified Fee1-1 _. Return Receipt Fee Postmark (Endorsement Required) Here Restricted Delivery Fee O (Endorsement Required) U-) mTotal Postage" _ m ru Sent To - ra l� Street,Apt.Na: Davide Simeone N or PO Box Na Well Operation Project Manager City,State,ZIP, Eni US Operating Co.Inc. - 3800 Centerpoint Dr.,Ste.300 PS Form 3800, Anchorage,AK 99503 SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY • Complete items 1,2,and 3.Also complete A. Signat e item 4 if Restricted Delivery is desired. X D Agent • Print your name and address on the reverse 0 Addressee so that we can return the card to you. B. Received by(Printed Name) C. Date of Delivery • Attach this card to the back of the mailpiece, or on the front if space permits. D. Is delivery address different from item 1? 0 Yes 1. Article Addressed to: If YES,enter delivery address below: 0 No 3. Seyrce Type Davide Simeone Certified Mail 0 Express Mail Well Operation Project Manager 0 Registered 0 Return Receipt for Merchandise Eni US Operating Co.Inc. 3800 Centerpoint Dr.,Ste.300 0 Insured Mail 0 C.O.D. Anchorage,AK 99503 4. Restricted Delivery?(Extra Fee) 0 Yes 2. Article Number 7012 3050 0001 4812 5658 (Transfer from service Iabe0 PS Form 3811,February 2004 Domestic Return Receipt 102595.02-M-1540' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended E] lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ 0' WAG ❑ WDSPL❑ No.of Completions: Service ❑., • Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 5/4/2012 212-029 • 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 3/3/2012 50-629-23466-00-00 ' 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4454.3 FSL 1350.6 FEL 19 T14N R9E UM 4/25/2012 S120-N4 • ,t Pr./04- /4 61----- Top of Productive Horizon: 8.KB(ft above MSL): 53.9• 15.Field/Pool(s): 4643 FSL 2265 FEL 19 T14N R9EUM GL(ft above MSL): 13.1, Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool - 4753 FSL 2868 FEL 13 T14N R8EUM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: 559.21 /0� 1 y-6053636.06 Zone- 4 12786'MD/3888'TVD. ADL 0388583,0388574,0391283 TPI: 0d `�1 y-6053823.82 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total De 10 fx .11 y-6059207.11 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes U • No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 13.1 (ft MSL) 1875 MD/1768'TVD 21.Logs Obtained(List all logs here an submit electronic and printed i ormation�pQ�r 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: 1 GR/RES/NEU/Den/Sonic/USIT Core- x'1/11''`/171 ' / /d•y','3 N/A 23. C,A(Z CASING,LINER ND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20 178.89 X-65 37 160 37 160 Driven N/A N/A 410 ppg ASL: bbls 13.375 68 L-80 36.95 2648 36 2401 16 10.7 ,/ N/A 12.5 ooa LiteCRETE:63 bbls o 9.625 40 L-80 35.63 4937 35 3688 12.25 Pg.'15.8 ppg Cement G 111bb� N/A �,g)•1f IS 125#5:001-Cement G:40 1 0 bis 5.5 15.5 L-80 4662 12746 3926 3887 8.75 Slotted Liner with Swelling Packer N/A fct. io•t►•03 24.Open to production or injection? Yes iyf No[ j If Yes,list each 25. TUBING RECORD m interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) -1 3 7'- 12.7 YG� P") ( gra--)--_ ,;"-) 4.5 4582 M7$`U/9832;TVD ��`.'I pp 3sg7'7 ECIVE3.5 12746 4}3gL fI 3gdo T� ,`.compLE_..___, 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. CG:rI?L�TlGN ; JUN 2 0 2012 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED . -"' ,, k AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate - N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes Q No❑ Sidewall Cores Acquired? Yes ❑ No Q 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. Core 1:Formations:Schrader Bluff N sand Lithology:sand,silstone+shale Top 3955'MD/3825'TVD Bottom 3958'MD/38289-VD Core 2:Formations:Schrader Bluff N sand Lithology:sand,silstone+shale Top 3971'MD/3841'TVD Bottom 4022'MD/3892'TVD Core 3:Formations:Schrader Bluff N sand Lithology:sand,silstone+shale Top 4111'MD/3981'TVD Bottom 4171'MD/4041'TVD 'DMS JUN 2 01011 - /01 13/13 /azi i3 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes Li•lo If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1875 1768 OA sand top 4118 3988 Formation at total depth: OA sand 12786 3888 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Michele Cesari Printed Name: Maurizio Grandi Title: Well Operations Project Manager Signature: AAA- l/ Phone: (907)865-3338 Date: 6/18/2012 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 lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 U'> > c 0 c > c L C co coo mi— O O- � O ~ J CO0V W cnn -0 N > d. o c) 16 0 M c a_ C H L r o y N c N .L O --► '� 00 Ul atv Q 2 0 +' C) V ++ It) O co E � .c ii MNM ati CO C) in a 'C U ` C) H H L C U) O o a Q N = 1 , 0 me O O) E W = = c cn It > O L N0) i 0 " U c J O C C J U Q c N g 6o g i. [4. O 0 G epi rl Q1 I� tG +� J J X 0 _ < N Y Y Y Y Y Y Y CO y C O_ Y a a a a a a a +' 6 d a a v d a m a L "0 = J N fl- U " a - an vii vii H vii vii vii EL ci. Z a) 3 O C X asC X p U N '+ 5 Q \ co C X , fii a i •IMI J, J, J, J, v, v, J, �, W = N C .V N �- ~ 0 (� c6 a) 'a 52 Q. O 0 M• M c gcr e _ = U) 1 0 O CO U i -0 C o M U > C c Z W N) o (Q O) O. P. o o • w X C H_ d p co > M 0 i 0 d C v= 0 iv) O r� N oo Z y D I+0 0 m C I s cn rici) 0 +. > O �, CO F— - Q N °2° C) IMD — LL E U co p�j C ,C N ba c V P.: �o e� m to U N \ �- O M CO +' C7 CO '� v' 8 o ni v^i n r" n FM = a) O 4 M 3 V M 4-, E -. o� m w n o C +�+ C c co0 o Cl) ; z 1111, N cn >> CD W \ \ 0 Y Y Y Y Y Y Y O N a a a a a a a ti N o a, E a 10 " 3 3 3 3 3 3 3 ` iii 4, NI `V fV iN fV W fV eV fV 3 m M m m M m m ' , .... M NNl M N coED, 00 L ilcl f.4 •L411 ,01, 0. �" _ (Q ++ kiD LyU E O 'i N Cf Ncn• 0. C Y L I— d . N :' sc a a xc sc xx I co p \di* 0 0 C)d 0 0 0 0 0 0 0 N D • amo cc I— o 0 :7c-I N V1 In 1s it r -0 C ill- Q M > C .Y m N t0 Ln v ;o t. ;o -N OL 0o N ~ V +L+ O M • p 0 N c4 i 8 o a of % O O C O ti CI t0 g .i .1 .� .� • d - di cc CNI z ti z M .en N _ • v u 4t Cr u tD u co elC) , Q .3M 0 0 0 0 0 0 0 0 u u u u u u u u Eni E&P Division I Well Name:S120-N4 011* ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • 2^n Date:3/22/2012 - Report#: 1 APIIUIM:629-23466-00-00 II I"I page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 -3.04 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 -37.8 Clear WC-62` 25°NNE @ 10 mph Daily summary operation _ 24h Summary Freeze protect well 5129-S2 w/164 bbls diesel.R/U wire line and changeout shear valve in GLM and test.R/D,move#3 pump skid,rock washer,and spotting sub base over S120-N4. Operation at 07.00 R/U on well S120-N4. 24h Forecast Spot sub over well S120-N4.Move the rest of the ng components and mate up.Secure location for spill protection. Lithology Shows MAASP(kgf/em') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 12:00 15:00 3.00 3.00 COMP A 2 P Rig down floor,blow down lines and disconnect,and remove suitcases. 15:00 18:00 3.00 6.00 COMP A 2 P Cleaning pits,remove rock washer. 18:00 19:30 1.50 7.50 COMP A 2 P Skid rig floor. 19:30 '20:30 1.00 8.50 COMP A 2 P Move#3 pump module,R/D interconnects,top off fuel tanks. 20:30 '00:00 3.50 12.00 COMP A 2 P Move sub base and spotting over well 5120-N4. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv 'SIDDnlling@enipetroleum.com '907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Chad Johnson Doyon Dolling Tour Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Eni representative Sach Bowe ENI Malls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/1/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') I 0 Eni E&P Division Well Name:Jit J-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • Date:3/23/2012 - Report#: 2 APIIUWI:629-23466-00-00 e i ii page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-144 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 -2.04 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 95.0 -30.0 Clear,WC-48 45"NE @ 19 mph Daily summary operation 24h Summary Spot rig over well and R/U other components as they are spotted.Berm. Operation at 07.00 R/U on well. 24h Forecast R/U on well 5120-04 and prep to spud. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 MOB A 2 P Spot sub over well S120-N4 and skid rig floor. 03:00 06:00 3.00 6.00 MOB A 2 P R/U diverter lines welding braces on well bays. 06:00 09:30 3.50 9.50 MOB A 2 P Spot SLB/MWD shack on top of sub.R/U suitcases. 09:30 13:30 4.00 13.50 MOB A 2 P Move pit complex,spot and R/U.Vetco set starter head and tested to 500 psi f/10 min. 13:30 16:00 2.50 16.00 MOB A 2 P Spot#3 pump complex.Install surface riser and test to 500 psi f/10 min. 16:00 18:00 2.00 18.00 MOB A 2 P Spot rock washer.Load multi-bowl well head in cellar. 18:00 00:00 6.00 24.00 MOB A 2 P N/U annular and test Vetco connection to 500 psi f/10 min.Continue to N/U and R/U. Note;AOGCC-Jeff Jones waived witness of Diverter test @ 0900 3-23-12. Daily Contacts Position Contact Name Company Title • E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv 'SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Dulling Tour Pusher 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Eni representative Sach Bowe ENI Matls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/1/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division I Well Name:S120-N4 cf* ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq e Date:3/24/2012 - Report#: 3 APIItNN:629-23466-00-00 en'r 11 page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator EM Share)%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG _ Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 -1.04 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 96.0 -29.4 Clear,WC-42` 0`N @ 10 mph Daily summary operation 24h Summary Complete R/U and prep to spud. Operation at 07.00 Spud 24h Forecast Spud well and drill ahead. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 MOB A 2 P R/U suit cases,diverter sys.and connect rig lines. 06:00 12.00 6.00 12.00 MOB A 2 P Continue rigging up and M/U 13 3nr hanger and landing jt. 12:00 18:00 6.00 18.00 MOB A 2 P Perform dummy run w/13 3/B"hanger/landing jt.Check Koomey bottles and test diverter sys as per State Regs.Witness waived by Jeff Jones. 18:00 00:00 6.00 24.00 MOB A 2 P Cut and slip ddg line.Pressure test suit case lines.Bring in SLB BHA and HWDP.Prep for spud. Daily Contacts Position _ Contact Name _ Company Title E-mail Office Mobile Eni representative Mike Ross ENI 'Senior Dulling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative John Spaulding ENI Dulling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Eni representative Sach Bowe ENI Malls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/1/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff)kgflcm') "SI Eni E&P DivisionWell Name:SizJ-N4 EN!Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq e APIIUWI:629-23466-00-00 2^n Date:3/25/2012 - Report#: 4 II 'I II page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 -0.04 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 97.0 -31.1 Clear,WC-42° 45°NE @ 6 mph Daily summary operation 24h Summary Complete R/U and prep to drill.Pre-spud meeting and wash and clean conductor to 160'.POOH and M/U BHA#2. Operation at 07.00 ----- ,/ c_07- g/(�L Drill ahead wl l6"ddg.assy. 24h Forecast Drill 16"surface hole to total depth of 2627'MD. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1054.5 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 MOB A 20 P R/U cuttings tank,bring HWDP to pipe shed inspect Top-Drive.Pressure test suit case lines and bong 800 bbls spud mud- to ng. 06:00 12:00 6.00 12.00 MOB A 20 P Calibrate pit sensors,P/U HWDP and jars and mobilize BHA to rig floor.P/U motor and M/U bit. 12:00 13:30 1.50 13.50 MOB A 20 P Fill conductor and check surface equipment.Replace diverter line gasket. 13:30 14:00 0.50 14.00 DRILL E 20 P Pre-Spud meeting. -14:00 15:30 1.50 15.50 DRILL E 20 P Fill conductor and check all surface equipment.Purge all mud pumps and pressure test mud lines to 3500 psi. 15:30 16:30 1.00 16.50 DRILL E 7 P Circ.,clean and wash conductor. 16:30 19:00 2.50 19.00 DRILL E 25 U Troubleshoot Top-drive problems. 19:00 20:30 1.50 20.50 DRILL E 7 P Clean and wash conductor t/160',600 gpm,400 psi,40 rpm. 20:30 21:30 1.00 21.50 DRILL E 20 P PJSM,P/U Howco wireline equip.for Gyro data. 21:30 22:00 0.50 22.00 DRILL E 20 P Calibrate block height w/Schlumberger. 22:00 00:00 2.00 24.00 DRILL E 4 P P/U 8 M/U BHA#2 w/SLB 8 Gyro Data.Orient same. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross -ENI Senior Drilling Supv SIDDnlling@enipetroleum.com '907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDdlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Eni representative Sach Bowe ENI Mats Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/1/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') Eni E&P Division 'Well Name:S120-N4 PI* ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name: Nikaitchuq • API/UWI:629-23466-00-00 2^n Date:3/26/2012 - Report#: 5 II Il page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 0.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 413.61 397.58 364.85 9.67 37.7 97.0 -38.9 Clear,WC-57' 53°NE @ 4mph Daily summary operation 24h Summary Spud and ddg f/160'-1357'MD. Operation at 07.00 Drilling ahead. 24h Forecast Drill to 2627'expected TD,circ and BROOH. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1066.5 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 3 P -Spud well and drag.f/160'-290'.@ 600 gpm,700 psi.10-12k wob,Gyro surveying as per SLB.1.92-AST/ADT,1.92-Jars/ Bit 03.30 04:00 0.50 4.00 DRILL E 4 P POOH f/290'-100',100k puw,100k sow. 04:00 06:00 2.00 6.00 DRILL E 4 P M/U stand of NM Flex DC's and Jar std.and RIH to 290'. 06:00 12:00 6.00' 12.00 DRILL E 3 P Dig.1/290'-567'MD(561'TVD),650 gpm,850 psi,40 rpm, 25-30k wob,105k puw/sow/rotw,6k tq on,3k tq off,Max gas 6.2.34-AST,.13-ART,2.47-ADT,4.39-Bit/Jars. 12:00 18:00 6.00 18.00 DRILL E 3 P DrIg.f/567'-940.MD(918'ND),755 gpm,1300 psi,60 rpm,20-25 wob,8-10k tq on.4-6k tq off,125k puw,122k sow,126 rotw,Max gas 20. .27-AST,1.61 ART,1.88-ADT,6.27-Bit/Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P Ddg.f/940'-1357'MD(1306'ND),760 gpm,1300 psi,40 rpm,20-25k wob,6-8k tq on,4-6k tq off,135k pow,125k sow, ✓ 133k rotw,Max gas 24. 1.37-AST,2.03-ART,3.40-ADT,9.67-Bit/Jars.R/D Howco wireline @ 1148'. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com •907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyonl 5@enipetroleum.com 907-685-0722 355-2607 Eni representative Sach Bowe ENI Malls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/1/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') ffill* Eni E&P Division ..i Well Name:bi J-N4 ENI Petroleum Co.Inc. Daily Re p o r Well Code:26302 Field Name:Nikaitchuq • APIIUWI:629-23466-00-00 2 II^,t Date:3/27/2012 - Report#: 6 II II page 1 of 1 Wellbore name: S12O-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND..,Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 1.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 807.11 767.69 393.50 8.79 44.8 97.0 -36.1 Clear.WC-48' 81"ENE @ 5mph Daily summary operation 24h Summary Dug 16"hole to 2648'TD.BROOH as per K&M to 1313'. Operation at 07.00 Running 13 3/8"casing. 24h Forecast Complete BROOH LD BHA R/U and run 13 3/8"casing and cement in place. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E '3 P Ddg.f/1357'-1873'MD(1766'TVD)@ 750 gpm.1500 psi,60 rpm,20-30k wob,143k puw,134k sow,138k rotw,7-8k tq on,4k tq oft,Max gas 273,10.15 ECD.2.5-AST,2.03-ART,4.53-ADT,14.2-Bit/Jars. 06:00 12:00 6.00 12.00 DRILL E .3 P Dig.f/1873'-2434'MD(2304'ND)@ 750 gpm,1500 psi,40 rpm,20-30k wob,153k puw,140k sow,150k rotw,6k tq on, 6k tq off,Max gas 355,10.09 ECD. .97-AST,1.94-ART,2.91-ADT,17.11-Bit/Jars 12:00 14:00 2.00 14.00 DRILL E .3 P Ddg.1/2434'-2648'MD(2518'ND)@ 745 gpm,1540 psi,60 rpm,20-30k wob,165k puw,143k sow,155k rotw,6-8k tq on,5k tq off,Max gas 110,9.79 ECD. .47-AST,.88 ART,1.38-ADT,18.46-Bit/Jars. 14,00 18:00 4.00 18.00 DRILL E '7 P CBU racking back std./bottoms up 1/2648'-2300'@ 800 gpm,1450 psi,80 rpm,165k puw,135k sow,150k rotw. 18.00 00:00 6.00 24.00 DRILL E .4 P BROOH f/2300'-1313'@ 800 gpm,1270 psi.80 rpm,6-8k tq,150k puw,115k sow,130k rotw. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv .SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dulling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng150doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 355-2607 Eni representative Sach Bowe ENI Matls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X-65 0.00 48.77 1/1/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division I Well Name: S120-N4 f fit ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • 2^ Date:3128/2012 - Report#: 7 APuuwl 629-23466-00-00 II 'f page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S120-N4 DRILLING 3/26/2012 3.895.95 1,167.00 4,342.79 128.31 33.8 2.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 607.11 767.69 0.00 99.0 -33.3 Clear,WC-28' 0'N Calm Daily summary operation 24h Summary Run 13 3/8"casing to 2636',Circ.&Reciprocate increasing GPM. Operation at 07.00 N/D Diverter equipment. 24h Forecast Perform surface cementing on 13 3/8"casing and bump plug.R/D from cementing and N/D diverter system.Install Vetco multi bowl well head equipment and N/U BOPE. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03.00 3.00 3.00 DRILL 'E -4 -P BROOH f/1313'-660'MD @ 800 gpm, 1200 psi,80 rpm,5-7k tq. 03:00 04.00 1.00 4.00 DRILL E 7 P Circulate @ 750 gpm,1000 psi,60 rpm until shakers were clean(2.5 X).Monitor well and Blow down Top-Drive. 04:00 05,00 1.00 5.00 DRILL E 4 P POOH on elevators f/660'-190'. 05:00 07.30 2.50 7.50 DRILL E 4 P L/D BHA as per SLB. 07:30 08:30 1.00 8.50 DRILL E '20 'P Clear and clean floor. 08:30 09:00 0.50 9.00 DRILL E 20 P Mobilize tools and equipment to ng floor for casing job. 0900 09:30 0.50' 9.50 DRILL E 20 P Change bails from short to long. 09:30 11:30 2.00 11.50 DRILL E 20 'P R/U GBR casing equipment. 11:30 12.00 0.50 12.00 DRILL E 20 P Lubricate ng. 12:00 20.30 8.50 20.50 DRILL E 4 P PJSM.run 13 3/8"689 L-80 BTC casing to 2636'fifling_every jt.and circ.every 10 its.@ 2 bpm.Landed on hanger @ ✓ 2030hrs.280k puw,180k sow.Notes:Ran 15 bow spring centralizers/3 stop rings. 20.30 22:00 1.50 22.00 DRILL E 7 •P Circ.,reciprocate and condition mud @ 2-5 bpm,275 psi. 22:00 23:00 1.00 23.00 DRILL E 20 P PJSM,Load plugs in Cement head and install on casing. 23:00 00:00 1.00 24.00 DRILL E 7 P Circulate,reciprocate and condition mud @ 4 bpm,110 psi. Daily Contacts Position Contact Name Company Title Email _ Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative John Spaulding ENI Dolling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Eni representative Sach Bowe ENI Mats Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division Well Name:S120-N4 If* EN!Petroleum Co.lnc Daily Report Well Code:26302 Field Name: Nikaitchuq • Date:3/2912012 - Report#: 8 APIIIW I:629-23466-00-00 2" " page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1.167.00 4,342.79 128.31 33.8 3.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 807.11 767.69 0.00 98.0 -36.7 Clear,WC-50° 193°SW @ 5 mph Daily summary operation 24h Summary Cement 13 3/8"csg.in place @ 2636'.100 bbls cmt returns.N/D Diverter sys.and N/U Vetco mukibowl well head and test.NIU BOPE. Operation at 07.00 Testing BOPE. 24h Forecast Test BOPE as per AOGCC.M/U BHA and RIH to FC and test casing to 2500 psi. Lithology Shows MAASP(kgflcm) Mud Weight(gIL) 1132.4 Time Log <- Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. s.A, 00.00 03:00 3.00 3.00'DRILL E 7 P Circulate,reciprocate and condition mud @ 5 bpm 160 psi.Blow air down cement line prior to cementing. 7 5‘r. 03.00 03.30 0.50 3.50 DRILL E 12 P Howco pressure test cement line to 3500 psi.Rig pump 100 bbls.10.1 ppg Mud Push @ 5 bpm,160 psi. 0- 03.30 06.00 2.50 6.00 DRILL H 7 P Drop Btm plug and pump 410 bbls.10.7 ppg lead cement @ 5 bpm,180 psi followed with 63 bbls.tail cement 12.5 ppg @ 180 psi.Kick out Top plug w/10 bbls water. c f,P' 06:00 07:00 1.00' 7.00 DRILL H 7 P Displace cement with 372 bbls 9.4 ppg mud and bump plug to 900 psi and hold for 5 min.100 bbls cement retums.CIP @ 06300 hrs.Bleed pressure and floats held. 07:00 -09:30 2.50 9.50 DRILL E 20 P R/D Cmt.head and equipment,elevators and landing jt. 09:30 11:00 1.50 11.00 DRILL E 20 P -Clear and clean rig floor. 11:00 12:00 1.00 12.00 DRILL E 20 P Changeout long bails to short bails. 12:00 13:00 1.00 13.00 DRILL E 20 P Johnny Wack diverter stack and sys. 13:00 18:00 5.00 18.00 DRILL E 20 P N/D Diverter system equipment. 18:00 21:00 3.00 21.00'DRILL E 20 P N/U Vetco Gray wellhead and test to 5000 psi for 10 min. 21:00 00:00 3.00 24.00'DRILL E 20 P N/U lower user and BOP stack. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com '907-685-0715 - Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative John Spaulding ENI Dulling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 355-2607 Eni representative Sach Bowe ENI Matls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.poner@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Iff* Eni E&P Division I Well Name:S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • API/UWI:629-23466-00-00 2 „I^ Date:3/30/2012 - Report#: 9 II II Ipage 1 of 1 Wellbore name: S)20-N4 - Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI20-N4 DRILLING 3/26/2012 3.895.95 1,167.00 4,342.79 128.31 33.8 4.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 807.11 767.69 0.00 102.0 -33.3 Clear,WC-47` 17°N @ 7mph Daily summary operation 24h Summary N/U and test BOPE to 250/3500 psi witnessed by AOGCC John Crisp.P/U BHA#3 and RIH. Operation at 07.00 Ddg.ahead. 24h Forecast RIH with 12 1/4"dolling assy to Float collar and test casing to 2500 psi.Displace well to FazePro drilling fluids.Drill out shoe track and 25'of new hole and CBU.Perform FIT/LOT test. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deser. 00:00 00:30 0.50 0.50 DRILL E 20 P N/U BOPE 00:30 02:30 2.00 2.50 DRILL E '25 P Change out saver sub on Top-Drive. �� 02:30 05:00 2.50 5.00 DRILL E 20 P Complete N/U for BOPE. 05:00 06:00 1.00 6.00 DRILL E 20 P PJSM and R/U for BOPE test. 06:00 14:00 8.00 14.00 DRILL E 12 P Test BOPE as per AOGCC witness John Crisp.Test Annular to 250/2500 psi,all rams,choke valves and other equipment to 250/3500 psi.Perform Koomey test, 14:00 16:00 2.00 16.00 DRILL E -20 P Drain stack,pull test plug and install wear nng. 16:00 17:30 1.50 17.50 DRILL 'E 20 P Clear and clean floor. 17:30 20:00 2.50 20.00 DRILL E 4 P P/U BHA#3 8 RIH to 650'. 20:00 22:00 2.00 22.00 DRILL E -19 P Fill pipe and perform shallow hole test @ 600 gpm,650 psi.K&M set up drilling parameters @ 30 rpm,111k puw,115k sow.111k rotw. 22:00 00:00 2.00 24.00 DRILL E 4 P RIH picking up single doll pipe to 1732'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com -907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondnlling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Eni representative Sach Bowe ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 813.21 773.78 FazePro 1114.4 35.8 1577.8122.0 flifi* Eni E&P Division Well Name:S120-N4 EN!Petroleum Co.Inc. Daily Report Well Code:26302 Field Name: Nikaitchuq • Date:3/31/2012 - Report#: 10 API/UWI:629-23466-00-00 2" "11 page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 326/2012 3.895.95 1.167.00 4,342.79 128.31 33.8 5.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,077.16 1,018.31 270.05 5.08 53.2 101.0 -25.6 Clear,WC-34° 45°NE @ 10 mph Daily summary operation 24h Summary RIH to FC and perform Casing test to 2500 psi for 30 min.Displace spud mud to FazePro and drill out shoe track plus 25'of new hole.Perform FIT test to 13.2 ppg.Dig.ahead to 3534'. Operation at 07.00 BROOH to inside casing shoe. 24h Forecast Drill to core point @ 3956'.POOH L/D BHA and P/U Core assembly.and RIH. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dar(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 0160 1.00 1.00 DRILL E 4 P RIH P 1732'-2417'. 01:00 02:00 1.00 2.00 DRILL E 4 P POOH 10 stds. 02:00 02:30 0.50 2.50 DRILL E 25 P Service rig,Top-Drive,Upper&Lower kelly valves. 02:30 04:30 2.00 4.50 DRILL E 4 P RIH singles from pipe shed and 3 stds.Wash down and tag @ 2535',175k puw,145k sow.150k rotw.Rack 1 std back. 04:30 05:00 0.50 5.00 DRILL E 7 P Circ.@ 400 gpm,390 psi surface to surface. 05:00 05:30 0.50 5.50 DRILL E 20 P Blow down Top-Dnve and R/U casing test equipment. 05:30 06:30 1.00 6.50 DRILL E 12 P Test 13 3/8"casing to 2500 psi for 30 min.Bleed pressure and R/D test equip. 06:30 08:30 2.00 8.50 DRILL E 7 P PJSM,Displace well @ 2510'w/40 bbls water @ 5 bpm.120 psi,followed w/50 bbls LVT @ 5 bpm,150 psi,followed w/ 361 bbls 9.2 ppg FazePro @ 9 bpm,280 psi. 08:30 10:00 1.50 10.00 DRILL E 20 P Blow down Top-Drive,clean drip pan,shakers and mud pit area,Bring on new mud. 10:00 12:00 2.00 12.00 DRILL E 7 P Wash down to Float Collar @ 2545'.Drill shoe track to Float shoe @ 2625'.Drill new hole to 2668',@ 600 gpm.950 psi,60 rpm,30k wob,3-7k tq. .19 ADT,.19 Bit,18.69 Jars. 12:00 13:00 1.00 13.00 DRILL E 7 P Circulate and condition mud @ 2668',680 gpm,1180 psi,20 rpm,2-4k tq,165k puw,145k sow, / 13:00 14:00 1.00 14.00 DRILL E 12 P Perform FIT to 13.2 ppg as per guidelines. 14:00 18:00 4.00 18.00 DRILL E 3 P Dig.f/2668'-306T MD(2938')@ 902 gpm,1915 psi,120 rpm,30-40k wob,6-8k tq on,4-6k tq off,170k puw,150k sow, 1, e</ 160 rotw,9.73 ECD,Max gas 14,2.37 ADT,2.56 Bit,21.06 Jars. I� Al''1 ,{ 18:00 00:00 6.00 24.00 DRILL E 3 P Ddg.f/3067'-3534'MD(3405')@ 902 gpm,2100 psi,100-120 rpm,30-40 wob,7-9k tq on,5-7k tq off, 185k puw,155k sow,171k rotw,9.75 ECD,Max gas 16. 2.52 ADT,5.08 Bit,23.58 Jars,SPR @ 3532'MD(3403'ND)9.3 MW#1 @ 30-70psi.@ 40-100 #2 @ 30-70 @ 40-100 #3 @ 30-90 @ 40-130 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Dnlling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Eni representative Sach Bowe ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE lack.po0er@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 II* Eni E&P Division I Well Name:S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • Date:4/1/2012 - Report#: 11 API/t1Wl:629-23466-00-00 2" "� page 1 of 1 wellbore name: S120-N4 Well Header PermitlConcession N° Operator EM Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) • 16.46 3.99 0.00 5.19 . Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 6.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,205.48 1,112.32 128.32 7.52 17.1 106.0 -24.4 Clear,WC-33` 53'NE @ 13 mph Daily summary operation 24h Summary Drlg to 3955'MD core point as per Geologists.Perform clean up cycle as per KW while POOH.L/D BHA and service rig.PJSM and M/U core assy#1. Operation at 07.00 M/U core assy.#1 24h Forecast RIH w/Core assy#1 and cut 60'core.POOH and UD core samples. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Ddg.f/3534'-3812'MD(3683'TVD)@ 903 gpm,2110 psi,45 rpm.35-40k wob,6-8k tq on,5-6k tq off.189k puw,167k sow,179k rotw,9.55 ECD,Max gas 21,4.5 ADT,9.56 Bit,23.0 Jars. 06.00 10:00 4.00 10.00 DRILL E 3 P Ddg.f/3812'-3955'MD(3826'TVD)@ 750 gpm,1560 psi,80 rpm.10-20k wob,5-6k tq on,5-6k tq off.189k puw,170k sow.179k rotw,9.65 ECD,Max gas 40,3.02 ADT,12.6 Bit,31.1 Jars.SPR @ 3945'MD(3811'TVD) 9.4 ppg MW #1 @ 30-90psi,@ 40-110 #2@30-90, @40-120 #3@30-90, @40-130. 10:00 17:00 7.00 17.00 DRILL E 4 P 'BROOH f/3955'-2510'CBU and pulling @ 22 min/std.as per KW @ 904 gpm,2100-1880 psi,80 rpm,4-6k tq. 17:00 20:00 3.00 20.00 DRILL E 4 P -POOH on elevators f/2510'-77'. 20:00 21:00 1.00 21.00 DRILL E 4 P PJSM UD BHA. 21'.00 22:00 1.00 22.00 DRILL E 20 P Service and lubricate ng. 22:00 00:00 2.00 24.00 DRILL I 20 P PJSM for coring project oath all hands involved.Work on pipe measurements and ball sub configuration. Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Mike Ross ENI 'Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher ng15@doyondnlling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Eni representative Sach Bowe ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm) Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 Eni E&P Division Well Name:biz,-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name: Nikaitchuq fif* • APIIUWI:629-23466-00-00 2^rl Date:4/2/2012 - Report#: 12 II II II page 1 of 1 Wellbore name: SI2O-N4 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 7.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,205.48 1,112.32 0.00 105.0 -23.3 Ptly Cldy,WC-32` 87°E©13mph Daily summary operation 24h Summary M/U core assy.and test.RIH to core point of 3958'Rabbitting pipe from derrick w/2.375".Tag btm.and set drilling parameters.Core section from 3958'-3971'. Jammed core sample.POOH. Operation at 07.00 POOH w/Core sample#1. 24h Forecast POOH W/core#1 and process as per coring personnel.M/U coring assy.and RIH to complete coring of N sands. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 ' 3.00 3.00 DRILL 1 20 P PJSM P/U coring equipment and M/U ball sub as per Coring Rep.P/U&M/U long bails to accommodate ball sub. 03.00 07:00 4.00 7.00 DRILL I 4 P PJSM P/U&M/U outer core barrel assy.as per Core Rep.and RIH.Run inner core barrels in outer assy. 07:00 08:00 1.00 8.00 DRILL 1 12 P PJSM test inner coring sleeve by dropping ball from ball sub and pump @ 250 gpm,90 psi,inc.to 500 gpm,250 psi,dec.to 250 gpm,120 psi.R/D XO's&blow down Top-Drive. 08:00 09:00 1.00 9.00 DRILL 1 20 P Break out inner barrels and retrieve ball.M/U inner barrels. 09:00 10:00 1.00 10.00 DRILL 1 20 P PJSM M/U rest of coring BHA as per SLB and rabbit pipe from derreck vA 2.375". 10.00 18:00 8.00 18.00 DRILL 1 4 P RIH on elevators to 3520'.Rabbit pipe and fill every 10 stds.Begin washing to bottom @ 2979'@ 250 gpm.325 psi. 18:00 19:00 1.00 19.00 DRILL 1 4 P Wash to bottom f/3520'-3958'@ 250 gpm 325 psi,185k puw,175k sow. 19:00 22:00 3.00 22.00 DRILL 1 3 'P Obtain SPR @ 3955'MD w/9.5 ppg MW#1/#2/#3 @ 30-120,a 40-170 psi.Core f/3958'-3971'@ 150 gpm,150 psi,40- 60 rpm,4-12k wob,4-5k tq.190k puw,182k sow.Predicted jammed core sample. 22.00 00:00 2.00 24.00 DRILL 1 4 P POOH f/3971'-3540'180k puw,115k sow. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling©enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Dolling Supv, SIDDnlling(genipetroleum.com 907-685-0715 632-3058 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Dolling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 355-2607 Eni representative Tom Klein ENI Mats Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter©enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 Eni E&P Division , ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name: Nikaitchug PI* � APIIUW1:629-23466-00-00 2^ Date:4/3/2012 - Report#: 13 II II page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name •Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 8.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,225.91 1,124.60 15.54 1.50 10.4 105.0 -20.6 Pity Cldy,WC-26` 27°ENE @ 16 mph Daily summary operation 24h Summary Continue POOH f/3530'-1/2594'.1 Monitor well and pump dry job./POOH f/2594'-1/650'./Reciprocate string for 1 hour as per tripping procedure./POOH f/650'-11250'.1 Reciprocate string for 1 hour.\POOH 1/250'-Ucoring assembly./L/D core barrel and process./P/U 8 M/U core assembly#2.1 RIH f/71'-2650'.1 Wash&ream f."2650'-1/3064'as per Corpro reps.\RIH 1/3064'-63841.1 Wash 8 ream 1/3841'- 83971'.\Corpro activated flow diversion ball and commence coring 1/3971'-4022'. Operation at 07.00 Reciprocate string @ 650'as per tripping procedure. 24h Forecast Activate full closure system as per Corpro reps.\POOH 1/4022-1171 as per tripping procedure./PJSM-Remove core barrel and process./L/D coring assembly.\P/U 12 1/4"BHA with(X5,PWD,GR/RES tools).\RIH 1/4022'ream out cored section and drill pilot hole to 2nd core point(5'above OA sand)./POOH as per KW model./L/D drilling assembly./M/U coring assembly as per Corpro procedure. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL I 4 P Continue POOH f/3530'-t/2594'as per Corpro tripping parameters(over pull 15-20K @ 2910')/Monitor well for 10 mins. inside shoe-static. ' 02:00 02:30 0.50 2.50 DRILL I 7 P Kely up-Pumped 17 bbls.of 11.0 ppg dry job-130 gpm @ 120 psi./Blow down top drive\Up wt.=151K-Dn wt.=141K. 02:30 05:30 3.00 5.50 DRILL 1 4 P POOH(/2594'-1/650'per tripping out parameters. 05:30 06:30 1.00 6.50 DRILL 1 19 P Reciprocate f/650'-1/736'for 1 hour as per procedure. 06:30 07:30 1.00 7.50 DRILL I 4 P POOH f/650'-11250'per tnpping out parameters. 07:30 08:30 1.00 8.50 DRILL 1 19 P Reciprocate f/250'-1/290'for 1 hour as per procedure. 08:30 09:00 0.50 9.00 DRILL 1 4 P POOH f/250'-1/core assembly as per Corpro. 09:00 12:00 3.00 12.00 DRILL 1 4 P PJSM-Work core BHA assembly-inspect bit./RIH with assembly and remove inner core barrel and L/D same./POOH and remove bit. 12:00 13:30 1.50 13.50 DRILL 1 4 P PJSM-P/U and M/U inner core barrel assembly as per Corpro reps and M/U MC 573 bit on assembly for core#2 @ core point#1. 13:30 17:00 3.50 17.00 DRILL I 4 P RIH 1/71'-82650'fill every 10 stands and verify circulation thru core barrel./Up wt.=135K-Dn wt.=130K. 17:00 20:00 3.00 20.00 DRILL I 6 P Continue RIH-wash and ream f/2650'-t/3064'as per Corpro reps.\241 gpm @ 230 psi./25 rpm @ 2-4K torque/WOB 2- 4K\Up wt.=170K-Dn wt.=160K-Rot wt.=165K. 20:00 21:00 1.00 21.00 DRILL I 4 P RIH without wash/ream 1/3064'-1/3841'/Up wt.=190K-Dn wt.=170K. 21:00 22:00 1.00 22.00 DRILL I 6 P Wash and ream per Corpro rep spec.f/3041'-U 3971'\Pump rate 242 gpm @ 260 psi./25 rpm @ 4-6K torque\WOB 2-4K\ Up wt.=190K-Dn wt.=180K-Rot wt.=186K. 22:00 00:00 2.00 24.00 DRILL I 3 P Corpro activated fast ball sub to seat flow diversion ball and commence conng 1/3971'-4022'/Pump rate 150 gpm @ 200 psi./45 rpm @ 5-6K torque/WOB=8-11K\Rot wt.=186K\Target achieved for core point#1.\Jars=33.10 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative John Spaulding ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 355-2607 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE 'jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 111* Eni E&P DivisionWell Name:Si a-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • Date:4/4/2012 - Report#: 14 APIIUWI:629-23466-00-00 e i ii page 1 of 1 Wellbore name: S120-N4 Well Header PermillConcession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 9.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,225.91 1.124.60 0.00 102.0 -25.9 Clear,WC-55' 49°ENE @ 17.3 mph Daily summary operation 24h Summary Activate full closure system as per Corpro reps.\POOH(/4022-567'as per timed tripping procedure-reciprocate string @ 650'and 250'for 1 hr.period each\PJSM-Remove core barrel and L/D as per Corpro reps-rack in carriers for processing-51'recovery./Rack back outer coring assembly in derrick./P/U and M/U BHA#6 with Schlumberger and shallow test @ 730'.\RIH 1/730'-52600'\Cut drilling line and service rig components./RIH f/2600'-53817'.1 Performed Mad Pass log with Schlumberger 1/3817'-53910'. Operation at 07.00 Circulating bottoms-up until clean @ 3910'to POOH. 24h Forecast Complete mad pass t/3910'-54022'.\Drill 1/4022'to second core point above OA Sand as per geologist-proposed 4110'.1 Back ream to 3900'as per K&M-CBU until dean./POOH on elevators and LID BHA#6 as per Schlumberger./P/U BHA#7 Coring assembly as per Corpro reps.\RIH 5second core point(wash 8 ream as required).\Corpro activate tool and commence to coring 60'section. Lithology Shows MAASP(kgfIcm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. AeL Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL I 3 P Drop ball to activate full closure system as per Corpro reps.\Pump 131 gpm @ 170 psi.and while rotating 20 rpm @ 4K torque.Close system and increased pump to 760 gpm @ 2300 psi.for one min+\Shut down rotary and pump-pull 10K over to break off core./Pump out 100 gpm @ 120 psi.f/4022'-1/39631/Up vs.=190K-Dn wt.=174K-Rot wt.=163K. 01:00 04:30 3.50 4.50 DRILL I 4 P POOH f/3963'-t/2594'as per Corpro tripping parameters-well out of balance&screw into each stands.\Monitor well for 10 mins.@ shoe-static.\Up wt.=160K-Dn wt.=145K. 04:30 05:00 0.50 5.00 DRILL I 7 P Pumped 18 bbls.of 11.2 ppg dry job-150 gpm @ 160 psi.\Blow down top drive. 05:00 08:00 3.00 8.00 DRILL I 4 P POOH f/2594'-51474'per topping out parameters @ 4 mins/stand.\Reduce speed t/1474'-5650'@ 6 mins/stand.'.Up‘sit= 125K-Dn wf.=120K. 08:00 09:00 1.00 9.00 DRILL I 19 P Reciprocate @ 650'for 1 hour as per procedure.\Rack back last stand of drill pipe. 09:00 09:30 0.50 9.50 DRILL I 4 P POOH f/650'-5250'per tripping out parameters @ 12 mins/stand. 09:30 10:30 1.00 10.50 DRILL I 19 P Reciprocate @ 250'for 1 hour as per procedure.\Up wt.=100K-Dn wt.=100K. 10:30 11:00 0.50 11.00 DRILL I 4 P POOH t/250'-Score assembly as per Corpro @ 12 mins/stand. 11:00 15:00 4.00 15.00 DRILL I 4 P PJSM-Pull bit to surface and inspect(removed core plug-RIH 567'/Clear and clean floor\Prep and remove inner core barrel and L/D same as per Corpro reps.-recovered 51'\POOH and remove bit.\Rack back out barrels in derrick.\P/U stand#36 and RIH remove and L/D ball sub and rack back in derrick. 15:00 15:30 0.50 15.50 DRILL I 20 P Clear and clean rig floor of Corpro tools and Prep to P/U Schlumberger for BHA#6. 15:30 18.30 3.00 18.50 DRILL E 4 P PJSM-P/U and M/U BHA#6 as per well plan and Schlumberger reps.\RIH with BHA from derrick V 730'.1 Performed swallow test on Schlumberger tools-good. 18:30 20:00 1.50 20.00 DRILL E 4 P RIH f/730'-52600'-fill pipe as required./Up wt.=150K-Dn wt.=140K. 20:00 22:00 2.00 22.00 DRILL E 25 P PJSM-Slip and cut drilling-inspect brake linkage.\Calibrate block height with Schlumberger.\Service rig components- top drive blocks.crown and draw-works. 22:00 23:00 1.00 23.00 DRILL E 4 P RIH 1/2600'-53817'-fill pipe as required./Up wf=185K-Dn wt=170K. 23:00 00:00 1.00 24.00 DRILL E 6 P Perform mad pass with Schlumberger-Wash/ream(/3817'-V3910'-Pump rate 700 gpm @ 1550 psi./80 rpm @ 4-6K torque.\Mud wt.=9.5 ppg\ECD 9.95 ppg.\Up wt.=190K-Dn wt.=170K-Rot wt.=182K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Dnlling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondnlling.com 907-685-0716 Eni representative Tom Norvig EM Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Lasf Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 !P " * Eni E&P Division (Well Name: S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name: Nikaitchuq • API/UW:629-23466-00-00 2^,t Date:4/5/2012 - Report#: 15 II �)II page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3.895.95 1,167.00 4,342.79 128.31 33.8 10.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,271.32 1,150.46 18.29 2.00 9.1 99.0 -19.5 Ptty Cldy,WC-52 62°ENE @28.8 mph Daily summary operation 24h Summary Complete mad pass 1/3910'-1/4022'.1 Drill 640221-V4111'second core point.\Back ream(/4111'-63900'as per KBM.\CBU(2.5X)until clean-reciprocate and rotate.\POOH on elevators and UD BHA #6 as per Schlumberger.\P/U BHA#7 Coring assembly as per Corpro reps.6162'\RIH 6162'-61576'.1 Service rig.\Repair draw-works lube oil pump./RIH(/1576'-1/4000'.1 Wash&ream f/4000'-114111'.\ Corpro activate tool and commence to coring 60'section 64111'-64171'-Target achieved for core point#2, Operation at 07.00 - � r� �. POOH with BHA#7 coring assembly. L1'' )-d 24h Forecast lll��. Activate full closure system as per Corpro reps.\POOH back reaming 1/4171'-1/2600'(13 3/8"csg shoe)due to hole condition(over pull and packing-off).\Monitor well and pump dry.\POOH on elevators to BHA#7.1 PJSM-work BHA coring assembly as per Corpro-UD same.\P/U BHA#8 to ream core section and drill pilot open for E-line.\POOH and UD BHA#8. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 6 P Perform mad pass with Schlumberger-Wash/ream(/3910'-64022'(cored section)-Pump rate 700 gpm @ 1610 psi.\80 rpm @ 5-6K torque.\Mud wt.=9.5 ppg\ECD 9.95 ppg.\Up wt.=190K-Dn wt.=178K-Rot wt.=182K. 00:30 03:30 3.00 3.50'DRILL ''E 3 P Drill rotary(/4022'-64111'(3982'TVD)-Control drilled @ 50 fph to second core point as per Geologist.\Pumping 750 gpm @ 1770 psi.\80 rpm©6-7K torque\WOB=25-30K\Mud wt=9.5 ppg\ECD 9.85 ppg.\Up wt.=192K-Dn wt=171K- Rot wt.=18010 ART=2.3 hrs.\ADT=14.9 hrs.\Jars=35.40 hrs. 03.30 04:00 0.50 4.00 DRILL E 4 P POOH back ream 1/4111'-*13900'per KEN parameters.\Pumping 750 gpm @ 1690 psi./80 rpm @ 5-7.2K torque.\Rot wt= 182K. 04.00 05:30 1.50 5.50 DRILL E 7 P Circulate bottoms-up(2.5 X)until clean-reciprocate(/3910'-113817'.1 Pumping750 gpm @ 1760 psi./80 rpm @ 5K torque.\ Up wt=192K-Dn wt.=171K-Rot wt.=180K. 05:30 07:00 1.50 7.00 DRILL E 4 P POOH(/3910'-62601'as per KW parameters.\Monitor well @ shoe-static.\Up wt.=150K-Dn w1.=142K. 07:00 07:30 0.50 7.50 DRILL E 7 P Pumped 20 bbls.of 11.2 ppg dry job-250 gpm @ 190 psi.\Slowdown top drive. 07:30 08:30 1.00 8.50 DRILL E 4 P POOH 1/2601'-VBHA#6.\Up wt.=110K-Dn wt.=110K. 08:30 10:00 1.50 10.00 DRILL E 4 P PJSM-UD BHA#6 as per Schlumberger and clear floor of tools. 10:00 13:00 3.00 13.00 DRILL I 4 P PJSM-P/U BHA#7-M/U bit to outer core barrel.\Install install inner core barrel assembly and gyro head @ 67'as per Corpro reps.\RIH f/67'-U162'. 13:00 15:00 2.00 15.00 DRILL I 4 P RIH(/162'-61576'-Fill every 10 stands.\Up wt.=145K-Dn wt.=134K. 15:00 15:30 0.50 15.50 DRILL I 25 P Service and lubricate ng components-top drive,blocks and draw-works. 15:30 17:00 1.50 17.00 DRILL I 25 P Down time:Repair draw-works lube oil pump belt and realign pulleys. 17:00 20:00 3.00 20.00 DRILL I 4 P RIH f/1576'-64000'-Fill every 10 stands and verify core barrel open./Up wt.=185K-Dn wt.=175K. 20:00 21:30 1.50 21.50 DRILL I 6 P Wash and ream as per Corpro rep spec.f/4000'-64111'1 Pump rate 240 gym @ 230 psi.\20 rpm @ 4-6K torque\WOB 2- 4K\Rot wt.=186K.\Install upper ball sub on stand#38. 21:30 00:00 2.50 24.00 DRILL I 3 P Corpro reps obtain torque rates and activated fast ball sub to seat flow diversion ball and commence coring(/4111'-4171'\ Pump rate 150 gpm @ 150 psi.\45 rpm @ 6K torque\WOB=5-12K\Up wt.=190K-Dn wt.=180K-Rot wt.=188K\Target achieved for core point#2.1 Drop ball to activate full closure system as per Corpro reps.\ART=2.0 hrs.\ADT=5.5 hrs.\Jars =37.40 hrs. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative 'Jack Keener 'ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229.6100 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 VI* Eni E&P Division Name:SI20-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • APIIUWI:629-23466-00-00 2�, Date:416/2012 - Report#: 16 II 'I page 1 of 1 Wellbore name: S120-N4 Well Header PermillConcession N° Operator ENI Share)%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DES(days) S120-N4 DRILLING 3/26/2012 3.895.95 1,167.00 4,342.79 128.31 33.8 11.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1.319.78 1,172.31 48.46 3.27 14.8 97.0 -19.8 Clear,WC-40.9" 230'WSW @ 18 mph Daily summary operation 24h Summary POOH pumping f/4171'-03094'(consult w/Corpro)due to hole condition back ream 3094'-812594'.1 Monitor well-Attempt to POOH-swabbing,pump out(/2594'-82220'S POOH on elevators 112127 with swabbing-monitor well.\Pump dry job\POOH to BHA#7.\PJSM-work BHA coring assembly as per Corpro-L/D same.\P/U BHA#8.1 RIH ream(/4032'-84171'(core section).\Drill 1/4171-84330'pilot hole for E-line. Operation at 07.00 L/D BHA#8. 24h Forecast Drill f/4330'-t 4350'/CBU 2.5X\POOH back ream 1/4330'-83752'\CBU 3X-set back stand each time.\POOH and UD BHA#8 as per Schlumberger.\R/U Schlumberger E-line.\Perform two logging run- #1 Quad Combo(open hole)-#2 CMR(Cored section).\R/D Schlumberger E-line.\P/U 3 1/2"cement stinger and RIH. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00-.00 05:30 5.50 5.50 DRILL I 4 P Pump out with core assembly 1/4171'-83094'\Pumping 100 gpm @ 120 psi.-signs of packing off-consult with Corpro reps.\Back ream 1/3094'-82594'-Pumping 135 gpm @ 145 psi./15 rpm @ 4-8K torque./Rot wt.=155K.\Monitor well- static. 05:30 06:30 1.00 6.50 DRILL I 4 P Attempt to POOH on elevators-started swabbing-pump out(/2594'-82220.1 Monitor for swabbing-POOH 82127'-no swabbing.\Monitor well. 06:30 07:00 0.50 7.00 DRILL I 7 P Pumped 20 bbls.of 11.2 ppg dry job-150 gpm @ 120 psi.\Blow down top drive.\Up wt.=142K-Dn wt.=135K. 07:00 08:30 1.50 8.50 DRILL I 4 P POOH f/2127'-81375'per tripping out parameters @ 4 mins/stand.\Reduce speed 1/1375'-8650'@ 6 mins/stand.\Up wt.= 115K-Dn wt.110K. 08:30 09:30 1.00 9.50 DRILL 1 19 P Reciprocate @ 650'for 1 hour as per procedure. 09:30 10:00 0.50 10.00 DRILL I 4 P POOH f/650'-8200'per tripping out parameters @ 8 mins/stand. 10:00 11:00 1.00 11.00 DRILL 1 19 P Reciprocate @ 200'for 1 hour as per procedure.\Up w1.=105K-Dn wt.=105K. 11:00 11:30 0.50 11.50 DRILL 1 4 P Set back jars and NM Flex DC as per Schlumberger. 11:30 15:00 3.50 15.00 DRILL 1 4 P PJSM-Pull and UD inner core barrel and prep to be processed-L/D outer core barrel assembly and bit as per Corpro reps.\Clear and clean floor of coring tools\PIU stand#38 and RIH-remove ball sub-POOH rack back in denick. 15:00 16:30 1.50 16.50 DRILL E 4 P PJSM-P/U and M/U BHA#8 8176'as per Schlumberger reps. 16:30 19:00 2.50 19.00 DRILL E 4 P RIH f/176'-114032'-fill pipe as required. 19:00 19:30 0.50 19.50 DRILL E 6 P Break circulation-ream and wash core section(/4032'-84171'-Stage pump to 730 gpm @ 1500 psi.\80 rpm @ 4-5K torque\WOB 3-5K\Up wt=190K-Dn wt=172K-Rot wt.=182K. 19:30 00:00 4.50 24.00 DRILL E 3 P Drill rotary 8/417i-1/4330'(4201'TVD)\Pumping 750 gpm @ 1620 psi.\80 rpm @ 6-7K torque\WOB=25-30K1 Mud wt.= 9.5 ppg.\Up wt.=190K-Dn wt.=172K-Rot wt.=182K.\ART=3.27 hrs.\ADT=18.17 hrs.\Jars=40.67 hrs. Daily Contacts Position Contact Name ' Company Title _ E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com .907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.cow 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondolling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Dolling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 III* Eni E&P DivisionWell Name: S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name: Nikaitchuq • APIIUWI:629-23466-00-00 2�,r, Date:4/7/2012 - Report#: 17 II iI II page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5120-N4 DRILLING 3/26/2012 3.895.95 1,167.00 4.342.79 128.31 33.8 12.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1.325.88 1,174.47 6.10 0.44 13.9 96.0 -19.8 Cloudy,WC-36.1- 59'ENE @ 15 mph Daily summary operation 24h Summary Drill f/4330'-t 4350'\CBU 2X\POOH back ream(/4330'-5/3860'1 CBU 2X-set back stand each time(/3860'-1/3654.1 Attempt to POOH(/3654'(pulled tight @ 3466')continue POOH back reaming 1/3466'- 1/2909'1 RIH(/2909'-1/4350'\CBU with magnets in ditch\POOH smooth and UD BHA#8 as per Schlumberger.\R/U Schlumberger E-line and P/U tool string.Down time:due to winch,trouble shooting problem and could not diagnose if it was electrical,hydraulic,pneumatic or mechanical-winch worked sporadically.Schlumberger started prepping second unit to replace @ 2000 hrs.Consult with town while on replacement to run logs./Notification to AOGCC of up-coming plug back @ 1718 hrs. Operation at 07.00 Schlumberger E-line logs. 24h Forecast Weight on Schlumberger replacement E-line unit.arnved on location @ 0200 hrs.\R/U E-line and perform two logging run-#1 Quad Combo(open hole)-#2 CMR(Cored section).\R/D Schlumberger E- line.\RIH with 5"DP and cement plug back pilot hole and lay kick-off plug./POOH. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 3 P Drill rotary 8/4330'-114350'(4221').\Pumping 750 gpm @ 1640 psi.\100 rpm @ 7-8K torque WOB=30K\Mud wt.=9.5 ppg.\Up wt.=190K-Dn wt.=172K-Rot wt.=182K./ART=0.44 hrs.\ADT=18.61 hrs.\Jars=41.11 hrs. 00:30 '01:30 ' 1.00 1.50 DRILL E 7 P Circulate bottoms-up(2X)until clean-reciprocate 8/4350'-1/4310'.\Pumping750 gpm @ 1620 psi./80 rpm @ 6K torque./ Rot wt.=182K. 01:30 02:30 1.00 2.50 DRILL E 4 P Back ream f/4350'-1/3860'.Pumping 825 gpm @ 1780 psi.\80 rpm @ 5K torque.\Rot wt=166K. ' 02:30 03:30 - 1.00 3.50 DRILL E 7 P Circulate 2X bottoms-up 8/3860'-1/3654'-rack stand each CBU.\Pumping 825 gpm @ 1780 psi.\80 rpm @ 5K torque./Rot wt=164K. 03:30 05:30 2.00 5.50 DRILL E 4 P Attempt to POOH 8/3654'on elevators-tight @ 3466'/POOH back reaming 8/3466'-5/2909'.1 Pumping 750 gpm @ 1550 psi.\80 rpm @ 5K torque.\Rot wt.=154K.\Trouble shoot Top drive./Install ditch magnets @ 0415 hrs. 05:30 06:30 ' 1.00 6.50 DRILL E 4 P RIH 1/2909'-1/4350'Circulate bottoms-up to remove metal from hole with magnets in ditch for Schlumberger CMR tool run. 06:30 07:30 1.00 7.50 DRILL E 7 P Circulate bottoms-up(2X)with ditch magnets for Schlumberger CMR logs-clean.\Rotate and reciprocate.1 Pumping750 gpm @ 1620 psi.\80 rpm @ 6K torque.\Rot wt=182K. 07:30 08:30 1.00 8.50 DRILL E 4 P POOH 1/4350'-1/3536'as per K&M parameters.\Up wt.=175K-Dn wt.=164K. 08:30 09:00 0.50 9.00 DRILL E 7 P Mondor well-static.\Pumped 20 bbls.of 11.2 ppg dry job-260 gpm @ 240 psi. 09:00 10:30 1.50 10.50 DRILL E 4 P POOH f/3536'-1/106'as per KEN parameters.\Up wl=105K-Dn wt.=105K. 10:30 11:30 - 1.00 11.50 DRILL E 4 P UD BHA#8 per Schlumberger rep. 11:30 12:30 1.00 12.50 DRILL J 19 P Clear and clean floor-PJSM wVSchlumberger-P/U and load tools on floor. 12:30 15:00 2.50 15.00 DRILL J 19 P M/U Quad Combo tool stnng as per Schlumberger.\Hang sheave in blocks and stung E-line to floor. 15:00 16:30 - 1.50 16.50 DRILL J 25 XS03 Down time:Schlumberger E-line winch quit operating(possible break froze-up,heated)and crew and mechanic trouble shoot and perform diagnose on trucks wire line spooler.\Started working again. 16:30 17:30 ' 1.00 17.50 DRILL J 19 P Test tool string•OK.\Load radioactive sources(neutron and gamma)in same and RIH 15'.\Notification to AOGCC of up- coming plug back @1718 hrs. 17:30 22:30 5.00 22.50 DRILL J 25 XS03 Down Time:Schlumberger E-line winch would not operate up or down./Mechanic and crew trouble shooting and could not diagnose the problem if electrical.hydraulic,pneumatic or mechanical-spool worked sporadically and started working after 4 hrs.\Engineer consult with slope manager and shop on problem./Prudhoe Bay shop started prepping replacement truck @ 2000 hrs.\Consult with town to replacing Schlumberger unit-OK. 22:30 00:00 1.50 24.00 DRILL J 25 XDO3 Unload radioactive sources(neutron and gamma)from tools string and secure./R/D sheaves and E-line from derrick and move Schlumberger unit.\Separator top section of logging tools stung(117')for well control./While on Schlumberger replacement unit. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI 'Senior Drilling Supv SIDDrilling@enipetroleum.com 907.685-0715 '715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Maas Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 10 Eni E&P Division well Name:SI20-Na EN!Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • Date:4/8/2012 - Report#: 18 APIIUWI:629-23466-00-00 en page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) [Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3.895.95 1.167.00 4.342,79 128.31 33.8 13.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 1.325.88 1.174.47 0.00 95.0 -22.3 Cloudy,WC-51' 47'ENE @ 20.7 mph Daily summary operation 24h Summary Wait on Schlumberger E-line truck-on location @ 0200 hrs.\Spot unit and re-head rope socket,load sources and connect top section of tool string./Test tools and E-line unit would not work-begin trouble shoot all Schlumberger equipment-change out components and computers on both tools and unit.Found Variac power regulator was bad-changed out./Test all equipment working properly for logging operation.\RIH 1/4333'WLM and log to 13 3/8"csg shoe./POOH and UD tools./P/U Si M/U CMR logging tools and RIH/4210'WLM./POOH logging to 4099'. Operation at 07.00 M/U 5"mule shoe and RIH with 5"drill pipe. 24h Forecast Complete#2 CMR logging run of cored section.\POOH\L/D tools and R/D Schlumberger E-line.\Move 5"HWDP&NM Flex DC to drillers side of derrick./RIH wrath 5"DP w'mule shoe/4350'-circulate& balance mud weights./PJSM-Schlumberger mix&pump balance cement plug for pilot hole-displace with rig./POOH 1/3500'slow\Circulate contaminated cement out and balanced-spot HI-vis pill.',,. POOH 1/3150'and Schlumberger mix&pump balanced cement kick-off plug-displace with rig./POOH. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr), Phase Opr. Act. Plan Oper.Descr. 00.00 02:00 2.00 2.00 DRILL J 24 XW02 Down time:Wait on Schlumberger replacement E-line truck from Deadhorse.\Clean and work on rig PM's. 02:00 04:30 2.50 4.50 DRILL J 20 XS03 Spot unit and re-head rope socket on E-line/PJSM-load radioactive sources(neutron and gamma ray)and M/U top section of tool string and lower in hole.\Pull line to floor and string in sheaves.\Down time. 04:30 09:00 4.50 9.00'DRILL J 20 XS03 M/U rope socket head to tools and test-would not work.Trouble shoot tools-remove PPC and re-test,no good./C/O EDCP retest,would not communicate.\Down time. 09:00 11:30 2.50 11.50'DRILL J 25 XS03 Re-install PPC in tool string and continue trouble shoot Schlumberger truck unit-change out computer and other components-found out Variac power regulator was bad and change out from other unit-retest tools and unit all working properly for logging operation./Down time. 11:30 13:30 2.00 13.50 DRILL J 19 P RIH with w/Quad Combo logging tools.\Tag bottom and confine @ 4333'WLM. 13:30 16:00 2.50 16.00 DRILL J 19 P Log f/4333'WLM to 13 3/8"csg shoe-continue POOH/90'. 16:00 17:00 1.00 17.00 DRILL J 19 P Perform post run Gama calibration-PJSM.\POOH and unload nuclear sources(neutron and gamma)and secure. 17:00 18:30 1.50 18.50'DRILL J 20 'P UD Quad combo tool string. 18:30 20:00 1.50 20.00 DRILL J 20 P P/U and M/U CMR tools string for second logging run. 20:00 22:00 2.00 22.00 DRILL J 19 P RIH with CMR tools 1/4210'WLM. 22:00 00:00 2.00 24.00 DRILL J 19 P POOH logging f/4210'-/4099'WLM as per well plan. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Jack Keener 'ENI Senior Drilling Supv SIDDdlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondnlling.corn 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 813.21 773.78 FazePro 11144 35.8 1577.8 122.0 ffifi* Eni E&P Division I Well Name:S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • 2^ Date:4/9/2012 - Report#: 19 APUUWI:629-23466-00-00 If II page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(/4) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4.342.79 128.31 33.8 14.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,325.88 1,174.47 0.00 98.0 -15.6 Overcast,WC-36.2° 50°ENE @ 23 mph Daily summary operation 24h Summary Schlumberger ran CMR logs(/4099'-t/3910'WLM-RIH and performed five(20 mins.)stationary log points f/4134'-1/3966'WLM.\POOH-L/D tools and R/D Schlumberger E-line.)Move NM Flex DC and 5"HWDP/Jars across derrick to drillers side.\M/U mule shoe and RIH with 5"DP 112523'.1 Safety Stand Down and meeting-monitor well. Operation at 07.00 Safety Stand Down-monitor well. 24h Forecast Safety Stand Down-monitor well. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur(Cr) Dur(Cr) Phase Opr. Act. _ Plan Oper.Descr. 00.00 03:00 3.00 3.00 DRILL J 19 P Continue POOH with Schlumberger CMR logging f/4099'-03910'WLM.\RIH to perform stationary logs @ 4134'-4119'- 4012'-3988'-3966'WLM for 20 minutes each.\Logging completed.)Monitor well with trip tank. 03:00 04:30 1.50 4.50 DRILL J 19 P POOH with CMR tools string(/3966'WLM-I/surface.)Monitor well with trip tank. 0430 05:30 1.00 5.50 DRILL J 19 P PJSM-R/D E-line sheaves and line from rig floor.)POOH and UD Schlumberger CMR tools.)Assist Schlumberger in R/D E-line truck units.)Monitor well. 05:30 06:30 1.00 6.50 DRILL E 4 P PJSM-Move Schlumberger NM Flex DC and 5"HWDP/Jars(5 stds.)across to driller's side of demck.\Monitor well. 06:30 08:30 2.00 8.50 DRILL E 4 •P M/U 5"(4 1/2"IF)mule and OX to 5"drill pipe and RIH to 2533'. 08:30 12:00 ' 3.50 12.00 DRILL E 21 P Safety Stand Down. 12:00 00:00 12.00 24.00 DRILL E 21 P Safety Stand Down and meeting. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dolling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Mats Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroteum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 01141 Eni E&P Division .} ell Name:SizO-N4 ENI Petroleum Co.Inc. Daily Re pQ 1 l Well Code:26302 Field Name:Nikaitchuq • Date:4/10/2012 - Report#: 20 API/UWI:629-23466-00-00 2" " page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 15.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,325.88 1,174.47 0.00 93.0 -12.8 Patchy Fog.WC- 72°ENE @ 17.3 22.5' mph Daily summary operation 24h Summary Safety Stand Doom-monitor well.\Decision to circulate well @ 2515"1 PJSM-stage pump to 168 gpm @ 60 psi.\Pumped surface to surface volume two times. Operation at 07.00 Safety Stand Down still in effect. 24h Forecast Continue Safety Stand Down.\PJSM-finished circulating well and blow down TD.1 Montior well on trip tank. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1138.4 Time Log Start • End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 20:00 20.00 20.00 DRILL E .21 P Safety Stand Down-monitor well. 2000 .00.00 400 24.00 DRILL E 21 P Safety Stand Down\Decision to circulate well bore @ 2515'-Held PJSM-Stage pump rate up to 168 gpm @ 60 psi.- pumped 2X surface to surface volume. Daily Contacts Position Contact Name Company Title E-mail Office Mobile _ Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.cow 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tour Pusher ng15@doyondnlling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) IP LeakOff(kgf/cm') 813.21 773.78 FazePro 1114.4 35.8 1577.81 122.0 I` _* Eni E&P Division I Well Name:S120-N4 EN!Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • API/UWI:629-23466-00-00 2�II II,II r, Date:4/11/2012 - Report#: 21 page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3.895.95 1.167.00 4,342.79 128.31 33.8 16.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,325.86 1,174.47 0.00 91.0 -16.1 Overcast.WC-31.7` 47°ENE @ 18 mph Daily summary operation 24h Summary Continue Safety Stand Down.\PJSM-finished circulating well and blow down TD.\Monitor well on trip tank.\Perform TapRoot investigation and meetings.\HSE requirements for JSA and Hazard Assessment Document. Operation at 07.00 Prep to begin well operation©1200 hrs. 24h Forecast Safety Stand Down-Implementing new JSA and Hazard Assessment Document and Process.\Housekeeping and maintenance.\HSE and operational startup requirements./Notification of service companies.\Notify AOGCC of BOP test./Tentatively to resume well operation @ 1200 hrs.after requirements have been meet.\POOH(/2516'.\Test BOP as per AOGCC requirements.\RIH to spot cement plug back of pilot hole. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 21 P Safety Stand Down./Finished circulating(third time)surface to surface volume pumping 168 bpm @ 60 psi through 5"mule shoe @ 2515'.\PJSM-break out TD and blow down./Install TIW and monitor well with trip tank. 01:30 00:00 22.50 24.00 DRILL E 21 P Stand Down for safety investigation(TapRoot)and meetings.\HSE requirements for JSA and Hazard Assessment Document. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener 'ENI Senior Drilling Supv SIDDnlling@enipetroleum.corn 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondnlling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) -Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 IP* Eni E&P Division ..} .1 -,,-.7-.S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name: Nikaitchuq • Date:4/12/2012 - Report#: 22 APIIUW:629-23466-00-00 2" " page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5120-N4 DRILLING 3'26/2012 3,895.95 1.167.00 4,342.79 128.31 33.8 17.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,325.88 1,174.47 0.00 91.0 -17.8 Clear,WC-43.8 40°NNE @ 25 mph Daily summary operation 24h Summary Safety Stand Down-monitor well on trip tank.)Implementing new JSA and Develop Hazard Recognition Worksheet.)Maintenance.\Meeting @ 0600 hrs.with service companies.)Notified AOGCC of BOP test @ 0635 hrs.and Jeff Jones returned call @ 0641 hrs.and waived witness of test.)Circulate surface to surface volume @ 2523'.1 PJSM-Develop Hazard Recognition Worksheet:Slip and cut drilling line.)POOH(/2523'8 L/D 5"mule shoe.\Pull wear bushing and install test plug with Vetco Gray rep.)R/U and test BOPE with 5 1/2"tubular as per AOGCC. Operation at 07.00 Put test plug and installing wear bushing-JSA. 24h Forecast Complete testing BOPE to AOGCC requirements on remaining 5 1/2"and change to 4 1/2"tubular.)M/U 5"mule shoe and RIH 1/4350'TD.\Circulate hole 8 balance mud weight in/out.)Schlumberger mix/pump cement plug to back of pilot hole,displace.)POOH slowly 63500'8 circulate.)POOH std and pump Nerf Ball wipe DP-balance mud weight in/out.)Spot Hi-vis pill @3400'.\POOH t/3150'8 CBU 2X.\Schlumberger mix/pump cement kick-off plug.)POOH 1/2350'and reverse out.\POOH 2 stds and pump Nerf Ball wipe DP.\POOH with 5"drill pipe 8 L/D mule shoe. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 09.00 9.00 9.00 DRILL E 21 P Safety Stand Down.)Implementing new JSA and Hazard Assessment Document and Process onsite practical training.) Start preparing to commence well operations-function test mud pumps,blow down line and get tools/equipment ready to POOH.\Test PVT sensor and gas sensor to AOGCC requirements.)Monitor well with trip tank.)Notified AOGCC of early BOP test @ 0635 hrs.(Recorder-left message)-Jeff Jones returned call @ 0641 hrs.to waive witness of test. 0900 12.00 3.00 12.00'DRILL E 7 P 'PJSM with JSA/Hazard Assessment:Circulate surface to surface mud volume-pumping(staging rate-up)to 168 bpm @ 70 psi through mule shoe @ 2516.1 Break out TD and blow down.)Monitor well-static.)Continue service rig components. 12:00 15:00 3.00 15.00 DRILL E 25 P PJSM-Develop Hazard Recognition Worksheet.)Slip and cut drilling fine)Check and adjust break knkage. 15:00 18:00 3.00 18.00 DRILL °E 4 P PJSM-Develop Hazard Recognition Worksheet.)POOH f/2523'and L/D 5"mule shoe.)Up wt.=120K./Clean floor. 18:00 19:30 1.50 19.50 DRILL E 20 P PJSM-Develop Hazard Recognition Worksheet.)Pull wear bushing and set test plug with Vetco Gray rep. 19:30 00:00 - 4.50 24.00 DRILL E 12 P PJSM-Develop Hazard Recognition Worksheet.)R/U to test equipment.)Test BOP to AOGCC requirements on 5 1/2" tubular.)Annular @ 250 psi./2500 psi.)Pipe rams(upper),choke manifold,stand pipe,floor and top drive valves 250 psi./3500 psi.-Chart record all test for 5 mins. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Dulling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKEI) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) IP LeakOff(kgflcm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 f* Eni E&P Division I Well Name:S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • Date:4/13/2012 - Report#: 23 APIIl1Wl:629-23466-00-00 e i o page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(in) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1.167.00 4,342.79 128.31 33.8 18.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,325.88 1,174.47 0.00 91.0 -11.5 Clear.WC-23.2 66'ENE @20.7 mph Daily summary operation 24h Summary Completed testing BOPE to AOGCC requirements on remaining 5 1/2"and change to 4 1/2"and 5"tubular./Install wear bushing./M/U 5"mule shoe and RIH V4299'-wash V4350'TD./Circulate hole& balance mud weight in/out.\Schlumberger mix/pump cement pilot hole plug and di e.\POOH slowly 1/3500'&reverse circulate./Pump Nerf Ball wipe DP-balance mud weight in/out./Spot Hi-vis 44 bbls.pill @3400'.\POOH 1/3150'8 CBU 2X. Operation at 07.00 POOH with 5"mule shoe. 24h Forecast Schlumberger mix/pump 120 bbls.cement kick-off plug./POOH 112350'and reverse out one drill pipe volume./POOH 3 stds to 2059'.1 Circulate surface to surface-pump Nerf Ball wipe DP-reciprocate string./POOH with 5"drill pipe&UD mule shoe./P/U BHA#11 Schlumberger assembly./RIH 112000'wait on cement. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) '138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:30 6.50 6.50 DRILL E 12 P Completed testing BOP to AOGCC requirements on remaining 5 1/2"and change to 4 1/2"tubular.\Annular 250/2500 psi. on 4 1/2"tubular./Pipe rams(upper and lower)&blind rams,mud cross choke/kill manual valve and HCR's to 250 psi/3500 psi.-Chart record for 5 mins./Koomey draw down test(Recovery times:1/1400-81 600 psi.(200 psi.)in 50 seconds with final©3000 psi.in 222 seconds-5 Nitrogen bottles @ 2400 psi.average)./Tested lower rams on 5"tubular 250/3500 psi.\Tested A&B manual chokes and hydraulic choke to 1500 psi.-Flow tested gas buster-12 bbls.volume.\ AOGCC Jeff Jones waived witness of test. 06.30 07:30 1.00 7.50 DRILL E 20 P Pull test plug-drain stack and set wear bushing with Vetco Gray-blow down and clean ng floor. 07.30 11:00 3.50 11.00 DRILL E 4 P PJSM-JSA/Hazard Recognition Worksheet.\P/U mule shoe RIH 114299'. 11:00 11:30 0.50 11.50 DRILL E 6 P Wash&ream(/4299'-5/4350'(set down 10K).\Pumping 126gpm @ 130 psi.\50 rpm @ 414 torque. 11:30 14:30 3.00 14.50 DRILL E 7 P Circulate&condition mud for cement job increase rate 168 gpm @ 120 psi./40 rpm @ 4k torque./Rot wt.=158K.\Stage rate up to 336 gpm @ 260 psi. 14:30 16:00 1.50 16.00 DRILL E 20 P PJSM-R/U cement head and dust Mud Push II to 10.5 ppg.-PJSM JSA/Hazard Recognition Worksheet with Schlumberger,Doyon,CH2MHill,MI Swaco for cement job. 16:00 18:00 2.00 18.00 DRILL H 7 P Schlumberger pump fluid pack line with water-test to 500/3500 psi.-good\Switched back to rig pumped 50 bbls.of Citric P•/ eee���"''''(((((( pill @ 9.7 ppg with 5 bpm @ 120 psi.\50 bbls.of Mud Push II @ 10.5 ppg-rate of 5 bpm @ 250 psi.\Shut-down and SLB ll mix&pump slurry 111 bbls.@ 15.8 ppg./G-Blend of 537sks.[1.16 Yield,mix water at 5.103 garsk.]-Pump rate of 4.5 bpm @ 450 psi./Schlumberger pumped 6.5 bbls.water to clear line./Switch back to rig:10 bbls.of Citric pill @ 9.7 ppg with 5 bpm @ 50 psi./Displace with 43 bbls.FazePro pump rate 8 bpm @ 210 psi.-reduce rate to 2 bpm @ 50 psi.the last 13 bbls.-notice 30 psi.increase./Shut down and R/D lines. T/�/ 18:00 18:30 0.50 18.50 DRILL H 4 P PJSM/HRW-POOH(/4350'-1/3500'.\Up wt.158K. 18:30 19:00 0.50 19.00 DRILL H 7 P PJSM/HRW-R/U to reverse circulate 3 bpm @ 400 psi./Calculated 60 bbls.Citrate and 37 bbls.Mud Push II retums during reverse-No cement retums. 19:00 19:30 0.50 19.50 DRILL H 4 P PJSM/HRW-R/D reverse lines-POOH 1/3500'-1/3400'.\Up wt=150K. 19:30 21:00 1.50 21.00 DRILL H 7 P PJSM-Nerf ball to wipe drill pipe./Circulate to balance mud weight in/out(9.5 ppg)./Pump rate 252 gpm @ 190 psi.for drill pipe volume and increased to 336 gpm @ 250 psi. 21:00 21:30 0.50 21.50 DRILL H 7 P Spot 44 bbls.Hi-vis(14.0 ppg)spacer pill @ 3400'.\210 gpm©100 psi. 21:30 22:00 0.50 22.00 DRILL H 4 P POOH(/3400'-1/3148'.\Up w1.=150K. 22:00 00:00 2.00 24.00 DRILL H 7 P Circulate 2X CBU and balance mud weight(9.5 ppg)as per well plan./Pump rate 336 gpm @ 230 psi./Held PJSM/HRW with Schlumberger,Doyon,CH2MHill,MI Swaco for cement job. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener -ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Dulling Tool Pusher ng 15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyen Drilling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOH(kgflcm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 i Eni E&P Division I Well Name:aiz0-N4 ENI Petroleum Co.Inc. Daily ReportWell Code:26302 Field Name:Nikaitchuq e ri Date:4/14/2012 - Report#: 24 APIIUW!:629-23466-00-00 2" " page 1 of 1 Wellbore name: S120-N4 Well Header PermitIConcession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3.895.95 1.167.00 4,342.79 128.31 33.8 19.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 829.06 789.63 25.60 0.05 512.1 91.0 -16.5 Clear,WC 5° 84°ENE @ 3.5 mph Daily summary operation 24h Summary Finished circulating for cement job.\Schlumberger mix/pump 120 bbls.cement kick-off plug./POOH 52347'and reverse out one drill pipe volume-lost returns.\POOH f/2347'-V 2056'.1 Circulate surface to surface-pump Nerf Ball wipe DP-reciprocate string.\POOH with 5"drill pipe&UD mule shoe.\PIU BHA#11(mud motor assembly)t/753'and shallow hole test.\RIH(1753'-111952'.)Wash/ream f/1952'-52636'(tag @ 2510'w/10K).1 Wash/ream 52636'-52720'with cement integrity./POOH V2617'to wait on cement-circulate&condition mud-reciprocate string.(centrifuge down-may be program problem). Operation at 07.00 Time drill to side tracking 12 1/4"well bore. 24h Forecast Wait on cement for compressive strength until 0600 hrs.\Tag kick-off plug and time drill to side track well.\Drill ahead to 9 5/8"csg.point as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1150.3 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL H 7 P Circulate&condition mud for Kick-off plug @ 3148'-Pump 252 gpm @ 220 psi. 00:30 01:30 1.00 1.50 DRILL H 7 P Schlumberger fluid pack lines with H2O-test to 500/3500 psi.-good\Change to rig mud pumps-50 bbls.of Citric pill @ 9.7 ppg rate of 5 bpm @ 120 psi./50 bbls.of Mud Push II @ 10.5 ppg-rate of 5 bpm @ 220 psi./Shut-down and SLB mix &pump slurry 120 bbls.@ 17.0 ppg.\G-Blend of 674 sks.[1.00 ft3/sk Yield,mix water at 3.871 gal/ski-Pump rate of 4.5 bpm @ 165 psi./6.5 bbls.H2O rate of 5 bpm @ 100 psi./Switch to ng mud pumps-10 bbls.of Citric pill @ 9.7 ppg with 5 bpm @ 100 psi./Displaced with 19 bbls.FazePro 9.5 ppg.pump rate 8 bpm @ 220 psi./Cement in place @ 0130 hrs. 01:30 02:30 1.00 2.50 DRILL H 4 P R/D lines./POOH f/3148'-1/2347'(slowly 25-30 ft./min.).\Up wl.=123K. 02:30 03:30 1.00 3.50 DRILL H 7 P R/U to reverse out.\Break circulation 84 gpm @ 100 psi.and increase to 168 gpm @ 340 psi.drill pipe volume pumped returns diminished./Shut down and open to choke static-open Hydril and annulus full./Broke circulation stage up to 126 gpm @ 100 psi.with full retums and pumped 12 bbls.and shut down. 03:30 04:00 0.50 4.00 DRILL H 4 P POOH 1/2347'-t/2056'.1 Up wt.118K. 04:00 05:30 1.50 5.50 DRILL H 7 P Drop Nerf ball to wipe drill pipe./Circulate and condition mud.\Stage rate up to 168 gpm @ 80 psi.\Dump 171 bbls.of contaminated mud. 05:30 06:00 0.50 6.00 DRILL H 20 P Blow down and R/D circulating lines/equipment.1 Monitor well 15 mins. 06:00 07:30 1.50 7.50 DRILL H 4 P PJSM/HRW-POOH f/2056'-Vmule shoe-L/D. 07:30 08:30 1.00 8.50 DRILL E 20 P Clear and clean floor and load with Schlumberger BHA components. 08:30 13:30 5.00 13.50 DRILL E 4 P PJSM/Hazard Recognition worksheet-P/U and M/U BHA#11 with Schlumberger DD/MWD as per well plan./RIH with 5" HWDP 1/753'-perform shallow test pumping 650 gpm @ 1060 psi./20 rpm @ 4K torque./Rot wt.=120K. 13:30 14:30 1.00 14.50 DRILL E 4 -P RIH 1/753'-5/1952'.1 Up wt.=138K-Dn wt=128K. 14:30 18:00 3.50 18.00 DRILL E 6 P Break circulate-Wash and ream f/1952'-5/2636'(tag @ 2510'w/10K)./340-650 gpm @ 515.1350 psi./20 rpm @ 3-5K torque\Wash(/2636'-1/2720'with no integrity(tag @ 2690'w/20K)Up wt.=165K-Dn wt.148K-Rot wt.=158K.\POOH 5/2620'. 18:00 2130 3.50 21.50 DRILL E 21 P Wait on cement-Circulate&condition mud @ 2617.1 Pump 126 gpm @ 180 psi.-reciprocate pipe./Up wt.=163K-Dn wt.=149K-Rot wt.156K. 21 30 00:00 2.50 24.00 DRILL E 21 P Wait on cement-reciprocate string and break circulation every 30 mins.with 126 gpm @ 150 psi./Up wt.=163K-Dn wt.= 149K./Centrifuge down,MI Swaco mechanic working-looks like a program problem. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyen DnIling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Dulling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date _ CASING - 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) IP LeakOff(kgf/cm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 ft* Eni E&P Division I Well Name:S120-N4 EN!Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • 2 I` Il�, Date:4/15/2012 - Report#: 25 APIIUNA:629-23466-00-00 page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0,00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..,Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP)mlhr) DFS(days) 5120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 20.96 Daily Information End Depth)mKB) End Depth(TVD)(... Depth Progress)m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 1,118.62 1,051.16 289.56 9.90 29.2 91.0 -10.3 Fog,WC 6' 6`N @ 2.4 mph Daily summary operation 24h Summary Wait on cement-break circulation and reciprocate pipe until 0500 hrs.\Circulate&condition mud.\Tag kick-off plug w 8K and time dol(/2720'-62763'-(Kick-off @ 2723')to side track-Total 29 hrs. waiting iting on cement. Drill ahead with mud motor as per well plan f/2763'-V3670'. -�- --�`-�� - i Operation at 07.00 r Dolling ahead with 12 114"mud motor assembly-back reaming stand before connection. /) 24h Forecast f //`//'/(y/ Drill ahead to 9 5/8"csg.point as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL E 21 P Wait on cement @ 2620'.1 Break circulation 30 mins.intervals pumping 126 gpm @ 190 psi.\Reciprocate pipe.\Up wt.= 162K-Dn wt.=149K.\Continue working on centrifuge with MI Swaco mechanic. 05:00 06:00 1.00 6.00 DRILL E 7 P Circulate and condition mud pumping 126 gpm @ 190 psi.\Reciprocate 0/2620'-V2526'.\RIH(/2526'-0/2720'.1 Up wt.= 162K-Dn wt.=150K.\Wait a total of 29 hrs.for cement compressive strength to drill. 06:00 10:30 4.50 10.50 DRILL E 3 P Time drill slide f/2720'-V2763'(2633'TVD)-Kick-off @ 27233 Pump rate 405 gpm @ 600 psi.\WOB 2-10K.\Mud wt=9.6 ppg\ECD 9.98 ppg.\Up wt.=163-Dn wt.=148K.\AST=2.91 hrs:ART=0.0 hrs.-ADT=2.91 hrs.\Jars=44.13 hrs. 10:30 12:00 1.50 12.00 DRILL E 3 P Drill slide/rotate f/2763'-1/2839'(2709'TVD).\Pump rate 547 gpm©1130 psi.\38 rpm @ 4-6.5K torque.\WOB 10-30K.\ Mud wt.=9.7 ppg.\ECD 10.05 ppg.\Up wt.=172K-Dn wt.=150K-Rot wt=164K.\AST=0.77 hrs.-ART=0.08 hrs:ADT =3.76 hrs.\Jars=47.04 hrs. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill slide/rotate(/2839'-0/3181'(3039'TVD).\Pump rate 848 gpm @ 2210 psi.\50 rpm @ 9-10K torque./WOB 20-30K.\ Mud wt.=9.5 ppg\ECD 9.90 ppg.\Up wt.=178K-Dn wt.=152K-Rot wt.=163K.\Back reaming stand before making connection.\AST=2.52 hrs.-ART=0.51 hrs.-ADT=6.79 hrs.\Jars=47.89 hrs. 18:00 00:00 6.00 24.00'DRILL E 3 P Drill slide/rotate f/3181'-0/3670'(3450'TVD)\Pump rate 902 gpm @ 2600 psi.\60 rpm @ 9-10K torque.\WOB 30K.\Mud wt.=9.4+ppg\ECD 9.84 ppg.\Up wt.=188K-Dn wt.=155K-Rot wt.=168K.5 Back ream before connection.\AST=2.07 hrs:ART=1.04 hrs:ADT=9.90 hrs.\Jars=51.00 hrs. Daily Contacts Position Contact Name Company Tit% E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon150enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Mutts Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geof.ackennan@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom)mKB) Run Date CASING 13 3/8 12,414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 I� Eni E&P Division I Well Name:aiz0-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • il Date:4/16/2012 - Report#: 26 API/UWI:629-23466-00-00 2" " page 1 of 1 Wellbore name: S)20-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16_46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 21.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,338.07 1,178.20 219.46 11.93 18.4 93.0 -11.0 Mostly Cloudy,Fog. 82°ENE @ 13.8 WC-13° mph Daily summary operation 24h Summary Drill ahead with 12 1/4"mud motor as per well plan 1/3670'-t/4390'.\Back reaming stand before making connection. Operation at 07.00 Drilling ahead slide/rotate as per well plan-Reaming before connection. 24h Forecast Drill ahead to TD for 9 5/8"csg.point as per well plan./Circulate bottoms-up 3X(Set back stand after each CBU).\POOH back reaming to shoe as per K&M parameters.:Circulate until shakers clean.: POOH on elevators and UD BHA#11.\Change rams 89 518"csg.and test to AOGCC requirements.\R/U Tesco casing equipment and prep to run 9 5/8"csg. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1132.4 Time Log Start End Cum Time Time Dur)hr) Dur(hr) Phase Opr. Act. Plan_ Oper.Descr. 00-.00 P 06.00 6.00 6.00 DRILL E 3 P Drill slide/rotate f/3670'-1/3798'(3543'TVD).\Pump rate 904 gpm @ 2580 psi./45-60 rpm @ 7-11K torque.\WOB 25-45K.\ Mud wt.=9.35 ppg.\ECD 9.68 ppg.\Up wt=190K-Dn wt.=150K-Rot wt.=168K./Backream before connection.\AST= 2.35 hrs.-ART=1.26 hrs.-ADT=13.51 hrs.\Jam=54.61 hrs. 0600 12 00 6.00 12.00 DRILL E 3 P Drill slide/rotate 113798'-1/3955'(3649'TVD).\Pump rate 900 gpm @ 2600 psi.\45-60 rpm @ 9-10K torque.\WOB 30-50K.: Mud wt.=9.3 ppg.\ECD 9.66 ppg.\Up wt.=190K-Dn wt=153K-Rot wt.=168K.\Back ream before connection.\AST= 1.71 hrs:ART=0.49 hrs:ADT=15.71 hrs.\Jam=56.81 hrs. 12.00 10 00 6.00 18.00 DRILL 'E 3 P Drill slide/rotate 63955-04172'(3781'TVD).\Pump rate 905 gpm @ 2610 psi.\45 rpm @ 9-10K torque.\WOB 30-50K.\ Mud wt.=9.4 ppg.\ECD 9.70 ppg.\Up wt.=190K-Dn wf.=150K-Rot wt=169K.\Back ream before connection.\AST= 3.16 hrs.-ART=0.28 hrs:ADT=19.15 hrs.\Jars=60.25 hrs. 1800 00 00 6.00 24.00 DRILL E 3 P Doll slide/rotate 04172'-1/4390'(3879'TVD).\Pump rate 701 gpm @ 1840 psi.\40 rpm @ 9-10K torque./WOB 25-50K.\ Mud wt.=9.45 ppg.\ECD 9.83 ppg.\Up wt.=186K-Dn wt.=150K-Rot wt.=163K.\Back ream before connection.\AST= 2.58 hrs.-ART=0.10 hrs.-ADT=21.83 hrs.\Jan=62.93 hrs. Total ADT=21.83 hrs. Total AST=18.07 hrs. Total ART=3.76 hrs. Total Jar=62.93 hrs. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative Jack Keener -ENI -Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Dolling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth)mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) IP LeakOff(kgflcm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 fill)* Eni E&P Division I Well Name:S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • API/UWI:629-23466-00-00 2�, Date:4/17/2012 - Report#: 27 �I II page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 5120-N4 DRILLING 3126i2012 3,895.95 1,167.00 4,342.79 128.31 33.8 22.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,510.89 1,201.57 172.82 9.80 17.6 96.0 -11.1 Mostly Cloudy, 287'WNW @5.8 Patchy Fog,WC 5.2" mph Daily summary operation 24h Summary Drill ahead to TD for 9 5/8"csg.point as per well plan./Circulate bottoms-up 4X(Set back stand after each CBU)./POOH back reaming to shoe as per K&M parameters. Operation at 07.00 POOH 24h Forecast BROOH,CBU,POOH LD BHA.Chg rams to 9 5/8"and test.Dummy run 9 5/8"hgr/landing jt.R/U and run 9 5/8"Csg, Lithology Shows MAASP(kgfIcm') Mud Weight(g/L) 1144.3 Time Log Start End Cum Time Time i Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 3 P Drip.f/4390'-4570'MD(3909'ND)@ 700 gpm,1650 psi,60 rpm,2-50k wob,10k tq on/off.180k puw,150k sow,166k rotw,Max gas 26,9.64 ECD. 3.69 AST,3.69 ADT 06:00 12:00 '. 6.00 12.00 DRILL E 3 'P Ddg.f/4570'-4764'MD(3928'ND)@ 900 gpm,2520 psi,100 rpm,2-40k wob,9k tq on,10k tq off,180k puw,147k sow, 162k rotw,Max gas 42,9.81 ECD.1.25 AST.2.06 ART,3.31 ADT,69.39 Jars,28.83 Bit SPR @ 4763'MD(3929'ND)w/9.4 ppg MW #1 @30-106 psi,@40-180 #3 @ 30-150,@ 40-190 12:00 16:00 - 4.00 16.00 DRILL E 3 'P 'Ddg.f/4764'-4957'MD(3945'ND)@ 901 gpm,2770 psi,100 rpm,30-40k wob,ilk tq on,10k tq 00,180k puw,147k sow,162k rotw,Max gas 1390, 1.47 AST.1.33 ART,2.80 ADT,72.75 Jars,31.03 Bit. SPR @ 4956'MD(3945'ND)kV 9.5 ppg MW #1@30-140,@40-180 #2@30-140,@40-180 #3@30-140,@40-180 psi. 16:00 18:00 2.00 18.00 DRILL E 4 P 'BROOH f/4957'-4709'as per KtiM @ 900 gpm,2600 psi,120 rpm,10k1q. 18:00 00:00 ' 6.00 24.00 DRILL E 4 P 'BROOH 1/4709'-3480'MD @ 900 gpm,2290 psi,120 rpm,7k tq. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Dolling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Malls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE peoff.ackemian@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13,02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 fa* * Eni E&P Division . Well Name: S -N4 ENI Petroleum Co.Inc. Daily Report` Well Code: 26302 Field Name: Nikaitchuq • APIIUWI:629-23466-00-00 2^rl Date:4/18/2012 - Report#: 28 I' �'II page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configurat on type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S120-N4 DRILLING 3/26/2012 3.895.95 1.167.00 4,342.79 128.31 33.8 23.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1 510.89 1.201.57 0.00 96.0 -9.6 Mostly Goody, 316'NNW @ 3.5 Patchy Fog, WC 5.2' mph Daily summary operation 24h Summary BROOH.CBU.POOH LD BHA.Chg rams to 9 5/8"and test.Dummy run 9 5/8"hgr/landing jt.R/U and run 9 5/8"Csg. Operation at 07.00 Circulate and condition mud prior to cement operations. 24h Forecast Run 9 5/8"csg to 4937',circulate and condition mud.Cement as per program with Citrate pill,mud push and 156 bbls of 12.5 ppg cement.Displace cmt w/OBM mud.bump plug and hold wl 500 psi over FCP.Bleed off pressure and R/D cmt equipment. Lithology Shows MAASP(kgl'/cm') Mud Weight(gIL) 1144.3 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 4 P BROOH f/3480'-2618'@ 900 qpm.2220 psi,120 rpm,6k tq,163k puw. 03:00 04:00 1.00 4.00 DRILL E 7 P Circulate hole clean @ 2618'-2523'@ 900 gpm,2000 psi,80 rpm,5k tq,150k puw. 04:00 05:30 1.50 5.50 DRILL E 4 P Attempt to POOH on elevators.Swabbing.BROOH f/2523'-2057'@ 900 gpm,2000psi,80 rpm,4k tq. 05:30 07:00 1.50' 7.00 DRILL E 4 P POOH f/2057'-288'. 07:00 10:30 3.50 10.50 DRILL E 4 P L/D BHA as per SLB DD. 10,30 11:00 0.50- 11.00 DRILL E 20 P Clear and clean dg floor. 11:00 12:00 1.00 12.00 DRILL E 20 P PJSM develop hazard rec.worksheet and pull wear bushing and install test plug as per Velco rep. 12:00 15:00 3.00 15.00 DRILL E 20 P Chg.upper rams to 9 5/8"and R/U test equipment. 15:00 16:00 1.00 16.00 DRILL E 20 P Fill stack w/water and test 9 5/8"rams to 2501 3500 psi for 5 min.R/D,blow down equiprnent and suck out stack. 16:00 19:00 3.00 19.00 DRILL G 20 P PJSM R/U Tesco equipment.Perform dummy run w/hanger/landing jt. 19:00 23:30 4.50 23.50 DRILL G 4 P PJSM R/U and M/U shoe track and test.RIH to 2600'filling every 10 joints. 23.30 00:00 0.50 24.00 DRILL G 7 P CBU @ 2600'staging pumps up to 5 bpm,90 psi.Get K8M rotating parameters,161k rotw,2.6k tq. Daily Contacts Position I Contact Name I Company I Title I E-mail I Office I Mobile Eni representative Mike Ross ENI Senior Dnlling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleuw.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondnIling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Matls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerrnan@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.414 L80 13.02 803.45 3/28/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm) Eq.Mud Weight(gIL) P LeukOff(kgf/cm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 0511` ? Eni E&P Division I Well Name:S120-N4 1 EN!Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • 2�, Date:4/19/2012 - Report#: 29 APIIUWI:629-23466-00-00 II II page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1.167.00 4,342.79 128.31 33.8 24.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,510.89 1,201.57 0.00 92.0 -13.5 Partly Cloudy.Patchy 30°ENE @ 11.5 Fog, WC-14.7" mph Daily summary operation 24h Summary Run 9 5/8"csg to 4937',circulate and condition mud.Cement as per program with Citrate pill,mud push and 156 bbls of 12.5 ppg cement.Displace cmt w/OBM mud,bump plug and hold w/500 psi over FCP.Bleed off pressure and R/D cmt equipment.Perform injectivity w/33 bbls of OBM.Set Vetco pack off and test to 5000 psi for 10 min.Chg rams to 4.5"X7"VBR.R/U and P/U 5"DP and rack back in derrick. Operation at 07.00 R/U to test BOPE. 24h Forecast P/U 5"DP to complete production hole.R/U and test BOPE as per AOGCC.Witness waived per Mat Herrera.Complete freeze protection w/153 bbls of diesel @ 1.5 bpm.800-990 psi.Job completed @ 0030 4-20-2012.P/U and M/U BHA and RIH to TOFC. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1144.3 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 02:30 2.50 2.50 DRILL G 4 P Run 120 jts.9 5/8"409 L-80 Hydril 563 casing.240k puw.210k sow. 02:30 03:00 0.50 3.00 DRILL G 4 P M/U hanger and landing jt.and land casing @ 4937'. ,,LL 03:00 05:00 2.00 5.00 DRILL G 7 P Break circulation @ 1/2 bpm,70 psi and stage up to 6 bpm,160 psi with full retums and reciprocation. ,/ 0500 05:30 0.50 5.50 DRILL G 20 P R/D Tesco casing drive sys. .1-l 05:30 06:30 1.00 6.50 DRILL G 20 P R/U long bails,cement head and circulating equipment. 06:30 09:00 2.50 9.00 DRILL G 7 P Circulate and condition mud @ 5 bpm 160 psi.PJSM for cementing. WT, ( N 09:00 10:00 1.00 10.00 DRILL H 7 P ' / Perform cement job with pumping 40 bbls citrate pill @ 5 bpm,140 psi followed with 80 bbls 10.5 ppg Mud Push©5 bpm. 160 psi and drop bottom plug.Mix and pump 160 bbls 12.5 ppg crate cement and kick out top plug with 10 bbls water. 10:00 12:00 2.00 12.00 DRILL H 7 P Displace cement with 358 bbls of 9.5 ppg OBMI2 5 bpm 160 psi.Reduce rate to 3.5 bpm and bumped plug at 700 psi FCP.Pressure to 1200 psi.CIP @ 1150 hrs.Note:23 bbl losses for cement job. 12:00 12:30 0.50 12.50 DRILL H 19 P Check floats-OK.R/D hoses and blow down lines. 12:30 13:00 0.50 13.00 DRILL H 19 P PJSM Close bag and perform injectivity test with 33 bbls mud @ 2 bpm,950-700 psi. 13:00 14:00 1.00 14.00 DRILL H 20 P PJSM R/D Tesco slips,cmt head and clean,and pull and L/D landing jt. 14:00 17:00 3.00 17.00'DRILL H 19 P C/O bails.P/U a std of HWDP M/U Vetco packoff and set.RILDS and test to 5000 psi for 10 min.R/D same. 17:00 18:00 1.00 18.00 DRILL E 20 P Change out upper rams to 4 1/2"X 7"VBR. r' 18:00 19:00 1.00 19.00 DRILL E 19 P R/U Johnny Wacker and clean stack.R/D same. 19:00 20:00 1.00 20.00 DRILL E 19 P RIH with HWDP,POOH and L/D same. 20:00 20:30 0.50 20.50 DRILL E 20 P P/U and install mouse hole. 20:30 21:30 1.00 21.50 DRILL E 25 P Service rig. 21:30 00:00 2.50 24.00 DRILL E 20 P PJSM P/U and M/U 60 jts DP and rack back in derrick. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative Mike Ross ENI Senior Drilling Supv -SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Matls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 10.86 1,504.95 4/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) •Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 Eni E&P Division I Well Name:S120-N4 Of* ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • Date:4/20/2012 - Report#: 30 API/WN:629-23466-00-00 2" " page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(Vol Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 25.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,510.89 1,201.57 0.00 93.0 -17.1 Party Cloudy,Patchy 13°NNE@ 15 mph Fog, WC-19° Daily summary operation 24h Summary P/U 5"DP to complete production hole.R/U and test BOPE as per AOGCC.Witness waived per Mat Herrera.Complete freeze protection w/153 bbls of diesel @ 1.5 bpm,800-990 psi.Job completed @ 0030 4-20-2012.P/U and M/U BHA and RIH. Operation at 07.00 Drilling shoe track. 24h Forecast RIH and log from 2636'to TO FC @ 4853'.Perform casing test to 3000 psi for 30 min.Displace well to new FazePro mud while dulling shoe track.Drill 20'of new hole and CBU.Perform FIT/LOT.Drill ahead as per SLB DD and Geologists. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1144.3 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 7.00 7.00 DRILL E 20 P P/U 5"DP and rack back in derrick.Freeze protect 13 3/8"X 9 5/8"Annulus with 153 bbls diesel @ 1.5 bpm 750-990 psi. 07:00 07:30 0.50 7.50 DRILL E 20 P Clear and clean floor. 07:30 08:30 1.00 8.50 DRILL E 20 P PJSM set test plug. 08:30 09:00 0.50 9.00 DRILL E 20 P R/U testing equipment. 09:00 16:00 7.00 16.00 DRILL E 12 P Test BOPE as per AOGCC regulations.Witness waived by Matt Herrera.Annular to 250/2500 psi.all other tests @ 250/3500 psi with 3.5"&5.5"test jts. 16:00 16:30 0.50 16.50 DRILL E 20 P R/U and drain stack,remove test plug and install wear bushing as per Vetco. 16:30 17:00 0.50 17.00 DRILL E 12 P Fill hole,close blind rams and pressure test casing to 2000 psi for 5 min. 17:00 18:00 1.00 18.00 DRILL E 20 P PJSM.Develop hazard recognition worksheet for P/U BHA and M/U as per SLB DD. 18:00 22:00 4.00 22.00 DRILL E 4 P P/U&M/U BHA#12 as per SLB DD with Nuclear source and RIH. 22:00 22:30 0.50 22.50 DRILL E 12 P Fill pipe and perform shallow hole test. 22:30 00.00 1.50 24.00 DRILL E 4 P RIH with BHA#12 f/281'-1681'filling pipe every 15 stds. Daily Contacts Position I Contact Name I Company I Title E-mail ' Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon 15@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Matls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 10.86 1.504.95 4/19/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm'( 813.21 773.78 FazePro 1114.4 35.8 1577.8 122.0 Eni E&P Division I Well Name:SI20-N4 01511* ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • 2^rt Date:4/21/2012 - Report#: 31 II APIIUWI:629-23466-00-00 II " page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 26.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,770.89 1,200.83 259.99 5.70 45.6 93.0 -17.8 Overcast,Patchy 30°ENE@ 13 mph Fog,WC-17° Daily summary operation 24h Summary RIH and log from 2636'to TO FC @ 4853'.Perform casing test to 3000 psi for 30 min.Displace well to new FazePro mud while drilling shoe track.Drill 20'of new hole and CBU.Perform FIT/LOT.Drill ahead as per SLB DD and Geologists to 5810'. Operation at 07.00 Drill ahead. 24h Forecast Drill ahead as per plan. • Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 4 P RIH f/1681'-2636',165k puw,150k sow. 00:30 05:30 5.00 5.50 DRILL E 4 P RIH @ 900 fph cement bond logging f/2636'-4761'. 05:30 06:00 0.50 6.00 DRILL E 7 P Wash down @ 2 bpm,140 psi f/4761'-4847'.Set down 10k on cement.170k puw,148 sow,152 rotw. 06:00 07:00 1.00 7.00 DRILL E 7 P Circulate and condition mud @ 500 gpm,1700 psi,20 rpm,reciprocate 4847'-0800'. 07:00 08:00 1.00 8.00 DRILL E 12 P PJSM L/D single,R/U and test 9 5/8"casing to 3000 psi for 30 min charted.R/D&blow down equipment P/U single. 08:00 09:00 1.00 9.00 DRILL E 7 P SPR @ 4819'with 9.15 ppg MW;#2 @ 30-120,@ 40-170,#3 @ 30-120,@ 40-170.Est.rotary parameters @ 500 gpm,1380 psi,60 rpm,5k tq.Drill out cement while swapping mud to new 9.3 FazePro @ 2-10k web I/4847'-4853'Top of Float Collar. 09:00 11:00 2.00 11.00 DRILL E 3 P Drill out shoe track f/4853'-4857'@ 500 gpm,1380 psi,60 rpm,10-12k wob,4-5k tq,tag Float Shoe @ 4934'. 11:00 11:30 0.50 11.50 DRILL E 3 P Drill formation f/4957'-0977'@ 500 gpm,1380 psi,60 rpm,4-10k wob,5-10 tq on,4-8k tq off,162k puw,140k sow,150k rotw,Max gas 9,10.22 ECD,.1 ADT,.1 Jars. 11:30 12:00 0.50 12.00 DRILL E 7 P Circulate&condition mud at drilling parameters. 12:00 13:00 1.00 13.00 DRILL E 19 P PJSM and Develop Hazard Recognition for LOT/FIT.R/U and perform LOT/FIT to 12.9 ppg equivalent. 13:00 13:30 0.50 13.50 DRILL E 20 P R/D from test and clean floor. ' 13:30 18:00 4.50 18.00 DRILL E 3 P Drill f/4977'-5318'MD(3940'ND)@ 550 gpm,1600 psi,120 rpm,8-12k wob,8-10k tq on,6-8k tq off,165k puw,131k sow,150k rotw,Max gas 1560,10.34 ECD.2.05 ADT,2.15 Bit/Jars. 18:00 00:00 6.00' 24.00 DRILL E 3 P Drill f/5318'-5810'MD(3938'ND)@ 550 gpm,1650 psi,60 rpm,8-20k wob,8-14k tq on,8-10k tq off,170k puw,130k sow,150k rotw,Max gas 333,10.44 ECD,3.55 ADT,5.70 Bit/Jars.SPR @ 5785'MD(3940'ND)wd 9.3 ppg MW; #1@30-140,@40-200 • #2 @ 30-140,@ 40-200 • Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907.685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Alex Dunlop Doyon Drilling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Malls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 10.86 1,504.95 4/19/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 1.510.89 1,201.57 FazePro 1114.4 54.8 1570.8 188.7 ft* Eni E&P Division I Well Name:S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • 11 Date:4/22/2012 - Report#: 32 API/DWI:629-23466-00-00 2" " page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) -Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI20-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 27.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,505.15 1,199.56 734.26 15.11 48.6 92.0 -14.6 Overcast,WC-8.7° 38°ENE @ 8 mph Daily summary operation 24h Summary Drill ahead f/5810'-8219'as per Geologist. Operation at 07.00 Drill ahead. 24h Forecast Drill t/8219'as per Geologist to Est TD @ 12,782'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill f/5810'-6345'MD(3944'TVD)@550 qpm,1650 psi,130 rpm,2-16k wob,5-13k tq on,8k tq off,170k puw,125k sow. 150k rotw,Max gas 5000,10.29 ECD,4.61 ADT,10.31 Bit/Jars. 06:00 12:00 6.00 12.00 DRILL E 3 P 'Drill V 6345'-7000'MD(3950'TVD)@ 550 gpm,1800 psi,130 rpm,2-16k wob,9-11k tq on,8-9k tq off.172k puw,127k sow.148k rotw,Max gas 2350.10.64 ECD,3.18 ADT,13.49 BiVJars.SPR @ 6718'MD(3949'TVD)w/9.3 ppg MW #1 @ 30-170,@ 40-230 #2 @ 30-190,@ 40-230 #3 @ 30-180,@ 40-220 12:00 18:00 6.00 18.00 DRILL E 3 P Drill f/7000'-7765'MD(3963'TVD)@ 550 qpm,1900 psi,160 rpm,4-6k wob,9k tq on,7k tq off,175k puw,118k sow, 147k rotw,Max gas 190,10.63 ECD.3.61 ADT,17.10 BiVJars.SPR @ 7652'MD(3961'TVD)wl 9.3 ppg MW #1 @ 30-220,@ 40-290 #2 @ 30-220,@ 40-280 #3 @ 30-220,@ 40-280 18:00 00:00 6.00 24.00 DRILL E 3 P Drill f/7765'-8219'MD(3934'TVD)@ 550 gpm,1920 psi,160 rpm,8-15k wob,9-148 tq on,7k tq off,180k puw,112k sow,142k rotw,Max gas 1516,10.79 ECD,3.71 ADT,20.81 Bit/Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dulling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.cow 907-685-0716 Tool Push Alex Dunlop Doyon Dulling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Dolling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Matls Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 10.86 1,504.95 4/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) 'Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,510.89 1,201.57 FazePro 1114.4 54.8 1570.8 188.7 1* Eni E&P Division I Well Name:S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • API/UWI:629-23466-00-00 en^il Date:4/23/2012 - Report#: 33 page 1 of 1 Wellbore name: S12O-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 28.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,176.63 1,183.02 671.47 15.79 42.5 93.0 -10.4 Cloudy,Snow,WC- 52"ENE @ 17.3 4" mph Daily summary operation 24h Summary Drill f/8219'-10.422'as per Geologist to Est TD @ 12,782'. Operation at 07.00 Drill ahead. 24h Forecast Drill f/10,422'as per Geologist to Est TD @ 12,782'. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1120.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill f/8219'-8865'MD(3909'TVD)@ 550 gpm,2000 psi,160 rpm.2-16k wob,10-12k tq on,2-10k tq off,182k puw,110k sow.145k rotw,Max gas 1125,10.94 ECD,4.34 ADT,25.15 Bit/Jars.SPR @ 8865'MD(3909'TVD')w/9.4 ppg MW. #1 @30-260.@40-350 #2 @ 30-270,@ 40-350 #3 @ 30-300,@ 40-350 06:00 12:00 6.00 12.00 DRILL E 3 P Drill f/8865'-9344'MD(3910'TVD)@ 550 gym,2080 psi,160 rpm.2-16k wob,10-12k tq on.9k tq off,180k puw,115k sow,145k rotw,Max gas 1230,11.07 ECD,3.38 ADT,28.53 Bit/Jars. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill f/9344'-9825'MD(3890'WD)@ 550 gpm,2150 psi,160 rpm.6-8 wob,12-14k tq on,10-11k tq off,175k puw,100k sow,140k rotw,Max gas 130.11.27 ECD,4.57 ADT,33.10 Bit/Jars. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill f/9825'-10,422'MD(3880'TVD)@ 550 gpm,2190 psi,160 rpm,8-14k wob,12-14k tq on,11-13k tq off,185kpuw, 98k sow,142k rotw,Max gas 1600,11.45 ECD,3.50 ADT,36.60 Bit/Jars.SPR @ 9889'MD(3888'TVD)ed 9.3 ppg MW. #1 @ 30-280,@ 40-360 #2 @ 30-290,@ 40-360 #3 @ 30-300.@ 40-360 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dulling Supv 'SIDDnlling@enipetroleum.com 907.685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondnIling.com 907-685-0716 Tool Push Alex Dunlop Doyon Dulling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Mat's Coordinator 907-685-0718 Eni representative Geoff Ackerman ENI HSE geoff.ackerman@enipetroleum.co 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 10.86 1,504.95 4/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 1,510.89 1,201.57 FazePro 1114.4 54.8 1570.8 188.7 Eni E&P Division Well Name:5I20-N4 Orif* ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • Date:4/24/2012 - Report#: 34 APIIUWI:629-23466-00-00 i i " page 1 of 1 wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 29.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3.754.53 1,181.81 577.90 14.82 39.0 93.0 -9.6 Cloudy,Light Snow, 54'ENE @ 6 mph WC T Daily summary operation 24h Summary Drill f/10,422'-12,318'as per Geologist to Est TD @ 12,782'. Operation at 07.00 Perform cleanup cycle as per KEN. 24h Forecast Drill to Geologist's TD @ Circulate and BROOH as per KW schedule. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11204 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL 'E 3 P Drill f/10,422'-10,735'MD(3894'TVD)@ 550 gpm,2190 psi,160 rpm.2-14k wob,13-14k tq on 1l k tq off,198k puw, 100k sow,141k rotw,Max gas 1600,11.37 ECD.4.4 ADT,41.0 Bit/Jars. 06:00 12'.00 6.00 12.00 DRILL E 3 P Drill f/10,735'-11,265'MD(3881'ND)@ 550 gpm,2280 psi,160 rpm,2-18k wob,12-13k tq on,9-10k tq off,188k puw, 141k rotw,Max gas 471,11.4 ECD,3.71 ADT,44.71 Bit/Jars.SPR @ 10,918'MD(3894'ND)w/9.35 ppg MW; #1 @ 30-360,@ 40-420 #2 @ 30-350,@ 40-430 #3@30-370,@40-430 12:00 18:00 6.00 18.00 DRILL E 3 P Drill f/11,265'-11,853'MD(3873'ND)@ 550 gpm,160 rpm,6-10k wob,12-15k tq on,9-10k tq off,175k puw,140k rotw, Max gas 960,11.67 ECD,3.53 ADT,48.24 Bit/Jars.SPR @ 11,851'MD(3867'TVD)w/9.35 ppg MW. #1©30-320,@ 40-400 #2©30-330,@40-390 #3©30-330,@40-400 1800 0000 6.00 24.00 DRILL 'E 3 P Drill f/11,853'-12,318'MD(3875'TVD)@ 550 gpm,2420 psi.160 rpm.10-18k wob,15-17k tq on,13k tq off,185k puw. 143k rotw,Max gas 136,11.75 ECD,3.18 ADT,51.42 Bit/Jars. Daily Contacts , Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Alex Dunlop Doyon Dnlling Tour Pusher 907-685-0716 Eni representative Tom Norvig ENI Dnlling Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKEt) Run Date CASING 9 5/8 8.835 L80 10.86 1.504.95 4/19/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') 'Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1.510.89 1,201.57 FazePro 1114.4 54.8 1570.8 188.7 IIII* Eni E&P Division 'Well Name:S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • API/INN:629-23466-00-00 2 „I^ Date:4/25/2012 - Report#: 35 II 'l Ipage 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 30.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,897.17 1,185.32 142.65 5.57 25.6 97.0 -10.1 Cloudy,Fog,Light 199'SSW @ 3.5 Snow,WC 6° mph Daily summary operation 24h Summary Drill to Geologist's TD @ 12,786'MD(3887 ND)Circulate and BROOH to 10.269'as per K8M schedule. Operation at 07.00 BROOH 24h Forecast BROOH to inside csg.shoe and CBU.POOH on elevators.L/D BHA. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 07:00 ' 7.00. 7.00 DRILL 'E 3 P Drill f/12,318'-12,786'MD(3887'TVD)@ 550 gpm,2500 psi,160 rpm,2-18k wob,13-15k tq on,2-6k tq off,185k puw, 143k rotw,Max gas 474,11.71 ECD,5.57 ADT,56.99 Bit/Jars. 07:00 07:30 ' 0.50' 7.50 DRILL 'E 19 P SPR @ 12,786'MD(3887'ND)w/9.4 ppg MW. #1 @ 30-340,@ 40-440 #2@30-340,@40-420 #3 @ 30-360,@ 40-430.Monitor well-Static. 07:30 17:00 ' 9.50' 17.00 DRILL -E 4 P BROOH f/12,786'-11.762'@ 550 gpm,2350 psi,130 rpm,10-13k tq,180k puw,100k sow,140 rotw.Cleanup cycle;Rack back std every Btms Up for 5 BU/then 2 stds/BU for 6 stds. 17:00 00:00 ' 7.00' 24.00 DRILL /E 4 P BROOH f/11,762'-10,269'@ 550 gpm,2220 psi.130 rpm,10-11k tq,175k pow,110k sow,145k rotw Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dolling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher ng15@doyondriiling.com 907-685-0716 Eni representative Tom Norvig ENI Dolling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Matls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 10.86 1.504.95 4/19/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1,510.89 1,201.57 FazePro 1114.4 54.8 1570.8 188.7 VI* Eni E&P Division I Well Name: SILO-N4 EN!Petroleum Co.Inc. Daily Report Well Code:26302 Field Name: Nikaitchuq • fl Date:4/26/2012 - Report#: 36 API/UWI:629-23466-00-00 2" " page 1 of 1 Wellbore name: 5120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP)mlhr) DFS(days) 0120-N4 DRILLING 3/26/2012 3,895.95 1.167.00 4,342.79 128.31 33.8 31.96 Daily Information End Depth)mKB) End Depth(TVD)(... Depth Progress)m) Drilling Hours)hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3.897.17 1,185.32 0.00 97.0 -8.8 Cloudy.Fog,Light 9'N @ 1.2 mph Snow,WC 15' Daily summary operation 24h Summary BROOH to inside csg.shoe and CBU.POOH on elevators. Operation at 07.00 RIH w/hole opener assembly. 24h Forecast Finish POOH,Rack back collar std with jars&HWDP.L/D BHA.M/U hole opener assy.and RIH to 12,786'.CBU and have MW @ 9.4 ppg. Lithology Shows MAASP(kgf/cm) Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL E 4 P BROOH f/10,269'-6625',@ 550 gpm.2250-1750 psi,130 rpm,8k tq. 12:00 17:00 5.00 17.00 DRILL E 4 'P BROOH f/6625'-4930',550 gpm,1550 psi,120 rpm,6-8k tq,160k puw,140k sow,150k rotw. 17:00 18:30 1.50 18.50 DRILL E 7 'P CBU @ 4930'vd 550 gpm,1600 psi,120 rpm. 18:30 20:00 1.50 20.00 DRILL E 4 'P POOH f/4930'-4200'. 20:00 00:00 4.00 24.00 DRILL E 4 P Pump slug and POOH f/4200'-281'. Daily Contacts Position Contact Name Company Title E-mall Office Mobile Eni representative Jack Keener ENI Senior Dnlling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher ng15@doyondnlling.com 907.685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Matls Coordinator 907-685-0718 Eni representative Jack Pofter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKEt) Run Date CASING 95/8 8.835 L80 10.86 1,504.95 4/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) IP LeakOff(kgf/cm') 1,510.89 1,201.57 FazePro 11144 54.8 1570.8 188.7 TIOsEni E&P Division ..} I Well Name: S120-N4 ENI Petroleum Co.Inc. Daily Re pO 1 l Well Code:26302 Field Name: Nikaitchuq • 2�,r, Date:4/27/2012 - Report#: 37 API/t1Wl:629-23466 -00 II II II page 1 of 1 Wellbore name: SI20-N4 - Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) S120-N4 DRILLING 3/26/2012 3.895.95 1,167.00 4.342.79 128.31 33.8 32.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,897.17 1.185.32 0.00 93.0 -7.1 Panty Cloudy.WC 9° 44°NNE @ 11 mph Daily summary operation 24h Summary Finish POOH,Rack back collar std with jars&HWDP.L/D BHA.M/U hole opener assy.and RIH to 12,786'.CBU and have MW @ 9.4 ppg. Operation at 07.00 Spot FazeAway Breaker. 24h Forecast Displace hole to FazeAway Breaker Fluid @ 9.5 ppg.POOH on elevators. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 20 P Monitor well @ 281'and PJSM for Nukes. 00:30 01:00 0.50 1.00 DRILL E 4 P Rack back HWDP/Jars/NMFIex DC's. 01:00 01:30 0.50 1.50 DRILL E 20 P Unload Nukes. 01:30 03:00 1.50 3.00 DRILL E 4 P L/D BHA 03:00 04:00 1.00 4.00 DRILL E 20 P Clear and clean floor. 04:00 05:00 1.00 5.00 DRILL E 4 P PJSM P/U&M/U BHA#13 as per SLB DD f/0-174'.Fill pipe and K&M gets rotating weight @ 84k. 05:00 09:00 4.00 9.00 DRILL E 4 P RIH f/174'-4841'filling pipe every 20 stds.165k puw,140k sow. 09:00 10:00 1.00 10.00 DRILL E 20 P PJSM&Complete Hazard Recognition Worksheet for Stip-N-Cut Drtg Line/Work on Wichita Brakes. 10:00 11:30 1.50 11.50 DRILL E 20 P Cut-n-Slip 128'drlg line.Inspect brakes,service ng. 11:30 12:00 0.50 12.00 DRILL E 4 P RIH f/4841'-5770',165k puw,140k sow. 12:00 18:00 6.00 18.00 DRILL 'E '4 P RIH f/5770'-12,776',190k puw,110k sow. 18:00 00:00 6.00 24.00 DRILL E 7 P CBU and condition mud to 9.4 ppg @ 550 gpm,2000 psi.60 rpm,180k puw,t00k sow,139k rotw.SPR @ 12,786'MD (3867'ND)w/9.4ppg MW; #1 @30-320,@40-370 #2@30-320,@40-370 Mixing FazeAway breaker @ mud plant. Daily Contacts Position Contact Name Company Title • E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com '907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Malts Coordinator 907-685-0718 Eni representative Jack Potter ENI I HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 10.86 1,504.95 4/19/2012 Last Leakoff Test Depth)mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1.510.89 1,201.57 FazePro 1114.4 54.8 1570.8 188.7 Eni E&P Division I Well Name: SizU-N4 ENI Petroleum Co.Inc. Daily ReportWell Code:26302 Field Name:Nikaitchuq VI* • APIIUWI:629-23466-00-00 2�, Date:4/28/2012 - Report#: 38 II II page 1 of 1 wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(in) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3.895.95 1,167.00 4,342.79 128.31 33.8 33.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3.897.17 1.185.32 0.00 98.0 -11.0 Partly Cloudy.WC 3' 83'ENE @ 9.6 mph Daily summary operation 24h Summary Displace hole to FazeAway Breaker Fluid @ 9.5 ppg.POOH on elevators to 4700'.Displace well to 9.1 ppg brine. Operation at 07.00 Running 5.5"Liner. 24h Forecast POOH&L/D BHA 8 13.R/U and run 5.5"Liner as per plan. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 01:30 1.50 1.50 DRILL E 7 P Circulate and condition mud @ 550 gpm,2000 psi 60 rpm 180k puw,100k sow,139k rotw.Prep.to spot FazeAway breaker. 01 30 05:30 4.00 5.50 DRILL E 7 P PJSM Prime line from mud plant w/LVT and pump 595 bbls of 9.5 ppg FazeAway Breaker @ 4 bpm,400 psi,30 rpm,ilk tq followed w/42 bbls of 9.4 ppg FazePro and 20 bbls 10.9 ppg dry job. 05:30 06:00 0.50 6.00 DRILL E 20 P PJSM,L/D single,monitor well and blow down top-drive. 06:00 12:00 6.00 12.00 DRILL E 4 P POOH f/12,773'-8800'as per KM schedule. 12:00 19:00 7.00 19.00 DRILL E 4 P POOH f/8800'-4737',112k puw. 19:00 20:00 1.00 20.00 DRILL E 20 P Monitor well and PJSM/Hazard rec.worksheet on brine displacement. 20:00 21:00 1.00 21.00 DRILL E 20 P Move mud and prep.for displacement. 21:00 23:00 2.00 23.00 DRILL E 7 P Displace well w/43 bbls of LVT+77 bbls Citric acid pill+370 bbls 9.1 ppg KCL inhibited brine w/0.5%Safe Lube @ 6 bpm.170 psi,78 rpm. 23:00 00:00 1.00 24.00 DRILL E 20 P Clean surface equipment and prep.for POOH. 96 bbls losses for day. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dolling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Matis Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.poner@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 10.86 1,504.95 4/19/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) IP LeakOff(kgflcm') 1.510.89 1,201.57 FazePro 1114.4 54.8 1570.81 188.7 Ili* Eni E&P Division I Well Name: S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name: Nikaitchuq • Date:4/29/2012 - Report#: 39 API/UWI:629-23466-00-00 2" " - page 1 of 1 Wellbore name: S(20-N4 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 DRILLING 3/26/2012 3,895.95 1.167.00 4,342.79 128.31 33.8 34.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,897.17 1,185.32 0.00 100.0 -10.0 Cloudy,WC 3` 131°ESE @ 9.6 mph Daily summary operation 24h Summary POOH&UD BHA#13.R/U and run 5.5"Liner as per plan. Operation at 07.00 POOH LDDP. 24h Forecast RIH w/5.5"liner on DP to 12,746'and set Baker liner packer.test and release from hanger.POOH and LDDP. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 02:30 2.50 2.50 DRILL E 20P Clean surface equip.,trip tank,possum belly,drip pan,floor etc.Drop rabbit down drill string and do poor boy dry job. 02:30 05:00 2.50 5.00 DRILL E 4P POOH on elevators 5/4737'-BHA. 0500 06:00 ' 1.00 6.00 DRILL E 4P L/D BHA 06.00 08.30 2.50 8.50 DRILL E 20 P Clear and clean floor area of tool and equip.P/U liner tools and equip.R/U GBR casing. 08.30 12.00 3.50 12.00 DRILL G 4 P PJSM and develop hazard rec.worksheet.M/U 5.5"shoe and RIH with 5.5"15.5#L-80 Hydril 521 Slotted liner w/swell packers on blanks as per tally to 2000'.98k puw,100k sow. 17.00 20.00 8.00 20.00 DRILL G 4P RIH vd 5.5"slotted liner f/2000'-8053'(total of 193 pieces).105k sow. 20.00 21 00 1.00 21.00 DRILL G 4P P/U&M/U Baker SLZXP Liner Packer and running tools as per Baker rep.Fill Frier tieback with Pal-Mix and let set for 30 min.RIH 1 std of DP,break circulation and record rotes @ 130k. 21 00 00.00 3.00 24.00 DRILL G 4 P RIH w/5.5"liner on DP f/8053'-10,991',143k rotw. Note;daily fluid losses @ 75 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv, SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 1,421.08 3,884.98 4/29/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1.510.89 1,201.57 FazePro 1114.4 54.8 1570.8 188.7 It* Eni E&P DivisionWell Name:IuzO-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • APIIUWI:629-23466-00-00 2 II^n Date:4/30/2012 - Report#: 40 II 'Ipage 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-N4 DRILLING 3/26/2012 3,895.95 1,167.00 4,342.79 128.31 33.8 35.96 Daily Information End Depth(mKB) End Depth(TVD)(...'Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3.897.17 1,185.32 0.00 97.0 -11.0 Party Cloudy,Fog, 246°WSW @ 4.7 WC 1° mph Daily summary operation 24h Summary RIH w/5.5"liner on DP to 12,746'and set Baker liner Hanger,test and release from hanger.POOH and LDDP. Operation at 07.00 Working on completion equipment. 24h Forecast LDDP.Load completion equipment in pipe shed and on rig floor,tally and inspect.When ready,P/U and M/U and RIH. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1090.4 Time Log Start ' End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL G 4 P RIH w/5.5"15.58 L-80 Hydril 521 liner on DP f/10,991'-12,670'fill pipe and establish rotating parameters @ 150k,10k tq. P/U std#50 and RIH to 12758',115ksow.Drop Baker setting ball,M/U top-drive and pull up to setting depth of 12,746', 190k puw. 02:00 02:30 0.50 2.50 DRILL G 19 P PJSM R/U testing equipment and pump Baker ball down string @ 2 bpm,60 psi.Seated ball and pressure up tp 3000 psi and hold for 10 min.to set packer.Slk off to 80k and increase pressure to 4000 psi to shear off of liner.Bleed pressure. Liner set and top of liner @ 4662'. 02:30 03:00 0.50 3.00 DRILL G 12 P Test liner packer by closing annular preventer and pumping down kill line to 1500 psi for 10 min.charted.Bleed pressure and R/D test equipment. 03:00 03:30 0.50 3.50 DRILL G 19 P Verify liner set by rotating and setting down on liner top as per Baker rep.Pull running tool from liner and rack back stand. 03:30 04:00 0.50 4.00 DRILL G 20 P Monitor well and blow down top-drive and kill line.Prep.for LDDP. 04:00 08:30 4.50 8.50 DRILL G 4 P POOH and LDDP f/4613'. 08:30 09:00 0.50 9.00 DRILL G 4 P Break out XO's and UD running tool as per Baker Tool. 09:00 09.30 0.50 9.50 DRILL E 20 P Clear and dean floor.P/U thread protectors and install mousehole. 0930 12.00 2.50 12.00 DRILL E 4 P PJSM and develop Haz.Rec.Worksheet.L/D 66 Its.of 5"DP from derrick w/mousehole. Note,31 bbl fluid loss for tour. 12:00 21:00 9.00 21.00'DRILL 'E 4 P RIH wl 64 stands/POOH UD singles. 21:00 21:30 0.50 21.50 DRILL E 20 P PJSM P/U completion handling equipment to ng floor. 21:30 00,00 2.50 24.00 DRILL E 4 P LDDP. Note:51 bbl fluid loss for tour. Daily Contacts Position Contact Name Company Title E-mail Office _ Mobile Eni representative Jack Keener ENI Senior Dolling Supv 'SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Sach Bowe ENI Mafls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipelroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) I Run Date _ LINER 51/2 4.950 L80 1,421.08 3,884.98 4/29/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) IP LeakOff(kgflcm') 1.510.89 1,201.57 FazePro 1114.4 54.8 1570.8 188.7 VP* Eni E&P Division I Well Name: S120-N4 EN!Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • API/t1Wl:629-23466-00-00 ten Date:5/1/2012 - Report#: 1 opage 1 of 1 wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16,46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 COMPLETION 3/26/2012 3,897.17 36.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 100.0 -11.5 Overcast,WC 1 317'NNW @ 4.7 mph Daily summary operation 24h Summary L/D 5"drill pipe from derrick.\Flush OBM from choke manifold and stack with 9.1 ppg brine.\Clear and clean floor.\PJSA-Load rig floor with completion jewelry and R/U Schlumberger,Halliburton and GBR tools/equipment.\PJSA-P/U 3 1/2"lower completion assembly as per well plan f/bull rose-t/4732'.1 Fluid loss for 24 hrs.87.5 bbls. Operation at 07.00 Running 3 1/2"lower completion assembly. 24h Forecast RIH w/lower completion string-switch to 4 1/2"tbg.and P/U Halliburton packer assembly and spice fiber optic-continue RIH completion.\Land tubing hanger,test seals to 5000 psi.\R/U pump down tbg. and set packer as per well plan-perform for 30 mins.(chart record)integrity on tbg and annulus. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1090.4 Time Log Start End Cum Time _ Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01 00 1.00 1.00 DRILL K 4 P PJSA-L/D remaining drill pipe out of derrick(30 jIs.) 01 00 02.00 1.00 2.00 DRILL K 7 P PJSA-R/U and flush choke manifold and lines with 9.1 ppg brine./P/U Johnny whacker and flush OBM residue out stack with 9.1 ppg brine./L/D same. 0200 03.30 1.50 3.50 DRILL K 5 P 'PJSA-P/U and pull wear bushing with Vetco Gray-R/D.\Clear and clean floor of tools and equipment. 03.30 09.30 6.00 9.50 DRILL K 1 P PJSA-Load completion tools/equipment to ng floor and R/U as per GBR,Halliburton and Schlumberger. 09:30 °1200 2.50 12.00 DRILL K 4 P 'PJSA with all parties involved completion.\P/U gauge mandrel assembly and Schlumberger install down hole gauge with fiber optic cable and test.\P/U ICD sub#1.1 RIH t/129'.112 hrs.loss=47.5 bbls. 12.00 18.00 6.00 18.00 DRILL K 4 P PJSA-P/U 3 1/2"(9.28;L-80,IBTM)tbg.f/129'-U1991'-as per tally details and well plan with Schlumberger,Halliburton and GBR./Instating champs and bands as required. 18:00 '00.00 6.00 24.00 DRILL K 4 P PJSA-P/U 3 1/2"(9.2#;L-80;IBTM)tbg.f/1991'-U4732'-as per tally details and well plan with Schlumberger,Halliburton and GBR.\Test every+/-1000'and record gauge readings.\Dn wt.=105K.\12 hrs.loss=37 bbls.-Total loss for 24 hrs.= 84.5 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 632-3058 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Mafls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Can.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 1,421.08 3,884.98 4/29/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1.510.89 1,201.57 FazePro 1114.4 54.8 1570.8 188.7 fliii* Eni E&P Division ., 'Well Name:S120-N4 ENI Petroleum Co.Inc. Daily Report Well Code:26302 Field Name:Nikaitchuq • API/UWI:629-23466-00-00 2^�I rl Date:5/2/2012 - Report#: 2 II II page 1 of 1 Wellbore name: S120-N4 Well Header Permit/Concession N" Operator ENI ShareConfiguration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) S120-N4 COMPLETION 3126/2012 3.897.17 37.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature ICI Weather Wind 0.00 100.0 -13.9 Overcast,WC-5 264°NE @ 7.3 mph Daily summary operation 24h Summary P/U 3 1/2"lower completion assembly per tally details&well plan 1/4732'-(/7838'.\Change out from 3 1/2"to 4 1/2"tbg.tongs/handling equipment.\P/U four joints 4 1/2"tbg.and Halliburton Mirage plug/auto fill assemblies followed by MFA packer assembly f/7838-08100'.1 Schlumberger cut fiber optic and electric lines-feed thru and splice back-tested good./Continue P/U 4 1/2"tbg completion assembly as per tally details&well plan f/8100'-1/10396'.(Found debris in joint#24 drift remaining joints in pipe shed t/3.833").\Fluid loss:24 hrs.=51 bbls.and total to well bore 299 bbls.) Operation at 07.00 Running 4 1/2"completion assembly as per tally and well plan details./P/U tbg hanger with Vetco Gray rep. 24h Forecast RIH with 4 1/2"tbg.completion string./P/U&land tubing hanger(test).\R/U to pump and set packer as per Halliburton procedures-perform for 30 mins.(chart record)integrity on tbg.completion string and annulus./Shear valve in GLM.\L/D landing joint and install BPV./N/D BOP stack./N/U tree with Vetco Gray and test same. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 -08:00 8.00 8.00 DRILL K 4 P PJSA-P/U 3 1/2"(9.2#;L-80;IBTM)tbg.f/4732'-5/7838'per tally details-P/U 3 1/2"gauge carrier-Schlumberger M/U electric line and installed gauge./Test fiber optics&electric*1-1000'\Up wt=116K-Dn wt.=93K. 08:00 09:00 1.00 9.00 DRILL K 20 P PJSA-R/D and clear floor of 3 1/2"equipment./R/U GBR 4 1/2"tbg.tongs/handling equipment.\Dress floor valves with Hydril 563 xo's./R/U torque turn equipment. 09.00 10:00 1.00 10.00 DRILL K 4 P PJSA-P/U 4 jts.4 1/2"(12.6#,L-80;Hydril 563)tbg;Halliburton mirage plug/auto fill assembly and MFA packer assembly f/7838'-5/8100'as per well plan./Up wt.=118K-Dn wt.=93K. 1000 12:00 2.00 12.00 DRILL 'K 4 P PJSA-Schlumberger cut electric wire and fiber optic line thread thru packer assembly,Halliburton installed fitting and pressure test 05000 psi.(witness by ENI Rep).\Schlumberger started to splice lines./12 hrs.loss=22 bbls. 1200 17.30 5.50 17.50-DRILL K 20 P PJSA-Schlumberger spliced electrical and fiber optic lines.(Witnessed by ENI company&completion rep.)./All tested good. 17.30 19.30 2.00 19.50 DRILL �K 4 P Continue RIH-P/U 4 1/2"(12.6#;L-80;Hydnl 563)tbg.f/8100'-1/8905'-as per tally details/well plan W Schlumberger, Halliburton and GBR reps-Torque tam connection./Installing clamps as required./Test electrical and fiber optics lines every+/-1000'.1 Dn wt.=95K. 1930 '2030 1.00 20.50 DRILL K .20 .P Debris found in joint#24 of 4 1/2"lbg.\L/D and re-drifted joint to 3.833 and remaining joints in pipe shed. 2030 '00.00 3.50 24.00'DRILL K 4 P PJSA-P/U 4 1/2"(12.6#;L-80;Hydril 563)tbg.f/8905'-1/10396'-per tally and well plan with Schlumberger,Hallibunon and GBR.\GBR torque tum connection.\Test every-f/-1000'on fiber optic and electric lines./Dn wt.=95K.\12 hrs.toss=29 bbls.-Total loss for 24 hrs.=51 bbls. Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Dulling Supv. SIDDnlling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rigl 5©doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleum.com 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date _ LINER 51/2 4.950 L80 1,421.08 3.884.98 4/29/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) IP LeakOff(kgflcm') 1,510.89 1,201.57 FazePro 1114.4 54,8 1570.8 188.7 Eni E&P Division . I Well Name: S120-N4 IP* ENI Petroleum Co.Inc. Daily Report` Well Code:26302 Field Name: Nikaitchuq • API/UWI:629-23466-00-00 2�,r, Date:5/3/2012 - Report#: 3 �` II II page 1 of 1 wellbore name: S120-N4 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.46 3.99 0.00 5.19 Rig Information Contractor Rig Name Rig Type DOYON DRILLING DOYON 15 LAND RIG Job Information Wellbore !Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SI20-N4 COMPLETION 3/26/2012 3.897.17 38.96 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 100.0 -17.2 Overcast.WC-3 313'NNW @ 7 mph Daily summary operation 24h Summary RIH with 4 1/2"tbg.completion string f/10396'-1/12434'.\P/U landing jt.and dress tbg hanger-found tree neck seals damaged-change out tbg hanger&redress\Land tubing hanger(Vetco Gray verified and tested 1/5000 psi).\R/U to pump and set packer as per Halliburton procedures-perform for 30 mins.(chart record)each integrity on tbg.completion string(3500 psi)and annulus(2500 psi).\Shear valve Mirage plug @ 4400 psi.bleed off.\Shear valve in GLM.\UD landing joint and install BPV.\N/D BOP stack.\N/U tree with Vetco Gray and test void U 5000 psi.f/10 mins. Operation at 07.00 Displace annulus and tbg.with diesel-Little Red pump down annulus thru GLM with returns to rig choke manifold./Halliburton R/U to change out sheared valve in GLM. 24h Forecast Pull BPV and install TWCV-test tree per well plan.\Pull TWCV./R/U manifold and Little Red-displace annulus and tbg with diesel-R/D\R/U Halliburton slick line-change our sheared valve in GLM- R/D.\Secure tree and wellhead./Schlumberger to splice fiber optic off wellhead./RDMO Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1090.4 Time Log Start End Cum Time Time Dur(hr) Dar(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 0430 4.50 4.50 DRILL K 4 P PJSA-P/U 4 1/2"(12.65,L-80;Hydril 563)tbg.(/10396'-5/12434'-per tatty and well plan with Schlumberger,Halliburton and GBR.\GBR torque turn connection and install poly clamps./Test every+/-1000'on fiber optic and electric lines./Up wt.=152K On wt.=92K. 0430 0630 2.00 6.50 DRILL K 19 P PJSA-P/U landing joint-tbg.hanger w/pup-XO pup(4 1/2"IBTM x Hydril 563)-M/U to spec.w/Vetco gray rep.\Notice damage to tree neck seal of tbg.hanger./B/O and UD hanger./P/U new spare tbg.hanger and dress./M/U to tbg. 06.30 07.30 1.00 7.50 DRILL K 19 P PJSA-Schlumberger dressed/feed electrical and fiber optic thru hanger-test lines and wrap around tbg. 0730 08.30 1 00 8.50 DRILL K 4 P PTSA-Drain BOP stack and rinse stack./Land Ibg,hanger and verified by Vetco Gray./Test upper and lower hanger seal 1/5000 psi.for 10 mins.(witness by ENI rep.).\Start R/D and clearing floor of tbg.equipment./Total jewelry in hole 15-(2 7/8"cannon clamps)/208-(3 1/2"poly clamps)/114-(4 1/2"poly clamps)/48-(stainless steel bands). 08.30 1330 5.00 13.50 DRILL K 4 P PJSA-R/U on landing joint to set packer and pressure test lines 1/5000 psi.-(fixed leaks and change out sensor hose)- retested 115000 psi.-good.\Halliburton reps and procedures-close Autofill-pressure 1/3500 psi.set packer and hold f/30 mins.for tbg.integrity test./Bleed back to 1500 psi.\Pressure up on IA 1/2500 ps f/30 mins.for integrity test(chart recorded)/Bleed of IA and continue to pressure-up tbg.1/4400 psi.shear open Mirage plug-bleed off.\Pressure-up on IA to shear valve in GLM @ 2500 psi.-bleed off pressure\R/D lines-pulled landing jt.and UD.\Vetco Gray set BPV./12 hrs. loss=14 bbls.\Total to well bore 313 bbls.\Off-line activity put WEI pump in pump room. 13:30 15:30 2.00 15.50 DRILL K 20 P PJSA-R/D Schlumberger and GBR equipment form running completion string off rig floor.\PJSA-Sim-Ops for WEI equipment install. 15:30 20:30 5.00 20.50 DRILL C 5 P PJSA-N/D BOP stack./Sim-Ops man rider re-position on rig floor. 20:30 00:00 3.50 24.00 DRILL C 5 P PJSA-Clean/prep tbg.hanger./Schlumberger prep electrical and fiber optic lines-feed both thru wellhead-connect • electrical lines and pressure isolated both outlets./N/U tree and test void 5/5000 psi f/10 mins.(witness by ENI rep). Daily Contacts _ Position Contact Name Company Title _ E-mail Office Mobile Eni representative Jack Keener ENI Senior Dolling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative David F Smith ENI Drilling Supv. SIDDolling@enipetroleum.com 907-685-0715 632-3058 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Tom Norvig ENI Dolling Rig Clerk AKRigClerksDoyon 15@enipetroleum.com 907-685-0722 229-6100 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Jack Potter ENI HSE jack.potter@enipetroleuracorn 907-685-0721 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L80 1,421.08 3,884.98 4/29/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 1.510.89 1,201.57 FazePro 1114.4 54.8 1570.8 188.7 Eni E&P DivisionWell Name. .d-N4 fil* ENI Petroleum Co.Inc. Daily Completion & Well Code:26302 Field Name:Nikaitchuq •Q Workover Report APIIUWI:629-23466-00-00 2 n II Wellbore name: S120-N4 Date:5/4/2012- Report#: 4- Cumulati 8 Well Header Permit/Concession N' Operator ENI Share(14) Well Configuration type 212-029 ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(B) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.99 13.10 0.00 17.04 Rigs Rig Name Contractor Rig Type Rig Nuns Rig Start Date Rig Release Date DOYON 15 DOYON DRILLING LAND RIG 0723 3/25/2012 Wellheads Type WP(psi) Install Date Corn Production Casing Cas.Type OD(in) ID(in) Grade Top(ttKB) Bottom(RKB) TVD Rot.(ftKB) Run Date LINER 51/2 4.950 L80 4,6624 12,746.0- 3,887.1 4/29/2012 Last Cementing Start Date:4/18/2012 String:CASING,4,937.5ftKB Comment:Good returns-loss 23 bbls.Bumped plug and CIP @ 1150 hrs. Stg 8 Top(ftKB) Top Meas Meth • Btm(ftKB) Purpose Corn 1 3,167.0 Sonic Log 4,937.0 Cement 500'above Pump 40 bbls Citrate pill @ 5 bpm,140 psi/80 bbls 10.5 ppg Mud Push @ 5 bpm, N sands 160 psi/drop bottom plug/mix and pump 160 bbls 12.5 Lite Crete cement wl 1 ppb CemNet/kick out top plug wl 10 bbls water/displace w/358 bbls 9.5 ppg OBM©5 bpm,160-700 psi/pressure up to 1200 psi and hold for 5 min.Bleed pressure and floats held.CIP©1150 hrs.23 bbls total fluid losses. Daily Information Job Phase Job Account Days LTI(days) Days RI(days) COMPLETION 5568 24h Forecast Run ESP completion on 4 1/2"tbg.(12.64,L-80,Hydril 563). 24h Summary Finished testing BOPE./R/D test equipment&blow down./Load rig floor with Centralift&hang ESP and cap sheaves in derrick.\R/U GBR equipment&tools./PJSA-P/U TTC assembly and found 7" shroud hanger wrong threads-discussed with completion engineers and consult with town-decide not to run./R/U Halliburton slick line and install pump assembly,tbg.pack-off and test plug. Operation at 07.00 Running 4 1/2"completion assembly. Weather Temperature('F) Wind Time Log Start Time End Time Dur(hr) Cum Dur(hr) Phase 1 Opr. Act. Plan Oper.Descr. 00.00 02.00 2.00' 2.00 PREP A 1 P PJSA-Vetco Gray pulled BPV and install TWCV-Test tree 0500 psi,lowf/5 mins and 05000 psi.high V15 mins.(chart record)./Blow down test equipment and Vetco Gray pulled TWCV. 02 00 030 5.50' 7.50 PREP i 7. A 1 P PJSA-R/U Little Red on annulus and manifold to freeze protect-Pressure test lines 0 2500 psi./Pumped 27 bbls.before retums to pits ICP=1100 psi.@ 1.7 bpm.-with 51 bbls.away pressure increased 02200 psi.-shut down-dropped 01850 psi.and attempted to pump again increased 02200 psi.-shut down and bleed off 2 bbls.to 150 psi./Start pumping to attempt to re-shear valve;got retums to pits with ICP=1700 psi.@ 1 bpm.-continue pumping pressure vaned(/1250-02400 psi.@ 1 bpm.\FCP=1250 psi©1 bpm. Pumped total 167 bbls.diesel with 140 bbls.returns to pits.\Equalizes annulus and tbg.pressure./R/D Little Red. 07:30 13:00 5.50' 13.00 PREP A 1 P PJSA-R/U Halliburton BOP and lubricator on tree-P/U sheave and wire line 0 ng floor-Re-head rope socket and M/U tool string./Test lubricator 02500 psi.\Off line activity.prep floor for WEI-ECD manifold installation and work on#1 mud pump. 13:00 15:30 2.50 15.50 PREP A 2 P Halliburton RIH with four runs to change out sheared valve in GLM-install 2500 psi.annulus to tubing shear valve in GLM @ 2267./Found valve was washed on body(not shear or seated property)./Secure tree./Disconnect and remove suit cases between rock wash and WIF for access with bed truck./ Disconnect lines between modules. 15:30 17:00 1.50 17.00 PREP A 2 P R/D Halliburton slick line and lubricator.\Continue disconnect lines between modules and prep for rig move. 17:00 19:00 2.00 19.00 PREP A 2 P PJSA-Blow down and disconnect power from rock wash module and move down pad with CHM2Hill bed truck./Continue disconnecting lines between modules and under rig floor for skid. 19.00 00.00 5.00. 24.00 PREP 'A 2 P PJSA-R/U and P/U WEI-ECD manifold from ground level to ng floor with CHM2Hill crane and rig tugger./ R/D from WEI manifold picks and re-install beaver slide doors and prep to lay over beaver slide./Continue prep rig modules and floor for rig move. Operation from 00:00 to 06:00 Cum Dur Start Time End Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. Fluid Checks Mud Base Mud System Mud Trt. Date Depth(ftKB) Density(Ib/gal) Vis(s/qt) PV Calc(cp) YP Calc(Ibf1100... Chlorides(mgtL) FW - -- 5/2/2012 Electric Stab(V) pH "Solids(%( Sand(%) NTU in NTU Out Cased Hole V.(... Temp Crystal(-F) Oil&Grease Static Sheen Mud Volume Tot.Circ.(hbl) Open Hole V.(bbl) Cased Hole V.(bbl) Vol Mud Res(bbl) Mud Lost(Hole)(b...Mud Lost(Surf)(bbl) Cum Lost(Hole)(... Cum Lost(Surf)(b...Mud Disposal(bbl) 149.5 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Dulling Supv SIDDhlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Eni representative David F Smith ENI Drilling Supv. SIDDnIling@enipetroleum.com 907-685-0715 632-3058 Eni representative Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Tool Push Chad Johnson Doyon Drilling Tour Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Eni representative Tom Norvig ENI Drilling Rig Clerk AKRigClerksDoyon15@enipetroleum.co 907-685-0722 .229-6100 m Eni representative • Page 1 of 3 •^ O O A A 0p�(l 0m A N 0 0 'NN 0 0 0 0 p O N A A M J 44444 OCCC COOOC 44444 CCOC CCeeC 4444.1 pCCCO p O O O O 44444 OCCC . d J_�!1^1§ �Oa ylg Mph ur O�IO0�IO0 SIO0�IO0SIO0 �IO0�IO0�IO0�IO0��OEl �IO0 �O �O �O AO �yO�YNJ N h Heil Y1 NCO§1 Iii N N 00000 00000 00000 00000 00 000 0 0 00000 0 0 0 0 0 00000 _ O N V CtlNO1MOp' o.1.. Wc'4p. N.TrO74'..s.0000 U?.1.*2 In Wain 'inn OOOm EEM-1 nopNim0m Egg0aOIA ..... 00000 ....ON {NANO0 a... .....ppO0 pN.EEOppNNN y„ooh N ON NN BONN COgMOm4 2mE��A 4.NYfv.m RWRI X00e0 $eNm6. ”18. N OCNN t� Oi tmo Hill .Nn vnN A_`E��'' A ��O`{�[f Mil Oe No� o mOp EG oA Cl O` 1 W Oy illEp E p �p �pO�plOip+O��pMO �tpN-+O1M i t M R F,N 4 i �pO y M z m o 0) m f0 f0 fD(D O f0 l0 f0 O O(O O fO 0 m m 0 0 0 m m p m m m m nom o m m aMEn 0 n tl Nmmt O OON 0 eNOCW'l C'l ;1,,m. 1 'rNm< 000 e e M 100 O�Z O N N e 10 MCG lV O O N e� (�r N r N - 0 O-� �.��m A M 0 e e e 13 E Q: L 2 EEOJ yI0� y pp p p �Eyy{{yy �O{y po yN� pEpp pp '= 3E823°284 00M00 388np,M OOyRrA{y ODN{pO88p �EDn PAM {My REM 8.74.Ep78.8. V ' -'6"6'i vO GGGN A tsEG N "'' '';g N<nM �OI IMOnOm pN NNN ANNNM RN NN mNN�I0 N e e 0 0 n 0 0 N w ="E0V4..$Ee.,$rl Vm"a3,.R e418n; o4i,.A.l,aB: °.d.ar,Ti0 E .2.$o `e3,Ep.P1i.D'� 0 0-0' IA 8' O O N M 0Ey A N_Y� 0ee'l A W G M pr O A 0$M e � 0 m 0 0 N N N t+l M Y 0 0 0 O 0 �� N� ��N m N I n�N C i Lo p (y .O p p a Ep a o a a �O y� p�O Z Z C8 E) O V Ce0- .;0$2 N� <UOI,.f),E8.4 .�EEOp1 EG'f�.2J4 Oh$ .2. d V e V N �R N$NECmy; Mmp�ANN N --61 . 0.5§.2.8.8 O S.8 c N- 0 e0.-Ei� "1�' ?ME ME'le<e ELM OOA�n RM6:0 EDGED bitMi Z E -fcc. g. R'-Nr . - - 8? o vl 5C� r m 8 m O Z$m N s M G w 0 N b W Q m f G N ”284. y a a s yy E+l a =E8 enp.8 OOO eO mAOOtl OnrMN N�m Nm Q�0 oa E��B$ $IYiO�a Z e N.-O0 roO tNv pp oI0f spEpyyO Emp ring�y y �+l ♦ of app �..I < GG.-G' M 0 Qi" "ac.4 MC'le e e ring ,E M! E nn nA Mil ON o z EO 9OcO � 0. « 0. wEQO' ..5 1,-11 N7 5OW92 2w 2'=-888882,2884 42.1""4.7-2 OipKIO (p0�M .T8Nz2gg. pA Y.+ m0NOOrly O0O ^OyD2OCO yNOO0p :Mil NNre Y = O 8CrOO` > tO 77 77 ,, .T0 . . . . . p . . m Cl) y hH 22 TWUK19LL . 02U m O Zrr000.0pupr m cH N>> N 4 r i'Oi 2 U' H J LL c '..i88EOy���E.IlN IpMp�N.n01; Ltm4O pAp y8I08pEaD V.O 4.8 2 N. �m�Eyy4.�E} 8p py pg00 O�p.,T:dO a OO.'0A O N n ii00�N Vei" :::::2—,AmO a',3P a .0a00g m DEO W N N ""JEit e 0 N N N N N N N N N N N N M M M Q Z p 0 00 pp Ey m Ep �O 8:,:. 4.21 Ep O N C$rl N���NEEyyy r ENI�ppOp 6l Erb c4I0.E p0n OO�QOIQD0�lYpp O�E$+ll(pN��pMp t� mag M p 1OmpNNOE�^� 0, oeO ,N Z 0 M M O N i O m o AE 5 b F N M E O Q 10 10 p$ N N N N N „� N g l i l . LL n N MN$EC p 2LONN0V S$M ." 8.44V." 8.44." 8.44V?! mO4Or I.1. 8.V.1. 1 4 ,sgMN OyN F' OROnp pMNMN HNasN 2288N 28484 8442A MMNAMMMMMM E - m• N 8 N N Acc gC8gg8ZE �g",7 m03<S$ X4242 4y33$g.4 MOOEDN p�?IO. Y W4P1,1 N E N �$i V?2,!§.t mp. - 66.'4'6 0 0 !2°.E2 N N N N Nc'7.48271 V neN EV •-.-O0' 'p N NIN+I Np 0 C1 N W N trl .. O tl l Z Z `y1 Z�+Np;l N M f,L g W Z N o a Z Z Z G geO ,p p{tall pe p p p. .7.v. 8.1. Na. OF2,0Op m.M8.4:8. 4 Opg. y A INN OOr gp0lNeOe PNMO 0MmMCemm N -$S. e- 71Vm' NNNNN N� N pIEA MMMN M E p O C o O H •C K vm Go 0= v n O W0 WONNU scO M ..O -9OLLE . '0 - 41) O m - =pp a M Om r - O TQCoON E OoS = hZgO7:M E Lr-q ? r u o K OIL(0;m Q M N r U J J O U' 8 'E ^F 0 pr l7 A M* ' NO OREg2b0m S'° NDrN1 8R8yN NNmiO 000gg gWiOi RWggg Olgg RI a 4444 agave O c d v a 44,444 <OV<Y O<444 a 4444 OQOe0 44444 O O,a 44444 dOaa 44444 O^t1p�p< FdNIy111H 11;; ;WI OORNNE F ROm m11�n m 'N m .S N O bCND aaCc!)22222 NNNNN NNNNN 21222 NNNNN 221 NNE ENE.. .NNN .0 l0EJ 0 0 0 0 0 00000 O G G O o O G O 0 0 O O C C G C COO C rC C C G o G C C G G 00000 O^CCG G 0 0 0 C G G G O A G G N n r n r r r r n n n A n n PPPPP A r A n n n n A n n n A PRPRP.r r r r n n O C W OnN00A2 V SvpmSnS pp SE!mm ON oo mrO 2E n V P.1.4 SS AN a s8nNNOp m 2P-M2 P'.(5 WEONvvN' ONmd glWy! �NmOmGQ/0d NlibP 1111O 01111 11M rh OOOOO !h!!! U $.NNN NNNNNNNN NNNNN SNNNN NNNNNSpp V1[J C gE OGD<m 2 S®�H OSN O yQ (SS Q Q O 842(7,8 mSS2 y2 S OO?t�fO�,N e'8 pS S 5 �SSQAO OE VIA0 L>SPS{S 0201 E 2S 1C1��5 2 V 1Hp NNr1�N0A ^4N yyyp NmON�O WEE pRO NmN' gpO gR6 GDNmNA EF ni O«GD MIN n d CC mmNMM CmD mm O m 00 NN OO ODn QO O� 00 NN Cy')ppp dN4D Oyn�GyD�GD 00 ANON �Q$�� P. m� tGl M m m m � MEI a d O ����n Q Q�f�� N N N N N N�i[OJ h h �N N h h N O O In b fb0 O O O N N z EEEEB 111818E EEEEE ElE11 sm EI SSNNm HUI BSN1S SSmmm SSSmm mmSES SSSSS SS m (mymm m m mmm e� mm m (mym ym� Gp p m p p y� a�y (y(�(y p fp �p �+l j o^,N tJ t m N Q N d d GO M N N 1�p Q N c0'),0 O t7 Q tG W: O N N O N O c0 Ol 0 0 CO r OD OD N GD W GD N GD 110 GOD,W O M N N I O O ,G n G p m fV d m d m d d N N In r,q e-e- �d:O d O �O fV m� d�N� Q�m N C NOG O lh C�O� G O l„)�N m O O th� N O N m G O� pIIIYYY e g:e g 0 h M a O A G 86268 A n N O N N N N dg 182436' 2 4 3 6' v P-N 4(N SN Nh E g 8 A aN S82:26 82:26 h .-PSS m 0 8 S N OlV 8 V.:"pONN♦q 4gmF^ pa 0mOOO EERIE NOgm8r2SS �Ghyp =Cm,No228172 00 n v m 6aSd D .3' N 22 ONN ..18-7.S.2 22884 OP ES$ NS 2 SPm A SSNP ONANONP P,N 'idamE gLIQN S8"8 OVERE Wigg V8OE ,Wig , 8NNVE , FIN Iv {y Q 1�p p p� �+l �+l �p p�y p p p �p (� 1� ivs Er1,IC� (ryytmmNz!Glp 1rA 1��I�(pO a�a Gp4Gp ON 1gr�N R (8m:2�p2yl aO lO Att+*0 g g OD m� rgrTara N nW'l,4 NNis �p8 v Opb8 s N 2 m�O+vl 2m;'Pi �inESEP y��Qm N s O N f� Ot7OQ oNCDn 0 W O 'tO fO'1 ON sAmN., Ol N N O Am O m8N NNps a nGD g8NN t70 inmr ED Of N N N N N N N N N N N m m m Ih m m O m m m —5,7;4-4 Q d Q d d d d Z _ p tp pp y� p p pp �l{�p(p � p iiE SAOm m 012OM OSOON SnSOQ SSSSS AN'NO S S N;Ib mOCAO v m ASn ON 42282 mSSE OO mm SO p A SO ` 100 mON ,T11;1 NNNNN NaMA 11H1 pqOdN 1111O OiimA n N6ZDGOC Oi c WCSOnOS mN:SE SMSNONm 22OS AnVQ:= ANONS SV0A 'a2,7-PP mS042 pt3OAS AV--,2V2 00 N1N Namn$mp§ M! hmOO pNgN N M 5r1 QpOo1; , YZ peg'ar VmAmmP Fess 'S4E2 !rtN SVE22 ASSES pOa!D AQN SS 15hi 1Eagi 11;i1 $$III LURE 1m11F, mum 11111 11111 1111 Hmmm m mmmOl 11 OEAOp2rFt=828 2,2ppn r4'092m Nt2'22 VS 2;NOO rmSS71222 SS22Emm2m2 ANNOS SO15 OOOdNibAm11111 11111 11111 11111 11117 7111VVVlNbmmA pE`'m tIL- 0 + 8OQ N,A:=N Qa:,868 °,248P8 222;34 ;MO7A 2ON,,4 A8844 Sr..-882 a g a468842 88 'ARM°, $A994y11S1 m m mmm m m m mmmm mmmm m m mmm m m m m mm m m m mm m m mmm m mmmm m m TACE 42a GD O N;:00 OGD22S Op020 22r26 PhbSr E S m0O S Q SzA ESSSS S$1C2Sa 010,$N r N m rp r0 'ARM. 426V6 ,2IX Nmmaa 88mgg 88288 88888 8mgg$ N&NNm NgSWa RSaFF aaR88 ma IESAS2 N 4'2 AmE �mNnanCNES mmAA 00 OSA S 2 D2 NO2 A6-2 - E1(�SVII5 2A4SQ <rSS4 AS 1byO 1,96 O7aV VV-16i 2'446 ^O §36A OOOOa P1m ,,s;7-44 aQdO i� TN2X � so n Dmy Cm pn 0 0 N N U Gy`�5 O 0 E • c 8 d 0 m^m a 8�m N mm m u�a� $',on$tyio m m 2 0 �`�'pN ps m" m q o 0 is f0 mI yyrW ��0 VpN SON a Spnwrth NONm aO nns r gg§ q^m Q' Nnm miS V �NN�O 4D Nmi0 mRgrig § nNN MlhiNN 0mrrm ,�I 'R 0 L", 8888, .8888 ga8ai iRi32 gdgg8 88828 88888 8'8886 Dims m 444 00 OGPGG 44444 e000 m 0 V:44 44444 aeeG GGGGG 44444 GGGG G4Ge6 aZ.0 m d _OmOm UW pp �ymm �y gy0 N f7JME ,g_,t/rp�tN+l Ommlm NpyLtyv�l�S rSig S AYm Wl+l rRNO 0 pmnp[mm�1mmm�m'S �d�CoS OOOOS �N�mmNN� Np H�N�m 0NN.0 UrCNn I OQ,lU ,C.h Nhh I....If I,..0O N A G R A r A n r 00000 e0000 00000 00000 00000 0000 r^r _ O N , , v Cm2G2 88S4'4.' 82888S'4;82 Omm(m8NAp0 pNOppm42m8 NhO N W r pnp prp prp QnQ prp pnp np pp §§§§1 N N N NNN,C N NNN N N N N N §§1§E N N N Cm00 �p8N,(m( 8O m �22888 aOpp 22,88mE S yN�2q8 �� mr 4D 004, 8 MOSn yO y2j; C'm M 0 0 2!N S <O N O m A 0 VGA!O O m N M lh t� m m l I r l^O$ m m O o $$°f n rmmco m 883 88mw nm �m2�; ;m$ z $$$ {$+hJp$m Inn 28282§2 22222 22222 mm mam{mym 2;'5222 mm2 ,Oj o00! t7 W N W! ”,HF. W 5;20 NOOim�,m tLmO�N m, S N m$ry ae ('(d 8 O pOe� NN�N� r NNth N�NN� �N��� �NthO� mtV NNIG NGO EE618 8 '442,78 ;84,7A 48882 244", r4 8S'' "228 S f9c328 8;02 "g § 4V401 MI! mpronm HIE! MV On pOi = • z,z�zzzz I NIA A NNN mm pp m m ty y p NNmm;N =,2802 52',7188 18;18;8 :742n82 mom 2 mS O .2; NyU2 nil! O2,a4ma S �tny; O 22 a xNNN ED tQy {my tyh y$�S pNp IMI mO nSO��N Hill Mel S n m COD W 00 a NNIhQ O mus C zzzzNN LS MI Y) tD I 5111 S SM SSS the vee ee a ee O vee a ni NN NNN; NNN m NNNNNN ��Og NNN. w- - . Z gE8z;! 2',:224 0mea 42ay42 82mO48;22828n 4Z47,a 22; N U ONBin 0om$lm 0iNmm Mil :q3 prnPpmmiml ;iii Z 9 1rBIIJ'n o2yaa: 182,5a!,81 18222:1 pr-”y :p8p$ ce11 42le" tn�no$t`�,I2 '866.2$ 88r >1§F Z � N�n OOn A m NnP0 mNN� 8CCmn 8(0880 MI CNC ^r np gg gg ^ U 841 N O $$ 9Qmm lin N 8'3oS mm2S ,o. n rnn rnn 'mmm°d� Illii 8'aeiam� Mt$ a$ 758,_ y 1122 N O & goa '0 W WG9 WENmN 8 6 8 82 802em "SSS 2 e8 22 m'om8m e8:18$ Nmmno 288 H ONai3eia N$ N qN RIM 0$88m ggI88 !OOP; c9 Hili Iii 2 O0 fIc 3 ,2 2 YNZmN 0mN 2 I2m N NNmNmI Z 2E244 28821 '42;m S8488 848128P;4� 10;28 24;24 288 sl 11111 11111 11111 11111 it RIM Mil ,, m gCthONOpS: nFaW! ,q.4:422 rymM moNON 88882 !,3,122',Z 8:21 N g_i gu N W s W 1`2pm 42240 28422 mm,224 24528 22,2m4 G22R8 82228 ;q; O• gi & JK 7 fNNmMn 7nr§ rA§Aga:mm m:m8m 2mmm0 :8888oas QA NzWW NNNF=" 'R S mFQF< O We:2 CmWW _ =222 222,7- 92000 ,Z$0 .2 mNAmm 848N2 4;nS4 NpN §N$22 ;Vag " 2;;2$ 88822 88;82 8;228 2$228 ;2228 2'4;2 O I .. moo 668 m ° "'W4 2a"" Q 28,L J J lymm U i u 297S OmmmN 22;44 4422'e; 244'::h mr22'4 S228;3 t22888 Spp 8&1' N iiR iah08IOiMN 07:412 VALI Wig NNE $m N o o _ Lo 1 N E m v 0 o Q m w`a` m ozz U h N N Schlumberger vitit Drilling&Measurements 2525 Gambell Street.Suite 400 • Anchorage AK 99503 Tel(907)273-1700 Fax(907)561-8317 Date: 25-Mar-2012 Well Name: S120-N4PH Company: ENI US Operating Company, Inc. API Number: 50-629-23466-70 AFE Number: 5567 Field: Nikaitchuq Rig: Doyon 15 Schlumberger aro.* • env Date: 25-Mar-2012 Well Name: S120-N4PH Company: ENI US Operating Company, Inc. API Number: 50-629-23466-70 AFE Number: 5567 Location: N 6053636.060 ft US, E 511559.210 ft US Field: Nikaitchuq Rig: Doyon 15 Drilling and Measurements Field Support: Operations Manager, Mario Pepe Field Service Manager, Hector Echeto Drilling and Measurements Field Crew: Cell Managers, Tobias Miller Michael Turner Cell Engineers, Stephen Fell SERVICES PROVIDED Services Services Dates Depth Intervals VISION*(Resistivity, Gamma Ray) 25-Mar-12 to 05-Apr-12 160 feet to 4511 feet Directional Survey Service 25-Mar-12 to 05-Apr-12 160 feet to 4511 feet OPERATING STATISTICS Total MWD Pumping Time: 71.72 hours Total LWD Pumping Time: 71.72 hours Total MWD Time Below Rotary: 127 hours Total LWD Time Below Rotary: 127 hours Total MWD Depth Interval: 4111 feet Total LWD Depth Interval: 4081 feet Total MWD Runs: 3 Total LWD Runs: 3 JOB PERFORMANCE Directional The final MWD survey point was located at 4038.44 feet with an inclination of.04 degrees and an azimuth of 147.87 degrees. The final drilled depth MD and TVD: Measured Depth: 4111 feet True Vertical Depth: 3981.65 feet Schlumberger • eno Formation Evaluation 16 inch Surface Section: The surface hole section was drilled out of the 20"conductor from 160 feet to a measured depth of 2648 feet in one run. This section had strict anti-collision parameters, so a Wireline Gyro was picked up along with a PowerPulse*, arcVISION*, and PowerPak*motor. Gamma Ray, Resistivity and ECD were measured by the arcVISION*and supplied in both Real-Time and Recorded Mode. Downhole weight on bit,downhole torque, torsional, lateral and axial vibrations were measured by PowerPulse* and provided in Real-Time. The Wireline Gyro surveys were taken from surface to 748.9 feet,at which point we switched to taking PowerPulse*surveys. 12-1/4 inch Intermediate Section: The intermediate section was drilled from 2648 to 4111 feet in two runs with a BHA composed of PowerDrive*X5-900, arcVISION*, and PowerPulse* for both runs. Downhole weight on bit, downhole torque, torsional, lateral and axial vibrations were measured by PowerPulse*and provided in Real-Time.The first run was drilled from 2648 to 3955 feet to the first coring point. After coring to a depth of 4022 ft, the second run was used with the same BHA except for a different PowerDrive*.This run was drilled from 4022 to 4111 feet. Gamma Ray, Resistivity and ECD were measured by the arcVISION* and supplied in both Real-Time and Recorded Mode. Real-time multi-vibrational measurements were obtained from the PowerPulse* MWD tool, which provided the information necessary to help mitigate shocks and vibrations. Additionally, near-bit Gamma ray was provided from the PowerDrive*and was able to help pick certain coring points. Innovation The Schlumberger MWD team was successfully able to demodulate real-time data at a rate of 6 bits per second during all sections of the well. We would like further encourage the use of MVC Modular Vibration Chassis to improve drilling performance and tool reliability, as well as ECD measurements to enable informed decisions about drilling practices. This was the first use of Gamma Ray from the PowerDrive*and it was able to give a better idea of corning points and overlaid well with the Gamma coming from the arcVISION*tool.. Schlumberger Oilfield Services — Drilling & Measurements appreciates the opportunity to provide ENI US Operating Company, Inc.with MWD and LWD services. Sincerely, Michael Turner/T. Miller MWD/LWD Engineer Schlumberger Drilling&Measurements MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday,June 04,2012 TO: Jim Regg J /5 f v SUBJECT:Mechanical Integrity Tests P.I.Supervisor g Y ENI US OPERATING CO INC SI20-N04 FROM: John Crisp NIKAITCHUQ S120-N04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry )F;� NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ S120-N04 API Well Number 50-629-23466-00-00 Inspector Name: John Crisp Permit Number: 212-029-0 Inspection Date: 5/22/2012 Insp Num: mitJCr120525073205 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5120-N04 1Type Inj W TVD 4384 IA I 1047 1573 ' 1550 1547 PTD 2120290 - Type Test SPT Test psi 1500 OA 220 240 240 240 " — — IntervalNITA- jP/F P Tubing 273 - 273 - I 274 274 Notes: Used diesel pump or freeze protect for test.Pump stopped at 1573.Guess on fluid pumped 1 bbl. , Monday,June 04,2012 Page 1 of 1 Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No S120-N4 Date Dispatched: 7-May-12 Installation/Rig Doyon 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs S12O-N4 Log 1 2 in MD 1 2inTVD 1 5 in MD 1 5 in TVD 1 Received By: Please sign and return one copy to: 3800 Centerpoint Drive,Suite 300 Anchorage,Alaska 99503, Andrew Buchanan andrew.buchanan(a�enipetroleum.com LWD Log Delivery V2.1,03-06-06 �l 531 Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No S120-N4PH Date Dispatched: 16-Apr-12 Installation/Rig Doyon 15 Dispatched By: Hector Echeto Data No Of Prints No of CDs S12O-N4PH Log 1 2inMD 1 2inTVD 1 5 in MD 1 5inTVD 1 1 Received By: � Li 4LiV Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 hecheto aa..slb.com Hector Echeto Fax:907-561-8317 LWD Log Delivery V2.1,03-06-06 Z1Li3 iv, 'IT\ I- a7 ` r 1 gns _ SEAN PARNELL,GOVERNOR `' UPJ u u ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Maurizio Grandi Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SI20-N4 ENI US Operating Co. Inc. Permit No: 212-029 Surface Location: 4454.3' FSL, 1350.6' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 4740' FSL, 2866' FEL, SEC. 13, T14N, R8E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced service well. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name SI20-N4PH and API number 50-629-23466-70 from records, data and logs acquired for well SI20-N4. 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 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, fcke-ci(7Z---•- Cath P. Foerster Chair DATED this i day of March, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED FEB 1 S 2C7 Elni •ArOHeU ROI fit* Alaska Oil&Gas Cons. Commission Anchorage 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com February 16,2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer SI20-N4 Dear Commissioners, • Eni US Operating Co.Inc.hereby applies for a Permit to Drill for the offshore Idector well SI20-N4.This well will be drilled and completed using Doyon 15. The planned spud ate could be as early as 3/12/2012. SI20-N4 is an injection well from which we will be drilling a pilot hole to acquire two full cores. The first core will be obtained in the Schrader Bluff N Sand and the second in the Schrader Bluff OA Sand interval. The N Sand is an oil bearing reservoir that lies approximately 100' stratigraphically above the primary reservoir for the Nikaitchuq project,the OA Sand. Following the core acquisition, a full suite of wire line logs will be obtained over both the N and OA Sand intervals for detailed Petrophysical analysis. Following the wire line logging the pilot hole will be Plugged and Abandoned prior to drilling the intermediate hole • section of SI20-N4. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Luca Borri 907-865-3328. Sincerely, AP- C116--)'1- Maurizio Grandi Well Operation Project Manager RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 16 2012 PERMIT TO DRILL 20 MC 25.005 Alaska Oil&Gas Cons. Commission la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj Q • Single Zone ❑ 1c.SpeciA( - oposed for: Drill Q• Redrill ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Geallaed-Gas ❑ ('ac wvorates n Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number:t�� . - ENI US Operating Co.Inc. Bond No. RLB0008627. S120-N4 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 • MD: 12587 TVD: 3829 • Nikaitchuq/Schrader Bluff 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 4454.3 FSL 1350.6 FEL S19 T14N R9E UM ADL 0388583,0388574,0391283" Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4409 FSL 1329 FEL 19 T14N R9EUM ADL 417493 3/12/2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4740 FSL 2866 FEL 13 T14N R8EUM 1280 11340'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 54.1 15.Distance to Nearest Well Open Surface:x- 511559 ` y- 6053636 ' Zone- 4 GL Elevation above MSL: 13.1 to Same Pool: 1200'to SP18-N5 16.Deviated wells: Kickoff depth: 200 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 96.26 degrees Downhole: 1765 psig . Surface: 1337 psig • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 160 36 36 160 160 Pre-Installed 1161 TOTAL sx 16" 13-3/8" 68 L-80 BTC 2524 35 35 2559 2484 LEAD:891 sx 10.7 ppg ASL ✓ TAIL:270 sx 12.5 ppg DeepCrete 12.25" 9-5/8" 40 L-80 Hydril 563 4738 33 33 4771 3939 502 TOTAL sx 502 sx 12.5 ppg DeepCrete 8-3/4" 5-1/2" 15.5 L-80 Hydril 521 8016 4571 3925 \ 12587 3829 Liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) I Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis LI Diverter Sketch E Seabed Report ❑ Drilling Fluid Program ❑., 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 2/16/2012 22. I hereby certify that the foregoing is true and correct. Contact Luca Born 907-865-3328 Printed Name Maurizio Grandi Title Well Operation Project Manager Signature A I C ) Phone (907)865-3320 Date 2/16/2012 �IAJ Commission Use Only Permit to Drill ) API Number: / / �n-sy, Permit Appro See cover letter for other Number: 21 50-(P �23��p�p-w'W Date: �,G`1\2, requirements. Conditions of approval: If IN is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: 3500 ps:- .re.......51-- Samples req'd: Yes❑ No 21 Mud log req'd: Yes [1No I I" H2S measures: Yes❑ Nog Directional svy req'd: Yes 2(No ❑ ,v UI�;mu.&- op e-r cti.. i ti wThS Ly A 3 a� +-r G'8i-- e Dive-4e kr-8 fQ.Lt1'C / AP ROVED BY THE COMMISSION ORIGINAL DATE: 3 `'�"/� ,47� ,COMMISSION Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(Z0 AA 5.005(g)) Submit in Duplicate 1 en l• us operating WELL SI20-N4 Drilling Procedure SI20-N4 Spy Island Conductor slot #20 Reservoir location #N4 Injector (Schrader Bluff) Nikaitchuq Project SI20-N4 Drilling Wellplan Page 1 of 47 02/16/12 I • 2n11 us operafirnns WELL SI20—N4 filliis Spy Island Nikaitchuq Field n° p r kuri North Slope - Alaska SI20-N4 DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD ND SIZE SPECS INFO Cement to Surface 20" e Hole Angle a 0-65 0° 20"Conductor Shoe 160' 160' Driven Welded N/A 0 GR/Res Surface Cso Dir/PWD $ 0 13-3/8" S. 68# MW(ppg) Wellbore Stability Mud Motor B/Permafrost 1750 1646 P L-80,ETC 8.8-9.5 Lost Circulation • Hole Cleaning '" Casing Sections KOP:200' ' Casing Wear OLS: Surface T/Tail Cement 1936 1870 0-3.°/100' Hole Angle 0.00 Deg 13-3/8"Csg 2,559' 2,484' di 11 50°F WBM GR/RES Neutron/Density/PWD Inter.Casino Wellbore Stability 9-5/8" ost Circulation • Mud Motor 40# MW(ppg) Hole Cleaning L-80,Hydril 563 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: Casing Wear 87.00 Deg BHA Expense Intermediate TOC 3,178' 3,085' Pick-up Top of Sand N In NOTE.Include SONIC LWD In Production Hole BHA N Top 4,178' 3,809' 'o 0 n • PHL Injection Packer 4,471' 3,678' n q 1 3 11 Hole Angle TOL 4,571' 3,925' • ►l 87.00 Deg 9-5/8"Casing Point 4,771' 3,939' 12.25 85°F WBM/MOBM GR/RES/SONIC ADN/PeriSCOPE/PWD �p p� Wellbore Stability 1s sI .ost Circulation• Slotted Liner Hole Cleaning 5-1/2" Torque&Drag 15.5# MW(ppg) Casing Sections Xceed 675 _ IE 21 L-80,Hydril 521 8.7-94 Casing Wear Tubing BHA Expense 4-1/2" Ei 12.6 lbs/ft El L-80,IBT-M Inner String 3-1/2" 9.2 lbs/ft IS .... SI L-80,IBT-M Hole Angle 90.53 Deg 5.5 • 12,587' 3,829' • 8-3;'4" 85°F MOBM SI20-N4 Drilling Wellplan Page 2 of 47 02/16/12 VIOs • enll us op rr t ri WELL SI20-N4 SPY ISLAND Nikaitchuq Field •0 n 11 p rioHcuim SI20-N4 (PB1 ) Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 0° 20"Conductor Shoe 160' 160' WA Welded/Driven N/A 0 GR/Res v Surface Csq Dr 33 13-3/8" to Base Permafrost 1,750' 1,693' > 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor r- L-80,BTC 9.2-9.5• Lost Circulation • Hole Cleaning 1 TOC KOP Plug 2,450' 2,375' • 13-318"Casing Point 2,559' 2,484' k 16" 50°F WBM • 17 ppg ', Class G I I Wellbore Stability 3,100' 3,025' Lost Circulation • 14 ppg mud Fi Vis f MW(ppg) Hole Cleaning 9.4/9.2 • Torque 8 Drag TOC 1 Plug 3,650' 3575 ' "M"Sand Top 3,979' 3903 OA sand Top 4,134' 4,059' v<�•'�` 15.8 ppg Class !�.fr- /- o G `s�*- ?-/3-14.— Pilot hole TD 4,325' 4,250' 12-1/4" 85°F WBM/OBM• SI20-N4 Drilling Wellplan Page 3 of 47 02/16/12 ena• us operating WELL SI20-N4 Table of Contents WELL PLAN SUMMARY 5 MIRU SECTION 7 SURFACE SECTION 8 Surface Drilling 9 Surface Casing 11 Surface Cementing 14 Pick Up Intermediate Drilling Assembly 22 INTERMEDIATE SECTION 17 Intermediate Drilling 19 Intermediate Casing 26 Intermediate Cementing 29 Pick Up Production Drilling Assembly 31 PRODUCTION SECTION 32 Production Drilling 34 Production Liner 35 ATTACHMENTS 39 Area of Review 40 Recommended Drilling Practices 41 Health, Safety & Environment 42 Safety Meeting Topics 43 Well Shut In Procedure While Running Production Tubing 45 Conductor Broach—Contingency Cementing Plan 46 TAM PORT COLLAR Utilization Decision Tree 47 S120-N4 Drilling Wellplan Page 4 of 47 02/16/12 ft* en II us operr fins WELL SI20-N4 WELL PLAN SUMMARY Rig: Doyon 15 Type of Well: Injector Well Design: 13-3/8"Surface x 9-5/8"Intermediate x 5-1/2"Liner Summary description SI20-N4 is an injection well from which we will be drilling a pilot hole to acquire two full cores. The first core will be obtained in the Schrader Bluff N Sand and the second in the Schrader Bluff OA Sand interval. The N Sand is an oil bearing reservoir that lies approximately 100' stratigraphically above the primary reservoir for the Nikaitchuq project, the OA Sand. Following the core acquisition,a full suite of wire line logs will be obtained over both the N and OA Sand intervals for detailed Petrophysical analysis. Following the wire line logging the pilot hole will be Plugged and Abandoned prior to drilling the intermediate hole section of SI20-N4. Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned, that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survey Program & Procedures Take MWD surveys as frequently as needed, but no less than every 100 ft.� Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues, hard lines and no-go lines. If a no-go or hard line has been or will be crossed, stop drilling ✓ immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program • Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. SI20-N4 Drilling Wellplan Page 5 of 47 02/16/12 co, en us operatong WELL SI20-N4 OBJECTIVES: 1. Drill the well at or under AFE cost and time. Perform work in a safe and professional manner • meeting all ENI Petroleum Health, Safety, and Environmental requirements. 2. Successfully acquire a full core for the N Sand covering the entire N Sand interval 3.Successfully acquire a full core for the OA Sand covering the entire OA Sand interval 4.Obtain Petrophysical logs over the N and OA sand interval including: Platform Express quad combo and CMR 5.Land Intermediate casing point within 100' radius of the planned directional target. 6. Land the Intermediate hole section with the targeted inclination above the OA sand. 7. Target Greater than 90%within the OA sand Reservoir. 8. 8-3/4" hole LWD Failure Requirements: GR/Res/Dir/PWD— Require GR/Res/Dir to achieve TD. SI20-N4 Drilling Wellplan Page 6 of 47 02/16/12 us operatong WELL SI20-N4 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (PPO) Type (psi) (psi) (kips) 20 178.89 X-65 Welded 18.25 3240 4980 3417 1. Confirm that the identification markings on the conductor match the planned surface location with the "as-built survey." If identification markings are not present on the conductor, contact the Drilling Supt. prior to moving the rig onto the well. ➢ Each conductor is to be marked with a common pad elevation survey mark by the surveyors ➢ Surveyors to also mark each conductor with a degree of angle to set each horizontal wing valve 2. Move in and rig up. Record move distance and rig floor distance to pad and sea level in WellView and on IADC reports. Initiate a Rig Elevation Record and place it on the N drive. • Ensure all concerned parties(Directional Drillers,MWD Operators, and Geologists) are using the same rig floor elevation. 3. Post drilling permit in the rig office and company office. 4. Nipple up the Vetco Gray landing ring,Vetco starter head,the diverter spool,and the annular preventer. Function test the system. ➢ Notify AOGCC prior to spudding well ➢ Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. ➢ Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access to diverter line area 5. Verify that two 3"threaded nipples have been welded on the conductor on opposite sides. Include ball valves and Cam-Lock male fittings on each nipple. Ensure threaded ball valves can be installed without running into the OD of the diverter head. Nipples are to be used as follows: ➢ Assist in washing out surface casing hanger on cement jobs ➢ Take returns to Vac trucks while cementing ➢ Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Refer to the detailed MI-Swaco Mud Program(attached). S120-N4 Drilling Wellplan Page 7 of 47 02/16/12 2rn111 us operrenrnns WELL SI20-N4 SURFACE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (6) True Formation Tops Measured Vertical Comments Depth,ft Depth,ft SV-4 755 752 SV-3 1137 1121 SV-2 1412 1379 B/Permafrost 1750 1646 SV-1 1937 1871 Ugnu Top(UG4) 2253 2179 13-3/8" Csg 2559 2484 SCP UG-2 Coal Bed Marker 2882 2805 Lower Ugnu 3621 3461 Schrader Bluff Top 4030 3736 N Sequence Top 4082 3764 N Top 4178 3809 ReCalc Intermediate Cement w/Actual N Bottom 4295 3856 N Sequence Base 4444 3901 9-5/8" Casing Point 4771 3939 OA Top 4866 3944 OA-2 Top 4975 3950 TD ' 12587 3829 • Total Depth SI20-N4 Drilling Wellplan Page 8 of 47 02/16/12 us operating WELL SI20-N4 Surface Close Approach Wells NOTE: It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. Surface Mud Program: NOTE: Maintain Weight up Schedule as listed below to casing point API Fluid Density 6 RPM Chlorides Interval Depth Loss PH (ppg) Reading ( 30min) (mg/I) 110'— 1800' 8.8 -9.2 20—24 <8 <2000 9.0—9.5 Surface: 1800'—C.P. 9.2—9.5 20—24 <6 <2000 9.0—9.5 Surface Logging/Formation Evaluation Program: Surface: MWD Directional LWD GR/Resistivity Surface Drill Pipe Pipe WT Grade Conn. Tool Tool Body Make Up Joint Body DP Tensile (pp) type Joint Joint ID(in) Torque Torsion Torsional capacity Capacity OD ID(in) (ft.lbs) al Yield Yield w/conn. (kips) (in) (ft lbs) (II.lbs) (gal/ft) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Efforts should be made to minimize high doglegs in surface hole. ESP equipment will be damaged running through high doglegs. Inform the Drilling Engineer of any doglegs over 6 degrees per hundred. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures • Flow rates and hole cleaning • Ported float valves are required in all hole sections 5120-N4 Drilling Wellplan Page 9 of 47 02/16/12 fif* 2nd us operating WELL S120-N4 Surface Hole Procedure: 1. Pick up and drift all DP,HWDP,and DC's for surface section to confirm free of debris. 2. PU BHA(Include UBHO for Single shot E-line Gyro if MWD surveys are not clean initially)for directionally drilling to Surface Casing point with one BHA 3. Directionally drill surface hole: ➢ Drilling Parameters: • 650-800 GPM • Lower flow rates of 450-600 GPM will help avoid anti-collision boundaries by minimizing hole washout and optimize dog leg capability in the build section • RPM:40-80 RPM ➢ Avoid anti-collision boundaries > Take MWD surveys as frequently as needed. Carefully review the anticipated close crossings with existing wellbores. Make sure that directional drillers are aware of all drilling close crossing issues,hardlines and no-go lines. If a no-go or hardline has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. 4. Hole conditions will always determine final mud properties. > Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas-cut mud before continuing to drill. • Due to expected gas hydrates,keep mud as cool as possible(cold lake water). • Control drilla 10 to 120 fph through any troublesome zone so the hole does not load-up with gas cut mud. • • Check and report trip gas. • • Have 2 ppb Lecithin on location prior to drilling below the permafrost to minimize the effects of hydrates on the mud if hydrates are encountered. > Consider adding 0.5%Drillzone for screen blinding in shallow intervals right below the conductor. 5. Surface casing point: ➢ Landed in good shale found in this area between 2000' SSTVD and 2150' SSTVD > Below the sand at the base of the Sagavanirktok Formation(SV-1). ➢ Inside the upper Ugnu(UG-4). > Drill the footage necessary to leave the appropriate amount of rathole below the casing shoe. 6. Backream out of the hole at surface casing point: > Circulate until shakers are clean(+/-3 to 5 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 800 GPM or higher • 80 RPM or higher ➢ Backream to the HWDP • 800 GPM or higher • 80 RPM or higher • Pull 5-10 feet per minute • Decrease backreaming speed as torque and pump pressure dictate. SI20-N4 Drilling Wellplan Page 10 of 47 02/16/12 em1 us itperat ng WELL SI20-N4 • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the HWDP. Do not attempt to pull out on elevators once backreaming has started. • Expect+/-100%increase in cuttings from 1800'-600'. • Lesson Learned from:While backreaming out of the hole in the transition from horizontal to vertical, have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate ➢ Once the HWDP is reached,circulate until hole is clean(shakers clean) 7. Pull and lay down BHA. 8. Perform a dummy hanger run before running casing. Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (PO) . Type (in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Surface Casing Connection Make Up Torque (ft.lbs) OD WT Opt. (in) (pp{) Grade Conn.Type Make Up Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casing Running Notes a. Surface casing will be landed on hanger and emergency casing slips will be the contingency plan. b. Rig up and utilize a Fill Up tool for the casing job. c. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. d. Any packing off while running casing,and especially while above the base permafrost,should be treated as a very serious problem if major returns are lost. Run 4"lines from side outlets on conductor to a Vac Truck to help reduce pack off problems and minimize chance of spill. It is preferable to pull casing out until circulation can be re-established rather than risk not getting cement to surface. Contact the Drilling Superintendent if the casing packs off high for discussion of the options. e. Have Vetco representative verify the correct casing hanger is on location prior to the point at which it is needed. f. Torque values for the BTC casing are determined at the rig by making up the connection to the make-up mark (base of triangle). Record torque values for the first 10 connections made up in this manner and average. This average will be used as the make up torque for the remainder of the string. SI20-N4 Drilling Wellplan Page 11 of 47 02/16/12 • 2nn us operrah nng WELL S120-N4 1. Inspect and drift all surface casing to 12.259". 2. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. 3. While RIH with the the Casing: ➢ obtain SO Weights every 10 joints ➢ obtain PU Weights every 10 joints 4. Run the surface casing as follows: Surface Casing Running Order 1 Float shoe Bakerlock 2 2 joints 13-3/8"68#L-80 BTC casing Bakerlock 3 Float Collar Bakerlock 4 _13-3/8"68#L-80 BTC casing ** TAM BTC port collar+/-500 ft Only run if losses are expected 6 13-3/8"68#L-80 BTC casing to hanger 7 Vetco Gray 13-3/8"mandrel hanger 13-3/8"landing joint Slick landing joint if not 8 running the TAM port collar **If TAM port collar is run: • A landing joint,which has a connection that can be broken below the rotary table,will need to be run to allow for running the drill pipe inside the 13-3/8"without needing a false rotary table. Also,the drill pipe running tool needs to be on location and stood back in the derrick ready to run in case the TAM port collar needs to be opened to circulate cement to surface. • If decision to run is at the last minute,ensure the additional footage of the port collar plus handling pup will allow for sufficient rathole below the surface casing shoe. Surface Centralizers +/- 18 13-3/8"Tandem Rise Weatherford SI20-N4 Drilling Wellplan Page 12 of 47 02/16/12 • us operating WELL SI20-N4 Surface Centralizer Placement 111 10' 13-3/8"x 16"Tandem Rise Centralizers oa Collar • 2 at 5'&8' above Float shoe on stop collars,using stop buttons or stop collars. • No centralization on collar of l't joint. • 1 at 10' above Float Collar,using stop buttons or stop collars. • From 3rd joint through tail slurry(500'tail slurry), 1 centralizer per joint run on collars. Do not allow centralizer to float between collars. • 2 on 13-3/8" casing collars,inside conductor @ TD so csg can be reciprocated. 5' A SI20-N4 Drilling Wellplan Page 13 of 47 02/16/12 %kis e n o us operrahng WELL SI2O-N4 Surface Cementing Program Section Casing Size Type of Fluid/ Cmt Volume Properties Mudpush II 100 bbls Density10.1 ppg Lead Slurry Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) 388 bbls Yield 2.45 ft3/sk Tail Slurry Density 12.5 ppg (DeepCRETE) 75 bbls yield 1.56 ft3/sk Top of Tail @ 1,936'MD Surface Cementing Casing Cementing Notes a. Obtain and review the Test Report from the cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. b. Use split landing joint if TAM port collar is utilized and needs to be opened by running tool on drill pipe. 1. After reaching bottom, rig up and circulate with casing on bottom at 5 bpm, if possible, without losing returns. Reduce mud viscosity prior to pumping cement if necessary. D To help ensure good cement to surface after running the casing, and if practical for existing hole conditions, condition mud to YP < 20 lb/100ft2 prior to cementing the casing but after the casing is on bottom. Have adequate supply of cold lake water on hand to ensure the desired rheologies can be achieved. 2. Rig up to cement and pressure test cement lines. 3. Pump cement job per the attached Schlumberger cementing plan. Cement volumes are based on 35%excess below the Permafrost and 190%excess in the Permafrost. D If necessary,verify that the TAM Tech has located the proper crossovers to his combo running tool D If necessary,rack TAM running tool in derrick and ready to run D Hook up or install a water inlet below the landing ring(to the 3"threaded nipples)and the mandrel hanger to add water to clabbered mud returns when necessary. D Run 4"lines x-over from 3"side outlets to a vacuum truck. • Include a tee to allow for cement sampling 4. Report the number of bbls of cement returned to surface: D Task one person to be in charge of monitoring for cement returns and volume of cement returns D Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement at 8.5 bpm maximum. 8. Drop circulation rate to 3 BPM for last 20 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. D Do not over displace the cement(no more than Y2 the shoe joint volume). SI20-N4 Drilling Wellplan Page 14 of 47 02/16/12 • anti us operating WELL SI20-N4 ➢ Watch for signs of packing-off during pumping operations and closely monitor the cellar area for mud or cement returns around the conductor. ■ The pack off problem has occurred on some offset wells when the hanger by-pass area was restricted. ➢ In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. ➢ AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with 17 top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indicated on the conductor markings. ➢ If there is any doubt about the proper orientation,call the Drilling Superintendent. ➢ Ensure that the seal between the casing hanger and well head is tested to 5,000 psi for 10 minutes. ➢ Measure the distance from the rig floor to the top flange of the well head and record on the IADC report and in WellView. Complete the Rig Elevation Record and place it in the electronic well folder. 12. Nipple up the 13-5/8" 5M BOP stack and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low F . ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. ■ PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC SI20-N4 Drilling Wellplan Page 15 of 47 02/16/12 • eno• us operating WELL SI20-N4 Pick Up Intermediate Drilling Assembly for Pilot Hole 1. Install wear bushing. Pick up: ➢ 12-1/4"bit • Mud Motor • PWD • GR/RES 2. RIH to top of float equipment and pressure test surface casing to 2500 psi for 30 min and record on chart. ➢ Plot Casing Pressure Test on LOT form on N drive. Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. ➢ Note: All BHA trips thru the TAM port collar(if applicable)should be done slowly with slow rotation to avoid accidentally opening port collar. If set-down weight is noted,stop immediately,PU,resume slow rotation and try slacking off through port collar area. 3. Displace hole to new LSND/OBM mud system. 4. Drill out the float collar&shoe. ➢ See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 5. Drill 20'-50' of new hole using spud mud. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 11.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Plot on LOT form on N drive. SI20-N4 Drilling Wellplan Page 16 of 47 02/16/12 e n a us operarins WELL S120-N4 PILOT HOLE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (PBI) Formation Tops Measured Depth,ft True Vertical Depth,ft Comments SV-4 754 751 SV-3 1136 1120 SV-2 1412 1378 Base Permafrost 1750 1693 SV-1 1937 1870 Ugnu Top(UG4) 2253 2178 13 3/8" csg point 2559 2484 UG-2 Coal Bed Marker 2840 2484 Surface CP LUgnu 3469 3394 / ._.Schrader Bluff 3880 3805 1st coring point will N Seq Top 3933 3858 be confirm after log N Top 3980 3904 N Bottom 4017 3942 N Seq Base 4079 4003 2nd coring point will be confirm after OA Sand Top 4135 4059 log OA sbl2 4145 4069 OA sbl3 4150 4075 OA sbl4 4163 4088 OA Sand Bottom 4175 4100 TD 12 1/4" Pilot TD 12 1/4" Pilot Hole 4325 4250 Hole SI20-N4 Drilling Wellplan Page 17 of 47 02/16/12 iffy* ( ru us operaing WELL SI20-N4 Pilot hole Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the"N" sand Interval Density P , 6 RPM API FL pH Drill Solids MBT (ppg) Reading (ml/30min) (%) Intermediate: 9.2—9.4 12-18 12-18 <6.0 9-10 <6.0 Intermediate Logging/Formation Evaluation Program: Intermediate: MWD—Directional/PWD(Pressure While Drilling) LWD—GR/Res Intermediate Drill Pipe Tool Tool Make Up Joint Body DP Tensile Pipe WT Conn. Joint Body Torque Torsion Torsional capacity Grade Joint Capacity (ppf) Type OD ID(in) al Yield Yield w/conn. (in) ID(in) (ft.lbs) Cl lbs) (ft.lbs) (Sal/ft) fps) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 46.21 Intermediate Section Notes: a. Shallow test MWD tools. b. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. c. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. d. Keep shut down times to a minimum during connections. e. Swab/Surge: Make"easy on,easy off'slips a standard practice f. Control the ROP if necessary to maintain good hole cleaning g. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. SI20-N4 Drilling Wellplan Page 18 of 47 02/16/12 • eno• us operating WELL SI20-N4 Pilot hole Drilling and coring 1. Directionally Drill 12-1/4" pilot hole to 1s` core point 2. POH drilling assembly 3. M/U and RIH coring assembly 4. Cut 1S`core(Nsand) as required 5. POH and L/D coring assembly 6. RIH drilling assembly ➢ 12-1/4"bit • Mud Motor • PWD • GR/RES 7. Drill 12 'A"hole to 2" core point 8. POH drilling assembly 9. M/U and RIH coring assembly 10. Cut 2"d core1OA Core)as required (coordinate with the well site geologistl; 11. POH and L/D coring assembly 12. RIH drilling,assembly ➢ 12-1/4"bit • Mud Motor • PWD • GR/RES 13. Drill ahead to Pilot hole TD 4325' MD; 14. Run open hole logs as per logging program(Ouad combo+caliper second run CMR) SI20-N4 Drilling Wellplan Page 19 of 47 02/16/12 filo, , us oiler ahng WELL SI20-N4 Pilot Hole Plug Back 1. At least 24 hours notice of plugging operations must be given to the AOGCC 2. ENSURE Pilot hole Geological objectives are met and logging is completed through the bottom of the reservoir. 3. Make up 5"mule shoe, and 5"drill pipe and RIH to TD. 4. Circulate and balance MW in&out. D. Circulate at least 2x hole volume to lower the bottom hole circulating temperature 5. Spot balanced cement plug per attached Schlumberger CemCADE: ➢ See attached plug cementing procedure from Schlumberger FLUID FLOW RATE VOLUME (bbl/min) (bbl) Citric Pill 5 40 MUDPUSH 5 70 Plug Slurry 4 11141 MUDPUSH 5 8.9 Citric Pill 3 5.1 Mud 8 50.3 D. TOC will be inside the 12-1/4"open hole at+/-3648' MD per Schlumberger design(N sand top 3979' MD) ➢ See attachment for 15.8 ppg Class G plug slurry mixture and pumping procedure ➢ Obtain lab results for mixture and setting times before pumping 6. After displacement,pull slowly(<30 ft/min to avoid contamination). 7. Reverse circulate contaminated cement(6 BPM)and until returns clean. 8. Pick up a few stands and pump"Nerf Ball"wiper ball down DP to wipe cement in DP 69--. ENI requests that AOGCC waive tagging the bottom cement plug per AAC25.112 Well plug requirement. Pending positive indications from the following: ➢ Wire line caliper log will be run to evaluate the exact volume of cement(+ 10%excess)to cover N sand interval and OA sand. \c", ➢ If there are some indications of poor cement job(losses,lost return,excess cement of surface during the circulation)Eni will tag the cement plug to evaluate the exact depth. ➢ PERMIT TO DRILL requires BOP testing frequency every 14 days 5120-N4 Drilling Wellplan Page 20 of 47 02/16/12 C?f O us operating WELL SI20-N4 • Kick-off Plug 1. Circulate and balance MW in&out. 2. Spot 44 bbl Hi Vis 14 ppg pill at 3400' 3. POOH to 3100' Circulate 2 bottoms up.. 4. Spot balanced cement plug per attached Schlumberger CemCADE: ➢ See attached plug cementing procedure from Schlumberger FLUID FLOW RATE VOLUME (bbl/min) (bbl) Citric Pill 5 40 MUDPUSH 5 70 Plug Slurry 3 105 MUDPUSH 5 9.9 Citric Pill 3 5.7 Mud 8 27.4 ➢ TOC will be inside the 13 3/8"casing at+/-2420' MD per Schlumberger design ➢ See attachment for 17 ppg Class G plug slurry mixture and pumping procedure ➢ Obtain lab results for mixture and setting times before pumping 5. After displacement,pull slowly(<30 ft/min to avoid contamination). 6. POOH to 2350' and circulate a full bottom up 7. Pick up a few stands and pump"Nerf Ball"wiper ball down DP to wipe cement in DP 8. Refer to compressive strength chart for WOC times 9. Stand back 5"DP. Visually inspect DP on trip out for cement. ➢ PERMIT TO DRILL requires BOP testing frequency every 14 days SI20-N4 Drilling Wellplan Page 21 of 47 02/16/12 en us operraCins WELL SI2O-N4 Pick Up Intermediate Drilling Assembly 1. Pick up: 12-1/4"bit • Mud Motor • PWD • GR/RES 2. Run in hole and tag TOC to ensure hardness > Refer to compressive strength chart for WOC times 3. Time drill cement top to sidetrack 4. Directionally Drill 12-1/4"hole to Intermediate casing point @ 4771' MD/3939' TVD. S120-N4 Drilling Wellplan Page 22 of 47 02/16/12 WELL SI20-N4 INTERMEDIATE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (6) True Measured Formation Tops Vertical Comments Depth,ft Depth,ft SV-4 755 752 SV-3 1137 1121 SV-2 1412 1379 B/Permafrost 1750 1646 SV-1 1937 1871 Ugnu Top(UG4) 2253 2179 13-3/8" Csg 2559 2484 SCP UG-2 Coal Bed Marker 2882 2805 Lower Ugnu 3621 3461 Schrader Bluff Top 4030 3736 N Sequence Top 4082 3764 N Top 4178 3809 ReCalc Intermediate Cement w/Actual N Bottom 4295 3856 N Sequence Base 4444 3901 9-5/8" Casing Point 4771 3939 OA Top 4866 3944 OA-2 Top 4975 3950 TD 12587 3829 Total Depth SI20-N4 Drilling Wellplan Page 23 of 47 02/16/12 101 en us operraing WELL SI20-N4 Intermediate Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the "N" sand Interval Density PV 6 RPM API FL pH Drill Solids MBT (ppg) Reading (ml/30min) (%) Intermediate: 9.2—9.4 12-18 12-18 <6.0 9-10 <6.0 <18 Intermediate Logging/Formation Evaluation Program: Intermediate: MWD—Directional/PWD(Pressure While Drilling) LWD—GR/Res Intermediate Drill Pipe Tool Joint Body DP Tool Make UTensile Pipe WT Grade Conn. Joint Joint Body Torguep Torsion Torsional capacity Capacity (ppJ) Type OD ID(in) al Yield Yield w/conn. (in) ID(in) (ftlbs) (ft lbs) (/t.lbs) (gal/ft) (fps) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 Intermediate Section Notes: h. If the well is to be an ESP producer,a pump tangent must be placed in the intermediate hole section as per the planned directional profile. The pump tangent must be within 300' TVD from the top of the uppermost OA sand and at least 200'MD in length. i. Efforts should be made to minimize high doglegs above the pump tangent(if applicable). The ESP equipment will be damaged running through high dog legs(>6 degrees per hundred). j. Shallow test MWD tools. k. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. 1. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. m. Keep shut down times to a minimum during connections. n. Swab/Surge: Make"easy on,easy off'slips a standard practice o. Control the ROP if necessary to maintain good hole cleaning p. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. SI20-N4 Drilling Wellplan Page 24 of 47 02/16/12 Iff* no us operating WELL SI20-N4 Intermediate Drilling 1. Directionally Drill 12-1/4"hole ➢ Use the following Parameters: 2. Casin2 Point: Land Intermediate casing 50' into the 0A2 sand reservoir 3. LOW ROP:Consult with Town as ROP drops to< 1-2 ft/hr for one(1)full hour. This usually occurs in the Lower Ugnu at high tangent angles(+80 degrees). Goal is to avoid excessive BHA and DP wear. Decision should be made to trip BHA out of the hole before excessive wear begins. 4. Backream at Intermediate Casin2 point: > Circulate until shakers are clean(+/-5 to 7 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 900 GPM • 120-140 RPM ➢ Backream into the surface casing shoe. • 900 GPM • 120 RPM • Slow backreaming speed when pulling into the surface casing shoe/rathole. Hold parameters steady at 900 GPM and 120 RPM. Large chunks of coal can be deposited in the 16"rathole near the shoe. • Lesson Learned from OP09-S 1:While backreaming out of the hole in the transition from horizontal to vertical,have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. Check drilling nipple for overflow at BOP's. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the surface casing shoe. Do not attempt to pull out on elevators once backreaming has started. ➢ Circulate until shakers are clean(+/-3 to 7 bottoms up per K&M model)in the surface casing shoe • 900 GPM • 120 RPM 5. Pull and lay down BHA. SI20-N4 Drilling Wellplan Page 25 of 47 02/16/12 co* us operating WELL SI20-N4 Intermediate Casing Program: (all depths feet RI(B) OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (PPP Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) **Special 9-5/8 40 L-80 H5631 10.625 8.835 Drift 3090 5750 916 8.75 Intermediate Connection Make Up Torq ie (ft.lbs) Mui' Target Maa. OD WT Make Up Grade Conn. Type Make Up Make Up Yield Torque (in) (PPP Torque, ft- Torque Torque lbs 9-5/8 40 L-80 H561 10,800 13,000 N/A 75,000 **Special Drift casing to 8.75 Intermediate Casing Interval Notes: a. Ensure proper sized rams are installed and tested prior to running intermediate casing. b. Rig up and utilize a casing fill up tool for the casing job. Shoe Track: 1. Have a spare float shoe and collar made up with centralizers and on location ready to go ➢ Shoe joint misalignment has caused cross threading with Hydril 563 connection and requires make up by hand for first 10-15 joints • Make-up Shoe track(and first 10-15 joints)by hand using chain tongs until enough weight is in the slips to prevent cross threading • The shoe track joints should be Bakerlocked. • Inspect the float valves as the shoe track is picked up. • Run the shoe track into the well to test and confirm the floats are holding negative differential pressure. Connection Make Up: 1. Refer to the TenarisHydril"Running Manual General Guidelines"attachment for make up,pipe dope,etc....(Also available on Tenaris website) 2. Make up the first joint to the specified target torque and relax the tongs. D Draw a longitudinal line across the pin and box and reapply the published target torque. ➢ If the drawn line does not move more than'h"after the second torque application,continue running the rest of the string normally using the published target torque. D If the drawn line moves more than'h"after the second torque application,this indicates that a portion of the torque was absorbed by other variables in the make-up system.If this occurs,follow these steps: • Increase the target torque by 15%and reapply the torque. • Draw a second line and apply the original,specified target torque. • If the second drawn line does not move more than 1/2",continue running the rest of the string normally using the 15%higher target torque. • If the second drawn line moves more than 1/2",recheck the alignment,dope application and tong function, then continue to repeat this procedure from above until the drawn line does not move more than''/z". SI20-N4 Drilling Wellplan Page 26 of 47 02/16/12 cf* 2no ass operahns WELL SI20-N4 • It is best practice to repeat this procedure in the event the tongs are changed out during the running of the pipe. 3. Ensure that the joint about to be made up is hanging along the same axis as the joint in the slips. Due to the fact that sometimes the rig is a few inches off center the slips and bell nipple may have to be adjusted. Casing Running Order 1 Float shoe—Davis-Lynch Model 501-DV-PVTS Baker Lock down jet float shoe(double valve)**** 2 2 joints 9-5/8"casing Baker-Lock Float Collar—Davis-Lynch Model Type 700 DVSB- 3 LAPN double-valve float collar w/anti-rotation Baker-Lock baffle**** 4 9-5/8"Casing 5 9-5/8"Casing 6 Vetco Gray 9-5/8"mandrel hanger 7 9-5/8"landing joint Slick landing joint for reciprocation purposes Centralizers +/-38 9-5/8"x 11-3/4"Rigid Hydroforms-CRIMPED Volant 1. Inspect and drift intermediate casing(drift 8.75"). 2. Centralizers(See Diagram Below) 3. Pull wear bushing. Install 9-5/8"rams and test. Pick up and run casing. 4. Monitor running speeds to minimize surge and swab pressures while running in or picking up off slips. ➢ K&M Engineer will provide a trip speed schedule for each intermediate casing run based on individual well mud properties,hole angle,and depth. ➢ Circulate casing capacity at surface casing shoe,then break circulation every+/-2,000'MD and check flow through floats. Circulate bottoms up each time. ➢ Monitor trip tank while running in hole. Reduce speed if decrease or loss of flow is noted. 5. While running in open hole with Casing: ➢ obtain SO Weights every 10 joints 6. Once on bottom with the casing: ➢ obtain PU and SO Weight 7. Run the casing string on bottom. Establish circulation rate and pressure while pumping at least 1-2 bottoms up to condition hole. Reciprocate casing while circulating and cementing. 8. If needed,circulate and thin mud to properties slightly as outlined in CemCADE and Mud plan summary after running casing to bottom and prior to pumping cement. SI20-N4 Drilling Wellplan Page 27 of 47 02/16/12 itio 1 • 2nn us operating WELL SI20-N4 Intermediate Centralizer Placement / NM a G 1 o' IIII4 Float 9-5/8"x 11-3/4" Hydroform Centralizers Collar Run 1 Hydroform: • On Stop collar 5'above Float shoe. • No centralizer on next joint • On Stop collar 10'above Float Collar. Hi • From 4th joint to+/-1000'above the shoe- 1 centralizer floated between collars • 1 centralizer floated between collars from N sand oil bearing zone to+/-500'above N sand oil bearing zone 1' ' a a PI D ._i 5' SI20-N4 Drilling Wellplan Page 28 of 47 02/16/12 11* en II us operr h nns I WELL S120-N4 Intermediate Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Citric Pill 35 bbls Density 9.5 ppg Intermediate 9-5/8" Mudpush II 80 bbls Density 10.5 ppg DeepCrete 139 bbls Density 12.5 ppg Top of Cement @ 3,178'MD (502 sacks) Yield 1.56 ft3/sk Intermediate Cementing Intermediate Cementing Notes: a. Obtain and review the Test Report from cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. If need be,confer with Drilling Superintendent. b. Do not over displace the cement(no more than 1/2 the shoe joint volume). c. For injectors,a cement bond log is required. Prefer to run sonic LWD in production hole BHA and log intermediate casing on trip in hole to drill out intermediate shoe. 1. Perform Rig pump efficiency check and confirm+96%efficiency before pumping and displacing cement. 2. Ensure Schlumberger re-calculates cement volume ba :: .nd actual depth! ➢ Cement volume is based on 50%excess and at least 100' of annular fill abo - .p of the N sand(highest known hydrocarbon bearing zone). Refer to attached cemen .- .i s eet for volumes. 3. Batch mix cement. Test cement lines and pump cement job as per the attached Schlumberger program. 4. Displace cement with rig pumps and LSND water-based drilling mud. ➢ Ensure that the cement unit and rig pumps are manifolded so there will be redundancy in case of any pump failure during displacement. D Pump cement at 5 bpm and displace with 8.0 bpm if possible without losing returns. Slow rate to 3 bpm during last+/-30 bbls prior to bumping plug. 5. When the plug bumps,pressure the casing to 500 psi over the fmal displacement pressure and ensure that the string is holding pressure. Notify the Drilling Superintendent if the string will not hold pressure. Bleed off pressure and ensure the floats are holding. If the floats leak,pressure back up to final displacement pressure and shut in cementing head. 6. Land casing on mandrel hanger ➢ Maintain reciprocation as long as possible 7. Install Vetco 9-5/8"packoff assembly. 8. Pressure test packoff per Vetco Gray. D Do not exceed 80%of intermediate casing collapse ➢ Record test on IADC report and in WellView SI20-N4 Drilling Wellplan Page 29 of 47 02/16/12 t#1 en i us operating WELL SI20-N4 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. ➢ Cement Consistency of 50 Bc(Bingham consistency)is not pumpable. 50 Bc is achieved roughly 4 hrs after mixing cement and starting downhole. ➢ Pressure limitations are as follows: 80%of surface burst or 80%of intermediate collapse,whichever is less. ■ 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) ➢ Freeze protect the surface by intermediate annulus with diesel at 1-1/2 to 3 BPM. Pump enough diesel to flush and freeze protect to the surface casing shoe. 10. Install rams and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC 11. Install wear bushing. 12. Clean mud pits in preparation to receive OBM • Pits must be clean and free of all Barite 5I20-N4 Drilling Wellplan Page 30 of 47 02/16/12 ifios • eno• us operating WELL SI20-N4 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly. ➢ 8-3/4"PDC ➢ Rotary Steerable ➢ Flow rate: 550 GPM ➢ 120-140 RPM 2. RIH to the float equipment. ➢ Pressure test the casing to 3000 psi for 30 min and record on chart(AOGCC required casing integrity test). ➢ Plot Casing Pressure Test on the Pressure LOT form in N drive Oil Based Mud Fluid Displacement 3. Displace casing to new Oil Based Reservoir Drilling Fluid ➢ Do not contaminate new OBM in rig pits ➢ Displace old water based fluid to trucks or exterior tanks for disposal 4. Drill out the float collar&shoe. ➢ See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 5. Drill 20'-50' of new hole using the Oil Based Reservoir Drill-In fluid. 6. Perform Leak Off Test as per AOGCC re. ' - • • owing the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise ..st 13.0 p EMW,s t down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 12.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Do not pump more than 1/2 bbl after leak off is determined. There is no need to pump more than 1/2 bbl into the leak off and extend the fracture. ➢ Plot on LOT form in N drive 5120-N4 Drilling Wellplan Page 31 of 47 02/16/12 tiff* en operrfins WELL SI20-N4 PRODUCTION SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan 2) True Measured Formation Tops Vertical Comments Depth,ft Depth, ft SV-4 755 752 SV-3 1137 1121 SV-2 1412 1379 B/Permafrost 1750 1646 SV-1 1937 1871 Ugnu Top(UG4) 2253 2179 13-3/8" Csg 2559 2484 SCP UG-2 Coal Bed Marker 2882 2805 Lower Ugnu 3621 3461 Schrader Bluff Top 4030 3736 N Sequence Top 4082 3764 N Top 4178 3809 ReCale Intermediate Cement w/Actual N Bottom 4295 3856 N Sequence Base 4444 3901 9-5/8" Casing Point 4771 3939 OA Top 4866 3944 OA-2 Top 4975 3950 TD 12587 3829 Total Depth SI20-N4 Drilling Wellplan Page 32 of 47 02 16.12 10101 • 2n0 us operreing WELL SI20-N4 Production Mud Program: FazePro Density HTHP FL Electrical Interval YP Oil:water Stability (ppg) (m1/30min) mlVolts Production 9.2 14-20 <5.0 65:35 >600 Production Logging/Formation Evaluation Program: Production: MWD Directional/PWD(Pressure While Drilling) LWD GR/Res/Sonic Production Drill Pipe Tool Tool Make Up Joint Body DP Tensile Pipe WT Grade Conn. Joint Joint Body Torque Torsion Torsional capacity Capacity (ppJ type OD ID(in) al Yield Yield w/conn. (in) ID(in) (Albs) (ft lbs) (Albs) (gal/ft) (kips) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 Production Section Notes: a. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow test MWD tools. c. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. d. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. e. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. OpenholeSidetrackin2 Practices: f. Lowside in a fast drilling interval where the wellbore is heading up and where the ABI's show a good build rate. g. Orient within 15 degrees either side of lowside and trough with high rotary RPM's while reciprocating from the kickoff point back to the first stabilizer. Trough for approximately 30 minutes. h. Time drill at 4 to 6 feet per hour with high flow rates and rotary RPM's for the first 5 feet. Gradually increase the penetration rate as the openhole sidetrack is achieved. i. If any openhole sidetracks are drilled,confer with Drilling Supt.and consider tripping without circulating or without rotating past the sidetrack point. SI20-N4 Drilling Wellplan Page 33 of 47 02/16/12 ------W eni us operatong WELL SI20-N4 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. ➢ Geosteering will be required to remain in the target boundary 100%of the time ➢ Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. ➢ Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: ➢ At TD circulate 50%of calculated TAD cleanup cycle pulling 1 stand per bottoms up. Once the first 50% cleanup cycle is completed circulate the remaining 50%of the calculated cleanup cycle pulling 2 standsper bottoms up. Decrease backreaming speed as torque and pump pressure dictate. • 550 GPM • 120-140 RPM ➢ Backream into the intermediate casing shoe. • 550 GPM • 120-140 RPM • Slow backreaming speed when pulling BHA into the Intermediate casing shoe/rathole. Hold parameters steady at 550 GPM and 120 RPM. • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming. Do not attempt to pull out on elevators once backreaming has started. 3. Drop rabbit down drill string once bit is above the intermediate shoe: the SLM of landing string portion of the tapered DP • Drift OD dependent on Completion • COMPLETION DP RABBIT SIZE: 2-3/8"OD • All drifting tools will be accounted for and held in one place at all times. 4. Continue backreaming until depth at which it is possible to pull out on elevators at>9.1 swab EMW at 2.5 min/stand • 550 GPM • 120-140 RPM • Determine depth at which swab can be kept>9.1 EMW at 2.5 min/stand as per K&M TAD Model. 5. Circulate until shakers are clean as per K&M. • 550 GPM • 120-140 RPM 6. Slug DP and trip out of hole on elevators. ➢ Utilize K&M's swab model to control trip speed and avoid swabbing the open hole below 9.1 ppg EMW. 7. Lay down BHA ➢ When out of hole,down load the recorded tool data and send to the Geologist in town SI20-N4 Drilling Wellplan Page 34 of 47 02/16/12 1 • 2nn us operating WELL SI20-N4 Production Liner Completion DP RABBIT SIZE Will BE: 2-3/8" OD Production Liner OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (ppb Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) 5-1/2 15.5 L-80 5 dni 5.713 4.95 4.825 4990 7000 361 Production Liner Connection Make Up Torque (ft-lbs) Min. Opt. Max. OD WT Grade Conn. Type Make Up Make Up Make Up Yield ( 0111.0Torque, ft- Torque* Torque Torque lbs 5-1/2 15.5 L-80 Hydril 521 5500 6200 N/A 24000 * See attached TenarisHydril Guidelines for make-up torque recommendations Production Liner Centralization From To Quantity/Joint Fixed/Floating Type Shoe Liner 1/joint Fixed 5-1/2"x 7" top -Mid joint -Crimped on -Hydroform,Volant(Crimp on) Liner Running Procedure Notes: • Ensure proper crossover from DP to slotted liner is on the rig floor in case of a well control situation. • The liner will be run in FazePro RDF. Consult with completions engineer for liner detail. Liner string will be adjusted according to actual depths after drilling. Consult with completion engineer and ops geologist to determine exact placement and number of swell packers prior to installation. • Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. • Ensure accurate torque and drag data is gathered. Record pick up and slack off weights every stand and free rotating torque every five stands. Data gathered will assist in future liner running operations throughout the project. • Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well and recorded in WellView. • Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. • Review all setting operations and shear pressures with Baker Oil Tools service hand. • Ensure that all workstring components have been rabbited as ball will be dropped to actuate downhole tools.Rabbit DP on last trip out of prior to running liner. • If any openhole sidetracks have been drilled,monitor sidetrack depths during run in and ensure shoe enters the correct hole. SI20-N4 Drilling Wellplan Page 35 of 47 02/16/12 VW* 2rn111 us operr has LWELL SI20-N4 • DO NOT run E-CD subs on drill pipe while running liner string. • Torque ratings for string components: String Components Yield Torque(ft-lb) 5" 19.5#TT525 Drill Pipe 74,100 HRD Running Tool 40,000 7"29#Hydril 563 39,000 5-1/2" 15.5#Hydril 521 16,000 • Shear pressures for liner hanger assembly: Item Description Shear Value Shear Range HRD Running Tool,7" Nominal- 3192 psi 15%+ 3671 psi 4650 mch rel,2 pins 15%- 2713 psi Pusher Tool Activation Nominal- 1986 psi 15%+ 2284 psi 15%- 1688 psi Pusher Tool Neutrlz. Nominal- 3588 psi 15%+ 4126 psi 15%- 3050 psi Ball Seat SOLID *****Make-up torque for liner hanger sub-assembly,including running tool connections,should be torqued to 14,000 ft-lbs prior to deliver to rig. Procedure: 1. Hold Pre job safety meeting to ensure all parties understand operation 2. PU the Liner Assembly and Running/Inner String as outlined above. 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. Fill Liner Tieback Sleeve with"pal mix" and ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 minutes for mixture to set up. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. Record ROTATE,PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIH with Liner Assembly as hole conditions allow,but do not exceed running speed of one stand per minute. Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. Circulate minimum of one DP volume and record ROTATE,PU and SO weights. 8. Record PU, SO, and Rotating torque in open hole every 500' to ensure friction factors are sufficient to run the liner to bottom successfully. If friction trend indicates liner will not go to bottom then call Drilling Supt.immediately. 9. Rotating liner 20-60 RPM will be necessary to run to bottom. 10. Continue RIH with Liner Assembly to proper setting depth. Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8"casing shoe. 11. Trip slightly deeper than desired liner top location with liner top. Last motion of the liner should be up to ensure it is set in tension. Ensure Liner Hanger assembly does not exit 9-5/8"casing shoe. 12. Prior to setting the hanger&packer,double check all pipe tallies and record amount of drill pipe on location. 13. Rig up to pump down workstring with rig pumps. Pressure test lines. Bleed off test pressure. SI20-N4 Drilling Wellplan Page 36 of 47 02/16/12 em us operating WELL SI20-N4 14. Drop setting ball down the workstring and pump slowly(1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 15. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 minutes each up to 4000 psi. 16. Packer can now be pressure tested. Bleed DP pressure to zero,close annular preventer and test annulus to 1,500 psi for 10 minutes and chart. 17. Bleed off pressure and pickup to verify that the HRD running tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, 4,650 ft-lbs of left hand torque can mechanically release the tool. 18. Once running tool is free and packer is tested,Displace mud from liner top to surface with 9.0 ppg KC1 brine per MI recommended program. 19. POOH and LD and inspect the liner running tools. Run 4-1/2" x 3-1/2" Injector Completion String Notes: a. An oil-based, delayed breaker system will be used to treat the wellbore prior installation of liner and completion. This fluid will be placed in the hole prior to the liner run. This system is designed to remove wall cake after a predetermined time interval. Fluid loss may be experienced beyond this time frame. Make note of time from displacement of this fluid to nipple up of tree. Ensure enough additional fluid is available to manage possible losses. b. Verify the rig is centered over the well prior to running the completion. c. Clear floor to allow room for two pneumatic spooling units. d. Strap and record the dimensions of each piece of equipment prior to RIH. e. Drift all 4-1/2", 12.6#tubing and equipment with a 3.833"OD rabbit, drift all 3-1/2" 9.23 tubing with a 2.867" rabbit. LCD's will only drift to 2.80". f. Three 4-1/2" x 6" VIT joints will be used below the tubing hanger. Locate VIT prior to beginning completion operations. g. If time permits, LCD's may be made up on full 3-1/2"joints prior to RIH in order to save time on rig. h. Use BOL 2000 NM thread compound with proper doping procedures. i. If rubber thread protectors, rather than shipping thread protectors, are used on skate, inpect protectors to ensure they will not damage pin connections. j. MU torque for IBTM tubing is determined by averaging the makeup torque required for the first 15 joints. Proper makeup occurs when the bottom of the pin makeup mark is flush with the top of the collar. k. TIH slowly (+/-1 jt/min) and avoid sudden starts and stops which may pre-set packer, especially while setting the rotary slips. Use caution when setting slips to avoid crushing control lines. 1. Verify all completion equipment has been operationally and pressure tested, and is dimensionally compatible with other equipment to be run. Record OD's and ID's of all auxiliary equipment on tubing detail. m. Inner string packers shall be spaced out to land in the middle of the blank packer joint and adjacent blank joint on the liner string(within +/-10 feet). Have 10' and 20' 3-1/2" pup joints on hand to assist in this spaceout. n. One 11x11 mm control line will be run from surface to TD on the completion string containing fiber optic lines and electric line for toe P/T gauge. A second 11 x 11 mm control line will be run from below the packer to surface for electric heel P/T gauge. Use extreme caution handling all gauge equipment and lines. 5120-N4 Drilling Wellplan Page 37 of 47 02/16/12 !ft* 2nd us operating WELL SI20-N4 o. Feed-through operations will be performed at each swell packer location on the 3-1/2" inner string. The encapsulated line will need to be stripped in the area of the feed-through for swell packers. Only strip enough line for the feed-through area,leaving encapsulation under all bands and clamps. p. A small table will be required over the rotary to perform feed-through for 3-1/2"packers. Allow room for table and cables around rotary. q. Tubing must not be allowed to turn while making connections or while TIH due to gauge lines. Back-up all connections while TIH. r. Fasteners for 3-1/2" polymer cable clamps should be made up to approximately 8.6 ft-lbs. A torque wrench capable of this torque will be required with a M8 hex socket cap head bit (back up wrench and bits are recommended). s. Fasteners for the 4-1/2"polymer clamps should be made up to approximately 8.6 ft-lbs using M8 hex bit. t. Ensure all ICD's are run in"open"position. Plug weep hole in pin thread protector,stand ICD subs upright and fill with water to check for flow-through just prior to running in hole and/or look inside and verify inner sleeve position. u. Space will need to be available for fiber optic and electric line splice work. Coordinate with Schlumberger service hands for requirements and placement. v. A"hot work"permit will be required for fiber optic line splice performed just above production packer. w. Do NOT place 3-1/2"polymer clamps any closer than one full joint from any jewelry in the string such as swell packers and 1CD's. Use banding for cable attachment in these areas. x. AHR Packer must be set below base of Ugnu formation must also be set at least 300' below top of intermediate cement. y. Ensure accurate drag data is collected during completion tubing run. Record pick-up and slack-off weights every 5 joints (or as directed by on-site engineer). Data gathered will assist in future completion operations throughout this development. z. Two 4-1/2"pup joints will we used between tubing hanger and VIT joints. This will allow make-up adjustment to orient hanger assembly properly without rotating entire string with cables. Do not torque this IBTM connection beyond makeup marks. aa. Completion Equipment Pressure Settings: GLM Valve Autofill Valve Mirage Plug AHR Packer 2,000 psi 1,050 psi 6,000 psi disc, start 1,700 psi, ann to tubing 4,250 psi shear full set 3,500 psi SI20-N4 Drilling Wellplan Page 38 of 47 02/16/12 If* en us operating WELL SI20-N4 ATTACHMENTS 1. Area of Review 2. Recommended Drilling Practices 3. Health,Safety,and Environment 4. Safety Meeting Topics 5. Well Shut In Procedure While Running Tubing 6. Conductor Broaching Contingency Plan 7. Port Collar Decision Tree SI20-N4 Drilling Wellplan Page 39 of 47 02/16/12 em us operating WELL SI20-N4 Area of Review To the knowledge of Eni US Operating Co.Inc.there are no other wells completed in the Schrader Bluff formation other then those stated in the attached 1/4 mile scan report. The Nikaitchuq Unit also includes the following wells drilled by Kerr McGee Oil&Gas Corporation: Nikaitchuq#1: Plugged and Abandoned 04/01/04 Nikaitchuq#2: Plugged and Abandoned 04/01/04 (East of Nikaitchuq Unit) Nikaitchuq#3: Plugged and Abandoned 04/26/05 Nikaitchuq#4: Plugged and Abandoned 04/21/05 Kigun#1: Plugged and Abandoned 03/30/05 Tuvaaq State#1: Plugged and Abandoned 03/09/05 To Eni US Operating Co. Inc.'s knowledge all wells have been cemented across the Schrader Bluff formation as per AOGCC regulations and plugged and abandoned. All wells that fall into the % mile radius said herein have been drilled and completed in the Schrader Bluff formation in accordance with 20 AAC 25 AOGCC regulations. SI20-N4 Drilling Wellplan Page 40 of 47 02/16/12 2rn10 us operfins WELL SI20-N4 Recommended Drilling Practices Hole Cleaning With a deviated well path and potential for losses,hole cleaning will require special practices. Pipe rotation is critical for effective hole cleaning. The maximum string RPM,as determined by the BHA,is specified for each hole section in the detailed procedures. The shakers should be monitored as an indicator of adequate circulating time. If circulation is of long duration,then pipe movement to prevent casing wear is critical and a stand should be laid down occasionally to prevent excess hole erosion over the length of pipe reciprocation. In addition the following practices should be employed at all times: a) Use all available solids control equipment to keep mud as clean as possible. b) Emphasize proper hole cleaning after slides by rotating at maximum allowable RPM c) As the hole angle increases,hole cleaning practices must be altered. Maximum pipe rotating speeds along with maximum achievable flow rates will increase hole cleaning efficiencies. Circulating times prior to trips should be increased accordingly to account for longer times required to remove cuttings from higher angle wells. d) Use good connection practices while drilling. After reaching the bottom of a stand,allow a small amount of circulating time to allow cuttings to get above the BHA prior to picking up off bottom. Be sure to pick up slowly to prevent packing off the cuttings bed around the top of the drill collars. Slower Trip/Connection Speeds High POOH and RIH speeds can aggravate fragile shales/formations due to the pressure variations between surge/swab. PWD data shows that excessive tripping and reaming speeds can exert pressure spikes in excess of 2 ppg equivalent. Effective ROP Strive to find the maximum effective rate of penetration.That is,the maximum rate at which a clean hole can be produced. While on bottom ROPs in excess of 400 fph may be possible,but such ROPs may load a high angle hole with cuttings that are not being removed fast enough. Using torque and drag trends,ECD and the shakers,establish a base line clean hole ROP,and then try to improve it by altering the hole cleaning practices. Slower Initial Pump Rates PWD data has shown that the most significant period for increased ECD occurs when the pumps are brought on at drilling rate while washing a connection to bottom. The study also concluded the least damaging procedure is if pump rates are held at 40%or less of drilling rate while reaming connections. SI20-N4 Drilling Wellplan Page 41 of 47 02/16/12 co* nd us operans WELL SI20-N4 Health, Safety & Environment The following are part of the mitigation&contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. H2S Contingency Measures Assume all locations have the potential for H2S. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H25 is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H,S encounter,drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures,full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,daily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. SI20-N4 Drilling Wellplan Page 42 of 47 02/16/12 11* 2ru us opereing WELL SI20-N4 Safety Meeting Topics Move In,Rig Up D Prior to spud,a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads-use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with various sizes of pipe and tubing, - Well control procedures, - Flow rates and hole cleaning,and - Diverter operation and crew responsibilities. D A'Diverting Shallow Gas'drill should be held with rig crews prior to spud,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. D. 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. D Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. D Perform and document all drills. D Designate crew member to control access at the pad entrance in case of diverter operation. Surface ➢ A'Stripping'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. > A'Well Kill'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. > A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. > Hole cleaning best practices,flow rates. D Stuck pipe,Lost circulation. ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production D Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss production hole risks and open hole drilling procedures. D Potential formation pressures and mud weight,Well control procedures. > Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. SI20-N4 Drilling Wellplan Page 43 of 47 02/16/12 001 rnn 1 us operr has WELL SI20-N4 D. Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Completion ➢ Operation of the control line spooler. ➢ Pinch points associated with tongs and slips. ➢ Proper tripping practices and hole fill calculations with tubing and control line. ➢ Well control practices while running production tubing with control line. ➢ Pressure testing and minimizing personnel exposure to pressurized lines. SI20-N4 Drilling Wellplan Page 44 of 47 02/16/12 • en0 us operating WELL SI2O-N4 Well Shut In Procedure While Running Production Tubing If well is suspected to be flowing: 1. Install TIW valve and pull back to the first banding point below the BOP stack. 2. Shut off air to control line spool and bleed off line pressure while checking well for flow. 3. If well is confirmed to be flowing,cut control line with bolt cutters directly above a banding point. 4. Slack off until full joint of pipe with no control line attached is spaced out across BOP stack. 5. Close annular and monitor pressure. If well is coming in rapidly and time is not permitted to complete above operations: 1. Install TIW and close annular around pipe and control line. 2. Shut off air to control line spool and bleed off line pressure while picking up a joint of drill pipe and making it up to TIW and top drive. 3. Close IBOP on top drive and open TIW valve. 4. Cut control line and strip the joint of drill pipe across stack for ram closure if needed. 5. If annular does not seal off around tubing and control line and the joint of drill pipe cannot be safely picked up, close blind/shear rams on production tubing. Notes: • Specify location of bolt cutters required to cut control line. • Need to have access to a joint of drill pipe and the appropriately sized elevators at all times. SI20-N4 Drilling Wellplan Page 45 of 47 02/16/12 voki • en0 us oyer atong WELL SI2O-N4 Conductor Broach— Contingency Cementing Plan In the event of a broach to surface of drilling fluids during the drilling of the surface interval,the following contingency plan is recommended to remediate the situation. Conductor Hole Diameter Conductor Casing Size 20" Conductor Setting Depth +/- 120' MD DP/Conductor Annular Volume 5"DP x 18.25"ID: (36 bbls) Conductor Pipe Volume 39 bbls 16"Open Hole Capacity 0.2487 bbls/ft 1. Upon establishing that a broach of the conductor casing has occurred,POOH and stand back BHA. 2. RIH with open-ended drill pipe to 20' below the base of the conductor pipe. 3. Establish circulation with mud at normal drilling rate. Begin circulating and establish rate of flow through broach with drilling fluid. 4. Circulate up to 120 bbls of water or until water returns are seen from the broach. 5. RIH to 200' below the base of the conductor. If mud viscosity is<300sec/qt.,spot a 150' pill of 150K cp polymer (Biozan)to 50' below the conductor. POOH to 20' inside the conductor. 6. Mix and displace+/-80 bbls of Artic Set 1 cement at 15.8 ppg. Cement may U-tube with no ability to obtain squeeze. Do not over displace DP. Monitor and gauge all returns. 7. POOH and WOC for 8 hours. 8. PU 16"bit and BHA and RIH to clean out cement to 40' below conductor. Establish normal circulating rate and evaluate broaching. If no broaching is seen,continue with planned operations. If additional broaching occurs, repeat steps 6,7 and 8. SI20-N4 Drilling Wellplan Page 46 of 47 02/16/12 • 2no us operafing WELL SI20-N4 TAM PORT COLLAR Utilization Decision Tree TAM Port Collar Utilization Decision Tree Begin Primary One Stage Cement Job No Cement Cement to to Surface Surface Drilling Foreman and ipple Up an. Engineer determine the X Test BOP's Top of Cement Top of 111111.1P7Continue wit Cement e above Port PortCompletion Collar ar (1000'TVD) TVD) X Indicators of Cement Top Perform Top Job as per ► Open Port Collar 1. Observation of Tracers in Spacer ahead of lead cement requirements of If Top Job is ineffective or using drillpipe. p AOGCC unacceptable to AOGCC 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface • Nipple Up and Circulate Cement Test BOP's to Surface and close Port Collar • Continue with Nipple Up and Completion Test BOP's Continue with Completion S120-N4 Drilling Wellplan Page 47 of 47 02/16/12 • Enll ° a Application for Permit to Drill SI20-N4 Proposed Drilling Program Requirements of 20 AAC 25005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: c 1) Move in / rig up Doyon 15. 1);�tj � re Ii,a) 2) ENI requests that AOGCC waive diverter requirements per 20 AAC 25.035. (h). (2). 3) Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4) Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 5) Install and test wellhead to 5000 PSI. 7G 6) Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. c" 7) Pressure test casing to 2500 psi per AOGCC regulations. Record results. 8) PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. i( f16- 9) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, -r( recording results. 10)12-1/4"Pilot hole section: 11) Directionally Drill 12-1/4" pilot hole to 1st core point, POH drilling assembly 12) M/U and RIH coring assembly k 13) Cut 1st core( Nsand) as required; 0,11.,ut14) POH and L/D coring assembly 15) RIH drilling assembly and drill 12 1/4 " hole to 2nd core point, POH drilling assembly 16) M/U and RIH coring assembly, Cut 2nd core (OA Core) as required; POH and L/D coring assembly 17) RIH drilling assembly Drill ahead to Pilot hole TD 4325' md; 18) Run open hole logs as per logging program ,/ 19)12 -1/4" Pilot hole plug back section: 20) RU to set cement plug 3�ro -7't 21) RIH to TD and circulate hole clean. Set a balance plug as per Ian. Circulate and drop drill pipe wiper. POOH{ ffoc) �, 22) Set a balance KOP plug as per plan. Circulate and drop drill pipe wiper. POOH 4-4,2 /05 084-5 23) PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD RIH and tag top of KOP cement plug. Polish cement plus to proposed KOP based on directional plan 24) Sidetrack well S ?- -- 120127$I29-S2-Drilling Proceudre.doc Page 1 of 3 Printed: 16-Feb-12 TOAti • EMI PtiroIIuim enll Application for Permit to Drill 25)12- 1/4"Intermediate hole section 26) Directionally drill to 9-5/8" casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 27) Install 9-5/8"casing rams in the BOP and test to 3500 PSI. 28) RU casing drive system. 29) Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 30) Install 9-5/8" Emergency Slips. 31) Install 9-5/8" packoff and test to 5000 psi. 32) Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. y�. 33) Pressure test casing to 3000 psi per AOGCC regulations. Record results." 67L 34) PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary-- steerable tool. RIH, clean out cement to top of float equipment. TZ 35) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. 36) Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 37) PU and run 5-1/2"slotted liner to TD. 38) Land liner, set liner hanger with 200' Liner lap inside the 9-5/8" intermediate casing. POOH laying down DP as required. 39) PU 4-1/2"completion assembly with Injection Packer as required and RIH to depth. • Verify that PHL packer placement is set below base of Ugnu formation and at least 300' below the top of intermediate cement prior to running in the hole. 40) Land tubing hanger and test upper and lower seals to 5,000 psi and hold for 10 min. 41) Line up to set packer. Test surface lines to 5,000 psi and bleed back to zero. 42) Set PHL Packer. • Pressure down tubing string to 3500 psi to set packer and hold for 30 min, record on chart. • Reduce tubing pressure to 2000 psi and pressure inner annulus to 2500 psi and hold for 30 min, record on chart. 43) Bleed all pressure off tubing. Pressure inner annulus to 2500 psi and shear SOV 44) Pull landing joint and set BPV 45) Nipple down BOP, nipple up tree and test void to 5000 psi for 10 min. • ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). (1). o- 120127 SI29-S2 Drilling Proceudre.doc Page 2 of 3 Printed: 16-Feb-12 los Enli PetirolItuim 2no Application for Permit to Drill • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. 46) Pull BPV and set TWCV. 47) Fill tree with diesel and function valves. Test and chart tree to 500 psi for 5 min. Test and chart tree to 5000 psi for 15 min. 48) Pull TWCV. 49) Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 50) Set BPV and secure tree and wellhead. 51) RDMO 3I1-‹3 120127 SI-29=S2 Drilling Proceudre.doc Page 3 of 3 Printed: 16-Feb-12 • • EMI eno Application for Permit to Drill SI20-N4 Saved: 16-Feb-12 Application for Permit to Drill Document Producer Well SI20-N4 Table of Contents 1. Well Name 3 Requirements of 20 MC 25.005(f) 3 2. Location Summary 3 Requirements of 20 MC 25.005(c)(2) 3 Please see Attachment 7:Surface Platt 4 Requirements of 20 MC 25.050(b) 4 3. Blowout Prevention Equipment Information 4 Requirements of 20 MC 25.005(c)(3) 4 4. Drilling Hazards Information 5 Requirements of 20 MC 25.005(c)(4) 5 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 MC 25.005(c)(5) 5 6. Casing and Cementing Program 6 Requirements of 20 MC 25.005(c)(6) 6 7. Diverter System Information 7 Requirements of 20 MC 25.005(c)(7) 7 8. Drilling Fluid Program 8 Requirements of 20 MC 25.005(c)(8) 8 Surface Hole Mud Program(extended bentonite) 8 Intermediate Hole Mud Program 8 (MOBM) 8 Lateral Mud Program 8 (MI FazePro Mineral Oil Base) 8 9. Abnormally Pressured Formation Information 9 Requirements of 20 MC 25.005(c)(9) 9 10. Seismic Analysis 9 AOGCC PERMIT Document.doc Page 1 of 11 Printed: 16-Feb-12 Eni Petirolleum en 11 Application for Permit to Drill SI20-N4 Saved: 16-Feb-12 Requirements of 20 MC 25.005(c)(10) 9 11. Seabed Condition Analysis 9 Requirements of 20 MC 25.005(c)(11) 9 12. Evidence of Bonding 9 Requirements of 20 AAC 25.005(c)(12) 9 13. Proposed Drilling Program 9 Requirements of 20 MC 25.005(c)(13) 9 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 10 Requirements of 20 MC 25.005(c)(14) 10 15. Attachments 11 Attachment 1 Directional Plan 11 Attachment 2 Drilling Hazards Summary 11 Attachment 3 BOP and Diverter Configuration 11 Attachment 4 Cement Loads and CemCADE Summary 11 Attachment 5 Drilling Procedure 11 Attachment 6 Formation Integrity And Leak Off Test Procedure 11 Attachment 7 Surface Platt 11 AOGCC PERMIT Document.doc Page 2 of 11 Printed: 16-Feb-12 .......... .... ...--..-.-... *4114r Enil •1 f -A pot Application for Permit to Drill SI20-N4 Saved: 16-Feb-12 1. Well Name Requirements of 20 MC 25.005(0 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: SI20-N4PB1 pilot, plug back hole SI20-N4 sidetrack, complete, then test SI20-N4 is an injection well from which we will be drilling a pilot hole to acquire two full cores. The pilot hole: SI20-N4PB1 will be drilled to acquire two full cores. The first core will be obtained in the Schrader Bluff N Sand and the second in the Schrader Bluff OA Sand interval. The N Sand is an oil bearing reservoir that lies approximately 100' stratigraphically above the primary reservoir for the Nikaitchuq project, the OA Sand. Following the core acquisition, a full suite of wire line logs will be obtained over both the N and OA Sand intervals for detailed Petrophysical analysis. Following the wire line logging the pilot hole will be Plugged and Abandoned prior to drilling the intermediate hole section of SI20-N4. 2. Location Summary Requirements of 20 MC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation, and at total depth, referenced to governmental section lines (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 4454.3 FSL 1350.6 FEL S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 54.1'AMSL Northing: 6,053,636' Easting:511,559' Pad Elevation 13.1'AMSL ENI petroleum plans to drill (then plug) a pilot hole with this final coordinates Pilot hole SI20-N4PB1 Location at Total Depth 3991 FSL 1136 FEL 19 T14N R9EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 4326 Northing: 6,053,173.220" Easting:511,775,920' Total Vertical Depth, RKB: 4250 Total Vertical Depth, 55: 4196 AOGCC PERMIT Document.doc Page 3 of 11 Printed:16-Feb-12 En! Application for Permit to Drill SI20-N4 Saved: 16-Feb-12 Injection SI20-N4 Location at Top of Productive Interval 4708 FSL 2360 FEL S19 T14N R9EUM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 4,866.49 Northing:6053887.05' Easting:510549.26' Total Vertical Depth, RKB: 3,944.20 Total Vertical Depth, 55: 3,890.10 Location at Total Depth 4740 FSL 2866 FEL 13 T14N R8EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12,587' Northing: 6,059,194' Easting: 504,957' Total Vertical Depth, RKB: 3,829' Total Vertical Depth, SS: 3,775' Please see Attachment 7:Surface Platt and (D)other information required by 20 MC 25.050(6); Requirements of 20 AAC 25050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.' (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.037,as applicable; Please see Attachment 3: BOP and Diverter Configuration AOGCC PERMIT Document.doc Page 4 of 11 Printed: 16-Feb-12 Air I* • En troleum ont, Application for Permit to Drill SI20-N4 Saved: 16-Feb-12 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards, including (A)the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is: MPSP = (3890TVDss)(0.45 - 0.11 psi/ft) Yc( = 1323psi f537/75 ''1-_ (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo pressured strata,lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: , (5)a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(0; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 5 of 11 Printed: 16-Feb-12 fp* • En! '' 'tre leu Application for Permit to Drill SI20-N4 Saved: 16-Feb-12 6. Casing and Cementing Program Requirements of 20 MC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program SI20-N4 See also Attachment 4: Cement Summary Hole Top Btm Csg/rbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 Driven 178.89 X-65 Welded 120 36/ 36 160'/ 160' Pre-Installed 1161 TOTAL sx 13-3/8 16 68 L-80 BTC 2524' 35/ 35 2559'/ 2484' LEAD: sx 2. ,pp De ASL TAIL: 270 sx 12.�ppg DeepCrete 502 TOTAL sx 9-5/8 12-1/4 40 L-80 Hydril 563 4738' 33 / 33 4771'/ 3939' 502 sx 12.5 ppg DeepCrete TOC:3,178'MD/3,085'TVD 8-3/4"OA 5-1/2 Sand 11.6 L-80 Hydril 521 8016' 4571'/ 3925' 12587'/ 3829' Liner in Open Hole-no cement Lateral SI20-N4 PB1 Pilot hole Plug from 4325' SI20-N4 PB1 Kick-Off Plug from 3100'to to 3650' 2450' FLOW VOLUME FLOW RATE VOLUME FLUID RATE FLUID (bbl/min) (bbl) (bbl/min) (bbl) Citric Pill 5 40 Citric Pill 5 40 MUDPUSH 5 70 MUDPUSH 5 70 111 105 Plug Slurry 4 15.8ppg Plug Slurry 3 Class G 17 ppg Class G MUDPUSH 5 8.9 MUDPUSH 5 9.9 Citric Pill 3 5.1 Citric Pill 3 5.7 Mud 8 50.3 Mud 8 27.4 AOGCC PERMIT Document.doc Page 6 of 11 Printed: 16-Feb-12 10A4111°' EniiEnt trole Application for Permit to Drill SI20-N4 Saved: 16-Feb-12 7. Diverter System Information Requirements of 20 MC 25005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 3: BOP Configuration. ENI requests that AOGCC waive diverter requirements per 20 MC 25.035. (h). (2). AOGCC PERMIT Document.doc Page 7 of 11 Printed:16-Feb-12 Enil =Aro ent Application for Permit to Drill SI20-N4 Saved: 16-Feb-12 8. Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program, including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 ✓ 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 sf) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (MOBM) (MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Value Point/pilot hole Density(ppg) 8.7-9.4 ✓ Value Plastic Viscostiy 15 - 25 Density(ppg) 8.8 - 9.5 / (CP) Funnel Viscosity T�60 Yield Point 15 - 20 (seconds) (lb/100 sf) Plastic Viscostiy 12 18 HTHP Fluid loss (CP) (m//30 min @ <5.0 Yield Point 18-24 200psi&100°F (lb/100 sf) Oil/Water 60/ 40 API Filtrate Ratio (cc/30 min)) 4 - 6 Electrical >600 Chlorides(mg/I) <500 Stability pH 9.0- 10.0 MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. AOGCC PERMIT Document.doc Page 8 of 11 Printed:16-Feb-12 fit* rail troDeum pm Application for Permit to Drill SI20-N4 Saved: 16-Feb-12 9. Abnormally Pressured Formation Information Requirements of 20 MC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 MC 25,005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 MC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 MC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 MC 25005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Please refer also to Attachment 5— Drilling Procedure • ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). (1). - • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the . tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. AOGCC PERMIT Document.doc Page 9 of 11 Printed:16-Feb-12 toot :j Eni iv trolleum pm Application for Permit to Drill SI20-N4 Saved: 16-Feb-12 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down the Spy Island Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. AOGCC PERMIT Document.doc Page 10 of 11 Printed:16-Feb-12 • EnO ° enn Application for Permit to Drill SI20-N4 Saved: 16-Feb-12 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Drilling Procedure Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt AOGCC PERMIT Document.doc Page 11 of 11 Printed: 16-Feb-12 N O ,7 r M60O6NN6s^bM 6N..6N D1f,7MN 6,746 bf,7M6 M,7aON 00) 0) b 2 66 60 ^ OO .OM N7.O6 nO N b 6NM M6 MMC Op 64... M Ob Nmr2M 60.-cyN aObbr 60 MaObb rrr,7r , d W" mmnLom mmm obbbb mbbbb 0,7,7,7,7 r,7n,7r nr nn nbbbn bnbhn nbbhb nnbbn N..nn b..nh .bnnh nn Q 0 Oa Mb b,7 N N,7IO626 8;828 C,726 NO0NM M OOO N '0002 OMM NN NN ( t X0 8.<0 2 N•1^7 0.6. I.7:282.7^ N.N ep 0b N OO b. h N0 M0^.0 b a2 r10pMr2 0 r7r7 N c 0 -c.c.. MpM MMNNN MMO Z MMMMn NMNMv22222 NovI2NNNN 2M0 22202 22 N 00000 00002 00000 OObpb 20000 20bMb 02022 00 N • Oibmm01O c•Noa MY)IO0 ,7200 0 aN0 o000' 0000b CO OI` O b ^ 60 6 0 b N a 00626 O)0 0 00 M o r 6' 6O) O)O) C W aC OG- 7.0^ C CNCyib N. N NN ei.000 4.-00 n 00 C Q -^ ..... NNNNN NNNNN2N^^ ,^ O a 2 X w 'a C at O 0 KC � O w N . d 0 0 0 N 0 2c,.:,2 O'R, a a b ra 6 M MM. ;-_`.2 •b M 6 M M 6 M 6 0OOo^ ^N0NN MM77M 76t766 Ml+ <aC pff0p faCae' Ca :2 C k 0 6 Q o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 88888 0 0 0 O O J'o 0 IO o 0 0 0 0 0 0 0 0 0 0 o O O o 0 0 0 0 0 0 0 0 0 0 0 0(0 0 0 0 O O D O 200N NNNNN NNNNN NN,-,:*- .^^^^ t7MMt71.j MMt7p OO 15 a ;: :::: 0 ::::: 00006 J0000 :::!: :!!!r 22 7JJJJ JJJJ EE 83262 NON.2 0 O)0 CO O 2°. ; .8 .11 O N,-4 O O G C O N .0 0 N N 646c;6 06c46.6N6 0 T O 80.- "b r r N.000 N N N N N N N v Etsgacr>�r�DD1No^ �N o a o ^ z 2 00 00 1,000 0 'D O S U 0 0 . O N O O K 3:28 N 0 Q m F O N 3 '“ 888g.1 O r N 0 N Io 6 6 6 a g%-"g-22,7 6 0 x 0 b a 0 M M NN610C OI�CbN O1) N O)M ln2)6,76 MANN Z OOO . NNNNN COpOi OO.piC 17Yi.<Oi eiON6ry No MC IMO IMo M0T 1 .. O G ^ ( ))4 ) I�6NM a M^*-NN"7,77 7c1" M^f,7r 2026 O NroM �n N O a o c v 9F oT d "lvgg4 'TIM YY N It ,o N p w c W t`U O W 9 N W q ffl«t1 ii Y O « pp 10 fO IC V O O V y :C «g C LY O I W 0 0 0 U) NY)6Ifr1< O h=?..,O N O) h 06)lay. LV-7. 2.f N O,.0 D c p M!W N N N N a N 6 1.0 c c Q Oy y 6� E `s V > "0,.7 vg"- N<OO6 00.1,0 IO a6 QON6n 6OMM 8 O Q d 6 L) N lJ O 5 . 7 �Ntf4� r6 NM a M^ANN 6^a,7,7 2026' bob b 1010 9 0. oyN77.YOV«•YFFY� Lt g T'7'1“p "72224 YYYY4 YY c OL !EE00 . 00 =Mm€92€ u qq po pp co U Ma d N;;�WHOf 2U' HZJ .Y E 000Tc60 N TCN00M 1.p r.1VpNN 8222,7 I=M8Y? 88:2;;8 MT00, Oro Z , N 0000)6 60,7„0) eit73 lyO 461 n6 ( 56.6 W rM 06 .446,6 NN M G 12 0 0 6 6 6 6 610 M N 8g.744, N N M a b b,7,7 0 6 0 ^ ' ^ '^^ b 6 N N 0 -,- N NNNNN NN W AO a am Z 6 .-m006n a6n 16.46,.- a06 NA 0 180•N10OMt`O) gooNp00 Nab0c00mo nn 0 Ob... V17^N 60NAc� OOiMej. V.4074 N. Oi OaNej OOdO 00 '?""401,1 O C C 6 0 b N N 6 N O 6 6 0 0 6 M r,7 r N ,7 r 0 M ,7,7 a b 0 b r M01.....0*- TOO^ N r M^a 'b 0,7,7 0.001- ^N M M' .4-u, N '_ IL r ^ ,*-*-NN N N N N N NN W UM= N N j 0 M o ._ ' 4 O..„ 00-0 00000 000°0 00000 00000 00000 00000 0 0 2- O N 000 0 00000 OOOOO 00000 00000 0 0 0 0 0 0.0.00c, 0 0 0 .02 c H 0� ,. 66606 .0 0 0 0 .0 . . . E ..h b b y) N y 0 N 0000 60.06 0000 I O I A N 2 ;;;"6:2 Q M ti'4^ 0 = N V N . N - :23.7R ^(0 00) 0 0 0 00000 000.0 .N000 O 0 N 0 C C C C O O N N N M N N N 0 0 00 C 0. ‘-'',S.-'?,,°.1g; 0 O 7.2-. 00000 -**• 0000. 0)0 0)b b 0)ION N. N 0 6 0 00000 M a s a 2 •, 00 00 NE 01 0 N y r O o 000.- i .n r OiO� 0,6 Oi NN .-000, ,..:.^6^ b MOO p OO N O C 9 R o^ W N M , te O ^ ..... N N N N N N ^^ Z.,, I`oaa 1a --nN o 0 m w Z Z o Z e a 6 a Y Q N N Y N 6 1?a n(0 O 00)i O W Z 0 0 0 J N Q v Z 2 Z C C 2E88888 88888 88828 06080 88888 20088 0007N 88 0 0 0 0 0 p O O O o.O O f O N O 00 00 O O cG K O O G% O O O<of 000 0000 v00)00100 000 M O O M O e-O 2o-Nn 000 b O h O W N M C b,7 r 0 6 O N M M a'b 0 r c D O)6 6 O^N N O u0)0)b 1 C,7 w N N N N N N N N N NN 0 ¢41 N O Is= O o 0 u K C p)Y d IO csi p g li O yJ C 8 ' U_ N E«_ c 0 w N �, « �c7 v ao C =� @apa c•a°° ccc � » E m� 8 M �° p� c im9To g= CS C C E22 6 v E w a q ? • N c ,o� d d > o > >0 0 0 o U c o r O'3 > 6 M O K U IL 0 m 0 6 1-U J J U U' U 7 YID 0) N 0• 0) 0 N ❑ W, Q N O N 0= 01 . . ^ N 0, MOMN NNN N ..... N NNN N ..... N... MN Cm . MMmWo %% .M..0mm2%m mmOmm M. m h Y1 r 1216 . 6 2 N Yjh I..... ..... ..... ..... .. . Y0 m n N A AAn nI, N N l` N I N l l N N r C.l N N I N r A 0- , N , rrrrr C.rnnn ^C NN, NN,N . NNNNN nn N h N N IO ION% 0)Y)%ION h•h 0I. Of YI.h h hYI.YI. N N Q 0 M N NN NNN N N NNN N N NNN N N NNN N N NNN N N C N N N N NNN N N NNN N ..... N NNN N N NNN N N N 1- L n Cn M MMMh 6maro CMC6a CC0066 6Ca6 ar n Nt,., N nnnNr NnrNr NANNI NN NN NNNN ` . . .NNN. M.... ... ..... M.•q .. Y .. ..... . N 0 00 00000 2 0 0 0 0 p Opp O p p b p N 00 0 m 00000 m m m m m m(O m m m m OEA O A N2W22 22222 A22. 22m22 22222 2222 2 2 m 2 0 22 NC a6 06 m aoioaoaoao adaom romaiaiao ttittiaoadIo uoco. o mm C .4 a 0( X W ii W N C O M M M MC1,1MM 'OMMMM N'm.lm'l.M ,,�m)'Cm1M in M MNM tm+iM 8 s a v V '6'6'6'6'6 V V V a V V V V V R O V V V V V V V V V V Ek c u 1 m^ o 0 0 00000 00000 00000 0$000 $0000 00 Og 0 0 0 00000 O p o p o 0 0 0 0 0 00000 000)06e 00000 O O O p 0 cid aa a a a a Z L i %mmmmm ! aaaaaa c4zzzzz li-_ 2 N N N N N N d f- Iq .6 lo I.fINNI.. ..22 ... ..... ...Y.. Y..... . O 0(0(00)00 XN N .- . .6IO N 00 00 00 .00 00.. ...YI OI .00 00. YI N•.. L a - m .... •m. d m aaaaaa ., dddddd w.. Zo N N N N N. N 0)000000 ', O O o ..... 0 0 0 0 0 0.00. 0 0 0 o o 000.00 a. 03 m (0M OIG m 0000 06000 D 0660606. 060100060! 0606000100 OO m a N N N 040.00 0101000 00000 000010 000001 0404 V Z O N _ ( N M MMMMM MMMMM CIMMCIM MMMMM MCIMMM 00 . N N N N NNN N N NNN N N NNN N N NNN N N Nt�NN N N N 'O N m . m ..... O'.MMm .0... (..... (MOO M(MO. W. .Mr d T 4 T /T/IT 4TTTT 44444 44444 44 4T TT -m— N roN >, y o o -p 'mm C O m N pj.t:. N N N NNNNN NNNNN NNNNN NNNNN NNNNN NN E4. 2.(-2 2 0. . m (Mo . ..... ,i2MMM (Mo.(Ov. IMOIMO.(Mom oIMO.(�olo .g c d� +� co T 4 T TTTTT 4T 44444 44444 44444 TT bCr T E Kmm.100ml .w o^ 2 p ro mmmmm 22 mm2 2%022 2222R Opo�hN 2� ml z y . 4 N aaa44 8 4 0 0 4 V 4 opo U j 4 000 Y 1 q O p V 4,5 J N . 00,-NM Dmf V 100(Non ft.... 00000 O mo 00 N NN y N N N NMMMM MMMMM MMMMM Mal.V pp p V V p V V V 2 m^ 2 0 00 ..... O%m2m O m 0 0% 0 0 2 0 0 000.. M O WW 000000 OW.. , m r ,,,,A p nrrr m Alp N V.,.,- ...Dv, O t0 0 0 0 0 00 N ,rNAAQrNO � .Onm 000OA % r a GGOOCC N Ar . OYA O0)602., r W N A .00,-N ..V.0 N C-mm m as 2 pp 22020 N D 000000 N N N N N M M M ..... MMMMM ...vv. p p V p V VV 0 W 2 3 w I , L O p 0 0 0000 O 000 Ooo 0p 0 o OO V O 000000) Z W 0 0 00000 00000 00000 00022 220$0 0o f -Oo00oo P.. ' Y0 IN .....OIGIGIG ..IOIOIO ymY0Y1. ..Y0.Y0 .00.00. z OOOOON V% E ' ^ ..... YI...YI b 0)0).00 YI Iry IO•YI. I.. O V NOVO.O 4 6m.. ~z O O V O M m V 4 N N V V y OI f ❑ UJ CI 1L J .w i.e. 0 0 0 00000 20000 00000 00000 00000 00 o E '-o 00000 a O o 0 0 0 0 0 o o o o o p o p p 0 0 0 0 0 0 0 u, 0 2 0 00000 00000 00000 00000 00000 o > c Z LL 0'60000 V _m 4 N 2 VN 000 1100 0. M a 3 4. 0 0.) <. • 1:1C o 0 00000 0000 ,-p,-,-o .,_,_ ,,,-,p o,_ yi 2..,. O .0000 NON-NO .V 0 V M I^.. ON " 0i O OOOOC OOOC0 .Oj00 60YY 0 NYO ON m0 , 0 00000 .0000 oMmO NO,-p - n `0) MMNm . 0••NMV pm0050) ....0 00a , INN MMMMM MMMMM MMMMV ppVpp ppVpV VV 0 O 0 0 O l. 0) E a° E N e N d Q ❑ W. U s m l0 a y I- m n ° c 0 C U > V F E m G M p C 1. w a O m E >.>, ° e o gm yh II y > > 0 �M , . 22 22 00 00 0 o m 0M 3 o 0 a" NgO.-ev Of r 4,b bib doMo roN'bp �'d'^"' m d C iT b M N 0 Q .N t O 2 V 4,M b r M r b M p O t O Q b O N r 2 N p O 2 c F 00Nr:ry h ,- Nd d gNriry r:vatiacr� OirtjMN a4,-,a4 W 8NbQ2 rZ-. 0 OrO00 Of M MM'Orb ,..-.:favo--, bgbwf q a W 'b b 22 r rr 2 r r b b bb 0,00) Q N OOO 00000 O M)0 U)U)Y) 000 h 0 .... ) N 0 Y)Y)0 00 11)N to 00 U)N 0 b 0 t4 N b 0 Q N O C N Npgabpb 222 ;1.. 2 22 222 ;R28% 42;28 8822282'424 N O t L Ohh-M10 hl�h ri2 n Ogo4,g.0 ;0MNdM r4,MMrh g 0ati1)r<aC Ngg do O N M OM N.iM oM M to 7 M^MNN 2MNMN NNMMM Qf MVM 0 t2M M 2 c,) OZ 00000 t 00 0 Ot000 00000 N 0tO t1)try 00000 N 0000 0 N OOOOO OOOpb bObOO OOOOp OOOOO OOpoo OOpOO O O g Ci rmq,.. Obf b W W MM ....41.0 O,..0 M W MOM N.M W. O b NUM.- 0M 0 U 0 Or 0OO O GOON Q NM 2 r8 O d Q gM to N L Rig=i-i btT' ^ N NO d d f f ggg :.':1°.',14; rim�NtO r,70.4O b L N N N�- N M M M MMM M 0 0 8 b b b r 2 r b O q u x W 0 t p i K C W N C C ' 844 N 0 b('AA r2220 '*O�w �'' NN 80N0N O $O 66. fYf '0 Q <ffYf 4444,i 4a.ui Yia2Ori 000i 0 q O w J O O O O O 88888 88888 SOOOp .”8.8.2 OOOOO 88.888 O C 011'1 N h N N O O NN,- NOO NNyi w w..,i of N yi N yi o...66. n i9 LL i 000z // 2 2 0 0 N Owomw bCK2ct KKKaCct ctmctwk Ixw EtmK 0 1-- ==,n, S = Z SS222 m8;-.$0) rrbdbr N,88 Nr)22M S 0 H MMNN 2288 NNNNN; NN0 Q 66°6 6 6 a NN z 6 _ J J N EE g N 3 2 .8 O > W e O g1W, g2:13. O' O OOO,N0) 2;r44.% O)-n... 0 Nt0) *y NN NN t1) M Z pp ty h N b 0 r h r f M b 0 to O h N'0 tV 1)i N 1)i 0 t1) 0 0 ap 0 0 r E ii 6 t0 =0.0. �p M N L e N 0100140 NNN q bMgdd Yt ' rt'%iM � YY4'?v) •99,9 ?Ra °l N aC O pOE O d g O O O O r a 0 p c� to O r = ' v 0 0 0 4,4 6 Ybr)' 4,1 2 R O > Z O O K N b a as l-0 N > ' "i- 1:-J.°2;7,2 NOd t2O 2 242 2:: 22222 42.O8 24848 b0.N r. m N NOONto CO r NtyOtONN t-00triN f OONOi yirtprt.. r.iviap t0� to 9 .y 9 2 1— v'T 044 YYT 4 Y '4IY4Y /I/'?"b? MM'701,.1 t"'yry.2_'7' v ' r' a `' a C• El .61— N a gE' Esgtc c mt c c 8 a W.s Y o 0 0 b. U O N a to 4 U bb.�M d0 N ONNM ON��q MbMO b0._ � m Q1 �0 5a..�' ,m tt�o G O O D u 2 t 0 O O C E m K W h2N08 NOa 124 r 2f tOb; ap Mob dO�hOp 0:4,NN NONr)r Q J... 2 2 2 ay0 q o 0 g Wg V N YjOONh Ci triad a O_I:auiN <tO.-Noi hraG�tl) t'i10N C. g O y ObNiO, yo._a.aY ts . 1) > 4"x'44 TYT 4 Y 444YY TYY"oP5 MM�Ntdy '" ''.. .-, U C C aw scc cc 9 c �u U U Y_ C. a !EfO022u- 2128 -p wtapt " 2 /0 rLoF. el et ♦+ pp ppp 2:':22 Z rn E p t O p t()O r.-a N O a D 0 0 0 r alp N Q O o O p N t O 8 0 N 24,8R2 0 b.. n Q V nhMap 000 O�d'aG .rQl os 810010.: :! : MU : :! dN NabbbMMto M MMMMMMrtngmm°M)t.. O H hhhhh NNN N N NNNNN NNeacni NtObo.= IVMONtd bb :: b N n r_ 8 b b b b 8 4,g q O',-,4 p O p O p M M 0 � d N� yE N N N N N N NNN N N NNN N N N N M M MMM M M M M M Q COes , o t-' N , 0 .Y3W O . ..-6- . W N= N p f 0 d.L "" QQe-NO 000 4, OOOrr r-Mh OrNMM gNrM 0-800 O N- D. r O O -�+ 0NeNM 000 p O OOOrr rr7 .N r 7002 0Igbb.� 70,0,0) O E (0 h lh A YUWi r 0 'P Oat 666,6 ON, N NNNMM 'MMB �tO0.46 OiM if Oi W V.W. W 60 ,; EE a 0* W N t0 0 MM M dd000 ...W. br2r W . ' 0,f f 5 d d n t'n M o O w d u Z 2 Z E gam a:u d ydEl $opo-, m m o 0 �W Z N N N�N�W Z ZZ o GS ,OoNO 000 N O OOOYO 8288; 00008 88282 88888 N N606 O 0 00000 OrOO66666 NON0'0 0 0'0 0 0 80 0004,0 ObOON 00N 80204, OOQOO 2e ,88 NNNNN .9;222 MMIOM MqOp p'0QNN 44400, br OCW 15= w R _O O kc mY 2 .. N we W m J 3 g I4- a y N N SCK: p LL U' O m F-- 1 m U m' — ..iP.3 1) V 2 .. r. m 2 a0 u o aa t r awCav m U z . ca a m ¢r o ° Kco > vZ LU LL m M bUJJ 0 0 >>rn O C 0 0000 Y W 0 N Z Z Z Z W Q V- . 0 a more, N 0MOn� . nroMn. ONO O.-NWMONM aa ,NO. p N...WQO Cy .. O, ....N Mo , ...On-. f,f .anmW . . .- VV... ). 60, ^aqO4,^ nMMOA 0a00fA,NfN faQT 0f1.ff 6.4:64OM 6.66.i 666 66r.:66 6m N , e. Q 0N O ., ..,^ NN...M ..-,AM 0.01 M.N. y.v,- fnO OM... .M dq W . 0a000 000. 00A0MM..WpM.fAAm 0 . AmO..0Q O 0 0000 00MOW mmm . mm ..C .CD ....co moo Uio Ua .. ..... U. UU ..... .0 . UUOp 00000, 0 ) COYy ) UU) ) NIOy ..y0 ) Uy . UOY (p y Q N O CA= = , *• f0.-:Nh. my^NM ^y•-0 O OCOf O 1Of Ot0M ON., N.,A O0m^^ ^ h1^N 7 UO O C m WO my0.0 fmD ^0.MN N0MA^ a...v. o.0., 0OOy01 .,^. N0...1.7 .... ) O. 2 My . , 0 mmmqro 6.-N.- mATG ^TMN^ IADO Tr O . VmN . Cm N , NWO0.. 00 �qM **ON 0 Nfm.^ ...AN fW.N. W . OON . W . 0,..0 MA Z CD 00 ^ NOONMOVVO OV00A ,..M O nNN N.NNyOe0V . p, „ ,. . 1NNNONNNNNNy.MNMM NMMMf .1-1-1,7,2 f 30 0 yy ) y0y 0 N 0 o 00 0 0000 00000 e000 00000 00000 00000 00000 0000 00000 00000 OOo00 .0 WM .. mmOOO CO m m m m CO m m m (0(0(0(0 m ..... mmmmm ..... mOOm ..... CO m m m ..... 1p m O M 0 . . M. MM... .m A g N m m m, O N N N N P N m V A A AAA, ..... .... ^m y 0 0 00000 A y.y .16 C .... y .. ....y 0.,.. M.60� 10....{{p mmyAO 00000 0,,, AAAA ^ 61ftppQ f f,f,a ay,^^^ C Q CMO CMD ON OOb W O NMMMp Oro W COO COOmmOmm COOm NCOOCOD 22222 22222 CMD CD CMOM2 a2ON C2D CD2 22222 OOOOM 0^; O 0 i (C W at OSi .i Gp X C W N 1'1 '44' 2:4 Mmmm6 O(A A O 0,^f f A„,AO N c1,22 O 0. 2;222 ^My. O! ..^ M Q m y 666-28 ,.m m . N f^' y y^m 6m q N oCp 14 .6,,iN6yhN 6 .666 NNNN yyU .N 6yy6y YyNNb h6NN0 0600 00666 00000 66600 W. ii 53 N J g O p O O O 88888 N N N N N N O N N 88888 0 0 0.. 88888 .2200 O O O O 22228 OOOOO N..O O p O O O O O 0 00 00000 ..M,.7 MOMM 0)0)666 60C)N0i 00066 NNNOO 0000 NN..jN O. 00000 NNNOO 00 1--”' I I I= =II:n f f N g N 2 0 N fm .Z S I I I w N N I I S S S N N N Z=Z. ..M S= S SSS N m N Z S Z X Z (D 6 ,A m m. m `-`-MMM A ,f Q y 0 d . T UU O)T CD y. T 4.-.- W TT C 6.. ^ .-O N N N N N N .^,, Y y y Z O N N ..r , q O. 'Ne.,f 0.-... .,^. .V.-V, ON.M, N..NN ..VO, .00m 00m ,O f N 70NMN Ymm . W. Om 7fN^y ...A. 0.00.0. •- myf fM.y^ VN.A. ^yfMO Wo.C. MQv.N 0.0.^ mfNO mm ZW0pppAUw ...0ONM7OfONg=NNUO. ,.O . NNq. M0. ...MOM N^N. . Nmm , O,0. „ CDV.O.N.NW . ... 00,...... ,QV .. .0 000^^ ^ 7MM MMMT V..y0 NN MQVV ..... '1"1“”1"I' m„m mmm.. 00Pp! . t . . . 1 . . . . . . . . . . . . . . . .2 .74 . .".1NNN N N N NN '1''1' {?1r N V Z .”" M O .,,NV 00,0". V.mm ...OM NN .N.0, V M m,m O.-N. WM...., a V M^ NN. 0. N Z y N y Mm f^ny OV... NA f f CDMA N, NI)n f M .m N.^ 0..70 y 1-.6.. N.NM ,M0y, M q. 0 K rtV W f w W., U)Nf 0)ei CO,TIZ ♦.T 666x6 604.3-66 *0-NTC NmM6 hA NA 666^T no.,f m ust..: N NN N........) VV...oO W.. A,,.. .0000 .-NN.')..7 f f f e.00 ..,, ^^$ N f^mmN ,-ANN O f iii ^^^^ ..... ..... m,.- ..... .m m .0 W N N N N N N N M N C N N . M ^ ^ 0 W L N M MO N,.NQ Of,mMm 464 4 mmmmM NPPNN 1Nm0, fMm,m OmNm mMmyM hffM^ 'N.^Oq� IT . MI` ,N 0OpM `NfTO, Dr. m m 6 6 66666 CNV66 vn6m6 N try6 W YN ON. ..N MO.., .c..m Oy ANNfA myyp GoNm Oy,f0 m^yA MOAfm ymm MAO, , q^N V" Mf Of L ^ NN NMMMM ffyy. mmmm AAm. .0000 ^" M "^ mmA� , mn m...' NN NM ^ ' - " ' ' .-..-.-NN NNNNN N ) YZ ▪. ON ,N .1 ...pp UQC .Oa7OOOO .-C)m rNOOm0OCNNLD00N..7 VOOODm ND ^ 0f q m ) A000N . . .V 66M.-. saM *. NmNmmNNUNNN0p,0 . Mmacom -yO 04 a .OCO N7. fQ0 40 MMMMoMM0UoMMMMMMMMMMMMMMMMMMMMMMMMMMP.q.q MM... 1111. p CM. )M0MMMMMMM MMM MMMMM MM . O N. m 0 0.m ...60 mfy 0.......- O,O M, ...00 .O V..m No.,- O.O O m 0 .^N M m ..... 0f m V O^ q M m.. mO...N VMM., .mm. 00,0. 0 fM0^N MOA.O Mf00M 0.,mm ...M. mM.y^ 0m _ 0 . .0 T.,0 ^.-646 TTTC OD,tON VMOVV ffffN 6 r:ft6 r6.,6 66,6o,6 6444 440046 66 m m mq . .. O..q mmmm m,,,, ,,,,, ,,,,, , ,,m m... .. .q .... M MMM. q m M00., mMM .. ...MMOmmmmmm0mmmmmmm mmmm mmmmm pm, , ..M.. .0,, . . . ...M. 7777 77m77 mMM 7. ,M. mMM M MMMM MM 2e O 888 88888 0000 a y^g1�m M ,rO nmm M M O m O f m m,mm, M n^A, A 646, M M M N N nt N N, N„MMM A PP f r4 ..j hN MM..jM ) MNrqCDODn CUnNn NHNNH yNNNn 66666 hhOH 46Ny646 66 666 66666 466 T1 ; MM MMMMM MMM,, MMM. MMMMM ..MMM MMMMM MMMM M MMMM MMM...) MMMMM MMMMM ,m 4 OOO00000 V c4NNaaOa wyffMOUAaaUOow. pp pp ....,NN NNNNN ♦ .M .0v 0f ,, w00 OO00 .. .,.. , .. IO 0 , N ,K A,K„ m^f ei 6 0 my M 0000 OO... T.T.. . f`r , ,-.:r: 0..0)00 00000 6.666 6. m m m m m mmm m m..q q MM.. MM... ..mmm m mmm m m mmm m m m m m m m m.. ..... ...M. q. fOg O p0.00. N V O N000.. 0 0 m0 0 N0.000 N 0 0 000.00 N n . 00000 0 0 0 0 0 00 00 0 000.,-, M . 0000. 0 0 0 0..0 0 O,, O00 .. N ^ O O Otp O,-Y)C.- OOO. D TNOO 6.-666 66r.:66 CCCCT NONOO O.p66 ON.-^N OOOON 66666 N. 0 , 6. ...Nov OOOOm mAOm 0,000 OMmON 0000. 0y00 0.0V O O N.A 00000 O^N O O v0 V Q V Q ..mo. U)U))U))i.M)VM) .O.ONN ...no, tU)U)N U,NMOO (0000.000 0mm0000 CDDb.000 rNnN-N ANAs N. N-n n nn Nm n, 0 0 0 6 N e. U 0 o to 0 O _ N M 0 f O `0 y 7.. a o. .. . n n - 0 U n r)° N )?n Z N 2 o f 2 0 Z n ,� 1—1.. 4 �z n m E E k L� it .+) N1� 0Mi Z 0 M? 0 N Z 0 H N ZN0N ni o-0 0- O y Q ..).¢ Z ¢¢ C Z C Z_ 2 Q Z 1 Q Q Z Q C 0 0) 0 WO 0 00 WO . W UW W 0 (0 W 0 0 COW0 0 (n W O 0 • V 0 M 0= r00 0.00- mm.MO MrOW. WNQOO VV... OWNa0 rWM.W ONOmNNAMW0NrMmNmm 0 S raN AWN. AmmNO 0,(1.0 QOA0Q00EDOm .0 NM. 0 ONmMOmrpNMAmvMmNNmQ0mOMOm WMOM NWOAOMAmmWNOONN� OrNN� qr0 )m "TN. WWNWNW0Bn rm � 101Onn0WYmO 24°444 G ONO 0 0D0000 rrrn nAnn, A r NNNNA Am0mm SSgS 000000000000p00000 a OOO 0000 OOOOO00000OOo0o OOOOO 00000 00000 O 0oo m u)m u) Q N O 0^ .-MN O O m r m M N A 0 M A r.A M V m 0 m O N Q m m O N A V N M m 0 0 0.00V Q N O r m m O M N N O A m m Q .-,..J. O C QMm Oman mrrmM OMMNN mmOmQmmAmN0QmN mMMm0 mmrAM MMMAm rmQOm 00N°0 -mM r V �m mNNMNNN0NNANOv�ON4 OMO GO "MMOv0v °NmArnMAM0'm nOMVNN . p� OmDNDOOQN Q r N Q �a .. O00gNNO Q tmmA mmmmm MOOrr NNN rQQ mm mmEf10p mpNN 0p0p0 p NNNNNNNNNNNNNNNNNNNNNNN0. mm NN 000mN 000 O00 00000 000 00000 00000 00000 00000 00000 00000 00000 000.00 OOO m m m m m m m m m m m m m m m m m 00)00(0 m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m 000.0 mmm M O=r N N^ m m m m D Om M M A AAAhmAm A N NmN M MMMMM Mmm Q Q Q ..... QQQr A AAA A ,,-. .-N r mmm A 0 0 0 S N N Orr mm mArNNNNNNQQ QQQQQNMM. MMMMm00000 00mrr rrrrr NrM1. 0 N4 Ammmm mmmmm %%t--, K LF , mt=mAtttm mmttt tmmOW mmtmtimr Am ,.m :gtt6m mmm c S a 0 K W ia c gC W N a O )E r NM mm MM O r NMQ1e) m mAm W moNM V O'f<Q O YNN o mmh W V ..0 00 N W 000 N m(O0100 WV.m C O NNN N N N N N N N M M M M M M M M M M M O Q Q Q � c mmm (TM mmmmm mmmmlc mmmmm mmmmm mmmmm mmmmm mmmmm mmmmm mmmmm mmmlcm mmm gk o f IEc m^ 000 0000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 000 J g RR. 0)1000 000010 .0000 000.10 00000 0..00 00000) .0000 00.00 00000 ...00000 0E 0 0 0 N N O O 0000401 N 0 0 0 0 O 0 N N lV 66666 O N N O O 000004 040000 00)11010 00000 N N N OO OO 666 W e' m J J C'm m m C V K¢K t/ tit 1000 N-N-)-Nm NNNNN -.,000 N t t1'-, m mmmm O W 000 NNNN-, MW N mm 000 "' Z r r N Z Z Z Z Z N N M Z Z Z Z= iv... Z Z Z Z Z m..Z Z Z ...mm N ZZZZZ Z m Z Z Z Z Z Z o, N N Z=Z .. Z (O m m m r r m m m m r r r ^ o o d rrr r Z O N U) E i t3ONO 00,0 O, NNN W.- O M�OQ)0Q0 N W mMeN- YMN7O Am W NN m r«N NAOQA 0M W ry rr a OD Nm CO.QeQ-vNa Am N NM M — ED m EDA m O A 06,4 m 01n01Ef mvam a .aav Oi 4OmED N aO �p .4., o.i.. Dr 0)mQ EDttjm Nmm Z m m r—MOM m O A r m{p M r m,O r 0.000 00v0/0 A M r Q r V A m O N m A Q 0.000, A Q N m V ♦A O N Q M A O� rrr 0000 VV...1 .00N. m m m m M O r r N N N M M Q V.000 A A A m M 00000 N M MV.I.. cow, '7'7"1 '7'7" 1 `,'",)`?'7'? 'i'?'?"?.? '7t7 , ")4444 /4444 444 /TM m n1n171n u)v)1n"? 4 .71;1? hmv) N c Z p 0= 000 MmQ WQ QO OmrAONmOWN Ar.OQ MNAmm 'mmQm mmmOM WmNm MmMmN NAmN OM ZLQQO mmQm mmMr NNMMQ VONO 0)remm OQAQ mmr0 MNMAQ ' Om mMrmQ mmmOM OAM 04.- MN N M .r.r O NQtV m NA Gr toarA MM 4rtpZ4.r N ODA O C OOi..- .^4EDN W46.. N-p.-.-fp A Q (n AM Om.M OAr Qm MN010' MQNNN NM V Y W YVt m MOON V Omm V N.M.. .NNNN Mo V to m 00f 0000100 rtoro O NNN mm AAmmm NMm N N N N N N N N NNN N N N M M ..... MMMMM M MMM M M MMM M ...VV Q a Q Q Q a Q Q Q Q Q Q Q Q Q Q Q Q C N M )T a Ot U) WV ma a++ N mo.-,w 0.000 NVNNO MmamNtOVWMr0YNMNMZQO mO .. . M100 Nn .- 0ON0O mQr MNNt NCAOA ONaaN NNA.N- NNMm 40rNrO OQ t- OraMN COCN Ore- pr 60mAM ommM OArQm MNMfDN QOMA QOAM vmOA O000 NMMOM MNMmm WMmN6 NNMm .m0 t QQQ Nmmm „ ..o. mMMO NNN NMOQm mm mmmM MMMO NNNN QYm ammm NNW NNNN NNNNN NNNMr MMMMM MMMMM MMMMM MMMMM MMMQQ VVVVVVVVQQ QQQV = Y_ Z OZ Vr0 ow.-v- mt.00MN W.V.V.' VN1°NV YNrgW ArN0. mmrNM 1000m100V t WT-NN NNNNv VWMOM .NN p a 1O M m N m Q V 0) 1OOMN N rr 00 000OS OOmtM mm W 0A W ON)MS m 0)0)000 Nto t00m 0000)mm GOO..N NN N0N 0mm 0 0 0 0 0 0 0 MMMMM m 0 0 0 M M m m m m mmmmm mmmmm mmmmm mmmmm mmmmm mmmmm mmmm m M M M M M M M MMM M M MMM M M MMM M MM... M MMM M MM... MMMMM M MMM M ... m m A m 0.•-V m M m r m O O A V Or..0. N ANA M m o m 10 M M1p Q m O Q m A M r00.0 r N N M p 0.000 m N A m M O m ...'N r N m N r N Q M M A M M r O m A m O 7 m N m A O Q N Q MAm M N N O m m 7..7...t p G p M�r N N m V7' j M m m M.-64 m ow... ...a am. v v v v a a a a"m)m M W M M M N N N r r °D A m M r 0 0 0 0 0 r:.... 00000 0 0 0.0 M M M MMM mmVm mmmmm mmmm, OVmmm ttmmmm MMttmm MMttmm mmmmo ....co mmmmm WWW.. MMM gr- mmv rm.. M M M) ..... r r r r r M O M M MMM M .0000 0000,- 00000 00--- ..... O Orr r r r r r N N m N o A A m M r m O Q Q Q Q V Q Q Iv ... .... ..... 0(000(6 6666.- E MMM .M M M MMMMM MMMMM MMMMM ..... MMMMM MMMMM MMMMM MMMMM MMMMM M M.V M M ... a y i MMm ---- ----0 0) O 0 mmmmm m m N O m 00000 m0MMM ....0 7 7 M O ..... m m m m m m m m m ..... m m m M M m m m 0MMm )AAAAAAO ^ r0Am mmmmm mmrrr ro N,4,,!,4 NNONN ,..,'“',N QMvQQ QvQ 00r Nm66 M66NN me-000 00000 OrNNN NNNN OO 00000 orNNN NNN MMM mmm mmmmm Mmmm mmmmm mmmmm mmmmm MMmmm mmmmm mmmmm MMmmm mmmmm Mm mO 0 0000. 0 0 00000 0 0 00 . 0 0 0 .- 0 00 0m00 00Mr 00 O00Ar 00000 00 00. 00000 OM Oo00AOm00 00 OAO .- 0OSNSN000000M0, 0000O000VVN00OVmm00000N " 00bO00000000 O0Q0000 00 p 0 MMO OOrN MVV.. WmAm. MMOOO NMQm mmmmA 0m000 OrNMy 0Nm0. Am000 OrrrN " 'm NNW mmmm mmmmm WWW. mmMMM MMMMM MMmMm mMOOO OOOO 00 OOOrr r rr p O 0 N N w N • m U •• m r 0 G'' 0CO Omr O0 Or. O r O E enU cn N Q 0 a N Q0 tmVitO ee4v 0 NQV emi Q 0� g. E `” `z. Z v z. z v Z v Z. Z v° _ O Z 1 C Z 1 Z 1 Z 1 C Z Z C Z 1 C m U U m w 0 m W Z 0 m W ()cow U m W U N W 0 co W 2 D v 0 a 0M .-mN .- a.NMas 0 . raCMM WOO) W N M.-O0 O A 0.-0 M N O A M N N d AA AA mma M NN 000) N.-000m �p} 000 0000 0 0 0 000000 0000 . Q N 0 W^ a 0M MMM M M00.0(0 m WON 0 O C M m M Mm.-AM Oi am Om Aa Om L c o h Y O t V 1:M M MON a O N.-A M 0 v M N aa.-Aa 0m m0A 0OAM W N Z OQD OMD amomM W amort gamDamo MM ap00i MCDMM O Om m m m m ‘4510.M.0 mmmmm N O 00000 OOOOO 00000 OW mmmmm mmmmm mmmmm 0 00 N 4^O N m m m m m W W M m m m m m m m Cp Q�m mod aaaaa aaaMM MMMMM N m M m m m m m m m m m m m m m m m 0C 0 t x W C C O g .�G x1 W N 4 x m m m m A m M 000.-.- .-N M a m C • m m m O m 0 r A A r A r A A 4.100 NNMMM MMMNN NNMMM Ek ift 0 G 00. 00 00000 00000 00000 J Z0. .0000 O O m m 0 0 00 0 00 00000 O ao 0 <46666t.i OOOO66 .600NN0 O.a a as r.r A m m W m m 4 4 LL f as 0.0.0.��-�- • a a a a a a a O Z Z Z Z Z Z Z W 66668666 - N N N N N N N N H 4^. NN mmmmm 000 (0000 0 00000000 000 ap04 5==X= MN.-MM 22 SS L CO a,r- nn mm m m mzzz _ a 0 R dad 06 d d d' m aaaa a N N zzzzz`J`-- Z 86666"" L,,,,,., d 00000 N (00000 W s^. 'm v A M M A m O m M M m N O v L M NMN m M O m r M m O M r M M O N m .-6.-Mr: N MMM M Z W N ::::: O Am ww Z�^. Ma Oa aNO: V OtNm O Mm (0 0.0 .-NW m.- W MMM Q .-‘0*.-t0 -0500 m M O N N N N ♦Mm m M M M $ a s V M a O W m MM... M m m m m -O m.- C N N N W Z0(00tO O M a 8^ Ma OOOOm Om6NM 4Nr NO .• p,0 0 0 < CO m L O.- MOW.-, MM V M M .-cow.-to O N.-tC F O 0 no ..,‘Now.- m M Q W a.-m 1 L W M O N N N N M W m O 6.1 Q (fi VV vaa W O .40... v"'.... O �re a Ci + F 20 s m appt 6 E. mm imI 'mimI'mi Z N(0-IM CO N CO m j mo! onowM NM tmN.+ m.- NMMam j N h 0 0 MMMM( M(0 0 M 0 M 0 N N m M M M MMM M M MMM M M M M M M E E M OpM m m.-m .ANN m MOW.. m C 0 0 0 0 0 0 W o A.- A W.a N .-N N N O .-N N M m m E -000.0.000 O 66 Q Q M N.- O M M 6 W M n M N V M 0000000000000000000 0 0 0 0 0 W WWWW mAAAA AAAAA A LL WW MA M M A r A A A r A AAAA N 0 0 0 0 0 0 0 0 0 M 0 M M 00000 00000 OW f 0 D a W MD • Of .-01 M MMM M 0)00.-.- V 0 0 0 0 0 0 m 0 W Z W W 00000 00-. - '^^'' F -0 0 0 0 0.O r am*, I- * 0o00oOOn E MM MMMM M MMMM M ;;;;.;1g;; O a00EQG a.o466 0.-Q o ZZ o m O a m M r m VV. a 6N N N a m' W-F M 9W'',_▪0. W-1-e y s M Oy, m m O M M M M M M i E O O O O O m m 000 0 c" M �Nm MM 10. 0000 CO. OOOO OOOOO to 0000000ggj LL OOOaaVm JN 1 a D mNNN WJJ Q aa WW ✓oece ♦♦ /01.1.1.1. z N 0 0 0 fC Wm (00000 OOOWO 0000. ��J M.- t..0000 OA0).-0 0000(0L m NN 0 M00O0 Ar m0C 00000 ' F .0000.- MVM. ..... N NNNN N NNNN 0 a 0 O 0 o_ N a C 01 o E o ' as 0. 0_ O Oen a O G o M ( 1 CO. O H W d € n i- t ...7.11 t 0) E NZ 0 IVaV > > > - a Z a a U Um W 000 H N 04) J 0 Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out 8-1/2" Open Hole / 5-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out,backreaming S120-N4(P6)Anti-Collision Report en 0 Analysis Method: 3D Least Distance Distance Unit: ft Depth Interval: Every 100.00(ft)Measured Depth Azimuth Unit: deg Step-down Trajectory: Reference Trajectory TC Azimuth Reference: North Analysis Date-24hr Time: February 07,2012-18:37 North Reference: True Analysis Machine: DEC-AKA-980 Client Eni Petroleum Database I Project: bcalhostdrilling-nikaitchuq_2.5 Version I Patch: 2.5.1100.0 NOTE:Measured Depth is referenced to individual borehole elevation. ND.NS,EW are referenced to the reference trajectory's wellhead location and borehole elevation. A minimum of 0.300 m is always included for borehole diameters. All local minima indicated. Results filtered:Depth 4960.00 ft e=MD<=12574.00 ft,Ct-Ct separation<=1500.00 ft Anti-Collision Rules Used Rule Set Name D&M AntiCollision Standard S002 v5.1/5.2 Exemption Risk Level: Minor Rule Name Risk Level Rule Type Rule Label NoGo Rule SLB Alert Zone Threshold OSF=5.0 S002 v5.1/5.2 Alert Ratio OSF=5.00 SLB Minor Risk Threshold OSF=1.5 S002 05.1/5.2 Minor Ratio OSF=1.50 X SLB Major Risk Threshold OSF=1.0 S002 v5.1/5.2 Major Ratio OSF=1.00 SLB Surface Rule S002 05.1/5.2 Major CT_CT MAS=32.81(ft) SLB Alert Zone Threshold CICt<=15m S002 05.1/5.2 Alert CT_CT MAS=49.21(ft) Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S120-N4\S120-N4\S120-N4(P6) 2/7/2012 6:39 PM Page 1 of 34 Reference Trajectory Summary Field: Nikaitchuq Well: 5120-N4 Structure: Spy Island Borehole: S120-N4 Slot: SP20 Trajectory: 5120-N4(P8) Client: Eni Petroleum Type: Del Plan Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08940154' Grid Scale Factor: 0.999900152 Magnetic Declination: 20.178° Magnetic Declination Date: December 31,2012 Magnetic Model: BGGM 2011 Reference Point: Northing Easting Elevation Structure Unc.(isd) Slot Unc.11sdl 6053636.060(SUS) 511559.210(flUS) 54.100(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Pros: Description MD From(ft) MD To(ft) EOU Freq(ft) Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 41.000 1/100.000 SLB_GYRO-MWD-Depth Only-No Global 16.000 S120-N4PB1/S120-N4PB1(P1) 41.000 500.000 1/100.000 SLB GYRO-MWD-No Global 16.000 S120-N4PB 1/S120-N4PB1(P1) 500.000 2484.000 1/100.000 SLB_MWD+GMAG-No Global 16.000 S120-N4PB1/S120-N4PB1(P1) 2484.000 2660.000 1/100.000 SLBMWD-STD-No Global 12.250 S120-N4PB1/SI20-N4PB1(P1) 2660.000 4314.945 1/100.000 SLB_M_WD+GMAG-No Global 12.250 S120-N4/S120-N4(P6) 4314.945 12586.518 1/100.000 SLB_MWD+GMAG^^3-No Global 8.750 S120-N4/S120-N4(P6) Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI20-N4\SI20-N4\SI20-N4(P6) 2/7/2012 6:39 PM Page 2 of 34 Offset Trajectory Summary Offset Selection Criteria: Wellhead distance scan:Global within 53597.02 ft Offset Selection Criteria:Definitive Surveys -All Non-Def Surveys when no Def-Survey is set in a borehole Offset Selection Summary Wells Selected:20 Boreholes Selected:30 Definitive Surveys Selected:28 Non-Def Surveys Selected:2 Definitive Plans Seleded:0 Non-Def Plans Selected:0 Total Trajectories:30 None OSF Otter in detailed report TrajectoryBorehole Well Type SP18-N5 SP18-N5 SP18-N5 Def Survey SP18-N5PB1 SP18-N5PB1 SP18-N5 Def Survey SP23-N3 surveys SP23-N3 SP23-N3 Non-Def Survey SP23-N3PB1 surveys SP23N3PB1 SP23-N3 Non-Def Survey SP27-N1 SP27-N1 SP27-N1 Def Survey SD37-DSP1 5037-DSP1 5037-DSP1 Def Survey OP09-S1 OP09-S1 OP09-S1 Def Survey Kigun 1 Kigun 1 Tuvaaq ST 1 Def Survey Kigun 1 PB1 Kigun 1 P81 Tuvaaq ST 1 Def Survey Tuvaaq ST 1 Tuvaaq ST 1 Tuvaaq ST 1 Oaf Survey OP14-S3 OP14-S3 OP14-S3 Def Survey OP10.09 OP10-09 OP10-09 Det Survey Nikattchuq 4 Nikattchuq 4 Nikaitchuq 4 Def Survey OPO4-07 OPO4-07 OPO4-07 Def Survey OP12-01 OP12-01 OP12-01 Def Survey 0113-03 0113-03 0113-03 Oaf Survey OP08-04 OP08.04 OP08-04 Def Survey 0PO4-07PB1 0PO4-07P81 OPO4-07 Def Survey 0107-04 0107-04 0107-04 Oaf Survey 0111-01 0111-01 0111-01 Dei Survey Oliktok Point 1-2 Oliktok Point 1-2 Oliktok Point 1-2 Def Survey OP17-02 OP17-02 OP17-02 Def Survey OP17-02PB1 OP17-02PB1 OP17-02 Oaf Survey OP03-P05 OP03-P05 OP03-P05 Def Survey 0106.05 0108-05 0106.05 Def Survey 0108-05PB1 0106-O5PB1 0108-05 Det Survey OP05-08 OP05-06 OP05-08 Oat Survey Oliktok Point 1-2PB2 Oliktok Point I-2P132 Oliktok Point 1-2 Det Survey OP03-P05PB2 OP03-P05PB2 OP03-P05 Def Survey OP05-08PB2 OP05-06PB2 OP05-08 Def Survey Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S120-N4\S120-N4\S120-N4(P6) 2/7/2012 6:39 PM Page 3 of 34 Field: Nikaitchuq Well: SP98-N5 Structure: Spy Island Borehole: SP78-N5 Slot: SP78 Trajectory: SP78-N5 Client Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08958397 Grid Scale Factor: 0.999900152 Magnetic Declination: 20.842° Magnetic Declination Date: November 05,2011 Magnetic Model: BGGM 2011 Reference Point: Northing !tidbit( Elevation Structure Unc.11 sr!) Slot Unc.(1sd) 6053640 670(ftUS) 511582.790(ftUS) 53.870(ft)MSL 0.000(ft) 0.000(11) Trajectory Error Model-ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prop: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole/Survey 0.000 40.000 Act-Stns SLB_NSG+MSHOT-Depth Only-No Globe 16.000 SP18-N5PB1/SP18-N5PB1 40.000 40.770 Act-Stns SLB_NSG+MSHOT-Depth Only-No Globe 16.000 SP18-N5PB1/SP18-N5PB1 40.770 760.000 Act-Stns SLB_NSG+MSHOT-No Globe 18.000 SP18-N5PB1 I SP18-N5PB1 780.000 2612.350 Act-Stns SLB_MWD+GMAG-No Globe 16.000 SP18-N5PB1 I SP18-N5PB1 2612.350 2725.580 Ad-Stns SLB_MWD-INC_ONLVc10-No Globe 12.250 SP18-N5PB1/SP18-N5PB1 W 2725.580 3186.970 Act-Stns SLB_MD+GMAG-No Globe 12.250 SP18-N5PB1 I SP18-N5PB1 3188.970 7695.640 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP18-N5PB1 I SP18-N5PB1 7695.840 13539.910 Act-Stns SLB_MWD+GMAG-No Globe 8.750 SP18-N5/SP18-N5 13539.910 13601.000 Act-Stns SLB BLIND 2-No Globe 8.750 SP18-N5/SP18-N5 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (8) (6) (6) (ft) (5) (ft) (ft) (ft) C) (6) (ft) C) All local minima indicated. Results filtered:Depth 4960.00 ft<0 MD 0=12574.00 ft Results filtered:Ct-Ct separation r_1500.00 ft Results highlighted:Ct-Ct separation<-1320.00 ft 6400.00 3929.00 1345.90 -2082.75 7558.76 3960.28 2548.94 -1213.46 46.97 1484.58 1399.03 17.54 9.96 6500.00 3929.54 1417.53 -2152.53 7640.03 3962.04 2598.05 -1280.68 46.83 1487.92 1380.85 17.04 9.31 6600.00 3933.19 1489.07 -2222.30 7720.60 3983.72 2646.18 -1345.27 46.56 1452.25 1383.81 18.59 8.69 6700.00 3937.46 1560.58 -2292.07 7792.75 3964.66 2690.30 -1402.35 46.48 1438.26 1348.37 16.17 7.74 6800.00 3941.72 1632.10 -2361.83 7012.53 3966.00 2764.03 -1498.73 46.34 1424.87 1332.49 15.58 8.43 6900.00 3945.99 1703.82 -2431.60 8027.10 3970.43 2832.23 -1588.68 46.33 1408.86 1314.10 15.01 9.02 7000.00 3949.80 1775.16 -2501.37 8100.18 3974.81 2876.35 -1646.78 48.82 1394.12 1297.77 14.61 8.17 7100.00 3949.79 1846.75 -2571.19 8172.00 3977.19 2920.87 -1703.08 46.89 1381.34 1283.42 14.24 6.95 7200.00 3949.41 1018.34 -2841.00 8248.47 3978.78 2969.41 -1782.18 46.98 1370.39 1270.81 13.89 8.01 7300.00 3949.02 1989.94 -2710.82 8309.94 3979.84 3009.33 -1808.87 47.04 1361.48 1260.57 13.81 4.31 7400.00 3948.63 2061.53 -2780.63 8365.05 3980.05 3046.52 -1849.54 47.08 1355.78 1253.70 13.40 2.33 7500.00 3948.23 2133.12 -2850.45 8423.88 3979.48 3087.45 -1891.51 47.05 1353.25 1249.98 13.22 0.85 7525.80 3947.94 2151.59 -2888.46 8438.84 3979.17 3098.24 -1902.16 47.051 1353.1 1249.52 13.18 0.23 7600.00 3946.86 2204.71 -2920.25 8486.67 3077.84 3132.78 -1935.21 47.03 1353.73 1249.14 13.06 1.57 7700.00 3944.94 2276.30 -2990.05 8557.79 3973.91 3185.04 -1983.29 46.91 1358.55 1250.54 12.91 3.90 7800.00 3943.21 2347.89 -3059.85 8885.39 3988.87 3264.77 -2055.34 48.77 1360.28 1251.83 12.85 1.97 7800.00 3941.49 2419.48 -3129.84 8810.91 3966.49 3370.55 -2155.23 46.78 1361.85 1249.95 12.27 0.82 8000.00 3939.65 2491.08 -3199.45 8946.27 3061.23 3466.12 -2250.93 48.59 1380.48 1245.35 11.91 1.40 8100.00 3934.81 2582.48 -3289.27 9073.87 3960.23 3554.49 -2342.98 48.97 1357.49 1239.48 11.59 5.03 8200.00 3928.34 2833,94 -3338.93 9190.70 3962.29 3832.89 -2429.45 47.39 1351.45 1230.78 11.28 5.81 8300.00 3921.86 2705.39 -3408.59 9289.20 3963.33 3686.21 -2487.15 47.65 1346.40 1223.88 11.07 4.92 8400.00 3915.39 2778.84 -3478.25 9341.77 3963.68 3736.38 -2539.59 47.87 1343.'188 1218.98 10.89 4.06 8500.00 3909.31 2848.34 -3547.90 9407.46 3963.78 3782.90 -2585.98 48.1E11 1342 121669 10.78 2.71 8600.00 3906.50 2920.25 -3617.32 9478.31 3963.85 3834.28 -2634.75 48.54 1343.1 1210.4d 10.67 1.56 8700.00 3904.47 2902.31 -3686.83 9574.89 3963.93 3905.39 -2700.10 48.62 1345.55 1218.51 10.50 1.59 8800.00 3902.44 3084.37 -3755.94 9814.67 3960.86 4074.74 -2869.63 48.71 1345.29 1210.75 10.07 4.85 8900.00 3900.41 3136.42 -3825.25 9923.57 3956.24 4145.84 -2951.98 48.63 1335.90 1198.74 9.80 5.29 9000.00 3898.85 3207.20 -3895.86 9984.86 3954.15 4186.64 -2997.66 48.25 1330.10 1191.30 9.64 1.43 9094.19 3897.48 3271.02 -3965.12 10009.43 3951.26 4263.75 -3082.34 43.81=MEIER 1188.31 9.47 0.88 9100.00 3897.42 3274.87 -3969.47 10108.34 3951.08 4268.35 -3087.50 43.80 1329.56 1188.17 9.46 0.87 9200.00 3896.27 3341.11 -4044.37 10231.35 3948.14 4350.84 -3181.58 43.74 1329.01 1184.71 9.27 0.94 9300.00 3895.12 3407.38 -4119.27 10350.22 3948.18 4427.02 4272.64 43.80 1326.39 1179.37 9.08 2.14 9400.00 3893.97 3473.60 -4194.18 10455.43 3948.88 4494.02 -3353.74 43.89 1323.10 1173.57 8.90 2.09 9500.00 3892.83 3539.84 -4269.08 10528.81 3948.66 4540.95 -3409.90 43.92 ..42 1168.82 8.78 1.06 9541.09 3892.10 3567.02 -4299.89 10555.65 3948.68 4558.67 -3430.33 43.7,iFFINE 1187.74 8.71 1.60 9800.00 3890.05 3805.76 -4344.22 10605.11 3948.82 4591.48 -3467.33 43.83 1320.82 1167.00 8.65 2.37 9700.00 3886.33 3871.48 -4419.52 10706.48 3949.12 4658.87 -3543.05 43.81 1321.79 1185.78 8.52 2.35 9800.00 3882.61 3737.15 -4494.82 10822.38 3949.51 4735.39 -3630.11 44.01 1322.37 1163.66 8.38 2.40 9900.00 3878.89 3802.85 -4570.12 10927.02 3950.22 4803.56 -3709.48 44.21 1321.82 1160.61 8.24 2.74 10000.00 3875.16 3868.55 -4645.42 11184.44 3952.59 4956.49 -3916.24 4478 1311.99 1147.15 8.00 7.73 10100.00 3872.04 3934.26 -4720.73 11289.90 3952.86 5004.26 -3987.10 44.83 1299.86 1132.78 782 6.65 10200.00 3869.86 3999.98 -4798.07 11341.44 3950.49 5045.43 -4045.56 4482 1289.47 1120.00 7.65 5.54 10300.00 3867.67 4065.70 -4871.41 11405.04 3946.30 5083.36 -4096.43 44.71 1281.57 1108.80 7.50 4.79 10400.00 3865.49 4131.43 -4946.75 11468.65 3940.38 5122,72 -4146.03 44.51 1276.49 1102.52 7.37 5.43 10500.00 3863.31 4197.15 -5022.08 11531.49 3932.20 5162.92 -4193.63 44.21=MEW& 1098.22 7.27 7.23 10556.34 3862.10 4234.18 -5064.53 11561.85 3927,74 5182.89 -4216.07 44.05 1274.4MillilatajEL 7.23 7.48 10585.00 3861.78 4253.02 -5086.12 11577.27 3925.50 5193.20 -4227.31 43.97 1274.97 109.50 7.22 8.24 1060000 3861.70 4262.88 -5097.42 11585.34 3924.33 5198.64 -4233.15 43.92 1275.36 1097.66 7.21 8.28 10700.00 3861.21 4328.63 -5172.77 11846.35 3915.71 5240.74 -4276.46 43.54 1279.95 1100.50 7.17 8.18 10800.00 3880.72 4394.38 -5248.11 1173256 3906.18 5301.50 -4336.85 43.12 1286.60 1104.94 7.12 8,45 10900.00 3860.22 4460.13 -5323.45 11885.85 3897.40 5408.19 -4446.51 42.75 1291.99 1106.89 7.00 1,85 11000.00 3859.73 4525.88 -5398.80 12004.21 3896.44 5487.68 -4534.19 42.73 1293.82 1105.67 6.91 0.96 11100.00 3858.83 4591.82 -5474.14 12108.45 3897.93 5557.21 -4611.82 42.82 1295.17 1104.46 6.82 3,80 11200.00 3854.93 4857.32 -5549.43 12229.13 3902.91 5636.46 -4702.70 43.2' ' 1101.92 6.73 4.94 11300.00 3850.58 472301 -5624.70 12317.09 3908.84 5693.98 -4769,12 43.58 1295.37 1099.69 8.65 4.98 11400.00 3846.22 4788.70 5899.98 12389.06 3909.55 5742.02 -4822.84 43.84 1297.1 1099.4, 6.59 4.56 11500.00 3841.87 4854.39 -577525 12471.12 3911.05 5797.94 -4882.67 44.06 1300.69 1100.95 654 3.56 11600.00 3838.78 4920.10 -585055 12545.83 3910.76 5849.77 -4936.48 4422 1305.76 1104.28 651 3.45 Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S120-N4\S120-N4\S120-N4(P6) 2/7/2012 6:39 PM Page 4 of 34 Trajectory:S120-N4(Pe)Vs.SP18-N5 Reference Cylinder North EOU-EOU Intersection MD Reference ND Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) • (ft) (ft) (ft) (ft) (ft) (R) (1 (ft) (ft) () 11700.00 3837.65 4985.83 -5925.91 12632.45 3909.61 5911.05 -4997.68 44.20 1312.57 1108.88 6.47 4.06 1 11800.00 3836.51 5051.55 -6001.27 12779.83 3907.38 6014.13 -5102.98 44.15 1318.52 1111.30 6.39 1.96 1 11900.00 3835.38 5117.28 -8076.83 12899.00 3907.04 6094.58 -5190.90 44.19 1320.90 1110.81 8.31 1.24 1 12000.00 3834.25 5183.00 -6151.99 12992.62 3906.61 6157.68 5280.06 44.21 1323.17 1 0 6.25 1.42 1 12079.07 3833.35 5234.97 -6211.58 13072.07 3906.08 6211.33 -5318.65 44.23 1325.11 i115541 620 1.38 1 12100.00 3833.15 5248.73 -6227.35 13094.24 3905.94 6226.29 -5335.01 44.25 1325.59 1110.80 6.19 1.31 1 12200.00 3832.23 5314.48 -6302.69 13201.94 3905.03 6298.73 -5414.70 44.24 1327.63 1109.97 8.12 1.13 1 12300.00 3831.30 5380.22 -8378.03 13293.97 3902.10 6380.43 -5482.92 44.15 1329. rtr'- '-j 6.06 2.55 1 12400.00 3830.38 5445.97 -6453.38 13377.59 3897.04 6417.45 5543.88 43.96 1332.44 1109.99 6.01 4.61 1 12500.00 3829.45 5511.72 -8528.72 13490.74 3885.02 8494.49 5825.86 43.48 1335.69 1110.33 5.95 8.41 1 12588.52 3828.85 5568.60 -8593.90 13587.66 3873.78 8559.52 5696.83 43.03 1337.421 1109.071 5.881 8.25 1 End of results • • • • • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S120-N4\S120-N4\S120-N4(P6) 2/7/2012 6:39 PM Page 5 of 34 Field: Nikaitchuq Well: SP78-N5 Structure: Spy Island Borehole: SP78-N5P81 Slot: SPI8 Trajectory: SP78-N5P81 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska Slate Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.0895839T Grid Scale Factor: 0.999900152 Magnetic Declination: 20.842° Magnetic Declination Date: November 05,2011 Magnetic Model: BGGM 2011 Reference Point: Northinn Eastinp Elevation Structure Unc.(1sd) Slot Unc.(1sd) 6053640.670(ftUS) 511582.790(ftUS) 53.870(ft)MSL 0.000(ft) 0.000(ft) • Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prop: Description MD From(ft) MD To(ft) EOU Frog Survey Tool Type Hole Diameter(In) Borehole I Survey 0.000 40.000 Act-Stns SLB_NSG+MSHOT-Depth Only-No Globe 16.000 SPI8-N5PB1/SP18-N5PB1 40.000 40.770 Act-Stns SLB_NSG+MSHOT-Depth Only-No Globe 16.000 SP18-N5PB1/SP18-N5PB1 40.770 780.000 Act-Stns SLB_NSG+MSHOT-No Globe 16.000 SP18-N5PB1/SP18-N5PB1 760.000 2612.350 Act-Stns SLB_MWD+GMAG-No Globe 16.000 SP18-N5PB1/SP18-N5PB1 2612.350 2725.580 Act-Stns SLB_MWD-NC_ONLY=10-No Globe 12.250 SP18-N5PB1/SP18-N5PB1 2725.580 3186.970 Act-Stns SLB_MWD+GMAG-No Globe 12.250 SP18-N5PB1/SPI8-N5PB1 3186.970 9420.890 Act-Stns SLB_MWD+GMAG-No Globa 8.750 SP18-N5PB1/SP18-N5PB1 9420.690 6481.000 Act-Stns SLB_BLIND_2-No Globa 8.750 SP18-N5P81/SP18-N5PB1 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (ft) (it) (ft) (ft) (ft( (0) (ft) (°) (ft) (ft) (°) All local minima indicated. Results filtered:Depth 4960.00 6<=MD<=12574.00 ft Results filtered:Ct-Ct separation 0=1500.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 6400.00 3928.00 1345.90 -2082.75 7556.76 3960.28 2548.94 -1213.46 46.97 1484.58 1399.03 17.54 9.96 1 6500.00 3929.54 1417.53 -2152.53 7640.03 3962.04 2588.05 -1280.68 46.83 1467.92 1380.85 17.04 9.31 1 6600.00 3933.19 1488.07 -2222.30 7723.11 3963.76 2647.67 -1347.29 46.56 1452.22 1363.73 16.58 8.79 1 6700.00 3937.46 1560.58 -2292.07 7798.42 3964.72 2693.45 -1407.07 46.47 1437.83 1347.82 16.14 7.98 1 6800.00 3941.72 1632.10 -2381.83 7853.67 3964.80 2728.13 -1450.09 46.39 1425.87 1334.73 15.80 6.53 1 8800.00 3945.99 1703.62 -2431.60 7918.70 3964.32 2770.48 -1499.44 46.26 1416.85 1324.38 15.48 523 1 7000.00 3949.80 1775.16 -2501.37 7999.40 3965.13 2823.99 -1559.83 46.29 1409.54 1315.43 15.13 3.83 1 7100.00 3949.79 1846.75 -2571.19 8084.41 3966.87 2881.07 -1622.80 46.43 1403.40 1307.55 14.78 3.55 1 7200.00 3949.41 1918.34 -2641.00 8159.61 3968.75 2932.35 -1677.78 46.52 1398.70 1301.32 14.50 2.85 1 7300.00 3949.02 1989.04 -2710.82 8201.49 3969.84 2961.60 -1707.72 46.571 1396.701 1298.51 14.37 1.45 1 7400.00 3948.63 2081.53 -2780.83 8233.85 3970.37 2985.37 -1729.66 46.60 1398.46 1300. 14.341 3.09 1 7500.00 3948.23 2133.12 -2850.45 8266.06 3970.60 3010.06 -1750.34 46.60 1407.04 1308.22 14.37 5.74 1 7600.00 3946.68 2204.71 -2920.25 8339.06 3971.03 3067.71 -1795.12 48.60 1418.20 1318.04 14.29 6.97 1 7700.00 3944.94 2276.30 -2000.05 8760.58 3985.97 3377.09 -2079.14 47.49 1429.39 1319.20 13.08 7.38 1 7800.00 3943.21 2347.89 -3059.85 8862.79 3988.95 3441.89 -2158.08 47.69 1418.48 1305.92 12.70 8.35 1 7900.00 3941.49 2419.49 -3129.60 8938.50 3987.56 3490.56 -2216.06 47.70 1408.53 1294.08 12.41 5.36 1 8000.00 3939.85 2491.06 -3199.45 9021.04 3982.62 3544.53 -2278.32 47.52 1400.05 1283.61 12.12 5.25 1 8100.00 3934.81 2562.48 -3269.27 9113.14 3973.85 3605.31 -2346.95 47.61 1392.72 1274.12 11.83 4.80 1 8200.00 3928,34 2833.94 -3338.93 9196.14 3963.59 3660.39 -2408.18 47.41 1388.05 1265.46 11.58 5.39 1 8300.00 3921.86 2705.39 -3408.59 9297.81 3948.42 3728.38 -2482.23 47.06 1380.35 1257.37 11.31 6.07 1 8400.00 3915.39 2776.84 -3478.25 8429.57 3928.08 3814.93 -2579.48 46.57 1373.16 1246.94 10.96 7.09 1 8500.00 3909.31 2848.34 -3547.90 9481.00 3920.04 3848.23 -2817.83 48.42 1365.62 1236.83 10.68 7.98 i 8526.16 3808.25 2867.10 -3568.10 9481.00 3920.04 3848.23 -2617.83 46.46 1364.54 1235.7 10.670 8.55 1 8560.70 3807.30 2891.93 -3590.08 9481.00 3920.04 3848.23 -2617.83 46.660 1363.79) 1235.11 10.67 9.36 1 8600.00 3906.50 2920.25 -3817.32 9481.00 3920.04 3848.23 -2817.83 46.66 1363.93 1235.33 10.68 9.36 1 8700.00 3904.47 2992.31 -3686.83 9481.00 3920.04 3848.23 -2817.83 48.66 1369.37 1241.13 10.75 9.36 1 8800.00 3902.44 3064.37 -3755.94 9481.00 3920.04 3848.23 -2617.83 46.66 1382.04 1254.67 10.93 9.36 1 8900.00 3900.41 3136.42 -3825.25 9481.00 3920.04 3848.23 -2617.83 46.66 1401.75 1275.70 11.20 9.36 1 9000.00 3898.65 3207.20 -3895.86 9481.00 3920.04 3848.23 -2617.83 44.45 1429.94 1305.70 11.59 8.86 1 9100.00 3887.42 3274.87 -3969.47 9481.00 3920.04 3848.23 -2617.83 42.15 1468.39 1346.31 12.12 8.36 1 End of results Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI20-N4\S120-N4\SI20-N4(P6) 2/7/2012 6:39 PM Page 6 of 34 Field: Nika#chug Well: SP23-N3 Structure: Spy Island Borehole: SP23-N3 Slot: SP23 Trajectory: SP23-N3 surveys Client: Eni Petroleum Type: Non-Del Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08921902' Grid Scale Factor: 0.999900151 Magnetic Declination: 20.734° Magnetic Declination Date: January 15,2012 Magnetic Model: BGGM 2011 Reference Point: • Northing Eastina Elevation Structure Unc.(1sd) Slot Unc.(tsd) 6053631.530(SUS) 511535.620(ftUS) 54.100(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 34) 95.000%Confidence 2.7955 sigma Sun/wino Pratt: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(In) Borehole/Survey 0.000 41.000 Act-Stns SLB_NSG+SSHOT-Depth Only-No Globe 30.000 SP23-N3/SP23-N3 surveys 41.000 41.000 Act-Stns SLB_NSG+SSHOT-Depth Only-No Globe 30.000 SP23-N3/SP23-N3 surveys 41.000 730.000 Act-Stns SLB_NSG+SSHOT-No Gbba 30.000 SP23-N3/SP23-N3 surveys 730.000 2692.400 Act-Stns SLB_MWD+GMAG-No Globe 30.000 SP23-N3/SP23-N3 surveys 2692.400 2719.400 Act-Stns SLB_MWD-INC_ONLY-No Globe 30.000 SP23-N3 I SP23-N3 surveys 2719.400 13960.000 Act-Sins SLB_MWD+GMAG-No Globe 30.000 SP23-N3/SP23-N3 surveys 13960.000 14021.000 Act-Stns SLB_BLIND+TREND-No Globe 30.000 SP23-N3/SP23-N3 surveys Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace# (ft) (0) (ft) (5) (ft) (6) (8) (ft) (°) (9) (8) (°) All local minima indicated. Results filtered:Depth 4960.00 ft<=MD<=12574.00 ft Results filtered:Ct-Ct separation<0 1500.00 ft Results highlighted:Ct-Ct separation c=1320.00 ft 8200.00 3928.34 2633.94 -3338.93 10018.84 3852.90 1825.94 -4599.90 227.90 1490.53 1266.07 6.48 12.44 1 8300.00 3921.86 2705.39 -3408.59 100698.97 3853.78 1868.02 -4626.53 227.76 1480.73 1251.76 6.51 10.74 1 8400.00 3915.39 2776.84 -3478.25 10113.74 3854.52 1904.03 -4653.77 227.62 1465.38 1241.28 8.58 8.91 1 8500.00 3909.31 2848.34 -3547.90 10168.41 3855.03 1937.80 -4679.84 227.73 1453.73 1235.25 6.70 6.14 1 8560.70 3907.30 2801.93 -3590.08 10181.57 3855.11 1957.21 -4695.88 228.11 1448.8 IMIManit 6.79 3.88 1 8600.00 3906.50 2920.25 -3617.32 10197.93 3855.07 1069.62 -4708.51 228.10 1446.62 1234.28 6.86 2.93 1 8700.00 3904.47 2992.31 -3686.63 10248.29 3854.49 2005.41 -4739.03 228.r:=MMIIII 1236.46 - 7.02 0.77 1 8800.00 3902.44 3084.37 -3755.94 10301.83 3852.59 2045.35 -4777.57 228.11 1443.82 1240.93 7.17 1.77 1 8900.00 3900.41 3136.42 -3825.25 10360.76 3849.51 2086.48 -4819.65 228.19 1447.01 1247.90 7.32 323 1 9000.00 3898.65 3207.20 -3895.86 10429.10 3845.71 2132.79 -4869.77 225.95 1451.08 1254.55 7.44 2.81 1 9033.75 3898.20 3230.39 -3920.37 10481.16 3844.21 2154.32 -4893.47 225.14 1451.81 1254.971 7.431 1.89 1 9100.00 3897.42 3274.87 -3969.47 10515.65 3842.41 2190.83 -4833.89 223.6; 1 1255.64 . 7.45 0.38 1 9200.00 3806.27 3341.11 -4044.37 10577.45 3843.07 2231.26 -4980.80 223.60 1452.87 1259.80 7.58 3.18 1 9300.00 3895.12 3407.38 -4118.27 10686.70 3846.53 2301.51 -5064.18 223.41 1455.37 1259.11 7.47 1.43 1 9400.00 3893.97 3473.80 -4194.18 10792.88 3850.42 2370.56 -5144.74 223.21 1458.76 1257.80 7.37 4.18 1 9500.00 3892.83 3538.84 -4269.08 10893.56 3856.32 2435.88 -5221.12 222.03 1458.23 1257.29 7.31 3.95 1 9600.00 3890.05 3605.76 -4344.22 11054.52 3862.54 2543.22 5340.88 222.11 1457.06 1246.54 6.07 3.22 1 9700.00 3886.33 3871.46 -4419.52 11138.56 3863.38 2600.40 -5402.44 221.96 1453.89 1243.48 6.95 3.38 1 9800.00 3882.61 3737.15 -4494.82 11359.15 3858.63 2757.67 5556.82 221.83 1444.92 1218.00 6.41 8.43 1 9900.00 3878.89 3802.85 -4570.12 11447.48 3850.75 2822.26 5818.55 222.02 1434.38 1207.08 6.35 7.39 1 1000000 3875.16 3868.55 -4645.42 11523.51 3840.37 2878.94 5688.34 222.33 1425.09 1199.00 6.34 8.54 1 10100.00 3872.04 3934.26 -4720.73 11810.97 3827.06 2938.97 -5728.53 222.83 1417.14 1191.r,, .cc 8.42 1 10200.00 3869.86 3989.98 -4798.07 11674.25 3819.28 2983.30 -5772.99 223.10 1410.88 1187.45 8.35 5.14 1 10300.00 3887.67 4065.70 -4871.41 11733.78 3815.12 3023.96 -5816.27 223.22�9� 1187.0211 6.43 2.00 1 10400.00 3885.49 4131.43 -4948.75 11790.68 3813.18 3061.57 5858.03 223.2 1406.91 1189.85 6.52 0.64 1 10500.00 3863.31 4197.15 -5022.08 11865.55 3812.42 3109.52 -5916.42 223.21 1409.03 1192.98 6.56 1.83 1 10600.00 3861.70 4262.88 5097.42 11967.19 3812.18 3173.89 -5995.07 223.13 1412.14 1193.94 6.51 1.77 1 10700.00 3861.21 4328.63 -5172.77 12077.87 3813.34 3244.62 -8080.20 223.06 1414.5•' 1 6.42 1.42 1 II 10800.00 3860.72 4394.38 -5248.11 12174.67 3812.78 3308.71 -6154.46 223.06 1418.61 1193.32 6.38 1.62 1 10900.00 3860.22 44600.13 -5323.45 12341.80 3804.23 3417.04 -8279.65 223.37 1418.15 1183.02 6.11 3.48 1 11000.00 3859.73 4525.88 -5398.80 12433.24 3799.90 3478.90 -6346.84 223.53 1413.69 1179.58 6.07 1.77 1 11100.00 3858.83 4591.62 -5474.14 12536.58 3798.96 3548.21 -8423.43 223.59 1411.98 1175.4 Lr 66 0. 1.80 1 11145.57 3857.30 4621.57 -5508.46 12568.38 3795.36 3569.59 -6446.89 223.60 1411.08) 1175.2111 6.02 0.89 1 11200.00 3854.93 4857.32 -5549.43 12593.13 3794.09 3585.90 -6465.49 223.80r1410.95) 1177.35 6.08 0.81 1 11300.00 3850.58 4723.01 -5624.70 12638.60 3791.84 3814.82 -6500.50 223.61 1413.71 1184.26 6.20 2.69 1 11400.00 3848.22 4788.70 -5699.98 12700.80 3788.14 3711.28 -6617.89 223.49 1416.62 1179.07 6.00 2.33 1 11500.00 3841.87 4854.39 -5775.25 12939.00 3788.52 3809.23 -6729.34 223.21 1416.15 1171.03 5.81 3.05 1 11600.00 3838.78 4920.10 -5850.55 13060.28 3789.04 3801.78 -6818.18 223.09 1412.88 1163.44 5.69 2.27 1 11700.00 3837.65 4985.83 -5925.91 13158.27 3789.40 3957.82 -6888.04 223.03 1408.99 1157.88 5.64 2.99 1 11800.00 3836.51 5051.55 -6001.27 13232.97 3793.68 4009.49 -6944.37 222.83 1406.14 1155.31 5.64 4.94 1 11900.00 3835.38 5117.28 -6076.63 13297.89 3798.84 4052.20 -6992.98 222.59 1405.50 1156.43 5.67 5.59 1 12000.00 3834.25 5183.00 -6151.99 13420.17 3809.69 4132.08 -7084.92 222.09 1405.48 1151.74 5.57 4.92 1 12100.00 3833.15 5248.73 -6227.35 13539.77 3813.97 4212.08 -7173.70 221.88 1403.77 1145.76 5.47 1.76 1 12200.00 3832.23 5314.48 -6302.69 13849.69 3814.04 4286.49 -7254.80 221.84 1401.14 1139.89 5.39 1.70 1 12300.00 3831.30 5380.22 -6378.03 13729.18 3812.90 4340.25 -7313.14 221.86 1398. 1137.44 5.381 1.08 1 12400.00 3830.38 5445.87 -6453.38 13803.30 3811.09 4389.26 -7388.72 221.90 1398.17 1137.49 5.39 0.85 1 12500.00 3829.45 5511.72 -6528.72 13881.85 3809.48 4440.22 -7428.47 221.94 1390.31 1138.71 5.40 124 1 12586.52 3828.85 5568.60 -8593.90 13951.54 3807.86 4484.72 -7482.07 221.98 1401.46 1140.72 5.40 1.99 1 End of results Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI20-N4\SI20-N4\SI20-N4(P6) 2/7/2012 6:39 PM Page 7 of 34 Field: Nikaitchuq Well: SP23-N3 Structure: Spy Island Borehole: SP23N3PB1 Slot: SP23 Trajectory: SP23-N3PB1 surveys Client: Eni Petroleum Type: Non-De/Survey Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08921907 Grid Scale Factor: 0.999900151 Magnetic Declination: 20.705° Magnetic Declination Date: February 02,2012 Magnetic Model: BGGM 2011 Reference Point: Northing Easting Elevation Structure Unc.(1sd) Slot Unc.(1sd) 6053631.530(ftUS) 511535.620(ftUS) 54.100(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prog: Description MD From(ft) MD To(ft) ECU Frog Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 41.000 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 30.000 SP23N3PB1/SP23-N3PB7 surveys 41.000 41.000 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 30.000 SP23N3PB1/SP23-N3PB7 surveys 41.000 730.000 Act-Stns SLB_NSG+SSHOT-No Global 30.000 SP23N3PB1/SP23-N3PB1 surveys 730.000 2692.000 Act-Stns SLB_MWD+GMAG-No Global 30.000 SP23N3PB1/SP23-N3PB1 surveys 2692.000 2719.400 Act-Stns SLB_MWD-INC_ONLY-No Global 30.000 SP23N3PB1/SP23-N3PB1 surveys 2719.400 10187.000 Act-Stns SLB_MWD+GMAG-No Global 30.000 SP23N3PB1/SP23-N3PB1 surveys Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance Clearance OSF Angle Trace It (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (`) (ft) (ft) (`) - All local minima indicated. Results filtered:Depth 4960.00 ft<=MD<=12574.00 ft Results filtered:Ct-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 8300.00 3921.86 2705.39 -3408.59 10038.20 3840.66 1838.01 -4616.35 228.32 1489.17 1226.76 5.70 8.95 1 8400.00 3915.39 2776.84 -3478.25 10105.46 3833.60 1892.14 -4655.63 228.45 1474.99 1216.46 5.73 8.36 1 8500.00 3909.31 2848.34 -3547.90 10187.00 3823.00 1956.84 -4704.11 228.93 1462.5' EC ..tc yJWARI 8.75 1 8600.00 3906.50 2920.25 -3617.32 10187.00 3823.00 1956.84 -4704.11 229.36 1454.73 1213.19 6.06 9.46 1 8700.00 3904.47 2992.31 -3686.63 10187.00 3823.00 1958.84 -4704.11 229.3>Il 1228.02 6.47 9.46 1 8800.00 3902.44 3064.37 -3755.94 10187.00 3823.00 1956.84 -4704.11 229.36 1460.12 1249.94 6.99 9.46 1 8900.00 3900.41 3136.42 -3825.25 10187.00 3823.00 1958.84 -4704.11 229.36 1473.03 1278.46 7.83 9.48 1 9000.00 3898.65 3207.20 -3895.86 10187.00 3823.00 1956.84 -4704.11 226.96 1490.76 1311.34 8.37 11.43 1 End of results Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI20-N4\S120-N4\SI20-N4(P6) 2/7/2012 6:39 PM Page 8 of 34 CD L CD o 0 0 CD § 0 0 0 (11 = -- I 0 0 ] ., || 0 I Li «. ® y K §! ' 0 0 cn (6 a E I H | | � §§ ,r . (|§ . !| 0 w N3i o E 0 ) \I|K . iP © $ II V. J a 2 I ` 3 2 I- C.) o � tO !■ \ - ( § LT, R! ( 1.i 2 § |_! / ! 00 ■ |§ [ ' 'k) /' !T § a' E §k e =w g V !$ 2 0 B •AI (7) f§ J $| / o o 0 0 o «< N m000 =inns S »> ,= C Iii / Field: Nikaitchuq Well: SD37-DSP7 Structure: Spy Island Borehole: SD37-DSP7 Slot: SP37 Trajectory: SD37-DSP1 Client: Eni Petroleum Type: Del Survey Coordinate System: NAD27 Alaska Stale Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.08812728° Odd Scale Factor: 0.999900147 Magnetic Declination: 20.907 Magnetic Declination Date: September 26,2011 Magnetic Model: BGGM 2011 Reference Point: Northing Easting Elevation Structure Unculsd) Slot Unc.tledl 6053604.090(ftUS) 511394.510(ftUS) 53.650(ft)MSL 0.000(ft) 0.000(ft) Traiectory Error Moder ISCWSAO 3-D 95.000%Confidence 2.7955 sigma Surveying Prog: Description MD From(ft) MD To(ft) EOU Freq Survey Tool Type Hole Diameter(in) Borehole I Survey 0.000 40.550 Act-Stns SLB_CNSG+CASING-Depth Only-No Global 16.000 SD37-DSP1/SD37-DSP1 40.550 40.550 Act-Stns SLB_CNSG+CASING-Depth Only-No Global 16.000 SD37-DSP1/SD37-DSP1 40.550 8550.000 Act-Stns SLB_CNSG+CASING-No Global 18.000 SD37-DSP1/SD37-DSPs 6550.000 6958.000 Act-Stns SLB_MWD+GMAG-No Global 12.250 SD37-DSP1/SD37-DSP1 Reference Cylinder North EOU-EOU Intersection MD Reference TVD Reference NS Reference EW Offset MD Offset NO Offset NS Offset EW Azim Ct-Ct Distance Clearance OSFAngle Trace It (5) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (`) (ft) (ft) (°) All local minima indicated. Results filtered:Depth 4980.00 ft<=MD<=12574.00 6 Results filtered:Cl-Ct separation<=1500.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 4900 00 3945 95 275.42 -1034.14 3950.81 3951.04 -34.09 -188.83 50.71 919.01 905.73 N/A 86.40 1 5000.00 395119 343.52 -1107.17 3957.45 3957.68 -33.99 -168.83 51.73 1011.46 998.04 N/A 86.38 1 5100.00 3955 58 412.00 -1179.90 3983.27 3963.51 -33.91 -168.84 48.81 1105.06 1091.48 N/A 88.01 1 5200.00 3955.48 482.40 -1250.91 3964.37 3964.61 -33.89 -168.84 42.80 1198.97 1185.23 N/A 90.81 1 5300.00 3950.45 554.67 -1319.83 3960.22 3960.45 -33.95 -168.83 36.85 1292.81 1278.90 N/A 93.63 1 5400.00 3940.94 828.48 -1386.81 395121 3951.44 -34.08 -168.83 34.18 1388.40 1372.32 N/A 94.77 1 5500.00 3934.10 701.86 -1454.18 3945.00 3945.23 -34.17 -168.82 40.03 1481.22 1467.01 N/A 91.87 1 End of results • Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S120-N4\S120-N4\S120-N4(P6) 2/7/2012 6:39 PM Page 10 of 34 Schlumberger Traveling Cylinder Plot TRAVHAVG CYLINDER PLOT Chert: Eni Petroleum Well: 920-N4 NoGo Region EOU's based on:Oriented EOU Dimension Field - Nikaitchuq NoGs Region Anti-Collision nde used Minor Risk .74 - Separation Factor 3nrtre: Spy Island .4 1® Date: December 03,2010 Oft to 600ft MD North 350 0 10 340 20 330 30 320 I t 144110) 16__ ��/ 310 )91 ( # 45'04 ►. .�►300 .iik 4 � •t � I� 60 409%61•1/44111,A4111 290 i ,w 4,6- Ad. \`, eiN44/114111WSfr : 11141 70 aiv III 260 "4/4164k4V4*-7,11- N,Vw/*4611.vs -tiplit'l , 80 il 11111111M1:': 11'\ NI. ,,ii_ ...lg.. . „„.,,..i 270 VITAlkaaiti f,� ika&k S � (P1) , . 90 '- r4 4 26 — VOAlltt#A04P.," 100 IOW wnh, ,,/-1 .,..-fe 25004, 4/4.:.,Mao's, I�' 110 240 v.04417 , fist 20 230 41111111k19), 130 220 . a 210 , 150 200• •80 190 180 170 W ell Ticks Type: MD on 5120-N4(P6) Calculation Method: Nomm�al Plane Ring Interval: 20.00 ll Azi uth Interval: 10.0 deg Scale: 1 INCH=25.00 ft Schlumberger Traveling Cylinder Plot TRAYH.ING CYLINDHt PLOT Client: Eni Pdrolann Well: 320-N4 NoG,Region EOU's based on:Oriented EOU Dimension Field: Nikaitchlq NoG,Region Anti-Collision role»sed Minor Risk- Separation Factor Structwe: Spy island A '` Date: December 03,2010 600ft to 1000ft MD 'cry -y North 350 u 10 340 20 330 �� 30 7-SE2(P 32 ' 40 '•� Ilk �t�i�- -tom � __310 �' � SI% � � 50 3004411, OP- '111.411111111111110 ,, .g * IIIS 1 diiiii,44 nee 60 290 ,, ♦ �sy, 70 VO iAf ®`p 280 _!`a _�► ♦ 20 80 4401010.01 270Viaterlitta k4,I i.•..1 A14,74111 I I k 90 , asuitft 1 no 7 VOL34440V1410.-4 100 250 � AVIWA4 •�� •►♦ ,`_ ©, ' 110 ,u 4 A.,ei& orisk, a1 / ,, Sikp 44 4i7 2 120 40 �� o� *WO. an 4 4 130 2204/11101.1M 150 11111140 2 AM 200 160 Well Ticks Type: MD on S120-N4(P6) Calculation Method: Normal Plane Ring Interval: 20.00 6 Azimuth Interval: 10.0 deg Scale: I INCH=30.00 0 Schlumberger Traveling Cylinder Plot TRAVELING CYLINDER PLOT Client: Eni Petroleum Well: 920-N4 NoGo Region EOU's based on:Oriented EOU Dimension Field: Nikaitchuq N NoGo Region Anti-Collision rile used:Minor Risk- Separation FactorStructure: Spy Island A`` Date: December 03,2010 1000ft to 2559ft MD 10 North 350 0 10 340 330 1/2‘430 320 III60 40 310 -irt 50 � 300 it/ ,, , lir60 ilkr 29°A.0. lliki.. i ' , , 70 20 ,/ ' ♦♦ 280 ,r * � �'0- 80 Atm 1 27061 �� 120-N4P- P 1) da,... 90 WI; lee)37 I ItrIL 260 !*/t7 ,.... Ow 100 250 .44N6(P2) Ildpillkto:IIIIIIIII*p4V,240 1041111pir0' N1ND}ffiID3STD (P5) 230 *dill4 130 Ilk 220 � ♦ O140 210 200 blot 80 190 160 170 Well Ticks Type: MD on S120-N4(P6) Calculation Method: Nonml Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=25.00 R Schlumberger Traveling Cylinder Plot _ ---- Client: Eni Petrolann Well: 920-N4 NoOo Region EOU's based on:Oriented EOU Dimension Field: NikaNchuq NoOo Region Anti-Collision rule used:Minor Risk- Separation Factor 9mctme: Ory Island .• 10. Date: December 03,2010 2559ft MD to TD i'oir North 350 0 10 340 20 330 30 ',140 320 , --- lit*".° �' 120 /44t. . 43#1° 50• 1i r. • 300 •�•♦♦♦• ir.••�. •♦, ♦♦•• 80 290 �,�..♦4 04 ♦41111 lit ®� ♦ .` • • ♦ 70 ab**41artA 'V280 � • , ♦, 80♦ ..#4°. AS MI 14 270 � n �= ,at N ° sl/ 90 260 1111111.1417.5.7441"74711 41191111ft ,o0 1111104)00/11 250 ♦ ,,P 0° 411/1111110* 110 240 \tip ♦.44411111614/110. , ■••■ ', 120 .♦ ♦. ,***aatim000 130�Ir 41/111110V14 0 2111111111r60 50 200 190 180 170 Well Ticks Type: MD On SI20 N4(P6) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft ' Schlumberger en; WELL S120-N4 (P6) FIELD Nikaitchuq STRUCTURE Spy Island Magnetic Punmaten Surface Location NAD27 Alaska State Plane,Zare.,US Feel Micella.oue ModM: 000M2011 Dip. 01.102r Data. December 31,2012 L. N 70 33 27 404 Northing. 8053030.00 RCS OM Com:008010154° SIM: SP20 TVD Ref. RRery Tel.(51.111 above MSL) Mag Dec- 20.178° FS'. 57840.1nT Lan: W 1413 54 10.1302 Ending'. SIIS3011 RCS Sot.Fact.044440015 Plow S120-Nd(PS) Stay Date:December 03,2010 6000 S120-N4(P6) TD EndCry £5414 Tgt 14 Cry 2.6/100 • 5000 End Cry SI-N4Tgt 13 Cry 2.5/100 • •C19 End Cry 81-N4Tgt 11 5I-N4 Tgt 12 Cry 2.5/100 Cry 2.5/100 4000 End Cry End Cry SI-N4 Tgt 10 SI-N4 Tgt 9 Civ 2.5/100 Cry 2.5/100 End Cry SI-N4 Tgt 8 • Cry 2.5/100 3000 End try • A SI414 Tgt 7 A Civ 2.5/100 z End Cry SI-N4 Tgt O 8 8 Civ 2.5/100 End Cry Cry g 2000 S4N4 Tgt 5: S4Na To 4 Cry 2.5/1Q0 Cry 2.5/100 (i$nj • End Cry -I-N4 Tgt 3 Cry 2/100 V End Cry V SI-N4 Tgt 2 V . Cry 1000 End Cry 51414 Tgt 1 Cry 3.25/100 End Cry RTE Cry 325/100 ` SINS heel KOP Bid 1.5/100 0 v .Bid 2/100 9-5/8"Casing Point? Drp 1/100 End Cry Dip 3/100 +, End Drp Cry 5/100 •> End Cry 13-3/8"Csg KOP Cry 5/100 S120-N4P81(P1) TD -1000 -6000 -5000 -4000 -3000 -2000 -1000 0 • <<< W Scale=1:1000(ft) E >>> k cY, e a o o to 102 t•A Cm !I i s CID 1 I E = = -a 1 S E' "••• 5 o o co Ca c w 1- .it CM cu 1 2 'Ft s >+ 5 "A O. (/) / S s' s1g t o i o S a .1. th 11- 5 .00 -- -2 o a '4 11 . 4 I. t • - :114 0 ..g. . ., N 1.•, .- 0 C,) 0 1 3 P a •_ e" g 3 I 511 S i ' _ r 0 o 5). i f a a a) i 2 5 < •r, ? •• 6— .. 0 co p 0. 0. 9 .3- 1 .7. 31 11 15 E 41 E Cr 1 i u 0 c 65 I V. 2 s t 3 t! 1 o 0 I,0 FP .—, s r,la t ia i.3 I z i 0 E ct li > 9 t 13§ — t • t— g 0 e-1 1 i 3 t 0 03 0 g 8 a in- g t 5 3 '• i I t .: .. . 0 8 t> s g e 6 S S 1 W 4 5 1;1 c, 1 go ee — ',''02 3 N ifJ 7 21 c0 i•mu ;-:i cp '"' 8 C E 5 1 Cid <Ss a' 8 t mr I g 1 , ii' :•1 4 o co e . 1:§qi.5` 111;c0:.i' m 0 D D -,wzZ Z-0 ii tt. 0 8 0 0 0 0 1- co 2 0 sr a N 0 i i N 01 'tt 04)009:L=oleos a/U_ irotit Schlumberger em M S120-N4(P6) FIELD Nikaitchuq STRUCTURE Spy Island apnetic PSGGM2O Surface loulid, N.27 Alaska Slate Plane,Zone 00,US Feel Mreu iecelleo Madel: SGGM 2011 DIP. 51.10Y Dote'. December 31.2012 Let'. N 70 33 27 900 Noctung 6063636 511539.21 SUS Grid F.0:009800151° Slot S920 TVD Rel'. Rot,0.0. Teda(50.19 above MSL) Meg Dec. 20.179° FS'. 57900.InT Lon: W 149 54 18.692 Eeding. 511559.21 SUS Scab Fact:O 99890015 Plan'. 5120-NO(P6) Sr,Dale:December 03.2010 200 — ., 9- ? �•1•$ :er2 cN_ r )�;".1i.•,.,, r -'t�`: II4($a. ':.''‘,A e8'(R 7( 2) .*, \00z -1...., ..i .1 . ,,,-- ' ,, .0. \,01 . • ,,, ' ' ‘,,N., kltl . 1h6 \l‘s, k 100 ' 414%, `1 `• \ - \:16 :tip?! 2(P4b) � ,k, \ , ,,,,,.,,"1 iliti .,„„„„„...._,_. , N ,,,,,„,:.,,.. .. •._._ ,.. ,....... N....11116.\... ,,____ -12,74,-,.. . "-.-- ---„ ..0 -NqikNo - . ,..„ ,.:,....,:iii,, ,,,,,,, , ‘ 1.,,,,%iis ), 100 —AT , �� : 111 . \\ . .m%. .o . z 200 , II I .111\ N • /00p• .000 . u j No \1 ° c4° �5� •S4' CO V , 1 . V -300 t.ILN4 (P4 • ,so'�"D 1/4,0,10 - 17-SE2 1 , . \ SP1 7(P2) -400 alb\i_:, illik ,,mi... , N....,••- • V. 1 �° � tice i 120-N41 1 (P1) -500 8 _ _. . 0127 SP33- 1 3('2) Tv, SP18-N5 D-S il SP36- 5 (P ) SI i-IV2(P2) SP18-N5PB1°M 1-ST Dr 5- 4(P2) I S—417 1 (P2 SP18-N . Sx34-N Snd (',5�TVD Sf127-N1 SP'3- 3(P5) sp.'8-N5PB -600 Ij 125-N2 (P21 -300 -200 -100 0 100 200 300 400 <<< W Scale = 1:100(ft) E >>> iiii* Schlumberger era "ALL S120-N4(P6) FIELD Nikaitchuq --Spy Island 04904 cParameters SUNace loce8m NPD27 ANN..Me Plane.2one 04,US Feat I Mleca)Muou Model: RGGM 2011 05. 81.102° Date'. December 31.2012 CM: N 703327904 Noreen° 005363606 SUS G/4 Com'.0.08040150° SIU: SP20 TVD Rei: 0085 Tab454.10 abwa MSL) Meg Dec:20.178° FS: 57840 1, Lan: W 1405118.802 EeMOO: 51155021 SOS Scale Fed:090090015 Plan'. S120-N4(P6) Srvy Dale:December 03.2010 2000 — SP10-FN5(P2) SP05-FN7(P2) SP01-SE7(P2) I13-FN4(P2) SIS -FN6 P2) S107-SEii6(ry•) �.o• SP04-SEI (P2) 7500TVD• 1,‘, SP1 �S��O• P1 N5 S102-SE6(P2) N ti _ gr P18-N5'B P1 W� . it ;• 4 1= i 25 TVD 1600 - SP18- 5 ' • ..00� T.14‘ ' 5 1 k li. „ I. 1200 1' .- 4,,C`.. y`P° 2tt1 ' A ,A,,.P! 4.1' 9 '0%71,D ia Zter°• 800 . • .tea 4SF1 ”- o Sao °• • SP12-SE3( 2) • o N \ 4 , • 1500 TVD • ni,.-N Sand (P2) W4• ` ° 'S�• D Ta co gm 2 f -;\ E. gtib ' ki .�. v P24-SE P2) •�Y�ff���i\�\ )ii, . �� ► ;� ."c,riiincl tSOp lyp I,.::''''. i kk ,;'e\o° % - , aoo — SP33-W3(P Sx34-N Sand(P2) ,_ .,149 �� ,2) NSI35-W4(P2) . �''4l :,D S /c • - `x'1.:,7.1. •' SP36-W5(P2 'c!-W1 (-. t ., 1 • E Boo — _ ___ SP24-SE: (P2) x34-N Sand ('- � •)850o ���r c 1 2 P. SI17-SE2 (PP) -1600 -1200 ,y,„„°800 -400 00 SP23-N3(P5) 12 40 2(P2) 800 <<< W Scale = 1:400(ft) E >>> Irotis Schlumberger esu "ALL S120-N4(P6) I F1EL0 Nikaitchuq STRUCTURESpy Island Mq�relic Pemmat,, I 5011se LoceBm NRD27 44.M.Stele Mew Zana 04.US Fel MiscelYrean sel S Mo. le 2011 On 81.102° D. December 31.2012 Ll: N 70 33 27 004 Northirg'. 0053038.008US Odd Cowry:0.08040151' Mot: SP20 TVD Rel 52.7 Tab0y54.111 abor.MSLI Meg Dec:20.178' FS: 57840.1oT Lon W 1405118.002 Ea5.19 511550.21 SOS 5cele Fact:02000015 Men 5120.04(78) Snot Dela'.December 03.2010 13-FN4 (P2) '10-' '•• .•2' •.RE2- N6(P2 'TAR. Kt) ,,• •18-N5 D-STD 6000 — 's SP16-FN3(P3) • 1 Nili S120414(13:g �• ihofjoh_''' e,4,08 4800 —I .` L --1 •! - - 4,..N. •-FN2 (P2) �4+°• 5102- 6�T2, • • a TL� ;O �.0 • a � 5PB1 D-ST. A 4' � �-11-N (P7 A 3600 — + " A ••. ivo Z - - -FN1 (P2) • gyploon,. 411. 5-N2 ' ,e 0 ,p' �p• g -1-14 •11.2) N . 0gsj s ) • 2400 1111%L.• 'i .. i1 -114- n a) i NI . aJkt rl , . Ta ,,, 4‘,.jlS q,2500 LL,.• >e V 1200 — .„F 1 .." . „..,,, .:‘, • 1,, . ' 7-N1 N.(4 .,.. , ,, 0 9 • 4,- ;may:4110 _.. ) <. ;6(w,2) K., e LiM11111 - ','-- evlittAiri..-- •:,.,.:,‘,%, _ - -30-W1 (P2) .• A. r 4 e. �o' 5,d• `1/ �:. .: f (P1) A ^�a; �,�°• 23-N3�( i y 1 • ip ^5�, s .:- ~ (P2) -1200 — •;4glc •� s Tuvaaq ST 1 -�44,. , TVD ,soo .^E'. -19—S1• � �4•4 i •• �‘ RSO • P H00fly •• ..i,'''K a° p^" O. • '. . ti88 2,t0 ° A SP241SE1 P2 -2400 •;, 2 •igt�# 8i2(• ,p) SP30-7 (P22P " _ ( (P2) -7200 -6000 a -4800 -3600 -24 rt -1200 0 1200 " <<< W Scale= 1:1200(ft) E >>> Schlumberger S120-N4 (P6) Anti-Collision Summary Report C2n 0 Analysis Date-24hr Time: January 30,2012-10:47 Analysis Method: 3D Least Distance Client: Eni Petroleum Reference Trajectory: S120-N4(P6)(Non-Def Plan) Field: Nikaitchuq Depth Interval: Every 100.00 Measured Depth(ft) Structure: Spy Island Rule Set: D&M AntiCollision Standard S002 v5.1/5.2 Slot: SP20 Min Pts: All local minima indicated. Well: S120-N4 Borehole: SI20-N4 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 53597.02 ft Selection filters: Definitive Surveys-Definitive Plans-Non-Def Surveys-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major S120-N4PB1(P1)(Def Plan) Fail Major 0.00 -1.22 -1.22 N/A 0.00 0.00 CtCt<=1511<15.00 OSF<150 SfcRul<0.37 Enter Major 0.00 -7.65 -10.86 -0.191 100.00 100.00 MinPt-O-SF 0.001 -11.451 -16.56 -0.12 1400.00 1367.35 MinPts 0.00 -9.44 -13.55 -0.151 1900.00 1835.40 MInPt-OSF 0.001 -10.0 -14.45 -0.14 2400.00 2324.96 MinPts I 0. -9.9 -1444 -0.11 2680.00 2584.89 MinPts 8.54 -0.68 4.79 0.92 2800.00 2724.55 OSF>1.50 OSF>1.00 Exit Major 25.04 15.69 11.50 2.87 2900.00 2823.14 C1Ct<=15m>15.00 Exit Alert 9097.13 9077.17 9067.88 479.31 12586.52 3828.65 TD SP16-FN3(P3)(Def Plan) Fall Minor 39.99 38.77 7.75 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 35.80 32.6 3.4 N/A 400.00 399.89 MinPts 36.93 32.57 4.69 N/A 500.00 499.57 CtCt<=15m>15.00 Exit Alert 461.15 367.28 320.84 4.95 11145.57 3857.30 OSF<5.00 Enter Alert 279.34 81.49 -16.95 1.41 12400.00 3830.38 OSF<1.50 Enter Minor 1 269.231 52.351 -55.591 1.241 12586.52 3828.65 MinPts 5119-FN2(P2)(Def Plan) Warning Alert 8.03 6.81 1.36 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert I 7.101 4.511 0.43 N/A 300.00 299.99 MinPts 27.36 22.10 20.0 6.4 500.00 499.57 C1Ct<=15m>15.00 Ext Alert 1805.58 1792.81 1786.96 154.1 3295.44 3188.27 MinPt-O-SF 1 1162.71 1032.02 967.14 8.95 10000.00 3875.16 MinPt-CtCt 1174.7 1022.65 947.10 7.77 10500.00 3863.31 MINPT-0-EOU 1185.47 1025.161 945.49 7.43 10700.00 3861.21 MinPt-O-ADP 1388.34 1157.42 104245 6.031 12586.52 382865 MInPt-O-SF SP22-FN1(P2)(Def Plan) Warning Alert 15.93 14.71 2.94 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert I 15.931 13.901 2.941 N/A 200.00 200.00 MinPts 41.58 36.61 28.59 N/A 500.00 499.57 CtCt<=15m>15.00 Exit Alert 1241.27 1231.98 1227.9 =HE 2300.00 2225.34 MinPt-O-SF 1803.78 1790.98 1785.1.IM11M1 3295.44 3188.27 MinPt-O-SF 1481.3 1434.36 1411.34 32.15 7300.00 3949.02 MinPt-CtCt 1487.8 1428.4 1399.27 25.46 7700.00 3944.94 MINPT-O-EOU 1496.80 1430.66 1398. 22.96 7900.00 3941.49 MinPt-O-ADP 1512.39 1435. 1397. 19.90 8200.00 3928.34 MinPt-O-ADP 2343.31 2120.18 2009.10 10.541 12586.52 3828.65 MinPt-O-SF SP18-N5 MWD-STD(Non-Def Survey) Warning Alert atEE 22.81 N/A 0.00 0.00 CtCt<=15m<15.05 Enter Alert 19.81 1466 0.32 N/A 600.00 598.93 MinPts 19.86 14.14 0.37 N/A 700.00 697.82 MINPT-O-EOU 40.58 33.44 21.09 N/A 1000.00 990.58 CtCt<=15m>15.00 Exit Alert 289.98 276.56 270. >It 2400.00 2324.96 MinPt-O-SF 390.15 369.79 360.1. KIE 2700.00 2624.89 MinPt-O-SF 855L11 1152.36 1052.28 6.76 7525.80 3947.94 MinPt-CtCt Mi= 1091.20 967.64 5.42 8500.00 3909.31 MinPt-C1Ct 1330.89 1059.13 923.75 4.91 8900.00 3900.41 OSF<5.00 Enter Alert MIME 1007.91 856.38 4.33 9541.09 3892.10 MinPt-CtCt IIKEBW 906.63 729.70 3.56 10546.31 3862.30 MinPt-CtCt 1262. - 905.6 727.82 3.55 10600.00 3861.70 MINPT-O-EOU MEME 887.12 691.07 3.26 11300.00 3850.58 MinPt-CtCt 1284.r.11111Ccem,. 683.73 3.21 11500.00 3841.87 MINPT-O-EOU 1288.46 884.6 1=1MEE 3.20 11571.61 3839.25 MinPt-O-ADP 1317.2Ir: 1111 12588.52 3828.65 MinPts SP18-N5PB1 MWD-STD(Non-Def Survey) Warning Alert inCE 22.81 :Eti N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 19.81 14.66 0.32 WA 600.00 598.93 MinPts 19.86 14.14 0.37 WA 700.00 697.82 MINPT-O-EOU 40.58 33.44 21.09 N/A 1000.00 990.58 CtCt<=15m>15.00 Exit Alert 289.98 276.56 270.46 MEM 2400.00 2324.96 MinPt-O-SF 390.15 369.79 360.1 r lllllllllll 'om''-1m 2700.00 2624.89 MinPt-O-SF Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI20-N4\5120-N4\5120-N4(P6) 1/30/2012 10:48 AM Page 1 of 9 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)„ EOU(ft), Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 1400.68 1211.62 1117.57 7.44 7300.00 3949.02 MinPts 140322 1212.24 111724' 7.38 7400.00 394863 MinPt-O-ADP 141010 1217.69 11212 7.31 7.36, 7495.23 3948.26 MinPI-O-SF 1363.21 1112.35 98741 5.45 8560.70 3907.30 MinPt-CtCt 13632 1112.14 987.08 5.451 8600.00 3906.50 MinPts 4329.51 4212.22 4154.07 37.22 12586.52 3828.65 TD SP18-N5(Def Survey) Warning Alert 22.81 mum N/A 0.00 0.00 CtCt<-15m<15.00 Enter Alert 19.81 14.66 0.32 N/A 600.00 598.93 MinPts 19.86 14.14 037 N/A 700.00 697.82 MINPT-O-EOU 49.21 41.96 29.72 N/A 1100.00 1086.46 CtCI<=15m>15.00 Exit Alert 389.7 =ma mow 16.81 2700.00 2624.89 MinPts 421.61 384.30 366.1.mew 2800.00 2724.55 MinPt-O-SF 1517.38 1496.09 1485.9, 4400.00 3889.50 MinPt-O-SF I 1353.10 1249.52 1198.22 13.18 7525.80 3947.94 MinPt-CtCt 1353.73 1249.14 1197.411 13.06 7600.00 3946.66 MinPts I1342.28 1216.69 1154.39 10.76 8500.00 390931 MinPt-CtCt 1343.19 1216.44 115349 10.67 8600.00 3906.50 MINPT-O-EOU 132955 1188.31 1118.18 947 909419 3897.48 MinPt-CtCt 1320.12 1167.74 1092.04 8.71 9541.09 3892.10 MinPt-CtCt 1274.28 1098.22 1010.68 7.27 10500.00 3863.31 MinPt-CtCt 1274.46 1097.3 100934 7.23 10556.34 3862.10 MINPT-O-EOU 1274.97 1097.5 1009.26 7.22 10585.00 3861.78 MinPt-O-ADP I 1295.36 1101.92 1005.69 6.73 11200.00 3854.93 MinPt-CtCt 1297.13 1099.49\ 1001.14 6.59 11400.00 384622 MinPts 1325.11 1110.61 1003.86 6.20 12079.07 3833.35 MINPT-O-EOU ' 1329.30/ 1109.18 999.61 6.06 12300.00 3831.30 MINPT-O-EOU 1337.42 1109.07 995.34 5.881 12586.52 3828.65 MinPts SP18-N5PB1(Def Survey) Warning Alert IMMO 22.81 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 19.81 14.66 0.32 N/A 600.00 598.93 MinPts 19.86 14.14 0.37 N/A 700.00 697.82 MINPT-O-EOU 49.21 41.96 29.72 N/A 1100.00 1086.46 CtCt<=15m>15.00 Exit Alert 389.751 365.64 354.08 16.81 2700.00 262489 MinPts 421.61 384.30 366.14` 11.5 2800.00 2724.55 MinPt-O-SF 1517.38 1496.09 1485.94 74.6 4400.00 3889.50 MinPt-OSF I1396.74 1298.581 1250.01 14.37 7300.00 3949.02 MinPts 1399.46 1300.93 1252.1614. 7400.00 3948.63 MinPt-0SF 136454 1235.77 1171.88 10.67 8526.16 3908.25 MinPt-OSF 1 1363.74 1235.111 1171.26 10.67 8560.70 3907.30 MinPts 4333.26 4256.15 4218.08 56.91 1258652 3828.65 TD SP23-N3(P5)(Non-Def Plan) Warning Alert 24.02 22.80 4.56 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 24.02 21.99 4.56 N/A 200.00 200.00 MinPts 2650 2006 7.03 WA 600.00 598.93 MINPT-O-EOU 47.91 38.40 28.44 N/A 1300.00 1274.95 CtCt<=15m>15.00 Exit Alen 62.36 48.84 42.69 4.97 1900.00 1835.40 OSF<5.00 Enter Alert 62.3'Mali M:EI5, 4.90 1918.92 185340 MinPts 64.35 49.93 43.33 MIME 2000.00 1931.08 OSF>5.00 Exit Alert 1348.2 1303.97 1282.30 31.09 4671.58 393400 MinPt-CtCt 1350.8 1299.261 127396 26.68 5041.58 3953.36 MinPts 1382.84 1327.97 1301.04 25.651 5300.00 3950.45 MinPt-OSF 7660.87 7616.75 7595.18 177.55 12586.52 3828.65 TD 8117SF2(P2)(Def Plan) Warning Alert •tam 32.07 30.84 6.17 N/A 0.00 0.00 CtCt<=15m<15,00 Enter Alert 1 27.641 24.011 1.741 N/A 400.00 399.89 MinPts 31.68 25.21 5.78 N/A 500.00 499.57 CtCt<=15m>15.00 Exit Alert 319.27 260.11 231.031 5.471 4971.58 3949.70 MinPt-OSF 315.8 258.14 229.8 5.56 5041.58 3953.36 MinPts 1 315.7 259.82 232.34 5.73 5100.00 3955.58 MinPt-CtCt 1947.23 1929.57 1921.2•MICE 7495.23 3948.26 MinPt-O-SF 6882.25 6860.11 6849.54 32533 12586.52 3828.65 TD • SP24-SE1(P2)(Def Plan) Warning Alert 31.97 30.75 6.15 N/A 0.00 0.00 CtCt<=15m<15.00 Enter Alert 1 31.971 29.941 6.151 N/A 200.00 200.00 MinPts 40.66 37.24 14.84 N/A 400.00 399.89 CtCt<=15m>15.00 Exit Alert 759.81 685.07 648.19 10.291 4400.00 3889.50 MinPt-O-SF 75420 680.58 644.27 10.37 4500.00 3912.88 MinPt-O-ADP 1 752.84 680.44 644.72 10.52 4600.00 3928.13 MinPts 748.12 684.35 652.94 11.90 5041.58 3953.36 MinPt-O-ADP 746.41 683.81 653.00 12.10 5100.00 3955.58 MINPT-O-EOU r745.36 684.67 654.82 1247 5200.00 3955.48 MinPt-CtCt 6649.44 6619.75 660539 23159 12586.52 382865 TD • SI13-FN4(P2)(Def Plan) Warning Alert • 63.97 62.75 31.16 N/A 0.00 0.00 Surface 1 57.101 50.791 24291 N/A 500.00 499.57 MinPts 829.83 660.13 575.77 491 10900.00 3860.22 OSF<5.00 Enter Alert I 804.7 602.622 502.03 400 11600.00 3838.78 MinPt-CtCt 815 589.91 477.65 3.63 12200.00 383223 MINPT-O-EOU 82420 591.9 476.33 3.56 12400.00 3830.38 MinPt-O-ADP 834.57 59659 478.09 3.521 12586.52 3828.65 MinP1-0-SF Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S120-N4\S120-N4\SI20-N4(P6) 1/30/2012 10:48 AM Page 2 of 9 • Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 725N2(P2))DeEP)en) Pass 55.08 53.86 22.27 N/A 0.00 0.00 Surface TiE 53.05®' N/A 200.00 200.00 MinPts 48.88 MEE N/A 500.00 499.57 MinPts 55.37=MI 22.56 N/A 600.00 598.93 MINPT-O-EOU 2459.68 2381.•M.5 32.03 5938.50 3928.07 MinPt-O-ADP F MIME MIME 3.2 12586.52 3825.65 MinPts SI14-N6(P2)(Def Plan) Pass 55.97 54.75 23.16 N/A 0.00 0.00 Surface 55.71 44.38 22.91 N/A 1384.83 1353.40 MinPts 55.72 44.28 22.91 N/A 1400.00 1367.35 MINPT-O-EOU 2518.72 2372.67 2300.13 17.36 9900.00 3878.89 MinPt-CtCt 2516.97 2339.01 2250.52 14.22 11145.57 3857.30 MinPt-CtCt 2515.36 2299.811 2192 5211 11.721 12586.52 3828.65 MinPts SP27-N1(Def Survey) Pass 71.10 69.87 38.29 N/A 0.00 0.00 MinPts 71.59 69.66 38,78 N/A 200.00 200.00 MINPT-O-EOU 75.40 69.84 42.59 N/A 600.00 598.93 MINPT-0-EOU 1437.84 1413.68 1402.0.MaiE 4400.00 3889.50 MinPt-O-SF • 3382.03 333845 39.80 7200.00 3949.41 MinPt-CtCt 3470. Mn. 3335.32 38.80 7300.00 3949.02 MINPT-0-EOU 3473.15 3350.53196 37.89 7400.00 3948.63 MinPt-O-ADP 3775.69 3641.961MM= 28.44 9094.19 3897.48 MinPl-0-ADP 3796.7 3649.761 3576.74 25.99 9600.00 3890.05 MINPT-O-EOU 3799.86 3650.5'® 25.61 9700.00 3886.33 MinPt-O-ADP 4071.58 3886.52 3794 48® 11523.81 3840.83 MinPt-O-SF MEM MIME MEM MEM 12586.52 3828.65 MlnPts SP12-SE3(P2)(Def Plan) Pass 87.12 85.89 54.31 N/A 0.00 0.00 Surface ( 79.061 72.451 46.25 N/A 500.00 499.57 MlnPts 1454.68 1397.87 1369.96 26.041 4200.00 3819.16 MinPt-O-SF 1068.72 1023.90 1001.98 24.36 5480.24 3935.05 MinPt-OSF I 1063.941 1019.661 998.01 24.55 5571.29 3932.16 MinPts 7017.79 6990.01 6976.61 261.82 12586.52 3828.65 TD 5129-52(P4b)(Def Plan) Pass 87.12 85.89 54.31 N/A 0.00 0.00 Surface M:31: N/A 200.00 200.00 MinPts MEM N/A 5600.00 3931.84 MinPts 1800.7!M1M13 1767.98 N/A 5700.00 3930.73 MINPT-O-EOU 2815.60 2739.07 2701.30 111MM 8300.00 3921.86 MinPt-OSF 3582.38 3486.05 3438.3.MEM 9506.56 3892.75 MinP1-OSF 5960.69 5854.92 5802.53 56.87 12586.52 3828.65 TD SP3O-W1(P2)(Def Plan) Pass 95.09 93.86 62.28 N/A 0.00 0.00 Surface 1 95.093.061 62.281 N/A 200.00 200.00 MinPts 97.411 92.15 64.61 N/A 500.00 499.57 MINPT-O-EOU 1597.94 1575.36 1564.57 73.961 4500.00 3912.88 MinPt-O-SF 3219.17 3181.61 3163.32 87 97 6459.00 3929.10 MinPt-O-SF 4614.29514507. 4454.38 43 54 8000.00 3939.65 MinPts I4696.34468.03 4354.37 20.65 12586.52 3828.65 MinPts SP11-N7(P2)(Def Plan) Pa„ 95.15 9392 6234 N/A 0.00 0.00 Surface 95.15 93.12( 62.341 N/A 200.00 200.00 MinPts 3710.73 3547.65 3466.60 22.89 9567.60 3891.26 MinPt-CtCt 3714.58 3472 591 3352 091 15.411 12586.52 3828.65 MinPts SP10-FN5(P2)(Def Plan) Pass 103.22 102.00 70.41 N/A 0.00 0.00 Surface N/A 500.00 499.57 MinPts MMIE 1400.72 1341.02 12.73 9000.00 3898.65 MinPt-CtCt 1522.61337.61 12.40 9100.00 3897.42 MINPT-0-EOU 1535.40 1401.1,�ME= 11.51 9400.00 3893.97 MinPt-O-ADP 1544.41 1404.2,: 11.09 9567.60 3891.26 MinPt-O-ADP 1945.04 1710.96 1594.41�.M 12586.52 3828.65 MinPl-OSF 0108-FNS(P2)(Def Plan) Pass 119.15 117.93 86.34 N/A 0.00 0.00 Surface 113.88 107.611 81.071 N/A 600.00 598.93 MinPts 1826.96 1786,64 1766.96 46.41 5961.98 3927.94 MinPt-CtCt 1827.1 1783.74 1762.51 43.02 6100.00 3928.49 MinPt-0tCt 1830. 1778.74 1753.17 35.78 6459.00 3929.10 MINPT-O-EOU 1831.84 1778."0,'11 1752.84 35.20 6495.12 3929.45 MinPt-O-ADP 2827.04 2615.27 2509.88 13.41 12079.07 3833.35 MinPt-O-SF 2984.49 2759.71 2647.81 13.33 12586.52 3828.65 MinPt-OSF SI32-W2(P2)(Def Plan) . ,.1tV5 .,: z...r, gy-/g s.F r'' k"*..,`n ' NF"*„ ',' _::-, 119.03 117.81 86.23 N/A 0.00 0.00 Surface 1 119.031 117.001 86.231 N/A 200.00 200.00 MinPts 121.80 115.42 88.99 N/A 500.00 499.57 MINPT-O-EOU 5895 60 5747.33 5673.69 40.02 9000.00 3898.65 MinPts 5897.27 5653.63 5532.30 24.30 12586.52 3828.65 MinPts S107-SE4(P2)(Def Plan) Pass Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S120-N4\S120-N4\S120-N4(P6) 1/30/2012 10:48 AM Page 3 of 9 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 127.11 125.89 94.31 N/A 0.00 0.00 Surface I122.13 115.441 89.321 N/A 500.00 499.57 MinPts 1804.68 1762.67 1742.15 43.96 5800,00 3929.61 MinPt-CtCt 1805.43 1762.371 1741.33 42.89 5900.00 3928.50 MlnPts 1864.86 1818.54 1795.88 41.121 6300.00 3928.83 MinPt-O-SF 703001 6985.96 6964.42 163.21 12586.52 3828.65 TD SP33-W3(P2)(Def Plan) Pass 127.12 125.90 94.32 N/A 0.00 0.00 Surface 1 127.121 125.091 94.32 N/A 200.00 200.00 MinPts 6557.93 6535.57 6524.89 306.81 9800.00 3882.61 MinPt-O-SF 1 7105.391 6872.711 6756.87 30.66 12586.52 3828.65 MinPts Sx34-N Sand(P2)(Def Plan) Paas 135.12 133.89 102.31 N/A 0.00 0.00 Surface 135.12 133.08 102.31 N/A 200.00 20000 MinPta 135.44 132.97 102.63 N/A 300.00 299.99 MINPT-O-EOU 1 519.19 464.55 437.73 9.66 5600.00 3931.84 MinPt-CtCt 525.87 459.49 426.79 8.03 6100.00 3928.49 MINPT-O-EOU 532.75 45949 423.35 7.36 6400.00 3929.00 MINPT-O-EOU 53490 459.79 422.73 7.20 6495.12 3929.45 MinPt-O-ADP 553.061 455.86 407.75 5.74 7400.00 3948.63 MinPts 556.15 45722 408.25 5.671 7495.23 3948.26 MinPt-OSF 513548 5108.06 5094.85 194.26 12586.52 3828.65 TD 5135-W4(P2)(Def Plan) Paas 143.11 141.89 110.30 N/A 0.00 000 Surface 1 143.111 141.081 110.30 N/A 200.00 200.00 MinPts ' 6342.00 6319.76 6309.13 298.30 9600.00 3890.05 M1nPt-OSF 8264.721 8038.981 7926.61 36.77 12588.52 3828.65 MinPta SP05-FN7(P2)(Def Plan) Paas 151.22 150.00 118.41 N/A 0.00 0.00 Surface I147.15 140.731 114.341 N/A 500.00 499.57 MinPts 2082.57 2050.36 2034.75 66.66 5500.00 3934.10 MinPt-CtCt 2082.90 2049.851 2033.81 64.92 5571.29 3932.16 MinPts 3740.33 3537.33 3436.3 18.51 1207907 3833.35 MinPt-O-SF 3947.12 3731.68 3624.45 18.40 12586.52 3828.65 MinPI-0-SF SP36-W5(P2)(Def Plan) Pass 151.17 149.95 118.36 N/A 0.00 0.00 Surface I 151.171 149.141 118.36 N/A 200.00 200.00 MinPts 6223.98 6201.70 6191.06 292.301 9500.00 3892.83 MinPt-OSF 9078.28 9052.83 904059 370.94 12586.52 3828.65 TD SPO4SE5(P2)(Def Plan) Pass 159.11 157.89 126.31 N/A 0.00 0.00 Surface 156.62 151.63 123.81 N/A 500.00 499.57 MinPta 157.58 151.26 124.77 N/A 600.00 598.93 MINPT-O-SOU I' 2088.31 2052. 20344 59.19 5500.00 3934.10 MinPta 2293.45 224560 2222.171 48.921 6495.12 3929.45 MinPt-OSF 7214.04 7156.42 7128.11 127.37 12586.52 3828.65 TD SD37-DSP1 MWD original(Non- Def Survey) Pass 167.79 166.57 134.98 N/A 0.00 0.00 Surface 166.12 162.25 133.31 N/A 300.00 299.99 MinPts 166.76 160.67 133.95 N/A 400.00 399.89 MINPT-O-EOU 295.3 276.8 262.511 N/A 3900.00 3659.12 MinPta 3443.39 3421.16 3410.5411 162.061 7495.23 3948.26 MinPt-O-SF 8525.90 8501.23 8489.38 35988 12586.52 3828.65 TD SD37-DSP1 GMAC(Non-Def Survey) Pass 167.79 166.57 134.98 N/A 0.00 0.00 Surface 166.12 162.25 133.31 N/A 300.00 29999 MinPts 16676 16067 133.95 N/A 400.00 399.89 MINPT-O-EOU I 295.2 276.7 262.4 N/A 3900.00 3659.12 MinPts 3348.88 3326.67 3316.05 157.711 7400.00 3948.83 MinPt-O-SF 8525.94 8501.22 8489.35 359.10 12586.52 3828.65 TD SD37-DSP1(Def Survey) Pass 167.79 166.57 134.98 N/A 0.00 0.00 Surface mom sun®' N/A 300.00 299.99 MinPts MIME MGM MEM N/A 3900.00 3659.12 MinPts 8525.52 8506.15 8492.71 N/A 12586.52 3828.65 TD S102-SE6(P2)(Def Plan) Pass 175.10 173.87 142.29 N/A 0.00 0.00 Surface 175.10 173.07 14229 N/A 200.00 200.00 MinPts 175.72 172.07 14291 N/A 400.00 399.89 MINPT-O-EOU 3815.58 3736.65 3697.68=Mal 8200.00 3928.34 MinPt.O-SF 7367.69 7278.81 7234.86 83.81 12586.52 3828.65 TD SP01-SE7(P2)(Def Plan) Pass 183.21 181.98 150.40 N/A 0.00 0.00 Surface 18245 17921 149.64 N/A 400.00 399.89 MinPts 18352 178.51 150.71 N/A 500.00 499.57 MINPT-O-EOU 4849.20 4775.38 4738.96 MZE1M 9033.75 3898.20 MinPt-O-SF Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI20-N4\S120-N4\S120-N4(P6) 1/30/2012 10:48 AM Page 4 of 9 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Des.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major ' 5260.85 5180.71 5141.14 66.48 9541.09 3892.10 MinPt-O-SF 7837.02 7722.49 7665 71 69.01 12586.52 3828.65 TD OP09-S1(Def Survey) Pass 4921.98 4763.42 4685.49 31.56 0.00 0.00 Surface 3692.24 3514.71 3427.81® 1600.00 1552.72 MinPt-OSF 2803.23 2392.23 2289.50 Min 4100.00 3772.73 MinPt-O-SF 2599.99 '2.65 4200.00 3819.16 MinPts 2681.12 2466.57 2362.31- 4800.00 3940.72 MinPt-O-SF 2886.98 2661.86 2552.3,MED 5571.29 3932.16 MinPt-O-SF 3133.68 2894.85 2778.:- 6400.00 3929.00 MinPt-O-SF 7567.76 7452.02 7397.30 69.10 12586.52 3828.65 TD Kigun 1(Def Survey) Pass 5037.42 5035.51 5004.62 N/A 0.00 0.00 Surface MOEUESh N/A 200.00 200.00 MinPts 5039.28 mirmo. 5006.47 N/A 500.00 499.57 MINPT-O-EOU 4565.80 4534.93 4520.48 157.82 5369.99 3944.01 MinPt-CtCt 4566.22 MEMO 4517.03 144 79 5600.00 3931.84 MINPT-O-EOU 4567.89 4532.98 MI= 138.23 5700.00 3930.73 MinPt-O-ADP 5403.06 5331.90 5297.1 - 8457.38 3911.68 MinPt-OSF 5658.78 5584.30 5547.86® 8907.85 3900.25 MinPt-O-SF 5881.71 5804.58 5766.81- 9300.00 3895.12 MinPt-O-SF 8212.13 8121.75 8077.36 92 49 12586.52 3828.65 TD • Kigun 1 P91(Def Survey) Pass 5037.42 5035.51 5004.62 N/A 0.00 0.00 Surface I 5037.32 5034.5.1 5004.511 N/A 200.00 200.00 MinPts 5039.28 5034.4 5006.47 N/A 500.00 499.57 MINPT-O-EOU 4712.03 4680.00 4664.81 155.05 5600.00 3931.84 MinPt-CtCt 4712.66 4679.211 4663.29 14803 5700.00 3930.73 MinPts 5526.77 5457.25 5423.30` 81.37 8500.00 3909.31 MinPt-O-SF 5751.33 5678.69 5643.17 80.95 8907.85 3900.25 MinPt-O-SF 602419 5948.11 5910.87 80.87 9400.00 3893.97 MinPt-0SF 8252.04 8162.88 8119.11 94.25 12586.52 382865 TD Tuvaaq ST 1(Del Survey) Pass 5037.42 5035.51 5004.62 N/A 0.00 0.00 Surface I 5037.32 5034. 5004.511 N/A 200.00 200.00 MinPts 5039.28 50344 5006.47 N/A 500.00 499.57 MINPT-O-EOU 4862.11 4822.97 4804.20 129.51 5900.00 3928.50 MinPt-CtCt 4862.56 4822.77 4803.68 127.33 5938.50 3928.07 MINPT-O-EOU 4863.64 4822.93 4803.38 124.35 6000.00 3928.23 MinPt-O-ADP 6554.88 6383.62 6298.80 38.63 12586.52 3828.65 MinPt-O-SF OP14-S3(Del Survey) _ peat 6633.40 6439.62 6344.13 34.72 0.00 0.00 Surface 6033.76 5830.69 5730.7,mom 1100.00 1086.48 MinPt-O-SF 4758.90 24.25 4100.00 3772.73 MinPts 5114.67 4895.08 4787.65=Elm 4500.00 3912.88 MinPt-O-SF 5332.09 5104.65 4993.4 Emma 5400.00 3940.94 MinPt-0-SF 5561.90 5327.84 5213.3 grel 6100.00 3928.49 MinPt-OSF 5721.87 5482.34 5365.1 6552.90 3931.19 MinPt-O-SF 5923.48 5676.53 5555621® 7100.00 3949.79 MinPt-O-SF 9264.56 9075.40 8983.44 50.34 12586.52 382865 TD 0115-04(P9b)(Def Plan) Pass 7632.07 7446.23 7354.78 41.71 0.00 0.00 Surface 6288.02 6084.25 5984.51 31.50 3900.00 3659.12 MInPt-CtCt 6288.40 6083.841 5983.71 31.38 4000.00 3719.25 MinPts 6363.56 6153.49 6050.57 308 4600.00 3928.13 MinPt-O-SF 6467.73 6253.72 6148.82 30.81 5041.58 3953.36 MinPt-O-SF 6944.96 6709.53 6593.81 29.99 6700.00 3937.46 MinPt-O-SF • 10079.66 9888.89 9795.82 54.13 12586.52 3828.65 TD OP10-09(Def Survey) Pass 8596.59 8392.90 8292.39 42.75 0.00 0.00 Surface 7389.40 7172.77 7066.2• 34.68) 3700.00 3520.80 MinPt-O-SF MEM 7166.90 7060.80 34.78 3900.00 3659.12 MinPts 7425.09 7203.70 7094.;,MffillE 4300.00 3858.18 MinPt-O-SF 7885.22 7854.21 7540.:,0 5700.00 3930.73 MinPt-0SF 7961.32 7728.41 7613.8, '0W6!' 5900.00 3928.50 MinP1-0SF 8118.64 7875.50 7755.7: 683 6300.00 3928.83 MinPt-O-SF 8350.77 8089.01 7959., ® 6900.00 3945.99 MinPt-O-SF 8569.37 8302.45 8170.7-® 7495.23 3948.26 MinPt-O-SF 8799.29 8527.83 8393.,t•MERE 8086.58 3935.68 MinPt-O-SF 9049.70 8766.25 8626..®' 8700.00 3904.47 MinPt-O-SF 10964.17 10709.02 10583.34 43.60 12586.52 3828.65 TO Nikaitchuq 4(Def Survey) Pass MMEIE 8170.1,MEM N'A 0.00 0.00 MinPts 8172.1' 'i W 8139.36 N;A 100.00 100.00 MINPT-O-EOU 7875.30 7829.38 7807.3:- 1100.00 1086.46 MinPt-O-SF MZEIM®" 167.67 2900.00 2823.14 MinPts 8140.93 8072.92 8039.7.main 5400.00 3940.94 MinPt-0-SF 8523.82 8450.91 8415. +MEM 6495.12 3929.45 MinPt-O-SF 9494.61 9408.44 9366.1 ® 8457.38 3911.68 MinPt-O-SF 9814.57 9725.13 9681.22® 9000.00 3898.65 MinPt-O-SF Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S120-N4\S120-N4\S120-N4(P6) 1/30/2012 10:48 AM Page 5 of 9 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 10157.76 10065.26 10019.82 111.75 9506.56 3892.75 MinPt-O-SF 12505.18 12397.21 12344.03 117.56 12586.52 3828.65 TD Nikaitchuq 3PB2(Def Survey) Pass 7924.13 7922.21 7891.32 N/A 0.00 0.00 Surface 7924.1 7921.9 7891.31 N/A 100.00 100.00 MinPts 7799.37 7791.14 7766.56 N/A 2660.00 2584.89 MinPts 12798.63 12738.47 12709.19 218.56 10048.86 3873.35 MinPt-O-SF 13244.77 13181.82 13151.15 215.90 10556.34 3862.10 MinPt-O-SF 14106.55 14038.65 14005.50 212.77 11523.81 3840.83 MinPt-O-SF 14805.48 14535.09 14500.70' 212.33 12077.07 3833.37 MinPt-O-SF 14989.43 14917.19 14881.88 212.22 12500.00 3829.45 MinPt-O-SF 15068.23 14995.62 14960.12 212.22 12586.52 3828.65 TD Nikaitchuq 3(Oaf Survey) Pam 7924.13 7922.21 7891.32 N/A 0.00 000 Surface 7924.1 7921.9 7891.31 N/A 100.00 100.00 MinPts 7799.37 7791.14 7766.56 N/A 2660.00 2584.89 MinPts 12798.63 12738.47 12709.19% 18.56 10048.86 3873.35 MinPt-OSF 13244.77 13181.82 13151.15 215.90 10556.34 3862.10 MinPt-OSF 14106.55 14038.65 14005.55. 212.77 11523.81 3840.83 MinPt-0SF 14605.48 14535.09 14500.70 212.33 12077.07 3833.37 MinPt-0SF 14989.43 14917.19 14881.88 212.22 12500.00 3829.45 MinPt-0SF 15068.23 14995.62 14960.12 21222 12586.52 382865 TD Nikaitchuq 3PB1(Def Survey) Pam 7924.13 7922.21 7891.32 N/A 0.00 0.00 Surface 7924.1 7921.9 7891.31 N/A 100.00 100.00 MinPts 7799.37 7791.14 7766.56 N/A 2660.00 2584.89 MinPts 12798.63 12738.47 12709.19 218.56 10048.86 3873.35 MinPt-0•SF 13244.77 13181.82 13151.15 10556.34 3862.10 MinPt-0SF 14106.55 1403865 14005.55. 212.77 11523.81 384083 MinPt-0SF 14605.48 14535.09 14500.70\ 212.33 12077.07 3833.37 MinPt-0SF 14989.43 14917.19 14881.88 212.22 12500.00 3829.45 MinPt-0-SF 1506823 14995.62 14960.12 21222 12586.52 382865 TD Nikaitchuq 3PB3(Def Survey) Pam 792413 7922.21 7891.32 N/A 0.00 0.00 Surface 7924.1 7921.9 7891.31 N/A 100.00 100.00 MinPts 7799.37 7791.14 7766.56 N/A 2660.00 258489 MinPts 12798.63 12738.47 12709.19s18.56 10048.86 3873.35 MinPt-0SF 13244.77 13181.82 13151.15.. 215.90 10556.34 3862.10 MinP1-0SF 14106.55 1403865 1400566\ 212.77 11523.81 3840.83 MinPt-0SF 14605.48 14535.09 14500.75. 212.33 12077.07 3833.37 MinPt-0SF 14989.43 14917.19 14881.08 212.22 12500.00 382945 MinPt-OSF 15068.23 14995.62 14960.12 212.22 12586.52 3828.65 TD Nikaitchuq 1(Def Survey) Pass 8056.70 8054.78 8023.89 N/A 0.00 0.00 Surface 7995.601 7986.511 7962.80 N/A 1918.92 1853.40 MinPts 8943.87 8920.48 890960 41069 4400.00 3889.50 MinPt-0SF 13725.80 13629.52 13582.18 144.97 11571.61 3839.25 MinPt-0SF 14122.02 14022.29 13973.23, 143.92 12077.07 3833.37 MinPt-OSF 14527.81 14424.77 1437406 14322 12586.52 3828.65 MinP1-0SF OP0407(Def Survey) Pass 9346.39 9284.02 9255.08 161.41 0.00 0.00 Surface I 8077.051 8013.771 7984.93 139.92 2900.00 2823.14 MinPts 8221.10 8156.73 8127.28 139.461 3500.00 3361.97 MinPt-0SF 17020.82 16954.78 1692226 261.65 12586.52 3828.85 TD Nikaitchuq 4PB1(Def Survey) Pass ME 8170.1•MEM N/A 0.00 0.00 MinPts 8172.1 ®r 8139.36 N/A 100.00 10000 MINPT-0-EOU 8176.71 I11111M11 8143.90 N/A 500.00 499.57 MINPT-O-EOU 8095.60 11111= 8062.79 N/A 2300.00 2225.34 MinPts 1314447 13083.96 1305451=MEEE 10048.86 3873.35 MinPt-0-SF 13589.52 13526.14 13495. •MEM 10556.34 3862.10 MinPt-0SF 14449.10 14380.64 14347.2.=ME 11523.81 3840.83 MinPt-0SF 14946.84 14875.82 14841.1. 12077.07 3833.37 MinPt-0SF 15408.51 15335.22 15299.371 12586.52 3828.65 MinP1-0-SF OP12-01(Def Survey) Pam 9742.27 9602.06 953377 71.30 000 000 Surface 8688.98 8539.92 8467.56 60.011 2800.00 2724.55 MinPt-0-SF 8643.831 8497.801 8427.07 61.07 3500.00 3361.97 MinPts 1517491 15068.87 15016.93 146.04 12586.52 3828.85 TD 0113-03(Def Survey) Pam 9965.62 9764.82 9665.55 50.18 0.00 0.00 Surface 8904.39 8693.99 8590.28 42.91 3800.00 3592.80 MinPt-CtCt 8908.02 8692.151 8585.65 41.81 400000 3719.25 MinPts 8940.11 8722.53 8615.20 41.64 430000 3858.18 MinPt-O-SF 9393.45 9162.11 9047.91 41.11 5700.00 3930.73 MinPt•O-SF 9659.45 9423.31 9306.73 41.42 6400.00 3929.00 MinPt-O-SF 9856.79 9613.82 9493.80 41.05 6900.00 3945.99 MinPt-O-SF 9936.72 9672.44 9541.54 37.95 710000 3949.79 MinPts 10154.72 9820.48 9653.86 30.47 7800.00 3943.21 MinPts 10164.67 9812.17 9636.41 28.91 8086.58 3935.68 MinPts Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI20-N4\SI20-N4\SI20-N4(P6) 1/30/2012 10:48 AM Page 6 of 9 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)1 EOU(ft) Dee.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 10275 88 9916 76 9737.87 28.72 9400.00 3893.97 MinPt-OSF 11025.29 10666 64 10488.60 30.96 12586 52 3828.65 TD OP08-04(Def Survey) Pass 10385.99 10336.68 10314.25 231.37 0.00 0.00 Surface 10350.72 10301.53 10279.16=.. 100.00 100.00 MinP1-O-SF 9397.74 9350.39 9329.30® 2100.00 2028.13 MinPt-O-SF 9255.68 9209.81 9189.58 228.60 2900.00 2823.14 MinPts 15003.67 14956.22 14933. •MEW 10043.51 3873.54 MinPt-O-SF 15471.33 15422.56 15399.11 MEM 10546.31 3862.30 MinPt-O-SF 16386.39 16335.04 16310.0 =.5! 11523.81 3840.83 MinPt-O-SF 16907.55 16854.84 16829.03.MME 12077.07 3833.37 MinPt-O-SF 17389.28 17335.16 1730858=MIJ 12588.52 3828.65 MinPt-0SF OPO4-07PB1(Def Survey) Pass 10513.38 10462.35 10439.01 225.05 0.00 0.00 Surface 9381.33 9330.88 9308.2 207.021 2500.00 2424.90 MinPt-OSF 1 9345.921 9295.631 9273.09 207.26 2800.00 2724.55 MinPts 9785.62 9713.01 9689.11 204.25 4000.00 3719.25 MinPt-O-SF 10103.67 10049.92 10025.31 205.161 4400.00 3889.50 MinPt-O-SF 18195.61 18137.58 18109.06 318.95 12586.52 3828.65 TD 0107-04(Def Survey) Pass 10545.10 10488.73 1046246 200.59 0.00 0.00 Surface I 9379.801 9321.67 9294.96 175.51 2800.00 2724.55 MinPts 9539.32 9480.19 9452.91 174.771 3500.00 3361.97 MinPt-OSF 18357.82 18297.84 18268.44 312.21 12586.52 3828.65 TD 0111-01(Def Survey) Pass 10764.88 10706.73 10679.76 199.54 0.00 0.00 Surface 9694.46 9633.74 9605.90 174.021 2700.00 2624.89 MinPt-0-SF I 9680.11 9619.781 9592.15 175.09 3000.00 291993 MinPts 15019.63 14959.23 14930.20 258.6 10043.51 3873.54 MinPt-OSF 15467.32 15405.48 15375.6 4=ErMIE 10546.31 3862.30 MinPt-OSF 16144.58 16080.55 16049.41 259.21 11300.00 3850.58 MinPt-O-SF 17315.17 17247.48 17214.21 260.16 12586.52 3828.65 TD Oliktok Point 1-2(Def Survey) Pass 10790.36 10619.49 10535.42 64.16 0.00 0.00 Surface 9815.80 9636.41 9548.37 55.731 3000.00 2919.93 MinPt-0SF I 9770.501 9593.051 9506.08 56.15 3600.00 3443.66 MinPts 15726.73 15582.97 15512.00 110.78 12586.52 382865 TD OP17-02(Def Survey) Pass 11404.31 11194.18 11089.87 54.66 0.00 0.00 Surface I 10434.23' 10217.481 10110.21 48.63 3800.00 3592.80 MinPts 10434.96 10218.09 10110.78 48.614 3900.00 3659.12 MinPt-O-SF 10728.13 10499.40 10386.17 5100.00 3955.58 MinPt-O-SF 11050.601 10792.871 10664.89 43.17 5938.50 3928.07 MinPts 11099.30 10837.82 10707.94 42.71 6100.00 3928.49 MinPt-O-SF 12929.66 12653.57 12516.60 47.19 10600.00 3861.70 MinPt-O-SF 13987.36 13714.72 13579.42 51.68 12586.52 3828.65 TD OP17-02P81(Def Survey) Pass 11457.47 11245.85 11140.78 54.52 0.00 0.00 Surface I 10495.47 10275.641 10166.79 4820 3900.00 3659.12 MinPts 10518.28 10293.88 10182.43 4727 4200.00 3819.16 MinPt-O-SF 10756.82 10529.78 10417.41 47.85 5100.00 3955.58 MinPt-O-SF 11085.61 10832.321 10706.62 44.09 5938.50 3928.07 MinPts 11703.37 11438.40 11303.88 44.15 7600.00 3946.66 MinPt-O-SF 11822.48 11551.43 11416.87 7900.00 3941.49 MinPt-O-SF 12021.42 11726.05 11579.14 40.911 8400.00 3915.39 MinPt-OSF 13805.58 13512.81 13367.40 47.46 12586.52 3828.65 TD OP03-P05(Def Survey) Petro 11720.81 11659.93 11631.07 202.99 0.00 0.00 Surface I 10632A61 10568.411 10538.33 176.66 2800.00 2724.55 MinPts 10665.66 10601.33 10571.10 176. 3100.00 3014.16 MinPt-O-SF 10727.48 10662.89 10632. 176. 3300.00 3192.14 MinPt-OSF 19639.62 19574.80 19542.89 307.65 12586.52 3828.65 TD 0106-05 MWD-Standard(Non-Def Survey) Pass 11916.44 11719.14 11621.65 61.11 0.00 0.00 Surface 1 10859.901 10653.711 10552.09 53.42 2800.00 2724.55 MinPts 10863.84 10657.46 10555.74 53.391 2900.00 2823.14 MinPt-0SF 19850.85 19647.67 19546.57 98.17 12586.52 3828.65 TD 0106-05(Def Survey) Pass 11955.29 11890.74 11859.63 192.12 0.00 0.00 Surface 1 10896.361 10830.201 10798.59 172 30 2800.00 2724.55 MinPts 10912.86 10846.53 10814.83ma. 172.09 3000.00 2919.93 MinPt-0-SF 11002.51 10935.87 10903.98 172.45 3300.00 3192.14 MinPt-0-SF 19885.91 19818.56 19785.37 29960 12586.52 3828.65 TD OP08-04PB1(Def Survey) Pass 12099.57 12070.94 12058 481 485.69 0 00 0.00 M1nP1-0-SF 11521.88 11494.49 11482 851 494.661 1400.00 1367.35 MinPt-O-SF I 11059.171 11033.701 11023.20 526 47 2800.00 2724.55 MinPts Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\S120-N4\5120-N4\S120-N4(P6) 1/30/2012 10:48 AM Page 7 of 9 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) , Fact. MD(ft) I TVD(ft) Alert I Minor I Major 11731.02 11699.79 11686.13 429.24 4400.00 3889.50 MinPt-O-SF 12418.21 12386.02 1237167 432.46 5147.89 3956.15 MinPt-O-SF 12631.17 12598.63 12584.04 432.70 5372.08 3943.78 MinPt-O-SF 13702.55 13668.00 13652.1 6495.12 3929.45 MinPt-O-SF 15589.83 15551.07 15532.54 420.65 8457.38 3911.68 MinPt-0-SF 17112.31 17069.58 17048.71 409.87 10048.86 3873.35 MinPt-0-SF 17596.18 17551.86 17530.1 10556.34 3862.10 MinPt-0-SF 18567.86 18520.47 18497.26 400.08 11571.61 3839.25 MinPt-O-SF 19053.48 1900463 18980.69' 398.01 12077.07 3833.37 MinPt-O-SF 19544.01 19493.71 19469.06 396.35 12586.52 3828.65 MinPt-O-SF 0106-05PB1 MWD-Standard(Non- Def Survey) Pass 12193.21 12002.94 11909.12 6497 0.00 0.00 Surface I 11152.501 10954.281 10856.70 57.13 2800.00 2724.55 MinPts 11156.87 10958.47 10860.80 57.101 2900.00 2823.14 MinPt-0-SF 20166.40 19970.18 19872.56 103.29 12586.52 3828.65 TD 0106-05P61(Oaf Survey) Pass 12234.06 12173.87 12144.99 211.78 0.00 0.00 Surface 1 11191.281 11130.031 11100.89 192.02 2800.00 2724.55 MinPts 1120849 11147.10 11117.89 191.84 3000.00 2919.93 MinPt-0-SF 11297.88 11236.23 11206. 192.2 3300.00 3192.14 MinPt-0-SF 20203.70 20141.22 20110.47 328.50 12586.52 3828.65 TD OP05-06(Det Survey) Pass 12565.91 1250769 12479.22 220.62 0.00 0.00 Surface I 11575.201 11516.881 11488.60 204.56 2800.00 2724.55 MinPts 11580.53 11522.16 1149384 204.45 2900.00 282314 MinPt-0SF 11691.64 11632.99 116044 2056 3300.00 3192.14 MinPt-0-SF 2047242 20408.30 20376.73 32424 12586.52 3828.65 TD 0124-08(P10b)(Def Plan) Pass 12518.26 12297.58 12187.76 56.99 0.00 0.00 Surface I 11612.231 11385.681 11273.22 51.62 3800.00 3592.80 MinPts 11627.34 11400.17 11287.46 51.571 4100.00 3772.73 MinPt-0SF 11949.801 11655.731 11509.18 40.77 5300.00 3950.45 MinPts 12050.48 11752.12 1160344 40.521 6026.50 3928.37 MinPt-0SF 14380.39 14074.07 13921.69 47.18 12586.52 382865 TD Oliktok Point I-2PB2(Dot Survey) Pass 12557.02 1243567 12376.40 105.92 0.00 0.00 Surface 11623.46 11497.63 11436.40 94.901 2800.00 272455 MinPt-0SF I 11613.421 11488.031 11427.05 95.20 3100.00 3014.16 MinPts 18411.78 18297.31 18240.57 162.23 12586.52 3828.65 TD 0111-01 PB1(Def Survey) Pan 13391.72 13370.32 13358.92 N/A 0.00 0.00 Surface 1 12415.311 12394.691 12382.50 N/A 2800.00 2724.55 MinPts 13028.10 13001.49 12989.91 562.62 4400.00 3889.50 MinPt-0SF 13916.26 13888.63 13876.2 5400.00 3940.94 MinP1-0SF 20137.43 2008581 20060.50 397.70 12079.07 3833.35 MinPt-0SF 20615.11 20561.51 2053520 391.77 12586.52 3828.65 MinPt-0SF OP05-06P82(Def Survey) Pea 13406.54 13352.12 13325.69 253.60 0.00 0.00 Surface 1 12423291 12369.821 12344.121 241.571 2800.00 272455 MinPts 21418.72 21361.00 21332.63 377.49 12586.52 3828.65 TD Oliktok Point I-1A-106(P5)(Def Plan) Pass 13515.80 13345.10 13260.72 80.07 0.00 0.00 Surface I 12563.89 12386.741 12299.04 71.62 2800.00 2724.55 MinPts 12569.36 12392.05 12304.27 71.591 2900.00 2823.14 MinPt-0SF 21356.57 21179.05 21091.10 121.40 12586.52 3828.65 TD OP22-W W 03(P1)(Def Plan) Pass 14827.79 14781.15 1475846 326.70 0.00 0.00 Surface I 12613.161 12561.761 12538.52 271.23 3600.00 3443.66 MinPts 12870.98 12816.36 1279168 260.711 4400.00 388950 MinPt-0SF 20190.16 20119.01 20084.85 295.44 12586.52 3828.65 TD OP23-W W02(Def Survey) Pass 14326.42 14290.19 14273.52 429.57 0.00 0.00 Surface 1 12625.00 12587.19 1257072 383.08 3200.00 3105.13 MinPt-CtCt 1262502 12587.101 1257059 382.14 329544 3188.27 MinPts 13045.34 1300428 12986.17 359.991 4400.00 3889.50 MinPt-0SF 20807.52 20757.99 20733.72 428.60 12586.52 3828.65 TD OP18-08(Def Survey) Paa 13732.34 13523.72 13419.95 66.16 0.00 0.00 Surface 12878.28 MERE�. '-, 60.26 3700.00 3520.80 MinPts 12924.67 12695.7: 4200.00 3819.16 MinPts 12982.2. 12699.01�:/ 4599 4500.00 3912.88 MinPts 12989 71 12696.1: 12549.91 4440 4700.00 3935.49 MINPT-0-EOU 12994.8. 12696.4. 12547.78 43.69 5000.00 3951.19 MINPT-0-EOU 12995.52 12696.68 IMEM 43.63 5041.58 3953.36 MinPt-0-ADP 13446.10 13122.47 12961.15 mms 7976.84 3940.17 MinPt-0-SF Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI20-N4\SI20-N4\SI20-N4(P6) 1/30/2012 10:48 AM Page 8 of 9 Offset Trajectory Separation Allow Sep. Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor IMajor 14979.80 14642.30 14474.04 44.51 12586.52 382865 TD 0P18-08PB2(Def Survey) Pass 13732.34 13523.77 13420.02 66.18 0.00 0.00 Surface 1 12878.281 12663.29 12556.47 60.27 3700.00 3520.80 MinPts 12924.67 12695.83 12581.98 56.74 4200.00 3819.16 MinPts 12976.831 12694.97 12554.5346.20 4500.00 3912.88 MinPts 13072.39 12786.24 12643.66. 45 5372.08 3943.78 MinPt-OSF 13157.61 12869.57 12726.04 45e 5800.00 3929.61 MinPt-0SF 15765.58 15461.67 1531020 52.04 12586.52 382865 TD OP16-03(Def Survey) Pass 14345.20 14144 38 14044.46 71.78 0.00 0.00 Surface 1 13528.571 13324.461 13222.93 66.62 3700.00 3520.80 MinPts 13563.72 13358.32 13256 19 66 401 4100.00 3772.73 MinPt-OSF 13842.731 13555.68 13412.64 48.39 4971.58 3949.70 MinPts 14313.55 14009.42 13857.85 47 211 7700.00 3944.94 MinPt-O-SF 16056.08 15733.03 15571.99 49 85 12586.52 3828.65 TD OP26-DSPO2(Del Survey) Pass 14881.53 14859.50 14848.72 N/A 0.00 0.00 Surface 1 13801.271 13578.051 1356842 705.55 3100.00 3014.16 MinPts 14069.79 14039.83 14026.71 535.89 4400.00 3889.50 MinPt-O-SF 14924.13 14893.12 14879.22,- 537.02 5372.08 3943.78 MinPt-OSF 21172.16 21119.53 21093.71 409.94 12079.07 3833.35 MinPt-O-SF 21649.04 21594.49 21567.71 404.19 12586.52 3828.65 MinPt-O-SF Oliktok Point I-2P51(Def Survey) Pass 14779.16 14696.46 14656.30 183.98 0.00 0.00 Surface 13875.23 13790.34 13749.301 169.031 2700.00 2624.89 MinPt-O-SF 1 13887.741 13782.941 13741.96 169.16 2900.00 2823.14 MinPts 21232.23 21138.07 21091,48 227.86 12586.52 3828.65 TD 0120-07(P14)(Def Plan) Pass 15611.14 15440.93 15356.35 9229 0.00 0.00 Surface 1487465 14694.861 14605.581 83.27 3500.00 3361.97 MinPts 14875.63 14604.05 14468.75 54.97 4100.00 3772.73 MinPt-CtCt 1487863_ 1460397 14467.13 54.36 4200.00 3819.16 MinPts 15004.23 1467823 14515.73 46.16 5100.00 3955.58 MinPts 15035.35 14647.88 14454.64 38.90 5300.00 3950.45 MinPts 15333.06 14917.38 14710.03 36.971 7495.23 3948.26 MinPt-0SF 16842.62 16413.07 16198.78 39.30 12586.52 3828.85 TD OP21-W W01(P3)(Def Plan) Pass 17112.63 17049.51 1701844 275.40 0.00 0.00 Surface 1 15656.481 15592.741 15561.96 254.35 3100.00 3014.16 MinPts 15868.89 15803.91 15772.51 252. 4000.00 3719.25 MinPt-O-SF 16147.68 16081.90 16050. 253. 4400.00 3889.50 MinPt-O-SF 23970.24 23894.10 23856.52 318.91 12586.52 3828.65 TD Nikaitchuq 2(Def Survey) Pass 15963.9 15962.0 15931.11 N/A 0.00 0.00 MinPts 15713.36 15703.10 15680.55 N/A 2400.00 2324.96 MinPts 1662452 16596.24 16582.91 623.5 4400.00 3889.50 MinPt-OSF 22984.12 22894.73 22850.85 261.85 12586.52 3828.85 MinPt-O-SF OP03-P05PB1(Def Survey) Pass 16732.69 1669405 16675.56 45256 0.00 0.00 Surface 1 15830.841 15791.491 15772.84 424.38 2800.00 2724.55 MinPts 16576.31 16534.48 1651424 409.521 4400.00 3889.50 Min1.60SF 24524.88 24472.56 24446.89 477.69 12586.52 3828.65 TD OP18-08PB1(Def Survey) Pass 17615.09 17602.94 17582.29 N/A 0.00 0.00 Surface 1 17100.241 17087.361 1706743 N/A 2400.00 2324.96 MinPts 25314.67 25257.64 25229.64 452.011 12586.52 3828.65 MinPt-0SF Oliktok Point I-1(Def Survey) Pass 17832.32 17831.21 17799.52 N/A 0.00 0.00 Surface MEMO EIEDE II= 704.17 2500.00 2424.90 MinPts 18119.10 18088.36 18073..: 608.9. 4400.00 3889.50 MinPt-0SF 19536.76 19505.12 19489.7-MEM 5938.50 3928.07 MinPt-0SF 20024.74 19992.23 19976.41 6459.00 3929.10 MinPt-OSF 2194747 21909.99 21891.7-1. 8500.00 3909.31 MinPt-O-SF 22231.94 22193.67 22175.0•mom 8800.00 3902.44 MinPt-O-SF 25707.57 25653.47 25626.91 man 12586.52 3828.65 MinPt-O-SF OP05-06P61(Def Survey) Paas =MR 17837.5, 17805.96 N/A 0.00 0.00 MinPts ME=MEM 17399.95 N/A2300.00 2225.34 MinPts 18277.53 18253.33 18241.7.=MI4400.00 3889.50 MinPt-0SF 19616.85 19589.79 19576.: 1u. 5900.00 392850 MinPt-O-SF 25727.16 25672.21 25645.23 476.69 12586.52 3828.65 MinPt-O-SF Drilling Office 2.5.1100.0 Nikaitchuq\Spy Island\SI20-N4\S120-N4\S120-N4(P6) 1/30/2012 10:48 AM Page 9 of 9 I x D 1 I5'5 5/11• I PIva ` _ a •.‘ 5 . hi .. __AV _ -•—ti-s-U- ----r--• AEI' I z T. i ( < ' I 6 AMI m Mp a �i �n lIi � �_ I 1I,• ii _iiIll 1111 I—u—} �I Z p V _ 1111 -- 11"1 ill I I, --- . :FL. . 7 4 - Z A.ZT1- r l'.Zln 3 W G7 _ -� - Cin /_ '}\y� O V Z X we �l m[�- dd .. C Q. N y E. ^� y ZCnC \�ll T.cx 0 V 6 k oZ - ocn� o -� - NUo A H\\,!, xi 0 IA z r N CI= • N > Z m I i 0 0& 04 1 0 1 yy rn m Z O v m U ? w N Oc Z O CO O co 03 n r wp9 O �g Z II o N D m .q r A m N fr*1 1 0� 9 0 °•O; � O� . 0" c 0' m > m z ZN v O p M N N O _ O ED� nm N O� Q C : - N g� gE$g -' E9 J• _ _. _. G G) > m C N n xi _m -r (111111 z 'o 77, F A o 3; i c i;•••m �� i s mom ra -73 n mP. n w A V y.- —El._,, 0 u-1f N N - c113 ; N N N N N N N N N O O O O O O O O O p O 0 W V�0 �(0 c CO V O)()IAGIN-• (O Co V 0)(nA W NS (O W 0) V (n AN� • LA IQ W N� O W V 0)(n. I.' a3 D a 3 o 0 s 0)0)0)a,a mONN CP(P(n Cn(P CP(P 01(n 0)U Cn(n(n CP(n(P Cn A A A A A A A A AA A A A A A A A A v m 1 O j, WNN-'—OOcoE Co OD V V O)0)(nNAWC.i.+N N�-•00(O k Co Co V',Con rn U 6,in tjj?W(.+N iv-• N3 0 3 N V N V CA 03 CN O) CO CA COW NCA 00 CA CO CO A(O A O ACO ACO (0 A(O ACO ACO A O, O(n O CP O(P 3 ,n 3 0 F,..C N I 6 if (O in C I P 1 �QN U U `s a) id c ; m o e ct a V V V v O 0)a,m O)O O>O>0)al N N(n(n 9,U(li U(P A A A A A A A A AA W CA CA W YC.+(.+CA CA W N c y �� `2,1'5 (.+N— (Obo V ON A C.+N— (0 00 V 0)�AWN— CON V en A W N— CO OO V O)OA W N— (O m co 0$ iit o b o c �� O Oo CO CO O]CO W CO CO W OJ W W V V V V V V V V V V V V V V V V v V V V O)0)0)0)0)0)0)0)0)0)0)0)m 9 m L C 0 (n(nAACA .o NNat OOOCOCO Oo Oo VVI O)(n in A A W W N N W-,00<O ro Oo W V V�son(n in A A W NmQ y y 8 (nONOC,O(n0 OCnONOU_.0)_. _.0)-,m-0)-,0)-` —0)-.V N V N V N N V N V N V 3 C mm m N y 9$1 n i4 1 " 'ANm ii) w comma) n D m V It 43 a ED W N W 2 W D zxi zg rneaftm G °° � �_► rrt 3 2 3 3 3 3 "• c ,D coo 43 - = _ 2 3 0) m.3 a 73N D xi- O6 � a Z coC— su ,co 0 r < o n m — ,,.- 5 Q < p) M < eo CA0< al g g 2 co W CD A z O. m dFit 0 Q O Eli rp 0 11 4 lit� � >1111111 iiimi , © h , fiii Air pit . . 0 ,.. ... Air ... Likii —At. Oli"--4 ° .. , ei lik TWIP 'r Ili I a) Z a • o Ivy _ Mt Jr ill co in a tic VO Y111, NI e A NNW Mk Schlumberger CemCAD E* well cementing recommendation for Kick-OFF-Plug OBM Operator : Eni Petroleum Well : S120-N4 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Nabors 245E Proposal No. : Draft v1 Service Point : Prudhoe Bay Alaska Date Prepared : 02-9-2012 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:2559.0 ft OD:13 3/8 in Weight:68.0 lb/ft Drill Pipe MD:3100.0 ft OD:5 in Weight:19.5 lb/ft Casing/liner Shoe MD 4325.0 ft Mud Line 0.0 ft Total MD 4325.2 ft BHST 59 degF Bit Size 12 1/4 in Mean OH Diameter 12.250 in Mean Annular Excess 15.0% Mean OH Equivalent Diameter 12.482 in Q� fi- Total OH Volume 267.3 bbl (including excess) `ym� C7 4 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 inferred and no intellectual property rights are granted hereby. *Mark of Schlumberger Page 1 S120-N4 Pilot hole vt 2-6-12.cfw;02-10-2012, LoadCase KOP Plug;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 SchI bergcr String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug Section 1 : fluid sequence Job Objectives: Set Kick-Off-Plug to allow sidetracking within 100'of the shoe. Original fluid Faze Pro Mud 9.30 lb/gal Pc:34.921 cP Ty: 16.10 lbf/100ft2 Displacement Volume 55.1 bbl Drill Pipe Volume 55.1 bbl Total Volume 258.0 bbl TOC 2420.4 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) Citric Pill 40.0 318.9 1543.5 9.80 k:5.16E-5 Ibf.s^n/ft2 n:1.000 Tv:0.46 Ibf/100ft2 MUDPUSH II 70.0 558.0 1862.4 10.10 k:2.54E-2 lbf.sAn/ft2 n:0.420 Ty:13.04 Ibf/100ft2 KOP Pilot 93.0 679.6 2420.4 17.00 Pv:236.284 cP Ty:27.13 Ibf/100ft2 KOP Pilot 12.1 2420.4 17.00 Pv:236.284 cP Ty:27.13 Ibf/100ft2 MUDPUSH II 9.9 1862.4 10.10 k:2.54E-2 lbf.s^n/ft2 n:0.420 Ty:13.04 Ibf/100ft2 Citric Pill 5.7 1543.5 9.80 k:5.16E-5 lbf.s^n/ft2 n:1.000 Tv:0.46 Ibf/100ft2 Faze Pro Mud 27.4 0.0 9.30 Pv:34.921 cP Ty:16.10 Ibf/100ft2 Static Security Checks: Frac 201 psi at 3100.0 ft Pore 196 psi at 2559.0 ft Csg.Pump out 25 ton Check Valve Diff Press 0 psi Page 2 3120-N4 Pilot hole v1 2-6-12.cfw;02-t0-2012; LoadCase KOP Plug;Version wcs-cem471_02 ow Client : Eni Petroleum Well : S120-N4 Schlumberger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug * CemCADE Client :Eni Petroleum Well :S120-N4 String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA ft lb/gal O 8 9 10 1I1 12 13 - —Hydrostatic —Mn.Hydrostatic O - —Max.Dynamic 0 —Mn.Dynamic — Frac —Fbre O - O- O - L— oi - v m O - O 3 N C 00 - N - E Oili _ NNN/ O U O o M - N O 3 O u - 00 in - 0 Fluid Sequence Dynamic Well Security E. e z N IIICitricRII 45.7 bbl 9.80 lb/gal Herschel:k =5.16E-5 Ibf.s^n/ft2 n =1.000 Ty=0.46 Ibf/100ft2 ■MUDPUSH II 79.9 bbl 10.10 lb/gal Herschel:k =2.54E-2 Ibf.s^n/ft2 n =0.420 Ty=13.04 Ibf/100ft2 7 KOP Riot 105.0 bbl 17.00 lb/gal Bingham:PV=236.284 cP Ty=27.13 Ibf/100ft2 ■Faze Fro Mud 27.4 bbl 9.30 lb/gal Bingham:PV=34.921 cP Ty=16.10 lbf/100ft2 Total Depth = 4325.2 ft Top of Cement= 2420.4 ft *Mark of Schlumberger SCIIMIIIIPP Page 3 S120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase KOP Plug;Version wcs-cem471_02 y Client : Eni Petroleum Well : S120-N4 Schilirger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug Section 2: fluid description Faze Pro Mud DESIGN Fluid No: 1 Density :9.30 lb/gal Rheo. Model : BINGHAM Pv :34.921 cP At temp. : 120 degF Ty : 16.10 Ibf/100ft2 Gel Strength :8.54 lbf/100ft2 MUD Mud Type : OBM Job volume :27.4 bbl Water Type : Fresh VOLUME FRACTION Solids : 11.5% Oil :59.0°Ao Water : 29.5% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. : 65 degF n :0.420 Ty : 13.04Ibf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :79.9 bbl Citric Pill DESIGN Fluid No:6 Density :9.80 lb/gal Rheo. Model : HERSCHEL_B. k : 5.16E-5 lbf.sAn/ft2 At temp. :86 degF n : 1.000 Ty :0.46 lbf/100ft2 Gel Strength :0.00 Ibf/100ft2 MUD Mud Type :WBM Job volume :45.7 bbl Water Type : Fresh VOLUME FRACTION Solids : 11.0% Oil : 0.0% Water : 89.0% Page 4 SI20-N4 Pilot hole v1 2-6-12.ciw,02-10-2012, LoadCase KOP Plug,Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 3cbloberger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug KOP Pilot DESIGN Fluid No:7 Density : 17.00 lb/gal Rheo. Model : BINGHAM Pv :236.284 cP At temp. :66 degF Ty :27.13 Ibf/100ft2 Gel Strength :74.18 lbf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid : 3.863 gal/sk Job volume : 105.0 bbl Dry Density : 199.77 lb/ft3 Yield : 1.01 ft3/sk Quantity : 586.71 sk Sack Weight :94 lb Solid Fraction :48.6% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 3.863 gal/sk Additives Code Conc. Function D046 0.200%BWOC Antifoam D065 1.000%BWOC Dispersant D167 0.200%BWOC Fluid loss S002 0.400%BWOC Accelerator Page 5 S120-N4 Pilot hole v1 2-6-12 cfw.02-10-2012: LoadCase KOP Plug,Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 ScMlolierger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug Section 1 : pumping schedule Start Job: Spot 44 bbl Hi Vis 14 ppg pill at 3400', POOH to 3100' Circulate Bottoms Up Have safety meeting with all involved parties. There are a lot of fluid swaps, ensure that enough personell are available and understand the sequence of fluids that will need to occur. Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) Citric Pill 5.0 40.0 8.0 40.0 80 Citric Pill Ahead Pause 0.0 0.0 2.0 0.0 80 Swap to Spacer MUDPUSH II 5.0 70.0 14.0 70.0 80 Spacer Ahead Pause 0.0 0.0 5.0 0.0 80 Weight Up Tub KOP Pilot 3.0 105.0 35.0 105.0 80 Mix&Pump KOP Slurry Pause 0.0 0.0 3.0 0.0 80 Swap to Spacer MUDPUSH II 5.0 9.9 2.0 9.9 80 Spacer Behind Pause 0.0 0.0 2.0 0.0 80 Swap to Citric Pill Citric Pill 3.0 5.7 1.9 5.7 80 Citric Pill Behind Pause 0.0 0.0 3.0 0.0 80 Swap to Mud Faze Pro Mud 8.0 27.4 3.4 27.4 80 Displace to Balance Total 01:19 hr:mn 258.0 bbl End Job: Pull out slowly from the plug; circulate full bottoms up at 2400', drop wiper balls to clean the pipe, inspect tool joints for residual cement. Dynamic Security Checks: Frac 167 psi at 3100.0 ft Pore 110 psi at 2559.0 ft Temperature Results BHCT 55 degF Simulated Max HCT 77 degF Simulated BHCT 77 degF Max HCT Depth 3100.0 ft CT at TOC 75 degF Max HCT Time 00:56:38 hr:mn:sc Static temperatures: At Time (hr:mn) 1 (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 45 degF Bottom Hole (degF) (degF) 59 degF Page 6 S120-N4 Pilot hole v1 2-6-12.cfw,02-10-2012; LoadCase KOP Plug:Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug WELL DATA Well Data Job Type: Kick-off Plug Rig Type: Land 75' ft Total Depth(Measured): 4325 ft ---- - True Vertical Depth(TVD): 4249.9 ft TOC in pipe before POOH: 2420.4 ft TOC in annulus before POOH: 2420.4 ft 11 ' ft 14 "ft 151. ft Open Hole Bottom Depth Mean Calliper Mean Excess Mean Equiv. 17' i ft Diameter Diameter 18. ,"f} 4325 ft 12.25 in 15% 12.478 in 22-- ' - Drill Pipe 24. 1 ft Bottom Measured OD ID Weight 25' , ft Depth '"' 3100 ft 5 in 4.276 in 19.5 Ibm/ft 2�i 2ft Casing Oft _ Bottom Measured OD ID Weight Depth 2559 ft 13.375 in 12.415 in 68 Ibm/ft l ft 493 ft :4'Z ft 48 ft Page 7 i 0120-N4 Pilot hole v12-6-12.cfw-02-10-2012. LoadCase KOP Plug.Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 3tiIsierger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug FORMATION DATA Formation Data MD Top MD Pore Top Pore Frac Top Frac Name/ Res.Fluid Bottom Bottom Bottom Lithology 0 ft 755 ft 0 psi 328 psi 0 psi 443 psi Siltstone 755 ft 1137 ft 328 psi 489 psi 443 psi 670 psi Sandstone 1137 ft 1412 ft 489 psi 602 psi 670 psi 823 psi Shale 1412 ft 1750 ft 602 psi 741 psi 823 psi 1029 psi Coal 1750 ft 1937 ft 741 psi 819 psi 1029 psi 1166 psi Sandstone 1937 ft 2253 ft 819 psi 955 psi 1166 psi 1392 psi Sandstone 2253 ft 2559 ft 955 psi 1090 psi 1392 psi 1613 psi Shale 2559 ft 2882 ft 1090 psi 1232 psi 1613 psi 1823 psi Sandstone 2882 ft 3521 ft 1232 psi 1513 psi 1823 psi 2238 psi Coal 3521 ft 4030 ft 1513 psi 1736 psi 2238 psi 2568 psi Sandstone 4030 ft 4082 ft 1736 psi 1759 psi 2568 psi 2602 psi Sandstone 4082 ft 4178 ft 1759 psi 1801 psi 2602 psi 2664 psi Sandstone 4178 ft 4295 ft 1801 psi 1852 psi 2664 psi 2740 psi Sandstone 4295 ft 4325.3 ft 1852 psi 1866 psi 2740 psi 2760 psi Shale Absolute Formation Pressure Pressure,psi 0 1000 2000 3000 2475 - 2723 - 2970 - \\a 3218 - —Pore °'3465Frac z 3713 - 3960 - 4208 - Equivalent Density Formation Pressure Page 8 S120-N4 Pilot hole v1 2 6-12.c1w;02.10-2012; LoadCase KOP Plug;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 ScMIMerger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug Equivalent Density,Ibmlgal 0 2 4 6 8 10 12 I 1 2475 - 2723 2970 - 3218 - —Pore ar 3465Frac S" osos 3713 3960 - 4208 - Page 9 S120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase KOP Plug;Version wcs-cem411_02 Client : Eni Petroleum Well : S120-N4 Schhoberger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug FLUIDS DATA Fluids Data Name Type Density, Model Consistency, Power Ty, Gel Ibm/gal Ibf.s^n/100ft Index lbf/100ft2 Strength, 2 Ibf/100ft2 Faze Pro Mud MUDI 9.3 Bingham 0.07293 1 16.1 8.54 MUDPUSH II SPACER 10.1 Herschel-B. 2.53688 0.42 13.04 0 Citric Pill MUD 9.8 Herschel B. 0.00516 1 0.46 0 KOP Pilot SLURRY 17 Bingham 0.49349 1 27.13 74.18 PLACEMENT VOLUMES Placement Summary Volume Optimization Custom Plug Length 650 ft Plug top MD after POOH 2450 ft Plug Volume 105.04 bbl Original Fluid Faze Pro Mud Underdisplacement Volume 0 bbl Drill Pipe Volume 55.06 bbl Fluid Sequence Name Balanced Volume, Annular Top MD,ft Density, Length,ft bbl Length,ft Ibm/gal Faze Pro Mud 193.6 1543.5 0 9.3 1543.5 Citric Pill 40 318.9 1543.5 9.8 318.9 MUDPUSH II 70 558 1862.4 10.1 558 KOP Pilot 93 679.6 2420.4 17 679.6 KOP Pilot 12.1 0 2420.4 17 679.6 MUDPUSH II 9.9 0 1862.4 10.1 558 Citric Pill 5.7 0 1543.5 9.8 318.9 Faze Pro Mud 27.4 0 0 9.3 1543.5 Page 10 S120-N4 Pilot hole v1 2-6-12.cfw,02-10-2012; LoadCase KOP Plug;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug STATIC PULL OUT OF HOLE (POOH) POOH Summary Final drill pipe shoe depth after POOH: 1248.94 ft Length of uncontaminated cement after POOH: 650 ft Length of contaminated cement after POOH: 0 ft Top MD of uncontaminated cement after POOH: 2450 ft POOH Simulation Results Interfaces in annulus Interfaces in pipe 7 ft 721 7,1 19 ft L 1 2ft 1442 i - 1442 1 1ft 1 ft v: 1f u a 2163 2 3 ft _. 1F_. v a a 7. 2 9f r m I 2883 2 2ft ia ,..:4 ft 3604 1 ft 3604 4Q 0 ft 4325 :4,1: S ft 4325 3100 2637 2174 1712 1249 - 3100 2637 2174 1712 1248 Shoe Depth MD,ft Shoe Depth MD,ft Page 11 S120-N4 Pilot hole v1 2-6-12.cfw,02-10-2012; LoadCase KOP Plug;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Scblmbergcr String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug PLACEMENT Pumping Schedule Fluid Name Flow Rate, Volume,bbl Time,min Backpressure, Cumulative bbl/min psi Time,min _ Citric Pill 5 40 8 0 8 Pause 0 0 2 0 10 _ MUDPUSH II 5 70 14 0 24 Pause 0 0 5 0 29 - KOP Pilot 3 105.04 35.01 0 64.01 Pause 0 0 3 0 67.01 _ MUDPUSH II 5 9.91 1.98 0 69 Pause 0 0 2 0 71 _ Citric Pill 3 5.66 1.89 0 72.88 Pause 0 0 3 0 75.88 Faze Pro Mud 8 27.42 3.43 0 79.31 Well Security Pressure,psi 0 331 662 993 1325 1656 1987 2318 2649 2980 0.00 r r - r r I r --_., 200.00 400.00 600.00 . 800.00 1000.00 1200.00 1400.00 1600.00 1800.00 a 2000 ®Pore Pressure,psi in Annulus 1 220100 Frac Pressure,psi in Annulus 2400A0 Min Pressure,psi r Annulus \,, Max Pressure,psi in Annulus 2600.00 Min Static Pressure,psi in Annulus 2800.00 Max Static Pressure,psi in Annulus 3000.00 '.., 3200.00 3400.00 3600.00 3800.00 4000.00- 4200.00 4400.00 460000 Min annular pore security 12%(224.7psi)at MD=4325ft. Min annular frac security 7.9%(155.2psi)at MD=3111.1ft. Min annular static pore security 10.1%(123.2psi)at MD= 2865ft. Min annular static frac security 10.3%(202.4psi)at MD= 3111.1ft. Page 12 S120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase KOP Plug.Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Sekl ierger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug FLUID MIXING BEFORE POOH Fluid Mixing at the end of placement Annulus Mixing Slurry in Annulus Pipe Mixing Slurry in Pipe Legend Zones Contamination Risk Zones Contamination Risk 0 Slurry Contamination Risk El No Slurry High Contamination Risk Medium Contamination Ri Low Contamination Risk 600- 600- nDD 600- 1200- 1200- 1200 1200- • 1850 1850- i:=50 1850- 2450 2460 2450 2450- Fluids IN Faze Pro Mud MUDPUSH II NI Citric Pill • S KOP Pilot 3100 • 3100 :100 3100 Slurry Contamination Risk Pipe High:423 ft Medium:100 ft Low:616 ft Annulus High:108 ft Medium:15 ft Low:659 ft Page 13 0120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase KOP Plug;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schimberg"r String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug FINAL MIXING RISKS AFTER PLACEMENT AND POOH Target Slurry after POOH To of Cement Contamination Risk 2056 2056 225D 2250 2460 Target TOC 2460 2446 ft 2450 ft 2465 ft 2650 2650 2850 2850 3100 3100 2385 ft<Target TOC<2515 ft 2449 ft<Top MD of Cement after POOH<2465 ft Page 14 S120-N4 Pilot hole v1 2-6-12.cfw,02-10-2012; LoadCase KOP Plug:Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumllrgcr String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : KOP Plug Section 2: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name G 55151 lb 587 sack 94 lb D182 443 lb 18 sack 251b D046 126 lb 3 sack 50 lb D031 7613 lb 70 sack 110 lb D065 552 lb 12 sack 50 lb D167 110lb 5 sack 251b S002_ 221 lb 3 sack 100 lb Mix Water Requirements : Fresh water 5371 gal MIXING PREPARATION MUDPUSH II Volume :79.9 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 73.906 bbl D182 443.439 lb 6.000 lb/bbl of base fluid D046 15.982 lb 0.200 lb/bbl of spacer D031 7613.041 lb 95.27 lb/bbl of spacer KOP Pilot Volume : 105.0 bbl Density : 17.00 lb/gal Yield : 1.01 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 54.0 bbl 10.0 bbl LAS Design G 55151.090 lb Fresh water 53.964 bbl 10.001 bbl D046 110.302 lb 0.200%BWOC D065 551.511 lb 1.000%BWOC D167 110.302 lb 0.200%BWOC S002 220.604 lb 0.400%BWOC Page 15 5120-N4 Pilot hole v1 2-6-12.ciw:02-10-2012. LoadCase KOP Plug,Version wcs-cem471_02 Schlumberger CemCAD E*well cementing recommendation for 9 5/8" Intermediate Casing Operator : Eni Petroleum Well : S120-N4 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Doyon 15 Proposal No. : Draft v1 (P6) Service Point : Prudhoe Bay Alaska Date Prepared : 02-10-2012 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 .GN n • 04. UATE 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 Iran infringement of any intellectual property rights of Schlumherger or others is not to be inferred and no intellectual property rights are granted hereby. k Mark of Schlumberger Client : Eni Petroleum Well : S120-N4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 50.0 ft Total MD : 4771.1 ft BHST : 85 degF Bit Size : 12 1/4 in ft Iblgal c_ ( ) 8 12 16 Frac _ _SIltstone — Pare f - •Sandstone•.•; U Shale • • • • •Sandstone• • • o Shale _ I. Shale Coal U — \14\1 I Shale M Shale III - Shale I Q 4 Well Lithology Formation Press. Page 2 si20-n4 v12-10-12.cfw;02-10-2012; LoadCase 95/8 FP;Version wcs-cem4/1_02 Client : Eni Petroleum Well : S120-N4 SW11110 81 String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2559.0 13 3/8 68.0 12.415 Landing Collar MD : 4691.0 ft Casing/liner Shoe MD : 4771.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 4771.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 BTCM Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 384.1 bbl (including excess) Max. Deviation Angle : 87 deg Max. DLS : 5.041 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 10.7 155.0 0.000 761.9 748.6 10.7 155.0 0.000 1137.0 1111.5 18.2 155.0 2.000 1413.2 1370.0 22.9 155.0 1.691 2006.8 1930.6 15.2 155.0 -1.296 2337.4 2255.6 5.3 155.0 -3.000 2660.0 2577.6 0.0 282.3 -1.643 2700.0 2617.6 2.0 282.3 5.000 2800.0 2717.3 7.0 282.3 5.000 2881.8 2798.1 11.1 282.3 5.001 2900.0 2815.9 12.0 282.3 4.997 3000.0 2912.7 17.0 282.3 5.000 3100.0 3006.9 22.0 282.3 5.000 3200.0 3097.9 27.0 282.3 5.000 3295.4 3181.0 31.8 282.3 4.998 3300.0 3184.9 31.8 282.3 -0.000 3400.0 3269.9 31.8 282.3 0.000 3467.2 3327.0 31.8 282.3 0.000 3500.0 3354.7 33.1 284.1 4.993 3600.0 3436.4 37.3 288.7 5.004 3621.3 3453.2 38.3 289.6 5.004 3700.0 3513.5 41.7 292.6 5.001 3800.0 3585.5 46.2 295.8 4.996 3900.0 3651.8 50.7 298.6 4.999 4000.0 3712.0 55.3 301.0 4.998 4030.0 3728.7 56.7 301.7 5.034 4082.4 3756.5 59.2 302.8 4.980 4100.0 3765.5 60.0 303.1 5.041 4177.6 3802.1 63.6 304.7 4.997 4200.0 3811.9 64.7 305.1 4.984 4294.7 3849.0 69.1 306.9 5.004 4300.0 3850.9 69.4 307.0 4.959 4400.0 3882.2 74.1 308.7 5.004 4444.1 3893.5 76.2 309.4 4.996 Page 3 si20-n4 v12-10-12.cfw,02-10-2012; LoadCase 95/8 FP;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4500.0 3905.6 78.8 310.3 4.999 4600.0 3920.8 83.6 311.9 5.003 4671.6 3926.7 87.0 313.0 4.995 4700.0 3928.2 87.0 313.0 0.000 4771.1 3931.9 87.0 313.0 0.000 . Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 755.0 11.35 8.39 SV-4 Siltstone 1137.0 11.50 8.40 SV-3 Sandstone 1412.0 11.50 8.41 SV-2 Shale 1750.0 11.70 8.42 Permafrost Base Sandstone 1937.0 11.70 8.42 SV-1 Sandstone 2253.0 12.30 8.44 Ugnu Top(UG4) Shale 2559.0 12.50 8.45 Surface Shoe Shale 2903.0 12.60 8.50 UG-2 Coal 3621.0 12.70 8.50 Lower Ugnu Shale 4030.0 12.70 8.50 Schrader Bluff Top Shale 4082.0 12.70 8.50 N Seq.Top Sandstone 4176.0 12.70 8.50 N Sand Top Sandstone 4295.0 12.70 8.50 N Sand Bottom Sandstone 4444.0 12.70 8.50 N Seq Bottom Sandstone 4771.1 12.70 8.50 TD Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1750.0 1684.9 32 0.7 4771.1 3931.9 85 1.7 Page 4 si20-n4 v1 2-10-12.cfw,02-10-2012, LoadCase 9 5/8 FP,Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Seklintiergnr String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP ft degF deg o_ 0 :lll 60 90 0 "IF 60 90 Geoth.Profile l I — Deviation I I Tubular Fluids tnnulus —±—ist— I Q I Q- -� a l Temp. Profile At 123 min Deviation Page 5 si20-n4 v12-10-12.cfw;02-10-2012; LoadCase 9 5/8 FP;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Srhlimierger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 2: fluid sequence Job Objectives: Cement coverage verifiable to 1000'above the top of the N-Sand (TOC 3178') Original fluid Mud 9.45 lb/gal k:4.32E-3 Ibf.s^n/ft2 n :0.760 Ty:8.18 Ibf/100ft2 Displacement Volume 343.4 bbl Total Volume 598.4 bbl TOC 3167.8 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (Ib/gal) Citric Pill 35.0 585.9 1486.6 9.50 k:9.93E-3 Ibf.s^n/ft2 n:0.575 Ty:13.59 Ibf/100ft2 MUDPUSH II 80.0 1095.3 2072.5 10.50 k:4.65E-2 Ibf.s^n/ft2 n:0.355 Ty:11.47 lbf/100ft2 LiteCRETE 140.0 1603.2 3167.8 12.50 k:5.36E-2lbf.s^n/ft2 n:0.564 Ty:1.87 lbf/100ft2 Mud 343.4 0.0 9.45 k:4.32E-3lbf.s^n/ft2 n:0.760 Ty:8.18 lbf/100ft2 Static Security Checks: Frac 357 psi at 2559.0 ft Pore 154 psi at 2559.0 ft Collapse 4399 psi at 4691.0 ft Burst 6846 psi at 50.0 ft Csg.Pump out 73 ton Check Valve Diff Press 172 psi Page 6 si20-n4 v12-10-12 cfw;02-10-2012, LoadCase 95/8 FP,Version wcscem471_02 Client : Eni Petroleum Well : S120-N4 ScI �rg�r String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP CemCADE Client :Eni Petroleum Well :S120-N4 String :9 5/8"Intermediate Casing District :Prudhoe Bay Alaska Country :USA lb/gal ft O 8 9 10 11 12 13 —Hydrostatic —Mn.Hydrostatic —Max.Dynamic — Mn.Dynamic — Frac — R,re o — I I N E Y _ e O O— a-. fh m (O - oo O _ OZ U O - CV Fluid Sequence Dynamic Well Security ■Citric RII 35.0 bbl 9.50 lb/gal Herschel:k=9.93E-3 bf.s^n/ft2 n=0.575 Ty=13.59 Ibf/100ft2 ■MUDPLJSH II 80.0 bbl 10.50 lb/gal Herschel:k=4.65E-2 bf.s^n/ft2 n=0.355 Ty=11.47 Ibf/100ft2 ■LiteCRETE 140.0 bbl 12.50 lb/gal Herschel:k=5.36E-2 bf.s^n/ft2 n=0.564 Ty=1.87 Ibf/100ft2 ■Mud 343.4 bbl 9.45 lb/gal Herschel:k=4.32E-3 bf.s"n/ft2 n=0.760 Ty=8.18 Ibf/100ft2 Total Depth = 4771.1 ft Top of Cement= 3167.8 ft "Mark of Schlumberger S eMillairr Page 7 si20-n4 v1 2-10-12.cfw,02-10-2012; LoadCase 9 5/8 FP;Version wcs-cem411_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 3: pumping schedule Start Job: Circulate at least 1 BU, note rates and Pressure, Safety Meeting, Test Surface Equipment Assign personell duties Establish that circulation rates are in line with expected pressures and rates Ensure full returns Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) Citric Pill 5.0 35.0 7.0 35.0 80 Pump Citric Pill Ahead 5.0 0.0 80 Line-up Cement Unit MUDPUSH II 5.0 80.0 16.0 80.0 80 Pump Spacer 3.0 0.0 80 Drop Bottom Plug 2.0 0.0 80 Line up to Pump Cement LiteCRETE 5.0 140.0 28.0 140.0 80 Mix&Pump Slurry at 3 to 7 BPM 5.0 0.0 80 Drop Top Plug Mud 7.0 10.0 1.4 10.0 80 Kick Out Plug 5.0 0.0 80 Line Up Rig Pumps Mud 7.0 333.4 47.6 343.4 80 Displace Casing Shut-In 0.0 0.0 3.0 0.0 80 Bleed-off/Check Floats Total 02:00 hr:mn 598.4 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 259 psi at 4771.0 ft Pore 126 psi at 2559.0 ft Collapse 4395 psi at 4691.0 ft Burst 6448 psi at 50.0 ft Temperature Results BHCT 83 degF Simulated Max HCT 71 degF Simulated BHCT 71 degF Max HCT Depth 4771.0 ft CT at TOC 71 degF Max HCT Time 02:00:03 hr:mn:sc Static temperatures : At Time (hr:mn) 00:03 hr:mn Geo.Temp. Top of Cement (degF) 71 degF 65 degF Bottom Hole (degF) 71 degF 85 degF Page 8 si20-n4 v1 2-1 D-12.cfw,02-10-2012, LoadCase 9 5/8 FP,Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 SckIinkerger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 95/8 FP ECD at Casing Shoe: _Depth= 4771 ft L7 N Hydrostatic Dynamic I Frac It) Fore at 0 Lo • <a O u) � I a_O Com_ C Q _ csi 67 I I I co I O Ico 0 20 40 60 80 100 120 140 Time (min) Page 9 si20-n4 v1 2-10-12,cfw;02-10-2012; LoadCase 9 5/8 FP,Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 ScIlehrger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP ECD at Surface Casing Shoe: Depth= 2559 ft Fluids at 4771 ft (Ni _ Hydrostatic Dynamic Frac L? Fbre T6 p ED.in • w o 112 CL 0 oi 0 06 Lf) 0 co I f 0 20 40 60 80 100 120 140 Time (min) Page 10 si20-n4 v1 2-10-12.cfw;02-10-2012; LoadCase 9 5/8 FP;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schholierger String : 95/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP BHCT Cement Slurry: 0 0D First Sack Temp. Last Sack Temp. N co- -M LL N O O O r- 2 a) U a) 0 d -(D N_ r-. -r� co d) 0 20 40 60 80 100 120 140 Time (min) Page 11 si20-n4 v1 2-10-12.cfw;02-10-2012, LoadCase 9 5/8 FP;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 ScIimerger String : 95/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 95/8 FP Surface Pressure Model: O 0 Calc.Pump Press. ti Calc.CemHP O O- co O O- O .-_O- 'y a- - (Y) N - \\\\ 0 \ 0 20 40 60 80 100 120 140 Time (min) Page 12 si20-n4 v1 2-10-12.cfw,02-10-2012, LoadCase 9 5/8 FP,Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 ScIimkerger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Returns Rate: Fluids at 4771 ft r` Q out Q In LeiC a) fd N 0 20 40 60 80 100 120 140 Time (min) Page 13 si20-n4 v1 2-10-12.cfw;02-10-2012, LoadCase 9 5/8 FP,Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 ScIorerger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 95/8 FP AnullarVelocity: o _Depth= 4771 ft O) Annular Velocity 0 c O_ 1 O co____, C E O—in_ U 0 C C Q O_ co N J O_ 0 20 40 60 80 100 120 140 Time (min) Page 14 si20-n4 v1 2-10-12.cfw,02-10-2012; LoadCase 9 5/8 FP;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlmierger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.45 lb/gal Rheo. Model : HERSCHEL_B. k :4.32E-3 Ibf.s^n/ft2 At temp. : 120 degF n :0.760 Ty :8.18 lbf/100ft2 Gel Strength :21.35 lbf/100ft2 MUD Mud Type :OBM Job volume :343.4 bbl Water Type : Fresh VOLUME FRACTION Solids : 12.0% Oil :58.0% Water :30.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k :4.65E-2 Ibf.s^n/ft2 At temp. : 80 degF n :0.355 Ty : 11.471bf/100ft2 Gel Strength :40.56 Ibf/100ft2 Job volume :80.0 bbl LiteCRETE DESIGN Fluid No:4 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k :5.36E-2 Ibf.s^n/ft2 At temp. : 72 degF n :0.564 Ty : 1.871bf/100ft2 Gel Strength :52.38 Ibf/100ft2 DESIGN BLEND SLURRY Name : 12.5(0.76) Mix Fluid : 5.171 gal/sk Job volume : 140.0 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :511.17 sk Sack Weight : 100 lb Solid Fraction : 55.0% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.171 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOC Antisettling Page 15 si20-n4 v1 2-10-12.cfw;02-10-2012; LoadCase 9 5/8 FP;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Sclmerger String : 95/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 95/8 FP Citric Pill DESIGN Fluid No:5 Density :9.50 lb/gal Rheo. Model : HERSCHEL_B. k :9.93E-3 Ibf.sAn/ft2 At temp. : 58 degF n :0.575 Ty : 13.59 lbf/100ft2 Gel Strength : (Ibf/100ft2) MUD Mud Type :WBM Job volume :35.0 bbl Water Type : Fresh VOLUME FRACTION Solids : 13.0% Oil :2.0% Water :85.0 Annulus ID : 9.625 in-OD: 12.250 in O — Citric Fill — L'fteCRETE — MUDPUSH1 — Mud N O O O O— O �— co 0— N ^L a_ O_ .0 f� o 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbl/min) Page 16 si20-n4v12-10-12.cfw;02-10-2012; LoadCase95/8FP;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 5: centralizer placement Top of centralization :50.0 ft Bottom Cent. MD :4751.0 ft Casing Shoe :4771.0 ft NB of Cent. Used :39 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 3211.0 0 0/0 0.0 3225.4 4771.0 39 1/1 NW-ST-9 5/8-6-ST A3A WO9R 33.6 3231.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-ST-9 5/8-6-ST WO9R 9 5/8 14.583 10.882 No Hannover 12.625 768.85 1656.84 A3A ft 0 20 40 60 80 100 o- < > 0. - Between Cent. + +At Cent. O O— O N O O_ O .G o o O - O O Well Pipe Standoff Page 17 si20-n4v12-10-12.cfw,02-10-2012: LoadCase95/8FP.Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Sinner ner String : 95/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 6: WELLCLEAN II ft % 0 0 50 100 0 25 50 75 100 - Std Betw.Cent. - Mud Contamination - - Cement Coverage - Uncontaminated Slurry F I 1 • E Zee • Q Fluid Sequence Cement Coverage Uncontaminated SI 4 9 u-rY Fade Cacatelvn Pods M W on the Well 3 z° z 3200 3200 3200- )-R 3200 3400 3400 3400- J 3400 3600 3600 3600- 3600 3800 3800 w E 3800- = 3800 w s 4000 4000 -c 4000- 4000 -c O_ a S. a ar a) a) - m ' 4200 4200 c' 4200- 4200 D 4400 4400 4400-- r._ 4400 4600 4600 4600 4600 4800 4800 4800- 4800 i 4) ; a) a) 3 a) -o o -o -o o -o 3 0 3 3 a z z IeCOETE ■C*i P1 ■M ■ Page 18 si20-n4 v1 2-10-12.ciw;02-10-2012; LoadCase95/8FP;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 ScblInIrgnr String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 6: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name D972 51117 lb 512 sack 100 lb LiteCRETE D047 8.0 gal 2 can 5.0 gal D182 5601b 23 sack 251b D031 93381b 85 sack 110 lb D046 102 lb 3 sack 50 lb D065 128 lb 3 sack 501b D167 1281b 6 sack 251b D153 33 lb 2 sack 251b Mix Water Requirements : Fresh water 136 bbls MIXING PREPARATION MUDPUSH II Volume :80.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 72.446 bbl D047 8.000 gal 0.100 gal/bbl of spacer D182 560.000 lb 7.000 lb/bbl of spacer D031 9337.875 lb 116.72 lb/bbl of spacer LiteCRETE Volume : 140.0 bbl Density : 12.50 lb/gal Yield : 1.54 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 62.9 bbl 10.0 bbl LAS Design 12.5(0.76) 51116.980 lb Fresh water 62.935 bbl 10.001 bbl D046 102.234 lb 0.200%BWOB D065 127.792 lb 0.250%BWOB D167 127.792 lb 0.250%BWOB D153 32.981 lb 0.100%BWOC Page 19 si20-n4 v1 2-10-12.cfw;02-10-2012; LoadCase 9 5/8 FP;Version wcs-cem471_02 Schlumberger CemCAD E*well cementing recommendation for 13.375" Surface Casing Operator : Eni Petroleum Well : S120-N4 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Doyon 15 Proposal No. : Draft v1 Service Point : Prudhoe Bay Alaska Date Prepared : 02-7-2012 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 ON II II* O 9(U RTE 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 DR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. . Mark of Schlumberger Client : Eni Petroleum Well : S120-N4 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2559.0 ft BHST : 48 degF Bit Size : 16 in ft (x 1000) psi co < i l — — — 0 1 2 —Frac — — —Pore —Siltstone— 0 o • • •Sandstone•.• o- Shale II Coal I o • • Sandstone • • Ill o . .II - tti ' ',Sandstone,' ' Shale I 0 0 0 co_ Well - Well Lithology Formation Press. Page 2 si20-n4 pilot hole v1 2-6-12.cfw;02-07-2012; LoadCase Surface Casing;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 160.0 20 169.0 - 18.376 Landing Collar MD : 2479.0 ft Casing/liner Shoe MD : 2559.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2559.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 137.7 % Mean OH Equivalent Diameter: 19.032 in Total OH Volume : 844.1 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1750.0 16.000 190.0 20.063 2559.0 16.000 35.0 16.822 Page 3 si20-n4 pilot hole v1 2-6-12,cfw:02-07-2012: LoadCa se Surface Casing,Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumdcrgcr String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 23 deg Max. DLS : 3.009 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 155.0 0.000 100.0 100.0 0.0 155.0 0.000 200.0 200.0 0.0 155.0 0.000 300.0 300.0 1.5 155.0 1.500 400.0 399.9 3.5 155.0 2.000 500.0 499.6 5.5 155.0 2.000 600.0 598.9 7.5 155.0 2.000 700.0 697.8 9.5 155.0 2.000 800.0 796.1 11.5 155.0 2.000 900.0 893.8 13.5 155.0 2.000 1000.0 990.6 15.5 155.0 2.000 1100.0 1086.5 17.5 155.0 2.000 1200.0 1181.3 19.5 155.0 2.000 1300.0 1274.9 21.5 155.0 2.000 1384.8 1353.4 23.2 155.0 2.004 1400.0 1367.4 23.0 155.0 -1.055 1500.0 1459.7 22.0 155.0 -1.000 1600.0 1552.7 21.0 155.0 -1.000 1700.0 1646.4 20.0 155.0 -1.000 1800.0 1740.6 19.0 155.0 -1.000 1900.0 1835.4 18.0 155.0 -1.000 1918.9 1853.4 17.9 155.0 -0.951 2000.0 1931.1 15.4 155.0 -3.009 2100.0 2028.1 12.4 155.0 -3.000 2200.0 2126.3 9.4 155.0 -3.000 2247.6 2173.4 8.0 155.0 -3.002 2300.0 2225.4 6.4 155.0 -2.998 2400.0 2325.0 3.4 155.0 -3.000 2500.0 2424.9 0.4 155.0 -3.000 2514.1 2439.0 0.0 155.0 -2.977 2559.0 2483.9 0.0 155.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 755.0 11.35 8.39 SV-4 Siltstone 1137.0 11.50 8.40 SV-3 Sandstone 1412.0 11.50 8.41 SV-2 Shale 1750.0 11.70 8.42 Permafrost Base Coal 1937.0 12.00 8.43 SV-1 Sandstone 2253.0 12.30 8.44 Ugnu Top(UG4) Sandstone 2559.0 12.50 8.45 TD Shale Page 4 si20-n4 pilot hole v1 2-6-12.cfw,02-07-2012, LoadCase Surface Casing,Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Sclolerger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Geothermal Temperature Profile MD ND Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1750.0 1693.4 32 -1.7 2600.0 2524.9 49 -0.5 ft degF deg 31 i;if" 90 0 25.0 —Geoth.Profile 1 I L Deviation Tubular Fluids —Pnnulus 0 o i o- r , i II 3 o N oo 1 I o M- Temp. Profile At 179 min Deviation Page 5 si20-n4 pilot hole v1 2-6-12.cfw;02-07-2012; LoadCase Surface Casing;Version wcscem471_02 Client : Eni Petroleum Well : S120-N4 Schlimlirier String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost, shoe integrity sufficient to drill ahead. Original fluid Mud 9.30 lb/gal k :2.06E-3 Ibf.s^n/ft2 n :0.812 Ty: 8.74 Ibf/100ft2 Displacement Volume 371.2 bbl Total Volume 935.2 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 k:2.54E-2 lbf.sAn/ft2 n:0.420 Ty:13.04 Ibf/100ft2 Lead Slurry 401.0 2054.4 10.70 k:8.93E-2 lbf.sAn/ft2 n:0.282 Ty:24.97 Ibf/100ft2 LiteCRETE 63.0 504.6 2054.4 12.50 k:2.01 E-2 lbf.sAn/ft2 n:0.673 Ty:20.18 Ibf/100ft2 Mud 371.2 0.0 9.30 k:2.06E-3lbf.s^n/ft2 n:0.812 Ty:8.74 lbf/100ft2 Static Security Checks: Frac 5 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 1973 psi at 2479.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 58 ton Check Valve Diff Press 214 psi Page 6 si20-n4 pilot hole v1 2-6-12.cfw,02-07-2012, LoadCase Surface Casing:Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing CemCADE Client :Eni Petroleum Well :S120-N4 String : 13.375"Surface Casing District :Prudhoe Bay Alaska Country :USA ft lb/gal 8 9 10 11 12 13 14 -Hydrostatic -Mn.Hydrostatic -Max.Dynamic -Mn.Dynamic O - Frac L -Pore N O_ OI O a � m o O_ > U O t O 0 N 0 4 OZ u O • 8 W M— N Fluid Sequence Dynamic Well Security c ■MUDPUSH II 100.0 bbl 10.10 lb/gal Herschel:k=2.54E-2 Ibf.s^n/ft2 n=0.420 Ty=13.04 Ibf/100ft2 N y 3 Lead Slurry 401.0 bbl 10.70 lb/gal Herschel:k=8.93E-2 Ibf.s^n/ft2 n=0.282 Ty=24.97 Ibf/100ft2 LIteCREfE(12.5) 63.0 bbl 12.50 lb/gal Herschel:k=2.01 E-2 Ibf.s^n/ft2 n=0.673 Ty=20.18 Ibf/100ft2 ■Mud 371.2 bbl 9.30 lb/gal Herschel:k=2.06E-3 Ibf.s^Nft2 n=0.812 Ty=8.74 Ibf/100ft2 Total Depth = 2559.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger Schbihrier Page 7 si20-n4 pilot hole v1 2-6-12.ctw;02-07-2012; LoadCase Surface Casing;Version wcs-cenr471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Volume Stage Time Cum.Vol lnj. Comments Rate (bbl) (min) (bbl). Temp. (bbl/min) (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead Pause 0.0 0.0 5.0 0.0 80 Drop Bottom Plug Lead Slurry 5.0 371.0 74.2 371.0 80 Mix&Pump Lead Slurry Lead Slurry 1.0 1.0 1.0 372.0 80 Top Plug at Float Collar(Psi spike) Lead Slurry 5.0 29.0 5.8 401.0 80 Mix&Pump Lead Slurry LiteCRETE 4.0 60.0 15.0 60.0 80 Mix&Pump Tail Slurry LiteCRETE 2.0 3.0 1.5 63.0 80 Finish Tail Slurry Pause 0.0 0.0 3.0 0.0 80 Drop Top Plug Mud 8.5 10.0 1.2 10.0 80 Kick Out Plug Pause 0.0 0.0 3.0 0.0 80 Line Up Rig Pumps Mud 8.5 351.2 41.3 361.2 80 Displace w/Rig Pumps Mud 3.0 10.0 3.3 371.2 80 Bump Plug Shut-In 0.0 0.0 5.0 0.0 80 Bleed-Off/Check Floats Total 02:54 hr:mn 935.2 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 0 psi at 160.0 ft Pore 8 psi at 160.0 ft Collapse 1972 psi at 2479.0 ft Burst 4720 psi at 0.0 ft Temperature Results BHCT 64 degF Simulated Max HCT 78 degF Simulated BHCT 78 degF Max HCT Depth 2559.0 ft CT at TOC 74 degF Max HCT Time 02:36:56 hr:mn:sc Static temperatures : At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 74 degF 60 degF Bottom Hole (degF) 77 degF 48 degF Page 8 si20-n4 pilot hole v1 2-6-12.cfw,02-07-2012, LoadCase Surface Casing.Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Scrlolerger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing ECD at Casing Shoe: Depth= 2559 ft_ ("I - O Hydrostatic Dynarrc Frac Pore a° 7 • E0• �O � u _ O c 0 20 40 60 80 100 120 140 160 180 200 Time (min) ECD at Conductor Shoe: Depth= 180 ft -Hydrostatic Dynamic -Frac -Pore � 0 I 0 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 9 si20-n4 pilot hole v1 2-6-12.cfw;02-07-2012; LoadCase Surface Casing;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 SChIlderger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Cement Slurry BHCT: o 1173 —First Sack Terry. Last Sack Temp. O_ r 0000 -N I� -M � O �p to -t0 P -00 0 20 40 60 80 100 120 140 160 180 200 Time (min) Surface Pressure: Calc.Pump Press. O Calc.CernHP O O Ci t>7 r� u) O O _ 77/_ 0 � 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 10 si20-n4 pilot hole v12-6-12.ctw:02-07-2012, oadCaoe Surface Casing Version wcs-cern4ll_02 Client : Eni Petroleum Well : S120-N4 Sehlolirger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Returns Rate: Fluids at 2559 ft 1 Q out Q in r`- 1 (0- C / \_ i 1 may` 8 I= M1 - N- 1-- 1 r, 0 -- 1� -T T T 0 20 40 60 80 100 120 140 160 180 200 Time (min) Annular Velocity: Depth= 2559 ft p Annular Velocity W I 8-- t 1\ - 1' / R- I 10- % 1 0 - I I I I -T--� 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 11 si20-n4 pilot hole v1 2-6-12.cfw;02-07-2012; LoadCase Surface Casing:Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 4: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2419.0 ft Casing Shoe :2559.0 ft NB of Cent. Used :35 NB of Floating Cent. :35 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 2039.0 25 1/2 NW-TR-13 3/8-8-TR 3 W304 17.5 379.0 2439.0 10 1/1 NW-TR-13 3/8-8-TR 3 W304 78.7 2039.0 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) NW-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 ( ft 0 20 40 60 80 100 Between Cent. + +At Cent. t t + O 1-F i-F i+ 1-r 1--r O O_ 1r +r + + I + + p_ (� t LO +t- ++ O + + N LO N M— Well Pipe Standoff Page 12 si20-n4 pilot hole v1 2-6-12.cfw,02-07-2012, LoadCase Surface Casing;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 5: WELLCLEAN II oro ft 0 50 100 0 25 50 75 100 o < I —Std Betw.Cent. Mud Contarrination - - —Cement Coverage — Uncontaminated Slurry g O ) .". 1— a CV N Fluid Sequence Cement Coverage Uncontaminated Slurry iLh CareaI ., aek Mud al theWal z z° 01 I 0 0 0 500— * 500 500 500 I 1000— 1000 . 1000 1000 L t - t 02 1500 1500 0 0 1500 1500 0 2000 _ 2000 2000 2000 2500 2500 2500 2500 i w ; a) d ; ro o -o a o 3L. 3 3 0 0 z z .MLtAIETE(1251 ii MnnPJSX II ■Medt. ■N Page 13 si20-n4 pilot hole v12-6-12.cfw;02-07-2012, LodCase Surface Casing Version wcs-cem47i_02 Client : Eni Petroleum Well : S120-N4 Schnell" String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.30 lb/gal Rheo. Model : HERSCHEL_B. k :2.06E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.812 Ty :8.74 lbf/100ft2 Gel Strength :38.42 Ibf/100ft2 MUD Mud Type :WBM Job volume :371.2 bbl Water Type : Fresh VOLUME FRACTION Solids :7.0% Oil :0.0% Water :93.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.04 lbf/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 :8.93E-2 Ibf.s^n/ft2 At temp. :69 degF n :0.282 Ty :24.97 lbf/100ft2 Gel Strength : 11.88 Ibf/100ft2 DESIGN _ BLEND SLURRY Name : B809(1001b) Mix Fluid : 10.532 gal/sk ob volume :401.0 bbl Dry Density : 106.82 lb/ft3 Yield :2.34 ft3/sk Quantity :960.48 s Sack Weight : 100 lb Solid Fraction :39.9% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 10.532 gal/sk LiteCRETE(12.5) DESIGN Page 14 si20-n4 pilot hole v1 2-6-12.cfw;02-07-2012; LoadCase Surface Casing;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlsalerger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Fluid No:4 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k :2.01E-2 Ibf.s^n/ft2 At temp. :72 degF n :0.673 Ty :20.18 lbf/100ft2 Gel Strength :64.13 Ibf/100ft2 DESIGN BLEND SLURRY Name : 12.5(0.76) Mix Fluid : 5.174 gal/sk Job volume :63.0 bbl Dry Density : 119.32 Ib/ft3 Yield : 1.54 ft3/sk Quantity :229.92 sk Sack Weight : 100 lb Solid Fraction :55.0% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 5.174 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Annulus ID : 13.375 in Flow Rate: 8.5 bbl/min 0 N- - LiteCRETE(12.5) Lead Slurry - MUDPUSHII - Mud O ° O O— N co d O LP U• LL O N 15.8 16.0 16.2 16.4 16.6 16.8 17.0 17.2 17.4 17.6 17.8 18.0 18.2 Annulus OD (in) Page 15 si20-n4 pilot hole vl 2-6-12.cfw;02-07-2012, LoadCase Surface Casing:Version wcs-cens471_02 Client : Eni Petroleum Well : S120-N4 Schlumherger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 5: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name D972 22993 lb 230 sack 100 lb LiteCRETE Blend B809 96048 lb 960 sack 100 lb ASL(Arctic Set Lite)Blend D182 555lb 23 sack 25lb D046 66 lb 2 sack 50 lb D031 9527 lb 87 sack 110 lb D065 57 lb 2 sack 50 lb D167 57 lb 3 sack 25 lb D153 231b 1 sack 25lb Mix Water Requirements : Fresh water 362 bbls MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density : 10.10 lb/gal Code Quantity Design Fresh water 92.485 bbl D182 554.912 lb 6.000 lb/bbl of base fluid D046 20.000 lb 0.200 lb/bbl of spacer D031 9526.843 lb 95.27 lb/bbl of spacer Lead Slurry Volume :401.0 bbl Density : 10.70 lb/gal Yield : 2.34 ft3/sk Dry Phase Liquid Phase Blend: 96048 lb Design Mix Water 240.8 bbl 10.0 bbl LAS Design B809(1001b) 96047.672 lb Fresh water 240.849 bbl 10.001 bbl LiteCRETE (12.5) Volume :63.0 bbl Density : 12.50 lb/gal Yield : 1.54 ft3/sk Dry Phase Liquid Phase Blend: (lb) Design Mix Water 28.3 bbl 10.0 bbl LAS Design 12.5(0.76) 22992.496 lb Fresh water 28.327 bbl 10.001 bbl D046 45.985 lb 0.200%BWOB D065 57.481 lb 0.250%BWOB D167 57.481 lb 0.250%BWOB D153 22.992 lb 0.100%BWOB Page 16 si20-n4 pilot hole v1 2-6-12.cfw,02-07-2012, LoadCase Surface Casing,Version wcs-cem471.02 Schlumberger CemCAD E* well cementing recommendation for Pilot Hole Plug OBM Operator : Eni Petroleum Well : S120-N4 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Nabors 245E Proposal No. : Draft v1 Service Point : Prudhoe Bay Alaska Date Prepared : 02-9-2012 Business Phone : (907)659-2434 FAX No. : (907)659-2538 Prepared by : Jeff Long Phone : (907)273-1778 E-Mail : JLong1Qslb.com well description Configuration Plug Stage:Single Rig Type:Land Prev.String MD:2559.0 ft OD:13 3/8 in Weight:68.0 lb/ft Drill Pipe MD:4325.0 ft OD:5 in Weight:19.5 lb/ft Casing/liner Shoe MD 4325.0 ft Mud Line 0.0 ft Total MD 4325.2 ft BHST 85 degF Bit Size 12 1/4 in Mean OH Diameter 12.250 in Mean Annular Excess 15.0% • yt� Mean OH Equivalent Diameter 12.993 in 441,‘‹? Total OH Volume 289.6 bbl (including excess) • • FL gZUATE 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 modals,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 GMEN CONCERNING ACCURACY OR COMPLETENESS OF DATA.INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL PRODUCTS OR SUPPLIES.RECOMMENDATIONS MADE.OR RESULTS Of THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. * Mark of Schlumberger Page 1 S120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase P&A plug(al;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Scrlrgcr String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) Section 1 : fluid sequence Job Objectives: Plug back pilot hole from TD to 3,650'MD Original fluid Faze Pro Mud 9.30 lb/gal Pv:34.921 cP Ty: 16.10 lbf/100ft2 Displacement Volume 76.8 bbl Drill Pipe Volume 76.8 bbl Total Volume 285.3 bbl TOC 3620.1 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) Citric Pill 40.0 286.3 2832.8 9.80 k:5.16E-5 lbf.sAn/ft2 n:1.000 Ty:0.46 lbf/100ft2 MUDPUSH II 70.0 501.0 3119.1 10.10 k:2.54E-2 lbf.s^n/ft2 n:0.420 Ty:13.04 lbf/100ft2 Plug 1 Slurry 98.5 704.9 3620.1 15.80 Pv:185.229 cP Ty:22.97 lbf/100ft2 Plug 1 Slurry 12.5 3620.1 15.80 Pv:185.229 cP Ty:22.97 lbf/100ft2 MUDPUSH II 8.9 3119.1 10.10 k:2.54E-2 lbf.s^n/ft2 n:0.420 Ty:13.04 lbf/100ft2 Citric Pill 5.1 2832.8 9.80 k:5.16E-5 lbf.s^n/ft2 n:1.000 Ty:0.46 lbf/100ft2 Faze Pro Mud 50.3 0.0 9.30 Pv:34.921 cP Ty:16.10 lbf/100ft2 Static Security Checks Frac 413 psi at 2559.0 ft Pore 110 psi at 2559.0 ft Csg.Pump out 35 ton Check Valve Diff Press 0 psi Page 2 S120-N4 Pilot hole v1 2-6-12.cfw.02-10-2012, LoadCase P&A plug(a),Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) CemCADE Client :Eni Petroleum Well :S120-N4 String :Pilot Hole Plug OBM District :Prudhoe Bay Alaska Country :USA ft lb/gal 8 9 10 11 12 13 o —Hydrostatic —Mn.Hydrostatic O - —Max.Dynamic 0— —Mn.Dynamic — Frac O _ — Pore O O O - o 0— I 9 O - O 3 N O - > O_ u7 = N ' rn O_ O q M - ° O_ tI7 Op- III ( t 3 � �i O _ N _ 2 Fluid Sequence Dynamic Well Security ®Citric Fill 45.1 bbl 9.80 lb/gal Herschel:k =5.16E-5 Ibf.s^n/ft2 n =1.000 Ty=0.46 Ibf/100ft2 fN ■MJDPUSH II 78.9 bbl 10.10 lb/gal Herschel:k =2.54E-2 Ibf.s^n/ft2 n =0.420 Ty=13.04 Ibf/100ft2 5 Plug 1 Slurry 111.0 bbl 15.80 lb/gal Bingham:Pk/=185.229 cP Ty=22.97 Ibf/100ft2 ■Faze Pto Mud 50.3 bbl 9.30 lb/gal Bingham:Pd=34.921 cP Ty=16.10 Ibf/100ft2 Total Depth = 4325.2 ft Top of Cement= 3620.1 ft *Mark of Schlumberger Page 3 S120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase P&A plug lal;Version wcs-cem471_02 String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Schl bergcr Country : USA Loadcase : P&A plug(a) Section 2: fluid description Faze Pro Mud DESIGN Fluid No: 1 Density :9.30 lb/gal Rheo. Model : BINGHAM Pv : 34.921 cP At temp. : 120 degF Ty : 16.10 lbf/100ft2 Gel Strength :8.54 lbf/100ft2 MUD Mud Type :OBM Job volume :50.3 bbl Water Type : Fresh VOLUME FRACTION Solids : 11.5% Oil :59.0% Water :29.5% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.04 lbf/100ft2 Gel Strength : (lbf/100ft2) Job volume :78.9 bbl Plug 1 Slurry DESIGN Fluid No:5 Density : 15.80 lb/gal Rheo. Model : BINGHAM Pv : 185.229 cP At temp. : 70 degF Ty :22.97 lbf/100ft2 Gel Strength :40.35 lbf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid : 5.080 gal/sk Job volume : 111.0 bbl Dry Density : 199.77 Ib/ft3 Yield : 1.16 ft3/sk Quantity : 536.27 sk Sack Weight : 94 lb Solid Fraction :41.6% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.070 gal/sk Additives Code Conc. Function D046 0.200%BWOC Antifoam D065 0.400%BWOC Dispersant D167 0.550%BWOC Fluid loss D177 0.010 gal/sk cement Retarder Page 4 S120-N4 Pilot hole v1 2-6-12 cfw;02-10-2012, LoadCa se P&A plug(a);Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schioberger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) Citric Pill DESIGN Fluid No:6 Density :9.80 lb/gal Rheo. Model : HERSCHEL_B. k :5.16E-5 Ibf.s^n/ft2 At temp. : 86 degF n : 1.000 Ty :0.46 lbf/100ft2 Gel Strength :0.00 lbf/100ft2 MUD Mud Type :WBM Job volume :45.1 bbl Water Type : Fresh VOLUME FRACTION Solids : 11.0% Oil : 0.0% Water : 89.0% Page 5 0120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase P&A plug(al;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Scklrger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) Citric Pill 5.0 40.0 8.0 40.0 80 Citric Pill Ahead Pause 0.0 0.0 2.0 0.0 80 Swap to Spacer MUDPUSH II 5.0 70.0 14.0 70.0 80 Spacer Ahead Pause 0.0 0.0 5.0 0.0 80 Weight up Tub Plug 1 Slurry 4.0 111.0 27.8 111.0 80 Mix&Pump Plug Slurry Pause 0.0 0.0 3.0 0.0 80 Swap to Spacer MUDPUSH 11 5.0 8.9 1.8 8.9 80 Spacer Behind Pause 0.0 0.0 2.0 0.0 80 Swap to Citric Pill Citric Pill 3.0 5.1 1.7 5.1 80 Citric Pill Behind Pause 0.0 0.0 3.0 0.0 80 Swap to Mud Faze Pro Mud 8.0 50.3 6.3 50.3 80 Displace to Balance Total 01:14 285.3 bbl hr:mn End Job: Pull out slowly from the plug, circulate a full bottoms up at 3400', spot 44 bbl Dynamic Security Checks: Frac 388 psi at 2559.0 ft Pore 110 psi at 2559.0 ft Temperature Results BHCT 75 degF Simulated Max HCT 78 degF Simulated BHCT 78 degF Max HCT Depth 4325.0 ft CT at TOC 78 degF Max HCT Time 00:29:00 hr:mn:sc Static temperatures: At Time (hr:mn) 1 (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 70 degF Bottom Hole (degF) (degF) 85 degF Page 6 S120-N4 Pilot hole v1 2-6-12.cfw:02-10-2012, LoadCase P&A plug(a),Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 ScIokerger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) WELL DATA Well Data Job Type: Abandonment Plug Rig Type: Land ft Total Depth(Measured): 4325 ft 75! True Vertical Depth(TVD): 4249.9 ft TOC in pipe before POOH: 3620.1 ft TOC in annulus before POOH: 3620.1 ft 11. ft 14 ' ft Open Hole Bottom Depth Mean Calliper Mean Excess Mean Equiv. 17. I ft Diameter Diameter 4325 ft 12.25 in 15% 12.993 in 19' ft -- 22. Drill Pipe Bottom Measured OD ID Weight 25 ft Depth 4325 ft 5 in 4.276 in 19.5 Ibm/ft •:'6: 3 ft 9 ft ' Bottom Measured OD ID Weight Depth 2559 ft 13.375 in 12.415 in 68 Ibm/ft 36 ft TrTi -- • :4p ft :4! ft :42 ft Page 7 S120-N4 Pilot hole v1 2-6-12 cfw 02-10-2012; LoadCase P&A plug(a);Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) FORMATION DATA Formation Data MD Top MD Pore Top Pore Frac Top Frac Name/ Res. Fluid Bottom Bottom Bottom Lithology 0 ft 755 ft 0 psi 328 psi 0 psi 443 psi Siltstone 755 ft 1137 ft 328 psi 489 psi 443 psi 670 psi Sandstone 1137 ft 1412 ft 489 psi 602 psi 670 psi 823 psi Shale 1412 ft 1750 ft 602 psi 741 psi 823 psi 1029 psi Coal 1750 ft 1937 ft 741 psi 819 psi 1029 psi 1166 psi Sandstone 1937 ft 2253 ft 819 psi 955 psi 1166 psi 1392 psi Sandstone 2253 ft 2559 ft 955 psi 1090 psi 1392 psi 1613 psi Shale 2559 ft 2882 ft 1090 psi 1232 psi 1613 psi 1823 psi Sandstone 2882 ft 3521 ft 1232 psi 1513 psi 1823 psi 2238 psi Coal 3521 ft 4030 ft 1513 psi 1736 psi 2238 psi 2568 psi Sandstone 4030 ft 4082 ft 1736 psi 1759 psi 2568 psi 2602 psi Sandstone 4082 ft 4178 ft 1759 psi 1801 psi 2602 psi 2664 psi Sandstone 4178 ft 4295 ft 1801 psi 1852 psi 2664 psi 2740 psi Sandstone 4295 ft 4325.3 ft 1852 psi 1866 psi 2740 psi 2760 psi Shale Absolute Formation Pressure Pressure,psi 0 1000 2000 3000 2475 - —-272• 3 - - 2970 - 0 3218 - --Pore 2 3465 - Frac n N 3713 - 3960 - • 4208 - 1 Equivalent Density Formation Pressure Page 8 S120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase P&A plug(al;Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Umbels, String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) Equivalent Density,Ibmlgal 0 2 4 6 8 10 12 _.—_i_.__---1-- i 1 I 2475 - 2723 - 2970 - ▪ 3218 - —Pore 41 3465 —Frac 3 a)3713 - 3960 - 4208 - Page 9 S120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase P&A plug(a):Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) FLUIDS DATA Fluids Data Name Type Density, Model Consistency, Power Ty, Gel Ibm/gal lbf.s^n/100ft Index Ibf/100ft2 Strength, 2 Ibf/100ft2 IFaze Pro Mud MUD 9.3 Bingham 0.07293 1 16.1 8.54 MUDPUSH II SPACER 10.1 Herschel-B. 2.53688 0.42 13.04 0 Plug 1 Slurry SLURRY 15.8 Bingham 0.38686 1 22.97 40.35 Citric Pill MUD 9.8 Herschel-B. 0.00516 1 0.46 0 PLACEMENT VOLUMES Placement Summary Volume Optimization Custom Plug Length 676.8 ft Plug top MD after POOH 3648.2 ft Plug Volume 111 bbl Original Fluid Faze Pro Mud Underdisplacement Volume 0 bbl Drill Pipe Volume 76.82 bbl Fluid Sequence Name Balanced Volume, Annular Top MD,ft Density, Length,ft bbl Length,ft Ibm/gal IIFaze Pro Mud 359.3 2832.8 0 9.3 2832.8 Citric Pill 40 286.3 2832.8 9.8 286.3 MUDPUSH II 70 501 3119.1 10.1 501 Plug 1 Slurry 98.5 704.9 3620.1 15.8 704.9 Plug 1 Slurry 12.5 0 3620.1 15.8 704.9 MUDPUSH II 8.9 0 3119.1 10.1 501 Citric Pill 5.1 0 2832.8 9.8 286.3 Faze Pro Mud 50.3 0 0 9.3 2832.8 Page 10 S120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase P&A plug(a);Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 SW11111811 String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) STATIC PULL OUT OF HOLE (POOH) POOH Summary Final drill pipe shoe depth after POOH: 2560.74 ft Length of uncontaminated cement after POOH: 674.81 ft Length of contaminated cement after POOH: Top MD of uncontaminated cement after POOH: 3650.19 POOH Simulation Results Interfaces in annulus Interfaces in i 0 0 7 . ft 721 7?1 11 ;7 ft 1, 2ft LL 1442 1442 1 .Oft 7. 1'1;7 ft 171 U C 2163 163 a 2.. ., 0 a N 2'..S fti. L I 2883 2'.:8 ft 2883 1f 3604 3604 ft 41c0 ft ,..' 4325 4325 ... 4325 3884 3443 3002 2561 41 - ft 4325 3884 3443 3002 2561 Shoe Depth MD,ft -• Shoe Depth MD,ft Page 11 S120-N4 Pilot hole v1 2-6-12.ciw.02-10-2012, LoadCase P&A plug(a) Version wcs-cem471_02 li Client : Eni Petroleum Well : S120-N4 SchillMerger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) PLACEMENT Pumping Schedule Fluid Name Flow Rate, Volume,bbl Time,min Backpressure, Cumulative bbl/min psi Time,min _ Citric Pill 5 40 8 0 8 Pause 0 0 2 0 10 _ MUDPUSH Il 5 70 14 0 24 Pause 0 0 5 0 29 ® Plug 1 Slurry 4 111 27.75 0 56.75 Pause 0 0 3 0 59.75 _ MUDPUSH II 5 8.9 1.78 0 61.53 Pause 0 0 2 0 63.53 _ Citric Pill 3 5.09 1.7 0 65.22 Pause 0 0 3 0 68.22 am Faze Pro Mud 8 50.32 6.29 0 74.51 Well Security Pressure,psi 0 331 663 994 1325 1656 1988 2319 2650 2982 0.00 - - , -. 1. 200.00 400.00 600.00 800.00 1000.00 1200.00 1400.00 1600.00 180.00 2060 -Pore Pressure,psi in Annulus ' 2200 ', ' `Frac Pressure,psi in Annulus Min Pressure,psi in Annulus 2400.00 Max Pressure,psi in Annulus 2190.00 Min Static Pressure,psi in Annulus 2800.00 Max\ Static Pressure,psi in Annulus 3000.00 3200.00 3400.00 3600.00 3800.00 4000.00 9200.00 \, 4400.00 4600.00 Min annular pore security 11.7% (217.4psi)at MD=4325ft. Min annular frac security 13.9% (383psi)at MD=4325ft. Min annular static pore security 10.1%(123.2psi)at MD= 2865ft. Min annular static frac security 16% (440.2psi)at MD= 4325ft. Page 12 S120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase P&A plug 1a);Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 Schlumberger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) FLUID MIXING BEFORE POOH Fluid Mixing at the end of placement Annulus Mixing Slurry in Annulus Pipe Mixing Slurry in Pipe Legend Zones Contamination Risk Zones Contamination Risk Slurry Contamination Risk 0 No Slurry 0 High Contamination Risk 0 Medium Contamination Ri Low Contamination Risk 850 850 850- 850- 1700 1700 1700- 1700- 2550 2550 2550- 2550- 3450 :3450 3450 3450- Fluids 0 Faze Pro Mad h4UDPUSH II 0 Plug 1 Slurry 0 Citric Pill 4325 4325 4:25 4325 Slurry Contamination Risk Pipe High:469 ft Medium:139 ft Low:599 ft Annulus High:130 ft Medium:22 ft Low:681 ft Page 13 S120-N4 Pilot hole vl 2-6-12.cfw;02-10-2012; LoadCase P&A plug(a);Version wcs-cem471_02 Client : Eni Petroleum Well : S120-N4 ScMier String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) FINAL MIXING RISKS AFTER PLACEMENT AND POOH Target Slurry after POOH To of Cement Contamination Risk 3259 3259 3450 3450 3650 Target TOC 3650 3655 ft • 3648 ft 3676 ft 3850 3850 4100 4100 4325 4325 3580 ft<Target TOC<3716 ft 3655 ft<Top MD of Cement after POOH<3676 ft Page 14 S120-N4 Pilot hole v1 2-6-12.cfw;02-10-2012; LoadCase P&A plug(a);Version wcs-cem471_02 A Client : Eni Petroleum Well : S120-N4 Sehlemkrger String : Pilot Hole Plug OBM District : Prudhoe Bay Alaska Country : USA Loadcase : P&A plug(a) Section 4: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name G 50410 lb 537 sack 941b D182 4381b 18 sack 251b D046 117 lb 3 sack 50lb D031 7517lb 69 sack 110lb D065 202 lb 5 sack 50 lb D167 277 lb 12 sack 251b D177 5.4 gal 1 drum 55.0 gal Mix Water Requirements : Fresh water 5784 gal MIXING PREPARATION MUDPUSH II Volume :78.9 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 72.970 bbl D182 437.821 lb 6.000 lb/bbl of base fluid D046 15.780 lb 0.200 lb/bbl of spacer D031 7516.597 lb 95.27 lb/bbl of spacer Plug 1 Slurry Volume : 111.0 bbl Density : 15.80 lb/gal Yield : 1.16 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 64.9 bbl 10.0 bbl LAS Design G 50409.777 lb Fresh water 64.735 bbl 9.981 bbl D046 100.820 lb 0.200%BWOC D177 5.363 gal 0.827 gal 0.010 gal/sk cement 0065 201.639 lb 0.400%BWOC D167 277.254 lb 0.550%BWOC Page 15 S120-N4 Pilot hole v1 2-6-12.cfw,02-10-2012, LoadCase P&A plug lal:Version wcs-cem471_02 SPEO IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. Em E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of`Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW = P x 10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Enr E&P Division REVISION STAP-P-1-M-6140 0 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. SPEO IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. Enl E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of 'Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. SPEOtilts IDENTIFICATION CODE PAG 209 OF 338 ENI S.p.A. En i E&P Division REVISION STAP-P-1-M-6140 0 1 PA LEAK—OFF TEST REPORT ReportN" Date: WELL NAME: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud T}pe: FWGELS Rig twe: J.UPs Hole GIameter(in): 12'1/4 Weight(KgA): 1.3 R.K.B.ele,stion(m): 28 Last Cog.Shoe(m): 797 Marsh Viscosity(sec1Ot): 44 Water Depth(m): 24 Csg.diameter(in): 13'3/8 P.V.(ops): 19 Pumps: 12-P-160 Grade: J.66 Y.P.0b/100 f): 6 Liners(in): 6.5" Weight 6blt): 61 Gels9b/10011: 2/8 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(cc/30 min): 10.5 Lithology. Shale Expected EMW KgIcm2J10 m Time Volume Pressure Time Volume Pressure Time Vdume Pressure (min) (bbl) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 60 9 2 400 16 2 435 2 050 100 95 2 480 3 0.76 200 10 2 470 4 1130 300 10.5 2 463 5 125 400 11 2 466 6 1.50 500 11.5 2 460 7 1.75 570 12 2 446 8 200 600 13 2 440 8 200 550 14 2 437 8.5 200 505 15 2 435 Neter Pumped with a constant low rate of(bbl): Vblume pumped(bbl): Volume returned(bbl): (psi) 1000 900 800 stop pump r 700 e 600 . shut in curve S 500 f U 400 r 18 minutes e 300 200 100 0 , 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bb() 10 10 Time mins RESULTS:(Press..,,i+Press.t„o,)xl OlDepth=[(1.3 x 797 110)+(430 x 0.07)]x10 1797=1.66(Kg/cm2/10 m) Note: I Company Representative I Figure 15-1 - Leak-Off Test Report 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 TTER CHECKLIST WELL NAME / / n/74 Ze 9 --7---- Ax PTD# Z72_ + ~Zc 0 Development " Service Exploratory Stratigraphic Test Non-Conventional/ Well �/ / ,�'� FIELD: /l/�/l (L` POOL: //1Z1z(747,-Gcc' Clt—tom -&-, 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 m st be cle rly differentiated in both well name ( r5 2- '/L" 9"PH) and API number (50- ,Z..`1-Z - 7l)) from ,7s, data and logs acquired for well _j _ 2.4.Z— . 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 m - a c To 0T a O r . ( ' 3p p O co co = j tv ° _. - 3.O W co 7 W C) O V1 (o.(o cn 0 a) C7 co 01 O p m LIj n NO N O N 0) a O C: O Oco O (D O (D q•• N N N C) W W W W W W W W CO W N N N N N N N N N N -, CO Co V fn (Cl A Co N ° c0 Co V C) (r A co N -� O O Co V C) C77 A W N O O (b m (n A W N -+ O V 17 0 cn cn 0 m K 0 * 0 Co Co 0 �, D �, D 0 0 0 0 cn 0 -0 D g 0 -0 m O O �. cn g * * C r -0 Z ,< O CD (D N (D ° .p p C- 0 0 = a °- v °- v K C o 3 = ° ° m ° m m m m ° ° N ° ° ° .Q at m v g. �. ° 3' oo v 'c m-, 0 m m -z m m -i 'gi a o = 0 3 < °CD _ _ _ c co 3 n m ' a - m ° ° CD _ ° v, P. a)) O. 0)) c° = o o m ° 0 o CD ° ° o o °: co 0 0 0 ° ° ? ' = m ' ° 0 m _ m — ° n o v 3 v ° co a v * c CD < C ""1 ild m 0 0 m 7 m m 2 ° u, o a u 0 a 0.0) w C) -. m > > s o 12 ° m m CD ( 3 CD • E 3 n ' ' Q ° 0 c _ri c = z m' < ° ° ° 0- a o- o- 0- gi a ( C) n n n a a• 0) O T m �: °n fD 0 m m ° c vo, c (Q ° 0 F. ° CD ° w ` (D •"o .0 0 v _, -.• (.0 m fD -0 o y a = a . .< co ' o vE.0v u, co m m a c'o ? -, = v 0 0 -o % m (o a o n) 3 o) () u, m a 0 V, 0 c c " (Nj) Z- o Co 3 N 0- (D .. O. — (D (D Ol -o o A 6' 0 c Cr) a n 6 ° N N °- CD -o N 0 > S?o CD C CO "a a = Co o 3 ° 3 n (n o -, 0 c 0 0 °^ c 0 3 co o n 0_ -Oar (D ° < n n , a n ° _ o a- ° co .c-. "O D N O O A c O .+ ♦^ '. 7 - < • a co o 7 n (fin o ° m co * co - 'o C) co ° o 3 0) u, °- m ° ° * * 0 • CD N ° ° z ",0� 3 < o o ° v° a ° s °1 co m o c_P ci a c° °' w a S 0 ° w m v n ° v 3 O �JiN3: m f CO c a o CD * o C S fl_' o z o ° „_ Ej m o 0 0 6 0 ° ° 0 3 ° v C� Z u ° ° p c° o a ( o ° 0 m CO 3 0 CD c 0 x _ d a o - - ° 9' . co a, a a• o O ,r�:' u_ ° F ° < Q m p m ' ED-' • -o 0 a (o ° =7- ° m w n o n 3 m D D o �. < v CO m �_. 0 — a cn ° v o g a n o c n o o • Z -1 COp a- N -0 ° ? ° ' X ••-. R� o o > > o m 3 > > a = 3 3 j n (� (D O 'O co O+ (D - a < 5 C) < 'O Os . co CD — 2 71 O 7 W o = ° (O O O 'co = W (D 7 O C -a (D N p_ O. (D O a j O Q =D CD c c_ n 'W 'o �_ v tU om c - O _ 0 'Y °' c 7 K c.. 7 0 co IUI1 ° c O 0 CL CD N 0 m m A %) m a o co c o' a -a ° Cr D D �J� _ n N ii c c o = T o a c m ° k N i 0 °� 0 o N -, m m a iv ° D Co O m 3 < o N CD r ° 3 n a z. a 0 C 0 z co C) -n Ci co O T `< CD y W O 30 co o O 0 co O 3 T O u c cn ....tis. o ii. o N ° T u! Er (D cnO b Z Z Z -< - -< Z -< -< -< -< -< -< -< Z -< - -< Z -< Z -< Z -< -< -< -< -< -< -< -< -< -< -< Z -< Z z 0 D 'D > (D ° ° 0 ° ° YD CD CD (D (D D CD ° (D O (D 'D CD O CD CD (D CD CD CD cD cD CD (D CD CD O CD > D u) N u' (/' d/' (/) ,, N d/' ,, (n o, u' u, (A (n N 0 u, u' (A N 0 u) 0 (n (/' V' l. y O T ° 0- OZ -IW m ° .< m = > > C? m Tl O 0 z n a 'xo N O D w < o (0 2 (^p ° n ° 0 - 0c Z cn x x ° D a v ° D o -°O 0 D 0 a) ° ? (D (D o 0 II O N coOo N c o OW 7 7 -i D CD Z CD O V' a X "� W 0)) .CD O 0 O_ O N O, ......1 CD i N a Zl 2 0r o co N OD 17 CD 0 m Co • o c v CD = (D a m C v 0 m C Co v D 'a ° CD 0 (D V O = .0 "a co -1 < Z p N co 0_, p W p CD 7 (D p' ° 0• Q W. N ' N' N ° O ' Z 0 ' *_ 0 V O O Z °) a o • o 0 3 D CD "o D o o o m o - A °- m y a - m ( 0 = �� a O °' m m m CL 0 O O co 3 5 (D V O D) ° ' ('') O N 3 0 0 D v c v m CD Co a s Cn = = Co v a• S W -o = c O 0 ° f Co U) ° ° o. ° 3 a c 3 cn m e o C a v,CD ° o 0 i a ° o = a 0 0 3 ao o y D v 0_ m Cr O_ 3' on 3 , - - N COiO *. O co — -o 5 W -a c a O' - a N 1 -0N v, O) * O ° (D al p °, O m c 'a m a m < -, 3 rn m o) °1 z (D co (° 7 o 'a (%' ° O a u, co (/, co n ° m a o co a a - p 0 0. . - A a O A 'a m N °- C" 0 (D (D O. o > Co N m 0 a 0 v 3 - m -a co Co 0 m co r a c 3 ° a 0 3 (n o co C O 0 co . - m co o- D) n) m CC co _= 3'a 3 N O ° < co V,° a 5 a O a co W 3' ° c O 5 m O 7 �(o y W CD o C) . o Co a) s a CO ! '0 C Co 3 < CO (fl ° CD 3 i.,' co N CD is.) A (D O 0. N a S ° 7 O 3 0 -0 co -a ° 737 O • co (D ° > A O S 2 0 'a 3 ,< O O ° w -a c - - m c CO n ° 0 -a m' Z1 O 3 o in ° 0 0 3 = v -o u, 3 III CDo- a m ° 0 0) 0 a •< (I)O co s n 3 v c 0 cD a 0 s I- 5' m' W CO CD CO CoCII CD Co C - O °J m o 1- 0 0 0 ( u' a O Co N L iL Technical Report Title Date Technical Report Title Date Technical Report Title Date Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: May 3, 2012 Surface Data Logging End of Well Report SI20-N4 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Show Reports 7. Formation Tops 8. Survey Report 9. Days vs. Depth Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format LAS Files ADI Backup GENERAL WELL INFORMATION Company: Eni Petroleum Rig: Doyon 15 Well: SI20-N4 & SI20-N4 PH Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23466-00-00 50-629-23466-70-00 (PH) Sperry Job Number: AK-AM-0009388918 Job Start Date: 22 Mar 2012 Spud Date: 26 Mar 2012 Total Depth Date: 6 April 2012 (PH) 25 April 2012 Total Depth: 4,350’ MD, 4,220.7’ TVD (PH) 12,786’ MD, 3888.8’ TVD North Reference: True Declination: 20.649˚ Dip Angle: 81.072˚ Total Field Strength: 57649.349 nT Date Of Magnetic Data: 09 Mar 2012 Wellhead Coordinates N: North 70° 33’ 27.90” Wellhead Coordinates W: West 149° 54’ 18.69“ Drill Floor Elevation: 53.99’ Ground Elevation: 13.10’ Permanent Datum: Mean Sea Level SDL Engineers: Zachary Beekman, Emil Opitz, Leigh Ann Rasher, Dave Mckechnie Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 DAILY SUMMARY Begin SI20-N4 03/22/2012 Rig is being moved. Mudloggers are on standby. 03/23/2012 Rig is being moved. Mudloggers are on standby. 03/24/2012 Mudloggers and loader operator got the mudlogging unit spotted. Mudloggers got with the rig electrician to get the unit plugged in and powered up so the heat and lights could be turned on. Once the unit and equipment were warmed up, the mudloggers were able to rig up their computers and gas equipment. 03/25/2012 Prepare the rig for pre spud acceptance. Rig conducted a pre spud meeting. Rig crew began making up the bit, motor, and BHA. Fill up the conductor. Run in hole and tag debris at 54’ MD. Trouble shoot the top drive. Clean out the conductor at 600 gpm, 400 psi, and 40 rpm to 160’ MD with the cleanout BHA. Pull out of the hole. Rig up gyro equipment. Run in the hole with BHA #2 as of midnight. 03/26/2012 Drill ahead from 160’ MD to 290’ MD. Pull out of the hole to 100’ MD. Pick up the flex stand, jar stand, float/saver sub, and cross over sub. Trip in hole to 289’ MD and gyro per DD. Drill the 16” surface hole from 289’ MD to 1357’ MD / 1306’ TVD at 600 to 760 gpm, 1300 psi, and 40 rpm. Rig down the Halliburton gyro unit at 1148’ MD. 03/27/2012 Continue drilling ahead with the 16” bit from 1357’ MD to TD at 2648’ MD / 2518’ TVD at 750 gpm, 1540 psi, and 60 rpm. Circulate bottoms up and rack back one stand per bottoms up per K&M rep to 2300’ MD at 800 gpm and 1450 psi. Monitor the well. Static. Backream out of the hole at 800 gpm, 80 rpm, and 1270 psi to 1313’ MD as of midnight. Max gas observed throughout the day was 566 units at a depth of 2029’ MD. Max gas observed while backreaming out of the hole was 322 units at a bit depth of 1693’ MD. 03/28/2012 Backream out of the hole at 800 gpm, 80 rpm, and 1200 psi from 1313’ MD to 660’ MD. Circulate two and a half bottoms up at 750 gpm, 60 rpm, and 1000 psi. Lay down the 16” BHA. Rig up and run 13 3/8” casing. Calculated displacement observed. Circulate and condition the mud for the cement job. Lay down the Franks tool and rig up the cement head. Circulate and condition the mud for the cement job as of midnight. 03/29/2012 Circulate and condition the hole for the cement job at 5 bpm and 160 psi. Pump cement. All cement returns are diverted through the stack to vac trucks. Bump the plug at the calculated strokes. 100 bbls of cement were observed at the surface. Flush surface stack with contaminated pill from pill pit #2. Nipple down the surface stack. Set the well head and test. Tested OK. Nipple up the BOP stack. Work on cleaning the pits and the cuttings box as of midnight. 03/30/2012 Changing the saver sub. Nipple up the BOP stack. Rig up to test the BOPE’s. Test the BOPE’s. Install the wear ring. Pick up BHA #3. Single in with 5” drill pipe from the pipe shed to a depth of 1732 feet as of midnight. Sperry gas equipment was calibrated for the start of the pilot hole and intermediate section. 03/31/2012 Trip in hole. Tag cement at 2535’ MD. Circulate bottoms up at 400 gpm and 390 psi. Casing pressure test for 30 minutes at 2500 psi. OK. Flush mud pump #3 with LVT. Displace mud to OBM. Clean the surface equipment. Drill out shoe track, casing shoe, and new hole to 2668’ MD. Perform an FIT at 13.0 ppg EMW. Drill ahead with the 12.25” hole to a depth of 3534’ MD at 905 gpm, 2100 psi, and 100-120 rpm. Max gas for the day was 63 units at a depth of 2940’ MD. 04/01/2012 Drill ahead with the 12.25” hole from 3534’ MD to core point at 3955’ MD / 3826’ TVD at 750 gpm, 1760 psi, 80 rpm, and 9.65 ppg ECD. Began to weight up the mud from 9.2 ppg to 9.4 ppg at 3800’ MD. At core point, circulate 3 bottoms up per K&M rep while backreaming out of the hole at 22 minutes per stand at 900 gpm, 200 psi, and 80 rpm to 2510’ MD. Monitor well static. Pull out of the hole on elevators. Lay down the BHA. Mobilize the core barrel equipment and stat picking up as of midnight. Max gas observed in the last 24 hours was 55 units at a depth of 3949’ MD. 04/02/2012 Mobilize the core barrel equipment. Make up and check the ball function in the core barrel assembly per CorPro. Make up BHA. Rabbit drill pipe in the derrick per stand. Fill pipe every 10 stands. Began washing down at 2979’ MD at 250 gpm and 325 psi. Began coring from 3955’ MD to 3971’ MD at 150 gpm and 150 psi. Pull out of the hole per CorPro spec’s for core protection. Pulled to a depth of 3530’ MD as of midnight. 04/03/2012 Pull out of the hole from 3530’ MD to 2594’ MD. Pumped a 17 bbls dry job. Continue to pull out of the hole from 2594’ MD to 650’ MD. Reciprocate for 1 hour at 650’ MD. Pull out of the hole from 650’ MD to 250’ MD. Reciprocate for 1 hour at 250’ MD. Pull out of the hole. Run in hole with the coring assembly and remove the inner cores. Lay down the coring assembly. Pick up the new coring assembly. Run in the hole from 71’ MD to 3971’ MD. Set core toll and begin coring with CorPro reps onsite from 3971’ MD to 4022’ MD. No gas and no samples were lagged up for analysis during coring. 04/04/2012 Drop and seat the ball at 3200’ psi. Backream out of the hole to 3963’ MD. Pull out of the hole from 3963’ MD to 2594’ MD. Pump a dry job then pull out of the hole from 2594’ MD to 650’ MD. Reciprocate for 1 hour at 650’ MD. Pull out of the hole to 200’ MD and reciprocate for 1 hour. Pull out of the hole to surface. Lay down the core barrel. Pick up and make up BHA #6. Run in hole from surface to 2600’ MD. Slip and cut the drill line. Run in hole from 2600’ MD to 3910’ MD as of midnight. 04/05/2012 Ream down and perform a mad pass as per SLB and geologist from 3910’ MD to 4022’ MD. Tag bottom at 4022’ MD. Drill to the new core point at 4111’ MD. Backream out of the hole from 4111’ MD to 3900’ MD. Circulate 2 bottoms up at 3900’ MD. Pull out of the hole from 3900’ MD to 2601’ MD. Pump a dry job. Pull out of the hole from 2601’ MD to the BHA. Lay down the BHA and pick up the coring tools. Run in hole from 67’ MD to 4111’ MD. Core from 4111’ MD to 4171’ MD as per CorPro and Eni reps. Max gas lagged up while pumping out of the hole after core drilled was 195 units from a depth of 4132’ MD. 04/06/2012 Pumped out of the hole form 4171’ MD to 3094’ MD. Noticed signs of packing off. Back reamed out of the hole from 3094’ MD to 2594’ MD. Attempted to pull out of the hole on elevators, noticed well started swapping. Pumped out of the hole from 2594’ MD to 2220’ MD. Monitored the well. Pulled out of the hole from 2127’ MD, no swabbing. Pumped a dry job and pulled out of the hole from 2127’ MD to 650’ MD. Reciprocate for 1 hour. Pulled out of the hole from 650’ MD to 200’ MD and reciprocate for 1 hour. Laid down the core barrels. Made up BHA #8 and ran into the hole to 4171’ MD. Drilled ahead with cleanout assembly from 4171’ MD to Pilot Hole TD at 4350’ MD. Max gas observed while drilling was 87 units at a depth of 4172’ MD. 04/07/2012 Circulated 2 bottoms up then back reamed out of the hole from 4,350’ MD to 3654’ MD Attempted to pull out of the hole, but pulled tight at 3466’ MD Back reamed out of the hole to 2909’ MD ran in the hole from 2909’ MD to 4304’ MD as per the geologist and company man. Circulated two bottoms up with the ditch magnets. Pulled out of the hole from 4340’ MD to 3562’ MD. Pumped a dry job. Pulled out of the hole from 3536’ MD to the BHA. Laid down the BHA and picked up wireline tools. Diagnosed the wireline truck spooler. Tested tools and loaded nuclear sources. Rigged down the wireline truck and unloaded the nuclear sources. Laid down the top section of the tool. Could not figure out exactly what was wrong with the truck and are waiting on a second wireline truck to come to location. 04/08/2012 Picked up the wireline tools and equipment, loaded sources and ran in the hole. Made up head and tested the tools. Troubleshot the tools and removed the PPC from the tool string. Tested the tools, rigged up PPC to the string- Tools tested OK. Ran in the hole with the quad combo wireline logging tools. Logged from 4333’ MD to the casing shoe. Pulled out of the hole to 90’ and performed the post run Gamma calibration. Unloaded the nukes and laid down wireline tools. Made up the CMR tool string. Run in the hole for the CMR logs to 4,210’ MD. Wireline CMR log from 4,210’ MD to 4099’ MD as of midnight. 04/09/2012 CMR log from 4099’ WLM. Complete CMR logs. Run in the hole and perform stationary logs at 4,134’ WLM, 4,119’ WLM, 4,020’ WLM and 3,966’ WLM. Pulled out of the hole to wireline tools. Rigged down wireline. Move collars and heavyweight to derrick. Made up mule shoe at cross over and ran in the hole to 2,523’ MD Currently observing a safety stand down. 04/10/2012 Safety stand down location wide. Break circulation of well at 20:00 hrs. Pumping at 4 bbl/min, circulating a total of 733 bbls. 04/11/2012 Safety stand down location wide. Circulating the hole at 4 bbl/min. Blow down top drive and monitor well. 04/12/2012 Circulate over top of hole while monitoring the well via trip tank. Function test mud pumps and test gas sensors. Cut drilling line. Pull out of the hole and laid down the mule shoe. Clean rig floor. Pull wear bushing and set test plug. Rig up and testing BOPs. 04/13/2012 Finished testing BOPs. Set wear bushing. Trip in the hole to ,4299’ MD. Circulate 2 bottoms up. Rig up for cementing. Pumped 50 bbl citric pill mud push, 111 bbl cement, 10 bbl citric pill. Pulled out of the hole to 3,400’ MD. Pumped nerf ball. Spot high viscosity spacer. Pulled out of the hole to 3,150’ MD. Held a pre job safety meeting for cement job. Circulated 2 bottoms up for kick off point. 04/14/2012 Pump 50 bbl citric pill and 50 bbl mud push, 120 bbl cement, 10 bbl citric pill. Rigged down cement equipment and pulled out of the hole to 2,347’ MD. Reverse circulate 42 bbl into circulation loss of returns. Pulled out of the hole to 2,056’ MD and dropped wiper ball and circulated out spacers. Blew down and rigged down cement equipment. Pulled out of the hole and laid down Mule shoe. Made up BHA #11. Shallow tested MWD tools successfully at 753’ MD. Tripped into the hole to 2,720’ MD. Cement not yet set up. Wait on cement before kicking off. 04/15/2012 Waiting for cement to set up. Kicked off as per schlumberger Directional Driller. Drilling ahead at report time. Max gas of 57 units with a 24 hour average of 22 units. 04/16/2012 Continue to drill ahead with cuttings consisting mostly of unconsolidated sands with lesser siltstone and some shale. Max gas of 365 units was noted at 4,432’ MD with an average of 57 units. 04/17/2012 Continue to drill ahead to intermediate TD of 4,957’ MD. Back reamed out of the hole as per K&M. Cuttings consisting primarily of shale and unconsolidated sands with lesser siltstone. Max gas of 1387 was noted at 4,900 with a 24 hour average of 96 units. 04/18/2012 Continue to back ream out of the hole as per K&M to 2,618’ MD. Attempted to pull out of the hole on elevators. Continue to back ream out of the hole to 2,057’ MD. Pulled out of the hole on elevators. Laid down BHA #11. Changed upper rams. Rig up casing equipment. Run in the hole with 9 5/8” casing. 04/19/2012 Finished running casing. Rigged up cement head. Pumped citric pill, mud push, 156 bbl cement 10 10 bbl water. Displaced cement with FazePro. Observed 23 bbl loss. Performed injectivity test, changed rams and picking up 5” drill pipe and beginning diesel freeze protect at time of report. 04/20/2012 Finished picking up 5” drill pipe and racked back. Freeze protect with diesel and set test plug. Test BOPs, installed wear ring and tested casing at 2000 PSI for 5 minutes. Tested OK. Picked up BHA #12 and currently running in the hole while filling every 15 stands. 04/21/2012 Ran in the hole with BHA #12. Sonic cement bond log from 2,636’ MD to 4,761’ MD. Successfully tested casing. Tagged the float collar at 4,853’ MD. Displace to new 9.25 ppg FazePro oil based mud. Tagged the shoe at 4,934’ MD. Drilled out cement and 20’ new formation to 4,997’ MD. Performed leak off test 12.9 ppg estimated mud weight. Drilling ahead at report time. Max gas of 3,824 units noted at 5,453’ with a 24 hour average of 1771 units. 04/22/2012 Continuing to drill 8.75” production section from 5,877 to 8,264 with samples consisting of unconsolidated sands with lesser amounts of calcareously cemented sandstone cuttings. Other lithologies observed include siltstone, silty sandstone, sandy siltstone and shale. Max gas of 3305 noted at 5,944’ with an average of 1729. 04/23/2012 Continue to drill 8.75” production section from 8,264’ to 10,464. Samples consist primarily of unconsolidated sand with lesser amounts of calcareously cemented sandstone cuttings. Other lithologies observed include siltstone, silty sandstone, sandy siltstone and shale. Max gas of 1679 noted at 10,299’ with an average of 811 units. 04/24/2012 Continue to drill 8.75” production section from10,464 to 12397. Samples consist primarily of unconsolidated sand with lesser amounts of calcareously cemented sandstone cuttings. Other lithologies observed include siltstone, silty sandstone, sandy siltstone and shale. Max gas of 1282 units noted at 10,899’ with an average of 546 units. 04/25/2012 Continue to drill 8.75” production section from10,464 to 12397. Samples consist primarily of unconsolidated sand with lesser amounts of calcareously cemented sandstone cuttings. Other lithologies observed include siltstone, silty sandstone, sandy siltstone and shale. Reached production TD of 12,788’ MD at 07:45 hrs. Max gas of 1084 units was noted at 12,487’ with an average of 471 units. Back reaming out of the hole at time of report. 04/26/2012 Continue to back ream out of the hole as per K&M to 4,930’ MD. Circulated the hole clean. Pumped dry job. Pulling out of the hole on elevators at time of report. 04/27/2012 Pulled out of the hole and laid down BHA #12. Made up BHA #13 and running in the hole to bottom at time of report. Consumables for SI20-N4 and SI20-N4PH were added in the daily cost. Sample catchers released from location. 04/28/2012 Spot 630 bbl of FazeAway breaker. POOH on elevators to casing shoe. Displace well to 9.1 ppg brine. Flush pumps with LVT pill, citric acid treated brine, and brine. 04/29/2012 Pulled out of hole and laid down BHA #13. Rigged up to run 5.5” slotted liner. Run in hole to 8053’ MD. Make up Baker liner hanger. Run in hole with 5” drill pipe filling every 25 stands. 04/30/2102 Run in hole with 5.5” slotted liner to 12758’ MD, set packer at liner depth of 12746’ MD. Packer set at 4662’ MD per Baker rep. PSI test to verify – Good. Lay down 5” drill pipe. . . Density (ppg) Viscosity out (sec/qt) Tuff Mud Data Casing Summary Grade ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 10.0 @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % Chlorides EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $6,810.00 Report For: Ross/Wimmer/Buchanan 0' 160' 160' Current Pump & Flow Data: Yesterday's Depth: Silt Siltst Total Charges: 3.0 RIH w/ BHA #2 Rig Activity: Flow In (spm) $2,810.00 Cht Depth in / out Smith XR+ Mill Tooth 160' Lithology (%) Ss Sh Clyst Cly (ppb Eq) cP PV MBT MWD Summary Depth 0' to 160' ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009113848 Customer: Well: Avg 1 25-Mar-2012 24:00:00 Time: Report #: Date: 2.30 19.0 34 1.117 34 Size Make 20" 16" (current) Weight 160' 200' Lst 1 8.80 160' YP Cor Solids (lb/100ft 2) 1,600 9.30 Condition GEL Depth Mud Type 109 ml/30min RPM mg/l Coal Gvl API FL 5.6 Tools ECD (ppg) Avg Min Max * 10000 units = 100% Gas In Air Connection (max) C-5n C-5i C-1 000 Gas Summary C-2 Zach Beekman C-3 0 Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) Report By: 0 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i 0' 0' Run in hole and tag debris at 54' MD. Trouble shoot the top drive. Clean out the conductor at 600 gpm, 400 psi, and 40 rpm to Prepare the rig for pre spud acceptance. Pre spud meeting. Make up the bit, motor, and BHA. Fill up the conductor. 0 md. Average 0 0 0 C-4n 0 160' with the cleanout BHA. Pull out of the hole. Rig up gyro equipment. Run in the hole with BHA #2 as of midnight. 0 0 Depth Units* 0 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: 0Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL 5.1 GEL Depth Mud Type 100 Cor Solids (lb/100ft 2) 2,200 9.50 Condition 1177' YP 1 40.0 9.20 Weight 160' 1357' 1197' Make 20" 16" (current) 2.30 19.5 34 1.117 27 Size 2 26-Mar-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009388918 Customer: Well: Avg PV MBT MWD Summary Depth 160' to 1357' Sh Clyst Cly Ss Cht Depth in / out Smith XR+ Mill Tooth 160' Lithology (%) Total Charges: 5.5 Drilling Ahead Rig Activity: Flow In (spm) 857.0 $2,810.00 (ppb Eq) cP $9,620.00 Report For: Ross/Wimmer/Buchanan 92.3 160' 1357' 1197' Current Pump & Flow Data: 636' Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH Chlorides EVAMAR % Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 605 142 SPP (psi) Gallons/stroke 815 @4.23 71.5 Max @ ft 20.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade Tuff Silt Siltst Lst * 10000 units = 100% Gas In Air Trip 907-685-0772 Unit Phone: 24 hr Recap: 25 Background Maximum 0 0 000 0 0 Depth Units* 043 600 gpm to 760 gpm, 1300 psi, and 40 rpm. Rig down the Halliburton gyro unit at 1148' MD 0 0 C-4n cross over sub. Trip in hole to 289' MD and Gyro per DD. Drill the 16" surface hole from 289' MD to 1357' MD / 1306' TVD at Drill from 160' MD to 290' MD. Pull out of the hole to 100' MD. Pick up the flex stand, jar stand, float/saver sub and 21 md. Average 0Minimum C-4i 993' 176' Chromatograph (ppm) 00 0 0 1839 5 2822 Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) Report By: Zach Beekman C-3 0 Gas Summary C-2 Connection (max) C-5n C-5i C-1 00181 . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Mud Data Casing Summary Grade ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft 20.0 826 @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 685 162 SPP (psi) Gallons/stroke % EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $12,430.00 Report For: Ross/Wimmer/Buchanan 56.7 1357' 2648' 1291' Current Pump & Flow Data: 1411' Yesterday's Depth: Total Charges: 6.0 Backreaming OOH Rig Activity: Flow In (spm) 993.2 $2,810.00 (ppb Eq) cP Cht Depth in / out Smith XR+ Mill Tooth 160' Lithology (%) Ss Sh Clyst Cly PV MBT MWD Summary Depth 1357' to 2648' ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009388918 Customer: Well: Avg 3 27-Mar-2012 24:00:00 Time: Report #: Date: 19.70 15.5 26 1.117 25 Size 20" 16" (current) Weight 160' 2648' 2488' Make 2648' YP 1 9.30 Cor Solids (lb/100ft 2) 1,100 9.50 Condition 60.0 Chlorides GEL Depth Mud Type - ml/30min RPM mg/l Coal Gvl API FL 5.1 Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD * 10000 units = 100% Gas In Air Connection (max) C-5n C-5i C-1 002105 Gas Summary C-2 Zach Beekman C-3 0 Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) Report By: 20260 22 70894 Chromatograph (ppm) 00 0 0 Minimum C-4i 2029' 1358' bottoms up and rack back one stand per bottoms up per K&M rep to 2300' MD at 800 gpm and 1450 psi. Monitor the well as Drill 16" surface hole from 1357' MD to TD at 2648' MD / 2518' TVD at 745 gpm, 1540 psi, and 60 rpm. Circulate 176 md. Average 0 0 0 C-4n 322 units at a bit depth of 1693' MD. 566 static. Backream out of the hole at 800 gpm, 80 rpm and 1270 psi to 1313' MD as of midnight. Monitor the well is static. Max gas observed throughout the day was 566 units at a depth of 2029' MD. Max gas observed while backreaming out of the hole was 0 0 Depth Units* 0 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL -GEL Depth Mud Type - 1-1-WT-A-I-E-NO-TD Cor Solids (lb/100ft 2) -8.70 Condition 60.0 Chlorides 2648' YP 1 9.50 Weight 160' 2648' 2488' Make 20" 16" (current) 18.50 - 18 1.117 23 Size 4 28-Mar-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009388918 Customer: Well: Avg PV MBT MWD Summary Depth 2648' to 2648' Sh Clyst Cly Ss Cht Depth in / out Smith XR+ Mill Tooth 160' Lithology (%) Total Charges: - Circulate/Condition Rig Activity: Flow In (spm) $2,810.00 (ppb Eq) cP $14,240.00 Report For: Ross/Wimmer/Buchanan 2648' 2648' 0' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft 20.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade Tuff Silt Siltst Lst * 10000 units = 100% Gas In Air Trip 907-685-0772 Unit Phone: 24 hr Recap: Background Maximum 0 0 000 0 0 Depth Units* 0 observed. Circulate and condition the mud for cement job. Lay down the Franks tool and rig up the cement head. Circulate and condition the mud for the cement job as of midnight. 0 0 C-4n bottoms up at 750 gpm, 60 rpm, and 1000 psi. Lay down the 16" BHA. Rig up and run 13 3/8" casing. Calculate displacement Backream out of the hole at 800 gpm, 80 rpm, and 1200 psi from 1313' MD to 660' MD. Circulate two and a half md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) Report By: Zach Beekman C-3 0 Gas Summary C-2 Connection (max) C-5n C-5i C-1 000 . . Density (ppg) Viscosity out (sec/qt) Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD ml/30min RPM mg/l Coal Gvl API FL -GEL Depth Mud Type - 1-1-WT-A-I-E-NO-TD Cor Solids (lb/100ft 2) -9.00 Condition 60.0 Chlorides 2648' YP 1 9.45 Weight 160' 2648' 2488' Make 20" 16" (current) 18.50 - 18 1.117 25 Size 5 29-Mar-2012 24:00:00 Time: Report #: Date: ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009388918 Customer: Well: Avg PV MBT MWD Summary Depth 2648' to 2648' Sh Clyst Cly Ss Cht Depth in / out Smith XR+ Mill Tooth 160' Lithology (%) Total Charges: - R/U BOP Stack Rig Activity: Flow In (spm) $2,810.00 (ppb Eq) cP $20,750.00 Report For: Ross/Wimmer/Buchanan 2648' 2648' 0' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) Hours ROP (ft/hr) Bit Type TFA pH EVAMAR % Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke @4.23 Max @ ft 20.0 Area: Location: ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Mud Data Casing Summary Grade Tuff Silt Siltst Lst * 10000 units = 100% Gas In Air Trip 907-685-0772 Unit Phone: 24 hr Recap: Background Maximum 0 0 000 0 0 Depth Units* 0 Flush surface stack with contaminated pill from pill pit #2. Nipple down the surface stack. Set the wellhead and test. Tested OK. Nipple up the BOP stack. Work on cleaning the pits and the cuttings box as of midnight. 0 0 C-4n diverted through the stack to vac trucks. Bump the plug at the calculated strokes. 100 bbls of cement were observed at the surface. Circulate and condition the hole for the cement job at 5 bpm and 160 psi. Pump cement. All cement returns are md. Average 0Minimum C-4i Chromatograph (ppm) 00 0 0 0 0 Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) Report By: Zach Beekman C-3 0 Gas Summary C-2 Connection (max) C-5n C-5i C-1 000 . . Density (ppg) Viscosity out (sec/qt) Tuff Silt Siltst Lst Mud Data Casing Summary Grade L-80 ROP Set At Size 178.9 X-65 Bit # Current in Footage WOB Area: Location: Max @ ft @4.23 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% SPP (psi) Gallons/stroke % BTC EVAMAR ROP (ft/hr) Bit Type TFA pH Flow In (gpm) Hours $23,560.00 Report For: Ross/Wimmer/Buchanan 2648' 2648' 0' Current Pump & Flow Data: Yesterday's Depth: Total Charges: - P/U 5" DP Rig Activity: Flow In (spm) $2,810.00 (ppb Eq) cP Cht Depth in / out Smith GF15B Insert Bit 160' 2636' Lithology (%) Ss Sh Clyst Cly PV MBT MWD Summary Depth 2648' to 2648' ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009388918 Customer: Well: Avg 6 30-Mar-2012 24:00:00 Time: Report #: Date: - 18 1.117 25 Size 20" 13.375 12.25" (current) 68.0 Weight 2648' Make 2648' YP 2 9.45 Cor Solids (lb/100ft 2) -- Condition Chlorides GEL Depth Mud Type - ml/30min RPM mg/l Coal Gvl API FL - Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD * 10000 units = 100% Gas In Air Connection (max) C-5n C-5i C-1 000 Gas Summary C-2 Zach Beekman C-3 0 Logging Engineers: Zach Beekman / Leigh Ann Rasher (max) (current) Report By: 0 0 Chromatograph (ppm) 00 0 0 Minimum C-4i Pick up BHA #3. Single in with 5" drill pipe from the pipe shed to a depth of 1732 feet as of midnight. Sperry gas equipment Changing the saver sub. Nipple up the BOP stack. Rig up to test the BOPE's. Test the BOPE's. Install the wear ring. md. Average 0 0 0 C-4n was calibrated for the start of the pilot hole and intermediate section. 0 0 Depth Units* 0 0000 0 Maximum 907-685-0772 Unit Phone: 24 hr Recap: Background Trip . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" BTC Grade L-80 ROP Set At Size 178.9 X-65 Bit # Area: Location: 96% 904 214 SPP (psi) Gallons/stroke 1985 @ Yesterday's Depth: 40.7 Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM Hours Bit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 2891'107.0 4.23 Flow In (spm) MWD Summary Total Charges: 2648' 3534' 886' Current Depth: 24 Hour Progress: Drilling 12.25" Hole Rig Activity: Doyon 15 Daily Charges: $3,410.00 7.4 Alkal Lime $26,970.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Tuff Gvl Coal 68.0 Weight Size Smith GF15B Insert Bit 160' 2636' 10 Lithology (%) (current) Sh Clyst Footage ENI Petroleum SI29-S2 Spy Island 24 hr Max North Slope 532.2 Customer: Well: Avg 1.117 16 12.25" 886' PV Oil / Water 2648' WOB 7 31-Mar-2012 24:00:00 Time: Report #: Date: AK-AM-0009388918 9.30 66/34 16 Ss Lst EVAMAR Make 9.30 115.0 2 70 Cht Silt Siltst 20 YP Cor Solids (lb/100ft 2) 3.45 2.65 Mud (lb/bbl) ml/30min 3534' Faze Pro Depth Mud Type Depth 3534'to 2648' Avg Min Max ECD (ppg) Tools API FL 25.0 * 10000 units = 100% Gas In Air Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) C-5i 907-685-0772 Unit Phone: 0 Zach Beekman Report By: C-1 0Maximum 0 0 Depth C-2 C-3 274 Minimum Average 0711 0 0 003227' 63 Units* 11 2940' at 2500 psi. Ok. Flush mud pump #3 with LVT. Displace spud mud to OBM. Clean the surface equipment. Drill out shoe track, Trip in hole. Tag FC at 2535' MD. Circulate bottoms up at 400 gpm and 390 psi. Casing pressure test for 30 minutes 16 md. casing shoe, and new hole to 2668' MD. Perform an FIT at 13.0 ppg EMW. Drill 12.25" hole at 905 gpm, 2100 psi, and 100-120 rpm. 7396 0 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 24 hr Recap: 15 Background Connection (max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL 30.0 Depth 3955'to 3534' Avg Min Max 3955' Faze Pro Depth Mud Type YP 2-2-BT-A-E-I-ER-CP Cor Solids (lb/100ft 2) 4.29 3.30 Mud (lb/bbl) ml/30min 2 10 Cht Silt Siltst 90 Ss Lst EVAMAR Make 9.40 100.0 12.60 62/38 15 2648' 3955' WOB 8 1-Apr-2012 24:00:00 Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 1.117 17 12.25" 1307' PV Oil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope 431.3 Lithology (%) (current) Sh Clyst 68.0 Weight Size Smith GF15B Insert Bit 160' 2636' Tuff Gvl Coal $3,410.00 8.4 Alkal Lime $30,380.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Total Charges: 3534' 3955' 421' Current Depth: 24 Hour Progress: P/U Core Barrel Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 3736'35.0 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set At Size 178.9 X-65 Bit # Grade L-80 20" 13 3/8" BTC * 10000 units = 100% Gas In Air Connection (max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 5031 10 Gas Summary md. K&M rep while backreaming out of the hole at 22 minutes per stand at 900 gpm, 200 psi, and 80 rpm to 2510' MD. Monitor well static. Pull out of the hole on elevators. Lay down the BHA. Mobilize core barrel equipment and start picking up as of midnight. Max gas observed in the last 24 hours was 55 units. and 9.65 ppg ECD. Begin to weight up the system from 9.2 ppg to 9.4 ppg at 3800' MD. At core point, circulate 3 bottoms up per Drill ahead with 12.25" hole from 3534' MD to 3955' MD / 3826' TVD before core point at 750 gpm, 1760 psi, 80 rpm, 27 Units* 16 3949'55 3651' 0 0 00Minimum Average 01028 0 Depth C-2 C-3 131 C-1 0Maximum 0 907-685-0772 Unit Phone: 0 Zach Beekman Report By: Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" BTC Grade L-80 ROP Set At Size 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM Hours Bit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 3959'4.7 4.23 Flow In (spm) MWD Summary Total Charges: 3955' 3971' 16' Current Depth: 24 Hour Progress: POOH Core Barrel Rig Activity: Doyon 15 Daily Charges: $3,410.00 9.0 Alkal Lime $33,790.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Tuff Gvl Coal 68.0 Weight Size CorPro MC572 Core Bit 160' 2636' Lithology (%) (current) Sh Clyst Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope 34.8 Customer: Well: Avg 1.910 18 12.25" 16' PV Oil / Water 3955' 3971' WOB 9 2-Apr-2012 24:00:00 Time: Report #: Date: AK-AM-0009388918 2.90 62/38 16 Ss Lst EVAMAR Make 9.50 40.0 3 10 Cht Silt Siltst 90 YP Cor Solids (lb/100ft 2) 3.51 2.70 Mud (lb/bbl) ml/30min 3971' Faze Pro Depth Mud Type Depth 3971'to 3955' Avg Min Max ECD (ppg) Tools API FL 5.0 * 10000 units = 100% Gas In Air Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) C-5i 907-685-0772 Unit Phone: 0 Zach Beekman Report By: C-1 0Maximum 0 0 Depth C-2 C-3 167 Minimum Average 07049 0 0 003965' 139 Units* 11 3962' Rabbit drill pipe in derrick per stand. Fill pipe every 10 stands. Begin washing down at 2979' Md at 250 gpm and 325 psi. Begin Mobilize the core barrel equipment. Make up and chek ball function in core barrel assembly per CorPro. Make up BHA. 82 md. coring from 3955' MD to 3971' MD at 150 gpm and 150 psi. Pull out of the hole pre CorPro spec's for core protection. Pulled to a depth of 3530' MD as of midnight. 16227 33 Gas Summary C-5n 00 C-4i C-4n 18 0 0 0 0 0 Trip 24 hr Recap: Background Connection (max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL 5.0 Depth 4021'to 3971' Avg Min Max 4021' Faze Pro Depth Mud Type YP Cor Solids (lb/100ft 2) 2.99 2.30 Mud (lb/bbl) ml/30min 3 Cht Silt Siltst Ss Lst EVAMAR Make 9.50 40.0 2.90 63/37 10 3955' 3971' WOB 10 3-Apr-2012 24:00:00 Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 1.910 18 12.25" 16' PV Oil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope 105.4 Lithology (%) (current) Sh Clyst 68.0 Weight Size CorPro MC572 Core Bit 160' 2636' Tuff Gvl Coal $3,410.00 8.9 Alkal Lime $37,200.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 3971' 4021' 50' Current Depth: 24 Hour Progress: POOH Core Barrel Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 3990'28.5 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set At Size 178.9 X-65 Bit # Grade L-80 20" 13 3/8" BTC * 10000 units = 100% Gas In Air Connection (max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 0 0 Gas Summary md. Pull out of the hole. Run in hole with the coring assembly and remove the inner cores. Lay down the coring assembly. Pick up coring assembly. Run in the hole from 71' MD to 3971' MD. Set core toll and begin coring with CorPro reps onsite from 3971' MD to 4022' MD. No gas and no samples were lagged up for analysis during coring. to 650' MD. Riciprocate for 1 hour at 650' MD. Pull out of the hole from 650' MD to 250' MD. Riciprocate for 1 hour at 250' MD. Pull out of the hole from 3530' MD to 2594' MD. Pumped a 17 bbls dry job. Continue to pull out of the hole from 2594' Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum 0 907-685-0772 Unit Phone: 0 Zach Beekman Report By: Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" BTC Grade L-80 ROP Set At Size 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM Hours Bit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 4021' 4021' 0' Current Depth: 24 Hour Progress: Slip n Cut / RIH Rig Activity: Doyon 15 Daily Charges: $3,410.00 8.9 Alkal Lime $40,610.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Tuff Gvl Coal 68.0 Weight Size Smith GF15B Insert Bit 160' 2636' Lithology (%) (current) Sh Clyst Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Customer: Well: Avg 1.117 19 12.25" PV Oil / Water 4021' WOB 11 4-Apr-2012 24:00:00 Time: Report #: Date: AK-AM-0009388918 64/36 11 Ss Lst EVAMAR Make 9.50 RR2 Cht Silt Siltst YP Cor Solids (lb/100ft 2) 2.99 2.30 Mud (lb/bbl) ml/30min 4021' Faze Pro Depth Mud Type Depth 4021'to 4021' Avg Min Max ECD (ppg) Tools API FL * 10000 units = 100% Gas In Air Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) C-5i 907-685-0772 Unit Phone: 0 Zach Beekman Report By: C-1 0Maximum 0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* Pump dry job then pull out of the hole from 2594' MD to 650' MD. Reciprocate for 1 hour at 650' MD. Pull out of the hole to 200' MD Drop and seat the ball at 3200 psi. Backream out of the hole to 3963' MD. Pull out of the hole from 3963' Md to 2594'. md. and reciprocate for 1 hour. Pull out of the hole to surface. Lay down the core barrel. Pick up and make up BHA #6. Run in hole from surface to 2600' MD. Slip and cut the drill line. Run in hole from 2600' MD to 3910' MD as of midnight. 0 0 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 24 hr Recap: Background Connection (max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" BTC Grade L-80 ROP Set At Size 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM Hours Bit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4156'28.6 4.23 Flow In (spm) MWD Summary Total Charges: 4021' 4171' 150' Current Depth: 24 Hour Progress: POOH w/ Core Barrel Rig Activity: Doyon 15 Daily Charges: $3,410.00 8.8 Alkal Lime $44,020.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Tuff Gvl Coal 68.0 Weight Size Smith GF15B Insert Bit 160' 2636' Lithology (%) (current) Sh Clyst Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope 139.8 Customer: Well: Avg 1.117 19 12.25" 90' PV Oil / Water 4021' 4111' WOB 12 5-Apr-2012 24:00:00 Time: Report #: Date: AK-AM-0009388918 2.30 64/36 11 Ss Lst EVAMAR Make 9.50 80.0 RR2 Cht Silt Siltst 100 YP 2-2-BT-A-E-I-ER-CP Cor Solids (lb/100ft 2) 2.73 2.10 Mud (lb/bbl) ml/30min 4157' Faze Pro Depth Mud Type Depth 4171'to 4021' Avg Min Max ECD (ppg) Tools API FL 9.0 * 10000 units = 100% Gas In Air Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) C-5i 907-685-0772 Unit Phone: 0 Zach Beekman Report By: C-1 0Maximum 0 0 Depth C-2 C-3 0Minimum Average 000 0 004120' 195 Units* 21 4132' Drill to the new core point at 4111' MD. Backream out of hole from 4111' MD to 3900' MD. Circulate 2 bottoms up at 3900' MD. Ream down and perform a mad pass as per SLB and geologist from 3910' MD to 4022' MD. Tag bottom at 4022' MD. 120 md. Pull out of the hole from 3900' MD to 2601' MD. Pump a dry job. Pull out of the hole from 2601' MD to the BHA. Lay down the BHA and pick up the coring tools. Run in hole from 67' MD to 4111' MD. Core from 4111' MD to 4171' MD as per CorPro and Eni reps. Max gas lagged up while pumping out of hole after core drilled was 195 units from a depth of 4132' MD. 0 0 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 24 hr Recap: Background Connection (max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL 30.0 Depth 4350'to 4171' Avg Min Max 4333' Faze Pro Depth Mud Type YP Cor Solids (lb/100ft 2) 2.86 2.20 Mud (lb/bbl) ml/30min RR2 Cht Silt Siltst 50 Ss Lst EVAMAR Make 9.50 95.0 5.70 63/37 10 4171' 4350' WOB 13 6-Apr-2012 24:00:00 Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 1.117 21 12.25" 179' PV Oil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope 124.6 50 Lithology (%) (current) Sh Clyst 68.0 Weight Size Smith GF15B Insert Bit 160' 2636' Tuff Gvl Coal $3,410.00 10.1 Alkal Lime $47,430.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 4171' 4350' 179' Current Depth: 24 Hour Progress: BROOH Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4173'29.1 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set At Size 178.9 X-65 Bit # Grade L-80 20" 13 3/8" BTC * 10000 units = 100% Gas In Air Connection (max) Chromatograph (ppm) 24 hr Recap: Background Trip 4 1 1 0 0 2 C-4i C-4n C-5n 00 4673 10 Gas Summary md. 2220' MD. Monitor well. Pull out of the hole to 2127' MD, no swabbing. Pump a dry job. Pull out of the hole from 2127' MD to 650' MD. Recicprocate for 1 hour. Pull out of the hole from 650' MD to 200' MD and reciprocate for 1 hour. Lay down the core barrels. Make up BHA #8 and run in hole to 4171' MD. Drill ahead with clean out assembly from 4171' MD to pilot hole TD at 4350' MD. Max gas to 2594' MD. Attempt to pull out of the hole on elevators, noticed well started swabbing. Pumped out of the hole from 2594' MD to Pump out of the hole from 4171' MD to 3094' MD. Notice signs of packing off. Backream out of the hole from 3094'MD 32 observed while drilling was 87 units at a depth of 4172' MD. Units* 22 4172'87 4198' 1 3 00Minimum Average 02554 0 Depth C-2 C-3 113 C-1 0Maximum 4 907-685-0772 Unit Phone: 0 Zach Beekman Report By: Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" BTC Grade L-80 ROP Set At Size 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM Hours Bit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 4350' 4350' 0' Current Depth: 24 Hour Progress: Waiting on Wireline Rig Activity: Doyon 15 Daily Charges: $3,410.00 8.9 Alkal Lime $50,840.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Tuff Gvl Coal 68.0 Weight Size Smith GF15B Insert Bit 160' 2636' Lithology (%) (current) Sh Clyst Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Customer: Well: Avg 1.117 21 12.25" 179' PV Oil / Water 4171' 4350' WOB 14 7-Apr-2012 24:00:00 Time: Report #: Date: AK-AM-0009388918 5.70 64/36 15 Ss Lst EVAMAR Make 9.45 95.0 RR2 Cht Silt Siltst YP Cor Solids (lb/100ft 2) 2.34 1.80 Mud (lb/bbl) ml/30min 4350' Faze Pro Depth Mud Type Depth 4350'to 4350' Avg Min Max ECD (ppg) Tools API FL 30.0 * 10000 units = 100% Gas In Air Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) C-5i 907-685-0772 Unit Phone: 0 Zach Beekman Report By: C-1 0Maximum 0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* a second wireline truck to come to location. hole, but pulled tight at 3466' MD. Backreamed out of the hole to 2909' MD. Run in hole from 2909' MD to 4340' MD as per the Circulated two bottoms up then backreamed out of the hole from 4350' MD to 3654' MD. Attempted to pull out of the nuclear sources. Laid down the top section of the tool. Could not figure out exactly what was wrong with truck and are waiting on md. geologist and company man. Circulated two bottoms up with the ditch magnets. Pulled out of the hole from 4340' MD to 3562' MD. Pumped a dry job. Pulled out of the hole from 3536' MD to the BHA. Laid down the BHA and picked up wireline tools. Diagnosed the wireline truck spooler. Tested tools and loaded the nuclear sources. Rigged down the wireline truck and unloaded the 0 0 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 24 hr Recap: Background Connection (max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL 30.0 Depth 4350'to 4350' Avg Min Max 4350' Faze Pro Depth Mud Type YP 2-2-BT-A-E-I-ER-TD Cor Solids (lb/100ft 2) 2.34 1.80 Mud (lb/bbl) ml/30min 2 RR2 Cht Silt Siltst Ss Lst EVAMAR Make 9.45 95.0 5.70 64/36 16 4171' 4350' WOB 15 8-Apr-2012 24:00:00 Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 1.117 20 12.25" 179' PV Oil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Lithology (%) (current) Sh Clyst 68.0 Weight Size Smith GF15B Insert Bit 160' 2636' Tuff Gvl Coal $3,410.00 9.4 Alkal Lime $54,250.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 4350' 4350' 0' Current Depth: 24 Hour Progress: Wireline Logging Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set At Size 178.9 X-65 Bit # Grade L-80 20" 13 3/8" BTC * 10000 units = 100% Gas In Air Connection (max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 0 0 Gas Summary md. the quad combo wireline logging tools. Logging from 4333' MD to the casing shoe. Pull out of hole to 90' and perform the post run Gamma calibration. Unload the nukes. Lay down the wireline tools. Make up the CMR tool string. Run in hole for the CMR logs to 4210' MD. Wireline CMR log from 4210' MD to 4099' MD as of midnight. the tools and remove the PPC from the tool string. Test tools. Rig up the PPC to string, and the tools tested OK. Run in hole with Pick up the wireline tools and equipment, load sources and run in hole. Make up head and test the tools. Troubleshoot Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum 0 907-685-0772 Unit Phone: 0 Zach Beekman Report By: Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" BTC Grade L-80 ROP Set At Size 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM Hours Bit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 4350' 4350' 0' Current Depth: 24 Hour Progress: Safety Stand Down Rig Activity: Doyon 15 Daily Charges: $3,410.00 9.4 Alkal Lime $57,660.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Tuff Gvl Coal 68.0 Weight Size 160' 2636' Lithology (%) (current) Sh Clyst Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Customer: Well: Avg 20 PV Oil / Water WOB 16 9-Apr-2012 24:00:00 Time: Report #: Date: AK-AM-0009388918 64/36 16 Ss Lst EVAMAR Make 9.45 Cht Silt Siltst YP Cor Solids (lb/100ft 2) 2.34 1.80 Mud (lb/bbl) ml/30min 4350' Faze Pro Depth Mud Type Depth 4350'to 4350' Avg Min Max ECD (ppg) Tools API FL * 10000 units = 100% Gas In Air Logging Engineers: Zach Beekman/Leigh Ann Rasher (max) (current) C-5i 907-685-0772 Unit Phone: 0 Zach Beekman Report By: C-1 0Maximum 0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* 4020' WLM, and 3966' WLM. Pull out of the hole to wireline tools. Rig down wireline. Move collars and heavy weight to derrick. CMR log from 4099' WLM. Complete CMR logs. Run in hole and perform stationary logs at 4134' WLM, 4119' WLM, md. Make up mule shoe at XO to drill pipe and run in hole to 2523' MD. Currently observing a safety stand down. 0 0 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 24 hr Recap: Background Connection (max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL Depth 4350'to4350' Avg Min Max 4350' Faze Pro Depth Mud Type YP Cor Solids (lb/100ft2) 2.341.80 Mud (lb/bbl)ml/30min Cht Silt SiltstSs Lst EVAMAR Make 9.50 65/35 17 WOB 17 10-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 20 PVOil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size 160' 2636' TuffGvlCoal $3,410.00 7.9 Alkal Lime $61,070.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 4350' 4350' 0' Current Depth: 24 Hour Progress: Safety Stand DownRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set AtSize 178.9 X-65 Bit # Grade L-80 20" 13 3/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 00 Gas Summary md 733 bbls. Safety stand down location wide. Break circulation of well @ 2000 hrs, pumping @ 4 bbl/min, circulating a total of Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 Emil OpitzReport By:Logging Engineers:Emil Opitz / Leigh Ann Rasher (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" BTC Grade L-80 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 4350' 4350' 0' Current Depth: 24 Hour Progress: Safety Stand DownRig Activity: Doyon 15 Daily Charges:$3,410.00 9.4 Alkal Lime $64,480.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size 160' 2636' Lithology (%) (current) ShClyst Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Customer: Well: Avg 20 PVOil / Water WOB 18 11-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 64/36 15 Ss Lst EVAMAR Make 9.45 Cht Silt Siltst YP Cor Solids (lb/100ft2) 2.341.80 Mud (lb/bbl)ml/30min 4350' Faze Pro Depth Mud Type Depth 4350'to4350' Avg Min MaxECD (ppg) Tools API FL * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / Leigh Ann Rasher (max)(current) C-5i 907-685-0772Unit Phone: 0 Emil OpitzReport By: C-1 0Maximum0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* Safety stand down location wide. Circulate hole @ 4 bbl/min. Blow down top drive and monitor well. md 00 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 24 hr Recap: Background Connection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL Depth 4350'to4350' Avg Min Max 4350' Faze Pro Depth Mud Type YP Cor Solids (lb/100ft2) 2.211.70 Mud (lb/bbl)ml/30min Cht Silt SiltstSs Lst EVAMAR Make 9.45 64/36 13 WOB 19 12-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 21 PVOil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size 160' 2636' TuffGvlCoal $3,410.00 8.9 Alkal Lime $69,490.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 4350' 4350' 0' Current Depth: 24 Hour Progress: BOP TestingRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set AtSize 178.9 X-65 Bit # Grade L-80 20" 13 3/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 00 Gas Summary md Note: Updated costs line. POOH and L/D mule shoe. Clean rig floor. Pull wear bushing and set test plug. R/U and test BOPs. Circulate over top of hole monitoring well via trip tank. Function test mud pumps and test gas sensors. Cut drilling Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 Emil OpitzReport By:Logging Engineers:Emil Opitz / Leigh Ann Rasher (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" BTC Grade L-80 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 4350' 4350' 0' Current Depth: 24 Hour Progress: CementingRig Activity: Doyon 15 Daily Charges:$3,410.00 8.6 Alkal Lime $72,900.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size 160' 2636' Lithology (%) (current) ShClyst Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Customer: Well: Avg 22 PVOil / Water WOB 20 13-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 9.55 63/37 15 Ss Lst EVAMAR Make 9.55 Cht Silt Siltst YP Cor Solids (lb/100ft2) 1.561.20 Mud (lb/bbl)ml/30min 4350' Faze Pro Depth Mud Type Depth 4350'to4350' Avg Min MaxECD (ppg) Tools API FL * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / Leigh Ann Rasher (max)(current) C-5i 907-685-0772Unit Phone: 0 Emil OpitzReport By: C-1 0Maximum0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* Pump 50bbl citric pill, 50 bbl mudpush, 111 bbl cement, 10 bbl citric pill. POOH to 3400' MD. Pump nerf ball. Spot Hi Vis spacer. Finish testing BOPs. Set wear bushing. TIH to 4299' MD. Wash and ream to 4350' MD. CBU 2x. R/U for cementing. md POOH to 3150' MD. PJSM for kick off cementing job. CBU 2x for kick off point. 00 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip 14 24 hr Recap: Background Connection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools SP Motor 1.5*, ARC825, PowerPulse 825 API FL Depth 2720'to4350' Avg Min Max Faze Pro Depth Mud Type YP Cor Solids (lb/100ft2) 2.211.70 Mud (lb/bbl)ml/30min 5 Cht Silt SiltstSs Lst EVAMAR Make 9.60 62/38 19 WOB 21 14-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 1.117 24 12.25 PVOil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size Hughes VMD-3 Milltooth 160' 2636' TuffGvlCoal $3,410.00 10.3 Alkal Lime $76,310.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 4350' 2720' -1630' Current Depth: 24 Hour Progress: Waiting on cementRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set AtSize 178.9 X-65 Bit # Grade L-80 20" 13 3/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 00 Gas Summary md wiper ball and circ out spacers. Blow down / R/D circ equipment. POOH and L/D mule shoe. M/U BHA #11. Shallow test MWD tools @ 753' MD. TIH to 2720' MD. Cement not yet set up. Wait on cement to set up before kicking off. 2347' MD. Reverse circulate 42 bbl into circulation loss of returns. Pump down DP with full returns. POOH to 2056' MD and drop Pump 50bbl citric pill and 50bbl mud push, 120 bbl cement, 10 bbl citric pill. R/D cementing equipment. POOH to Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 Emil OpitzReport By:Logging Engineers:Emil Opitz / Leigh Ann Rasher (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" BTC Grade L-80 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 904 214 SPP (psi) Gallons/stroke 2464 @ Yesterday's Depth: 79.4 Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 3388'233.2 4.23 Flow In (spm) MWD Summary Total Charges: 2720' 3685' 965' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 Daily Charges:$3,410.00 10.1 Alkal Lime $79,720.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size Hughes VMD-3 Milltooth 160' 2636' 60 Lithology (%) (current) ShClyst Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope 946.7 Customer: Well: Avg 1.117 2666 12.25 PVOil / Water 2720' WOB 22 15-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 60/40 21 Ss 4.0 Lst EVAMAR Make 9.30 5 30 Cht Silt Siltst 10 YP Cor Solids (lb/100ft2) 1.691.30 Mud (lb/bbl)ml/30min 3400' Faze Pro Depth Mud Type Depth 3685'to2720' 10.259.709.91 Avg Min MaxECD (ppg) Tools SP Motor 1.5*, ARC825, PowerPulse 825 API FL * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / Leigh Ann Rasher (max)(current) C-5i 907-685-0772Unit Phone: 0 Emil OpitzReport By: C-1 0Maximum0 0 Depth C-2 C-3 340Minimum Average 012620 0 002767' 57 Units* 7 2884' Wait for cement to set up. Kick off per SLB DD @ 2720' MD. Drill ahead. 22 md 5925 0 Gas Summary C-5n 00 C-4i C-4n 2 0 0 0 0 0 Trip 24 hr Recap: 13Background Connection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools SP Motor 1.5*, ARC825, PowerPulse 825 API FL Depth 4389'to3685' 10.599.539.66 Avg Min Max 4389' Faze Pro Depth Mud Type YP Cor Solids (lb/100ft2) 2.081.60 Mud (lb/bbl)ml/30min 5 20 Cht Silt Siltst 80 Ss 4.2 Lst EVAMAR Make 9.45 9.45 64/36 15 2720' WOB 23 16-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 1.117 2858 12.25 PVOil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope 830.6 Lithology (%) (current) ShClyst 68.0 Weight Size Hughes VMD-3 Milltooth 160' 2636' TuffGvlCoal $3,410.00 11.0 Alkal Lime $83,130.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 3685' 4389' 704' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4271'147.9 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: 72.4 Rig: Job No.: ROP (ft/hr) Area: Location: 96% 702 166 SPP (psi) Gallons/stroke 1737 ROP Set AtSize 178.9 X-65 Bit # Grade L-80 20" 13 3/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 24 hr Recap: 31Background Trip 9 8 1 0 0 0 C-4i C-4n C-5n 00 44351 110 Gas Summary md Continue to drill ahead. Cuttings consist primarily of unconsolidated sands, with lesser siltstone, and some shale. 57 Units* 19 4342'365 3747' 0 0 00Minimum Average 03430 0 Depth C-2 C-3 242 C-1 0Maximum0 907-685-0772Unit Phone: 0 Emil OpitzReport By:Logging Engineers:Emil Opitz / Leigh Ann Rasher (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" BTC Grade L-80 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 905 213 SPP (psi) Gallons/stroke 2037 @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4912'83.7 4.23 Flow In (spm) MWD Summary Total Charges: 4389' 4957' 568' Current Depth: 24 Hour Progress: BROOHRig Activity: Doyon 15 Daily Charges:$3,410.00 12.3 Alkal Lime $86,540.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size Hughes VMD-3 Milltooth 160' 2636' Lithology (%) (current) ShClyst Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope 708.5 Customer: Well: Avg 1.117 2856 12.25 PVOil / Water 2720' WOB 24 17-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 9.55 64/36 16 Ss 4.2 Lst EVAMAR Make 9.55 5 10 Cht Silt Siltst 90 YP Cor Solids (lb/100ft2) 3.192.45 Mud (lb/bbl)ml/30min 4957' Faze Pro Depth Mud Type Depth 4957'to4389' 9.969.599.70 Avg Min MaxECD (ppg) Tools SP Motor 1.5*, ARC825, PowerPulse 825 API FL * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / Leigh Ann Rasher (max)(current) C-5i 907-685-0772Unit Phone: 33 Emil OpitzReport By: C-1 64Maximum101 0 Depth C-2 C-3 969Minimum Average 053932 93 004556' 1387 Units* 29 4900' unconsolidated sands, with lesser siltstone. Continue to drill ahead to intermediate TD of 4957' MD. BROOH per K&M. Cuttings consist primarily of shale and 96 md 151665 381 Gas Summary C-5n 00 C-4i C-4n 10 3 1 0 2 116 Trip 143 24 hr Recap: Background Connection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL Depth 4957'to4957' Avg Min Max 4957' Faze Pro Depth Mud Type YP Cor Solids (lb/100ft2) 2.992.30 Mud (lb/bbl)ml/30min 5 Cht Silt SiltstSs Lst EVAMAR Make 9.55 64/36 16 2720' 4957' WOB 25 18-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 1.117 2868 12.25 PVOil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size Hughes VMD-3 Milltooth 160' 2636' TuffGvlCoal $4,710.00 12.3 Alkal Lime $91,250.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 4957' 4957' 0' Current Depth: 24 Hour Progress: RIH w/ 9 5/8" casingRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set AtSize 178.9 X-65 Bit # Grade L-80 20" 13 3/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 00 Gas Summary md elevators. L/D BHA #11. Change upper rams. R/U casing equipment. RIH with 9 5/8" casing. Continue to BROOH per K&M to 2618' MD. Attempt to POOH on elevators. Continue to BROOH to 2057' MD. POOH on Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 Emil OpitzReport By:Logging Engineers:Emil Opitz / David Mckechnie (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools API FL 40.0 Depth 4957'to4957' Avg Min Max 4957' Faze Pro Depth Mud Type YP 3-7-WT-A-E-5-RG-TD Cor Solids (lb/100ft2) 2.602.00 Mud (lb/bbl)ml/30min 5 Cht Silt SiltstSs Lst EVAMAR Make 9.55 60.031.70 64/36 16 2723' 4957' WOB 26 19-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 1.117 2871 12.25 2234' PVOil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size Hughes VMD-3 Milltooth 160' 2636' TuffGvlCoal $3,410.00 12.3 Alkal Lime $94,660.00 Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: 4957' 4957' 0' Current Depth: 24 Hour Progress: P/U 5" DPRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set AtSize 178.9 X-65 Bit # Grade L-80 20" 13 3/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 118 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 00 Gas Summary md cement with FazePro. 23 bbl loss. Injectivity test. Change rams. P/U 5" DP. Begin diesel freeze protect. Finish running casing. R/U cement head. Pump citrate pill, mudpush, 156 bbl cement and 10 bbl water. Displace Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 Emil OpitzReport By:Logging Engineers:Emil Opitz / David Mckechnie (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed675, EcoScope675, TeleScope675, sonicVision675 API FL Depth 4957'to4957' Avg Min Max 4957' Faze Pro Depth Mud Type YP Cor Solids (lb/100ft2) 3.382.60 Mud (lb/bbl)ml/30min 6 Cht Silt Siltst HYDRIL Ss Lst EVAMAR Type 9.55 64/36 16 4957' WOB 27 20-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 0.902 2875 8.75 PVOil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size Hycalog SKH616M-E1D 160' 2636' 4937' TuffGvlCoal $3,410.00 Alkal Lime $98,010.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Total Charges: 4957' 4957' 0' Current Depth: 24 Hour Progress: RIH w/ BHA #12Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air Connection(max) Chromatograph (ppm) 24 hr Recap: Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 00 Gas Summary md 2000psi for 5 min - OK. P/U BHA #12. RIH w/ BHA #12 filling every 15 stands. Finish P/U 5" DP & rack back. Freeze protect w/ diesel. Set test plug. Test BOPs. Install wear ring. Test casing @ Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 Emil OpitzReport By:Logging Engineers:Emil Opitz / David Mckechnie (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 508 120 SPP (psi) Gallons/stroke 1404 @ Yesterday's Depth: 184.4 Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 5455'222.3 4.23 Flow In (spm) MWD Summary Total Charges: 4957' 5877' 920' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 Daily Charges:$3,710.00 8.5 Alkal Lime $101,720.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size Hycalog SKH616M-E1D 160' 2636' 4937' Lithology (%) (current) ShClyst Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope 385.3 Customer: Well: Avg 0.902 1447 8.75 PVOil / Water 4957' WOB 28 21-Apr-2012 24:00:00Time: Report #: Date: AK-AM-0009388918 9.30 65/35 13 Ss 4.4 Lst EVAMAR Type 9.30 6 Cht Silt Siltst 100 HYDRIL YP Cor Solids (lb/100ft2) 2.541.95 Mud (lb/bbl)ml/30min 5785' Faze Pro Depth Mud Type Depth 5877'to4957' 10.479.8610.27 Avg Min MaxECD (ppg) Tools Xceed675, EcoScope675, TeleScope675, sonicVision675 API FL * 10000 units = 100% Gas In Air Logging Engineers:Emil Opitz / David Mckechnie (max)(current) C-5i 907-685-0772Unit Phone: 29 Emil OpitzReport By: C-1 70Maximum129 48 Depth C-2 C-3 9292Minimum Average 1814569464 123 41345809' 3824 Units* 139 5453' Displace to new 9.25 ppg FazePro OBM. Tag shoe @ 4934' MD. Drill cement and 20' new formation to 4977' MD. Perform LOT to RIH w/ BHA #12. Sonic cement bond log from 2636' MD to 4761' MD. Casing test - OK. Tag float collar @ 4853' MD. 1771 md 12.9 ppg EMW. Drill ahead. 294660 533 Gas Summary C-5n 2140 C-4i C-4n 243 82 41 54 71 173 Trip 24 hr Recap: 128Background Connection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) 9 5/8" BTC Grade L-80 40.0 20" ROP Set AtSize 178.9 X-65 Bit # L-80 Area: Location: 96% 546 129 SPP (psi) Gallons/stroke 1947 ROP (ft/hr) 13 3/8" @ Yesterday's Depth: 194.6 Rig: Job No.: Casing Summary Condition in Mud Data Hours Depth in / out % RPM MWD Summary Bit Type TFA Cly Daily Charges: Current Pump & Flow Data: Max @ ft Current 5950'251.8 4.23 Flow In (spm) Flow In (gpm) Total Charges: 5877' 8264' 2387' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 $3,410.00 10.3 Alkal Lime $105,130.00 Report For: Ratio cP Ross/Wimmer/Buchanan 4937' TuffGvlCoal 68.0 Weight Size Hycalog SKH616M-E1D 160' 2636' 435.0 Lithology (%) (current) ShClyst Oil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope AK-AM-0009388918 Customer: Well: Avg 0.902 1951 8.75 PV 29 22-Apr-2012 24:00:00Time: Report #: Date: 9.30 64/36 16 Ss 4.3 Lst EVAMAR Type 9.30 6 Cht Silt Siltst 100 HYDRIL YP Cor Solids (lb/100ft2) 2.471.90 Mud (lb/bbl)ml/30min 8133' FazePro Depth Mud Type Depth 8264'to5877' 11.0710.1210.60 Avg Min MaxECD (ppg) Tools Xceed675, EcoScope675, TeleScope675, sonicVision675 API FL 4957' WOB * Logging Engineers:Emil Opitz / David Mckechnie (max)(current) C-5i 907-685-0772Unit Phone: 53 Emil OpitzReport By: 106Maximum182 C-3 9637 C-1 55130856 45 122 152 6248 3305 7800'Minimum Depth 5944' C-2Units* 108 of calcareously cemented sandstone cuttings. Other lithologies observed include siltstone, silty sandstone, sandy siltstone, and Continue to drill 8.75" production section. Samples consist primarliy of unconsolidated sands with lesser amounts 1729 Gas Summary md shale. 279606 487 77 C-5n 49 C-4i C-4n 291 150 98 91 154 201 Trip Average 24 hr Recap: 70Background Chromatograph (ppm) 100% Gas In Air=10,000 UnitsConnection(max) . . Density (ppg) Viscosity out (sec/qt) 20" 9 5/8" BTC MWD Summary TFA Grade L-80 40.0 Set AtSize 178.9 X-65 Bit # Casing Summary Depth in / out L-80 Cly 4937' Area: Location: 96% 550 130 SPP (psi) Gallons/stroke 2224 ROP (ft/hr) 13 3/8" @ Yesterday's Depth: 142.5 Rig: Job No.: Condition in Mud Data Hours % RPMBit Type Current Pump & Flow Data: Max @ ft Current 9780'261.4 4.23 Flow In (spm) ROP Total Charges: 8264' 10464' 2200' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 Daily Charges:$3,410.00 11.4 Alkal Lime $108,540.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size Hycalog SKH616M-E1D 160' 2636' 552.6 Lithology (%) (current) ShClyst Oil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope AK-AM-0009388918 Customer: Well: Avg 0.902 1953 8.75 PV 30 23-Apr-2012 24:00:00Time: Report #: Date: 9.35 65/35 22 Ss 4.3 Lst EVAMAR Type 9.35 6 Cht Silt Siltst 100 HYDRIL YP Cor Solids (lb/100ft2) 2.992.30 Mud (lb/bbl)ml/30min 10390' FazePro Depth Mud Type Depth 10464'to8264' 11.5110.4711.11 Avg Min MaxECD (ppg) Tools Xceed675, EcoScope675, TeleScope675, sonicVision675 API FL 4957' WOB * Maximum Report By:Logging Engineers:Emil Opitz / David Mckechnie (max)(current) C-5i 907-685-0772Unit Phone: 112 Emil Opitz C-3 5596 171540 792 62506 181 301 767069 1679 9502'Minimum Depth 10299' C-2Units* 95 of calcareously cemented sandstone cuttings. Other lithologies observed include siltstone, silty sandstone, sandy siltstone, and Continue to drill 8.75" production section. Samples consist primarliy of unconsolidated sands with lesser amounts 811 Gas Summary md shale. C-5n 6093 367 196 C-4i C-4nC-1 239 84142 111 232 450 387 Trip Average 24 hr Recap: 103Background Chromatograph (ppm) 100% Gas In Air=10,000 UnitsConnection(max) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed675, EcoScope675, TeleScope675, sonicVision675 API FL 4957' WOB Depth 12397'to10464' 11.8110.8811.47 Avg Min Max 12180' FazePro Depth Mud Type YP Cor Solids (lb/100ft2) 2.211.70 Mud (lb/bbl)ml/30min 6 10 Cht Silt Siltst 90 HYDRIL Ss 4.5 Lst EVAMAR Type 9.35 65/35 20 31 24-Apr-2012 1/1/1900 0:00Time: Report #: Date: AK-AM-0009388918 Customer: Well: Avg 0.902 1953 8.75 PVOil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope 407.9 Lithology (%) (current) ShClyst 68.0 Weight Size Hycalog SKH616M-E1D 160' 2636' TuffGvlCoal $3,410.00 11.7 Alkal Lime $111,950.00 Report For: Ratio cP Ross/Wimmer/Buchanan Flow In (gpm) Total Charges: 10464' 12397' 1933' Current Depth: 24 Hour Progress: Drilling AheadRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 10840'232.8 4.23 Flow In (spm) ROP RPMBit Type % Condition in Mud Data Hours @ Yesterday's Depth: 223.6 Rig: Job No.: ROP (ft/hr) 13 3/8" Area: Location: 96% 553 131 SPP (psi) Gallons/stroke 2439 4937' Cly Set AtSize 178.9 X-65Casing Summary MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 20" 9 5/8" BTC * 100% Gas In Air=10,000 UnitsConnection(max) Chromatograph (ppm) 24 hr Recap: 90Background Average Trip 122 227 593 369 80141 C-4i C-4nC-1 C-5n 5898 424 229 shale. of calcareously cemented sandstone cuttings. Other lithologies observed include siltstone, silty sandstone, sandy siltstone, and Continue to drill 8.75" production section. Samples consist primarliy of unconsolidated sands with lesser amounts 546 Gas Summary md Units* 121 10899' C-2 1282 10581'Minimum Depth 77 26442925 190 373 849514 130698 974 74 907-685-0772Unit Phone: 126 Emil Opitz C-5iC-3 Maximum Report By:Logging Engineers:Emil Opitz / David Mckechnie (max)(current) . . Density (ppg) Viscosity out (sec/qt) 20" 9 5/8" BTC MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 Set AtSize 178.9 X-65Casing Summary Cly 4937' Area: Location: 96% 563 133 SPP (psi) Gallons/stroke 1946 ROP (ft/hr) 13 3/8" @ Yesterday's Depth: Rig: Job No.: Condition in Mud Data Bit Type % ROP RPM Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 12434'183.0 4.23 12397' 12786' 389' Current Depth: 24 Hour Progress: BROOHRig Activity: Report For: Ratio cP Keener/Smith/Buchanan Flow In (gpm) Total Charges: Flow In (spm) $3,410.00 12.2 Alkal Lime $115,360.00 Hycalog SKH616M-E1D 160' 2636' TuffGvlCoal 385.7 Lithology (%) (current) ShClyst Oil / Water Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope AK-AM-0009388918 Customer: Well: Avg 0.902 1953 8.75 PV 32 25-Apr-2012 24:00:00Time: Report #: Date: 68.0 Weight 9.50 65/35 17 Size Hours Ss 4.3 Lst EVAMAR Type 9.50 6 Cht Silt Siltst 100 HYDRIL YP Cor Solids (lb/100ft2) 2.281.75 Mud (lb/bbl)ml/30min 12786' FazePro Depth Mud Type Depth 12786'to12397' 11.8011.1211.62 Avg Min MaxECD (ppg) Tools Xceed675, EcoScope675, TeleScope675, sonicVision675 API FL 4957' WOB * Maximum Report By:Logging Engineers:Emil Opitz / David Mckechnie (max)(current) 907-685-0772Unit Phone: 137 Emil Opitz 8049 110592 877 101 33392 167 397 9099 221 1084 12694'Minimum Depth 12487' C-2 md Units* 114 of calcareously cemented sandstone cuttings. Other lithologies observed include siltstone, silty sandstone, sandy siltstone, and Continue to drill 8.75" production section. Samples consist primarliy of unconsolidated sands with lesser amounts 471 Gas Summary shale. Reached production TD of 12786' MD @ 0745 hrs. BROOH per K&M. 5489 453 251 C-5nC-4i C-4nC-1 C-5iC-3 74131 116 203 595 293 Trip Average 181 24 hr Recap: Background Chromatograph (ppm) 100% Gas In Air=10,000 UnitsConnection(max) . . Density (ppg) Viscosity out (sec/qt) API FL 4957' WOB Lst 12786' Avg Min MaxECD (ppg) Tools Xceed675, EcoScope675, TeleScope675, sonicVision675 Depth Mud Type YP Cor Solids (lb/100ft2) 2.541.95 Mud (lb/bbl)ml/30min Cht Silt Siltst HYDRIL 9.40 6 12786' FazePro 4.3 EVAMAR Type 65/35 17 Customer: Well: 68.0 Weight Size Hours Hycalog SKH616M-E1D Ratio 33 26-Apr-2012 24:00:00Time: Report #: Date: 0.902 1950 8.75 PV Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope AK-AM-0009388918 Lithology (%) (current) ShClystSs 160' 2636' TuffGvlCoal $3,410.00 11.5 Alkal Lime $118,770.00 Report For: cP Keener/Wimmer/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 12786' Avg to 12786' 12786' 0' Current Depth: 24 Hour Progress: POOHRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 ROP RPM % Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) 13 3/8" Area: Location: 96% SPP (psi) Gallons/stroke Cly Set AtSize 178.9 X-65Casing Summary MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-804937' Bit Type 20" 9 5/8" BTC * 100% Gas In Air=10,000 UnitsConnection(max) Chromatograph (ppm) 41 24 hr Recap: Background Average Trip 0 00 C-4i C-4nC-3 00 0 C-1 C-5i C-5n 0 0 0 BROOH per K&M to 4930' MD. Circulate hole clean. Pump dry job. POOH on elevators. Gas Summary 0 md Units* C-2 Minimum Depth 0 0 0 0 0 0 0 00 0 907-685-0772Unit Phone: 0 Emil Opitz Maximum Report By:Logging Engineers:Emil Opitz / David Mckechnie (max)(current) . . Density (ppg) Viscosity out (sec/qt) 20" 9 5/8" BTC MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-804937' Bit Type Set AtSize 178.9 X-65Casing Summary Cly Area: Location: 96% SPP (psi) Gallons/stroke ROP (ft/hr) 13 3/8" @ Yesterday's Depth: Rig: Job No.: Condition in Mud Data % ROP RPM Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 12786' 12786' 0' Current Depth: 24 Hour Progress: Circulate & ConditionRig Activity: Keener/Wimmer/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 12786' Avg to $4,832.00 Alkal Lime $123,602.00 Report For: 160' 2636' TuffGvlCoal Lithology (%) (current) ShClystSs Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope AK-AM-0009388918 0.902 56 8.75 7829' PV 9.40 cP Hycalog SKH616M-E1D Ratio 34 27-Apr-2012 24:00:00Time: Report #: Date: Customer: Well: 68.0 Weight Size Hours Type 57.00 9.40 160.06 12786' FazePro Cht Silt Siltst HYDRIL YP 1-2-CT-S-X-I-NO-TD Cor Solids (lb/100ft2)Mud (lb/bbl)ml/30minDepth Mud Type 12786' Avg Min MaxECD (ppg) Tools API FL 12.04957' 12786' WOB Lst EVAMAR * Maximum Report By:Logging Engineers:Emil Opitz / David Mckechnie (max)(current) 907-685-0772Unit Phone: 0 Emil Opitz 00 0 0 0 0 0 0 0 0Minimum Depth C-2 md Units* POOH and L/D BHA #12. M/U BHA #13 and RIH to bottom. NOTE: Consumables for SI20-N4 & SI20-N4PH added in daily cost. Sample Catchers released from location. Gas Summary 0 0 0 0 C-5nC-1 C-5i 00 0 C-4i C-4nC-3 00 0 Trip Average 303 24 hr Recap: Background Chromatograph (ppm) 100% Gas In Air=10,000 UnitsConnection(max) . . Density (ppg) Viscosity out (sec/qt) EVAMAR ECD (ppg) Tools API FL WOB Avg Min Max Mud (lb/bbl) ml/30min Depth Mud Type Lst HYDRIL YP Cor Solids (lb/100ft 2) 9.10 4737' Brine Type Customer: Well: 68.0 Weight Size Hours Ratio 35 28-Apr-2012 24:00:00 Time: Report #: Date: 28 PV cP Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope AK-AM-0009388918 Lithology (%) (current) Sh Clyst Ss Cht Silt 160' 2636' Tuff Gvl Coal $2,810.00 Alkal Lime $126,412.00 Report For: Keener/Wimmer/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 12786' Avg to 12786' 12786' 12786' 0' Current Depth: 24 Hour Progress: Displace to Brine Rig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 ROP RPM % Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) 13 3/8" Area: Location: 96% SPP (psi) Gallons/stroke Cly Siltst Set At Size 178.9 X-65 Casing Summary MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-80 4937' Bit Type 20" 9 5/8" BTC * 100% Gas In Air =10,000 Units Connection 0 Chromatograph (ppm) 24 hr Recap: Background (max) Average Trip 00 C-4i C-4n C-3 00 0 C-1 C-5i C-5n 0 0 0 with LVT pill, citric acid treated brine, and then brine. Spot 630 bbl of FazeAway breaker. POOH on elevators to casing shoe. Displace well to 9.1 ppg brine. Flush pumps Gas Summary 0 md. Units* C-2 Minimum Depth 0 0 0 0 0 0 0 0 0 0 907-685-0772 Unit Phone: 0 Emil Opitz Maximum Report By: Logging Engineers: Emil Opitz / David Mckechnie (max) (current) . . Density (ppg) Viscosity out (sec/qt) 20" 9 5/8" BTC MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-804937' Bit Type Set AtSize 178.9 X-65Casing Summary ClySiltst Area: Location: 96% SPP (psi) Gallons/stroke ROP (ft/hr) 13 3/8" @ Yesterday's Depth: Rig: Job No.: Condition in Mud Data % ROP RPM Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 12786' 12786' 0' Current Depth: 24 Hour Progress: RIH w/ 5.5" linerRig Activity: Keener/Wimmer/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 12786' Avg to12786' $2,810.00 Alkal Lime $129,282.00 Report For: 160' 2636' TuffGvlCoal Lithology (%) (current) ShClystSs Cht Silt Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope AK-AM-0009388918 28 PV cPRatio 36 29-Apr-2012 24:00:00Time: Report #: Date: Customer: Well: 68.0 Weight Size Hours Type 9.104737' Brine HYDRIL YP Cor Solids (lb/100ft2)Mud (lb/bbl)ml/30minDepth Mud Type Lst Avg Min MaxECD (ppg) Tools API FL WOB EVAMAR * Maximum Report By:Logging Engineers:Emil Opitz / David Mckechnie (max)(current) 907-685-0772Unit Phone: 0 Emil Opitz 00 0 0 0 0 0 0 0 0Minimum Depth C-2 md Units* 25 stands. POOH and L/D BHA #13. R/U for 5.5" liner run and RIH to 8053' MD. M/U Baker liner hanger. RIH w/DP filling every Gas Summary 0 0 0 0 C-5nC-1 C-5i 00 0 C-4i C-4nC-3 00 Trip Average 24 hr Recap: Background (max) Chromatograph (ppm) 100% Gas In Air=10,000 UnitsConnection 0 . . Density (ppg) Viscosity out (sec/qt) EVAMAR ECD (ppg) Tools API FL WOB Avg Min Max Mud (lb/bbl)ml/30minDepth Mud Type Lst HYDRIL YP Cor Solids (lb/100ft2) 9.104737' Brine Type Customer: Well: 68.0 Weight Size Hours Ratio 37 30-Apr-2012 24:00:00Time: Report #: Date: 28 PV cP Footage ENI Petroleum SI20-N4 Spy Island 24 hr Max North Slope AK-AM-0009388918 Lithology (%) (current) ShClystSs Cht Silt 160' 2636' TuffGvlCoal $2,810.00 Alkal Lime $132,092.00 Report For:Keener/Wimmer/Buchanan Flow In (gpm) Total Charges: Flow In (spm) Oil / Water Depth 12786' Avg to12786' 12786' 12786' 0' Current Depth: 24 Hour Progress: L/D DPRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 ROP RPM % Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) 13 3/8" Area: Location: 96% SPP (psi) Gallons/stroke ClySiltst Set AtSize 178.9 X-65Casing Summary MWD Summary TFA Grade L-80 40.0 Bit # Depth in / out L-804937' Bit Type 20" 9 5/8" BTC * 100% Gas In Air=10,000 UnitsConnection 0 Chromatograph (ppm) 24 hr Recap: Background (max) Average Trip 00 C-4i C-4nC-3 00 0 C-1 C-5i C-5n 0 0 0 verify - good. L/D 5" DP. RIH w/ liner to 12758' MD, set packer @ liner depth of 12746' MD; packer set @ 4662' MD per Baker rep. PSI test to Gas Summary 0 md Units* C-2 Minimum Depth 0 0 0 0 0 0 0 00 0 907-685-0772Unit Phone: 0 Emil Opitz Maximum Report By:Logging Engineers:Emil Opitz / David Mckechnie (max)(current) WELL NAME:SI20-N4 & SI20-N4 PH LOCATION:Spy Island OPERATOR:ENI Petroleum AREA:North Slope MUD CO:MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:26-Mar-12 SPERRY JOB:AK-AM-0009388918 TD:25-Apr-12 BIT RECORD MWD BHA# SDL RUN # Bit #Bit Type Bit Size Depth In (ft) Depth Out (ft) Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max) Bit Grade Remarks 2 100 1 Smith XR+ Mill Tooth 16"160 2648 2488 18.50 1.117 134.7 30 60 1400 750 1-1-WT-A-I-E-NO-TD Surface TD reached 3 200 2 Smith GF15B Insert Bit 12.25"2648 3955 1307 12.60 1.117 103.7 30 100 2000 900 2-2-BT-A-E-I-ER-CP Core point reached 4 300 3 CorPro MC572 Core Bit 12.25"3955 3971 16 1.50 1.910 10.7 6 40 150 150 0-0-NO-A-X-I-NO-PR Core barrel jammed. Pulled to lay down core 5 400 4 CorPro MCP573 Core Bit 12.25"3971 4022 51 0.50 1.910 102.0 9 45 180 150 0-1-BT-T-X-I-PN-TD Core section TD. Pulled to lay down core 6 500 2 RR1 Smith GF15B Insert Bit 12.25"4022 4111 89 2.30 1.117 38.0 9 80 1600 750 2-2-BT-A-E-I-ER-CP Core point TD reached 7 600 4 RR1 CorPro MCP573 Core Bit 12.25"4111 4171 60 2.00 1.910 30.0 9 35 180 150 0-2-BT-T-X-I-PN-TD Core section TD. Pulled to lay down core 8 700 2 RR2 Smith GF15B Insert Bit 12.25"4171 4350 179 3.70 1.117 48.2 30 100 1500 750 2-2-BT-A-E-I-ER-TD Pilot hole TD reached 11 800 5 Hughes VMD-3 Mill Tooth 12.25"2723 4957 2234 31.70 1.117 70.6 40 60 2780 900 3-7-WT-A-E-5-RG-TD Intermediate TD reached 12 900 6 Hycalog SKH616M-E1D PDC 8.75"4957 12786 7829 57.00 0.902 137.4 12 160 2450 550 1-2-CT-S-X-I-NO-TD Production TD reached WE L L N A M E : L O C A T I O N : OP E R A T O R : A R E A : MU D C O : S T A T E : RI G : S P U D : SP E R R Y J O B : T D : Mu d R e c o r d W a t e r B a s e d M u d R e c o r d 16 0 ' t o 2 , 6 4 8 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oil / W a t e r Sd P m p H M B T P f / M f C h l o r H a r d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l m g / l C a + + 25 - M a r 1 6 0 8 . 8 0 1 0 9 3 4 3 4 1 6 / 3 4 / 4 2 5 . 6 1 0 2 / 6 8 / 6 4 / 3 8 / 1 6 / 1 4 1 / - 3 . 0 1 / 9 6 - 0 . 0 5 9 . 3 1 9 . 0 . 0 4 / . 4 5 1 6 0 0 1 0 0 D r illing 16" Hole 26 - M a r 1 3 5 7 9 . 2 0 1 0 0 2 7 3 4 1 9 / 4 9 / 6 1 5 . 1 8 8 / 6 1 / 5 0 / 3 8 / 1 9 / 1 7 2 / - 5 . 5 . 5 / 9 4 0 . 2 5 0 . 1 0 9 . 5 1 9 . 5 . 0 8 / . 4 8 2 2 0 0 1 2 0 D r illing 16" Hole 27 - M a r 2 6 4 8 9 . 3 0 - 2 5 2 6 1 5 / 3 6 / 4 7 5 . 1 7 6 / 5 1 / 4 1 / 2 9 / 1 5 / 1 4 1 . 5 / - 5 .0 . 2 5 / 9 3 . 7 5 0 . 1 5 0 . 0 7 9 . 5 1 5 . 5 . 0 6 / . 5 2 1 1 0 0 4 0 B R O O H 28 - M a r 2 6 4 8 9 . 5 0 - 2 3 1 8 7 / 1 7 / - - - - - - - - 8 . 7 - - - - C i r c u l a t e a n d C o n d i t i o n m u d 29 - M a r 2 6 4 8 9 . 4 5 - 2 5 1 8 7 / 1 3 / - - - - - - - - 9 . 0 - - - - R / U B O P S t a c k 30 - M a r 2 6 4 8 9 . 4 5 - 2 5 1 8 - - 6 8 / 4 3 / 3 4 / 2 3 / 7 / 6 - - - - - - - - - - P / U D r ill Pipe Oi l B a s e d M u d R e c o r d F az e P ro Pi l ot H o l e 2 ,64 8 ' t o 4 ,3 5 0' 2, 7 2 3 ' t o 4 , 9 5 7 ' 4, 9 5 7 ' t o 1 2 , 7 8 6 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e Co r r . So l i d s Oil / W a t e r Oil P m L i m e S a l t C l - Em u l St a b i l i t y S d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l l b / b b l % W t m g / L m g / l % v o l 31 - M a r 3 5 3 4 9 . 3 0 - 1 6 1 6 6 / 6 / 7 4 . 6 4 8 / 3 2 / 2 4 / 1 6 / 7 / 6 - / 5 0 0 7 . 4 1 6 6 / 3 4 5 8 . 5 2 . 6 5 3 . 4 5 3 3 . 3 7 9 6 0 0 0 3 5 0 - D r ill 12.25" Hole 1- A p r 3 9 5 5 9 . 4 0 - 1 7 1 5 6 / 6 / 7 5 . 8 4 9 / 3 2 / 2 3 / 1 5 / 7 / 6 - / 1 8 . 4 0 6 2 / 3 8 5 4 3 . 3 0 4 . 2 9 3 1 . 4 0 9 8 0 0 0 6 2 5 - P / U C o r e B a r r e l s 2- A p r 3 9 7 1 9 . 5 0 - 1 8 1 6 6 / 6 / 7 - 5 2 / 3 7 / 2 4 / 1 6 / 7 / 6 - / 1 9 . 0 4 6 2 / 3 8 5 4 2 . 7 0 3 . 5 1 3 1 . 0 6 9 5 0 0 0 4 9 0 - P O O H w / C o r e B a r r e l s 3- A p r 4 0 2 1 9 . 5 0 - 1 8 1 0 5 / 6 / 7 - 4 6 / 2 8 / 2 2 / 1 4 / 5 / 4 - / 1 8 . 8 6 6 3 / 3 7 5 5 2 . 3 0 2 . 9 9 3 2 . 4 0 9 8 0 0 0 4 0 0 0 . 0 5 P O O H 4- A p r 4 0 2 1 9 . 5 0 - 1 9 1 1 6 / 6 / 7 - 4 9 / 3 0 / 2 3 / 1 5 / 6 / 5 - 8 . 8 9 6 4 / 3 6 5 6 2 . 3 0 2 . 9 9 3 2 . 8 7 9 7 0 0 0 3 6 0 0 . 0 5 5- A p r 4 1 7 1 9 . 5 0 - 1 9 1 1 6 / 6 / 7 - 4 9 / 3 0 / 2 2 / 1 5 / 6 / 5 - / 1 8 . 8 4 6 4 / 3 6 5 6 2 . 1 0 2 . 7 3 3 3 . 1 0 9 8 0 0 0 4 0 0 - D r ill to CP/ Drill Core 6- A p r 4 3 3 3 9 . 5 0 - 2 1 1 0 6 / 6 / 7 5 . 3 5 2 / 3 1 / 2 4 / 1 6 / 7 / 6 - / 1 1 0 . 0 9 6 3 / 3 7 5 4 . 5 2 . 2 0 2 . 8 6 3 1 . 9 5 9 6 0 0 0 4 1 0 - C i r c u l a t i n g B U 7- A p r 4 3 5 0 9 . 4 5 - 2 1 1 5 6 / 6 / 7 - 5 7 / 3 6 / 2 8 / 1 9 / 8 / 7 - 8 . 9 1 6 4 / 3 6 5 6 1 . 8 0 2 . 3 4 3 2 . 7 6 9 6 5 0 0 5 5 0 - W a i t i n g o n w i r e l i n e 8- A p r 4 3 5 0 9 . 4 5 - 2 0 1 6 6 / 6 / 7 - 5 6 / 3 6 / 2 8 / 1 8 / 8 / 7 - 9 . 4 3 6 4 / 3 6 5 6 1 . 8 0 2 . 3 4 3 3 . 0 0 9 6 0 0 0 5 5 0 - W i r e l i n e l o g g i n g 9- A p r 4 3 5 0 9 . 4 5 - 2 0 1 6 6 / 6 / 7 - 5 6 / 3 6 / 2 8 / 1 8 / 8 / 7 - 9 . 4 3 6 4 / 3 6 5 6 1 . 8 0 2 . 3 4 3 3 . 0 0 9 6 0 0 0 5 5 0 - S a f e t y S t a n d D o w n 10 - A p r 4 3 5 0 9 . 5 0 - 2 0 1 7 6 / 7 / 7 - 5 7 / 3 7 / 2 7 / 1 8 / 8 / 7 - 7 . 9 1 6 5 / 3 5 5 7 1 . 8 0 2 . 3 4 3 2 . 7 6 9 6 5 0 0 5 0 0 - S a f e t y S t a n d D o w n 11 - A p r 4 3 5 0 9 . 4 5 - 2 0 1 5 6 / 7 / 7 - 5 5 / 3 5 / 2 6 / 1 7 / 7 / 6 - 9 . 4 3 6 4 / 3 6 5 6 1 . 8 0 2 . 3 4 3 2 . 4 1 9 6 5 0 0 5 0 0 - S a f e t y S t a n d D o w n 12 - A p r 4 3 5 0 9 . 4 5 - 2 1 1 3 6 / 6 / 7 - 5 5 / 3 4 / 2 5 / 1 7 / 7 / 6 - 8 . 9 1 6 4 / 3 6 5 6 1 . 7 0 2 . 2 1 3 2 . 7 6 9 6 5 0 0 4 7 5 - T e s t B O P s 13 - A p r 4 3 5 0 9 . 5 5 - 2 2 1 5 6 / 6 / 7 - 5 9 / 3 7 / 2 8 / 1 9 / 6 / 5 - 8 . 6 4 6 3 / 3 7 5 5 1 . 2 0 1 . 5 6 3 1 . 0 6 9 5 0 0 0 4 9 5 - C e m e n t i n g 14 - A p r 4 3 5 0 9 . 6 0 - 2 4 1 9 7 / 8 / 8 - 6 7 / 4 3 / 3 3 / 2 7 / 7 / 6 - 1 0 . 2 9 6 2 / 3 8 5 3 1 . 3 0 2 . 2 1 2 9 . 9 1 9 0 0 0 0 4 9 0 - W a i t o n c e m e n t 15 - A p r 3 7 3 6 9 . 3 0 6 6 2 6 2 1 8 / 8 / 9 - 7 3 / 4 7 / 3 7 / 2 5 / 9 / 8 - 1 0 . 0 6 6 0 / 4 0 5 2 1 . 3 0 1 . 6 9 3 0 . 4 2 9 5 0 0 0 4 7 5 - D r ill 12.25" Hole 16 - A p r 4 4 2 5 9 . 4 5 5 8 2 8 1 5 8 / 8 / 9 1 . 0 7 1 / 4 3 / 3 4 / 2 3 / 9 / 8 - / 1 1 1 . 0 4 6 4 / 3 6 5 4 1 . 6 0 2 . 0 8 3 2 . 1 8 9 4 0 0 0 5 6 0 - D r ill 12.25" Hole 17 - A p r 4 9 5 7 9 . 5 5 5 6 2 8 1 6 7 / 8 / 8 1 . 4 7 2 / 4 4 / 3 2 / 2 0 / 8 / 7 - / 1 1 2 . 3 2 6 4 / 3 6 5 4 2 . 4 5 3 . 1 9 3 1 . 4 6 8 8 0 0 0 5 2 0 - B a c k r e a m i n g / T D i n t e r m e d i a t e 18 - A p r 4 9 5 7 9 . 5 5 6 8 2 8 1 6 7 / 8 / 8 - 7 2 / 4 4 / 3 2 / 2 1 / 8 / 7 - 1 2 . 3 2 6 4 / 3 6 5 4 2 . 3 0 2 . 9 9 3 1 . 4 6 8 8 0 0 0 5 2 0 - C i r c u l a t e / c o n d i t i o n 19 - A p r 4 9 5 7 9 . 5 5 7 1 2 8 1 6 7 / 8 / 8 - 7 2 / 4 4 / 3 2 / 2 0 / 8 / 7 - 1 2 . 3 2 6 4 / 3 6 5 4 2 . 0 0 2 . 6 0 3 1 . 4 6 8 8 0 0 0 5 0 0 - P i c k u p 5 " D P 20 - A p r 4 9 5 7 9 . 5 5 7 5 2 8 1 6 6 / 7 / 7 - 7 2 / 4 4 / 3 1 / 2 0 / 7 / 6 - 1 6 . 0 0 6 4 / 3 6 5 4 2 . 6 0 3 . 3 8 3 1 . 4 6 8 8 0 0 0 5 0 0 - R I H W / 8 . 7 5 B H A 21 - A p r 5 8 1 0 9 . 3 0 4 7 1 4 1 3 5 / 6 / 6 - 4 1 / 2 7 / 2 1 / 1 5 / 6 / 5 - / 1 8 . 4 8 6 5 / 3 5 5 7 1 . 9 5 2 . 5 4 3 2 . 7 7 9 5 0 0 0 6 8 5 - D r ill 8.75" hole 22 - A p r 8 2 1 9 9 . 3 0 5 1 1 9 1 6 7 / 8 / 8 1 . 5 5 4 / 3 5 / 2 8 / 1 9 / 8 / 7 - / 1 1 0 . 3 3 6 4 / 3 6 5 5 1 . 9 0 2 . 4 7 3 2 . 3 0 9 3 0 0 0 8 4 5 - D r ill 8.75" hole 23 - A p r 1 0 4 2 2 9 . 3 5 5 3 1 9 2 2 8 / 9 / 9 1 . 5 6 0 / 4 1 / 3 3 / 2 3 / 9 / 8 - / 1 1 1 . 4 2 6 5 / 3 5 5 5 2 . 3 0 2 . 9 9 3 0 . 9 7 8 6 0 0 0 8 6 5 - D r ill 8.75" hole 24 - A p r 1 2 1 8 0 9 . 3 5 5 3 1 9 2 0 7 / 8 / 8 1 . 5 5 8 / 3 9 / 3 1 / 2 2 / 8 / 7 - / 1 1 1 . 7 0 6 5 / 3 5 5 6 1 . 7 0 2 . 2 1 3 0 . 9 7 1 0 2 0 0 0 8 6 0 - D r ill 8.75" hole 25 - A p r 1 2 3 1 8 9 . 3 5 5 3 1 9 2 0 7 / 8 / 8 1 . 5 5 8 / 3 9 / 3 1 / 2 2 / 8 / 7 - / 1 1 1 . 7 0 6 3 / 3 5 5 6 1 . 7 0 2 . 2 1 3 0 . 9 7 8 4 0 0 0 8 6 0 - D r ill 8.75" hole 26 - A p r 1 2 7 8 6 9 . 5 0 5 3 1 9 1 7 7 / 8 / 9 1 . 0 5 5 / 3 6 / 2 9 / 2 0 / 8 / 7 - / 1 1 2 . 2 4 6 5 / 3 5 5 5 1 . 7 5 2 . 2 8 3 1 . 1 8 8 7 0 0 0 8 5 0 - T D I n t e r m e d d i a t e / B a c k r e a m 27 - A p r 1 2 7 8 6 9 . 4 0 5 6 1 9 1 7 7 / 8 / 8 - 5 5 / . 3 / 2 8 / 2 0 / 7 / 6 - 1 1 . 3 1 5 5 1 . 9 0 2 . 4 7 3 2 . 5 8 9 2 0 0 0 7 4 0 C i r c u l a t e / c o n d i t i o n Ca s i n g R e c o r d SI 2 0 - N 4 & S I 2 0 - N 4 P H EN I P e t r o l e u m MI S w a c o Do y o n 1 5 9 5 / 8 " I n t e r m e d i a t e @ 4 , 9 3 7 ' M D Su r f a c e S e c t i o n Fa z e P r o MI S p u d M u d Fa z e P r o AK - A M - 0 0 0 9 3 8 8 9 1 8 13 3 / 8 " S u r f a c e @ 2 , 6 3 6 ' M D Pr o d u c t i o n S e c t i o n In t e r m e d i a t e S e c t i o n Sp y I s l a n d No r t h S l o p e Ala s k a 26 - M a r - 1 2 25 - A p r - 1 2 20 " C o n d u c t o r @ 1 6 0 ' M D Well Name:Depth (MD)to ft Location:(TVD)to ft Operator:Show Report No.Show Reports Report Prepared By:Formation: Report Delivered To:Date Drilled: Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5ppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Showppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5ppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons SI20-N4 PH Hydrocarbon Ratios 97000 Mud Chlorides (mg/L) =97000 3790 1 3613 Andrew Buchanan No producible oil within these zones based upon gas and chromatograph data collected. 27 Mud Chlorides (mg/L) =97000 7 0 408 1689 18665 1 172 1417 3900 4200 98500Mud Chlorides (mg/L) = Spy Island ENI Petroleum Emil Opitz 479 #DIV/0! 19 0 19 0 0 1 0 Mud Chlorides (mg/L) = 27 16224 2 Apr 2012 to 6 Apr 2012 N & OA Sands 18 0 85 6 63 6 4153 39 26 20082 1417 0 0 0 0 7 4148 0 0 33 0 144 16227 487 38 4042 13853 33 122 9 2030 0 0 0 18 #DIV/0!0 139 0 0 16083 #DIV/0! #DIV/0! 779 718 691 260 11823 0 26 0 27 548 823 236 14807 27 141 3962 57 Interpretation: Gas Units Gas Units Gas Units Gas Units 11823 29 79 Hydrocarbon Ratios 2 1 3 4 39 1 10 100 1000 Oil Gas NPH NPH 1.0 10.0 100.0 1000.0 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator:Show Report No.Show Reports Report Prepared By:Formation: Report Delivered To:Date Drilled: Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5ppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Showppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5ppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons SI20-N4 Hydrocarbon Ratios 104000 Mud Chlorides (mg/L) =95000 3956 1 3942 Andrew Buchanan No producible oil within these zones based upon gas and chromatograph data collected. 182 Mud Chlorides (mg/L) =92000 153 77 580 1884 274962 114 3176 4452 4890 6500 105000Mud Chlorides (mg/L) = Spy Island ENI Petroleum Emil Opitz 1571 3744 212 69 143 0 34 129 15 Mud Chlorides (mg/L) = 244 277238 21 Apr 2012 to 22 Apr 2012 OA Sands 180 87 487 30 519 27 6422 201 152 279606 4644 26 20 123 46 173 5947 9 69 318 22 10873 207619 665 533 5450 294660 296 3745 36 6380 34 102 56 93 578793 2063 76 7 196746 2851 2116 1908 3819 2182 554 2529 80 72 27 217 1257 2933 602 272786 126 3107 5058 492 Interpretation: Gas Units Gas Units Gas Units Gas Units 288280 497 457 Hydrocarbon Ratios 2 1 3 4 175 1 10 100 1000 Oil Gas NPH NPH 1.0 10.0 100.0 1000.0 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator:Show Report No.Show Reports Report Prepared By:Formation: Report Delivered To:Date Drilled: Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5ppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Showppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5ppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons SI20-N4 Hydrocarbon Ratios 92000 Mud Chlorides (mg/L) =92000 3966 2 3956 Andrew Buchanan No producible oil within these zones based upon gas and chromatograph data collected. 292 Mud Chlorides (mg/L) =96000 237 84 523 1129 255457 169 3125 13478 6500 7650 92000Mud Chlorides (mg/L) = Spy Island ENI Petroleum Emil Opitz 1166 3186 322 123 199 86 129 263 94 Mud Chlorides (mg/L) = 336 251447 22-Apr-12 OA Sands 258 167 607 94 701 78 7548 299 232 271372 15915 80 49 216 132 286 7089 117 231 543 52 9319 266683 524 567 6950 278320 491 3247 55 10692 215 450 131 91 1995333 2935 274 43 257364 1114 773 1196 7096 1587 382 1584 196 36 63 273 872 2615 498 237969 161 2615 6652 623 Interpretation: Gas Units Gas Units Gas Units Gas Units 267628 512 513 Hydrocarbon Ratios 2 1 3 4 219 1 10 100 1000 Oil Gas NPH NPH 1.0 10.0 100.0 1000.0 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator:Show Report No.Show Reports Report Prepared By:Formation: Report Delivered To:Date Drilled: Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5ppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Showppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5ppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios 2 1 3 4 357 7970 648 Interpretation: Gas Units Gas Units Gas Units Gas Units 135422 795 671 434 1332 165 158466 232 1630 655 1066 478 245 448 204 104 72 365 149 119 1101408 1807 337 41 178348 603 437 295 891 9185 142161 605 1348 96 6739 258 527 119 296 652 47 10418 188766 308 118459 7647 87 88 363 212 514 10026 22 Apr 2012 to 23 Apr 2012 OA Sands 309 190 768 97 720 72 10422 444 383 141 242 96 162 447 145 Mud Chlorides (mg/L) = 437 167076 8610 7900 10450 96000Mud Chlorides (mg/L) = Spy Island ENI Petroleum Emil Opitz 310 897 381 Mud Chlorides (mg/L) =86000 426 151 170 318 110812 302 1139 SI20-N4 Hydrocarbon Ratios 78000 Mud Chlorides (mg/L) =80000 3885 3 3957 Andrew Buchanan No producible oil within these zones based upon gas and chromatograph data collected. 1 10 100 1000 Oil Gas NPH NPH 1.0 10.0 100.0 1000.0 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator:Show Report No.Show Reports Report Prepared By:Formation: Report Delivered To:Date Drilled: Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5ppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Showppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5ppmppmppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= ProductionAnalysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios 2 1 3 4 594 10897 768 Interpretation: Gas Units Gas Units Gas Units Gas Units 92672 739 897 220 901 123 100879 407 1070 381 349 272 131 358 114 317 130 459 74 112 393715 1282 587 45 120767 223 169 133 861 11726 100551 910 965 122 7879 354 794 79 542 978 68 9969 130736 431 113571 2932 56 123 373 246 575 12096 24 Apr 2012 to 25 Apr 2012 OA Sands 390 278 948 51 886 118 12482 650 448 183 265 47 307 420 161 Mud Chlorides (mg/L) = 589 107532 6653 10700 12786 92000Mud Chlorides (mg/L) = Spy Island ENI Petroleum Emil Opitz 186 730 481 Mud Chlorides (mg/L) =92000 452 127 125 205 110639 259 1119 SI20-N4 Hydrocarbon Ratios 102000 Mud Chlorides (mg/L) =102000 3889 4 3898 Andrew Buchanan No producible oil within these zones based upon gas and chromatograph data collected. 1 10 100 1000 Oil Gas NPH NPH 1.0 10.0 100.0 1000.0 NPH Oil Gas NPH Marker MD INC AZ TVD TVDSS 16" Surface Borehole 20" Conductor Shoe 160.00 0.00 0.00 160.00 -106.01 SV-4 782.00 16.60 156.90 766.36 -712.37 SV-3 1155.00 22.60 154.70 1121.00 -1067.01 SV-2 1439.50 28.50 157.40 1377.25 -1323.26 Permafrost Base 1875.00 21.80 152.90 1768.43 -1714.44 SV-1 2054.00 19.60 149.20 1935.66 -1881.67 Ugnu Top (UG4)2389.50 6.86 148.00 2260.19 -2206.20 13 3/8" Casing Shoe 2636.00 2.30 134.30 2506.65 -2452.66 TD 16" Borehole 2648.00 2.26 134.26 2518.66 -2464.67 KOP in 12 1/4" section 2720.00 0.60 126.00 2590.70 -2536.71 UG-2 Coal Bed Marker 2940.00 12.96 312.56 2808.85 -2754.86 Lower Ugnu 3700.00 41.00 301.00 3471.50 -3417.51 Schrader Bluff 4107.00 56.10 301.35 3740.73 -3686.74 N Sequence Top 4158.00 58.50 301.36 3768.34 -3714.35 N Sand Top 4251.00 63.42 301.70 3813.47 -3759.48 N Sand Bottom 4379.50 70.10 303.74 3864.06 -3810.07 Lower N-Marker 4442.00 73.94 304.76 3883.55 -3829.56 N Sequence Base 4540.00 80.70 305.30 3904.60 -3850.61 OA Sand Top 4900.00 86.00 306.30 3940.10 -3886.11 9 5/8" Casing Shoe 4937.00 87.00 308.20 3942.40 -3888.41 TD 12 1/4" Borehole 4957.00 87.60 308.90 3943.30 -3889.31 UG-2 Coal Bed Marker 2941.00 0.06 98.73 2811.65 -2757.66 Lower Ugnu 3612.00 0.01 248.85 3482.65 -3428.66 Schrader Bluff 3889.50 0.00 38.09 3760.15 -3706.16 N Sequence Top 3918.50 0.00 302.79 3789.15 -3735.16 Top of Core #1 (drilled to)3955.00 0.00 42.30 3825.65 -3771.66 Top of Core #1 (core bit tag)3958.00 0.00 42.30 3828.70 -3774.71 N Sand Top 3962.00 0.00 270.40 3832.65 -3778.66 Top of Core #2 3971.00 0.00 42.30 3841.70 -3787.71 N-2 Top 3973.50 0.00 262.23 3844.15 -3790.16 N-3 Top 3989.00 0.00 241.86 3859.65 -3805.66 N Sand Bottom 4016.50 0.00 175.10 3887.15 -3833.16 Base of Core #2 4022.00 0.00 42.30 3892.70 -3838.71 Lower N-Marker 4040.00 0.00 147.40 3910.65 -3856.66 N Sequence Base 4063.00 0.00 147.90 3933.65 -3879.66 Top of Core #3 4111.00 0.00 148.00 3981.65 -3927.66 OA-Sand Top 4117.00 0.00 147.85 3987.65 -3933.66 OA-sbl2 Top 4125.00 0.00 147.85 3995.65 -3941.66 OA-sbl3 Top 4128.00 0.00 147.85 3998.65 -3944.66 OA-sbl4 Top 4141.00 0.00 148.00 4011.65 -3957.66 OA-Sand Bottom 4153.00 0.00 148.00 4023.65 -3969.66 Base of Core #3 4171.00 0.00 147.80 4041.65 -3987.66 TD 12 1/4" Borehole-PH 4350.00 0.00 147.80 4220.65 -4166.66 8 3/4" Lateral Borehole OA-sbl2 Top 6300.00 86.60 316.20 3941.40 -3887.41 OA-sbl3 Top 6335.00 86.10 315.90 3943.70 -3889.71 Fault A (unplanned)7650.00 88.90 314.50 3961.50 -3907.51 OA-Sand Bottom 7850.00 93.70 315.20 3956.60 -3902.61 OA-sbl4 Top 7953.00 94.92 317.50 3948.74 -3894.75 Fault B (prognosed)8170.00 92.50 316.10 3937.50 -3883.51 OA-sbl4 Top 8290.00 93.40 316.80 3932.50 -3878.51 OA-sbl3 Top 8490.00 92.50 315.00 3918.80 -3864.81 OA-sbl2 Top 8610.00 91.30 314.70 3915.30 -3861.31 Fault C (unplanned)8680.00 92.50 315.60 3913.00 -3859.01 OA-sbl3 Top 9690.00 92.50 312.60 3896.80 -3842.81 OA-sbl2 Top 9774.00 92.40 311.94 3893.39 -3839.40 Fault D (prognosed)9940.00 92.40 313.30 3885.80 -3831.81 Fault E (prognosed)10430.00 90.10 308.40 3881.30 -3827.31 OA-Sand Top 10620.00 85.80 304.90 3889.40 -3835.41 Fault F (unplanned)10690.00 87.40 304.40 3893.60 -3839.61 OA-sbl3 Top 10780.00 89.50 305.60 3895.80 -3841.81 OA-sbl3 Top 11110.00 92.80 311.50 3890.70 -3836.71 OA-sbl2 Top 11307.00 93.45 312.44 3881.36 -3827.37 OA-sbl2 Top 12110.00 87.10 311.10 3874.00 -3820.01 OA-sbl3 Top 12440.00 92.66 318.44 3875.81 -3821.82 TD 8 3/4" Borehole 12786.00 87.50 309.90 3888.80 -3834.81 SI20-N4 Interpolated Tops 12 1/4" Intermediate Borehole - Pilot hole - SI20-N4 PH 12 1/4" Intermediate Borehole DIRECTIONAL SURVEY REPORT Eni PetroleumSI20-N4 PHNikaitchuq Alaska United States AK-XX-0009388918 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 93.50 0.30 348.22 93.50 0.24 N 0.05 W 0.24 0.32 187.20 1.82 182.27 187.19 1.01 S 0.16 W -1.01 2.25 283.30 4.54 172.37 283.13 6.30 S 0.29 E -6.30 2.88 377.40 8.97 166.50 376.55 17.13 S 2.49 E -17.13 4.76 469.40 13.76 160.44 466.73 34.43 S 7.83 E -34.43 5.36563.30 16.92 156.40 557.27 57.48 S 17.05 E -57.48 3.55 654.60 17.16 153.80 644.57 81.74 S 28.31 E -81.74 0.87 748.90 17.15 156.39 734.67 106.96 S 40.02 E -106.96 0.81 773.03 16.54 156.60 757.77 113.37 S 42.81 E -113.37 2.54 868.41 16.68 159.77 849.17 138.68 S 52.94 E -138.68 0.96 962.12 16.89 158.03 938.89 163.92 S 62.68 E -163.92 0.58 1054.75 18.46 154.64 1027.14 189.65 S 74.00 E -189.65 2.03 1147.99 22.44 154.55 1114.49 219.07 S 87.97 E -219.07 4.27 1241.84 23.87 156.26 1200.78 252.63 S 103.31 E -252.63 1.68 1335.22 27.10 155.89 1285.06 289.35 S 119.61 E -289.35 3.46 1427.91 28.48 156.92 1367.06 328.95 S 136.90 E -328.95 1.58 1522.14 28.68 160.94 1449.81 371.00 S 153.10 E -371.00 2.05 1615.42 27.46 160.00 1532.12 412.37 S 167.76 E -412.37 1.39 1708.56 25.55 157.73 1615.47 451.14 S 182.72 E -451.14 2.32 1802.73 22.48 155.37 1701.48 486.30 S 197.92 E -486.30 3.42 1895.07 21.58 152.14 1787.08 517.37 S 213.22 E -517.37 1.63 1988.54 20.69 147.38 1874.27 546.47 S 230.15 E -546.47 2.07 2082.38 19.62 150.07 1962.36 574.09 S 246.95 E -574.09 1.51 2175.53 14.64 148.37 2051.35 597.68 S 260.93 E -597.68 5.37 2268.90 13.31 146.05 2141.96 616.65 S 273.13 E -616.65 1.55 2362.47 7.97 147.86 2233.89 631.08 S 282.60 E -631.08 5.72 2455.07 4.08 148.62 2325.96 639.34 S 287.73 E -639.34 4.20 2548.72 2.65 136.73 2419.44 643.76 S 290.95 E -643.76 1.69 2576.60 2.26 134.26 2447.30 644.61 S 291.79 E -644.61 1.45 2673.89 1.19 131.69 2544.54 646.62 S 293.91 E -646.62 1.10 2732.02 0.19 90.04 2602.67 647.02 S 294.46 E -647.02 1.82 2825.44 0.09 109.77 2696.09 647.05 S 294.69 E -647.05 0.122918.61 0.06 110.86 2789.26 647.09 S 294.80 E -647.09 0.03 3012.23 0.06 56.78 2882.88 647.08 S 294.89 E -647.08 0.06 3106.34 0.04 76.99 2976.99 647.04 S 294.96 E -647.04 0.03 3197.15 0.06 339.32 3067.80 646.99 S 294.97 E -646.99 0.08 3292.44 0.03 77.62 3163.09 646.94 S 294.98 E -646.94 0.07 3385.15 0.06 94.54 3255.80 646.94 S 295.05 E -646.94 0.04 3478.63 0.04 216.65 3349.28 646.97 S 295.08 E -646.97 0.09 3572.58 0.09 325.33 3443.23 646.94 S 295.02 E -646.94 0.12 3666.02 0.12 156.69 3536.67 646.96 S 295.02 E -646.96 0.22 3759.48 0.04 136.88 3630.13 647.08 S 295.08 E -647.08 0.09 3852.25 0.08 221.67 3722.90 647.15 S 295.06 E -647.15 0.09 3946.18 0.06 277.03 3816.83 647.19 S 294.97 E -647.19 0.07 4038.44 0.04 147.85 3909.09 647.21 S 294.93 E -647.21 0.10 4350.00 0.04 147.85 4220.65 647.40 S 295.05 E -647.40 0.00 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINTTVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES (GRID)A TOTAL CORRECTION OF 0.00 DEG FROM MAGNETIC NORTH TO GRID NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD.HORIZONTAL DISPLACEMENT(CLOSURE) AT 4350.00 FEETIS 711.46 FEET ALONG 155.50 DEGREES (GRID) Date Printed:03 May 2012 DIRECTIONAL SURVEY REPORT Eni PetroleumSI20-N4Nikaitchuq Alaska United States AK-XX-0009388918 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 93.50 0.30 348.22 93.50 0.24 N 0.05 W 0.24 0.32 187.20 1.82 182.27 187.19 1.01 S 0.16 W -1.01 2.25 283.30 4.54 172.37 283.13 6.30 S 0.29 E -6.30 2.88 377.40 8.97 166.50 376.55 17.13 S 2.49 E -17.13 4.76 469.40 13.76 160.44 466.73 34.43 S 7.83 E -34.43 5.36563.30 16.92 156.40 557.27 57.48 S 17.05 E -57.48 3.55 654.60 17.16 153.80 644.57 81.74 S 28.31 E -81.74 0.87 748.90 17.15 156.39 734.67 106.96 S 40.02 E -106.96 0.81 773.03 16.54 156.60 757.77 113.37 S 42.81 E -113.37 2.54 868.41 16.68 159.77 849.17 138.68 S 52.94 E -138.68 0.96 962.12 16.89 158.03 938.89 163.92 S 62.68 E -163.92 0.58 1054.75 18.46 154.64 1027.14 189.65 S 74.00 E -189.65 2.03 1147.99 22.44 154.55 1114.49 219.07 S 87.97 E -219.07 4.27 1241.84 23.87 156.26 1200.78 252.63 S 103.31 E -252.63 1.68 1335.22 27.10 155.89 1285.06 289.35 S 119.61 E -289.35 3.46 1427.91 28.48 156.92 1367.06 328.95 S 136.90 E -328.95 1.58 1522.14 28.68 160.94 1449.81 371.00 S 153.10 E -371.00 2.05 1615.42 27.46 160.00 1532.12 412.37 S 167.76 E -412.37 1.39 1708.56 25.55 157.73 1615.47 451.14 S 182.72 E -451.14 2.32 1802.73 22.48 155.37 1701.48 486.30 S 197.92 E -486.30 3.42 1895.07 21.58 152.14 1787.08 517.37 S 213.22 E -517.37 1.63 1988.54 20.69 147.38 1874.27 546.47 S 230.15 E -546.47 2.07 2082.38 19.62 150.07 1962.36 574.09 S 246.95 E -574.09 1.51 2175.53 14.64 148.37 2051.35 597.68 S 260.93 E -597.68 5.37 2268.90 13.31 146.05 2141.96 616.65 S 273.13 E -616.65 1.55 2362.47 7.97 147.86 2233.89 631.08 S 282.60 E -631.08 5.72 2455.07 4.08 148.62 2325.96 639.34 S 287.73 E -639.34 4.20 2548.72 2.65 136.73 2419.44 643.76 S 290.95 E -643.76 1.69 2576.60 2.26 134.26 2447.30 644.61 S 291.79 E -644.61 1.45 2673.89 1.19 131.69 2544.54 646.62 S 293.91 E -646.62 1.10 2731.85 0.56 125.31 2602.50 647.18 S 294.59 E -647.18 1.10 2824.28 5.39 324.76 2694.80 643.90 S 292.46 E -643.90 6.412922.82 12.48 311.35 2792.09 633.07 S 281.78 E -633.07 7.45 3011.76 14.99 316.79 2878.49 618.33 S 266.69 E -618.33 3.17 3100.52 19.83 314.82 2963.16 599.34 S 248.14 E -599.34 5.49 3198.21 24.02 315.39 3053.76 573.50 S 222.41 E -573.50 4.29 3291.50 28.32 311.94 3137.47 545.18 S 192.60 E -545.18 4.89 3384.91 32.51 310.21 3218.01 514.15 S 156.93 E -514.15 4.58 3478.39 35.05 307.11 3295.71 481.73 S 116.33 E -481.73 3.28 3571.24 36.44 303.86 3371.07 450.27 S 72.17 E -450.27 2.53 3662.33 39.68 300.38 3442.79 420.48 S 24.59 E -420.48 4.26 3758.02 43.19 300.18 3514.52 388.56 S 30.08 W -388.56 3.67 3852.23 46.83 297.75 3581.12 356.34 S 88.38 W -356.34 4.27 3945.43 49.66 299.75 3643.18 322.88 S 149.31 W -322.88 3.43 4038.53 53.29 301.34 3701.16 285.85 S 212.01 W -285.85 4.12 4131.73 57.11 301.35 3754.34 246.05 S 277.36 W -246.05 4.10 4224.61 62.02 301.40 3801.38 204.37 S 345.71 W -204.37 5.29 4318.57 67.02 302.43 3841.79 159.53 S 417.68 W -159.53 5.41 4417.11 72.01 304.52 3876.27 108.61 S 494.63 W -108.61 5.44 4504.69 78.80 305.35 3898.32 60.10 S 564.07 W -60.10 7.81 4598.24 83.82 305.11 3912.45 6.77 S 639.58 W -6.77 5.37 4691.72 84.59 304.22 3921.89 46.13 N 716.07 W 46.13 1.26 4785.91 84.68 305.42 3930.70 99.67 N 793.06 W 99.67 1.27 4885.77 85.66 306.31 3939.11 157.97 N 873.70 W 157.97 1.32 4970.51 87.89 309.36 3943.88 209.86 N 940.50 W 209.86 4.45 5063.64 91.56 311.07 3944.32 269.97 N 1011.60 W 269.97 4.35 5157.30 91.07 311.06 3942.17 331.48 N 1082.20 W 331.48 0.52 5250.97 90.55 312.16 3940.85 393.68 N 1152.23 W 393.68 1.30 5343.53 90.33 311.44 3940.14 455.37 N 1221.23 W 455.37 0.81 5437.71 89.72 313.69 3940.10 519.07 N 1290.59 W 519.07 2.48 5531.18 89.69 316.78 3940.58 585.43 N 1356.40 W 585.43 3.315624.84 89.97 317.86 3940.86 654.28 N 1419.89 W 654.28 1.19 5718.05 90.91 317.55 3940.14 723.22 N 1482.61 W 723.22 1.06 5812.06 89.59 313.68 3939.73 790.39 N 1548.36 W 790.39 4.35 5904.74 89.56 314.88 3940.42 855.10 N 1614.71 W 855.10 1.30 5997.99 90.90 317.31 3940.04 922.27 N 1679.37 W 922.27 2.98 6091.52 90.19 316.48 3939.15 990.56 N 1743.28 W 990.56 1.17 6183.19 90.87 317.11 3938.31 1057.37 N 1806.03 W 1057.37 1.01 6278.74 86.86 316.31 3940.20 1126.89 N 1871.52 W 1126.89 4.28 6371.41 85.61 315.69 3946.28 1193.41 N 1935.75 W 1193.41 1.51 6465.40 88.83 316.34 3950.84 1260.95 N 2000.94 W 1260.95 3.49 6557.81 90.49 317.72 3951.39 1328.56 N 2063.92 W 1328.56 2.34 6651.67 90.99 317.52 3950.18 1397.89 N 2127.19 W 1397.89 0.57 6744.53 89.64 316.05 3949.67 1465.56 N 2190.77 W 1465.56 2.15 6838.25 89.99 315.28 3949.97 1532.59 N 2256.26 W 1532.59 0.90 6931.00 89.81 315.51 3950.13 1598.63 N 2321.39 W 1598.63 0.31 7024.89 90.04 315.28 3950.25 1665.47 N 2387.32 W 1665.47 0.35 7118.04 88.61 312.34 3951.35 1729.95 N 2454.53 W 1729.95 3.51 7210.97 89.20 311.98 3953.13 1792.31 N 2523.40 W 1792.31 0.74 7304.09 88.98 313.68 3954.61 1855.60 N 2591.68 W 1855.60 1.84 7398.13 88.93 314.46 3956.32 1921.00 N 2659.24 W 1921.00 0.83 7491.17 88.90 313.26 3958.08 1985.46 N 2726.31 W 1985.46 1.29 7581.84 88.63 313.95 3960.04 2047.97 N 2791.95 W 2047.97 0.82 7678.48 88.98 314.77 3962.05 2115.53 N 2861.03 W 2115.53 0.92 7771.04 92.50 315.08 3960.86 2180.87 N 2926.55 W 2180.87 3.82 7864.17 93.96 315.20 3955.61 2246.78 N 2992.13 W 2246.78 1.57 7958.07 94.97 317.63 3948.30 2314.58 N 3056.67 W 2314.58 2.80 8050.89 92.07 315.64 3942.60 2381.92 N 3120.28 W 2381.92 3.798144.21 92.76 316.09 3938.67 2448.84 N 3185.20 W 2448.84 0.88 8237.49 91.86 316.21 3934.91 2516.05 N 3249.77 W 2516.05 0.97 8331.36 94.55 317.23 3929.66 2584.28 N 3314.02 W 2584.28 3.06 8424.42 94.14 316.00 3922.61 2651.71 N 3377.76 W 2651.71 1.39 8518.42 91.79 314.57 3917.75 2718.41 N 3443.80 W 2718.41 2.93 8610.74 91.29 314.69 3915.27 2783.25 N 3509.47 W 2783.25 0.56 8704.35 92.89 315.86 3911.85 2849.71 N 3575.30 W 2849.71 2.12 8797.33 90.12 315.23 3909.41 2916.05 N 3640.39 W 2916.05 3.06 8891.42 90.08 315.38 3909.25 2982.93 N 3706.57 W 2982.93 0.16 8984.24 89.78 314.88 3909.36 3048.71 N 3772.05 W 3048.71 0.63 9077.66 91.04 315.86 3908.69 3115.19 N 3837.68 W 3115.19 1.71 9170.97 90.60 315.32 3907.36 3181.84 N 3902.97 W 3181.84 0.75 9264.14 88.02 312.54 3908.48 3246.47 N 3970.05 W 3246.47 4.079357.66 89.57 312.56 3910.45 3309.69 N 4038.93 W 3309.69 1.66 9450.97 91.54 313.47 3909.54 3373.34 N 4107.15 W 3373.34 2.33 9544.67 94.02 314.59 3905.00 3438.38 N 4174.43 W 3438.38 2.90 9637.68 93.02 313.99 3899.29 3503.20 N 4240.88 W 3503.20 1.25 9731.32 92.13 311.42 3895.08 3566.64 N 4309.62 W 3566.64 2.90 9824.55 92.71 312.56 3891.14 3628.96 N 4378.85 W 3628.96 1.37 9917.86 92.70 313.62 3886.74 3692.63 N 4446.91 W 3692.63 1.13 10011.28 91.28 312.28 3883.50 3756.24 N 4515.25 W 3756.24 2.09 10105.31 91.07 311.12 3881.57 3818.78 N 4585.44 W 3818.78 1.25 10198.45 89.49 308.82 3881.11 3878.60 N 4656.81 W 3878.60 3.00 10291.46 90.05 307.32 3881.49 3935.95 N 4730.03 W 3935.95 1.72 10384.48 90.13 308.98 3881.34 3993.41 N 4803.18 W 3993.41 1.79 10478.16 90.00 307.71 3881.23 4051.53 N 4876.65 W 4051.53 1.36 10571.68 84.84 305.73 3885.44 4107.37 N 4951.51 W 4107.37 5.91 10664.37 86.68 304.18 3892.30 4160.32 N 5027.26 W 4160.32 2.59 10757.21 89.30 305.12 3895.55 4213.07 N 5103.58 W 4213.07 3.00 10851.85 90.13 307.03 3896.02 4268.80 N 5180.07 W 4268.80 2.20 10945.42 90.90 308.18 3895.18 4325.89 N 5254.19 W 4325.89 1.48 11038.12 91.39 310.05 3893.33 4384.36 N 5326.10 W 4384.36 2.08 11131.17 93.15 311.88 3889.64 4445.31 N 5396.30 W 4445.31 2.73 11225.31 92.11 313.25 3885.32 4508.92 N 5465.56 W 4508.92 1.83 11318.31 93.63 312.33 3880.67 4572.01 N 5533.72 W 4572.01 1.91 11411.75 91.24 313.02 3876.70 4635.29 N 5602.35 W 4635.29 2.66 11504.98 89.73 312.70 3875.91 4698.70 N 5670.69 W 4698.70 1.66 11598.38 89.62 314.48 3876.44 4763.09 N 5738.33 W 4763.09 1.91 11692.73 90.68 313.47 3876.19 4828.60 N 5806.23 W 4828.60 1.55 11785.28 92.23 313.51 3873.84 4892.28 N 5873.35 W 4892.28 1.6811878.57 92.45 315.40 3870.03 4957.55 N 5939.88 W 4957.55 2.04 11972.08 89.05 315.63 3868.81 5024.25 N 6005.39 W 5024.25 3.6412065.03 87.24 311.73 3871.82 5088.40 N 6072.56 W 5088.40 4.62 12158.31 86.94 310.35 3876.55 5149.56 N 6142.83 W 5149.56 1.51 12252.10 91.44 313.98 3877.88 5212.49 N 6212.31 W 5212.49 6.16 12344.82 89.11 315.22 3877.43 5277.59 N 6278.32 W 5277.59 2.85 12437.83 92.76 318.50 3875.92 5345.42 N 6341.89 W 5345.42 5.28 12531.83 88.26 316.02 3875.08 5414.44 N 6405.66 W 5414.44 5.47 12625.08 85.49 310.69 3880.17 5478.33 N 6473.33 W 5478.33 6.43 12719.28 87.50 309.91 3885.93 5539.14 N 6545.04 W 5539.14 2.29 12786.00 87.50 309.91 3888.84 5581.91 N 6596.16 W 5581.91 0.00 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINTTVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEADVERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES (GRID)A TOTAL CORRECTION OF 0.00 DEG FROM MAGNETIC NORTH TO GRID NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD.HORIZONTAL DISPLACEMENT(CLOSURE) AT 12786.00 FEETIS 8641.01 FEET ALONG 310.24 DEGREES (GRID) Date Printed:02 May 2012 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 11,000 12,000 13,000 14,000 0 5 10 15 20 25 30 35 40 Me a s u r e d D e p t h Rig Days Prognosed Actual SI20-N4 Days vs. Depth 27 Mar 2012Reached surface TD at 1350 hrs2,648' MD / 2,518' TVD 20 Apr 2012Run & Land 9 5/8" casing to 4,937' MD 25 April 2012TD reached12,786' MD / 3,889' TVD 28 Mar 2012Run & Land 13 3/8" casing to 2,636' MD 24 Mar 2012 SDL rig up unit and gas equipment 25 Mar 2012Pre Spud Meeting 1st Core Barrel Jams. 2nd "N Sand" Core begins @ 3,971' MD. 15 Apr 2012Kick-off cement plug @ 2,720' MD 1st "N Sand" Core begins @ 3,955' MD Drill ahead to "OA Sand" core point @ 4,111' MD. Pick up core barrel and core OA Sand. 9 Apr - 12 Apr 2012 Safety Stand Down 18 Apr 2012Reached intermediate TD at 1540 hrs4,957' MD / 3,943' TVD 6 April 2012SI20-N4 PH TD reached4,350' MD / 4,221' TVD Surface Data Logging After Action Review Employee Name: Emil Opitz Date: 30 Apr 2012 Well: SI20-N4 Hole Section: Production What went as, or better than, planned: Gas traps functioned well. Insite functioned well. Lag was calculated properly. Gas lines did not freeze. Difficulties experienced: We still have constant accumulations of moisture in our gas system, resulting in failures of the gas gear. Future wells will be utilizing WEI subs, meaning that there will be constant pumping for 7+ days, and we will not be able to blow back our gas lines without relinquishing the ablilty to monitor gas in an open hole that is being pumped. We are still awating a "vortex cooler", which was ordered in Feb 2012. Recommendations: Blow back gas lines whenever the possibility arises. Innovations and/or cost savings:
