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210-022
i • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,February 20,2018 Jim Regg P.I.Supervisor e/ei Z Z1l,e SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD3-121 FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-121 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry.jr'j►Z NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-121 API Well Number 50-103-20615-00-00 Inspector Name: Lou Laubenstein Permit Number: 210-022-0 Inspection Date: 2/11/2018 Insp Num: mitLOL180212124753 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3-121 Type InjW 'TVD 6800 Tubing 2463 2463• 2442 2440 PTD I 2100220 Type Test, SPT Test psi 1700 ' IA 1450 1950 1900 • I 1890 " 1- . ' BBL Pumped: 0.3 '1BBL Returned: 0.2 OA 650 653 _ 651 - 650 Interva4YRTST - T l. P/F P ✓ I Notes: SCANNED 1 .'4i: `$ 2 , . :i. Tuesday, Tuesday,February 20,2018 Page 1 of 1 2\0 - 022. CP 3 , 1C9- RECEIVED C:onoc®PhiIIips APR 2 7 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 23, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AIS 99501 SUMEr i\/14c . %01` i Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. A s per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, MJ oveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant T op ofi Report of Sundry Operations(10404) Alpine Field Date 4/23/2015 CD3 PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal CD3-121 50103206150000 2100220 32"(--> NA 32" NA 29.7 3/12/2015 CD3-122 50103206090000 2091530 74" NA 74" NA 49.3 3/12/2015 CD3-130 50103206770000 2131600 38" NA 38" NA 20.4 3/12/2015 CD3-198 50103206370000 2110240 28" NA 15" NA 2.5 3/24/2015 CD3-316 50103205590300 2140180 9" NA 26" NA 14 4/20/2015 CD3-320 50103206670000 2130060 6" NA 6" NA 1.7 3/24/2015 0 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q i Q - D °eC a Well History File Identifier Organizing (done) Two -sided III (' lIIII III ❑ Rescan Needed 1 1111 I I 1 11 R CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Di kettes, No. p' ❑ Maps: Greyscale Items: Other, No/Type: G V / VO. '� ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: 1/51/ a ... /s/ TIP Project Proofing I 11111111111 BY: Maria Date: VS/0_ /s/ n 1 Scanning Preparation 3 x 30 = D + 9_7 = TOTAL PAGES l 1 7 V5- (Count does not include cover sheet) BY: Date: ` J /s/ Production Scanning I '11111111 11111 Stage 1 Page Count from Scanned File: ' 1 C 1 , (Count does include cov r sheet) Page Count Matches Number in Scanning Preparation: include NO BY: Date: 1/5/1a /s/ V}1 10 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I I I III III 1 ReScanned I I BY: Maria Date: /s/ Comments about this file: Quality Checked I 12/22/2011 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 10/24/2011 Permit to Drill 2100220 Well Name /No. COLVILLE RIV FIORD CD3 -121 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20615 -00 -00 MD 15081 TVD 7014 Completion Date 4/6/2010 Completion Status WAGIN Current Status WAGIN /1110 REQUIRED INFORMATION Mud Log No Samples No Directional Surve ;� DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: ill Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med /Frmt Number Name Scale Media No Start Stop CH Received Comments - -- ----------------------- - - - - -- ----- - - - - -- -- - - - - -- - -- - - -- " pt LIS Verification 2687 15081 Open 4/13/2010 LIS Veri, GR, RPD, FET, RPS, RPM, RPX, ROP C Lis 19544 ✓Induction /Resistivity 2687 15081 Open 4/13/2010 OH LIS GR, RPD, FET, RPS, RPM, RPX, ROP plus Graphics 1 og Induction /Resistivity 25 Col 114 15081 Open 4/13/2010 MD ROP, DGR, EWR og Induction /Resistivity 25 Col 114 7014 Open 4/13/2010 TVD ROP, DGR, EWR d og Cemen Bond 15 Col 7645 8878 Open 5/6/2010 BAT. GR �D C Tf 19611 Cement Bond 7645 8878 Case 5/6/2010 CBL in CGM, PDS, EMF, TIFF graphics I ED C Asc • Directional Survey 33 15081 Open t Directional Survey 33 15081 Open Well Cores /Samples Information: • t Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Daily History Received? Y N Chips Received? - 1'-1 -PFD Formation Tops 6/ N Analysis i' -4-N- VJ Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/24/2011 Permit to Drill 2100220 Well Name /No. COLVILLE RIV FIORD CD3 -121 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20615 -00 -00 MD 15081 TVD 7014 Completion Date 4/6/2010 Completion Status WAGIN Current Status WAGIN UIC Y Compliance Reviewed By: 40 Date: ?f O /tr) • • • Nov ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 3, 2011 -2-2 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 FEB 0 4 2011 Anchorage, AK 99501 , iverke CI1~ a. Gfi Cons. C , .:::asion Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped January 31, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, 7 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 2/3/2011 CD3 Pad Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped . cement date inhibitor sealant date ft bbls ft gal CD3 -106 50103206110000 2100010 16" NA 16" NA 7.65 1/31/2011 CD3 -110 50103205090000 2050410 4" NA 6" NA 2.13 1/312011 Cb3- 112 50103205270000 2060320 3" NA 16" NA 2.73 1/31/2011 CD3- 114 50103205440000 2070330 5" NA 14" NA 2.55 1/312011 /0> CO3 =121 50103206150000 2100220 32" NA 32" NA 27.2 1/31/2011 CD3- 122 50103206090000 2091530' 74" NA _ 74" NA 32.2 1/31/2011 C133 -124 50103206120000 _ 2100080 17" NA 17" NA 5.1 1/31/2011 CD3 -301A 50103205430100 2060170 9" NA 15" NA 4.25 1/31/2011 CD3 -302A 50103205220100 2100350 _ 5" NA 16" _ NA 3.83 1/31/2011 CD3 -304 50103205980000 _ 2090280 18" NA 18" NA 5.9 1/312011 • • 1 . rii7 2A° , 0�v I•'S:2,C. 'I CAI. INTEGRITY R PORT - _!Un DATE: - . /0 Zo /b OPEB & tan) ..... P. 'l/dos C Ieu. G RELE4 cE . • _ 1 1f i /Zoi o _ WELL NUMBER C D,3 - /Z../ — (F•rQ) LL DATA 'a:A: I 5 .. 7o 1 4 TVD.; oBTD: /5676 : 70/`> r D S te ' - c a s i n g : 9 �4 • Shoe. : '2723 W ZY( ; DV : -ice TVD '7" 'Lintz : Thal. _• Sboe: ' 87r .Iai ( 1vD; _OP: MD TVD :'ubirg y p €ckc= IV TVD; Set at Hole Si.:a /ZS~ and ; Perfs S4/�� �.o' -c . .771}I , KECRANIf AL INTEGRITY -• ?ART (1 A.nnui•v.s P.ressi lest: :::. Sy`j0 { 15 Mild 30 min .3342, Cot ants : / o.., /,4 4/ 'E.CILNICAS, INTEGRITY -• PART „�...� G� s; nL . ? Cameac Vo1uvs.s r, Amt. G'Z i-kkeg , ; DV .• Cta t vol. Lc cover pert. s - 2/E7,-.6-, Z .4=„ �., Theoretical TOC --- L( .�..� ?• ;(.�- •4 - -, Cement Bond Lag( or No) L_; In AOGCC File CBI. Evaluation, tone above perfs : s:ti i. Production Log: Typa /tl ; Evaluation • _ _. - ' CONCLUSIONS : . ?irt: ,. / —..,, _. _ .. .,.� -•rte? ..— — _. , •_�. • ?,a..zt 12 c C___e____,•-".....G.s.76.....,602, ____;,..5_________ _ i * . ."az.. .a I. ...401.4..c Nd 'c4 w/1:4,. , / $4 • , 13/Vr `-`' c • MIN no... '0 I'M cP3 I maim= ..= cA i,.... idifflumb.7 pc l ' t e No.... imii INIIIMMIN I =WILMA ' I r, 1111111 7650 , , II i i I i i %MUM 011111101111 • *NM i I 1 ____ MIIIMILII 1 NM. I* 1 1 9 11 11111.1.111 2 11 : 1 MIMI. Vs or IMMINIMMIMIIIIII ' ' il , 1 i'llEIMINIZI en, 11.1=11.11 , - .....ma , i , .4 - • '1 . '`,1' , ■IIII 1 4 *MinInil & , l 1 t '' -- ilIMINI1 ' i i I 07//WA M 11 I 1 ' ' ' 1 1 41 as 1111 . , 1 . 1 , . 1 , 1 , 1 r 1 i , 1 I t , ., , , 4 i I q/M1.11 , 2 NI ir f . . & • i i 1 , i, 11: : , . . 1 i li g. 7 h , aimum 7700 Min . NM , , o 1 IMMO air, l 1 ( 1 i ilinillil _ 411I I WI I 4 ) I ' 1 1 4 I 7 I I 1 a 1 WM ili * $ • • . 1 1 4 II 1 • III IIIII 7' . . or I l'i I I I ) 1 l i I OEMS= it. 4 4 . 1 .1 MN 7750 .... ..... - I I‘ t I 11111.11.11 1 I I 4 i i II MI WM t - . . ■ MI I I k I I I ''.. Ma Minna -talk p t . ill .... 71•1111 t 11 , „. I , =mom wigme aigh.t. ... ir, , 1 . , ,.. ) . \ II r- ,., , ir I I I ' II En • . . a wii 4 , i 111•11111111 .. .. i 1 ME W M i l k ) 1 I 1 I I 4 li Mi _ R 1 a I . it . , k • MARRA i ■ ' - OM aliali 7800 t i - ■IIIIl I f 1H, riii li f 111 . , - ..._%r- t ''''' 1 , 1 • 4 'f '' Inn r '. i , MIIIMIIIIIMIINMMOW % ' tr ,. , - • 51111 I . 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'gig ;- ..._. ____ f , _ k. . _ ,,,.._ 8600 . t , _ . - .� r v < - # 3 r - fi b s g t < .` ]f 4 :} - � i f 8700 s F 1 1 � � ' i E s Z .. r. -, " r' O000 DTC Casing Ener HF Waveform HB Waveform microsecperft MD BAT HF STC BAT HB STC g gy o 255 0 255 240 40 ft 240 40 240 40 0 700 0 700 1 : 1200 microseconds microseconds SGRC CASING CASING microsec per ft microsec per ft api CASING DTC DTC microsec per ft microsec per ft microsec per ft 240 40 240 40 CASING DTC DTC microsec per ft microsec per ft microsec per ft 240 240 40 240 40 SGRC CASING CASING 0 200 microsec per ft microsec per ft Casing Energy api DTC Casing Energy HF Waveform HB Waveform microsec per ft MD BAT HF STC BAT HB STC o 255 0 255 240 40 ft 240 40 240 40 0 700 1 : 240 microseconds 700 0 microseconds VVV - .(.). ConocoPhillips WELLBORE TARGET DETAILS (MAP CO-ORDINATES) C D 3 121 w p 0 3 Name TVDSS ON/-S +E / -W Northing Easting Shape CD3 -121 wp03 Toe 7023.00 - 3872.88 1482.115999636.98 /529429.54 Circle (Radius: 100.00) HALLIBURTOR! CD3- 121wp03 Toe Circle 7023.00 - 3872.88 1482.115999636.981529429.54 Circle (Radius: 1320.00) `-oorrV Orin, Quarter Mile View 13:47, February 11 2010 e 1 �� CO AO NA' < e`j 9 � N0 409 � GO3 � 0 ��� 6 G� , - G�31o9 GOB, �'� CD3-I07L GOB CO C d 0Ow e) 0: )� ?, \ 0 O � o CO 3p1 • 4000 w ` do' u),_ / �� 0, 111110 2000 0 W C cli a f 14 i Ix. N !1.32. y c..„ .„\art,W.2„,f, / Li , . t. N Ad GOB, 0 ey 0 NN'I II r4 ca Z 2000 , ii o CO PI G ti,, O _'� "gyp - 4000 �� � Ci NI - 6000 doZ -- -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 West( -) /East( +) (2000 ft /in) • • ConocoPhillips • INE 2. CD3 -121 Completion Schematic Colville River Field CD3 -121 Nechelik Injector Well Completion Updated 02/16/2010 Sperry Drilling Services 16" Conductor to 114' p 9 CD3-121wp03 O 3 DB Nipple @ 2147' MD / 2000' TVD """ 4 -1/2" 12.6 ppf IBT M tubing run with Jet Lube Run'n'Seal pipe dope V ■ 9 -5/8" 40 ppf L -80 BTC -Mod Surface Casing 2743' MD / 2470' TVD cemented to surface TOC @ +/- 4272' MD/ 3675' TVD Qannik interval top +/- 4772' MD / 4068' TVD ES Cementer +/- 5298' MD / K Q 0 MD TVD 4483' TVD Upper Completion _ 1) Tubing Hanger 32' 32' 2) 4 -'V,' 12.6 # /ft IBT -Mod Tubing 3) Camco DB Landing Nipple (3.813" ID) 2147' 2000' 4)4-W 12.6#/ft IBT -Mod Tubing 5) Camco 4-%" KBG -2 GLM (3.883" ID) 8200' 6725' 6) 4 -'/4" 12.6#/ft IBT -Mod Tubing (2) 7) Baker 4.5" X 7" Premier Packer 8300' 6770' 8) 4-%" 12.6 # /ft IBT -Mod Tubing (1) 9) HES No-Go "XN" (3.725" min ID) (go 65 8350' 6791' 10) 4-%" 12.6 # /ft IBT -Mod 10' Pup Jt 11) 4- 12.6#/ft IBT -Mod WLEG 8700' 6909' • © Packer TOC Calculated :.......... +/- 7863' MD / 6544' TVD (500' MD above Reservoir) • O © Well TD ® 14982' MD / Top Kuparuk Cat 8363' MD / 6796'TVD 7072' TVD Top Nechelik at 8908' MD / 6949' TVD 7" 26 ppf L -80 BTC Mod Casing 8946' / 6954' TVD @ 83° CD3 -121 Page 3 of 3 Drilling Program Version (2/18/2010) 40 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday, May 24, 2010 J im Regg e j Z 6 �, �, P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3 -121 FROM: John Crisp COLVILLE RIV FIORD CD3 -121 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry TX NON Comm Well Name: COLVILLE RIV FIORD CD3 - 121 API Well Number: 50 103 - 20615 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr100524103346 Permit Number: 210 - 022 - Inspection Date: 5/3/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. / Well CD3 -121 ' Type Inj. W 1 TVD 6800 s IA 860 3020 ✓ 2960 2940 P.T.D 21002201 TypeTest SPT 1 Test psi 1700 ., OA 454 649 ' 591 571 Interval INITAL p/F P - Tubing 18o0 1800 1800 1800 Notes: Monday, May 24, 2010 Page 1 of 1 • b McMains, Stephen E (DOA) From: Anderson, Nina M [ Nina .Anderson @conocophillips.com] Sent: Friday, May 07, 2010 11:07 AM To: McMains, Stephen E (DOA) Cc: Allsup- Drake, Sharon K; Walker, Jack A Subject: CD3 -121 Completion Report Steve — Below is a summary of events on CD3 -121 post rig release on April 1s'. Please let me know if you have any further questions. You can also contact the production engineer Jack Walker at 265 -6268. Thanks. The Doyon 19 rig was released from CD3 -121 on April 1=' 2010. Follow up post rig work to pull the ball & rod occurred o. April 5h, 2009. The well at this point was ready for fiowback operations. CD3 -121 was in flowback operations for one week from April 6th until April 13`h. Once this operation was complete, CD3 -121 was shut in awaiting the completion of surface facility tie in work. Post rig slickline work continued on April 23rd to prepare the well for injection service. Following a passing MITIA on April 24th, CD3 -121 was ready for injection. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)- 265 -6403 Cell: (907) 575 -3256 1 • • CD3 -121 Well Events Summary DATE SUMMARY 4/5/10 PULLED BALL & ROD FROM 8427' SLM. MEASURED BHP @ 8400' RKB; 3242 PSI. PULLED DV FROM 8277 RKB, REPLACED W/ 1/4" OV. PULLED RHC PLUG BODY FROM 8446' RKB. WELL IS READY FOR FLOWBACK. 4/18/10 TAG VERY THICK CRUDE W/ 2.5" BAILER @ 1257' SLM, MAKE SEVERAL GAUGE RING RUNS UNABLE TO WORK PAST 1350' SLM W/ 1.52" GAUGE RING. COMPLETE MOVE TO CD1 -10 4/23/10 TUBING OPEN 3.80 TO 8446' RKB, SET 4 1/2 STANDING VALVE @ 8446' RKB, PULLED 1" OV @ 8279' RKB. RDMO SLICKLINE, MIRU LRS PUMPING UNIT AND CIRCULATE TBGxIA 41 BBLS DIESEL ,206 BBLS INHIBITED SEAWATER (1% CRW -132) FOLLOWED BY 33 BBLS DIESEL FREEZE PROTECT, RETURN IN THE AM TO SET DMY GLV AND COMPLETE MIT -IA, (IN PROGRESS) 4/24/10 SET 1" DMY VLV @ 8276' RKB, GOOD MIT IA, SET 3.812" A -1 INJ VALVE @ 2151' RKB (S /N: HWS -379, ID 1.5 "), GOOD CLOSURE TEST, COMPLETE MOVE TO CD3 -302 • • Page 1 of 2 Schwartz, Guy L (DOA) From: Walker, Jack A [ Jack .A.Walker @conocophillips.com] Sent: Thursday, April 15, 2010 3:50 PM To: Schwartz, Guy L (DOA) Subject: RE: CD3 -121 Service Well pr. 2/0 - 0Z2_ Thanks, Guy. Will have the MIT -IA charted before injection is started. Jack From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, April 15, 2010 3 :46 PM To: Walker, Jack A Cc: Maunder, Thomas E (DOA) Subject: RE: CD3 -121 Service Well Jack, Based on review of the BAT log approval for initial injection into CD3 -121 is granted. Cement quality is quite good above 8800' for the most part with a few poor areas spread in the 8800 -8400' and range. I didn't see the projected TOC of 7860' and ( top logged interval is 7700' md) on this log but cement is good up to this depth (8400- 7700'md) and should provide zonal isolation. Though the top plug did not bump, based on the follow -up drilling of stringers a couple of hundred feet above the float collar, the stroke volume appeared to have been close. Be sure to chart the MIT -IA before injection in started. A follow -up witnessed MIT -IA is needed once the well is stable. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Walker, Jack A [ mailto:J ack .A.Walker @conocophillips.com] Sent: Thursday, April 15, 2010 2:22 PM To: Schwartz, Guy L (DOA) Cc: Robertson, Ryan G; Reed, Scott Subject: CD3 -121 Service Well Guy, The CD3 -121 (PTD- 2100220) was planned as a Service — WAG class well, and we propose starting injection operations after completing a mechanical integrity test. Enclosed is the BAT Bi -Modal Acoustic log that demonstrates isolation of the injection fluids to the approved interval (Fiord Oil Pool). I also enclosed other background information: (pre - completion) well sketch and time log summary with cementing operations. Please let me know if you concur on the cement log per AAC 25.030.(d)(7). We expect to complete the mechanical integrity test next week. Please call or reply with any questions. Jack Walker ConocoPhillips Alaska, Inc. Western North Slope Development 265 -6268 4/15/2010 BAT Sonic • • Page 1 of 2 Anderson, Nina M From: Schwartz, Guy L (DOA) [guy.schwartz @alaska.gov] Sent: Thursday, April 15, 2010 9:57 AM To: Anderson, Nina M c Subject: FW: BAT Sonic Nina, n 9 � List is below of what is not here. For injectors we need both hard copy and digital. ` Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Mahnken, Christine R (DOA) Sent: Thursday, April 15, 2010 8:21 AM To: Schwartz, Guy L (DOA) Subject: RE: BAT Sonic CD2 -121 No BAT: ap��l9� Jsi lo a CD3 -124 BAT is there Ll Z �'- i9 6// CD4 -24 BAT is there UaC 910-0a CD2 -78 BAT is there CD2 -73 No BAT -$ c7/b -03/ �� ,r It is on RBDMS under Logs or Data List to look for what we have and what I have put into it. From: Schwartz, Guy L (DOA) Sent: Wednesday, April 14, 2010 10:38 AM To: Mahnken, Christine R (DOA) Subject: FW: BAT Sonic Christine, Is this something that is easy to check ? ?? I would still like hard copies... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Anderson, Nina M [mailto: Nina .Anderson @conocophillips.com] Sent: Wednesday, April 14, 2010 10:30 AM To: Schwartz, Guy L (DOA) Subject: FW: BAT Sonic Guy - Can you please verify your records and see if you have hard copies of the BAT sonic data from the following injectors? If the data from any of these wells still needs to be updated, would you prefer just a log or also a CD? Thanks. • • WELL LOG TRANSMITTAL To: State of Alaska April 6, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: MWD Formation Evaluation Logs: CD3 -121 AK -MW- 0006991485 CD3 -121 2" x 5" MD Gamma Ray/Resistivity Logs: 1 Color Log 50 -103- 20615 -00 2" x 5" TVD Gamma Ray/Resistivity Logs: 1 Color Log 50 -103- 20615 -00 Digital Log Images & LWDG- formatted LIS Data w /verification listing; 1 CD Rom 50 -103- 20615 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3536 Fax: 907 - 273 -3535 (.4.7.- Bryan.Burinda @halliburton.com alb - t9 544 k D Date: pc 201ry Signed: L ..: 4 .;r • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION r Mechanical Integrity Test Email to: Winton_Aubert©admin.state.ak.us; Bob_Fleckenstein • admin.state.ak.us; Jim_Regg @admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips Alaska • FIELD / UNIT / PAD: Alipne DATE: 03/31/10 OPERATOR REP: D. Burley / J. Browning AOGCC REP: Packer Depth _ Pretest Initial 15 Min. 30 Min. Well CD3 -121 Type Inj. TVD 6,799' Tubing 1,040 1,440 1,500 1,510 Interval P.T.D. 2100220 Type test P Test psi 3490 Casing 0 3,490 3,392 3,362 P/F P Notes: OA 0 0 0 0 Well ' Type Inj. TVD Tubing ' Interval' P.T.D. Type test Test psi Casing P/F Notes: OA J Well Type Inj. I TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test, Test psi Casing P/F Notes: OA Well Type Inj. I TVD Tubing Interval P.T.D. Type test l Test psi Casing P/F Notes: OA ( TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waist M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I= Industrial Waistewater R = Intemal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) • ( MIT Report Form BFL 9/1/05 CD3 -121 MIT.xls • • Page 1 of 1 Schwartz, Guy L (DOA) From: Robertson, Ryan G [ Ryan. G.Robertson@conocophillips.com] Sent: Wednesday, February 24, 2010 2:30 PM To: Schwartz, Guy L (DOA) Subject: CD3 -121 Permit Details Attachments: CD3 -121- Completion Schematic - 2- 18- 10.pdf; CD3- 121wp03 PlanSummary (Nad27).pdf Guy, Attached is the information requested. There are no open pools within a % mile of CD3 -121. All hydrocarbon bearing zones on CD3 pad have been isolated from each other with cement. Ryan D1;IIing Engtmeer i t, oitocoFhnlips Alaska ; Direct (9 )7) 265 -6818 Mobile (907 ) 980-510; 2/24/2010 STATE OF ALASKA • RECEWED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 6 2010 WELL COMPLETION OR RECOMPLETION REPORT fission la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: And 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG iv WDSPL ❑ No. of Completions: Service El Stratigraphic Test El 2. Operator Name: 5. Dates., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: April 6, 2010 210 - 0220 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 March 10, 2010 50 103 - 20615 - 00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 3993' FNL, 1069' FEL, Sec. 5, T12N, R5E, UM March 28, 2010 CD3 - 121 Top of Productive Horizon: 8. KB (ft above MSL): 49' RKB 15. Field /Pool(s): 2308' FSL, 1925' FWL, Sec. 5, T12N, R5E, UM GL (ft above MSL): 12.5' AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2631' FSL, 440' FWL, Sec. 9, T12N, R5E, UM 15076' MD / 7014' TVD Fiord Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 387974 y 6003784 Zone 4 15081' MD / 7014' TVD ADL 372105, 372104 TPI: x - 385701 y - 6004840 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit Total Depth: x 389436 y 5999826 Zone 4 nipple @ 2152' MD / 2002' TVD 2560 18. Directional Survey: Yes i0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1543' MD / 1500' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD GR/Res not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H -40 36' 114' 36' 114' 24" pre - installed 9.625" 40# L -80 36' 2723' I 36' 2457' 12.25" 384 sx AS Lite III, 257 sx LiteCRETE ✓ 7" 26# L -80 34' 8878' ✓ 34' 6945' 8.75" 225 sx Class G, 191 sx Class G 4.5" 12.6# L -80 8702' 15076' 6909' 7014' 6.75" slotted liner 24. Open to production or injection? Yes ❑ No i0 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" 8710' 8388' MD / 6799' TVD slotted liner from 8894' -9884' MD 6946' -6960' TVD and from 10412'- 14992' MD 6971' -7022' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 27, 2010 WAG injector Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> 2200 Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No i0 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. -' 6i1 �i'L t f�Q AT NONE �'� Form 10 -407 Revised 12/2002_ DMS w 0 6 9f1 CONTINUED ON REVERSE Submit original only 4. kz.0„„ e-,0...4, • 28. GEOLOGIC MARKERS (List all formations and marke rs encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes IN No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1543' 1500' needed, and submit detailed test information per 20 AAC 25.071. K -2 (Qannik) 4773' 4069' K -1 8180' 6710' Kuparuk C 8362' 6789' Nechelik 8819' 6936' N/A Formation at total depth: Nechelik 30. LIST OF ATTACHMENTS Summary of Daily Operations, final directional survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nil @ 265 - 6403 Printed Name Ivord Title: Alaska Drilling Manager NN Signature Phone 265 - 6120 Date ' �(s 1 I r 000 Sharon Allsup -Drake 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 la: 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: 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 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 ir,,, WNS • CD3 -121 COnOCCoPhilh ps =',• Well Attributes 'Max Angle 8, MD TD fsC4)4i3 Inc Wellbore APVUWI Field Name Well Status Inc! (.) MO (ftKB) Act Btm (ftKB) 4u�ro1�lva,p• ? 501032061500 FIORD NECHELIK INJ 9487_ 15,01508 15,0810 ( ) (plan/ Comment IH25 Date Annotation 'End Date KB -Grd (ft) Rig Release Date •• Well Config. HORIZONTAL _003.121,4/25/2010 8 09 45 AM SSSV NIPPLE �LosI WO - - l 42 07 4/1/2010 _.. Schematic Actual Annotation Depth kKB End Date Annotation Last Mod ... End Date Last Tag- I CI I Rev Reason- Set Inj Vlv, GLV C/0 Imosbor 4/25/2010 Casing Strings HANGER. 31 -:;. Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 24" 16 15.250 36.0 114. 114.0 62.50 (1 WELD Insulated c` Casing De String 0... String ID ... Top (ftKB) Set Depth f .. Set De D String Wt .. String String Top Thrd ( M 9 9 ( Depth (N ) 9 9 ... SURFACE 9 5/8 8.835 36.0 2,723 3 2,457.2 40.00 L-80 BTC -M — — % " -- Casing Description String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd r 1 4 INTERMEDIATE 7 6.276 337 8,8/8.1 6,944.5 26.00 L 8TC - m ;. Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd Slotted Liner 41/2 3.958 8,701.7 15,076.0 7,014.4 12.60 L -80 SLHT - - , ' Liner Details CONDUCTOR Top Depth 24' Insulated, I .` (TVD) Top Inc! Nomi... 36 -114 i To• ftKB (ftKB) (°) Item Description Comment -_. -. ID(in) 8,701.7 6,908.9 74 07 Setting Sleeve "HRD" Setting Sleeve w/ 10' Seal Bore Receptacle 5.750 1x 8,714.7 6,912.5 74.54 NIPPLE "RS" Packoff Seal Nipple 4.850 8,718.5 6,913.5 74.67 HANGER Baker Flexlock "DG" 5 "0 7" Liner Hanger (Shear Pressure 2,000 Psi) 4.900 NIPPLE, 2,152 8,728.2 6,915.5. 75.27 XO - Reducing X0 5 1/2" Hydril 521 Box to 4 1/2" SLHT Pin 3.930 VALVE, 2,152 ri Strings String 0... String ID ... T Tubing Strings '- Tubing De op (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... Strmg ... !String Top Thrd I s Tubing - Waterin). I 41/2 3.958 I 30 -7 I 8,710.0 6,9112 12.60 L -80 IBTM - Completion Details Top Depth ' (ND) Top Inc/ Nomi... Top (NCB) (BBB) (') Item Description -_.- Comment ID (in) 30.7 30.7 -0.05 HANGER FMC 4 1/2" IBTM Tubing Hanger w/41/2" IBTM Pup Joint 4.500 2,151.7 2,001.5 36.75 NIPPLE Camco 4 1/2" 'DB' Landing Nipple 3.812 SURFACE, _.. + , 8,388.0 6,799.7 66.04 PACKER Baker Premier 4 1/2" by 7" Packer 3.870 36 - 2,723 — - - - - -- T' 8,445.6 6,822.2 - 66.32 NIPPLE HES "XN" Nipple w/ RHC Plug (3.813" ID w/ 3725" No -Go) 3.725 ■ ,;■ 8,699.6 6,908.3 73.99 LOCATOR Fluted No -Go Sub Above Locator (TOL 8701.69' MD) 4.500 ,,r 8,700.4 6,908.5 74.02 LOCATOR Fluted No-Go Sub Below Locator 4.500 8,709 0 6,911 0 74 33 WLEG WLEG 3.960 Other In Hole 'reline retrievable plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT,_ '' - (TVD) Top Inc' 8,277 - Top (ftKB) (ftKB) (') Description _.. Comment Run Date ID (in) 2,152 2,001.6 36.75 VALVE 3.812 "A -1 INJECTION VALVE (HWS -379) 4/24/2010 1.500 Perforations & Slots _ Shot XO - Threads, Top (TVD) Btm (TVD) Dens 6.378 Top (ftKB) Ban (8609 (ftKB) (MB) Zone Date (eh ... Type Comment PACKER, 6,386 - -- - r.r.0 a 8,894 9,884 6,946.4 6.959.7 3/30/2010 32.0 SLOTS Slots 1/8x225 ", 8 slots/row, 4 rows /ft; no slots 3' from box/pin 10,412 14,992 6,971.3 7,021.5 3/30/2010 32.0 SLOTS Slots 1/862.25 ", 8 slots/row, 4 rows/ft; no slots 3' from box/pin Notes: General & Safety NIPPLE, 8,446 -- L End Date Annotation 4/17/2010 OTE: VIEW SCHEMATIC w /Alaska Schematic9.0 III LOCATOR, 8,700 LOCATOR, 8,700 WLEG, 8,709— -- I �. I i ` Mandrel Details - - Top Depth Top port (TVD) Inc/ OD Valve L atch SW TRO Run Stn Top (1166); (ftKB) 1") Make Model (in) Tye (in) n) Sexy Type p (psi) Run Date Com... NTERMEDIATE, 1 8,27(x.6'. 6,753.4 64,90 Camco KBG 1 GAS LIFT DMY BK 0.000 0.0 4/24/2010 34 -8,878 - -_ - SLOTS, 8,894 -9,884 -- SLOTS. . 10,412- 14,992 Slotted Liner, 8,702- 15,076 TD, 15,081 - 0 - = ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3 -121 - F 50103206150000 -, :. Sperry Drilling Services - Definitive Survey Report t 02 April, 2010 1 A a G • - :rt i HALLIBURTON Sperry Drilling Services 1 I • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -121 Project Western North Slope TVD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft ( Doyon 19) Well: CD3 - 121 North Reference: True Wellbore: CD3 - 121 Survey Calculation Method: Minimum Curvature Design: CD3 -121 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD3 - 121 Well Position +N / -S 0.00 ft Northing: 6,003,784.21 ft Latitude: 70° 25' 9.396 N +E / - 0.00 ft Easting: 387,974.13 ft Longitude: 150° 54' 45.417 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.50ft Wellbore CD3 - 121 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) (°) (nT) BGGM2009 3/15/2010 21.26 80.78 57,628 Design CD3 - 121 Audit Notes: i Version: 1.0 Phase: ACTUAL Tie On Depth: 36.87 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) r) 36.87 0.00 0.00 142.00 Survey Program Date 4/2/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 83.91 1,200.00 CD3 -121 Gyro (CD3 -121) GYD -GC -SS Gyrodata gyro single shots 3/11/2010 1: 1,235.73 2,687.07 CD3 -121 MWD -1 (CD3 -121) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 3/11/2010 1: 2,778.33 8,846.60 CD3 -121 MWD -3 (CD3 -121) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 3/14/2010 1: 8,931.96 15,015.08 CD3 -121 MWD-4 (CD3 -121) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 3/24/2010 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/-W Northing Easting DLS Section (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100') (ft) Survey Tool Name 36.87 0.00 0.00 36.87 -12.50 0.00 0.00 6,003,784.21 387,974.13 0.00 0.00 UNDEFINED 83.91 0.35 260.78 83.91 34.54 -0.02 -0.14 6,003,784.19 387,973.99 0.74 -0.07 GYD -GC -SS (1) 172.00 0.61 254.24 172.00 122.63 -0.19 -0.86 6,003,784.03 387,973.27 0.30 -0.38 GYD -GC -SS (1) 265.00 0.76 268.82 264.99 215.62 -0.34 -1.95 6,003,783.90 387,972.17 0.25 -0.93 GYD -GC -SS (1) 357.00 1.36 300.03 356.97 307.60 0.19 -3.51 6,003,784.46 387,970.63 0.88 -2.31 GYD -GC -SS (1) 451.00 2.32 305.31 450.92 401.55 1.85 -6.03 6,003,786.15 387,968.13 1.04 -5.17 GYD -GC -SS (1) 543.00 3.00 313.37 542.83 493.46 4.58 -9.30 6,003,788.93 387,964.90 0.84 -9.33 GYD -GC -SS (1) 634.00 4.54 330.19 633.63 584.26 9.34 -12.82 6,003,793.74 387,961.45 2.07 -15.25 GYD -GC -SS (1) 727.00 6.56 338.61 726.19 676.82 17.48 -16.58 6,003,801.94 387,957.81 2.34 -23.99 GYD -GC -SS (1) 820.00 7.80 335.20 818.46 769.09 28.16 -21.17 6,003,812.68 387,953.39 1.41 -35.22 GYD -GC -SS (1) 914.00 10.21 329.04 911.30 861.93 41.09 -28.13 6,003,825.72 387,946.62 2.76 -49.70 GYD -GC -SS (1) 4/2/2010 10 :05:34AM Page 2 COMPASS 2003.16 Build 69 i I ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -121 Project Western North Slope TVD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft (Doyon 19) Well: CD3 - 121 North Reference: True Wellbore: CD3 - 121 Survey Calculation Method: Minimum Curvature Design: CD3 - 121 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °!100') (ft) Survey Tool Name 1,009.00 16.19 324.13 1,003.75 954.38 59.06 -40.24 6,003,843.87 387,934.79 6.40 -71.31 GYD -GC -SS (1) 1,104.00 16.88 325.34 1,094.82 1,045.45 81.14 -55.84 6,003,866.17 387,919.52 0.81 -98.32 GYD -GC -SS (1) 1,200.00 18.16 323.62 1,186.36 1,136.99 104.65 -72.64 6,003,889.93 387,903.07 1.44 - 127.19 GYD -GC -SS (1) 1,235.73 19.31 323.28 1,220.20 1,170.83 113.87 -79.48 6,003,899.25 387,896.38 3.23 - 138.66 MWD +IFR -AK- CAZ -SC (2) 1,286.16 21.07 322.53 1,267.53 1,218.16 127.75 -89.98 6,003,913.28 387,886.09 3.53 - 156.06 MWD +IFR -AK- CAZ -SC (2) 1,330.99 21.90 322.58 1,309.24 1,259.87 140.79 -99.96 6,003,926.47 387,876.30 1.85 - 172.48 MWD +IFR -AK- CAZ -SC (2) 1,426.67 25.65 325.89 1,396.79 1,347.42 172.12 - 122.42 6,003,958.13 387,854.31 4.16 - 211.00 MWD +IFR -AK- CAZ -SC (2) 1,521.88 28.01 326.87 1,481.75 1,432.38 207.90 - 146.20 6,003,994.27 387,831.08 2.52 - 253.84 MWD +IFR -AK- CAZ -SC (2) 1,617.21 29.54 327.38 1,565.30 1,515.93 246.45 - 171.11 6,004,033.17 387,806.75 1.63 - 299.55 MWD +IFR -AK- CAZ -SC (2) 1,709.49 32.50 325.39 1,644.38 1,595.01 286.02 - 197.46 6,004,073.14 387,781.00 3.39 - 346.95 MWD +IFR -AK- CAZ -SC (2) 1,806.94 33.33 324.99 1,726.19 1,676.82 329.50 - 227.69 6,004,117.06 387,751.43 0.88 - 399.82 MWD +IFR -AK- CAZ -SC (2) 1,902.04 37.71 325.31 1,803.57 1,754.20 374.83 - 259.24 6,004,162.86 387,720.56 4.61 - 454.98 MWD +IFR -AK- CAZ -SC (2) 1,997.58 38.58 325.73 1,878.71 1,829.34 423.48 - 292.65 6,004,211.99 387,687.89 0.95 - 513.88 MWD +IFR -AK- CAZ -SC (2) 2,092.64 36.35 323.37 1,954.16 1,904.79 470.59 - 326.15 6,004,259.60 387,655.10 2.79 - 571.63 MWD +IFR -AK- CAZ -SC (2) 2,188.22 37.00 322.25 2,030.82 1,981.45 516.06 - 360.66 6,004,305.58 387,621.28 0.98 - 628.71 MWD +IFR -AK- CAZ -SC (2) 2,281.90 36.78 322.25 2,105.74 2,056.37 560.52 - 395.09 6,004,350.55 387,587.53 0.23 - 684.94 MWD +IFR -AK- CAZ -SC (2) 2,378.20 37.55 324.07 2,182.48 2,133.11 607.08 - 429.96 6,004,397.62 387,553.36 1.39 - 743.10 MWD +IFR -AK- CAZ -SC (2) 2,472.67 37.60 324.12 2,257.36 2,207.99 653.75 - 463.75 6,004,444.78 387,520.28 0.06 - 800.67 MWD +IFR -AK- CAZ -SC (2) 2,567.88 36.72 325.36 2,333.23 2,283.86 700.70 - 496.95 6,004,492.23 387,487.79 1.21 - 858.11 MWD +IFR -AK- CAZ -SC (2) 2,663.08 37.12 325.12 2,409.34 2,359.97 747.68 - 529.55 6,004,539.69 387,455.90 0.45 - 915.21 MWD +IFR -AK- CAZ -SC (2) 2,687.07 37.27 325.13 2,428.45 2,379.08 759.58 - 537.85 6,004,551.71 387,447.79 0.63 - 929.69 MWD +IFR -AK- CAZ -SC (2) 2,778.33 36.87 324.42 2,501.27 2,451.90 804.52 - 569.57 6,004,597.11 387,416.74 0.64 - 984.63 MWD +IFR -AK- CAZ -SC (3) 2,874.32 36.98 324.46 2,578.01 2,528.64 851.43 - 603.11 6,004,644.52 387,383.91 0.12 - 1,042.25 MWD +IFR -AK- CAZ -SC (3) 2,967.77 38.11 322.16 2,652.10 2,602.73 897.08 - 637.14 6,004,690.67 387,350.57 1.93 - 1,099.17 MWD +IFR -AK- CAZ -SC (3) 3,062.98 37.21 322.07 2,727.48 2,678.11 942.99 - 672.86 6,004,737.11 387,315.55 0.95 - 1,157.34 MWD +IFR -AK- CAZ -SC (3) 3,159.29 38.54 321.78 2,803.50 2,754.13 989.53 - 709.33 6,004,784.19 387,279.79 1.39 - 1,216.47 MWD +IFR -AK- CAZ -SC (3) 3,255.12 38.46 321.42 2,878.49 2,829.12 1,036.28 - 746.38 6,004,831.49 387,243.44 0.25 - 1,276.12 MWD +IFR -AK- CAZ -SC (3) 3,349.96 38.98 322.80 2,952.49 2,903.12 1,083.10 - 782.81 6,004,878.84 387,207.73 1.06 - 1,335.44 MWD +IFR -AK- CAZ -SC (3) 3,444.95 38.33 321.68 3,026.67 2,977.30 1,130.01 - 819.14 6,004,926.29 387,172.11 1.01 - 1,394.77 MWD +IFR -AK- CAZ -SC (3) 3,540.22 38.92 321.67 3,101.10 3,051.73 1,176.66 - 856.02 6,004,973.49 387,135.94 0.62 - 1,454.24 MWD +IFR -AK- CAZ -SC (3) 3,634.50 38.67 324.18 3,174.59 3,125.22 1,223.78 - 891.62 6,005,021.13 387,101.04 1.69 - 1,513.29 MWD +IFR -AK- CAZ -SC (3) 3,729.19 38.25 323.73 3,248.73 3,199.36 1,271.40 - 926.28 6,005,069.26 387,067.11 0.53 - 1,572.15 MWD +IFR -AK- CAZ -SC (3) 3,825.94 37.67 321.79 3,325.02 3,275.65 1,318.78 - 962.28 6,005,117.17 387,031.83 1.37 - 1,631.65 MWD +IFR -AK- CAZ -SC (3) 3,917.73 37.25 323.07 3,397.88 3,348.51 1,363.02 - 996.32 6,005,161.91 386,998.46 0.96 - 1,687.48 MWD +IFR -AK- CAZ -SC (3) 4,015.15 36.94 324.28 3,475.59 3,426.22 1,410.36 - 1,031.13 6,005,209.76 386,964.37 0.81 - 1,746.21 MWD +IFR -AK- CAZ -SC (3) 4,106.64 37.65 324.57 3,548.37 3,499.00 1,455.45 - 1,063.38 6,005,255.33 386,932.80 0.80 - 1,801.59 MWD +IFR -AK- CAZ -SC (3) 4,203.86 39.45 325.20 3,624.40 3,575.03 1,505.01 - 1,098.22 6,005,305.40 386,898.71 1.89 - 1,862.10 MWD +IFR -AK- CAZ -SC (3) 4,298.94 38.76 322.99 3,698.18 3,648.81 1,553.58 - 1,133.38 6,005,354.49 386,864.29 1.64 - 1,922.02 MWD +IFR -AK- CAZ -SC (3) 4,394.19 38.18 322.81 3,772.76 3,723.39 1,600.85 - 1,169.12 6,005,402.28 386,829.26 0.62 - 1,981.27 MWD +IFR -AK- CAZ -SC (3) 4,484.82 38.76 325.48 3,843.72 3,794.35 1,646.54 - 1,202.13 6,005,448.46 386,796.94 1.94 - 2,037.60 MWD +IFR -AK- CAZ -SC (3) 4/2/2010 10:05:34AM Page 3 COMPASS 2003.16 Build 69 S ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -121 Project Western North Slope TVD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft (Doyon 19) Well: CD3 - 121 North Reference: True Wellbore: CD3 - 121 Survey Calculation Method: Minimum Curvature Design: CD3 - 121 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azl TVD TVDSS +NJ-S +E/ -W Northing Easting DLS Section (ft) ( °) ( (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 4,583.63 38.70 324.49 3,920.80 3,871.43 1,697.17 - 1,237.61 6,005,499.61 386,762.24 0.63 - 2,099.33 MWD +IFR -AK- CAZ -SC (3) 4,679.61 38.56 323.87 3,995.78 3,946.41 1,745.75 - 1,272.67 6,005,548.71 386,727.91 0.43 - 2,159.21 MWD +IFR -AK- CAZ -SC (3) 4,774.50 38.52 324.19 4,070.00 4,020.63 1,793.60 - 1,307.40 6,005,597.08 386,693.90 0.21 - 2,218.29 MWD +IFR -AK- CAZ -SC (3) 4,868.23 37.94 323.26 4,143.63 4,094.26 1,840.36 - 1,341.71 6,005,644.34 386,660.30 0.87 - 2,276.27 MWD +IFR -AK- CAZ -SC (3) 4,964.38 37.45 323.90 4,219.71 4,170.34 1,887.67 - 1,376.62 6,005,692.16 386,626.11 0.65 - 2,335.04 MWD +IFR -AK- CAZ -SC (3) 5,056.22 37.75 323.44 4,292.47 4,243.10 1,932.81 - 1,409.82 6,005,737.80 386,593.60 0.45 - 2,391.05 MWD +IFR -AK- CAZ -SC (3) 5,153.96 38.19 324.25 4,369.53 4,320.16 1,981.37 - 1,445.29 6,005,786.87 386,558.86 0.68 - 2,451.15 MWD +IFR -AK- CAZ -SC (3) 5,249.16 37.58 322.68 4,444.66 4,395.29 2,028.34 - 1,480.09 6,005,834.36 386,524.77 1.20 - 2,509.59 MWD +IFR -AK- CAZ -SC (3) 5,343.30 37.24 322.23 4,519.44 4,470.07 2,073.69 - 1,514.94 6,005,880.22 386,490.61 0.46 - 2,566.77 MWD +IFR -AK- CAZ -SC (3) 5,439.65 37.20 324.13 4,596.17 4,546.80 2,120.33 - 1,549.86 6,005,927.38 386,456.39 1.19 - 2,625.04 MWD +IFR -AK- CAZ -SC (3) 5,534.61 36.82 322.82 4,672.00 4,622.63 2,166.27 - 1,583.88 6,005,973.82 386,423.07 0.92 - 2,682.18 MWD +IFR -AK- CAZ -SC (3) 5,629.20 36.75 321.95 4,747.75 4,698.38 2,211.14 - 1,618.45 6,006,019.19 386,389.18 0.56 - 2,738.81 MWD +IFR -AK- CAZ -SC (3) 5,677.78 36.34 322.14 4,786.78 4,737.41 2,233.94 - 1,636.24 6,006,042.26 386,371.74 0.88 - 2,767.74 MWD +IFR -AK- CAZ -SC (3) 5,725.84 35.68 320.57 4,825.66 4,776.29 2,256.01 - 1,653.88 6,006,064.59 386,354.43 2.36 - 2,795.99 MWD +IFR -AK- CAZ -SC (3) 5,772.45 34.81 318.64 4,863.73 4,814.36 2,276.50 - 1,671.31 6,006,085.34 386,337.31 3.03 - 2,822.86 MWD +IFR -AK- CAZ -SC (3) 5,820.98 33.85 316.12 4,903.80 4,854.43 2,296.64 - 1,689.83 6,006,105.75 386,319.10 3.53 - 2,850.14 MWD +IFR -AK- CAZ -SC (3) 5,872.83 32.50 313.67 4,947.20 4,897.83 2,316.67 - 1,709.92 6,006,126.08 386,299.31 3.67 - 2,878.29 MWD +IFR -AK- CAZ -SC (3) 5,916.06 31.92 311.42 4,983.78 4,934.41 2,332.25 - 1,726.89 6,006,141.91 386,282.58 3.08 - 2,901.02 MWD +IFR -AK- CAZ -SC (3) 5,960.70 30.42 309.61 5,021.98 4,972.61 2,347.26 - 1,744.45 6,006,157.18 386,265.25 3.96 - 2,923.66 MWD +IFR -AK- CAZ -SC (3) 6,010.89 28.68 307.38 5,065.64 5,016.27 2,362.68 - 1,763.81 6,006,172.89 386,246.13 4.10 - 2,947.72 MWD +IFR -AK- CAZ -SC (3) 6,057.70 28.29 304.28 5,106.78 5,057.41 2,375.75 - 1,781.90 6,006,186.22 386,228.23 3.27 - 2,969.16 MWD +IFR -AK- CAZ -SC (3) 6,106.28 28.26 301.55 5,149.57 5,100.20 2,388.25 - 1,801.21 6,006,199.01 386,209.11 2.66 - 2,990.90 MWD +IFR -AK- CAZ -SC (3) 6,151.90 27.94 297.08 5,189.82 5,140.45 2,398.77 - 1,819.93 6,006,209.81 386,190.55 4.67 - 3,010.72 MWD +IFR -AK- CAZ -SC (3) 6,198.47 27.35 293.96 5,231.07 5,181.70 2,408.08 - 1,839.43 6,006,219.41 386,171.20 3.36 - 3,030.05 MWD +IFR -AK- CAZ -SC (3) 6,242.77 27.59 291.47 5,270.38 5,221.01 2,415.96 - 1,858.27 6,006,227.58 386,152.48 2.65 - 3,047.87 MWD +IFR -AK- CAZ -SC (3) 6,296.51 26.99 287.66 5,318.14 5,268.77 2,424.22 - 1,881.47 6,006,236.18 386,129.40 3.44 - 3,068.66 MWD +IFR -AK- CAZ -SC (3) 6,343.22 26.50 283.71 5,359.86 5,310.49 2,429.91 - 1,901.70 6,006,242.17 386,109.27 3.95 - 3,085.60 MWD +IFR -AK- CAZ -SC (3) 6,386.69 26.30 280.79 5,398.79 5,349.42 2,434.01 - 1,920.58 6,006,246.55 386,090.45 3.02 - 3,100.45 MWD +IFR -AK- CAZ -SC (3) 6,437.46 26.04 276.77 5,444.36 5,394.99 2,437.43 - 1,942.70 6,006,250.30 386,068.39 3.53 - 3,116.76 MWD +IFR -AK- CAZ -SC (3) 6,486.45 26.67 273.23 5,488.26 5,438.89 2,439.31 - 1,964.36 6,006,252.52 386,046.76 3.46 - 3,131.58 MWD +IFR -AK- CAZ -SC (3) 6,531.84 27.17 268.65 5,528.74 5,479.37 2,439.64 - 1,984.89 6,006,253.15 386,026.24 4.70 - 3,144.49 MWD +IFR -AK- CAZ -SC (3) 6,581.64 28.07 264.14 5,572.87 5,523.50 2,438.18 - 2,007.92 6,006,252.04 386,003.20 4.57 - 3,157.51 MWD +IFR -AK- CAZ -SC (3) 6,628.75 28.96 261.27 5,614.27 5,564.90 2,435.32 - 2,030.22 6,006,249.51 385,980.86 3.47 - 3,168.98 MWD +IFR -AK- CAZ -SC (3) 6,676.73 29.15 258.21 5,656.21 5,606.84 2,431.17 - 2,053.14 6,006,245.70 385,957.88 3.12 - 3,179.82 MWD +IFR -AK- CAZ -SC (3) 6,724.89 28.77 254.82 5,698.35 5,648.98 2,425.73 - 2,075.81 6,006,240.61 385,935.13 3.50 - 3,189.50 MWD +IFR -AK- CAZ -SC (3) 6,773.02 29.39 250.12 5,740.42 5,691.05 2,418.68 - 2,098.09 6,006,233.90 385,912.74 4.92 - 3,197.66 MWD +IFR -AK- CAZ -SC (3) 6,819.90 30.28 246.12 5,781.09 5,731.72 2,409.99 - 2,119.72 6,006,225.53 385,890.99 4.65 - 3,204.13 MWD +IFR -AK- CAZ -SC (3) 6,863.65 31.32 242.33 5,818.67 5,769.30 2,400.24 - 2,139.88 6,006,216.08 385,870.69 5.03 - 3,208.86 MWD +IFR -AK- CAZ -SC (3) 6,915.64 32.29 238.01 5,862.86 5,813.49 2,386.61 - 2,163.63 6,006,202.81 385,846.74 4.76 - 3,212.73 MWD +IFR -AK- CAZ -SC (3) 6,956.37 32.81 235.56 5,897.19 5,847.82 2,374.60 - 2,181.96 6,006,191.08 385,828.24 3.48 - 3,214.56 MWD +IFR -AK- CAZ -SC (3) 4/2/2010 10:05:34AM Page 4 COMPASS 2003.16 Build 69 • i ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -121 Project Western North Slope TVD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft (Doyon 19) Well: CD3 - 121 North Reference: True Wellbore: CD3 - 121 Survey Calculation Method: Minimum Curvature Design: CD3 - 121 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +Ni-S +El -W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) ( °!100') (ft) Survey Tool Name 7,009.77 32.92 232.47 5,942.05 5,892.68 2,357.58 - 2,205.40 6,006,174.41 385,804.54 3.15 - 3,215.58 MWD +IFR -AK- CAZ -SC (3) 7,058.59 33.22 228.75 5,982.97 5,933.60 2,340.68 - 2,225.98 6,006,157.83 385,783.72 4.20 - 3,214.93 MWD +IFR -AK- CAZ -SC (3) 7,104.83 34.31 225.61 6,021.41 5,972.04 2,323.21 - 2,244.81 6,006,140.64 385,764.62 4.45 - 3,212.76 MWD +IFR -AK- CAZ -SC (3) 7,153.37 35.02 224.11 6,061.33 6,011.96 2,303.64 - 2,264.28 6,006,121.37 385,744.86 2.29 - 3,209.32 MWD +IFR -AK- CAZ -SC (3) 7,199.75 36.33 221.20 6,099.01 6,049.64 2,283.74 -2,282.60 6,006,101.75 385 726.25 4.62 -3,204.92 MWD +IFR -AK- CAZ -SC (3) 7,246.31 38.62 218.86 6,135.96 6,086.59 2,262.05 - 2,300.80 6,006,080.33 385,707.73 5.79 - 3,199.03 MWD +IFR -AK- CAZ -SC (3) 7,294.80 40.87 216.90 6,173.25 6,123.88 2,237.57 - 2,319.83 6,006,056.15 385,688.34 5.31 - 3,191.46 MWD +IFR -AK- CAZ -SC (3) 7,343.10 43.49 215.98 6,209.03 6,159.66 2,211.48 - 2,339.08 6,006,030.35 385,668.69 5.57 - 3,182.75 MWD +IFR -AK- CAZ -SC (3) 7,390.57 45.41 214.80 6,242.92 6,193.55 2,184.38 - 2,358.33 6,006,003.54 385,649.05 4.40 - 3,173.25 MWD +IFR -AK- CAZ -SC (3) 7,438.66 46.64 212.15 6,276.31 6,226.94 2,155.51 - 2,377.41 6,005,974.97 385,629.54 4.72 - 3,162.25 MWD +IFR -AK- CAZ -SC (3) 7,485.13 47.42 209.22 6,307.99 6,258.62 2,126.28 - 2,394.75 6,005,946.00 385,611.76 4.91 - 3,149.88 MWD +IFR -AK- CAZ -SC (3) 7,533.33 48.46 206.15 6,340.29 6,290.92 2,094.59 - 2,411.37 6,005,914.57 385,594.67 5.20 - 3,135.14 MWD +IFR -AK- CAZ -SC (3) 7,582.96 50.01 202.88 6,372.70 6,323.33 2,060.39 - 2,426.95 6,005,880.61 385,578.58 5.89 - 3,117.79 MWD +IFR -AK- CAZ -SC (3) 7,627.11 50.24 199.85 6,401.00 6,351.63 2,028.85 - 2,439.29 6,005,849.26 385,565.77 5.29 - 3,100.53 MWD +IFR -AK- CAZ -SC (3) 7,676.77 50.53 196.52 6,432.67 6,383.30 1,992.51 - 2,451.22 6,005,813.11 385,553.29 5.20 - 3,079.24 MWD +IFR -AK- CAZ -SC (3) 7,720.95 50.82 194.91 6,460.67 6,411.30 1,959.61 - 2,460.47 6,005,780.36 385,543.55 2.89 - 3,059.02 MWD +IFR -AK- CAZ -SC (3) 7,770.51 51.54 192.49 6,491.74 6,442.37 1,922.10 - 2,469.61 6,005,742.99 385,533.85 4.07 - 3,035.08 MWD +IFR -AK- CAZ -SC (3) 7,818.57 53.13 189.97 6,521.11 6,471.74 1,884.79 - 2,477.01 6,005,705.80 385,525.89 5.31 - 3,010.24 MWD +IFR -AK- CAZ -SC (3) 7,864.64 54.10 188.15 6,548.44 6,499.07 1,848.17 - 2,482.85 6,005,669.27 385,519.50 3.81 - 2,984.97 MWD +IFR -AK- CAZ -SC (3) 7,914.01 56.39 186.31 6,576.59 6,527.22 1,807.93 - 2,487.94 6,005,629.12 385,513.81 5.56 - 2,956.40 MWD +IFR -AK- CAZ -SC (3) 7,961.37 58.15 184.96 6,602.19 6,552.82 1,768.29 - 2,491.85 6,005,589.54 385,509.31 4.42 - 2,927.57 MWD +IFR -AK- CAZ -SC (3) 8,005.67 59.57 183.00 6,625.10 6,575.73 1,730.47 - 2,494.48 6,005,551.76 385,506.11 4.96 - 2,899.38 MWD +IFR -AK- CAZ -SC (3) 8,055.78 60.10 180.23 6,650.29 6,600.92 1,687.17 - 2,495.70 6,005,508.49 385,504.24 4.89 - 2,866.01 MWD +IFR -AK- CAZ -SC (3) 8,103.62 60.85 177.09 6,673.87 6,624.50 1,645.56 - 2,494.72 6,005,466.88 385,504.60 5.92 - 2,832.62 MWD +IFR -AK- CAZ -SC (3) 8,151.98 61.87 175.11 6,697.05 6,647.68 1,603.22 - 2,491.83 6,005,424.50 385,506.85 4.17 - 2,797.47 MWD +IFR -AK- CAZ -SC (3) 8,197.69 62.75 172.17 6,718.29 6,668.92 1,563.00 - 2,487.34 6,005,384.22 385,510.73 6.01 - 2,763.02 MWD +IFR -AK- CAZ -SC (3) 8,245.58 63.71 169.74 6,739.86 6,690.49 1,520.78 - 2,480.62 6,005,341.91 385,516.82 4.95 - 2,725.61 MWD +IFR -AK- CAZ -SC (3) 8,294.07 65.08 167.51 6,760.82 6,711.45 1,477.91 - 2,471.99 6,005,298.92 385,524.81 5.02 - 2,686.52 MWD +IFR -AK- CAZ -SC (3) 8,341.72 65.58 165.88 6,780.71 6,731.34 1,435.78 - 2,462.02 6,005,256.65 385,534.14 3.28 - 2,647.18 MWD +IFR -AK- CAZ -SC (3) 8,386.36 66.02 164.32 6,799.01 6,749.64 1,396.43 - 2,451.55 6,005,217.15 385,544.02 3.34 - 2,609.73 MWD +IFR -AK- CAZ -SC (3) 8,436.87 66.64 162.48 6,819.29 6,769.92 1,352.10 - 2,438.34 6,005,172.63 385,556.57 3.55 - 2,566.66 MWD +IFR -AK- CAZ -SC (3) 8,484.23 67.53 161.10 6,837.73 6,788.36 1,310.67 - 2,424.70 6,005,131.00 385,569.57 3.28 - 2,525.62 MWD +IFR -AK- CAZ -SC (3) 8,528.60 68.92 159.12 6,854.19 6,804.82 1,271.93 - 2,410.68 6,005,092.06 385,583.01 5.19 - 2,486.46 MWD +IFR -AK- CAZ -SC (3) 8,577.53 70.64 157.80 6,871.10 6,821.73 1,229.22 - 2,393.82 6,005,049.11 385,599.23 4.33 - 2,442.42 MWD +IFR -AK- CAZ -SC (3) 8,625.59 71.81 155.02 6,886.57 6,837.20 1,187.53 - 2,375.61 6,005,007.15 385,616.81 5.99 - 2,398.36 MWD +IFR -AK- CAZ -SC (3) 8,672.25 73.01 153.65 6,900.68 6,851.31 1,147.44 - 2,356.35 6,004,966.78 385,635.47 3.80 - 2,354.91 MWD +IFR -AK- CAZ -SC (3) 8,720.75 74.75 152.24 6,914.14 6,864.77 1,105.95 - 2,335.15 6,004,924.98 385,656.03 4.55 - 2,309.17 MWD +IFR -AK- CAZ -SC (3) 8,765.39 77.16 151.30 6,924.97 6,875.60 1,067.80 - 2,314.67 6,004,886.53 385,675.94 5.77 - 2,266.49 MWD +IFR -AK- CAZ -SC (3) 8,810.11 79.43 151.15 6,934.05 6,884.68 1,029.42 - 2,293.59 6,004,847.84 385,696.44 5.09 - 2,223.27 MWD +IFR -AK- CAZ -SC (3) 8,846.60 80.73 149.77 6,940.33 6,890.96 998.15 - 2,275.87 6,004,816.31 385,713.69 5.15 - 2,187.72 MWD +IFR -AK- CAZ -SC (3) 4/2/2010 10:05:34AM Page 5 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -121 Project Western North Slope TVD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft (Doyon 19) Well: CD3 - 121 North Reference: True Wellbore: CD3 - 121 Survey Calculation Method: Minimum Curvature Design: CD3 - 121 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az! TVD TVDSS +NI-S +E/ -W Northing Easting DLS Section (ft) (°) (°) (ft) on on (ft) (ft) (ft) (1100') (ft) Survey Tool Name 8,931.96 85.05 147.92 6,950.90 6,901.53 925.69 - 2,232.06 6,004,743.21 385,756.41 5.50 - 2,103.64 MWD +IFR -AK- CAZ -SC (4) 9,027.32 88.14 147.41 6,956.56 6,907.19 845.27 - 2,181.15 6,004,662.04 385,806.10 3.28 - 2,008.93 MWD +IFR -AK- CAZ -SC (4) 9,122.19 89.01 144.37 6,958.92 6,909.55 766.75 - 2,127.97 6,004,582.74 385,858.09 3.33 - 1,914.32 MWD +IFR -AK- CAZ -SC (4) 9,215.41 88.95 141.74 6,960.58 6,911.21 692.27 - 2,071.95 6,004,507.43 385,912.98 2.82 - 1,821.14 MWD +IFR -AK- CAZ -SC (4) 9,313.22 88.20 138.14 6,963.01 6,913.64 617.44 - 2,009.03 6,004,431.68 385,974.76 3.76 - 1,723.44 MWD +IFR -AK- CAZ -SC (4) 9,361.94 88.76 137.17 6,964.30 6,914.93 581.45 - 1,976.23 6,004,395.20 386,007.02 2.30 - 1,674.87 MWD +IFR -AK- CAZ -SC (4) 9,409.24 88.88 135.76 6,965.28 6,915.91 547.16 - 1,943.66 6,004,360.43 386,039.07 2.99 - 1,627.80 MWD +IFR -AK- CAZ -SC (4) 9,455.73 89.87 136.23 6,965.79 6,916.42 513.73 - 1,911.36 6,004,326.52 386,070.86 2.36 - 1,581.57 MWD +IFR -AK- CAZ -SC (4) 9,504.73 90.80 136.78 6,965.50 6,916.13 478.18 - 1,877.63 6,004,290.47 386,104.04 2.21 - 1,532.80 MWD +IFR -AK- CAZ -SC (4) 9,592.36 90.92 137.59 6,964.18 6,914.81 413.91 - 1,818.09 6,004,225.32 386,162.61 0.93 - 1,445.49 MWD +IFR -AK- CAZ -SC (4) 9,694.36 91.11 139.02 6,962.38 6,913.01 337.76 - 1,750.25 6,004,148.17 386,229.29 1.41 - 1,343.72 MWD +IFR -AK- CAZ -SC (4) 9,786.55 91.22 140.52 6,960.50 6,911.13 267.39 - 1,690.72 6,004,076.92 386,287.75 1.63 - 1,251.62 MWD +IFR -AK- CAZ -SC (4) 9,884.74 89.75 144.12 6,959.67 6,910.30 189.70 - 1,630.72 6,003,998.34 386,346.58 3.96 - 1,153.46 MWD +IFR -AK- CAZ -SC (4) 9,978.72 89.93 144.77 6,959.93 6,910.56 113.24 - 1,576.07 6,003,921.08 386,400.07 0.72 - 1,059.56 MWD +IFR -AK- CAZ -SC (4) 10,075.07 91.04 144.61 6,959.12 6,909.75 34.62 - 1,520.38 6,003,841.64 386,454.57 1.16 - 963.32 MWD +IFR -AK- CAZ -SC (4) 10,169.04 86.61 143.87 6,961.04 6,911.67 -41.60 - 1,465.50 6,003,764.61 386,508.30 4.78 - 869.47 MWD +IFR -AK- CAZ -SC (4) 10,265.98 87.71 143.53 6,965.85 6,916.48 - 119.63 - 1,408.18 6,003,685.74 386,564.44 1.19 - 772.69 MWD +IFR -AK- CAZ -SC (4) 10,361.37 88.02 144.19 6,969.40 6,920.03 - 196.61 - 1,351.96 6,003,607.93 386,619.49 0.76 - 677.42 MWD +IFR -AK- CAZ -SC (4) 10,457.06 87.71 144.89 6,972.97 6,923.60 - 274.49 - 1,296.48 6,003,529.22 386,673.78 0.80 - 581.89 MWD +IFR -AK- CAZ -SC (4) 10,552.49 87.40 144.52 6,977.04 6,927.67 - 352.31 - 1,241.40 6,003,450.60 386,727.69 0.51 - 486.65 MWD +IFR -AK- CAZ -SC (4) 10,647.47 89.00 144.39 6,980.02 6,930.65 - 429.55 - 1,186.21 6,003,372.54 386,781.71 1.69 - 391.81 MWD +IFR -AK- CAZ -SC (4) 10,738.80 87.96 142.33 6,982.44 6,933.07 - 502.81 - 1,131.73 6,003,298.49 386,835.08 2.53 - 300.55 MWD +IFR -AK- CAZ -SC (4) 10,837.72 89.25 143.19 6,984.85 6,935.48 - 581.53 - 1,071.89 6,003,218.88 386,893.73 1.57 - 201.67 MWD +IFR -AK- CAZ -SC (4) 10,924.70 87.77 142.24 6,987.11 6,937.74 - 650.71 - 1,019.22 6,003,148.92 386,945.35 2.02 - 114.73 MWD +IFR -AK- CAZ -SC (4) 11,028.96 87.65 140.95 6,991.28 6,941.91 - 732.34 - 954.50 6,003,066.33 387,008.83 1.24 -10.55 MWD +IFR -AK- CAZ -SC (4) 11,119.06 88.20 140.18 6,994.54 6,945.17 - 801.89 - 897.31 6,002,995.95 387,064.97 1.05 79.46 MWD +IFR -AK- CAZ -SC (4) 11,215.68 90.18 141.27 6,995.91 6,946.54 - 876.67 - 836.15 6,002,920.26 387,124.99 2.34 176.04 MWD +IFR -AK- CAZ -SC (4) 11,313.87 89.25 141.29 6,996.40 6,947.03 - 953.28 - 774.74 6,002,842.75 387,185.24 0.95 274.22 MWD +IFR -AK- CAZ -SC (4) 11,410.58 89.99 140.23 6,997.04 6,947.67 - 1,028.18 - 713.56 6,002,766.95 387,245.28 1.34 370.90 MWD +IFR -AK- CAZ -SC (4) 11,504.97 89.07 142.48 6,997.81 6,948.44 - 1,101.89 - 654.62 6,002,692.36 387,303.10 2.58 465.27 MWD +IFR -AK- CAZ -SC (4) 11,601.11 88.33 143.18 6,999.99 6,950.62 - 1,178.48 - 596.55 6,002,614.92 387,360.01 1.06 561.38 MWD +IFR -AK- CAZ -SC (4) 11,696.86 88.58 143.55 7,002.57 6,953.20 - 1,255.28 - 539.44 6,002,537.27 387,415.96 0.47 657.07 MWD +IFR -AK- CAZ -SC (4) 11,792.27 88.51 145.13 7,005.00 6,955.63 - 1,332.78 - 483.84 6,002,458.96 387,470.39 1.66 752.36 MWD +IFR -AK- CAZ -SC (4) 11,885.62 88.08 143.53 7,007.78 6,958.41 - 1,408.58 - 429.43 6,002,382.36 387,523.65 1.77 845.59 MWD +IFR -AK- CAZ -SC (4) 11,982.99 88.82 144.09 7,010.41 6,961.04 - 1,487.13 - 371.96 6,002,302.96 387,579.93 0.95 942.88 MWD +IFR -AK- CAZ -SC (4) 12,078.51 87.96 142.82 7,013.09 6,963.72 - 1,563.84 - 315.10 6,002,225.41 387,635.62 1.61 1,038.32 MWD +IFR -AK- CAZ -SC (4) 12,173.75 87.77 140.10 7,016.64 6,967.27 - 1,638.27 - 255.81 6,002,150.10 387,693.79 2.86 1,133.49 MWD +IFR -AK- CAZ -SC (4) 12,268.75 88.88 141.23 7,019.42 6,970.05 - 1,711.72 - 195.62 6,002,075.77 387,752.86 1.67 1,228.42 MWD +IFR -AK- CAZ -SC (4) 12,363.17 88.82 141.74 7,021.31 6,971.94 - 1,785.58 - 136.84 6,002,001.04 387,810.53 0.54 1,322.81 MWD +IFR -AK- CAZ -SC (4) 12,458.30 87.65 141.56 7,024.24 6,974.87 - 1,860.15 -77.84 6,001,925.60 387,868.39 1.24 1,417.89 MWD +IFR -AK- CAZ -SC (4) 4/2/2010 10:05:34AM Page 6 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -121 Project Western North Slope TVD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -121 (36.87 +12.5) @ 49.37ft (Doyon 19) Well: CD3 - 121 North Reference: True Welibore: CD3 - 121 Survey Calculation Method: Minimum Curvature Design: CD3 - 121 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +V -W Northing Easting DLS Section (ft) ( °) ( °) (n) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,552.87 88.51 141.46 7,027.41 6,978.04 - 1,934.13 -19.02 6,001,850.75 387,926.09 0.92 1,512.41 MWD +IFR -AK- CAZ -SC (4) 12,648.40 88.14 143.45 7,030.20 6,980.83 - 2,009.84 39.17 6,001,774.19 387,983.13 2.12 1,607.89 MWD +IFR -AK- CAZ -SC (4) 12,743.93 90.05 144.29 7,031.71 6,982.34 - 2,086.98 95.49 6,001,696.21 388,038.28 2.18 1,703.35 MWD +IFR -AK- CAZ -SC (4) 12,839.37 89.75 142.19 7,031.88 6,982.51 - 2,163.44 152.60 6,001,618.91 388,094.24 2.22 1,798.76 MWD +IFR -AK- CAZ -SC (4) 12,932.53 90.30 141.76 7,031.84 6,982.47 - 2,236.82 209.99 6,001,544.68 388,150.51 0.75 1,891.92 MWD +IFR -AK- CAZ -SC (4) 13,029.13 90.12 142.18 7,031.49 6,982.12 - 2,312.91 269.50 6,001,467.71 388,208.87 0.47 1,988.52 MWD +IFR -AK- CAZ -SC (4) 13,124.40 90.49 142.48 7,030.98 6,981.61 - 2,388.32 327.72 6,001,391.45 388,265.95 0.50 2,083.79 MWD +IFR -AK- CAZ -SC (4) 13,213.30 91.04 142.26 7,029.79 6,980.42 - 2,458.72 381.99 6,001,320.25 388,319.15 0.67 2,172.68 MWD +IFR -AK- CAZ -SC (4) 13,314.41 90.12 141.10 7,028.77 6,979.40 - 2,538.04 444.68 6,001,240.00 388,380.64 1.46 2,273.78 MWD +IFR -AK- CAZ -SC (4) 13,407.66 88.45 140.30 7,029.93 6,980.56 - 2,610.19 503.74 6,001,166.98 388,438.60 1.99 2,366.99 MWD +IFR -AK- CAZ -SC (4) 13,505.69 87.53 140.13 7,033.37 6,984.00 - 2,685.48 566.43 6,001,090.77 388,500.15 0.95 2,464.91 MWD +IFR -AK- CAZ -SC (4) 13,600.74 87.77 140.69 7,037.27 6,987.90 - 2,758.66 626.95 6,001,016.69 388,559.56 0.64 2,559.85 MWD +IFR -AK- CAZ -SC (4) 13,696.56 88.45 142.67 7,040.43 6,991.06 - 2,833.79 686.33 6,000,940.68 388,617.80 2.18 2,655.61 MWD +IFR -AK- CAZ -SC (4) 13,792.00 88.33 142.46 7,043.11 6,993.74 - 2,909.55 744.32 6,000,864.07 388,674.64 0.25 2,751.00 MWD +IFR -AK- CAZ -SC (4) 13,887.39 89.31 144.40 7,045.07 6,995.70 - 2,986.14 801.14 6,000,786.64 388,730.30 2.28 2,846.34 MWD +IFR -AK- CAZ -SC (4) 13,971.42 87.95 144.37 7,047.08 6,997.71 - 3,054.43 850.06 6,000,717.63 388,778.18 1.62 2,930.27 MWD +IFR -AK- CAZ -SC (4) 14,078.25 89.13 144.55 7,049.80 7,000.43 - 3,141.33 912.13 6,000,629.82 388,838.94 1.12 3,036.97 MWD +IFR -AK- CAZ -SC (4) 14,167.48 90.55 146.05 7,050.05 7,000.68 - 3,214.68 962.93 6,000,555.71 388,888.63 2.31 3,126.04 MWD +IFR -AK- CAZ -SC (4) 14,269.34 89.99 144.59 7,049.57 7,000.20 - 3,298.44 1,020.88 6,000,471.10 388,945.31 1.54 3,227.73 MWD +IFR -AK- CAZ -SC (4) 14,364.60 90.30 143.56 7,049.33 6,999.96 - 3,375.58 1,076.77 6,000,393.14 389,000.04 1.13 3,322.92 MWD +IFR -AK- CAZ -SC (4) 14,459.56 90.12 142.95 7,048.98 6,999.61 - 3,451.67 1,133.58 6,000,316.21 389,055.69 0.67 3,417.86 MWD +IFR -AK- CAZ -SC (4) 14,555.21 91.54 142.07 7,047.60 6,998.23 - 3,527.56 1,191.79 6,000,239.47 389,112.75 1.75 3,513.49 MWD +IFR -AK- CAZ -SC (4) 14,651.34 92.34 141.03 7,044.34 6,994.97 - 3,602.80 1,251.53 6,000,163.35 389,171.35 1.36 3,609.56 MWD +IFR -AK- CAZ -SC (4) 14,746.51 93.70 140.91 7,039.33 6,989.96 - 3,676.62 1,311.38 6,000,088.64 389,230.07 1.43 3,704.58 MWD +IFR -AK- CAZ -SC (4) 14,842.13 94.07 140.39 7,032.85 6,983.48 - 3,750.39 1,371.86 6,000,013.97 389,289.44 0.67 3,799.96 MWD +IFR -AK- CAZ -SC (4) 14,937.57 94.37 141.46 7,025.83 6,976.46 - 3,824.28 1,431.86 5,999,939.20 389,348.32 1.16 3,895.12 MWD +IFR -AK- CAZ -SC (4) 15,015.08 94.87 141.46 7,019.59 6,970.22 - 3,884.71 1,480.00 5,999,878.06 389,395.54 0.65 3,972.37 MWD +IFR -AK- CAZ -SC (4) 15,081.00 94.87 141.46 7,013.99 6,964.62 - 3,936.09 1,520.92 5,999,826.08 389,435.68 0.00 4,038.05 PROJECTED to TD 4/2/2010 10:05:34AM Page 7 COMPASS 2003.16 Build 69 • ,,,.,- Time Log & Summary ConocoPhillips 9 Wellview Web Reporting Report Well Name: CD3 - 121 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 3/10/2010 4:00:00 AM Rig Release: 4/1/2010 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/09/2010 24 hr Summary Move rig f/ CD3 -124 to CD3 -121. Note: Rig acce t CD3 -121 @ 0400 hrs 3 -10 -2010. 21:00 00:00 3.00 114 114 MIRU MOVE MOB P Moving rig f/ CD3 -124 to CD3 -121. 03/10/2010 Spot and level rig over CD3 -121. Lower feet and cellar wind walls. Spot and level motor and pit complex. Then spot pipe shed. Hook up service lines (Air, water, steam). Pre job safety meeting on nipple up riser and connecting flow line. Nipple up riser and flow line. Bring spud mud into pits. Install Mouse Hole. Pre job safety meeting on Picking up/ Make up 5" drill pipe and stand back in the derrick. Stand back 23 stands of 5" drill pipe and 8 stands of 5" HWDP. Pre job safety meeting. Make up BHA to clean out ice plug in the conductor (52' to 55'). Lay down clean out BHA. Pre job safety meeting. Pick up/ Make up BHA #1. Pre spud safety meeting. Fill hole test mud lines to 3500 psi. Spud © 1400 hrs, drilling from 114' to 443', trouble shoot Sperry Sun MWD tools- reboot surface computers- all ok now, continue drilling f/ 443' to 715' w/ gyro surveys. Note: Rig electrician tested H2S and Methane alarms on rig. Note: Rig floor in drilling position @ 0200 hrs. Rig taking on water @ 0330 hrs. Rig accept CD3 -121 @ 0400 hrs 3 -10 -2010. On Hi line with one engine at 0400 hrs 3 -10 -2010. Note: MI /Swaco Ball mill spotted at 0430 hrs. Spud from 114' @ 1400 hrs. 00:00 01:15 1.25 MIRU MOVE MOB P Spot and level rig over CD3 -121. Lower feet and cellar wind walls. 01:15 02:45 1.50 MIRU DRILL MOB P Jacking rig floor to drilling position, in place @ 0200 hrs. Spot and level motor and pit complex. Then spot pipe shed. 02:45 04:00 1.25 MIRU DRILL RURD P Hook up service lines (Air, water, steam). Rig taking on water @ 0330 hrs. Rig on Hi- line with one engine @ 0400 hrs. Rig Accepted @ 0400 hrs. 04:00 04:15 0.25 MIRU DRILL SFTY P Pre job safety meeting on nipple up riser and connecting flow line. 04:15 05:30 1.25 MIRU WHDBO NUND P Nipple up riser and flow line. Bring spud mud into pits. Note: MI /Swaco Ball mill spotted at 0430 hrs. Note: Rig electrician tested H2S and Methane alarms on rig. 05:30 06:00 0.50 MIRU DRILL RURD P Install Mouse Hole. 06:00 06:15 0.25 MIRU DRILL SFTY P Pre job safety meeting on Picking up/ Make up 5" drill pipe and stand back in the derrick. 06:15 09:30 3.25 MIRU DRILL PULD P Pickup/ Make up/ Stand back in the derrick 23 stands of 5" drill pipe and 8 stands of 5" HWDP 09:30 09:45 0.25 MIRU DRILL SFTY P Pre job safety meeting on Picking up/ Make up a BHA to clean out ice in the conductor. Page 1 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 11:00 1.25 52 101 SURFA( DRILL PULD P Make up a BHA to clean out ice in the conductor. Bitsub, crossover and bit on stand of 5" HWDP. Clean out ice plug from 52' to 55'. Break and lay down bit sub, crossover and break off bit. 11:00 11:15 0.25 0 0 SURFA( DRILL SFTY P Pre job safety meeting on Picking up/ Make up a BHA #1 to drill 12 -1/4" surface hole. 11:15 12:00 0.75 0 0 SURFA( DRILL PULD P Make uo a BHA #1 to drill 12 -1/4" surface hole. Pickup SperryDrill motor w/ 1.5 deg bend. Sperry Sun EM tool, make up Hughes MXL -1X bit. 12:00 12:45 0.75 0 0 SURFA( DRILL PULD P Continue picking up BHA #1. 12:45 13:00 0.25 0 0 SURFA( DRILL SFTY P Pre job safety meeting on spud. 13:00 13:30 0.50 0 0 SURFA( DRILL PULD P Finish picking up BHA #1. 13:30 13:45 0.25 114 114 SURFA( DRILL PRTS P Fill hole, check for leaks. Test mud lines to 3500 psi. OK. 13:45 14:00 0.25 114 114 SURFA( DRILL PULD P Make a connection. 14:00 18:15 4.25 114 443 SURFA( DRILL DRLG P Spud @ 1400 hrs. Drilling 12 -1/4" surface hole from 114' to 443' w/ Gyro surveys. Note: KOP 302' @ 1615 hrs 3/10/2010. Total hrs on the bit = 1.7 hrs. Actual drilling time= 1.7 hrs, of which 1.37 hrs rotating, .33 hrs sliding. 18:15 19:15 1.00 443 443 SURFA( DRILL OTHR T Trouble shoot Sperry Sun MWD, reboot surface computers, all ok now. 19:15 00:00 4.75 443 715 SURFA( DRILL DDRL P Continue drilling 12 -1/4" surface hole from 443' to 715' w/ Gyro surveys. Total hrs on the bit = 5.15 hrs. Actual drilling time 3.45 hrs, of which 2.65 hrs rotating, .8 hrs sliding. .03/11/2010 Continue directional drilling 12 -1/4" hole w/ 1.5 deg bend motor f/ 715' to 1200' w/ gyro surveys. Continue directional drilling 12 -1/4" hole w/ 1.5 deg bend motor f/ 1200' to 2733' w/ MWD surveys. Circulate bottom's up at TD f/ surface casing. 00:00 06:00 6.00 715 995 SURFA( DRILL DDRL P Continue drilling 12 -1/4" surface hole w/ 1.5 deg bend SperryDrill motor from 715' to 955' w/ Gyro surveys. Total hrs on the bit = 8.09 hrs. Actual drilling time= 2.94 hrs, of which .63 hrs rotating, 2.31 hrs sliding Page 2 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 995 1,376 SURFA( DRILL DDRL P Continue drilling 12 -1/4" surface hole w/ 1.5 deg bend Sperry Drill motor from 955' to 1376' w/ Gyro surveys. Total hrs on the bit = 10.53 hrs. Actual drilling time= 2.44 hrs, of which 1.18 hrs rotating, 1.26 hrs sliding Note: Last gyro survey @ 1200'. 12:00 18:00 6.00 1,376 2,272 SURFA( DRILL DDRL P Continue drilling 12 -1/4" surface hole w/ 1.5 deg bend SperryDrill motor from 1376' to 2272' w/ Gyro surveys. Total hrs on the bit = 14.52 hrs. Actual drilling time 3.99 hrs, of which 3.19 hrs rotating, .8 hrs sliding Note: Released Sperry Sun and GyroData for gyro surveys after 2100'. 18:00 23:45 5.75 2,272 2,733 SURFA( DRILL DDRL P Continue drilling 12 -1/4" surface hole w/ 1.5 deg bend SperryDrill motor from 2272' to 2733' w MWD surveys. Total hrs on the bit = 18.77 hrs. Actual drilling time= 4.25 hrs, of which 3.81 hrs rotating, .22 hrs sliding. Pumped a 40 bbl bit balling sweep while drilling at 2595' (7.5ppb nut plug, 20 gallons screenKleen). 23:45 00:00 0.25 2,733 2,733 SURFA( DRILL CIRC P Circulate bottom's up, pumping 600 gpm w/ 1600 psi. Reciprocate from 2733' to 2708'. Rotate 80 rpm w/ 8k ft/lbs of torque. PU wt 150k, SO wt 140k, Rot wt 148k. 03/12/2010 Circ BU at TD (2733'), backream to 812', trip in the hole to 2733', tag bottom- no fill, circ and condition hole for 9 -5/8" casing. POOH on the trip tank from 2733' to 905'. Observe well for flow @ HWDP (905')- static. Con't to pull out of the hole on the trip tank. PJSM on laying down BHA #1. Lay down BHA #1. Clean & clear rig floor. RU to run 9 -5/8" 40 ppf L -80 BTC -m surface casing. PJSM. Run 9 -5/8" 40 ppf L -80 BTC -m surface casing. Make up Ray Oil Tool Silver bullet w/ 36 ppf K -55 BTC jt (one centralizer 10' above shoe on stop and on collar of jt #1). All other joints are 40 ppf L -80 BTC -m casing. Make up jt #2 (Thread lock joint) (stop 10' below box w/ bow spring centralizer), make up Jt #3 w/ Halliburton Sure Seal II Float collar on bottom. Make up jt #4 (baker locked pin). Stab Frank's fillup tool and circulate w/ shoe above conductor shoe. Continue to run casing using Run -N- Seal dope. Centralizers are on box of first 13 joints then every other jt. Run in jt # 31 to 1170', lost 10k to 105k SO wt. Pick up to 1145', stab Frank's fillup tool. Estab circulation pumping 4 bpm w/ 200 psi- 28% Totco flow out. Increase pump rate to 5 bpm w/ 270 psi, wash in the hole from 1145' to jt # 40 in the hole -- 1515'. Worked through numerous areas from 1170' to 1515' which we saw a reduction in slack off wt, so washed casing string in the hole. Con't to run casing w/o pumping from 1515' to 1670' (jt # 41 thru jt # 44). Circulate 1.5 BU (150 bbls) while recip from 1670' to 1705' (Jt # 45 in the hole). Con't to run 9 -5/8" 40 ppf L -80 BTC -m surface casing f/ 1705' to 2680' (jt #71). Make up FMC hanger and landing joint. Run in hole and land on hanger w/ shoe @ 2723.25'. PU wt 175k, SO wt 140k. Rig down Frank's fill up tool. Blow down the top drive. RU Dowell cement head & lines. Circ and condition mud and hole for cement job. Reciprocate pipe f/ 2723' to 2688' (35'). Initial pump rate 5 bpm w/ 320 psi, 6 bpm w/ 380 psi, final 7 bpm w/ 420 psi. Circ a total of 857 bbls @ midnight. 00:00 00:15 0.25 2,733 2,733 SURFA( DRILL CIRC P Circulate bottom's up, pumping 600 gpm w/ 1600 psi. Reciprocate from 2733' to 2708'. Rotate 80 rpm w/ 8k ft/lbs of torque. PU wt 150k, SO wt 140k, Rot wt 148k. Page 3 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:15 05:15 5.00 2,733 812 SURFA( DRILL REAM P Backream out of the hole from 2733' to 1560', pumping 600 gpm w/ 1580 to 1800 psi, rotate 80 rpm w/ 6.5k ft lbs of torque. Continue to backream out of the hole from the base of the permafrost @ 1560' to 812', pumping 500 gpm w/ 1200 to1100 psi, rotate 80 rpm w/ 6.5 to 3.5k ft lbs of torque. 05:15 06:15 1.00 812 2,710 SURFA( DRILL TRIP P Trip in the hole f/ 812' to 2710'. Slack off weight 120k. Tight spots on trip in the hole @ 852', 1194', 1247', 1297' and 2277'. 06:15 06:30 0.25 2,710 2,733 SURFA( DRILL TRIP P Break circulation, tag bottom at 2733' w/ no fill. 06:30 07:30 1.00 2,733 2,733 SURFA( DRILL CIRC P Circulate and condition mud and hole f/ 9 -5/8" surface casing. Initial 500 gpm w/ 1150 psi, final 6650 gpm w/ 1850 psi. Rotate 60 rpm w/ 6k ft lbs of torque. 07:30 07:45 0.25 2,733 2,733 SURFA( DRILL OWFF P Observe well for flow- static. 07:45 09:15 1.50 2,733 905 SURFA( DRILL TRIP P Pull out of the hole on the trip tank from 2733' to 905'. At 905' : PU wt 115k, SO wt 110k. 09:15 09:30 0.25 905 905 SURFA( DRILL OWFF P Observe well for flow @ HWDP (905')- static. 09:30 10:15 0.75 905 168 SURFA( DRILL TRIP P Continue to pull out of the hole on the trip tank. 10:15 10:30 0.25 168 168 SURFA( DRILL SFTY P Pre job safety meeting on laying down BHA #1. 10:30 11:45 1.25 168 0 SURFA( DRILL PULD P Lay down BHA #1. 11:45 12:30 0.75 0 0 SURFA( DRILL OTHR P Clean and clear rig floor. 12:30 12:45 0.25 0 SURFA( CASING SFTY P Pre job safety meeting on rig up to run casing. 12:45 14:00 1.25 0 0 SURFA( CASING RUNL P Rig up to run 9 -5/8" 40 ppf L -80 BTC -m surface casing. 14:00 14:15 0.25 0 0 SURFA( CASING SFTY P Pre job safety meeting on run casing. 14:15 17:00 2.75 0 1,170 SURFA( CASING RNCS P Run 9 -5/8" 40 DDf L -80 BTC -m surface casing. Make up Ray Oil Tool Silver bullet w/ 36 ppf K -55 BTC jt (one centralizer 10' above shoe on stop and on collar of jt #1). All other joints are 40 ppf L -80 BTC -m casing. Make up jt #2 (Thread lock joint) (stop 10' below box w/ bow spring centralizer), make up Jt #3 w/ Halliburton Sure Seal II Float collar on bottom. Make up jt #4 (baker locked pin). Stab Frank's fillup tool and circulate w/ shoe above conductor shoe. Continue to run casing using Run -N- Seal dope. Centralizers are on box of first 13 joints then every other jt. Run in jt # 31 to 1170', lost 10k to 105k SO wt. Page 4 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 19:00 2.00 1,170 1,515 SURFA( CASING RNCS P Pick up to 1145', stab Frank's fillup tool. Establish circulation pumping 4 bpm w/ 200 psi- 28% Totco flow out. Increase pump rate to 5 bpm w/ 270 psi, wash in the hole from 1145' to jt # 40 in the hole -- 1515'. Worked through numerous areas from 1170' to 1515' which we saw a reduction in slack off wt, so washed casing string in the hole. 19:00 19:15 0.25 1,515 1,710 SURFA( CASING RNCS P Continue to run casing without pumping in the hole from 1515' to 1670' (jt # 41 thru jt # 44). 19:15 19:45 0.50 1,670 1,705 SURFA( CASING CIRC P Circulate 1.5 BU (150 bbls) while recip from 1670' to 1705'. Wash Jt # 45 in the hole. 19:45 21:15 1.50 1,705 2,680 SURFA( CASING RNCS P Continue to run 9 -5/8" 40 ppf L -80 BTC -m surface casing f/ 1705' to 2680' 21:15 21:30 0.25 2,680 2,723 SURFA( CASING RNCS P Make up FMC hanger and landing joint. Run in hole and land on hanger w/ shoe @ 2723.25'. 21:30 21:45 0.25 2,723 2,723 SURFA( CASING RURD P Rig down Frank's fill up tool. Blow down the top drive. 21:45 22:00 0.25 2,723 2,723 SURFA( CEMEN" RURD P Rig up Dowell cement head, connect lines. 22:00 00:00 2.00 2,723 2,723 SURFA( CEMEN" CIRC P Circulate and condition mud and hole for cement job. Reciprocate pipe f/ 2723' to 2688' (35'). Initial pump rate 5 bpm w/ 320 psi, after 35 bbls 6 bpm w/ 380 psi 28 %, after 90 bbls 7 bpm w/ 420 psi 32 -34% Totco flow out. Total of 857 bbls pumped at midnight. PV/YP in 23/18, 63 funnel vis. Held PJSM f/ cementing while circulating. 03/13/2010 Con't to circ & cond mud & hole for cement job. Recip pipe f/ 2723' to 2688' (35'). Pump 7 bpm w/ 300 psi. Circ a total of 962 bbls (PV/YP 23/18, vis 63 in, PV/YP 25/19 out. Rig mixed & pump 50 bbls of 9.7 ppg mud w/ nut plug marker (5ppb), follow w/ 36.5 bbls of vis water w/ nut plug (5ppb). Pump @ 7 bpm w/ 280 to 220 psi. PU wt 170k, SO wt 150k. Dowell press test to 3500 psi. Drop bottom plug. Dowell pump 49.6 bbls of MudPush II (10.5 ppg). Pump 5.8 bpm w/ final press of 210 psi. Dowell mixed and pumped a total of 308.3 bbls (384 sx) of 10.7 ppg ArcticSet Lite 3 cement (Yield 4.51 cuft/sx) (21.23 gal /sx mix water). Avg pump rate of 7.5 bpm w/ initial press of 210 and final of 273 psi. Dowell mixed & pumped 53.2 bbls (257 sx) of 15.8 ppg LiteCrete tail cement ( Yield 1.16 cuft/sx) (21.23 gal /sx mix water). Avg pumping rate of 4.8 bpm w/ final of 136 psi. Drop top plug. Dowell displace & wash up through the tub, pumping 20.1 bbls of water @ 6 bpm w/ 100 psi. Recip pipe f/ 2723' to 2688' (35'). Rig displaced cement w/ 9.7 ppg mud. Pumping the first 170 bbls @ 7.5 bpm w/ 250 psi initial and 600 psi final, then slowed rate for the last 10 bbls to 4 bpm w/ 480 psi. Bumped plugs w/ 500 psi over - -1000 psi @ 0248 hrs 3/13/2010, held f/ 5 minutes. Note: Recip pipe f/ 2723' to 2703' (20') while displacing cement, set on hanger 30 bbls prior to bumping plug. Had 35 bbls of good 10.7 ppg cement to surface. Note: Cement in place @ 0248 hrs 3 -13 -2010. Bled off press - floats held. PJSM, R/D cement equip. Monitor ann, dropping slightly. 2 bbls of cement allowed to replace itself in the cond. Flush stack. L/D FMC landing joint. PJSM, N/D riser & FMC quick connect. Install FMC Gen II Wellhead. Orient. Measure RKB to lockdown screws. Test metal to metal seal to 1000 psi for 10 minutes. PJSM, Nipple up 13 -5/8" BOPE. RU -Test BOPE, witness of test waived by AOGCC inspector Lou Grimaldi. Set wear bushing, L/D 2 8" DC w/ jars, PU 48 stands 5" dp, slip and cut 60' drill line, PU BHA #2 Page 5 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 2,723 2,723 SURFA( CEMEN" CIRC P Continue to circ and condition mud and hole for cement job. Reciprocate pipe f/ 2723' to 2688' (35'). Pumping 7 bpm w/ 300 psi. Circ a total of 962 bbls. Final mud properties: MW in 9.6+ ppg, PV/YP = 23/18, vis 63. MW out 9.7 ppg, PV/YP 25/19. 00:30 01:00 0.50 2,723 2,723 SURFA( CEMEN CMNT P Riq mixed and pumped 50 bbls of 9.8 ppg mud w/ nut plug marker (5ppb),_ followed w/ 36.5 bbls of viscosified water w/ nut plug (5ppb). Reciprocate pipe f/ 2723' to 2688' (35'). Pumped @ 7 bpm w/ 280 to 220 psi. PU wt 170k, SO wt 150k. 01:00 01:11 0.19 2,723 2,723 SURFA( CEMEN" PRTS P Dowell pressure test lines to 3500 psi. Rig changed pressure sensor. Dowell trouble shoot display screen in the dog house. Drop bottom plug after testing. 01:11 01:20 0.16 2,723 2,723 SURFA( CEMEN" CMNT P Dowell pumped 49.6 bbls of MudPush 1I (10.5 ppg). Pumping 5.8 bpm w/ final pressure of 210 psi. Reciprocate pipe f/ 2723' to 2688' (35'). 01:20 02:03 0.72 2,723 2,723 SURFA( CEMEN" PUCM P Dowell mixed and pumped a total of 308.3 bbls (384 sx) of 10.7 ppg ArcticSet Lite 3 cement (Yield 4.51 cuft/sx) (21.23 gal /sx mix water). Average pumping rate of 7.5 bpm w/ initial pressure of 210 and final of 273 psi. Reciprocate pipe f/ 2723' to 2688' (35'). 02 :03 02:15 0.20 2,723 2,723 SURFA( CEMEN" PUCM P Dowell mixed and pumped 53.2 bbls (257 sx) of 15.8 ppg LiteCrete tail cement ( Yield 1.16 cuft/sx) (21.23 gal /sx mix water). Average pumping rate of 4.8 bpm w/ final of 136 psi. Reciprocate pipe f/ 2723' to 2688' (35'). 02:15 02:16 0.03 2,723 2,723 SURFA( CEMEN" OTHR P Drop top plug. 02:16 02:20 0.07 2,723 2,723 SURFA( CEMEN" DISP P Dowell displace and wash up through the tub, pumping 20.1 bbls of water @ 6 bpm w/ 100 psi. Reciprocate pipe f/ 2723' to 2688' (35'). Page 6 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:20 02:53 0.55 2,723 2,723 SURFA( CEMEN" DISP P Rig displaced cement w/ 9.7 ppg mud. Pumping the first 170 bbls @ 7.5 bpm w/ 250 psi initial and 600 psi final, then slowed rate for the last 10 bbls to 4 bpm w/ 480 psi. Bumped plugs w/ 500 psi over - -1000 psi e 0248 hrs 3/13/2010, held f/ 5 minutes. Note: Reciprocated pipe f/ 2723' to 2703' (20') while displacing cement, set on hanger 30 bbls prior to bumping plug. Had 35 bbls of good 10.7 ppg cement to surface. Note: Cement in place @ 0248 hrs 3 -13 -2010. 02:53 02:57 0.08 2,723 2,723 SURFA( CEMEN" OTHR P Bled off pressure to check floats , floats held. 02:57 03:12 0.25 2,723 2,723 SURFA( CEMEN" SFTY P Pre job safety meeting on rigging down cementing and casing equipment. 03:12 03:42 0.50 2,723 2,723 SURFA( CEMEN" RURD P Rig down Dowell cement head. Blow down cementing line. 03:42 04:27 0.75 2,723 2,723 SURFA( DRILL OWFF P Monitor annulus while rigging down equipment and lay down mouse hole. Annulus dropping slightly. Final drop of 15' below the flow line - -2 bbls of cement allowed to replace itself in the conductor. 04:27 05:12 0.75 2,723 0 SURFA( DRILL RURD P Flush stack w/ black water. Back out and lay down FMC landing joint. 05:12 05:27 0.25 SURFA( WHDBO SFTY P Pre job safety meeting on nippling down riser and FMC quick connect. 05:27 06:12 0.75 SURFA( WHDBO NUND P Nipple down surface riser. Disconnect turnbuckles and flow line. 06:12 06:27 0.25 SURFA( WHDBO NUND P Remove FMC quick connect 06:27 06:53 0.44 SURFA( WHDBO NUND P Install FMC Gen II Wellhead. Orient to flow lines. Measure RKB to lockdown screws. 06:53 06:56 0.06 SURFA( WHDBO PRTS P Test metal to metal seal to 1000 psi for 10 minutes- good test. 06:56 07:11 0.25 SURFA( WHDBO SFTY P Pre job safety meeting on nippling up BOPE. 07:11 08:26 1.25 SURFA( WHDBO NUND P Nipple up 13 -5/8" BOPE. 08:26 09:26 1.00 SURFA( WHDBO RURD P Rig up to test BOPE. Pick up 5" test joint. Set FMC lower test plug. Fill lines with water. 09:26 09:41 0.25 SURFA( WHDBO SFTY P Pre job safety meeting on testing BOPE. Page 7 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:41 14:26 4.75 SURFA( WHDBO BOPE P Test BOPE. Witness of test waived by AOGCC inspector Lou Grimaldi. Electrician tested gas alarms. Tested pad evacuation alarm at noon, as today is Saturday. Performed Koomey recovery test. All Boe tests were charted. All tests were held 5 minutes. All tests with 5" test joint. Tested annular to 250 psi low and 2500 psi high. Test upper and lower pipe rams, blinds, kill and choke line valves, choke manifold, mud valve in mezzanine, top drive IBOP valves and floor safety valves to 250 psi low and 3500 psi high. 14:26 14:56 0.50 SURFA( WHDBO OTHR P Blow down choke line, kill line, and choke manifold. Pull test 5" test joint w/ FMC lower test plug. 14:56 15:11 0.25 SURFA( WHDBO OTHR P Set FMC long (4.33') wear bushing (10 -3/4" OD x 10" ID). 15:11 15:26 0.25 SURFA( DRILL RURD P Pick up drilling bales and 5" elevators. 15:26 15:56 0.50 SURFA( DRILL PULD P Lay down 8" NMDC w/ jars from the derrick. 15:56 16:11 0.25 SURFA( DRILL SFTY P Pre job safety meeting on picking up/ standing back 5" drill pipe in the derrick via the mouse hole. 16:11 21:56 5.75 SURFA( DRILL PULD P Pick up/ standi back 48 stands of 5" drill pipe in the derrick via the mouse hole. 21:56 22:11 0.25 SURFA( RIGMNT SFTY P Pre job safety meeting on slip and cut drilling line. 22:11 23:11 1.00 SURFA( RIGMNTSVRG P Slip and cut 60' of 1 -3/8" drilling line. 23:11 23:26 0.25 SURFA( DRILL SFTY P Pre job safety meeting on picking up BHA #2. 23:26 23:56 0.50 0 43 SURFA( DRILL PULD P Pick up/ Ma a uR BHA #2 Hughes 8 -3/4" PDC 605z bit, SperryDrill 7" motor 7/8 6 stage motor, nm float sub, internal blade stabilizer, 6 -3/4" NM DM to 43'. 03/14/2010 Continue to PU /MU BHA #2, upload, con't to PU BHA, shallow pulse test @ 265', PU jars, RIH w/ 5 stands of 5" HWDP, PJSM, PU/MU /RIH w/ 57 joints of 5" DP f/ pipe shed to 2529', circ/ wash to 2620', PJSM, RU then test 9 -5/8" 40 ppf L -80 BTC -m casing to 3550 psi f/ 30 min- lost 60 psi- good test, R/D equip, trouble shoot Sperry Sun MWD- no pulses- unable to resolve, Wash in hole to 2620', drill float collar @ 2639', cement, to 2710', circ f/ trip out to fix MWD tools, monitor well, POOH to 728', monitor well, con't POOH to 81', download MWD, inspect bit, rebuild pulsar, Make up HOC, upload MWD @ 81', pulse test MWD, trip in the hole to 2624', wash to 2710', finish drilling shoe track then the shoe @ 2720 - 2723', rat hole to 2733' and 20' new hole to 2753', circulate and condition hole to perform FIT /LOT.RU then perform LOT to 15.9 ppg EMW (9.6 ppg mud weight, 1100 psi applied pressure, TVD of shoe @ 2457'). Rig down testing equipment. Directional drill 8 -3/4" hole w/ SperryDrill 7" motor (1.37 de._ bend) from 2753' to 3387'. 00:00 00:30 0.50 43 75 SURFA( DRILL PULD P Continue to pick up/ Make up BHA #2 to 70.99'. Make up DGR, EWR, PWD, HCIM, HOC. 00:30 01:15 0.75 75 75 SURFA( DRILL PULD P Upload MWD. Page 8 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 01:45 0.50 75 265 SURFA( DRILL PULD P Continue to pick up/ Make up BHA #2 to 70.99'. Make up Flex drill collars, run in the hole with a stand of 5" HWDP. 01:45 03:00 1.25 265 265 SURFA( DRILL DHEQ P Shallow pulse test MWD. Pumping 550 gpm w/ 1280 psi. Note: Daylight savings time f/ 0200 to 0300 hrs. 03:00 03:30 0.50 265 729 SURFA( DRILL TRIP P Pick up 6.25" DNTjars, run in the hole w/ 5 stands of HWDP to 729'. PU wt 95k, SO wt 95k. 03:30 03:45 0.25 729 729 SURFA( DRILL SFTY P Pre job safety meeting on PU /RIH w/ 5" drill pipe f/ pipe shed. 03:45 05:30 1.75 729 2,529 SURFA( DRILL PULD P Pick up/ make up/ run in the hole 57 jts (19 stands) of 5" drill pipe, on top of BHA #2. Run in the hole f/ 729' to 2529'. PU wt 140k, SO wt 115k. 05:30 06:15 0.75 2,529 2,620 SURFA( DRILL WASH P Circulate and condition mud @ 2529'. Wash down to 2620'. Pumping 600 gpm w/ 1980 psi, rotate 50 rpm w/ 8k ft Ibs of torque. 06:15 06:30 0.25 2,620 2,620 SURFA( DRILL SFTY P Pre job safety meeting on rigging up to test casing. 06:30 06:45 0.25 2,620 2,620 SURFA( DRILL RURD P Rig up to test casing. 06:45 07:15 0.50 2,620 2,620 SURFA( DRILL PRTS P Test 9 -5/8" 40 ppf L -80 BTC -m casing for 30 minutes. Tested both inner annulus valves on the FMC wellhead. Pressure test to 3550 psi. Lost 60 psi in 30 minutes. 07:15 07:30 0.25 2,620 2,620 SURFA( DRILL RURD P Rig down testing equipment, blow down lines. 07:30 08:15 0.75 2,620 2,620 SURFA( DRILL OTHR T Trouble shoot Sperry Sun MWD tools. No pulses. Unable to resolve issue. 08:15 08:30 0.25 2,620 2,639 SURFA( CEMEN" COCF P Wash in the hole f/ 2620' to tag Halliburton Sure Seal II float collar @ 2639'. Drill cement and wiper plugs. Pumping 650 gpm w/ 2110 psi, rotate 50 rpm w/ 8.5k ft Ibs of torque. 08:30 09:15 0.75 2,639 2,710 SURFA( CEMEN" DRLG P Drill float collar © 2639', then cement to 2710' (Leaving 10' of cement above shoe). Pumping 650 gpm w/ 2100 psi, rotate 50 rpm w/ 8.5k ft Ibs of torque. 09:15 09:30 0.25 2,710 2,710 SURFA( DRILL CIRC T Circulate and condition mud for trip out for MWD pulsar problem. Pumping 650 gpm w/ 2100 psi, rotate 50 rpm w/ 8k ft Ibs of torque. 09:30 09:45 0.25 2,710 2,710 SURFA( DRILL OWFF T Monitor well- static. Blow down the top drive. 09:45 10:30 0.75 2,710 728 SURFA( DRILL TRIP T Pull out of the hole on the trip tank from 2710' to 728'. PU wt 95k, SO wt 95k. 10:30 10:45 0.25 728 728 SURFA( DRILL OWFF T Monitor well- static. Page 9 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 11:30 0.75 728 81 SURFA( DRILL TRIP T Continue to pull out of the hole on the trip tank from 728' to 81'. Stand back 5" HWDP and NM Flex drill collars. 11:30 12:00 0.50 81 81 SURFA( DRILL PULD T Download MWD tools. 12:00 13:00 1.00 81 81 SURFA( DRILL PULD T Continue to download, the PU to inspect bit. Pull pulsar, break off HOC, rebuild pulsar. 13:00 13:45 0.75 81 81 SURFA( DRILL PULD T Make up HOC, then plug in and upload MWD. 13:45 14:15 0.50 81 81 SURFA( DRILL DHEQ T Make up top drive. Pulse test MWD tools, pumping 500 gpm w/ 850 psi - OK. Blow down the top drive. 14:15 15:15 1.00 81 2,624 SURFA( DRILL TRIP T Trip in the hole from 81' to 2624'. 15:15 15:30 0.25 2,624 2,710 SURFA( DRILL WASH T Make a top drive connection, fill pipe, wash in the hole from 2634' to 2710'. 15:30 16:00 0.50 2,710 2,733 SURFA( CEMEN DRLG P Finish drilling the shoe track cement (2710' to 2720') and then the shoe (@ 2720' to 2723'). Clean out the rat hole to 2733'.Pumping 500 gpm w/ 1340 psi. Rotate 60 rpm w/ 8k ft Ibs of torque. 16:00 16:15 0.25 2,733 2,753 SURFA( DRILL DRLG P Drill 8 -3/4" hole w/ SperryDrill motor (1.37 deg bend) from 2733' to 2753'. Actual drilling time .1 hrs. 16:15 16:30 0.25 2,753 2,753 SURFA( DRILL CIRC P Circulate and condition mud for FIT /LOT test. Pumping 650 gpm w/ 2110 psi. Rotate 60 rpm w/ 8k ft Ibs of torque. 16:30 16:45 0.25 2,753 2,753 SURFA( DRILL RURD P Blow down the top drive. Rig up to perform FIT. 16:45 17:15 0.50 2,753 2,753 SURFA( DRILL LOT P Perform LOT interperted 15.9 ppg EMW. Applied pressure 1100 psi, MW 9.6 ppg, TVD of 9 -5/8" shoe 6 2457.05'. 17:15 17:30 0.25 2,753 2,753 INTRM1 DRILL RURD P Rig down testing equipment. 17:30 00:00 6.50 2,753 3,387 INTRM1 DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 2753' to 3387'. Displace to new LSND mud while drilling. Drill w/ 2 to 8k weight on bit. Pumping 600 to 650 gpm w/ 2180 to 1670 psi. Rotate 60 to 100 rpm w/ 8 to 8.5k ft Ibs of torque. Actual drilling time 3.45 hrs, of which .5 hrs were sliding. 03/15/2010 Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 3387' to 5783' (4872' TVD). Drill w/ 5 to 15k weight on bit. Pumping 650 gpm w/ 1740 to 2640 psi. Rotate 100 rpm w/ 8.5 to 10.5k ft Ibs of torque on bottom, 8 to 10.5k ft Ibs off bottom.. Actual drilling time 13.66 hrs, of which 2.45 hrs were sliding. Note: Pumped sweeps @ 3863', 4260', 4623', 4930', 5220'. Dilution of 175 bbls @ 4148', 275 bbls @ 5574'. Page 10 of 32 . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 3,387 4,580 INTRMI DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 3387' to 4580' (3917' TVD). Drill w/ 5 to 15k weight on bit. Pumping 650 gpm w/ 1740 to 2160 psi. Rotate 100 rpm w/ 8.5 to 10k ft Ibs of torque on bottom, 8 to 9k ft Ibs off bottom. Actual drilling time 6.59 hrs, of which .95 hrs were sliding. Note: Pumped sweeps @ 3863', 4260'. Dilution of 175 bbls @ 4148'. 12:00 00:00 12.00 4,580 5,783 INTRMI DRILL DDRL P Directional drill 8 -3/4" intermediate _ hole w/ SperryDrill 7" motor from 4580' to 5783' (4872' TVD). Drill w/ 6 to 15k weight on bit. Pumping 650 gpm w/ 2160 to 2640 psi. Rotate 100 rpm w/ 10 to 10.5k ft lbs of torque on bottom, 9.5 to 10.5k ft Ibs off bottom. Actual drilling time 7.07 hrs, of which 1.5 hrs were sliding. Note: Pumped sweeps @ 4623', 4930', 5220'. Dilution of 275 bbls @ 5574'. 03/16/2010 Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 5783' to 7151' (6058' TVD). Drill w/ 6 to 15k weight on bit. Pumping 650 gpm w/ 2160 to 2640 psi. Rotate 100 rpm w/ 10 to 14k ft Ibs of torque on bottom, 9.0 to 13.5k ft Ibs off bottom.. Actual drilling time 12.1 hrs, of which 8.18 hrs were sliding. Total hrs on the bit 29.77 hrs. Note: Pumped sweeps @ 6005'. Dilution of 275 bbls @ 6360' and 7025'. 00:00 06:00 6.00 5,783 6,145 INTRM1 DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 5783' to 6145' (5183' TVD). Drill w/ 6 to 15k weight on bit. Pumping 650 gpm w/ 2350 to 2420 psi. Rotate 100 rpm w/ 10 to 12k ft lbs of torque on bottom, 9.0 to 10.5k ft lbs off bottom. Actual drilling time 2.86 hrs, of which 1.44 hrs were sliding. Note: Pumped 35 bbls nut plug sweep @ 6005'. 06:00 12:00 6.00 6,145 6,550 INTRMI DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 6145' to 6550' (5544' TVD). Drill w/ 7 to 13k weight on bit. Pumping 650 gpm w/ 2380 to 2310 psi. Rotate 100 rpm w/ 12k ft lbs of torque on bottom, 10.5 to 11.5k ft Ibs off bottom. Actual drilling time 3.21 hrs, of which 2.09 hrs were sliding. Note: Dilution of 275 bbls @ 6360'. Page 11 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 6,550 6,935 INTRM1 DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ Sperry Drill 7" motor from 6550' to 6935' (5876 TVD). Drill w/ 6 to 12k weight on bit. Pumping 650 gpm w/ 2310 to 2320 psi. Rotate 100 rpm w/ 12.5 to 13k ft Ibs of torque on bottom, 11.5 to 13k ft Ibs off bottom. Actual drilling time 3.52 hrs, of which 2.58 hrs were sliding. Total bit hrs 27.26 hrs. 18:00 00:00 6.00 6,935 7,151 INTRM1 DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 6935' to 7151' (6058' TVD). Drill w/ 6 to 12k weight on bit. Pumping 650 gpm w/ 2300 to 2180 psi. Rotate 100 rpm w/ 12 to 13k ft Ibs of torque on bottom, 13k ft lbs off bottom. Actual drilling time 2.51 hrs, of which 2.07 hrs were sliding. Total hrs on bit 29.77 hrs. Note: Dilution of 275 bbls @ 7025'. 03/17/2010 Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 7151' to 7191' (6092' TVD). Backream f/ 7191' to 6811' to clean hole (a little trouble sliding). trip in the hole f/ 6811' to 7191'. Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 7191' to 7477' (6302' TVD). Circulate and condition hole for backream trip to the 9 -5/8" shoe. Backream f/ 7477' to 2720'. Pulling speed approx 20' /minute. Slow pulling speed f/ 3005' to 2720'. Run 3 stands back in to 3005', backream again to 2710'. Max ECD's 11.26 ppg. Service rig- monitor well- static. Trip in the hole f/ 2720' to 7382' (filled pipe @ 4053', 5954', and 6811'). At 7382' pumped a 35 bbl high vis nut plug sweep, circulate surface to surface, working pipe f/ 7382' to 7287'. Trip in the hole f/ 7382' to 7457', then ream 20' to bottom @ 7477'. Orient motor, then directional drill f/ 7477' to 7492'. Note: Pumped sweeps @ 6906, 3005', 7382'. Start inhibycol displacement while drilling ahead. 00:00 01:00 1.00 7,151 7,191 INTRM1 DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 7151' to 7191' (6092' TVD). Drill w/ 6 to 12k weight on bit. Pumping 650 gpm w/ 2300 to 2180 psi. Rotate 100 rpm w/ 12 to 13k ft lbs of torque on bottom, 13k ft Ibs off bottom. Actual drilling time .5 hrs, of which .35 hrs were sliding. Total hrs on bit 30.27 hrs. 01:00 02:15 1.25 7,191 6,811 INTRM1 DRILL REAM P Backream out of the hole to clean up hole f/ sliding w/ motor. Pumping 650 gpm w/ 2040 psi. Rotate 100 rpm w/ 14k ft lbs of torque. Pumped a nut plug sweep w/ pulling f/ 6906' to 6811'. 02:15 02:30 0.25 6,811 7,191 INTRM1 DRILL TRIP P Trip in the hole on elevators f/ 6811' to 7191'. PU wt 235k, SO wt 180k. Page 12 of 32 1 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 06:00 3.50 7,191 7,382 INTRM1 DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 7191' to 7382' (6237' TVD). Drill w/ 6 to 17k weight on bit. Pumping 650 gpm w/ 2190 psi. Rotate 100 rpm w/ 14k ft Ibs of torque on bottom, 13k ft Ibs off bottom.. Actual drilling time 2.04 hrs, of which 1.6 hrs were sliding. Total hrs on bit 32.31 hrs. 06:00 08:00 2.00 7,382 7,477 INTRMI DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 7382' to 7477' (6302' TVD). Drill w/ 6 to 17k weight on bit. Pumping 650 gpm w/ 2190 psi. Rotate 100 rpm w/ 14k ft Ibs of torque on bottom, 13k ft Ibs off bottom. Actual drilling time 1.09 hrs, of which .89 hrs were sliding. Total hrs on bit 33.4 hrs. 08:00 08:45 0.75 7,477 7,477 INTRMI DRILL CIRC P Circulate and condition mud @ 7477' prior to backreaming to the shoe. Pumping 650 gpm w/ 2180 psi. Rotate 100 rpm w/ 12.5k ft Ibs of torque. Reciprocating from 7477' to 7382'. 08:45 12:00 3.25 7,477 5,574 INTRMI DRILL REAM P Backream f/ 7477' to 5574'. Pumping 650 gpm w/ 2180 to 2020 psi. Rotate 100 rpm w/ 12.5 to 12k ft Ibs of torque. Pulling 20' /min. ECD's @ 5574' 10.43 ppg. 12:00 16:15 4.25 5,574 3,005 INTRM1 DRILL REAM P Continue to backream f/ 5574' to 3005'. Pumping 650 gpm w/ 2020 to 1740 psi. Rotate 100 rpm w/ 12 to 8k ft Ibs of torque. Pulling 20' /min. ECD's climbing to a max of 11.3 ppg while reaming above 4000'. 16:15 17:15 1.00 3,005 2,720 INTRMI DRILL REAM P Continue to backream f/ 3005' to 2720' with slower pulling speed, while pumping high vis nut plug sweep out of the hole from 3005' to 2720'. Pumping 650 gpm w/ 1740 psi. Rotate 100 rpm w/ 8k ft Ibs of torque. ECD's climbing to a max of 11.26 ppg while reaming above 3005'. Final ECD was 10.95 ppg. 17:15 17:30 0.25 2,720 3,005 INTRMI DRILL TRIP P Monitor well- static. Run in the hole f/ 2720' to 3005'. 17:30 18:30 1.00 3,005 2,720 INTRM1 DRILL REAM P Backream f/ 3005' to 2720' again. Pumping 650 gpm w/ 1740 psi. Rotate 100 rpm w/ 8k ft Ibs of torque. ECD's climbing to a max of 11.26 ppg while reaming above 3005'. Final ECD was 10.5 ppg. 18:30 19:00 0.50 2,720 2,720 INTRMI RIGMNTSVRG P Blow down the top drive. Service rig while monitoring well- static. 19:00 20:15 1.25 2,720 4,053 INTRMI DRILL TRIP P Trip in the hole from 2720' to 4053'. Monitor well on the trip tank. Obtain PU and SO wt's every 5 stands. Page 13 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 20:30 0.25 4,053 4,147 INTRMI DRILL CIRC P Filled pipe @ 4053'. Appears that the float is not holding. Drill pipe filling while running in the hole. Blow down the top drive. 20:30 21:15 0.75 4,147 5,954 INTRMI DRILL TRIP P Trip in the hole from 4147' to 5954'. Obtain PU and SO wt's every 5 stands. Monitor well on the trip tank. 21:15 21:30 0.25 5,954 6,050 INTRM1 DRILL CIRC P Filled pipe @ 5954'. Pipe filled right away. Float not preventing fluid from flowing up drill pipe. 21:30 21:45 0.25 6,050 6,811 INTRMI DRILL TRIP P Trip in the hole from 6050' to 6811'. Obtain PU and SO wt's every 5 stands. Monitor well on the trip tank. 21:45 22:00 0.25 6,811 6,811 INTRMI DRILL CIRC P Filled pipe @ 6811'. Pipe filled right away. Float not preventing fluid from flowing up drill pipe. 22:00 22:30 0.50 6,811 7,382 INTRM1 DRILL TRIP P Trip in the hole from 6811' to 7382'. Appears that the float is not holding. Drill pipe filling while running in the hole. At 7382': PU wt 250k, SO wt 170k. 22:30 23:30 1.00 7,382 7,382 INTRM1 DRILL CIRC P Make a top drive connection. Break circulation, then pump a 35 bbl high vis sweep w/ nut plug, surface to surface. Monitoring shakers- 10 to 20% increase in cuttings observed. Pumping 650 gpm w/ 2130 psi. Rotate 100 rpm w/ 13k ft Ibs of torque. ECD's 10.57 ppg, before and after circulating. 23:30 23:45 0.25 7,382 7,477 INTRM1 DRILL TRIP P Trip in the hole from 7382' to 7457'. Ream last 20' to bottom @ 7477'. Orient motor. Pumping 650 gpm w/ 2190 psi. Rotate 100 rpm w/ 14k ft Ibs of torque on bottom, 13k ft Ibs off bottom. PU wt 250k, SO wt 170K, Rot wt 205k. 23:45 00:00 0.25 7,477 7,492 INTRM1 DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 7477' to 7492' (6312' TVD). Drill w/ 5 to 17k weight on bit. Pumping 650 gpm w/ 2190 psi. Rotate 100 rpm w/ 14k ft Ibs of torque on bottom, 13k ft Ibs off bottom. Actual drilling time .28 hrs, of which .28 hrs were sliding. Total hrs on bit 33.68 hrs. Note: Start displacment and inhibycol dilution while drilling ahead from 7477'. 03/18/2010 Continue to directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 7492' to 8807' (6934' TVD). Note: Started inhibycol displacement while drilling ahead from 7492'. Used 230 bbls of 9.6ppg spike fluid w/ 36% Glydrill. Used 275 bbls black water spike w/ Soltex and Resinex to bring concentration to 6 ppb Soltex and 4 ppb Resinex. Added Lube 776 and Lotorq to bring lubes to 4 %. Note: TD of intermediate hole @ 8888' MD (projected 6946' TVD, projected 83.25 deg, 149 deg azimuth @ 0300 hrs 3/19/2010. Page 14 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 7,492 8,143 INTRMI DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ Sperry Drill 7" motor from 7492' to 8143' (6693' TVD). Drill w/ 6 to 14k weight on bit. Pumping 650 gpm w/ 2260 to 2540 psi. Rotate 100 rpm w/ 13.5 to 14k ft Ibs of torque on bottom, 13 to 10k ft Ibs off bottom. Actual drilling time 6.22 hrs, of which 4.19 hrs were sliding. Total hrs on bit 39.90 hrs, of which 18.44 hrs are sliding. Note: Started inhibycol displacement while drilling ahead from 7492'. Used 230 bbls of 9.6ppg spike fluid w/ 36% Glydrill. Used 275 bbls black water spike w/ Soltex and Resinex to bring concentration to 6 ppb Soltex and 4 ppb Resinex. Added Lube 776 and Lotorq to bring lubes to 4 %. 12:00 00:00 12.00 8,143 8,807 INTRMI DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ SperryDrill 7" motor from 8143' to 8807' (6934' TVD). Drill w/ 8 to 15k weight on bit. Pumping 650 gpm w/ 2540 to 2670 psi. Rotate 100 rpm w/ 14k ft Ibs of torque on bottom, 10 to 10.5k ft Ibs off bottom. Actual drilling time 6.41 hrs, of which 4.03 hrs were sliding. Total hrs on bit 46.31 hrs, of which 22.47 hrs are sliding. Note: TD of intermediate hole @ 8888' MD (projected 6946' TVD, projected 83.25 deg, 149 deg azimuth @ 0300 hrs 3/19/2010. 03/19/2010 Direct'I drill 8 -3/4" hole f/ 8807' to 8888' (6946' TVD). (8888' projected 6946' TVD, 83.25 deg, 149 deg azimuth @ 0245 hrs 3/19/2010.) Circ a nut plug -hi vis sweep w/ recip from 8888' to 8807'. Monitor well- static. Obtain SPR's. Circ 2 more BU's standing back a stand every .5 hour. Work f/ 8807' to 8616'. Backream out of the hole from 8616' to 7572'. Pulling speed 20' /minute. Con't to backream out f/ 7572' to 7382'. Pulling speed 2 -3' /minute. Monitor well- static. RIH f/ 7382' to 8807'. Circ & cond f/ 7" casing. Precautionary ream f/ 8807' to 8888'. Recip from 8888' to 8807'. Circ & cond hole f/ 7" csg. Increase MW from 9.8 ppg to 10 ppg. Recip from 8888' to 8807'. Load casing running pill in the dp. POOH, spot casing running pill from 8888' to 7477'. Pump 3 bpm w/ 320 psi, w/ pulling a stand at 25 ft/min. Monitor well- static. Blow down top drive. POOH f/ 7477' to 6525', monitor well on the trip tank. Monitor well - static, pump a dry job, POOH on trip tank f/ 6525' to 2725', monitor at csg shoe- static, con't POOH f/ 2725' to 728', monitor well @ HWDP- static, POOH/ stand back HWDP, UD jars, PU single stand back HWDP. UD (3) 6 -5/8" NM Flex DC's. Download MWD, clean stabs and bit, break off bit, finish downloading. Finish UD BHA #3. Clean floor, MU stack washing tool, flush stack, break tool/ stand back stand, blow down top drive. Drain stack, pull master bushing, clean driop pan to perform repair on riser (Leaking). Lay down drilling tools, pick up cement head. Page 15 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:45 2.75 8,807 8,888 INTRM1 DRILL DDRL P Directional drill 8 -3/4" intermediate hole w/ Sperry Drill 7" motor from /(p 8807' to 8888' (6946' TVD) Drill w/ 8 to 15k weight on bit. Pumping 650 gpm w/ 2540 to 2670 psi. Rotate 100 rpm w/ 14k ft Ibs of torque on bottom, 10 to 10.5k ft Ibs off bottom. PU wt 247k, SO wt 185k, Rot wt 207k. Actual drilling time 1.63 hrs, of which .43 hrs were sliding. Total hrs on bit 47.94 hrs, of which 23.89 hrs are sliding. Obtain final survey. Note: TD of intermediate hole @ 8888' MD (projected 6946' TVD, projected 83.25 deg, 149 deg azimuth @ 0300 hrs 3/19/2010. 02:45 03:00 0.25 8,888 8,888 INTRM1 DRILL OWFF P Monitor well- static. 03:00 04:00 1.00 8,888 8,807 INTRMI DRILL CIRC P Circulate a 35 bbl nut plug hi vis sweep surface to surface while reciprocate from 8888' to 8807'. Rotate 100 rpm w/ 11.5k ft Ibs of torque. Pumping 650 gpm w/ 2130 psi. 04:00 04:15 0.25 8,807 8,807 INTRM1 DRILL OWFF P Monitor well- static. Obtain slow pump rates. 04:15 05:15 1.00 8,807 8,616 INTRM1 DRILL CIRC P Continue to circulate 2 more bottom's up while rotating 100 rpm w/ P 9 P 11.5 ft Ibs of torque. Pumping 650 gpm w/ 2130psi. Stand back a stand every 1/2 hour. Worked string from 8807' to 8616'. 05:15 07:15 2.00 8,616 7,572 INTRM1 DRILL REAM P Backream out of the hole from 8616' to 7572'. Pumping 650 gpm w/ 2130 to 2280 psi. Rotate 100 rpm w/ 11.5 to 11k ft Ibs of torque. Pulling speed 20' /minute. 07:15 08:00 0.75 7,572 7,382 INTRMI DRILL REAM P Continue to backream out of the hole from 7572' to 7382'. Pumping 650 gpm w/ 2280 psi. Rotate 100 rpm w/ 11k ft Ibs of torque. Pulling speed 2 -3' /minute. 08:00 08:15 0.25 7,382 7,382 INTRM1 DRILL OWFF P Monitor well- static. Blow down the top drive. 08:15 08:45 0.50 7,382 8,807 INTRMI DRILL TRIP P Trip in the hole on elevators f/ 7382' to 8807'. PU wt 243k, SO wt 182k. 08:45 09:00 0.25 8,807 8,888 INTRMI DRILL REAM P Precautionary ream in the hole from 8807' to 8888'. Circulate and condition mud and hole f/ 7" casing. Pumping 650 gpm w/ 2400 psi. Rotate 100 rpm w/ 12k ft Ibs of torque. Page 16 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:45 1.75 8,888 8,888 INTRM1 DRILL CIRC P Circulate and condition mud and hole f/ 7" casing. Increase mud weight from 9.8 ppg to 10 ppg. Pumping 650 gpm w/ 2400 psi. Rotate 100 rpm w/ 12k ft lbs of torque. Reciprocate from 8888' to 8807'. Load casing running pill in the drill pipe. Note: Casing running pill consists of: 50 % of used active mud 10 ppg / 50% new fluid 10 ppg w/ 17% Glydril GP, 6% total lube concentration (4% system concentration plus additional 2% Lube 776). 5 ppb Safe Carb 40, 5ppb Safe Carb 250, 5 ppb Sack Black, 5 ppb Alpine drill Beads. 10:45 12:45 2.00 8,888 7,477 INTRM1 DRILL CIRC P Pull out of the hole s_ooJng ino running pill in the open hole from 8888' to 7477'. Pump 3 bpm w/ 320 psi, while pulling a stand at 25 to 30 ft/min. PU wt 240k, SO wt 180k. 12:45 13:00 0.25 7,477 7,477 INTRM1 DRILL OWFF P Monitor well- static. Blow down the top drive. 13:00 14:30 1.50 7,477 6,525 INTRMI DRILL TRIP P Pull out of the hole on elevators. Monitor well on the trip tank. Obtain PU wt's every 5 stands per rig engineer. PU wt 215k, SO wt 180k. 14:30 14:45 0.25 6,525 6,525 INTRM1 DRILL OWFF P Monitor well- static. 14:45 15:00 0.25 6,525 6,525 INTRMI DRILL CIRC P Pump a dry job. Blow down the top drive. 15:00 17:45 2.75 6,525 2,725 INTRM1 DRILL TRIP P Pull out of the hole on the trip tank from 6525' to 2725'. PU wt 145k @ 6525'. 17:45 18:00 0.25 2,725 2,725 INTRM1 DRILL OWFF P Monitor well at the 9 -5/8" casing shoe- static. 18:00 19:00 1.00 2,725 728 INTRMI DRILL TRIP P Continue to pull out of the hole on the trip tank from 2725' to 728'. 19:00 19:15 0.25 728 728 INTRM1 DRILL OWFF P Monitor well at the HWDP- static. PU wt 100k. 19:15 20:00 0.75 728 175 INTRM1 DRILL TRIP P POOH /stand back 5" HWDP, lay down jars, PU a single to replace jars. 20:00 20:30 0.50 175 81 INTRM1 DRILL PULD P Lay down (3) 6 -5/8" NM Flex DC's f/ 175' to 81'. 20:30 21:15 0.75 81 81 INTRM1 DRILL PULD P Screw lift sub in Sperry Sun TM. Download Sperry Sun MIND depth 81'. PU/ clean off stabs and bit. Break bit. Clean floor. 21:15 22:00 0.75 81 0 INTRMI DRILL PULD P Finish laying down BHA #3. 22:00 22:30 0.50 0 0 INTRM1 DRILL OTHR P Clean floor. 22:30 23:30 1.00 0 0 INTRM1 DRILL PULD P Make up stack washing tool on stand of 5" drill pipe. Wash f/ 45' to 8'. Pumping 700 gpm w/ 450 psi. Rotate 20 rpm. Blow down top drive. Break stack washing tool. Set back stand of 5" dp. Page 17 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 23:45 0.25 0 0 INTRM1 DRILL OTHR P Pull Master bushing. Clean drip pan for repair of drilling riser (Leak). 23:45 00:00 0.25 0 0 INTRM1 DRILL PULD P Lay down drilling tools, Pick up cement head. 03/20/2010 Pull wear bushing, change top rams to 7 ", test to 250/3500 psi. Pull test plug, set casing running wear bushing. RU to run 7" csg. PJSM, Run 7" 26 ppf L -80 BTC -m csg per detail. Circ w/ Frank's fillup tool after 4 joints, check floats- OK. Con't to run csg to 2702' (66 jts), circ 2+ BU (150 bbls) stage up to 6 bpm w/ 410 psi. Con't to run csg to 4704' (115 jts), circ +/- 2 BU (240 bbls) stage up to 6 bpm w/ 510 psi. Con't to run csg to 6745' (165 jts), circ 2 BU (363 bbls) stage up to 6 bpm w/ 550 psi. Con't to run csg to 7765 (190 jts), circ 1.5+ BU (342 bbls) stage up to 6 bpm w/ 640 psi. Con't to run csg to 8841' (216 jts) PU wt 300k, SO wt 185k. Make up FMC 7" csg hanger w/ landing joint. RIH /land on hanger w/ shoe @ 8878.14' Final PU wt 300k, SO wt 180k. UD FU Tool - BD Top Drive & M/U Dowell cement head. Circ & Cond mud prior to First Stage Cement. Circ a total of 632 bbls prior to cementing. Stage pumps up from 3.5 bpm w/ 420 psi, final 6 bpm w/ 600 to 650 psi, totco 21 to 25% flow out. Recip 25' stroke f/ 8878' to 8858'. Final PU wt while circulating 270k, SO wt 180k. Note: Held pre job safety meeting on cement job while circ. Final mud weight 10 ppg, PV/YP= 12/19. Dowell pump 3 bbl of CW 100, shut down, pressure test lines to 3500 psi, con't to pump 37 more bbls of CW 100 (Total of 40 bbls CW 100). Crosssover on the landing joint was leaking. Shut down and tightened the cement crossover while Dowell mixed Mudpush II to 11.5 ppg. Pumped 35 bbls MudPush II (11.5 ppg) at 4 bpm w/ 400 -350 psi. Shut down load and kick out bottom plug w/ 5 bbls of MudPush II (Total of 40 bbls MudPush II). Shut down & load shut -off plug, while Dowell mix Alpine tail cement. Dowell pump 46.4 bbls (225 sx) of Alpine tail cement (15.8 ppg)(1.16 cu ft/sx) 5.076 gal /sx) (5.34 hrs thickening time). Pumping 4.3 bpm w/ 350 psi initial -100 psi final. Drop Halliburton shut -off plug. Dowell displace 20 bbls of water. Rig displace cement w/ 10 ppg mud. Pumpin5 7 bpm w/ initial 350 psi. 00:00 01:15 1.25 INTRM1 WHDBO OTHR P Pull FMC long wear bushing (10" ID). Used air hoist- no go. Used blocks up to 15k overpull- no go. Steamed body of wellhead, rechecked all lockdown screws were backed out. Pulled wear bushing w/ blocks and 19k overpull. 01:15 01:30 0.25 INTRMI WHDBO SFTY P Pre job safety meeting on changing top pipe rams. 01:30 03:15 1.75 INTRMI WHDBO NUND P Change top pipe rams from 3 -1/2" x gbP 6" variables to 7" solid body w/ blind rams shut. Rigging up casing equipment on floor (long bales, elevators and Frank's fillup tool). 03:15 03:45 0.50 INTRMI WHDBO BOPE P Set FMC test plug. Fill hole with water. Lower annulus open. 03:45 04:00 0.25 INTRMI WHDBO BOPE P Test top pipe rams to 250 psi mow and 3500 psi high. Hold test f/ 5 minutes each. Chart test. 04:00 04:30 0.50 INTRMI WHDBO RURD P Rig down test equipment. Set FMC thin wall casing running wear bushing ( 1.53' long x 10 -7/8" OD x 10 -3/8" ID). Lay down running tool and test joint. 04:30 05:30 1.00 INTRM1 CASING RURD P Finish rigging up to run 7" casing. 05:30 05:45 0.25 INTRM1 CASING SFTY P Pre job safety meeting on running 7" 26 ppf L -80 BTC -m casing. Page 18 of 32 1110 410 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment "t 05:45 06:45 1.00 0 130 INTRM1 CASING RNCS P Run 7" casing: Pick up jt #1: Ray Oil tool 7 -5/8" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7 "" x 8- 5/16 ") floating f/ shoe to 10' above the shoe with stop ring. Thread lock joint #2 w/ 7" x 8- 5/16" aluminum centralizer between box and 10' below box with stop ring. Baker lock Halliburton Sure Seal II Float Collar w/ baffle adapter installed. Thread lock jt #3 w /Ray Oil Tool aluminum centralizer (7 "" x 8- 5/16 ") floating f/ pin to 10' above pin with stop ring. Baker lock Halliburton Baffle adapter, then Baker lock pin of Jt #4 with centralizer floating the full joint. Four connections were baker - locked. 06:45 07:00 0.25 130 130 INTRMI CASING CIRC P Stab Frank's fillup tool, then circulate 20 bbls of mud to check floats. Pumping 4.5 bpm w/ 180 psi. 07:00 09:30 2.50 130 2,702 INTRM1 CASING RNCS P Continue to run 7" 26 ppf L -80 BTC -m casing f/ 130' to 2702' (66 jts in the hole). PU 133k, SO 123k. Obtain PU & SO wt's per rig engineer. 09:30 10:00 0.50 2,702 2,702 INTRMI CASING CIRC P Circulate 2+ BU 150 bbls. Stage up f/ 3.5 bpm w/ 260 psi to 6 bpm w/ 410 psi, 23 to 25% Totco flow meter. 10:00 12:00 2.00 2,702 4,704 INTRM1 CASING RNCS P Continue to run 7" 26 ppf L -80 BTC -m casing f/ 2702' to 4704' (115 jts in the hole). PU wt 175k, SO wt 150k. Obtain PU & SO wt's per rig engineer. 12:00 13:00 1.00 4,704 4,704 INTRMI CASING CIRC P Circulate 2 +/- bottom's up, 240 bbls. Stage up f/ 3.5 bpm w/ 380 psi to 6 bpm w/ 510 psi, 25% Totco flow meter. PU wt 170k, SO wt 145k. 13:00 15:00 2.00 4,704 6,745 INTRMI CASING RNCS P Continue to run 7" 26 ppf L -80 BTC -m casing f/ 4704' to 6745' (165 jts in the hole). PU wt 237k, SO wt 170k. Obtain PU & SO wt's per rig engineer. 15:00 16:15 1.25 6,745 6,745 INTRMI CASING CIRC P Circulate 2- bottom's up, 362 bbls. Stage up f/ 3.5 bpm w/ 410 psi to 6 bpm w/ 550 psi, 25 to 27% Totco flow out. PU wt 220k, SO wt 174k. 16:15 17:15 1.00 6,745 7,765 INTRMI CASING RNCS P Continue to run 7" 26 ppf L -80 BTC -m casing f/ 6745' to 7765' (190 jts in the hole). PU wt 265k, SO wt 184k. Obtain PU & SO wt's per rig engineer. 17:15 18:30 1.25 7,765 7,765 INTRM1 CASING CIRC P Circulate 1.5+ bottom's up, 342 bbls. Stage up f/ 3.5 bpm w/ 410 psi to 6 bpm w/ 640 psi, 23 to 25% Totco flow out. Page 19 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:45 1.25 7,765 8,841 INTRM1 CASING RNCS P Continue to run 7" 26 ppf L -80 BTC -m casing f/ 7765' to 8841' (216 jts in the hole). PU wt 300k, SO wt 185k. Final PU wt 300k, SO wt 180k. Obtain PU & SO wt's per rig engineer. 19:45 20:00 0.25 8,841 8,878 INTRM1 CASING RNCS P Make up FMC 7" casino hanaerw/ landing joint. 51H and land on hanger w/ shoe @ 8878.14' Final PU wt 300k, SO wt 180k. 20:00 20:30 0.50 8,878 8,878 INTRMI CEMEN" PULD P UD Franks Fill -Up Tool - Blow Down the Top Drive & M/U Dowell cement head and lines. 20:30 22:38 2.14 8,878 8,878 INTRM1 CEMEN" CIRC P Circ & Condition Mud Prior to First Stage Cement. Circulated a total of 632 bbls prior to cementing. Stagged pumps up from 3.5 bpm w/ 420 psi, after 20 bbls 4 bpm w/ 480 psi, after 50 bbls pumped 5 bpm w/ 510 psi, after 100 bbls pumped, went to 6 bpm w/ 600 to 650 psi, totco 21 to 25% flow out. Reciprocated 25' stroke f/ 8878' to 8858'. Final PU wt while circulating 270k, SO wt 180k. Note: Held pre job safety meeting on cement job while circulating. Final mud weight 10 ppg, PV/YP= 12/19. 22:38 23:23 0.75 8,878 8,878 INTRM1 CEMEN" PUCM P Dowell pump 3 bbl of CW 100, shut down, pressure test lines to 3500 psi, continue to pump 37 more bbls of CW 100 (Total of 40 bbls CW 100). Crosssover on the landing joint was leaking. Shut down and tightened the cement crossover while Dowell mixed Mudpush II to 11.5 ppg. Pumped 35 bbls MudPush II (11.5 ppg) at 4 bpm w/ 400 to 350 psi. Shut down load and kick out bottom plug w/ 5 bbls of MudPush II (Total of 40 bbls MudPush II). Shut down and load Halliburton shut -off plug, while Dowell mix Alpine tail cement (15.8 ppg, 1.16 cuft/sx, 5.08 gal /sx water). 23:23 23:38 0.25 8,878 INTRM1 CEMEN" PUCM P Dowell pump 46.4 bbls (225 sx) of Alpine tail cement (15.8 ppg)(1.16 cu ft/sx) 5.076 gal /sx) (5.34 hrs thickening time). Pumping 4.3 bpm w/ 350 psi initial and 100 psi final. 23:38 23:45 0.13 8,878 8,878 INTRMI CEMEN' DISP P Drop Halliburton shut -off plug. Dowell displace 20 bbls of water behind plug. Pumping 4.3 bpm w/ 50 psi. Page 20 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:45 23:58 0.23 8,878 8,878 INTRMI CEMEN" DISP P Rig displace cement w/ 10 ppg mud. Pumping 7 bpm w/ initial 350 psi. At midnight 100 bbls of mud had been displaced, pumping 7 bpm w/ 390 psi, 26% flow out. PU wt 270k, SO wt 190K. Reciprocating 13' from 8878' to 8865'. 03/21/2010 Rig con't to displ cmt w/ 10 ppg mud. PU wt 270k, SO wt 190K. Recip 13' from 8878' to 8865'. Slow rate to 4 bpm w/ 80 psi while bottom plug went through the cementer, increased rate back to 7 bpm w/ 360 to 390 psi, then slowed to 4 bpm w/ 40 to 70 psi while top plug went through cementer. Increased rate back to 7 bpm w/ 300 psi & final of 630 psi before slowing down last 10 bbls to 3 bpm w/ initial 320, final of 450 psi prior to pumping max strokes (3158 strokes) (317.4 bbls). Set casing on hanger during last 10 bbls pumped. Did not bump plug. Refigure pump volume using .1 bps instead of .1005 bps, then pumped to 3174 strokes (317.4 bbls). Still did not bump plug. Pumped 2 more bbls (4 of 5 bbls in shoe track). Did not bump plug. Town engineer was contacted and decision to WOC before trying to open cementer for second stage. CIP @ 0055 hrs 3/21/2010. WOC 5.42 hrs. Pumping 3 bpm, press up to 900 psi (28 strokes to attain 900 psi). Hold 900 psi for 5 minutes. Con't to press up to open Halliburton cementer @ 5315'. Cementer opened at 3500 psi. Circ & cond mud for 2nd stage job. Circ 4 to 5 bpm w/ 260 to 300 psi. PJSM. Dowell pump 30 bbls CW 100, pump 5 bpm w/ 340 to 380 psi.. Mix & pump 30 bbls mud push spacer (11.5 ppg), pumping 4.3 bpm w/ 350 to 290 psi. Dowell mix/pump 39.5 bbls (191.2 sx) cement, pumping 4.3 bpm w/ 300 to 116 psi. Shut down, drop Halliburton top plug. Dowell kick out the plug with 20 bbls of water, pumping 4.7 bpm w/ 87 psi. Rig displace cement w/ 183.1 ppg mud (1822 strokes). Pumping 5 bpm w/ initial 100 psi. , 21% flow out. Final rate of 3 bpm w/ 375 psi. Bump plug w/ 200 psi over to 600 psi. Increase pressure to 1500 psi to shift cementer sleeve closed. Hold f/ 5 minutes, bled off to check floats- OK. CIP at 0855 hrs.R /D cmt equip, Pull wear bush, install 7" packoff, test to 5000 psi f/ 10 min -ok, change top pipe rams to 3 -1/2x 6 ", test upper & lower rams w/ 4" test joint, test annular. R/D, set wear bushing, PJSM, UD 5" dp f/ derrick (8+ 80) 00:00 00:55 0.92 8,878 8,878 INTRMI CEMEN" DISP P Rig continue to displace cement w/ 10 ppg mud. 100 bbls had been pumped prior to midnight Pumping 7 bpm w/ initial 390 psi. PU wt 270k, SO wt 190K. Reciprocating 13' from 8878' to 8865'. Slowed rate to 4 bpm w/ 80 psi while bottom plug went through the cementer, increased rate back to 7 bpm w/ 360 to 390 psi, then slowed to 4 bpm w/ 40 to 70 psi while top plug went through cementer. Increased rate back to 7 bpm w/ 300 psi and a final of 630 psi before slowing down last 10 bbls to 3 bpm w/ initial 320, final of 450 psi prior to pumping maximum strokes (3158 strokes) (317.4 bbls). Set casing on hanger during last 10 bbls pumped. Did not bump plug. Refigure pump volume using .1 bps instead of .1005 bps, then pumped to 3174 strokes (317.4 bbls). Still did not bump plug. Pumped 2 more bbls (4 of 5 bbls in shoe track). Did not bump plug. Town engineer was contacted and decision to WOC before trying to open cementer for second stage. CIP @ 0055 hrs 3/21/2010. Page 21 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:55 06:20 5.42 8,878 8,878 INTRMI CEMEN" WOC T WOC. While waiting on cement to cure: Prepare as much as possible to lay down 5" drill pipe. Rig crew work on work orders, perform derrick inspection. Service and inspect the top drive. Prepare to change out upper pipe rams. Prepare for upcoming BOPE test. 06:20 06:23 0.05 8,878 8,878 INTRM1 CEMEN" PRTS T Pumping 3 bpm, press up to 900 psi (28 strokes to attain 900 psi). 06:23 06:29 0.11 8,878 8,878 INTRM1 CEMEN" PRTS P Hold 900 psi for 5 minutes. Continue to pressure up to open Halliburton cementer @ 5315'. Cementer opened at 3500 psi. 06:29 07:29 1.00 8,878 8,878 INTRM1 CEMEN' CIRC P Circulate and condition mud for second stage cement job. Circulate 4 to 5 bpm w/ 260 to 300 psi. 07:29 07:44 0.25 8,878 8,878 INTRMI CEMEN" SFTY P Pre job safety meeting on 2nd stage cement job. 07:44 07:59 0.25 8,878 8,878 INTRM1 CEMEN "CMNT P Dowell pump 30 bbls CW 100, pumping 5 bpm w/ 340 to 380 psi.. Mix and pump 30 bbls mud push spacer (11.5 ppg), pumping 4.3 bpm w/ 350 to 290 psi. 07:59 08:10 0.19 8,878 8,878 INTRMI CEMEN' PUCM P Dowell mix then pump 39.5 bbls A (191.2 sx) cement, pumping 4.3 bpm �j11/l w/ 300 to 116 psi. Y" l 08:10 08:11 0.02 8,878 8,878 INTRMI CEMEN" CMNT P Shut down, drop Halliburton top plug. 08:11 08:15 0.08 8,878 8,878 INTRMI CEMEN DISP P Dowell kick out the plug with 20 bbls of water, pumping 4.7 bpm w/ 87 psi. 08:15 08:57 0.71 8,878 8,878 INTRMI CEMEN' DISP P Rig displace cement w/ 183.1 ppg mud (1822 strokes). Pumping 5 bpm w/ initial 100 psi. , 21% flow out. Final rate of 3 bpm w/ 375 psi. Bump plug w/ 200 psi over to 600 psi. Increase pressure to 1500 psi to shift cementer sleave closed. Hold f/ 5 minutes, bled off to check floats- OK. CIP at 0855 hrs. 08:57 09:57 1.00 8,878 0 INTRMI CEMEN RURD P Rig down cementing equipment. Lay down 7" landing joint. 09:57 10:27 0.50 INTRMI WHDBO OTHR P Pull FMC thin wall ( 1.53' long x 10 -7/8" OD x 10 -3/8" ID) casing running wear bushing. 10:27 10:57 0.50 INTRMI WHDBOOTHR P Install FMC 7" packoff. Run in lock down screws. 10:57 11:12 0.25 INTRMI WHDBO PRTS P Test FMC packoff to 5000 psi for 10 minutes. Good test. 11:12 11:27 0.25 INTRM1 WHDBO PULD P Lay down casing equipment. 11:27 13:12 1.75 INTRM1 WHDBO NUND P Change out upper pipe rams from 7" to 3 -1/2" x 6" variables. Change out the saver sub on the top drive to 4" XT39. Change heads in grabber f/ top drive to 4 ". Pick up short bales (Drilling bales), install elevators. Page 22 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:12 13:27 0.25 INTRM1 WHDBO RURD P Pick up 4" test joint, make up FMC upper test plug. Set test plug. Fill stack with water. Rig up to test. 13:27 14:27 1.00 INTRMI WHDBO BOPE P Test annular to 250 psi low and 2500 psi high. Test upper and lower pipe rams to 250 psi low and 3500 psi high. Hold each test f/ 5 minutes. Chart tests. 14:27 14:42 0.25 INTRM1 WHDBO RURD P Rig down testing equipment, pull 4" test joint w/ FMC test plug. Break and lay down test plug. 14:42 15:12 0.50 INTRMI WHDBO OTHR P Set FMC upper wear bushing. Run in lock down screws. 15:12 15:27 0.25 INTRM1 DRILL SFTY P Pre job safety meeting on laying down 5" drill pipe from the derrick. 15:27 23:57 8.50 INTRMI DRILL PULD P Lay down 8 stands of 5" HWDP from the derrick via the mousehole. Then laying down a total of 90 stands of 5" G -105 drill pipe from the derrick. 80of 90 layed down at midnight. Note: Dowell performed injectivity on 9 -5/8" x 7" to 14.9 ppg EMW. Then pumped 300 bbls water, �( followed w/ 50 bbls of Diesel freeze protection for initial annular injection on CD3 -121. 03/22/2010 Con't to lay down 10 more stnds of 5" dp f/ derrick (Total of 8 HWDP and 90 5" DP layed down). Change heads in iron roughneck to 4 ". PU BHA #4 (6 -1/8" bit, SperryDrill straight motor, nm float sub, (3) 4 -7/8" nm Flex collars. x -o, jars, (5) 4" HWDP, run in the hole w/ 51 stands of 4" dp f/ derrick to 5165'. Rig up/ test casing to 1050 psi f/ 10 min -OK. R/D testing equipment. Wash in the hole from 5165', tag cement at 5308', drill cement to HES cementer @ 5315' to 5317.43', ream to 5546'. CBU x2, RU, then test casing to 1000 psi f/ 10 minutes -OK. Pump a dry job, POOH, Lay down BHA #4, Pull wear bushing, Rig up, then test BOPE, witness of test waived by AOGCC inspector John Crisp. Complete BOP test with 4" test joint. Then use a 4 -1/2" test joint and test annular and upper and lower pipe rams. All tests were held 5 min each, high and low press. Charted tests. Tested the annular to 250 psi low and 2500 psi high. All other components were tested to 250 psi low and 3500 psi high. Tested upper pipe rams (3 -1/2" x 6" variables), lower pipe rams (3 -1/2" x 6 "), and blind rams, tested all valves in the choke manifold. Tested the manuel and HCR valves on the kill and choke line. Tested demco mud valve to the kill line. Tested floor safety valve and IBOP. Tested manuel and auto IBOP on the top drive. Tested the accumulator. Tested gas alarms. Rig down testing equipment. Blow down choke manifold, choke and kill lines. Pull FMC test plug, then install FMC upper wear bushing (1.8' long, 10 -5/8" OD x 6- 15/16" ID). Run in lockdown screws. Service the top drive. PJSM, Pick up/ Make up BHA #5: 6 -1/8" Hycolog bit, geopilot (ser # TL048), nm geoPilot flex collar, smart atab, DGR & EWR, smart stab, DM HOC, PWD, TM HOC, integral blade stab to 95'. Pick up, plug in, then upload Sperry Sun MWD. Con't to PU /MU BHA #5: BAT, nm float sub, (3) 4 -7/8" NM Flex DC's, x -o, jars, (1) HWDP, bumper sub, (4) HWDP to 417.58'. Shallow pulse test MWD. Pumping 215 gpm w/ 850 psi. PT geospan to 3500 psi. 00:00 01:00 1.00 INTRMI DRILL PULD P Continue to lay down 10 more stands of 5" dp f/ derrick (Total of 8 HWDP and 90 5" DP layed down). 01:00 01:30 0.50 INTRM1 DRILL RURD P Change heads in iron roughneck to 4 ". 01:30 02:30 1.00 0 154 INTRM1 DRILL PULD P PU BHA #4 (6 -1/8" bit, SperryDrill straight motor, nm float sub, (3) 4 -7/8" nm Flex collars. x -o, jars. 02:30 03:00 0.50 154 307 INTRM1 DRILL PULD P Pick up make up run in the hole with (5) 4" HWDP. Page 23 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 05:45 2.75 307 5,165 INTRM1 DRILL TRIP P Run in the hole w/ 4" dp f/ derrick from to 5165 (51 stands of 4" in the hole). 05:45 06:00 0.25 5,165 5,165 INTRM1 DRILL CIRC P Fill pipe. Blow down the top drive. 06:00 06:30 0.50 5,165 5,165 INTRM1 DRILL PRTS P Rig up to test casing to 1000 psi f/ 10 minutes @ 5165'. 06:30 06:45 0.25 5,165 5,165 INTRM1 DRILL PRTS P Test casing to 1050 psi f/ 10 minutes @ 5165'. (12 strokes).Good test 06:45 07:00 0.25 5,165 5,165 INTRM1 DRILL PRTS P Rig down testing equipment. 07:00 07:15 0.25 5,165 5,308 INTRM1 DRILL WASH P Wash in the hole f/ 5165' to top of cement @ 5308'. 07:15 07:45 0.50 5,308 5,317 INTRMI CEMEN" DRLG P Drill cement from 5308' to 5315', then Halliburton Cementer f/ 5315' to 5317.43'. Pumping 300 gpm w/ 1350 psi, rotate 50 rpm w/ 6.5k ft Ibs of torque. 07:45 08:15 0.50 5,317 5,546 INTRMI DRILL WASH P Wash /Ream to from 5317' to 5546'. Pumping 300 gpm w/ 1350 psi, rotate 50 rpm w/ 6.5k ft Ibs of torque. 08:15 09:15 1.00 5,546 5,546 INTRMI DRILL CIRC P Circulating bottom's up. Pumping 300 gpm w/ 1250 psi. Rotate 50 rpm w/ 6.5 to 7k ft Ibs of torque. 09:15 09:30 0.25 5,546 5,546 INTRMI DRILL PRTS P Rig up to test casing to 1000 psi f/ 10 minutes @ 5546'. 09:30 09:45 0.25 5,546 5,546 INTRMI DRILL PRTS P Test casing to 1000 psi f/ 10 minutes @ 5546'. 09:45 10:00 0.25 5,546 5,546 INTRM1 DRILL PRTS P Rig down testing equipment. 10:00 10:15 0.25 5,546 5,546 INTRM1 DRILL CIRC P Pump a dry job. Blow down the top drive. 10:15 12:45 2.50 5,546 117 INTRMI DRILL TRIP P Pull out of the hole from 5546' to 117', standing back 2 stands of 4" HWDP. 12:45 13:00 0.25 117 27 INTRMI DRILL TRIP P Change elevators, stand back a stand of nm Flex collars. 13:00 13:15 0.25 27 0 INTRM1 DRILL PULD P Lay down motor and bit. 13:15 13:45 0.50 INTRM1 DRILL PULD P Pick up 4" test joint. Pull FMC wear bushing. 13:45 14:15 0.50 INTRM1 WHDBO RURD P Install FMC upper test plug w/ 4" test joint. Fill hole. Rig up to test BOPE. Page 24 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 19:15 5.00 INTRM1 WHDBO BOPE P Test ROPE. Witness of test waived by AOGCC inspector John Crisp. Complete BOP test with 4" test joint. Then use a 4 -1/2" test joint and test annular and upper and lower pipe rams. All tests were held 5 min each, high and low press. Charted j))6 � P tests. Tested the annular to 250 psi �� ✓ ✓ low and 2500 psi high. All other components were tested to 250 psi low and 3500 psi high. Tested upper pipe rams (3 -1/2" x 6" variables), lower pipe rams (3 -1/2" x 6 "), and blind rams, tested all valves in the choke manifold. Tested the manuel and HCR valves on the kill and choke line. Tested demco mud valve to the kill line. Tested floor safety valve and IBOP. Tested manuel and auto IBOP on the top drive. Tested the accumulator. Tested gas alarms. 19:15 19:30 0.25 INTRM1 WHDBO RURD P Rig down testing equipment. Blow down choke manifold, choke and kill lines. 19:30 19:45 0.25 INTRM1 WHDBO PULD P Pull FMC test plug, then install FMC upper wear bushing (1.8' long, 10 -5/8" OD x 6- 15/16" ID). Run in lockdown screws. 19:45 20:00 0.25 INTRMI RIGMNT SVRG P Service the top drive 20:00 20:15 0.25 INTRMI DRILL SFTY P Pre job safety meeting on picking up BHA #5 (GeoPilot). 20:15 22:00 1.75 0 95 INTRMI DRILL PULD P Pick up/ Make up BHA #5: 6 -1/8" Hycolog bit, geopilot (ser # TL048), nm geoPilot flex collar, smart atab, DGR & EWR, smart stab, DM HOC, PWD, TM HOC, integral blade stab to 95'. 22:00 22:45 0.75 95 95 INTRM1 DRILL PULD P Pick up, plug in, then upload Sperry Sun MWD. 22:45 23:45 1.00 95 417 INTRM1 DRILL PULD P Continue to PU /MU BHA #5: BAT, nm float sub, (3) 4 -7/8" NM Flex DC's, x -o, jars, (1) HWDP, bumper sub, (4) HWDP to 417.58' 23:45 00:00 0.25 417 417 INTRM1 DRILL DHEQ P Shallow pulse test MWD. Pumping 215 gpm w/ 850 psi. Pressure geospan to 3500 psi -OK. 03/23/2010 Complete Shallow Pulse test fo MWD Tools - RIH t/ 7,089' MD Filling Pipe Every 20 Stands - Slip / Cut 120' Drill Line - Continue to RIH t/ 7,752' MD - Log Cement f/ 7,752 - 8,567' MD (Tagged Cement Stringers) - Circ & Condition Mud for Casing Test - Test Casing U 3500 Psi f/ 30 Minutes - Clean Out Sho Track t/ 8,888' MD - Drill 20' of New Hole t/ 8,908' MD - CBU - Conduct FIT t/ 12.5 PPG EMW - POOH & Continue Logging Cement f/ 8,567' - 8,905' MD (Bit Depth) - Displace Mud f/ 9.7 PPG LSND t/ 9.1 PPG Flo -Pro 00:00 00:15 0.25 417 417 INTRM1 DRILL DHEQ P Finish shallow pulse test MWD. Pumping 215 gpm w/ 850 psi. OK. 00:15 00:30 0.25 417 417 INTRMI DRILL OTHR P Blow down the top drive. Page 25 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 00:45 0.25 417 417 INTRMI DRILL SFTY P Pre job safety meeting on picking up 4" drill pipe from the pipe shed and running in the hole on top of BHA #5 (GeoPilot). Rabbit pipe to 1.85 ". 00:45 02:00 1.25 417 2,320 INTRM1 DRILL TRIP P PU /MU /RIH w/ 4" dp on top of BHA #5 from 417' to 2320'. (20 stands in the hole). 02:00 02:30 0.50 2,320 2,320 INTRMI DRILL CIRC P Fill pipe, circulate 210 gpm w/ 1090 psi. MWD working ok. Blow down the top drive. 02:30 03:45 1.25 2,320 4,226 INTRMI DRILL TRIP P PU /MU /RIH w/ 4" dp on top of BHA #5 from 2320' to 4226'. (40 stands in the hole). 03:45 04:15 0.50 4,226 4,226 INTRM1 DRILL CIRC P Fill pipe, circulate pumping 210 gpm w/ 1160 psi. MWD working ok. Break in seals on the geoPilot. Blow down the top drive. 04:15 05:45 1.50 4,226 6,135 INTRMI DRILL TRIP P PU /MU /RIH w/ 4" dp on top of BHA #5 from 4226' to 6135'. (60 stands in the hole). 05:45 06:15 0.50 6,135 6,135 INTRM1 DRILL CIRC P Fill pipe, circulate pumping 210 gpm w/ 1300 psi. MWD working ok. Blow down the top drive. 06:15 07:00 0.75 6,135 7,089 INTRM1 DRILL TRIP P Continue to RIH U 7,089' MD (10 Stands) 07:00 07:15 0.25 7,089 7,089 INTRMI RIGMN1SFTY P PJSM on Slipping /Cutting Drill Line 07:15 08:30 1.25 7,089 7,089 INTRM1 RIGMN1 SLPC P Slip & Cut 120' of Drill Line - Calibrate EDMS 08:30 09:00 0.50 7,089 7,752 INTRMI DRILL TRIP P Continue to RIH t/ 7,752' MD f/ the Derrick (7 Stands) 09:00 12:30 3.50 7,752 8,567 INTRM1 DRILL DLOG P Loq Cement w/ BAT Sonic Tool f/ 7,752' - 8,567' MD - Drill String Taking Weight 12:30 13:30 1.00 8,567 8,567 INTRM1 DRILL CIRC P Circ & Condition Mud for Casing Test - 200 GPM @ 1420 Psi w/ 50 RPM, Torque 10K P/U 220, S/O 175, Rot 175 13:30 13:45 0.25 8,567 8,567 INTRM1 DRILL SFTY P PJSM on Testing 7" Casing 13:45 15:00 1.25 8,567 8,567 INTRM1 DRILL PRTS P R/U and Test Casing t/ 3500 Psi f/ 30 Minutes - Blow Down and Rig Down Lines 15:00 16:15 1.25 8,567 8,742 INTRM1 CEMEN COCF P Clean Out Cement Stringers t/ Float Collar @ 8,742' MD - 200 GPM @ 1350 Psi w/ 50 RPM, Torque 12 K 16:15 18:15 2.00 8,742 8,888 INTRMI CEMEN" DDRL P Drill Shoe Track t/ 8,888' MD 18:15 19:00 0.75 8,888 8,908 INTRMI DRILL DDRL P Drill 20' of New Hole t/ 8,908' MD (ADT.23) 19:00 20:00 1.00 8,908 8,908 INTRMI DRILL CIRC P CBU - 200 GPM @ 1100 Psi, 90 RPM , Torque 13 K 20:00 20:15 0.25 8,908 8,908 INTRM1 DRILL SFTY P PJSM on FIT 20:15 21:00 0.75 8,908 8,908 INTRM1 DRILL FIT P R/U and Perform FIT t/. 12.5 PPG , EMW - (1010 Psi @ 6949' TVD) 21:00 21:30 0.50 8,908 8,524 PROD1 DRILL TRIP P POOH t/ 8,524' MD Page 26 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 23:00 1.50 8,524 8,905 PROD1 DRILL DLOG P Continue Logging Cement w/ BAT Sonic Tool f/ 8,567' - 8,905' MD (Bit Depth) 23:00 00:00 1.00 8,905 8,905 PROD1 DRILL CIRC P Displace 9.7 PPG Mud w/ 9.1 PPG Flo -Pro as Follows - Pump 40 Bbls Water Spacer, 70 Bbl Hi -Vis Flo -Pro Spacer and Flo -Pro 03/24/2010 Complete Displacement t/ 9.1 PPG Flo -Pro - Drilled f/ 8,908' to 10,391' MD - Drilled Out of Zone (High) f/ 10,010 to 10,320' MD - Completed 275 Bbl Whole Mud Dilutions @ 9,700' and 10,350' MD Mud Lost to Formation 23 Bbls 00:00 00:45 0.75 8,905 8,908 PROD1 DRILL CIRC P Continue to Displace 9.7 PPG LSND with 9.1 PPG Flo -Pro - 200 GPM @ 1260 psi w/ 100 RPM 00:45 01:00 0.25 8,908 8,908 PROD1 DRILL OWFF P OWFF - Flowing; Decreasing to Slight Ooze 01:00 09:15 8.25 8,908 9,530 PROD1 DRILL DDRL P Drilled 6 1/8" Hole f/ 8,908 to 9,530' MD - Possible Excessive Dog Leg Originally Showed 12° & 20° - Flow Static After First Stand Drilled Down ADT 6.07 P/U 205, S/O 162, Rot 184 Torque On /Off 9 / 7.5 220 GPM @ 1450 Psi / ECD 10.39 WOB 8 -12, RPM 130 09:15 09:45 0.50 9,530 9,530 PROD1 DRILL CIRC T Circ & Condition Mud - Discovered Faulty Magnetometer in Directional Probe - Corrected Surveys w/ Cassandra - Dog legs Corrected to 3.7° and 2.3° (Acceptable) 09:45 12:00 2.25 9,530 9,664 PROD1 DRILL DDRL P Continue to Drill 6 1/8" Hole f/ 9,530' to 9,664' MD ADT 1.35 P/U 205, S/O 162, Rot 184 Torque On /Off 9 / 7.5 220 GPM @ 1550 Psi / ECD 10.45 WOB 8 -12, RPM 120 12:00 00:00 12.00 9,664 10,391 PROD1 DRILL DDRL P Continue to Drill 6 1/8" Hole f/ 9,664' to 10,391' MD - Drilled Out of Zone (High) f/ 10,010' to 10,320' MD, Encountered Shale at 10,150' MD Sample ADT 7.76 P/U 212, S/O 160, Rot 182 Torque On /Off 9.5/7.5 220 GPM @ 1650 Psi / ECD 10.47 WOB 6 -15, RPM 120 03/25/2010 Continue Drilling f/ 10,391' to 12,020' MD Mud Lost to Hole in Previous 24 Hours: 121 bbls - Total Lost to Hole 144 bbls Page 27 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 10,391 11,215 PROD1 DRILL DDRL P Continue to Drill 6 1/8" Hole f/ 10,391'to 11,215' MD ADT 8.88 P/U 220, S/O 155, Rot 185 220 GPM @ 1760 Psi / ECD 10.52 Torque On /Off 10.5/8.5 WOB 7 -10, RPM 120 12:00 00:00 12.00 11,215 12,020 PROD1 DRILL DDRL P Continue to Drill 6 1/8" Hole f/ 11,215' to 12,020' MD ADT 8.61 P/U 223, S/O 152, Rot 184 220 GPM @ 1800 Psi / ECD 10.53 Torque On /Off 10/8.5 WOB 7 -11, RPM 120 03/26/2010 Continue Drilling f/ 12,020' to 13,516' MD Mud Lost to Hole in Previous 24 Hours: 136 bbls - Total Lost to Hole 280 bbls 00:00 12:00 12.00 12,020 12,809 PROD1 DRILL DDRL P Continue to Drill 6 1/8" Hole f/ 12,020' to 12,809' MD ADT 9.33 P/U 230, S/O 146, Rot 184 220 GPM @ 1860 Psi / ECD 10.79 Torque On /Off 12.5/10 WOB 7 -11, RPM 120 12:00 00:00 12.00 12,809 13,516 PROD1 DRILL DDRL P Continue to Drill 6 1/8" Hole f/ 12,809' to 13,516' MD ADT 8.98 P/U 235, S/O 142, Rot 184 205 GPM @ 1850 Psi / ECD 10.65 Torque On /Off 11.5/9.5 WOB 7 -10, RPM 120 03/27/2010 Continue Drilling f/ 13,516' to 14,662' MD; Drilling Slowed to 1 FPH After Turning Up to Look for the Formation Top (14,652' MD - 7,045' TVD) Mud Lost to Hole in Previous 24 Hours: 201 bbls - Total Lost to Hole 481 bbls 00:00 12:00 12.00 13,516 14,238 PROD1 DRILL DDRL P Continue Drilling f/ 13,516' - 14,238' MD ADT 8.60 P/U 236, S/O 138, Rot 184 210 GPM @ 1890 Psi; ECD 10.6 120 RPM / WOB 7 -10 Torque On /Off 12/10 Page 28 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 14,238 14,662 PROD1 DRILL DDRL P Continue Drilling f/ 14,238' - 14,662' MD - Slow Drilling After Turning Bit Up to Look for the Top of Formation - Drilling Slowed to 1 FPH @ 1730 (14,652' MD - 7,045' ND) and Continued to Midnight (14,662' MD) ADT 6.83 P/U 237, S/O 130, Rot 183 210 GPM @ 2050 Psi; ECD 10.83 WOB 10 -23 / RPM 120 Torque On /Off 13.5/10.5 03/28/2010 Continued Drilling f/ 14,662' to 15,081' MD (TD) - CBU X2 - BROOH to 8,805' MD Mud Lost to Hole in Previous 24 Hours: 169 bbls - Total Lost to Hole 650 bbls 00:00 07:45 7.75 14,662 15,081 PROD1 DRILL DDRL P - Continue to Drill f/ 14,662' to TD at 15,081' MD (7,014' ND) ADT 5.86 P/U 240, S/O 130, Rot 185 WOB 7 -14, RPM 120 Torque On /Off 14/10.5 210 GPM @ 1910 Psi / ECD 10.65 07:45 11:00 3.25 15,081 14,715 PROD1 DRILL CIRC P CBU X2 - 210 GPM @ 1980 Psi w/ 120 RPM - Stand Back 1 Stand Every 30 Minutes t/ 14,715' MD 11:00 00:00 13.00 15,081 8,805 PROD1 DRILL REAM P BROOH f/ 15,081' to 8,805' MD (62 Stands) - 210 GPM @ 1700 Psi w/ 100 RPM - (Dropped Rabbit @ 9,187' MD) 03/29/2010 OWFF (Flowing) - CBU X2 - OWFF (Flowing) - Displace Wellbore t/ 9.2 PPG KCL Brine - OWFF (Static then Flowing) - Increase Brine Weight U 9.5 PPG - OWFF (Static) - POOH on TT - UD BHA #5 - Run Slotted /Blank Liner t/ 6,470' MD 00:00 00:15 0.25 8,805 8,805 PROD1 DRILL OWFF P OWFF (Flowing) 00:15 02:15 2.00 8,805 8,805 PROD1 DRILL CIRC P CBU X2; 220 GPM @ 1540 Psi w/ 110 RPM 02:15 04:00 1.75 8,805 8,805 PROD1 DRILL OWFF P OWFF (Flowing) - flow Rate Decreased f/ .83 BPH to .45 BPH in 1 Hour 04:00 05:30 1.50 8,805 8,805 PROD1 DRILL CIRC P Displace Wellbore Fluid f/ 9.2 PPG Flo -Pro to 9.2 PPG KCL - 220 GPM @ 1270 Psi 05:30 05:45 0.25 8,805 8,805 PROD1 DRILL OWFF P OWFF (Static then Flowing) 05:45 07:15 1.50 8,805 8,805 PROD1 DRILL CIRC T PJSM; Increase Mud Weight to 9.4 PPG - 220 GPM @ 1230 Psi 07:15 07:30 0.25 8,805 8,805 PROD1 DRILL OWFF T OWFF (Static) 07:30 09:00 1.50 8,805 8,805 PROD1 DRILL CIRC T Increase Weight to 9.5 PPG for Trip Margin - 190 GPM @ 940 Psi 09:00 10:00 1.00 8,805 8,805 PROD1 DRILL OWFF T OWFF (Static) - Continue to Monitor the Well While Increaseing the Weight of TT Fluids t/ 9.5 PPG 10:00 14:15 4.25 8,805 417 PROD1 DRILL TRIP P POOH on TT f/ 8,805' to 417' MD (88 Stands) 14:15 17:00 2.75 417 0 PROD1 DRILL PULD P UD BHA #5 - Download MWD Data Page 29 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:45 0.75 0 0 PROD1 DRILL OTHR P Clean /Clear Rig Floor - R/U to Run Liner 17:45 18:15 0.50 0 0 COMPZ CASING SFTY P PJSM on Runing 4 1/2" SLHT Liner 18:15 22:30 4.25 0 6,341 COMPZ CASING PUTB P P/U and RIH w/ 4 1/2" SLHT Slotted /Blank Liner per Detail t/ 6,314' MD (159 Joints) - P/U 138, S/O 118 22:30 23:45 1.25 6,341 6,374 COMPZ CASING PULD P M/U Liner Hanger and Runing Tools - Apply Pal Mix and Allow to Cure 23:45 00:00 0.25 6,374 6,470 COMPZ CASING RUNL P RIH w/ Liner on 4" DP t/ 6,470' MD 03/30/2010 Run Liner per Detail and Set Hanger w/ Liner Tail © 15,076' MD, Top @ 8,702' MD - OWFF (U- Tubing) - CBU - OWFF (Static) - Slip & Cut Drill Line - POOH & UD Liner Running Tools - R/U and Run Completion String t/ 6,125' MD 00:00 00:15 0.25 6,470 6,470 COMPZ CASING CIRC P Establish Circulation @ 4 BPM w/ 200 psi 00:15 02:15 2.00 6,470 8,875 COMPZ CASING RUNL P RIH w/ Liner on 4" DP t/ 8,875' MD (26 Stands) 02:15 02:45 0.50 8,875 8,875 COMPZ CASING CIRC P Circulate a Tubing Volume @ 4 BPM w/ 260 Psi 02:45 07:15 4.50 8,875 15,055 COMPZ CASING RUNL P Continue to RIH w/ Liner t/ 15,055' MD - Taking Torque and Drag Measurements per the T &D Engineer - P/U 245, S/O 135 (65 Stands) 07:15 09:00 1.75 15,055 15,076 COMPZ CASING HOSO P Tag Bottom @ 15,081' MD and Space Out to Set Liner @ 15,076' MD - Drop 29/32" Ball - Circulate Down at 4 BPM w/ 470 Psi X2 Pipe Volumes - Drop 1 3/4" Ball and Pump Down - Ball on Seat w/ 64 Bbls Pumped - Pressure Up t/ 3,000 Psi to Set the Hanger, then 4,000 Attempting to Release - Bled Pressure to 0 and Pulled Running Tools f/ Hanger - Liner Top @ 8,702' MD and Tail @ 15,076' MD 09:00 09:30 0.50 15,076 8,528 COMPZ CASING TRIP P POOH w/ Running Tools t/ 8,528' MD 09:30 09:45 0.25 8,528 8,528 COMPZ CASING OWFF P OWFF - Fluids Dropping in Annulus and Flowing from Drill Pipe 09:45 10:45 1.00 8,528 8,528 COMPZ CASING CIRC P CBU @ 7 BPM w/ 870 Psi 10:45 11:00 0.25 8,528 8,528 COMPZ CASING OWFF P OWFF - Fluid Level Dropping Slightly (Approximately .75 BPH) 11:00 12:30 1.50 8,528 8,528 COMPZ RIGMNT SLPC P Slip & Cut 120' of Drill Line - Service Top Drive & Draw Works 12:30 15:45 3.25 8,528 52 COMPZ CASING TRIP P POOH w/ Liner Running Tools t/ 52' MD (91 Stands) 15:45 17:00 1.25 52 0 COMPZ CASING PULD P UD Liner Running Tools - Clean & Clear Rig Floor 17:00 17:30 0.50 0 0 COMPZ RPCOM RURD P Riq Up to Run Tubing _ 17:30 00:00 6.50 0 6,125 COMPZ RPCOM RCST P Run Completion Tubing t/ 6,125' MD (141 Jts + Jewelry) - P/U 139, S/O 120 Page 30 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/31/2010 24 hr Summary Continue to Run Completion Tubing - Space Out and Land Tubing w/ tail @ 8,710' MD - Test Hanger Seals t/ 5,000 Psi f/ 10 Minutes - N/D BOPE - N/U & Test Tree t/ 5,000 Psi - Rig Up and Displace Wellbore Fluids w/ Inhibited Brine and Diesel - Drop Ball & Rod - Set the Packer - Pressure Test Tubing t/ 4925 Psi f/ 30 Minutes - Pressure Test Tubing by Casing Annulus t/ 3490 Psi f/ 30 Minutes - Secure Well - UD 4" DP from the Derrick (55 Stands @ Midnight) 00:00 02:00 2.00 6,125 8,552 COMPZ RPCOM RCST P Continue to RIH w/ Completion Tubing t/ 8,552' MD (57 Joints & DB Nipple) 02:00 03:15 1.25 8,552 8,552 COMPZ RPCOM HOSO P XO to 4" XT39 and Space Out Completion w/ Drill Pipe - Tag Liner Hanger on Depth @ 8,701' MD - Set Down 10 K to Shear Locator Pins - Stand Back Drill Pipe and Calculate 4 1/2" IBT Pups Needed 03:15 03:45 0.50 8,552 8,602 COMPZ RPCOM OTHR P M/U 4 1/2" Pups and 1 Jt of Tubing (Jt 199) & Pull Wear Ring 03:45 04:45 1.00 8,602 8,710 COMPZ RPCOM HOSO P M/U Last Joint of 4 1/2" IBT and Tubing Hanger - Land Tubing hanger in Wellhead and RILDS - Tail @ 8,710' MD - P/U 165, S/O 130 04:45 05:45 1.00 8,710 0 COMPZ RPCOM PRTS P Set TWC &Test Hanger Seals t/ 5,000 Psi f/ 10 Minutes 05:45 06:45 1.00 8,710 0 COMPZ RPCOM PULD P UD Tubing Running Equipment - Clear Rig Floor 06:45 09:45 3.00 0 0 COMPZ WHDBO NUND P Nipple Down BOPE Stack - Nipple Up Tree 09:45 10:15 0.50 0 0 COMPZ WHDBO PRTS P R/U and Test Tree t/ 5,000 Psi f/ 5 Minutes 10:15 10:45 0.50 0 0 COMPZ WHDBO MPSP P M/U Lubricator and Pull TWC 10:45 11:45 1.00 0 0 COMPZ RPCOM CIRC P R/U hard lines and circulating manifold 11:45 12:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM Safety and Ops meeting on fluid displacement 12:00 14:00 2.00 0 0 COMPZ RPCOM CIRC P Line up to Dowell - Pressure test lines to 3000 psi - Displace 9.5 PPG KCL from well w/ 95 Bbls of 9.2 PPG Inhibited KCL and 200 Bbls of Diesel Pumped 3.0 bpm 416 psi - P @ P P 1077 psi Shut in pressures Tubing = 850 psi Annulus = 300 psi 14:00 14:30 0.50 0 0 COMPZ RPCOM PACK P RU Doyon lubricator and drop ball / rod 14:30 14:45 0.25 0 0 COMPZ RPCOM PACK P Pressure test lines to 5000 psi - Pressure up on tubing to 4971 psi - set packer 14:45 16:15 1.50 0 0 COMPZ RPCOM PRTS P tested tubing to 4925 psi, bled to 4710 psi in 30 minutes - bled off tubing to 1050 psi - Pressure test 4 1/2" x 7" annulus to 3490 psi, bled to 3362 psi in 30 minutes 16:15 17:15 1.00 0 0 COMPZ RPCOM RURD P Flush and blow down lines - RD hard lines and circulating manifold 17:15 18:15 1.00 0 0 COMPZ WHDBO MPSP P RU FMC lubricator - install BPV - RD lubricator and secure wellhead Page 31 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 18:30 0.25 0 0 COMPZ RPCOM RURD P Install Mouse Hole and R/U to UD 4" DP 18:30 00:00 5.50 0 0 COMPZ RPCOM PULD P UD 4" DP f/ the Derrick (55 Stands) 04/01/2010 UD Remaining 46 Stands of 4" DP f/ the Derrick - P/u BHA Components /Subs for Next Well - Blow Down Service Lines & Prep to Move - Released Rig @ 0600 00:00 05:15 5.25 0 0 COMPZ RPCOM PULD P UD 4' DP f/ the Derrick (46 Stands) 05:15 06:00 0.75 0 0 COMPZ MOVE DMOB P Pull Mouse Hole - Blow Down Service Lines - Prep Rig for Move to CD3 -123 - Released Rig @ 0600 Page 32 of 32 • SEAN PARNELL, GOVERNOR ALASKA 011. AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, Alaska 99510 -0360 Re: Colville River Field, Fiord Oil Pool, CD3 -121 ConocoPhillips Alaska Inc. Permit No: 210 -022 Surface Location: 3993' FNL, 1069' FEL, SEC. 5, T12N, R5E, UM Bottomhole Location: 2586' FNL, 4879' FEL, SEC. 9, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, 0 ' Daniel T. Seamount, Jr. Chair „t DATED this -u day of February, 2010 Y rY� cc: Department of Fish 86 Game, Habitat Section w/ o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) • • RECEIVED STATE OF ALASKA FEB 1 7 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil & Gas Cons. O ssion 20 AAC 25.005 Anchorage la. Type of Work: 1b. Proposed Well Class: Development - Oil ❑ Service - Winj ❑ Single Zone U . lc. Specify if well is proposed for: hi Test Development - Gas Service - Supply Multiple Zone Coalbed Gas ❑ Gas Hydrates ❑ Drill Q Re drill ❑ Stratigraphic ❑ p ❑ ppI y ❑ P ❑ Exploratory Service - WAG 0 • Service - Disp ❑ p ry P ❑ Shale Gas ❑ Re-entry ❑ r'I 2. Operator Name: 5. Bond: u Blanket ❑ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 -52 -180 • CD3 -121 • 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 -0360 MD: 14982' . TVD: 7072' • Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): 3993' FNL, 1069' FEL, Sec. 5, T12N, R5E, UM • ADL 372105, 372104 • Fiord Oil Pool • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3087' FNL, 3269' FEL, Sec. 5, T12N, R5E UM Tobin - 932002 and 932000 3/12/2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2586' FNL, 4879' FEL, Sec. 9, T12N, R5E, UM 2560 +/- 4.0 miles north to ADL 391451 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 41 x.9!1 {eet 15. Distance to Nearest Well Open r 6. Surface: x- 387974.1 • y- 6003784.2 Zone- 4 GL Elevation above MSL: / Z, ffeet to Same Pool: CD3- Z 2L' 0 16. Deviated wells: Kickoff depth: 350 • ft. 17. Maximum Anticipated Pressures in psig (see 20 nAC 25.035) • Maximum Hole Angle: 89.1 deg Downhole: 3200 psig . Surface: 2493 psig t 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5 H-40 Welded 77 37 37 114 114 Pre Installed 12.25" 9.625" 40 L -80 BTC -M 2706 37 37 2743 2470 492 sx AS Lite 3, 230 sx 15.8 'G' 8.75" 7" 26 L -80 BTC -M 8909 37 37 8946 6954 1st - 211 sx 15.8 'G' 2nd - 185 sx 15.8 G 4.5" 12.6 L -80 IBT -M 8668 32 32 8700 6,909 Tubing 6.125" N/A .1498P' S crYG isy' 14982 7072 Open Hole 6003V 2Z`t *lc 19 PRESENT WELL CONDITION SUMMARY 7 (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective 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 ❑ BOP Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Ryan Robertson - 265.6318 Printed Name A Chip Alvord Title Alaska Drilling Manager Signature 0„( Phone 265 - 6120 Date 2 (r'I ( 2.0 f 0' V' Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: Zf b C- 2-2L) 50 - /(.) S - 7 /S Date: ,/ /e for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed L� 1 meethane, gas hydrates, or gas contained in shales: -3500 f Si &'1 /G$ F Samples req'd: Yes ❑ No u Mud log req'd: Yes ❑ No Q Other: AG ZS CO s, Lys_ 1;54- (ii-i- . measures: Yes ❑ No [ " Directional svy req'd: Yes Er No ❑ �rv�� zs .a3S (/ Jt At t l r� - 4.�,a..,� � 0 Ver 4-e f lfctide_oe 2ca,4.q 6CU - qoe- "^ �1Ce;er� - � F4 ' CIO �kcke.: ! /ace ., ptY+ Z ®. Z' .y /Z CO APPROVED BY T.-IE COMMISSION 2 DATE: • % - , COMMISSIONER! ,---- ' a•on -ha a..� -•,, , Form 10 -401 (Revised 7/2009) This permit is a d • 2 o . •f approval (20 AA.' 5.005(g)) Submit in b up1ica t e Q A A 2 12- r'' • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 February 16 2010 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3 -121 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD3 pad. The intended spud date for this well is March 12 2010. It is intended that Doyon Rig 19 be used to drill the well. CD3 -121 will penetrate the reservoir horizontally. After setting the 7" intermediate casing, the horizontal section will be drilled and the well completed as a Nechelik injector. Once completed, the well will be flowed • back to mitigate reservoir damage and then hooked up to begin production. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement through the intermediate casing shoe and then open a stage tool and pump a second cement job to isolate the K2 formation with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. This will be ✓ the 6 winter season of drilling on the CD3 pad, and to date there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. . Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10 -401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program with request for approval of annular pumping operations. 3. A proposed completion diagram. 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Nina Anderson at 265 -6318 or Chip Alvord at 265 -6120. Sincere ,/ Ryan Robertson Drilling Engineer ORIGINAL • i Attachments: cc: CD3 -122 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1570 Nina Anderson ATO 1706 Mike Winfree ATO 1704 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation II I ORiGU'IAL • • CD3 -121 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12 -1/4" Hole / 9 -5/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Employ gyro single shots and traveling cylinder diagrams. Gas Hydrates Low Monitor well at base of permafrost, increase mud • weight, decreased mud viscosity, increase circulating times, control drilling rates and low mud temperatures. Running Sands and Gravel Low Maintain planned mud parameters, increase mud weight if needed and use weighted sweeps. Abnormal Pressure in Low Increase mud weight to 9.6 — 9.8 ppg. Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, thin mud rheology, pump LCM pills and use of low density cement slurries. 8 -3/4 ee Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills. Mud weight of 9.6 or higher. Flow 9 ppg 9 Surface Formations checks during connections. Mud weight increase if >2000' TVD needed. Lost circulation Low Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced tripping speeds. Engineered mud properties. Ensure proper hole fill. Pump out of hole if needed. Monitor real time equivalent circulating density (ECD). Use of weighted sweeps. Abnormal Reservoir Low Well control drills. Increase mud weight. No mapped Pressure faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H drills. Detection systems and alarms. Use standard well control practices. Employ mud scavengers. 6 -1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced trip speeds. Pump out to 7" shoe. Engineered mud properties. Ensure proper hole fill. Pump out of hole if need. Monitor real time equivalent circulating density (ECD). Use weighted sweeps. Abnormal Reservoir Medium BOPE drills. Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed. Increase mud weight if necessary. Perform well control drills. Hydrogen Sulfide gas Low , H drills. Detection systems and alarms. Use standard well control practices. Employ mud scavengers. ORIGINAL • Rig Procedure 1. Move rig onto CD3 -121. 2. Rig up riser. 3. Drill 12 -1/4" hole to surface casing point as per the directional plan (Directional /MWD) 4. Run and cement 9 -5/8" surface casing.. 5. Install BOPE and test to 3,500 psi. 6. Pick up and run in the hole with 8 -3/4" drilling BHA. 7. Pressure test casing to 3,500 psi. 8. Drill out 20' of new hole and perform leak off test. 9. Drill 8 -3/4" hole to intermediate casing point into the Nechelik reservoir sand (GR/RES /PWD). - 10. Run and cement 7" casing as per drilling program. Perform a leak off test down the 9 -5/8" x 7" annulus to confirm the fracture pressure referenced to the surface casing shoe. If needed, a second stage cement job will be pumped to isolate the K2 (Qannik) formation. 11. Freeze protect the casing annulus to surface. 12. Perform BOPE test to 3,500 psi. 13. Pick up and run 6 -1/8" drilling BHA. 14. Drill out HES cementing tool used to isolate the Qannik formation. - 15. Pressure test 7" intermediate casing to 3,500 psi. 16. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 17. Perform MADD pass with BAT Sonic tool while tripping to bottom to ensure first stage cement quality. 18. Displace well to Flo -Pro mud system. 19. Drill 6 -1/8" horizontal section to well TD (LWD Program: GR/RES /PWD) • 20. Circulate hole clean and pull out of hole. 21. Run upper completion: 4 -1/2 ", 12.6 ppf, L -80 tubing with DB Profile, GLM, Premier Packer, and XN nipple. 22. Install two way check valve and pressure test hanger seals to 5,000 psi. 23. Nipple down BOP 24. Install tubing head adapter assembly. 25. Pressure test adapter assembly to 5,000 psi. 26. Remove two way check valve. 27. Circulate tubing to diesel and install freeze protection in the annulus. 28. Install BPV and secure well. 29. Move rig off CD3 -121. ORIGINAL • WELL PROXIMITY RISKS Directional drilling and collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3 -112 is the nearest existing well to the CD3 -121 plan with 45.72' well to well separation at 1,908' MD. DRILLING AREA RISKS There are no high risk events anticipated. • No over pressured zones are expected. Faulting within the Nechelik reservoir is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with any drilling fluid losses to the drilled formations. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. ANNULAR PUMPING OPERATIONS: Incidental fluids developed from drilling operations on well CD3 -121 will be injected into a permitted annulus on the • CD3 pad, or the class 1 disposal well on CD1 pad. The CD3 -121 surface /intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. Significant hydrocarbon zones include the Nechelik reservoir, and potentially the Qannik and Kuparuk reservoir. There will be 500' of cement fill placed above the top of the Kuparuk reservoir, along with 500' of cement above and below the Qannik reservoir as per regulations. Once CD3 -121 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10 -403 would then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable /industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C -40). These 450 -500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surface Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,470') + 1,500 psi = 3,060 psi Pore Pressure = 1,131 psi Therefore Differential = 3,041 psi — 1,131 psi = 1910 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9 -5/8" 40 L -80 3 BTC 3,090 psi 2,626 psi 5,750 psi 4,888 psi 7" 26 L -80 3 BTC -Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL • • DRILLING FLUID PROGRAM SPUD to 9 -5/8" Intermediate hole to 7" Production Hole surface casing point casing point — 8 3/4" Section — 6 1/8" — 12 1/4" Density 8.7 — 9.8 ppg 9.6 — 9.8 ppg 9.0 ppg PV 10 — 16 7 —12 YP 30 -60 13 -16 10 -15 Funnel Viscosity 70 — 300 Initial Gels 8 — 10 6 - 9 10 minute gels <20 8 - 12 API Filtrate NC — 10 cc / 30 min 5 — 12 cc /30 min (drilling) HPHT Fluid Loss at 10 cc /30 min 165 8.5 -9.0 9.0 -10.0 9.0 -9.5 PH 6 % KCL Surface Hole: A standard high viscosity fresh water gel spud mud is planned for the surface interval. Flow line viscosity will be kept at ± 300 sec /qt while drilling gravels. Viscosity prior to cementing will be reduced to ± 80 -100 sec /qt. Mud weight will be maintained at <9.8 ppg by use of solids control system and dilution where necessary. Using cold make up water will help keep the flow line temperature as low as possible. Intermediate Hole Section: A fresh water polymer mud system is to be used for the intermediate section due to expected soft formations and higher rates of penetration. Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. The potential for lost circulation exists, particularly after the Nechelik reservoir is penetrated. Mud weight will be maintained at or below 9.8 ppg to minimize losses, and lost circulation material will be introduced to the system if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be beneficial in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a MI Swaco's Flo -Pro drill -in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo - Vis Polymer and Dual -Flo starch will be used for viscosity and fluid loss control respectively. nPlrik! A I • • CD3 -121 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (ppg) (psi) (psi) 16" 114 / 114 10.9 52 53 9 -5/8" 2743 / 2470 14.5 1118 1615 7" 8946 / 6954 16.0 3147 2493 N/A 14982 / 7072 16.0 3200 • N/A • NOTE: Doyon 19's 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP): ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi /ft 0.1 = Gas gradient in psi /ft D = True vertical depth of casing seat in ft RKB OR 2) ASP = FPP — (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD ASP CALCULATIONS 1. Drilling below conductor casing (16 ") ASP = [(FG x 0.052) — 0.1] D = [(10.9 x 0.052) — 0.1] x 114 = 53 psi OR ASP = FPP — (0.1 x D) = 1118 — (0.1 x 2470') = 871 psi 2. Drilling below surface casing (9 -5/8 ") ASP = [(FG x 0.052) — 0.1] D = [(14.5 x 0.052) — 0.1] x 2470 = 1615 psi OR ASP = FPP — (0.1 x D) = 3147 — (0.1 x 6954') = 2451 psi 3. Drilling below intermediate casing (7 ") ASP = FPP — (0.1 x D) = 3200 — (0.1 x 7072') = 2493 psi • OP!rTh !Al 1 • Cementing Program: 9 5/8" Surface Casing run to 2743' MD / 2470' TVD. Cement from 2743' MD to 2243' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2243' to surface with 10.7 ppg Arctic Set Lite 3. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1540' MD). Lead slurry: (2243' - 1540') x 0.3132 ft /ft x 1.5 (50% excess) = 330 ft below permafrost 1540 - 114' x 0.3132 ft /ft x 4.0 (300% excess) = 1787 ft above permafrost 114' x 0.6381 ft /ft x 1.0 (0% excess) = 73 ft in conductor annulus Total volume = 330 + 1787 +73 = 2190 ft => 492 Sx @ 4.45 ft3 /sk r System: 492 Sx ArcticSet Lite 3 @ 10.7 PPG Tail slurry: (2743' - 2243') x 0.3132 ft /ft x 1.5 (50% excess) = 235 ft annular volume 80' x 0.4341 ft /ft = 34.7 ft shoe joint volume Total volume = 235 + 34 = 269 ft => 230 Sx @ 1.17 ft /sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft /sk 7" Intermediate Casing run to 8946' MD / 6954' TVD: Cemented in two stages Cement from 8946' MD to 7863' MD (300' MD above the packer & minimum 500' MD above top of Kuparuk reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. First Stage: Lead: (8946' - 7863') x 0.1503 ft /ft x 1.4 (40% excess) = 228 ft annular vol. 80' X 0.2148 ft /ft = 17 ft shoe joint volume Total volume = 228 + 17 = 245 ft => 211 Sx @ 1.16 ft /sk System: 211 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3 /sk Second Stage: Cement from ports in a stage tool set 500' below the Qannik (K2) interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (5298' - 4272') X 0.1503 ft /ft X 1.4 (40% excess) = 216 ft annular vol. Total Volume = 216 ft => 185 Sk @ 1.17 ft /sk System: 185 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.17 ft /sk ORIGINAL • • ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Plan: CD3 -121 Plan: CD3 -121 Plan: CD3- 121wp03 Standard Proposal Report 'permit NCR 12 February, 2010 27 L.I.IIIIII!IIIIIIIIIIIIIUI Fil D� N iO T print HALLIBURTON Sperry Drilling Services ORIGINAL *- - � q -J Project: Western North Slope Sit: CD3 Fiord ■ ■/x� ■/�]�■/� ■ ■/�) ■}.■/� 'll*� � s Well: Plan: CD3- -121 CD3 -121 wp03 V■ ■V `V• N � ,599 �Y... Wellbore: Plan: 0D31µ1 DD - 6.732 - 3000 a 4500 -_. -' - - L /1 ^ d - Al aska DOI < 6.0 . Relatively h at, simple mils a ample p with low tatuos COI 6.0 -6.4: Shorts wells th high tortuosity orlonger wale w;th tow tams = Start DLS 4.70 4 Ot D6.4 -6.8: Long was .0161 relatively tortuous profiles ® _ Start DLS 3.70 TFO - 130.00 , ° DDI > 6.8 • Lang, tortuous ppea. s wih a high degree of dirficu+y B - __ - H ALLI LJ RTO N REFERENCE INFORMATION Surface Location Start DLS 1.00 TFO 180.00 Northing 6003531.41 Start DLS 4.63 TFO -61.10 - CaaOnRe (WE) R44aen0e: Well Pia.: CD3-121. True NOM casting 1528006.04 3000 Veticd (TOO) Reference Flan: 0133 421 (36.3+12.5) 0.00E) 48.805 (D9 19) Ground Lead 12.50 Sperry Drilling �s0 �J4�- Section Rdaece Slot -(0. Cataiatm Method Minimum Curvature Latitude ]0'25'8.2?ON Latitude 150 °54.56.794W 1500 -- a - 1500 Geodetic zone Alaska Zane 4 . p" n3 a 11:34, February 11 2010 Geodetic Daum: North Amakal Datum 1983 CASING DETAILS SURVEY PROGRAM � O __ _. , C EP r 9 -5/8" x 12 -1/4" ND NO55 MD Name Size - I CD3 -121 3 Haab - -"iii. m 2470.00 2421.20 2743.28 95/8 9- 5/8 -1/4' 36.30 1000.00 CD3-121wp03 (Ban: 003 CB- GYROSS wp 6953.80 6905.00 8945.56 7 Tx 8.3/4' 1 000.00 11961.79 CD3- 121wp03 (Ban: CD3 -121) MWD +IF R- AKCAZSC 7071.78 7022.98 14982.34 4 -1/2 4- 1)2' &1/8" _ = - 7" x 84/4" ., Name TVOSS +wS •E/ - Northing Basting Shape ° Start Build 1.40 ♦� �L�.� Start 3570.00 hold at 1950.00 MD 063.121+503 T 7023.00 - 387288 1482.11 5999636.98 1529429.54 CYde (Radius: 100.00) a 0- . 0 o O q berms- _ - __. v - . - -. - Start 56017 hold 8127 MD .0 hod at 93. s0 No.01 n0 Darting 6 • Sec MD Inc .00 rvD 7509.5 +04/4 .0 0.00 Northing 0 'Mace +sac Target 0.00 0.0Target - °� Start DLS 2.61 TFO - 8.73 - 1 36.30 0.00 0.00 36.30 1250 0.00 0.00 0.00 00 ^10 2 350.00 0.00 0.00 350.00 301.20 0.00 0.00 0.00 0.00 0.00 3 550.09 3.00 330.00 550.00 501.20 4.54 -2.62 1.50 330.00 5.19 y Start Build 2.20 - 4 902.90 10.76 330.00 900.00 851.20 41.12 -23.74 2.20 0.00 47.02 - 5 1950.08 38.00 323.50 1844.88 1796.08 391.57 - 269.03 2.61 5.73 474.19 Z 6 5520.00 38.00 323.50 4658.08 4609.28 2158.38 - 1578.39 0.00 0.00 -2671.35 o Start Build 1.50 7 5680.00 36.40 323.50 4785.52 4736.72 2236.14 - 1633.93 1.00 180.00 - 2788.05 - - 8 7269.45 42.00 221.84 6136.54 6087.74 2217.37 - 2331.59 3.70 - 130.00 .3182.72 4.70 40.00 -2862.46 9 9301.2] 89.10 102.37 6 0 142.37 .89 6935.00 1 56208 - 19]7.22 t.40 5 0.00 1635.91 0D}121wp03 Heel % - 1560 - 41;:::* - - 1500 X 12 14982.34 89.10 142.37 7071.80 7023.00 . 3072.88 1482.11 0.00 0.00 3964.35 0.133 - 121x9103 Toe -7500 - 5000 3500 0 2500 > - ...e. I I_ I I I_ I I I 1 I I I I I I 1 L I I L X I I I I 1 -- 4000 -- rf - 4000 • r e...4• 0 - Start Build 1.50 , . 9 0° _ CD3"121wp03 To .6 �ry ." - Start Build 2.20 - - - . J GOn3 Start DLS 2.61 TFO -8.73 f ' " 2O° I I I I I I I 1 I I l j I I I I I I I I I - Start 3570.00 hold at 1950.00 MD ..?0,, -3000 -1500 0 1500 - C -30 414 West(- ) /East(4') (1500 ft/in) c_ b - ' �� _. ... ° C-20 C-20 - 9-5/8" x 12 -1/4" ANNOTATIONS 0 In • NO T00 M Build L CNI 3 - 900,0+ 350.00 301.20 350.00 0 Slat Start BuOd 1.50 550.00 n. - K - 3 K - 3 Basal B° O 5011020 550.09 star Bu6e 220 900.00 85120 902.90 Start DLS 261 030 5.73 a) 1844.88 V 00/ -1/ 0 4658.08 4609.28 5520.00 5ta1D S1�O0 1950.00 MD 0 - - - 4785.52 4736.72 5680.00 5111019310 TFO- 130.00 N - _ 6645.64 6596.84 800220 Slat DLS 4.63 TFO 51.10 6136.54 6087.74 7269.45 Sta1 DLS 4.70 WO -80. - - -- _ S - - - - - -- 6983.80 8935.00 9381.27 Start 5601.07 1.Od A 938 27 MD K - Start DLS 1.00 TFO 180.00 O 7071.78 7022.98 14982.34 10 4 14982.34 > K - 2 Basal 0 - 2 Start DLS 3.70 TFO - 130.00 2- 5000 6 Start DLS 4.70 TFO -80.00 - 5000 Albian 97 ., Start DLS 4.63 TFO $1.1 Start Build 1.40 - FORMATION TOP DETAILS Albion 96 7UOU Start 5601.07 hold at 9381.27 MD -- - -- - - - - - - - -- - TVDpah TVOsepath MDPah Formation 7" X 6 2483.80 2435.00 2760.80 C-30 Top HRZBase HRZK - Top Kuparuk Ku aruk ❑ o - _ 2573.80 2625,00 3255.71 C-20 .. - _ - P P �CU 38 ° � o O' O O O O N 38 93.80 3845.00 4550.11 K-3 - - - - 0 °O O O O o0 O .80 92.00 4736.66 K -3 Basal - W - O _ o or 29 O - - - -_ - - - - 4063.80 4125.00 4 K -2 Basal _ _ - _ ' aD r .- - -. - - - - - -- -- - - _ _ - - _ - - - - ICD3- 121W003 _ - - - _ _ 5908.80 5860.00 6979.22 A 5558.80 5510.00 6570.92 Abiat97 Albian 96 -- -- - O NOIQSOt _ - 6539.60 6491.00 7856.13 Top HRZ Base Nupsut T p ICD3 - 121 wp03 Heel - 7500 6710.86 6662.00 8170.62 Base H 1 76x0 Base Necheli�0P Nechelik ICD3 121wp03 Toe 4 1/2 "x6 - 1 /8" 6753.80 6705.00 8262.69 Top KupaukD 6796.80 6748.00 8363.08 Top Kupauk C I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 6798.80 6750.00 8388.00 LCU 6798.80 6750.00 8368.00 Top NuxryA - 7500 - 6000 -2500 0 2500 5000 7500 6863.80 6815.00 8545.86 Base Nugsut 6948.80 6900.00 8907.66 Top Nechdk Vertical Section at 142.00 °(2500 ft/in) 7023.80 6975.00 11927.85 Base Nechato Project: Western North Slope CD3 -121 wp03 S: CD3 Conoc Wellbore Plan: CD3 -121 I I I � 1 00 I -2000 2000 Alask I I I I I I I I I I I I I A 'k I wl <fi.o: Ralau.ay annn. :ln,ge wale oro paamw6h lw� artunary Shorter DDI6.0 -6.4: Sh we v4thhgh tortuosity or longer we m s with low totul DDI = 6.732 d111- DDI 6.4 - 6.8: Long well with relatively tortuous pron. -4000 Da " 8.8 : Long, fatuous profiles with a high degree of dfiaky MALLIBURTON REFERENCE INFORMATION SurfaceLocaton - 66 111 - COordn9e (N/E) Reference Referen Wei non. CD3 -121, True North Northing 600 3531.61 Vertical (750) Reference Plan: CD3 -121 36.3.12.5) 48.800 Estin9 12 08.04 - Section (VS) Reference Slot lMN �E) (Dorian 19 ) Gmund Lrvd 12.50 Sperry Drilling Calculation Me hod Minimum Curvature ure Longitude 150 W Start DLS 170 TFO - 130.00 Geodetic Zone Alaska Zone - O 1a February 11 2010 Geodetic Douro: Wet, American Datum 1983 es CASING DETAILS 0895505 PROGRAM - Start DLS 4.70 TFO - 80.00 - - - Start DLS 1.00 TFO 180.00 - TVD NOSS MD Name Size - 2470.00 2421.20 2743.28 9.5/8 99/B 121/4 38.30 1000.00 CD3.121 %an: C - 12 11 CB-GYRO-SS -GYRO-SS 0553 8945 6953.80 6905.00 8945.56 7 7'x8 -3/4' 1000.00 14981.]9 CD3- 121wp03 ( %an: GD3.121) MWD.IFR- AK-CAZSC 2000- 4 -2000 7071.78 7022.98 14982.34 4 -1/2 4- 112 xe -1/8' Start DLS 4.63 TFO - 61.10 Targets . None TVD55 41/4 OE/-W Northing Eas.ng Shape C - - CD3- 1210003 Toe 7023.00 387288 1482.11 5999636.98 1529429.54 C✓de(Radius: 100.00) � 9 - 5/8" x 12 - 114" C - CD3 -121 t _ - `` - x 8-3/4" AA Start 3570.00 hold at 1950.00 MD Bea MD Inc Ad ND TVDSS 14/4 4EI-W Northing Easting DLag TFece VSec T get '4.412.74‘ 0� 1 36.30 0.00 0.00 36.30 1250 0.00 0.00 0.00 0.00 0.00 2 350.00 0.00 0.00 350.00 30120 0.00 0.00 0.00 0.00 0.00 . = 0- ,\ - 0 • 3 550.09 3.00 330.00 550.00 501.20 4.54 -2.82 1.50 330.00 9.19 i Start Build 1.49 4 902.90 10.76 330.00 900.00 85130 41.12 -23.74 2.20 0.00 -47.02 5 1950.00 38.00 323.50 1844.88 1796.08 391.57 - 269.03 2.61 9.71 470.19 _ Start DLS 2.61 TFO - 8.73 6 5520.00 38.00 323.50 4658.08 4609.28 2158.38 •1576.39 0.00 0.00 - 2871.35 O (a 7 5680.00 36.40 323.50 4785.52 4736.72 2236.14 - 1633.93 1.00 180.00 - 2768.05 ��s�/ 0 7269.45 42.00 221.84 6136.54 6087.74 2217.37 - 2311.50 3.70 - 130.00 -3182.72 Start 5601.07 hold at 9381.27 MD /�� ^� '!-/ 9 8042.28 58.00 178.38 6645.64 6596.84 1879.01 - 2500.37 10 8045.56 83.00 142.37 6953.80 6905.00 906.57 - 220249 4.63 41.10 - 2070.37 803- 121w003 Heel it 93813] 89.10 112.37 6983.80 6935.00 562.48 - 1937.22 1.40 0.00 - 1635.91 _ - 12 1498234 89.10 112.37 ]0]1.80 7023.00 3872.88 1082.11 4.70 40.00 .286246 0.00 0.00 3984.35 003- 121wp03 Tae Start Build 2.20 _ OOO ti ^ ^a Start Build 1.50 •••••• -2000- N.a ` 4 .-.2000 /G O 15. 1 ,50 • 4 - woo 0 3000 I I I _. I I I 1 11 I I I I 1 I I I I I I I I 1 1 I 1 1 -_Li I 1tf? 4 - 1/2" x 6 - 1 /8 " .d _ ICD3- 121wp03 Tool A sti ^ry.�4" - 00 Start Build 1.50 4600 - 4P - 4000 It _ - 4 pv15i1 - 0 9 0 -4000 -2000 0 2000 Start Build 2.20 - - West( - )/East( +) (2000 ft/in) c _ r Start DLS 2.61 TFO -8.73 6';', 20. • ° o Start 3570.00 hold at 1950.00 MD /0 - ANNOTATIONS CD M C - - TVD TVOSS MD Annotation 350.00 301.20 350.00 Start 6404 1.50 y 550.00 501.20 550.09 Val 6004 2.20 900.00 851.20 902.90 Slat DLS 261 TFO -8.73 d - ,/ -- - 1844.88 1796.08 1950.00 Start 3570.00 hold d 1950.00 MD a1 G20 ' / 9 x 12 - 1/4" 4785.52 4736.22 5680.00 Sw1 180.00 4785.52 4736.72 5680.00 Slat 131.5 3.70 TFO -100.00 • 3000- - 3000 6136.54 6087.74 7269.45 Slat DLS 4.70 TFO 40.0.00 K -3 3 B= / / 6645.64 6905 804288 slat DLS 0.61 TFO -61.10 10 Y K - Basal - > ,0 _ - 6983 7071.78 702.98 14982.34 TD 0 14982.34 S .80 6935.00 9381.27 art 5801.07 hold 3 9381.27 MD - Start DLS 1.00 TFO 180.00 S / • - - -- - - K -2 - _ - K -2 Basal - Start DLS 3.70 TFO - 130.00 Start DLS 4.70 TFO -80.00 Start Build 1.40 - FORMATION TOP DETAILS - Albion 97 6, " Start DLS 4.63 TFO -61.w- _ _, Albian 96 _ - - _ - - - - Start 5601.07 hold at 9381.27 MD 248.80 2435: 0 26580 FannC- 0 8000 - " Top HRZBase FIRZK -1 Top Kuparuk ' 7" x 8-3/4" IiO - - 40408 399200 4]3666 .sal _ P _ P _ �p Kup 0 0 0 " o ° o °o °o c‘:,13 - - - 4173.80 4120.00 4905.44 K-2 BK2 - CD3 3845.00 4550.11 K-3 I1't2 - - -- - _ _ _ ,6 0 cr Q o 0 - - _ an3. 4125.00 6905.-4 K-2 Basal ...-00 V = - - - 5558.80 58 697922 Alban an97 i^ _ _ - - __ -- - = 653980 6616.00 0 7656.13 Tap HRZ _ - - ICD3- 121w 9 �3 - I CD3 - 1116 -_ - -_ _. 6]1080 6662.00 8]062 Base K-1 k Base Nui sutTop Nuigsl�t;D3- 121wp03 e el I CD3- 121wp03I - 675380 6705.00 8262.69 Top KUpaek0 - Ba c plechc'2op Nocholi q Tce 4- 1/2"x6 -1/8" 67%80 e74e oo 8363.08 Top KUpaekc "7 4 I I 1 1 I I I I 1 t t I I 1 I I I I I I I I 6798.10 675000 8368.00 LCO 6]98.60 6750.00 8368.00 Top Nupsut .8000 4000 3000 0 3000 8000 9000 12000 6963.80 6815.00 8545.86 Base Nunsut 6948.80 6900.00 8907.66 Tap Nechdk Vertical Section at 142.00`(3000 ft/in) 7023.80 6975.00 11927.85 Base Nechdk Easting (3500 ft/in) I II ii 1 i I Iiii III,, Im, Iiiiil m iIiiill m iIi,,,l m il m iImiIiiiilm iIim Iim Ill,, Iim IimI - 11 :34, February 11 2010 - — CD3- 126wp02 — _ CD3 -109 CD3- 125wp02 - CD3 106wp10 — CD3 -106 1W3:431-108 — CD3 -110 CD3 -111L CD3-3 *1 - CD3 -301 • wp07 CD' -g,4KP g,c L1 - CD3 -111 1D3 -106 Ri. -. eys CD3 -112 CD3 -107 • CD3 -113 - D3- 302Aw.13 \ a • 3- 301APB wp0 - CD3 -114 - _ Z — CD3 -302 - o _ CD3 -118 CD3 -115 /2C3 CD3 -307 _ cc D3- / — w _ CD3- 124wps -CD3 -117 /� - o o I p— / — Z _ _ , / CD3 303 �� '�' =� -- D3- 198wp01 ' 124 RigSu ; • ,. CD3 6 • _' /'" ' 9 CD3 -316A �/'• CD3- 199wp01 �„��� C D3 -120wp • .' � 3 119wp02 - CD3 -304 CD3- 121wp03 . _ CD3- 305PB1 — CD3 -122 - CD3 -305 - ConocoPhillips(Alaska) Inc. -NS CD3 W — Western North Slope CD3 Fiord Pad - i I I I 1 i i i , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 , 1 1, 1 1 1 1 1 1 1 1 1 1 1 1, 1, 1 1 1 1 1 1 1 1, 1 1 1 1 1 1 1 1, 1 1 1 1 1 1 1 1 ,, 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1, 1 1 1 1 1 1 1 1 1 1 1 1 Easting (3500 ft/in) 1110 • ConocoPhillips HALLIBURT N Standard Proposal Report Database: EDM v16 Prod Lo alCo- ordinate Reference: Well Plan: CD3 -121 Company: ConocoPhillips(Alaska) Inc. TVO Reference Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 . Project: Western North Slope MD Reference; Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Site: CD3 Fiord Pad North Reference: True - Welt Plan: CD3 -121 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3 -121 Design: CD3- 121wp03 Project Western North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor 1 Site CD3 Fiord Pad Site Position: Northing: 469.98ft Latitude: 53° 58' 43.652 N 1 From: Map Easting: - 401.26ft Longitude: 152° 19' 30.231 W Position Uncertainty: 0.00ft Slot Radius: " Grid Convergence: -1.88 ° Well Plan: CD3 -121 Well Position +N/-S 0.00 ft Northing: 6,003,784.21ft - Latitude: 70° 25' 9.396 N +E / -W 0.00 ft Easting: 387,974.13 ft Longitude: 150° 54' 45.417 W Position Uncertainty 0.00ft Wellhead Elevation: ft Ground Level: 12.50ft Welibore Plan: CD3 -121 fl Magnetics Model Name Sample Date Deciin : • : gle Field Strength ° k , r, w, ( °) (nT) BGGM2007 2/11/2010 16.31 79.70 57,325 Design CD3- 121wp03 - 4 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth from► ) .. t : +EI-W Direction ( , � ; .` 2 ' (ft) ( 36.30 0.00 0.00 142.00 Plan Sections Measured Vertical '''iz- z.144411 Dogleg Build Turn Depth Inclination Azimuth Depth , -. +141/..S +EI W Rate Rate Rate Tool Face (ft) ( ( (ft) < . yr,;.: (ft) (ft) (1100ft) ( °1100ft) ( °I100ft) ( 36.30 0.00 0.00 36.30 -12.50 0.00 0.00 0.00 0.00 0.00 0.00 350.00 0.00 0.00 350.00 301.20 0.00 0.00 0.00 0.00 0.00 0.00 550.09 3.00 330.00 550.00 501.20 4.54 -2.62 1.50 1.50 0.00 330.00 902.90 10.76 330.00 900.00 851.20 41.12 -23.74 2.20 2.20 0.00 0.00 1,950.00 38.00 323.50 1,844.88 1,796.08 391.57 - 269.03 2.61 2.60 -0.62 -8.73 5,520.00 38.00 323.50 4,658.08 4,609.28 2,158.38 - 1,576.39 0.00 0.00 0.00 0.00 5,680.00 36.40 323.50 4,785.52 4,736.72 2,236.14 - 1,633.93 1.00 -1.00 0.00 180.00 7,269.45 42.00 221.84 6,136.54 6,087.74 2,217.37 - 2,331.50 3.70 0.35 -6.40 - 130.00 8,042.28 58.00 178.38 6,645.64 6,596.84 1,679.01 - 2,500.37 4.70 2.07 -5.62 -80.00 8,945.41 82.99 142.35 6,953.80 6,905.00 906.78 - 2,202.41 4.63 2.77 -3.99 -61.12 9,380.82 89.10 142.37 6,983.80 6,935.00 562.97 - 1,937.27 1.40 1.40 0.00 0.18 I 14,982.25 89.10 142.38 7,071.80 7,023.00 - 3,873.04 1,481.81 0.00 0.00 0.00 91.48 2/12/2010 10:50 :04AM Page 2 COMPASS 2003.16 Build 69 CRIGINI\L • 0 ConocoPhillips HALLIBURT ®N Standard Proposal Report Database: EDM v16 Prod Local CO-ordinate Referefce : Well Plan: CD3 -121 Company: ConocoPhillips(Alaska) Inc. NafteferetiOet I Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Project: Western North Slope Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Site: CD3 Fiord Pad Ndtir t±eita: True Welk. Plan: CD3 -121 Survey CaIcut8tion Method: Minimum Curvature Welibore: Plan: CD3 -121 Design: CD3- 121wp03 Planned Survey I � Measured Vertical - . Map Map p Depth Inclination Azimuth Depth . TVDss +N/-S. +E/-Wlf Northing Fasting DLS Vert Section (ft) (°} (1 (ft} t_ {ft} , (t1) : (ft) -12.50 36.30 0.00 0.00 36.30 -12.50 0.00 0.00 6,003,784.21 387,974.13 0.00 0.00 100.00 0.00 0.00 100.00 51.20 0.00 0.00 6,003,784.21 387,974.13 0.00 0.00 200.00 0.00 0.00 200.00 151.20 0.00 0.00 6,003,784.21 387,974.13 0.00 0.00 300.00 0.00 0.00 300.00 251.20 0.00 0.00 6,003,784.21 387,974.13 0.00 0.00 350.00 0.00 0.00 350.00 301.20 0.00 0.00 6,003,784.21 387,974.13 0.00 0.00 Start Build 1.50 400.00 0.75 330.00 400.00 351.20 0.28 -0.16 6,003,784.50 387,973.97 1.50 -0.32 500.00 2.25 330.00 499.96 451.16 2.55 -1.47 6,003,786.78 387,972.69 1.50 -2.92 550.09 3.00 330.00 550.00 501.20 4.54 -2.62 6,003,788.79 387,971.58 1.50 -5.19 Start Build 2.20 600.00 4.10 330.00 599.81 551.01 7.21 -4.17 6,003,791.49 387,970.07 2.20 -8.25 700.00 6.30 330.00 699.39 650.59 15.06 -8.70 6,003,799.40 387,965.66 2.20 -17.22 800.00 8.50 330.00 798.56 749.76 26.21 -15.13 6,003,810.65 387,959.39 2.20 - 29.97 900.00 10.70 330.00 897.15 848.35 40.65 -23.47 6,003,825.21 387,951.27 2.20 -46.49 902.90 10.76 330.00 900.00 851.20 41.12 -23.74 6,003,825.68 387,951.01 2.20 -47.02 Start DLS 2.61 TFO -8.73 1,000.00 13.27 328.32 994.96 946.16 58.46 -34.13 6,003,843.17 387,940.88 2.61 -67.08 1,100.00 15.87 327.15 1,091.74 1,042.94 79.72 -47.58 6,003,864.63 387,927.76 2.61 -92.11 1,200.00 18.46 326.29 1,187.28 1,138.48 104.38 -63.78 6,003,889.53 387,911.92 2.61 - 121.52 1,300.00 21.07 325.64 1,281.38 1,232.58 132.40 -82.72 6,003,917.82 387,893.41 2.61 - 155.26 1,400.00 23.67 325.13 1,373.85 1,325.05 163.71 - 104.34 6,003,949.45 387,872.27 2.61 - 193.24 1,500.00 26.27 324.71 1,464.49 1,415.69 198.25 - 128.60 6,003,984.35 387,848.52 2.61 - 235.40 1,600.00 28.88 324.37 1,553.12 1,504.32 235.94 - 155.46 6,004,022.44 387,822.24 2.61 - 281.64 1,700.00 31.48 324.07 1,639.56 1,590.76 276.72 - 184.86 6,004,063.65 387,793.46 2.61 - 331.87 1,800.00 34.09 323.82 1,723.62 1,674.82 320.50 - 216.73 6,004,107.89 387,762.26 2.61 - 385.98 1,900.00 36.70 323.60 1,805.14 1,756.34 367.17 - 251.00 6,004,155.08 387,728.68 2.61 - 443.87 1,950.00 38.00 323.50 1,844.88 1,796.08 391.57 - 269.03 6,004,179.74 387,711.03 2.61 - 474.19 Start 3570.00 hold at 1950.00 MD 2,000.00 38.00 323.50 1,884.28 1,835.48 416.32 - 287.34 6,004,204.76 387,693.10 0.00 - 504.96 2,100.00 38.00 323.50 1,963.09 1,914.29 465.81 - 323.96 6,004,254.79 387,657.23 0.00 - 566.51 2,200.00 38.00 323.50 2,041.89 1,993.09 515.30 - 360.58 6,004,304.82 387,621.35 0.00 - 628.05 2,300.00 38.00 323.50 2,120.69 2,071.89 564.79 - 397.20 6,004,354.85 387,585.48 0.00 - 689.60 2,400.00 38.00 323.50 2,199.49 2,150.69 614.28 - 433.82 6,004,404.88 387,549.61 0.00 - 751.14 2,500.00 38.00 323.50 2,278.29 2,229.49 663.77 - 470.44 6,004,454.91 387,513.74 0.00 - 812.69 2,600.00 38.00 323.50 2,357.09 2,308.29 713.26 - 507.06 6,004,504.94 387,477.87 0.00 - 874.24 2,700.00 38.00 323.50 2,435.89 2,387.09 762.75 - 543.68 6,004,554.97 387,442.00 0.00 - 935.78 2,743.28 38.00 323.50 2,470.00 2,421.20 784.17 - 559.53 6,004,576.62 387,426.47 0.00 - 962.42 9 -5/8" x 12 -1/4" 2,760.80 38.00 323.50 2,483.80 2,435.00 792.84 - 565.95 6,004,585.38 387,420.19 0.00 - 973.20 C-30 2,800.00 38.00 323.50 2,514.69 2,465.89 812.24 - 580.30 6,004,605.00 387,406.13 0.00 - 997.33 2,900.00 38.00 323.50 2,593.49 2,544.69 861.73 - 616.92 6,004,655.03 387,370.26 0.00 - 1,058.87 3,000.00 38.00 323.50 2,672.30 2,623.50 911.22 - 653.55 6,004,705.06 387,334.39 0.00 - 1,120.42 3,100.00 38.00 323.50 2,751.10 2,702.30 960.71 - 690.17 6,004,755.09 387,298.52 0.00 - 1,181.96 3,200.00 38.00 323.50 2,829.90 2,781.10 1,010.20 - 726.79 6,004,805.12 387,262.64 0.00 - 1,243.51 2/12/2010 10:50:04AM Page 3 COMPASS 2003.16 Build 69 7 • • ConocoPhillips HALLIBURTOP.J Standard Proposal Report Database: EDM v16 Prod LecalGo -bate Reference: Well Plan: CD3 -121 Company: ConocoPhillips(Alaska) Inc. TVD'R nce: Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Project: Western North Slope MO Referent*: Cep: Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Site: CD3 Fiord Pad North Reference: True Well: Plan: CD3 -121 Survey CatauIaBonMethod: Minimum Curvature Welibore: Plan: CD3 -121 Design: CD3- 121wp03 Planned Survey Measured Vertica4 #AUp Map Depth Inclination Azttnuth Depth TVDss +NAS +EJ•WE, N rstdiing Easting DLS Vert Section (ft) ( ( (ft) it ' {f#}' ..' (ft) «t) (ft) 2,825.00 1 3,255.71 38.00 323.50 2,873.80 2,825.00 1,037.78 - 747.19 6,004,832.99 387,242.66 0.00 - 1,277.79 C -20 3,300.00 38.00 323.50 2,908.70 2,859.90 1,059.69 - 763.41 6,004,855.15 387,226.77 0.00 - 1,305.05 3,400.00 38.00 323.50 2,987.50 2,938.70 1,109.18 - 800.03 6,004,905.18 387,190.90 0.00 - 1,366.60 3,500.00 38.00 323.50 3,066.30 3,017.50 1,158.67 - 836.65 6,004,955.21 387,155.03 0.00 - 1,428.14 3,600.00 38.00 323.50 3,145.10 3,096.30 1,208.16 - 873.27 6,005,005.24 387,119.16 0.00 - 1,489.69 3,700.00 38.00 323.50 3,223.90 3,175.10 1,257.65 - 909.89 6,005,055.27 387,083.29 0.00 - 1,551.23 3,800.00 38.00 323.50 3,302.70 3,253.90 1,307.14 - 946.51 6,005,105.30 387,047.42 0.00 - 1,612.78 3,900.00 38.00 323.50 3,381.50 3,332.70 1,356.63 - 983.13 6,005,155.33 387,011.55 0.00 - 1,674.32 4,000.00 38.00 323.50 3,460.31 3,411.51 1,406.13 - 1,019.75 6,005,205.36 386,975.68 0.00 - 1,735.87 4,100.00 38.00 323.50 3,539.11 3,490.31 1,455.62 - 1,056.38 6,005,255.39 386,939.80 0.00 - 1,797.41 4,200.00 38.00 323.50 3,617.91 3,569.11 1,505.11 - 1,093.00 6,005,305.42 386,903.93 0.00 - 1,858.96 4,300.00 38.00 323.50 3,696.71 3,647.91 1,554.60 - 1,129.62 6,005,355.45 386,868.06 0.00 - 1,920.50 ' 4,400.00 38.00 323.50 3,775.51 3,726.71 1,604.09 - 1,166.24 6,005,405.48 386,832.19 0.00 - 1,982.05 4,500.00 38.00 323.50 3,854.31 3,805.51 1,653.58 - 1,202.86 6,005,455.51 386,796.32 0.00 - 2,043.59 4,550.11 38.00 323.50 3,893.80 3,845.00 1,678.38 - 1,221.21 6,005,480.58 386,778.34 0.00 - 2,074.43 K-3 4,600.00 38.00 323.50 3,933.11 3,884.31 1,703.07 - 1,239.48 6,005,505.54 386,760.45 0.00 - 2,105.14 4,700.00 38.00 323.50 4,011.91 3,963.11 1,752.56 - 1,276.10 6,005,555.57 386,724.58 0.00 - 2,166.68 4,736.66 38.00 323.50 4,040.80 3,992.00 1,770.70 - 1,289.53 6,005,573.91 386,711.43 0.00 - 2,189.24 K-3 Basal 4,772.19 38.00 323.50 4,068.80 4,020.00 1,788.28 - 1,302.54 6,005,591.69 386,698.68 0.00 - 2,211.11 K -2 4,800.00 38.00 323.50 4,090.71 4,041.91 1,802.05 - 1,312.72 6,005,605.60 386,688.71 0.00 - 2,228.23 4,900.00 38.00 323.50 4,169.52 4,120.72 1,851.54 - 1,349.34 6,005,655.63 386,652.84 0.00 - 2,289.77 4,905.44 38.00 323.50 4,173.80 4,125.00 1,854.23 - 1,351.33 6,005,658.35 386,650.89 0.00 - 2,293.12 K -2 Basal I 5,000.00 38.00 323.50 4,248.32 4,199.52 1,901.03 - 1,385.96 6,005,705.66 386,616.97 0.00 - 2,351.32 5,100.00 38.00 323.50 4,327.12 4,278.32 1,950.52 - 1,422.59 6,005,755.69 386,581.09 0.00 - 2,412.86 5,200.00 38.00 323.50 4,405.92 4,357.12 2,000.01 - 1,459.21 6,005,805.72 386,545.22 0.00 - 2,474.41 I 5,300.00 38.00 323.50 4,484.72 4,435.92 2,049.50 - 1,495.83 6,005,855.75 386,509.35 0.00 - 2,535.95 5,400.00 38.00 323.50 4,563.52 4,514.72 2,098.99 - 1,532.45 6,005,905.78 386,473.48 0.00 - 2,597.50 5,500.00 38.00 323.50 4,642.32 4,593.52 2,148.48 - 1,569.07 6,005,955.81 386,437.61 0.00 - 2,659.04 5,520.00 38.00 323.50 4,658.08 4,609.28 2,158.38 - 1,576.39 6,005,965.82 386,430.44 0.00 - 2,671.35 Start DLS 1.00 TFO 180.00 5,600.00 37.20 323.50 4,721.47 4,672.67 2,197.62 - 1,605.43 6,006,005.48 386,402.00 1.00 - 2,720.14 5,680.00 36.40 323.50 4,785.52 4,736.72 2,236.14 - 1,633.93 6,006,044.42 386,374.08 1.00 - 2,768.05 Start DLS 3.70 TFO - 130.00 5,700.00 35.93 322.53 4,801.67 4,752.87 2,245.57 - 1,641.03 6,006,053.96 386,367.12 3.70 - 2,779.85 5,800.00 33.69 317.36 4,883.79 4,834.99 2,289.27 - 1,677.68 6,006,098.20 386,331.13 3.70 - 2,836.85 5,900.00 31.70 311.59 4,967.96 4,919.16 2,327.13 - 1,716.13 6,006,136.63 386,293.26 3.70 - 2,890.36 6,000.00 30.00 305.18 5,053.83 5,005.03 2,358.99 - 1,756.23 6,006,169.08 386,253.64 3.70 - 2,940.15 6,100.00 28.64 298.15 5,141.04 5,092.24 2,384.70 - 1,797.81 6,006,195.42 386,212.46 3.70 - 2,986.01 6,200.00 27.67 290.57 5,229.24 5,180.44 2,404.17 - 1,840.69 6,006,215.53 386,169.88 3.70 - 3,027.76 6,300.00 27.14 282.61 5,318.05 5,269.25 2,417.32 - 1,884.70 6,006,229.33 386,126.07 3.70 - 3,065.21 2/12/2010 10 :50 :04AM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips HALL1BURTON Standard Proposal Report Database: EDM v16 Prod LOcM0b-ortfinate Reference: Well Plan: CD3 -121 Company: ConocoPhillips(Alaska) Inc. R R ' Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Project: Western North Slope MD Refe Plan: CD3 -121 (36.3 +12.5) @ 48.80ft ( Doyon 19 Site: CD3 Fiord Pad North Reference: True Well: Plan: CD3 -121 SuraeycalCttion Method: Minimum Curvature Wellbore: Plan: CD3 -121 Design: CD3- 121wp03 Planned Survey Measured Verticai Map ` Map Depth inclination AiZimuth. Depth . VOW!: 444,4 :.% .: Northing.. Easting DLS Vert Section (ft) ( (°) (ft) it . ,. ,::.' ..: {ft) (ft) 5,358.30 6,400.00 27.07 274.49 5,407.10 5,358.30 2,424.08 - 1,929.66 6,006,236.76 386,081.23 3.70 - 3,098.22 6,500.00 27.46 266.45 5,496.02 5,447.22 2,424.43 - 1,975.37 6,006,237.80 386,035.53 3.70 - 3,126.63 6,570.92 28.01 260.93 5,558.80 5,510.00 2,420.79 - 2,008.14 6,006,234.66 386,002.71 3.70 - 3,143.94 Albian 97 6,600.00 28.30 258.74 5,584.44 5,535.64 2,418.37 - 2,021.64 6,006,232.44 385,989.18 3.70 - 3,150.35 6,700.00 29.54 251.53 5,671.99 5,623.19 2,405.93 - 2,068.29 6,006,220.69 385,942.35 3.70 - 3,169.26 6,800.00 31.15 244.92 5,758.31 5,709.51 2,387.15 - 2,115.11 6,006,202.62 385,895.26 3.70 - 3,183.29 6,900.00 33.06 238.95 5,843.04 5,794.24 2,362.11 - 2,161.92 6,006,178.29 385,848.08 3.70 - 3,192.38 6,979.22 34.75 234.67 5,908.80 5,860.00 2,337.90 - 2,198.86 6,006,154.65 385,810.79 3.70 - 3,196.05 AIbian 96 7,000.00 35.22 233.60 5,925.82 5,877.02 2,330.92 - 2,208.51 6,006,147.81 385,801.03 3.70 - 3,196.49 ! 7,100.00 37.60 228.82 6,006.32 5,957.52 2,293.72 - 2,254.70 6,006,111.30 385,754.29 3.70 - 3,195.61 7,200.00 40.15 224.54 6,084.18 6,035.38 2,250.64 - 2,300.29 6,006,068.92 385,708.07 3.70 - 3,189.73 7,269.45 42.00 221.84 6,136.54 6,087.74 2,217.37 - 2,331.50 6,006,036.12 385,676.36 3.70 - 3,182.72 Start DLS 4.70 TFO -80.00 7,300.00 42.27 219.73 6,159.19 6,110.39 2,201.85 - 2,344.89 6,006,020.81 385,662.75 4.70 - 3,178.74 7,400.00 43.41 213.03 6,232.56 6,183.76 2,147.15 - 2,385.13 6,005,966.72 385,621.69 4.70 - 3,160.41 7,500.00 44.92 206.64 6,304.33 6,255.53 2,086.75 - 2,419.71 6,005,906.85 385,586.21 4.70 - 3,134.10 7,600.00 46.77 200.61 6,374.01 6,325.21 2,021.05 - 2,448.38 6,005,841.60 385,556.56 4.70 - 3,099.98 7,700.00 48.92 194.97 6,441.15 6,392.35 1,950.50 - 2,470.96 6,005,771.40 385,532.93 4.70 - 3,058.29 7,800.00 51.33 189.71 6,505.28 6,456.48 1,875.57 - 2,487.29 6,005,696.73 385,515.48 4.70 - 3,009.30 7,856.13 52.77 186.91 6,539.80 6,491.00 1,831.78 - 2,493.68 6,005,653.05 385,508.43 4.70 - 2,978.72 Top HRZ 7,900.00 53.95 184.80 6,565.98 6,517.18 1,796.76 - 2,497.26 6,005,618.09 385,504.32 4.70 - 2,953.34 8,000.00 56.76 180.22 6,622.84 6,574.04 1,714.61 - 2,500.81 6,005,536.01 385,499.54 4.70 - 2,890.79 8,042.28 58.00 178.38 6,645.64 6,596.84 1,679.01 - 2,500.37 6,005,500.40 385,499.45 4.70 - 2,862.46 Start DLS 4.63 TFO -61.10 8,078.87 58.83 176.64 6,664.80 6,616.00 1,647.87 - 2,499.02 6,005,469.25 385,500.34 4.63 - 2,837.09 Base HRZ 8,100.00 59.32 175.66 6,675.66 6,626.86 1,629.79 - 2,497.80 6,005,451.15 385,501.28 4.63 - 2,822.09 8,170.62 61.01 172.43 6,710.80 6,662.00 1,568.87 - 2,491.43 6,005,390.16 385,506.74 4.63 - 2,770.17 K -1 8,200.00 61.73 171.12 6,724.88 6,676.08 1,543.35 - 2,487.73 6,005,364.59 385,510.05 4.63 - 2,747.78 8,262.68 63.32 168.38 6,753.80 6,705.00 1,488.63 - 2,477.83 6,005,309.73 385,519.13 4.63 - 2,698.56 Top Kuparuk D 8,300.00 64.29 166.79 6,770.27 6,721.47 1,455.94 - 2,470.63 6,005,276.93 385,525.84 4.63 - 2,668.36 8,363.07 65.97 164.15 6,796.80 6,748.00 1,400.56 - 2,456.26 6,005,221.35 385,539.37 4.63 - 2,615.88 Top Kuparuk C 8,367.99 66.10 163.95 6,798.80 6,750.00 1,396.23 - 2,455.03 6,005,217.01 385,540.54 4.63 - 2,611.71 LCU - Top Nuiqsut 8,400.00 66.97 162.64 6,811.55 6,762.75 1,368.11 - 2,446.59 6,005,188.76 385,548.56 4.63 - 2,584.36 8,500.00 69.75 158.66 6,848.43 6,799.63 1,280.45 - 2,415.77 6,005,100.66 385,578.05 4.63 - 2,496.31 8,545.83 71.06 156.89 6,863.80 6,815.00 1,240.48 - 2,399.44 6,005,060.45 385,593.78 4.63 - 2,454.76 Base Nuiqsut 8,600.00 72.62 154.82 6,880.68 6,831.88 1,193.52 - 2,378.38 6,005,013.19 385,614.13 4.63 - 2,404.79 2/12/2010 10 :50 :04AM 0- r 1 # b L COMPASS 2003.16 Build 69 • ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co- ordblate Reference: Well Plan: CD3 -121 Company: ConocoPhillips(Alaska) Inc. TVD Reference: - Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Project Western North Slope ce:. ' Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Site: CD3 Fiord Pad North cue::. True Well: Plan: CD3 -121 Survey' bri-Method: - Minimum Curvature Wellbore: Plan: CD3 -121 Design: CD3- 121wp03 Planned Survey Measured Vey Map' Map Depth Inclination Azimuth Depth TVDss. +$J fel* Northing Fasting DLS Vert Section 1 (ft) (1 . (1ft - .- .ft - (ft); -- ` (ft) (ft) 6,859.29 I 8,700.00 75.56 151.10 6,908.09 6,859.29 1,107.90 - 2,334.66 6,004,926.92 385,656.56 4.63 - 2,310.40 I 8,800.00 78.56 147.48 6,930.49 6,881.69 1,024.14 - 2,284.89 6,004,842.43 385,705.06 4.63 - 2,213.75 8,900.00 81.60 143.94 6,947.71 6,898.91 942.78 - 2,229.40 6,004,760.26 385,759.32 4.63 - 2,115.48 I 8,907.54 81.83 143.68 6,948.80 6,900.00 936.76 - 2,225.00 6,004,754.17 385,763.63 4.63 - 2,108.02 Top Nechelik I 8,945.41 82.99 142.35 6,953.80 6,905.00 906.78 - 2,202.41 6,004,723.85 385,785.76 4.63 - 2,070.49 CD3- 121wp03 Heel 8,945.56 82.99 142.35 6,953.82 6,905.02 906.66 - 2,202.32 6,004,723.73 385,785.85 0.00 - 2,070.34 Start Build 1.40 - 7" x 8-3/4" 9,000.00 83.76 142.35 6,960.10 6,911.30 863.84 - 2,169.29 6,004,680.43 385,818.23 1.41 - 2,016.26 9,100.00 85.16 142.36 6,969.75 6,920.95 785.03 - 2,108.50 6,004,600.72 385,877.82 1.40 - 1,916.74 9,200.00 86.56 142.36 6,976.96 6,928.16 706.05 - 2,047.59 6,004,520.85 385,937.54 1.40 - 1,817.00 9,300.00 87.97 142.37 6,981.73 6,932.93 626.95 - 1,986.60 6,004,440.85 385,997.33 1.40 - 1,717.12 9,380.82 89.10 142.37 6,983.80 6,935.00 562.97 - 1,937.27 6,004,376.14 386,045.69 1.40 - 1,636.32 9,381.27 89.10 142.37 6,983.81 6,935.01 562.61 - 1,937.00 6,004,375.78 386,045.96 0.00 - 1,635.88 Start 5601.07 hold at 9381.27 MD 9,400.00 89.10 142.37 6,984.10 6,935.30 547.78 - 1,925.56 6,004,360.78 386,057.17 0.00 - 1,617.15 9,500.00 89.10 142.37 6,985.67 6,936.87 468.59 - 1,864.51 6,004,280.69 386,117.02 0.00 - 1,517.17 9,600.00 89.10 142.37 6,987.24 6,938.44 389.41 - 1,803.46 6,004,200.60 386,176.87 0.00 - 1,417.18 9,700.00 89.10 142.37 6,988.81 6,940.01 310.22 - 1,742.42 6,004,120.51 386,236.71 0.00 - 1,317.19 9,800.00 89.10 142.37 6,990.38 6,941.58 231.03 - 1,681.37 6,004,040.43 386,296.56 0.00 - 1,217.21 9,900.00 89.10 142.37 6,991.96 6,943.16 151.84 - 1,620.32 6,003,960.34 386,356.41 0.00 - 1,117.22 10,000.00 89.10 142.37 6,993.53 6,944.73 72.65 - 1,559.28 6,003,880.25 386,416.25 0.00 - 1,017.24 10,100.00 89.10 142.37 6,995.10 6,946.30 -6.53 - 1,498.23 6,003,800.16 386,476.10 0.00 - 917.25 10,200.00 89.10 142.37 6,996.67 6,947.87 -85.72 - 1,437.18 6,003,720.07 386,535.94 0.00 - 817.27 10,300.00 89.10 142.37 6,998.24 6,949.44 - 164.91 - 1,376.14 6,003,639.98 386,595.79 0.00 - 717.28 10,400.00 89.10 142.37 6,999.81 6,951.01 - 244.10 - 1,315.09 6,003,559.89 386,655.63 0.00 - 617.30 10,500.00 89.10 142.37 7,001.38 6,952.58 - 323.29 - 1,254.05 6,003,479.80 386,715.48 0.00 - 517.31 10,600.00 89.10 142.37 7,002.95 6,954.15 - 402.48 - 1,193.00 6,003,399.71 386,775.32 0.00 - 417.32 10,700.00 89.10 142.37 7,004.52 6,955.72 - 481.67 - 1,131.96 6,003,319.62 386,835.17 0.00 - 317.34 10,800.00 89.10 142.37 7,006.09 6,957.29 - 560.86 - 1,070.91 6,003,239.53 386,895.01 0.00 - 217.35 10,900.00 89.10 142.37 7,007.66 6,958.86 - 640.05 - 1,009.87 6,003,159.44 386,954.85 0.00 - 117.37 11,000.00 89.10 142.37 7,009.23 6,960.43 - 719.25 - 948.83 6,003,079.34 387,014.70 0.00 -17.38 11,100.00 89.10 142.37 7,010.81 6,962.01 - 798.44 - 887.78 6,002,999.25 387,074.54 0.00 82.60 11,200.00 89.10 142.37 7,012.38 6,963.58 - 877.63 - 826.74 6,002,919.16 387,134.38 0.00 182.59 11,300.00 89.10 142.37 7,013.95 6,965.15 - 956.82 - 765.70 6,002,839.07 387,194.22 0.00 282.57 11,400.00 89.10 142.37 7,015.52 6,966.72 - 1,036.01 - 704.66 6,002,758.98 387,254.07 0.00 382.56 11,500.00 89.10 142.37 7,017.09 6,968.29 - 1,115.21 - 643.62 6,002,678.88 387,313.91 0.00 482.54 11,600.00 89.10 142.38 7,018.66 6,969.86 - 1,194.40 - 582.57 6,002,598.79 387,373.75 0.00 582.53 11,700.00 89.10 142.38 7,020.23 6,971.43 - 1,273.59 - 521.53 6,002,518.70 387,433.59 0.00 682.52 11,800.00 89.10 142.38 7,021.80 6,973.00 - 1,352.78 - 460.49 6,002,438.60 387,493.43 0.00 782.50 11,900.00 89.10 142.38 7,023.37 6,974.57 - 1,431.98 - 399.45 6,002,358.51 387,553.27 0.00 882.49 11,927.19 89.10 142.38 7,023.80 6,975.00 - 1,453.51 - 382.86 6,002,336.73 387,569.54 0.00 909.67 Base Nechelik 12,000.00 89.10 142.38 7,024.94 6,976.14 - 1,511.17 - 338.41 6,002,278.42 387,613.11 0.00 982.47 2/12/2010 10 :50:04AM a e 6 1 A I COMPASS 2003.16 Build 69 I ORIbINAL , • • ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod LocaECo-oord# rate Reference: Well Plan: CD3 -121 Company: ConocoPhillips(Alaska) Inc.. Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Project: Western North Slope MDRefi rence Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Site: CD3 Fiord Pad North Roferm True Well: Plan: CD3 -121 Slimily Calo on Method: Minimum Curvature Wellbore: Plan: CD3 -121 Design: CD3- 121wp03 Planned Survey Measured Vertical. Map Map Depth Inclination Azimuth Depth _ . TYDss .. $ ;_ +EYW ' Northing Easting DLS Vert Section (ft) ( °) (1 (ft)° ft . `.{f) - - (ft) (ft) 6,977.71 I 12,100.00 89.10 142.38 7,026.51 6,977.71 - 1,590.37 - 277.37 6,002,198.32 387,672.95 0.00 1,082.46 12,200.00 89.10 142.38 7,028.09 6,979.29 - 1,669.56 - 216.33 6,002,118.23 387,732.79 0.00 1,182.44 12,300.00 89.10 142.38 7,029.66 6,980.86 - 1,748.75 - 155.29 6,002,038.13 387,792.63 0.00 1,282.43 12,400.00 89.10 142.38 7,031.23 6,982.43 - 1,827.95 -94.25 6,001,958.04 387,852.46 0.00 1,382.41 12,500.00 89.10 142.38 7,032.80 6,984.00 - 1,907.14 -33.22 6,001,877.94 387,912.30 0.00 1,482.40 12,600.00 89.10 142.38 7,034.37 6,985.57 - 1,986.34 27.82 6,001,797.85 387,972.14 0.00 1,582.39 12,700.00 89.10 142.38 7,035.94 6,987.14 - 2,065.53 88.86 6,001,717.75 388,031.98 0.00 1,682.37 12,800.00 89.10 142.38 7,037.51 6,988.71 - 2,144.73 149.90 6,001,637.66 388,091.81 0.00 1,782.36 12,900.00 89.10 142.38 7,039.08 6,990.28 - 2,223.93 210.93 6,001,557.56 388,151.65 0.00 1,882.34 13,000.00 89.10 142.38 7,040.65 6,991.85 - 2,303.12 271.97 6,001,477.46 388,211.49 0.00 1,982.33 13,100.00 89.10 142.38 7,042.23 6,993.43 - 2,382.32 333.01 6,001,397.37 388,271.32 0.00 2,082.31 13,200.00 89.10 142.38 7,043.80 6,995.00 - 2,461.51 394.04 6,001,317.27 388,331.16 0.00 2,182.30 13,300.00 89.10 142.38 7,045.37 6,996.57 - 2,540.71 455.08 6,001,237.17 388,390.99 0.00 2,282.28 13,400.00 89.10 142.38 7,046.94 6,998.14 - 2,619.91 516.12 6,001,157.08 388,450.83 0.00 2,382.27 13,500.00 89.10 142.38 7,048.51 6,999.71 - 2,699.11 577.15 6,001,076.98 388,510.66 0.00 2,482.25 13,600.00 89.10 142.38 7,050.08 7,001.28 - 2,778.30 638.19 6,000,996.88 388,570.50 0.00 2,582.24 13,700.00 89.10 142.38 7,051.65 7,002.85 - 2,857.50 699.22 6,000,916.78 388,630.33 0.00 2,682.23 13,800.00 89.10 142.38 7,053.22 7,004.42 - 2,936.70 760.26 6,000,836.68 388,690.17 0.00 2,782.21 13,900.00 89.10 142.38 7,054.79 7,005.99 - 3,015.90 821.29 6,000,756.59 388,750.00 0.00 2,882.20 14,000.00 89.10 142.38 7,056.37 7,007.57 - 3,095.10 882.32 6,000,676.49 388,809.83 0.00 2,982.18 14,100.00 89.10 142.38 7,057.94 7,009.14 - 3,174.30 943.36 6,000,596.39 388,869.67 0.00 3,082.17 14,200.00 89.10 142.38 7,059.51 7,010.71 - 3,253.50 1,004.39 6,000,516.29 388,929.50 0.00 3,182.15 1 14,300.00 89.10 142.38 7,061.08 7,012.28 - 3,332.69 1,065.42 6,000,436.19 388,989.33 0.00 3,282.14 14,400.00 89.10 142.38 7,062.65 7,013.85 - 3,411.89 1,126.45 6,000,356.09 389,049.16 0.00 3,382.12 I 14,500.00 89.10 142.38 7,064.22 7,015.42 - 3,491.09 1,187.49 6,000,275.99 389,108.99 0.00 3,482.11 I 14,600.00 89.10 142.38 7,065.79 7,016.99 - 3,570.29 1,248.52 6,000,195.89 389,168.82 0.00 3,582.09 14,700.00 89.10 142.38 7,067.36 7,018.56 - 3,649.49 1,309.55 6,000,115.79 389,228.66 0.00 3,682.08 14,800.00 89.10 142.38 7,068.94 7,020.14 - 3,728.70 1,370.58 6,000,035.69 389,288.49 0.00 3,782.07 14,900.00 89.10 142.38 7,070.51 7,021.71 - 3,807.90 1,431.61 5,999,955.59 389,348.32 0.00 3,882.05 . 14,982.25 89.10 142.38 7,071.80 • 7,023.00 - 3,873.04 1,481.81 5,999,889.70 389,397.53 0.00 3,964.29 CD3- 121wp03 Toe Targets Target Name - hit/miss target Dip Angle D.ip TVD +N /-S +E(-W Northing Easting - Shape (°) • ( (ft) . :(ft) (ft) (ft) (ft) CD3 121wp03 Heel 0.00 6,953.80 906.78 - 2,202.41 6,004,723.85 385,785.76 - plan hits target center - Circle (radius 100.00) CD3 121wp03 Toe 0.00 0.00 7,071.80 - 3,873.04 1,481.81 5,999,889.70 389,397.53 - plan hits target center - Circle (radius 100.00) 2/12/2010 10 :50 :04AM Page 7 COMPASS 2003.16 Build 69 OR Gt • i ConocoPhillips H ALL 1 B U R'TO N Standard Proposal Report Database: EDM v16 Prod local Co+ordinateReference: Well Plan: CD3 -121 Company: ConocoPhillips(Alaska) Inc. TVD ' ncd: Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Project: Western North Slope MD . _ Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19 Site: CD3 Fiord Pad R True Well: Plan: CD3 -121 Calcaladott< od: Minimum Curvature Welibore: Plan: CD3 -121 Design: CD3- 121wp03 . Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") ( ") 2,743.28 2,470.00 9 -5/8" x 12 -1/4" 9 -5/8 12 -1/4 8,945.56 6,953.82 7" x 8 -3/4" 7 8 -3/4 14,982.34 4 -1/2" x 6 -1/8" 4 -1/2 6 -1/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) ( ft Name . ...l ftttology { °) { °) 8,907.54 6,948.80 Top Nechelik I 2,760.80 2,483.80 C -30 I 6,979.22 5,908.80 Albian 96 I 6,570.92 5,558.80 Albian 97 8,367.99 6,798.80 Top Nuiqsut 3,255.71 2,873.80 C -20 8,363.07 6,796.80 Top Kuparuk C 4,736.66 4,040.80 K -3 Basal 8,262.68 6,753.80 Top Kuparuk D 8,078.87 6,664.80 Base HRZ 8,367.99 6,798.80 LCU 7,856.13 6,539.80 Top HRZ 11,927.19 7,023.80 Base Nechelik 4,905.44 4,173.80 K -2 Basal 4,550.11 3,893.80 K -3 8,545.83 6,863.80 Base Nuiqsut I 8,170.62 6,710.80 K -1 4,772.19 4,068.80 K -2 ., j Plan Annotations ... ;,V f',- Measured Vertical LOCad ... x F Cr Depth Depth , +EJ. , (ft) (ft) (ft) (ft) 'Comment 350.00 350.00 0.00 0.00 Start Build 1.50 550.09 550.00 4.54 -2.62 Start Build 2.20 I 902.90 900.00 41.12 -23.74 Start DLS 2.61 TFO -8.73 1,950.00 1,844.88 391.57 - 269.03 Start 3570.00 hold at 1950.00 MD 5,520.00 4,658.08 2,158.38 - 1,576.39 Start DLS 1.00 TFO 180.00 5,680.00 4,785.52 2,236.14 - 1,633.93 Start DLS 3.70 TFO - 130.00 7,269.45 6,136.54 2,217.37 - 2,331.50 Start DLS 4.70 TFO -80.00 8,042.28 6,645.64 1,679.01 - 2,500.37 Start DLS 4.63 TFO -61.10 8,945.56 6,953.82 906.66 - 2,202.32 Start Build 1.40 9,381.27 6,983.81 562.61 - 1,937.00 Start 5601.07 hold at 9381.27 MD 14,982.34 TD at 14982.34 2/12/2010 10:50:04AM Page 8 COMPASS 2003.16 Build 69 0 RIJ1 'AL ConocoPhillips(Alaska) Inc. -WNS `! ,,, Western North Slope 4 CD3 Fiord Pad Plan: CD3 -121 Plan: CD3 -121 F r CD3- 121wp03 III Sperry Drilling Services Clearance Summary r- Anticollision Report tti r$,, "# . 11 February, 2010 i Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) 04 Reference Design: CD3 Fiord Pad - Plan: CD3 -121 - Plan: CD3 -121 - CD3- 121wp03 Well Coordinates: 6,003,531.41 N, 1,528,006.04 E (70° 25' 08.23" N, 150° 54' 56.79" W) III <{ Datum Height: Plan: CD3 -121 (36.3 +12.5) @ 48.80ft (Doyon 19) ''';°- "' Scan Range: 0.00 to 14,982.34 ft. Measured Depth. 1 ;,: Scan Radius is 1,694.60 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 a .tY Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference i Scan Type: 25.00 HALLIBURTON 1 Sperry Drilling Services ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -121- CD3- 121wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -121 - Plan: CD3 -121 - CD3- 121wp03 Scan Range: 0.00 to 14,982.34 ft. Measured Depth. Scan Radius is 1,694.60 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad III - CD3 -109 - CD3 -109 199.19 239.59 199.19 235.46 200.00 57.928 Centre Distance Pass - Major Risk CD3 -109 - CD3 -109 - CD3 -109 422.72 241.37 422.72 232.37 425.00 26.815 Clearance Factor Pass - Major Risk CD3 -110 - CD3 -110 - CD3 -110 99.08 219.94 99.08 218.03 100.00 115.202 Centre Distance Pass - Major Risk CD3 -110 - CD3 -110 - CD3 -110 324.07 221.47 324.07 214.72 325.00 32.845 Clearance Factor Pass - Major Risk Q CD3 -111 - CD3 -111 - CD3 -111 595.51 194.31 595.51 182.08 600.00 15.888 Centre Distance Pass - Major Risk CD3 -111 - CD3 -111 - CD3 -111 620.00 194.53 620.00 181.90 625.00 15.401 Clearance Factor Pass - Major Risk CD3 -111 - CD3-111L1 - CD3-111L1 595.51 194.31 595.51 182.08 600.00 15.888 Centre Distance Pass - Major Risk G) CD3 -111 - CD3-111L1 - CD3-111L1 620.00 194.53 620.00 181.90 625.00 15.401 Clearance Factor Pass - Major Risk CD3 -112 - CD3 -112 - CD3 -112 1,884.17 45.75 1,884.17 15.17 1,925.00 1.496 Clearance Factor Pass - Major Risk CD3 -112 - CD3 -112 - CD3 -112 1,908.13 45.72 1,908.13 15.21 1,950.00 1.499 Centre Distance Pass - Major Risk CD3 -113 - CD3 -113 - CD3 -113 148.90 159.32 148.90 156.28 150.00 52.354 Centre Distance Pass - Major Risk >I' CD3 -113 - CD3 -113 - CD3 -113 496.81 161.32 496.81 150.71 500.00 15.201 Clearance Factor Pass - Major Risk CD3 -114 - CD3 -114 - CD3 -114 373.52 139.56 373.52 131.63 375.00 17.604 Centre Distance Pass - Major Risk 1 CD3 -114 - CD3 -114 - CD3 -114 838.77 143.97 838.77 125.98 850.00 8.002 Clearance Factor Pass - Major Risk CD3 -115 - CD3 -115 - CD3 -115 1,125.57 50.13 1,125.57 27.58 1,150.00 2.223 Centre Distance Pass - Major Risk CD3 -115 - CD3 -115 - CD3 -115 1,149.43 50.28 1,149.43 27.51 1,175.00 2.208 Clearance Factor Pass - Major Risk CD3 -117 - CD3 -117 - CD3 -117 789.90 62.99 789.90 45.92 800.00 3.690 Clearance Factor Pass - Major Risk • CD3 -118 - CD3 -118 - CD3 -118 868.28 33.02 868.28 16.93 875.00 2.052 Centre Distance Pass - Major Risk CD3 -118 - CD3 -118 - CD3 -118 892.50 33.09 892.50 16.53 900.00 1.999 Clearance Factor Pass - Major Risk CD3 -122 - CD3 -122 - CD3 -122 36.30 19.87 36.30 18.96 36.10 21.785 Centre Distance Pass - Major Risk CD3 -122 - CD3 -122 - CD3 -122 875.81 22.81 875.81 6.04 875.00 1.360 Clearance Factor Pass - Major Risk I CD3 -316 - CD3 -316 - CD3 -316 571.81 97.33 571.81 85.65 575.00 8.331 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316 - CD3 -316 620.61 97.69 620.61 85.20 625.00 7.824 Clearance Factor Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 571.81 97.33 571.81 85.65 575.00 8.331 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 620.61 97.69 620.61 85.20 625.00 7.824 Clearance Factor Pass - Major Risk CD3 -316 - CD3- 316APB1 - CD3- 316APB1 571.81 97.33 571.81 85.65 575.00 8.331 Centre Distance Pass - Major Risk CD3 -316 - CD3- 316APB1 - CD3- 316APB1 620.61 97.69 620.61 85.20 625.00 7.824 Clearance Factor Pass - Major Risk Plan: CD3 -119 - Plan: CD3 -119 - CD3- 119wp02 224.70 39.92 224.70 35.29 225.00 8.623 Centre Distance Pass - Major Risk 11 February, 2010 - 11:13 Page 2 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -121- CD3- 121wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -121 - Plan: CD3 -121 - CD3- 121wp03 Scan Range: 0.00 to 14,982.34 ft. Measured Depth. Scan Radius is 1,694.60 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Plan: CD3 -119 - Plan: CD3 -119 - CD3- 119wp02 499.31 42.06 499.31 31.46 500.00 3.967 Clearance Factor Pass - Major Risk Plan: CD3 -120 - Plan: CD3 -120 - CD3- 120wp03 374.86 19.83 374.86 11.95 375.00 2.514 Centre Distance Pass - Major Risk Plan: CD3 -120 - Plan: CD3 -120 - CD3- 120wp03 699.56 23.17 699.56 8.17 700.00 1.545 Clearance Factor Pass - Major Risk • Plan: CD3 -120 - Plan: CD3 -120 - CD3- 120wp02 374.66 19.83 374.66 11.95 375.00 2.515 Centre Distance Pass - Major Risk Plan: CD3 -120 - Plan: CD3 -120 - CD3- 120wp02 699.36 23.17 699.36 8.18 700.00 1.546 Clearance Factor Pass - Major Risk °- Plan: CD3 -123 - Plan: CD3 -123 - CD3- 123wp02 374.77 40.11 374.77 32.23 375.00 5.086 Centre Distance Pass - Major Risk Plan: CD3 -123 - Plan: CD3 -123 - CD3- 123wp02 650.57 42.97 650.57 29.08 650.00 3.094 Clearance Factor Pass - Major Risk ▪ Plan: CD3 -125 - Plan: CD3 -125 - CD3- 125wp02 574.50 77.02 574.50 64.78 575.00 6.289 Centre Distance Pass - Major Risk Plan: CD3 -125 - Plan: CD3 -125 - CD3- 125wp02 623.68 77.35 623.68 64.01 625.00 5.800 Clearance Factor Pass - Major Risk • -. Plan: CD3 -126 - Plan: CD3 -126 - CD3- 126wp02 550.38 100.01 550.38 88.31 550.00 8.544 Centre Distance Pass - Major Risk Plan: CD3 -126 - Plan: CD3 -126 - CD3- 126wp02 649.36 100.71 649.36 86.83 650.00 7.253 Clearance Factor Pass - Major Risk Rig: CD3 -124 - Rig: CD3 -124 - CD3 -124 RigSurveys 36.30 59.94 36.30 59.02 36.30 65.721 Centre Distance Pass - Major Risk Rig: CD3 -124 - Rig: CD3 -124 - CD3 -124 RigSurveys 500.71 64.07 500.71 53.39 500.00 6.001 Clearance Factor Pass - Major Risk Rig: CD3 -124 - Rig: CD3 -124 - CD3- 124wp04 425.32 59.82 425.32 50.79 425.00 6.625 Centre Distance Pass - Major Risk Rig: CD3 -124 - Rig: CD3 -124 - CD3- 124wp04 525.65 60.98 525.65 49.78 525.00 5.442 Clearance Factor Pass - Major Risk Survey tool program • From To Survey /Plan Survey Tool (ft) (ft) 36.30 1,000.00 CD3- 121wp03 CB- GYRO -SS 1,000.00 14,981.79 CD3- 121wp03 MWD +IFR- AK- CAZ -SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 11 February, 2010 - 11:13 Page 3 of 5 COMPASS GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:25, February 11 2010 CD3- 121wpO3 Ellipsoid Color 36.30 To 14982.34 36 250 1750 " 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 "" " " " " "` "' "` 1000 3500 4250 14250 16250 24000 24500 300 1000 -- 1250 4250 5250 16250 18250 1250 1500 5250 6250 18250 19750 30 / 3111111 30 1500 1750 6250 7750 19750 21250 Ai t CD3- 119wp02 �-� CD3 -112 7� / - 200 CD3-120 6 CD3- 120wp03 60/30�� _ ` ' / CD3 -111L1 0/360 / OPsalt04k � ICD3 -111 30 / 330 f 30 CD3- 120wp03 i CD3- 120wp02 t vim-F.44 ��,, � ... r rCD3 -110j f �ullllllll`' CD3 � 1 1 -10� 60 / 300 r � � . s � � � ��� ��������1���ki�— ": CD3- 119wp02 -90 / 271 : � -�. -- I �� // ' �,9 � / 90 :,,,: '-, •� �� ..;.„. tip. , � -90 / 270 _— , -- � l , q A` � . . 90 s 1111 ut tht�� / / / /��t �� . 1 _ ice', ,,� v,t �,,,, �tt,;t��v�\ /, /�,� o ✓ v i ` i,.. [[i �tl[ y y��r1V 1 111 � / t �4r � + a , � �,. i � V\ r An � r VIVO � filI� �1 �' � ,A•47 ." ♦ _ < ■ \ 9 � ��, \ < Ate` i� IH,,i i � � , l e 'r =�..' A O ., c. i i V t;.".• ' � - 4 e m,, - ,• CD3- 123wp02 \ _ y � y ,, -120 / 240 iii�� 0. .,,, , ws " " . ' m i, 4�► \ 120 ' is ���; p , 41 ,44. 4 , • . 1r � 0$ . , • ♦ ., /� �/ ��. -b, \ 'h 120 / 240 . .-'' i I •11 120 vI `` , ��� • / � �! % >r � `NCI / �� �. � ` • � C D3 -113 �� �ir►���I��I / �d l /P�:i '� CD3- 123wp02 �� �� er � � � �� � �� � i L �� \�S _` _ CD3- 316AP61 ��'�/ [� � ��d� �w�� �" I u ►� a a r � Asp► e, t r r. t I 00 ,, ,c,_. , 3 o�I ,� ► � s l ∎4 0 . , o ,1 .- .. r ep ' -' =� 0 t s s ' r F∎ � �. I CD3 -316A -150 / 210 1 ��p� 1 ' 1 1?�� 1 4 C�4.y 150 CD3 -124 RigSurveys - 150 „ „ „< � ♦ 150' 444 ,f r �� – CD3 -112 °:"� i ' .. , CD3 -316 CD3 -122 -180 / 180 CD3- 124wp04 t 3& CD3- 125wp02 180 / 180 CD3 -118 CD3 -118 CD3- 126wp02 CD3 -117 CD3 -114 CD3 -115 CD3 -122 Travelling Cylinder Azimuth (TFO+AZI) [1 vs Centre to Centre Separation [25 ft/in] Easting (3000 ft/in) m i l ,,, Hi, il m i1 ii 11m I1 miIliil1 i,ill m l ,,,I m i1m Him 11 1 I 111 1 1 1I.1 . 1.1m 11:24, February 11 2010 r C D3- 126wp02 CD3 - 109 CD3- 125wp02 - - CD3 -110 CD3-111L1 - CD3 -111 - - CD3 -112 - - CD3 -113 • - CD3 -114 ---r - Z o —o - CD3 -118 CD3 -115 s = 3 um w rn —o co = CD3- 124wp04 CD3 -117 _ a i Z- - ��- r - CD3- 316AP _ i _ ' � / - ':�4 RigSurveys - C D3 -316 CD3 -3 FFrA /' �_�' CD3- 120wp08 C D3- 119wp02 CD3- 121wp03 - ConocoPhillips(Alaska) Inc. -WNS — = Western North Slope - CD3 -122 = CD3 Fiord Pad - CD3- 123wp02 - I I 1 1 1 I l I I 1 1 1 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 I 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Easting (3000 ft/in) • • HALLIBURTON Conoc CD3 -121 wp03 Alaska Sperry Drilling ANTI- COLLISION SETTINGS 11:19, February 11 2010 Interpolation Method: MD, interval: 25.00 Depth Range From: 36.30 To 14982.34 Results Limited By: Centre Distance: 1694.60 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey /Plan Tool 36.30 1000.00 CD3- 121wp03 (Plan: CD3 -121) CB- GYRO -SS 1000.00 14981.79 CD3- 121wp03 (Plan: CD3 -121) MWD +IFR- AK- CAZ -SC CASING DETAILS TVD MD Name Size 2470.00 2743.28 9 -5/8" x 12 -1/4" 9 -5/8 6953.80 8945.56 7" x 8 -3/4" 7 7071.78 14982.34 4 -1/2" x 6 -1/8" 4 -1/2 FP N OW 3 4 3 9 3 3 N 0 0] moo O 0 0 O 0 0 0 U W U U U U U V 0 U U � irr,,,,, ,,k,H, , � rI� ` p 60 - - .,. -- _ " "1 :!mil loilL11 1 1 101151III�IIIII R.of I ___.... t-,,,,-. • iu:ullll� lim i �opo I!� r Pr ; l l ` 0 11 1,16,14'' � 1 11 r . 11 iillllll l l �ll i . riil1 I 0 - spa. = 11 �I_ 1 -i 1 0 iii i 1 1 1 I � I I I 1 1 T 1 I I I 1 I f I ; I I 1 1111 1 1 0 400 800 1200 1600 2000 2400 2800 Measured Depth LEGEND -0- Plan', CD3 -120, Plan: CD3 -120, CD3- 120wp02 VC X( CD3 -113, CO3 -113, CD3 -113 V6 -A- CD3 -316, CD3 -316, CD3 -316 VO -X- Plan: CD3 -125, Plan: CD3 -125, CD3- 125wp02 VO I ', -X- CD3 -109, CD3 -109, CD3 -109 V5 - CD3 -114, CD3 -114, CD3 -114 V14 -EH CO3 -316, CD3 -316A, CD3 -316A V0 -e-- Plan: CD3 -126, Plan: CD3 -126, CD3- 126wp02 VO i,. $ - CD3 -110, CD3 -110, CD3 -110 V12 -0- CD3 -115, CD3 -115, CD3 -115 VO CD3 -316, CD3- 316APB1, CD3- 316APB1 VO -4-- Rig: CD3 -124, Rig: CD3 -124, CD3 -124 RigSurveys VO -4- CD3 -111, CD3 -111, CD3 -111 V7 -13_ CD3 -117, CD3 -117, CD3 -117 VO -$- Plan: CD3 -119, Plan: CD3 -119, CD3- 119wp02 VO--B- Rig: CD3 -124, Rig: CD3 -124, CD3- 124wp04 VO - CD3 -111, CD3- 111L1, CD3 -111L1 V1 _e_ CD3 -118, CD3 -118, CD3 -118 VO -e_ Plan: CD3 -120, Plan: CD3 -120, CD3- 120wp03 V0-8- CD3- 121wp03 - CD3 -112, CD3 -112, CD3 -112 V3 -A- CD3 -122, CD3 -122, CD3 -122 VO -0- Plan: CD3 -123, Plan: CD3 -123, CD3- 123wp02 VO ORGIN GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:27, February 11 2010 . CD3- 121wp03 Ellipsoid Color 36.30 To 500.00 36 250 1750 2250 7750 9250 21250 22250 250 500 2250 " " " " "" 2750 9250 11750 22250 -- 23250 500 750 2750 3500 11750 " " " " " " " " " " " " " " " "" 14250 23250 24000 0 / 360 750 --- -" 1000 3500 4250 14250 16250 24000 24500 300 1000 1250 4250 5250 16250 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 7750 19750 21250 a p 200 • -60 / 300 60 . 0/ / 50 - -30 / 330 30 10 0 CD3 -112 CD3- 'wp02 1-o = ''� i i )9 3 -111 1_ CD3- 120wp03 +;:' D3- 113� ! 11 s-' -60 / 300 25 60 90 / 270 ■c` ' CD3 316A 90 CD3- 120wp02 � CD3-119wp02 _ • 1 � � D3 -124 ' S ��' 23vp ,� � CD3 -11i1 �� \ ! - UM [D3 -316 I GD3- 124wp04 D3 -115 90 / 270 �`� \ \'�'/ 90 CD3 -!�' 7A _•1IT51�r CD3 -123w. r:� ` ,k Imo. -120 / 240 120 -120 / 240 CD3 -122 120 III 201 - 150/210 150 - 150/210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:27, February 11 2010 CO3- 121wp03 Ellipsoid Color 500.00 To 1000.00 36 -_ 250 1750 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 - --- 1000 3500 4250 14250 16250 24000 24500 300 1000 1250 4250 5250 16250 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 7750 19750 21250 200 -60 / 300 60 0 / 360 50 D -30 / 330 D3 -1 � % t1 ;^� 101 C D3- 44 'V 1'11 0 CD3- 110 �►7/ � k �•, �'4L 1 1r \\ \,. . , t� ` 17iii iii '—'- :�: ���� CD3- 119wp0o _ _ _ . �1 li ^ ty Flo r r� ' �:j ,! �!! : ! / /� P 1 CD3 - 109 -60 / 300 * \ \ \l 0/ 270 �� i i �-4 w A� l CD3 113 7r� 1`� CD3123 k � No _ ,� .�" +r3 ...ta r LCD3-1m 90 / 270 \ \ ,. / � �� =`� 90 Su s * �1]' I , _ , � � ��'� 9 Y �� o 1 11", ' 0 i�� � CD3 -124 RigSu ! CD3 316APB1] � � /� ��� / il ls „Ilk ���° r /GPI r \ ` ► / _ ` �`- CD3- 124wpI4 ' ffie Iia.1 1CD3 -316A1 CD3- 123wp02 • ,i „: i i l l �� / � r' 14. CD3 -117 `� � .��� i� �po / 120 / 240 ` _ 120 �� >' „� �� � ��� CD3 -316 -120 / 240 / 120 200 �_125wp02 /l CD3 126wp02 rrr�i ` ��� - 150/210 150 -150 / 210 150 0 -180 / 180 _ 300 CD3 -118 -180/ 180 1 Travelling Cylinder Azimuth (TFO+AZI) [O] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:28, February 11 2010 1 CD3- 121wp03 Ellipsoid Color 1000.00 To 1500.00 36 250 1750 2250 7750 _ 9250 21250 22250 250 500 2250 2750 9250 11750 22250 — - 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 " — 1000 3500 4250 14250 16250 24000 24500 300 1000 — — 1250 4250 5250 16250 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 7750 19750 21250 200 III CD3- 119wp02 CD3- 120wp03 60 / 300 60 0 / 360 CD3- 120wp02 %.,��� Cy ► f ' 30, 121.*" \I\iit /`i 30/330 i I. � 10 .�n ,11 11,. f C 13 -111, j& G) = F(((lit .F -60 / 300 1`�� � 60 ACC -- 9 0 / 270 � � � r 90 � ""r•..... —.. i 1 ` ♦ ` ` ` �� b 4. r illiriL )1_ ; ` „till " a111, 90 / 270 �!� 90 CD3 -123 . ► � � j ► hN .�, �.� v.v., ♦1 ♦ A� • i ♦ � r�� \� r �wf'�bi�. I�,��r ����i\ rj�Q i '- if-fv r• V G� °G \+fir ♦Vr %1 r:• ++ ++ �//-� 120 / 240 . r it + rI r� G. ira y �G ®3 -113 N.A♦ +gam �,/� r � v►�1�aO► i . \1�� • `i / yam+ ++ ,. �'..V �i �,��11► ���►�`i ►�,�,�� %�►�! =r-� � ♦� rte \� � ► r L V,A. ■, ", 4 4 • + t �j 0 1s' p�� -120 / 240 �� ga 11. i r , // ,• 120 110 1 r. n' +e 4 •` ► .Rei ) -;,,i,4 ►� *Va y1� � `rf r- „ra�j�� i � �,. �!�.` .A\ •r• ■ 1110 � 1∎0 1� -`,� i�d w\ CD3- 316APB1 11 ∎•14 ,, ¢:, I �Af�, � �I%„Li � �� "�� i Abe �� %Oi��� -m�ii CD3 316A -150 / 2 10 �i;�A r,4 ` ,. 150 CD3 -124 RigSurveys -15i021 . � ; , ,: .�����; ` r- • 150 `�i tyi�,,. � , ' 1 Oi !, ,'�r moor CD3 -316 CD3 -122 -180 / 180 CD3- 124wp04 300 -180 / 180 CD3- 125wp02 CD3 -118 CD3- 126wp02 CD3 -117 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation 125 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:28, February 11 2010 . CD3- 121wp03 Ellipsoid Color 1500.00 To 2000.00 36 250 1750 '" 2250 7750 9250 21250 22250 250 500 2250 " " " " "" 2750 9250 11750 22250 — 23250 500 750 2750 3500 11750 " " " " " " " " "" "" 14250 23250 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 24500 300 1000 — -- 1250 4250 5250 16250 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 - 7750 19750 21250 CD3- 119wp02 200 CD3- 120wp02 �� • K2 120wp03 -60 / 300 �� 60 0 / 360 \K CD3- 111L11 50� .� r. CD3 -111 30 / 330 , ��30 -60 / 300 60 IP ANION .E 112 1 90 -90 / 270 Ng* " pp' �� i 1 w -90 / 270 / /�� 1 P, 120 / 240 / SW r �, '411114 c 11, i .. t bl y i 1 20 110 'i�9'r'! -120 / 240 \ 120 ' \ 1 4 1,r ' •fi r i ii CD3 -113 �� �,f Nor, 20 l II Nor / , i j -150 / 210 150 CD3 -112 -150 / 211 l ' ! 150 ilikb- ■ v - 180/180 CD3-118 -180 / 180 CD3 -122 CD3 - 114 CD3 - 115 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:29, February 11 2010 CO3- 121wp03 Ellipsoid Color 2000.00 To 2500.00 36 - 250 1750 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 - 24500 300 1000 1250 4250 "" " "" 5250 16250 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 7750 19750 21250 200 CD3- 120wp02 D -60 / 300 •D3- 120wp03 `� 60 0 / 360 . J �� \ 5 0 �/ / "� �� (..: 30 / 330 30 -60 / 300 60 90/270 90 i ::?.r -90 / 270 90 CD3 -112 ` r * -120 /240 ....ii , 120 -120 / 240 120 200 O 0 �� 150 : Gas It - 150 /210 ;G����r 150 /21 I►��.ili; 150 I � -.4414/f -180 / 180 �'/ 300 - 180/180 CD3 -122 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft /in] I GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:29, February 11 2010 CD3- 121wp03 Ellipsoid Color 2500.00 To 3000.00 36 250 1750 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 `- 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 ` 1000 3500 4250 14250 16250 24000 "-""` 24500 300 1000 1250 4250 5250 16250 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 7750 19750 21250 200 CD3- 120wp1• • 60 / 300 60 CD CD3- 120wpo i I-2) I 0/ 360 / (111 iIIIi I , 30 / 330 50 I ii���r 30 101 , A � % ' I V J `,� „i,i �� �i�i ,--",;/, -60 / 300 60 0 / 270 / 90 Ill -90 / 270 \\,\ 90 11 -120 / 240 "72,� 120 Mil I ° -120 / 240 120 CD3 - 112% -\1 '' ) 0 - 150/210 150 -150 / 210 150 50 300 -180 /180 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:30, February 11 2010 CD3 121wp03 Ellipsoid Color 3000.00 To 4000.00 36 250 1750 "- "- --- 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 — 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 " " " " " " " " "" "" 1000 3500 4250 14250 16250 24000 " " " " "" "" " " "" " 24500 300 1000 "— "" 1250 4250 5250 16250 _ 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 7750 19750 21250 I CD3- 120wp02 200 -60 / 300 �, ‘ 60 �� d �I /l��lj�ll��� ' � 0 / 360 3 All 10 r 30 / 330 30 �� ��� [ -60 / 300 60 -- 7 Aii 1 f __,______2„.„,_.„„ ., .... -90 /270 �� so gl D3 -120w 03 90 / 270 p f ((( 90 p -120 / 240 120 -120 / 240 120 r•-•—••■■■�� � 200 / � 150 / 210 150 -150 / 21 f ,' 150 50 4. %f: yam: -180 / 180 'f 4; 300 -180 / 180 CD3 -112 Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:31, February 11 2010 CD3 -121 wp03 Ellipsoid Color 4000.00 To 5000.00 36 250 1750 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 — 24500 300 1000 1250 4250 5250 16250 18250 1250 1500 5250 6250 18250 19750 -30 / 330 30 1500 1750 6250 7750 19750 21250 200 sJ , 1: \ 4 -60 / 300 �� /� / 60 0 / 360 -30 / 330 50 30 0 '`�� 60 / 300 60 o % j' $ ! ! " D0p1 > ‘--. ' •%,, .,; ilk -120 / 240 120 i -120 /240 \ 120 20• -150 / 210 150 -150 / 210 150 50 - 180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:32, February 11 2010 . CD3- 121wp03 Ellipsoid Color 5000.00 To 6000.00 36 250 1750 " 2250 7750 9250 21250 22250 250 500 2250 " " "` " " " " "' "' 2750 9250 11750 22250 23250 500 750 2750 3500 11750 " " " " " " " " "`" 14250 23250 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 — 24500 300 1000 1250 4250 5250 16250 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 7750 19750 21250 200 -60 / 300 60 0 / 360 50 -30 / 330 30 11 r 10. _........,...„,, -60 / 300 60 i -90 / 270 —) 90 O Ali , -90 / 270 90 W d3- 120wp03 -120 / 240 " % 120 -120 / 240 120 200 IF' - 150/210 150 -150 /210 150 50 -180 /180 300 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft /in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:32, February 11 2010 . CD3 -121 wp03 Ellipsoid Color 6000.00 To 7000.00 36 250 1750 2250 7750 - 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 24500 300 1000 1250 4250 " "" 5250 16250 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 7750 19750 21250 200 �X ° 4111 , OIL -60 / 300 / i 60 ; ilam 0 / 360 f���� % ii� - _ _ 50 YO.: � /- CD3- 120wp03� -30 / 330 30 D AI 10 . iI 4. ii ,,,,•: op. 5$ -90 / 270 i 1 �' 1 �� � 90 60 / 30 60 ... r -90 / 270 90 -120 / 240 120 -120 / ii150 120 200 Ill" • 150 -150 / 216 150 50 - 180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:32, February 11 2010 CD3- 121wpO3 Ellipsoid Color 7000.00 To 8000.00 36 250 1750 2250 7750 "' 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 ° " " " " "" " " "` "" 14250 23250 24000 0 / 360 750 " " " " " " " " "" "" 1000 3500 4250 14250 16250 24000 " " "" " " " "" " " "" 24500 300 1000 -- 4250 5250 16250 18250 1250 1500 5250 6250 18250 19750 30 / 3 1.11 30 1500 1750 6250 — 7750 19750 21250 CD3 -112 � �.200 -60 / 300 .� 60 0 / 360 � ..♦ � \ 50 � �1\ -30 / 330 30 L �1 1 10. 1 Kw" f III. ∎∎ 60 / 300 60 -90 / 270� niPAI■11 � 90 �� 1����1 -90 / 270 90 -120/240* � ��►'� 120 Mr �� �� ►���� -120 / 240 120 �'-� 200 i�����41 -150 / 210 150 150 / 21 r ''. : : 111 1 300 150 -180 5 180 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ °1 vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:33, February 11 2010 CD3- 121wp03 Ellipsoid Color 8000.00 To 14982.34 36 250 1750 -___" 2250 7750 — 9250 21250 22250 250 500 2250 ' "" 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 — 1000 3500 4250 14250 16250 24000 24500 300 - 1000 1250 4250 5250 16250 "" 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 7750 19750 21250 200 -60 / 300 60 0 / 360 50 J _ 10. -30 / 330 30 -60 / 300 60 .� -90 / 270 — 90 Ali -90 / 270 90 111 -120 / 240 120 - 120 /240 120 20I - 150/210 150 - 150/216 150 e -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] COtlOCi PIIl lips WELLBORE TARGET DETAILS (MAP CO-ORDINATES) C D 3 121 w p 0 3 Name CD3- 1210p03 Toe TVDSS +N / -S +E/ -W Northing Easfi Shape 7023.00 - 3872.88 1482.115999636.981529429.54 54 Circle (Radius: 100.00) HJ L.LJE.BUR i`Ct CD3-121wp03 Toe Circle 7023.00 -3872.88 1482.115999636.981529429.54 Circle (Radius: 1320.00) Quarter Mile View 13:47, February 11 2010 ry 11 e`1 11� ,�p G�3113 GQ� ^� C�3. �,�+‘�� �6��9SJ� GD _ - 0319 Gp��o G � 3 CD3-1 A . °7 a'O� C� 03'3 4000 vii, ru,,,,, °� 11 .0 40 • A� VD 7 2000 c 1 Iii \ / CD ., O _�Q „ — CO N 0 - � i .__ le i ` N ^ 2000 g h 1 � � 1 r.,,,,---0. • ! O ^ 3 ^1� I V a GQ� G� .3o, -4000 - 1 -6000 r -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 West( -) /East( +) (2000 ft /in) DDet da: ConocoPnipu(Almkaloc. -NNS b1OCa,oction: -026 ° bENa MN /A I � ISeld western Nate Slope Akq.NkDocb,dIon: 2122 ° AR Nat MN /A Wei CD3- 111wp03 00 6026 ° ANN* MN /A RI% MN /A DoySD Mt 100 ft Sya.n (NW x.r.nca Mon Swlsvd Sottssloodbn Original VS Plane: 142.00 ° Pace Ws! ow:CW.121 X 151800604 n View VS Plane: 142.00 ° k[.IWSet: 4880 M '.. 0: 600353141 ft Unll 5y9.m: API BM. /IPS 5.dbn (05) 4Mt.nca slot Comments: POOL: PP" ViBw a o 0 0 0 0 o a ° S o § § § O h h N O 2 Q N h 2 2 2 2 2 CD3- 121wp03 Plan: 8945' to 14982.34' MD t CD3 -122: 9130' to 15408' MD — — c.- -- - - -- 6013000 CD3 -112: 8572' to 16021' MD _ _ 6012000 CD3 -113: 9364' to 17338' MD � ,$ - - - -- - -- - - -- o 6011000 CD3 -111: 8659' to 15073' MD — ___ - -_ -_- - __ - - -- . —. _____ - 6010000 _ . -_ ____. —__. 6009000 • N € a' - __--- __ —_._ , 6008000 .\. s. , • 6007000 € ii 0 Z — _ -___, -- ________- • — 6006000 ,.I.. Ak1� ' - - - 6005000 11 —*— CD3- 121wp03 Plan — CD3 -122 CD3 -112 1�1, !! /���V /// Section View -__ - 14111111111% . ► ... —__ 6004000 —s— CD3-113 CD3 -111 lip _ jj — __� - = 6003000 - _- _- __ -_____ 6002000 f --- ----- ----- -- - L -- _ - . _ .. ° 6001000 i 1(f _ ._ -- -- -- -- - 6000000 - _ -. - - _ _ - 5999000 - -- - -- - ----- - --- 5998000 — — — - -- ' 5997000 r ro East ( +) / West ( -) • D t N N 2 i . E i lly , N -- - - - ---- --- --- - - - --- - -- --- --- - --- --- --- —_ - 6500 " - - . - - - - - - - - 1 7500 Vert ical Section along View VS Plane' Combo Preview Page 1 of 1 (CD3- 121wp03 Toolboxlds) 2/12/2010 10:13 AM Closest in POOL Closest Ppproach: Reference Well: CD3- 121wp03 Plan Offset Well: CD3 -122 Coords. - Coords. - ASP ASP 3 - D ctr - ctr Meas. Incl. TRUE Subsea N( +)/S( -) View VS Meas. Incl. TRUE Subsea N( +)/S( -) View VS Distance. Depth Angle Azi. TVD E( +) /W(- (142) Comments Depth Angle Azi. TVD E( +) /W(- (142) Comments PUUL Min PUUL Min Distance (2045.52 Distance (2045.52 ft) in POOL (8945 - ft) in POOL (8945 - 14982.34 MD) to 14982.34 MD) to CD3 -122 (9130 - CD3- 121wp03 Plan 2045.5 - - 9125 85.51 142.37 6922.97 6004328 1525924 - 1891.85 15408 MD) 9105.02 86.29 162.29 6907.92 6003107 1524283 - 1990.82 (9130 - 15408 MD) Closest Approach: Reference Well: CD3- 121wp03 Plan Offset Well: CD3 -112 • Coords. - Coords. - ASP ASP 3 - D ctr - ctr Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +)/S( - View VS Distance. Depth Angle Azi. TVD E( +) /W(- (142) Comments Depth Angle Azi. TVD E( + ) /W(- (142) Comments - T PUUL Mn POOL Min Distance (2224.05 Distance (2224.05 -...- ,N• ft) in POOL (8945 - ft) in POOL (8945 - w�,�. 14982.34 MD) to 14982.34 MD) to [�^^^ CD3.112 (8572 - CD3 121wp03 Plan 16021 M 2224.1 -- - - 8945.56 83 142.37 6905.01 6004471 1525817 - 2070.37 8547.58 85.87 321.63 6869.66 6006405 1524720 - 4347.82 ( 8572 - 16021 MD) Closest Ppproach: Reference Well: CD3- 121wp03 Plan Offset Well: CD3 -113 Coords. - Coords. - m -j- ASP ASP "°°"" 3-D ctr - ctr . . . Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. . . ' Depth Angle Azi. TVD E( +) /W( (142) Comments Depth Angle Azi. TVD E( +) /W(- (142) Comments FOUL Mn PUUL Min Distance (2849.27 Distance (2849.27 ft) in POOL (8945 - ft) in POOL (8945 - 14982.34 MD) to 14982.34 MD) to CD3 -113 (9364 - CD3- 121wp03 Plan 2849.3 8945.56 83 142.37 6905.01 6004471 1525817 - 2070.37 17338 MD) 9339 83.77 328.33 6857.67 6005057 1523029 - 4285.46 (9364 - 17338 MD) • Closest Approach: Reference Well: CD3- 121wp03 Plan Offset Well: CD3 -111 Coords. - ASP ASP 3 - D ctr Meas. Incl. TRUE Subsea N( + /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. Depth Angle Azi. TVD E( +) /W( (142) Comments Depth Angle Azi. TVD E( +) /W( (142) - Comments PUUL Mn PUUL Min Distance (3354.81 Distance (3354.81 ft) in POOL (8945 - ft) in POOL (8945 - 14982.34 MD) to 14982.34 MD) to CD3 -111 (8659 - CD3- l21wp03 Plan 3354.8 8945.56 83 142.37 6905.01 6004471 1525817 - 2070.37 15073 MD) 8634.91 83.71 329.3 6880.25 6007793 1526284 - 4519.29 (8659 - 15073 MD) PoolSummaryl 2/12/2010 10:25 AM I Surface rface Location: ra CPAI Coordinate Converter . ' From: . To: Datum: INAD83 Region: alaska Datum: INAD27 Region: �alaska Latitude /Longitude Decimal Degrees (` Latitude /Longitude 'Decimal Degrees UTM Zone: r South i UTM Zone: 'True r South C. State Plane Zone: 4 Units: :us-ft . +'" State Plane Zone: True . Units: us-ft + 1 Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 11528006.04 Township: 1012 - N Range: 005 E X6003531.41 Meridian: U . Section:15 FNL .1 13993.3925 IFEL • 11068.8786 • I Transform j Quit I Help CD3 121wp03 Intermediate Casing Point: i :P 4: ao1 dinate t :onverter i ; wil X; From. To 1 Datum: INAD83 d Region: Jalaska .j Datum: NAD27 ■ Region: Jalaska r Latitude /Longitude Decimal Degrees _:_J °` Latitude /Longitude 'Decimal Degrees ;=.! x ( UTM Zone: t r South '' UTM Zone: True r South ';" State Plane Zone: 4 Units: us ft State Plane Zone: True . Units: us-ft C .+- Legal Description (NAD27 only) Starting Coordinates: _ Legal Description X: 11525817.64 Township: 1012 N E. Range: 005 E • Y: 6004470.96 Meridian: U Section :15 JFNL ■1 13086.9248 141 7 13268.5827 Transform I Quit I Help ORIGINAL I • CD3- 121wp03 Toe /TD: CPA! Coordinate Converter Lmj From: To: Datum: INAD83 Region: )alaska Datum: INAD27 .1 Region: Jalaska Latitude /Longitude 'Decimal Degrees Latitude /Longitude 'Decimal Degrees UTM Zone: j South C UTM Zone: ;True r South fi+ State Plane Zone: 4 . Units: 5:;s-TEE r- State Plane Zone: true + Units: yusft .) Legal Description (NAD27 only) - Starting Coordinates: _ Legal Description 1529429.54 Township: 012 N Range: 005 E Y: 15999636.9$ Meridian: 7 Section :19 FNL 12586.2980 IFEL •, 14878.5740 Transform Quit I Help tk OR REV DATE BY CK APP • DESCRIPTION REV DATE BY APP DESCRIPTION 5 4/8/07 AG DB C.A. UPDATED PER K07041ACS 6 4/13/09 AG DB C.A. UPDATED PER K090003ACS N i, \. ``\\ `' ' -RO , _S- .� ' � ,. A`w ` � If .._r i_ Ail \ � , 1 r � — / DL re' — . dLPtfd�- f -i Ptuto " c.' , `'� G o`' �� % C ' y y ' - LOCATION OF ./ C�', `. _, ,` ..1- . THIS SURVEY . ' � s; a� , z z • 12N" lt. i' T71 N ALPINE SATELLITE DEVELOPMENT ; VICINITY MAP NOT TO SCALE AND pE51GN SHOULDER OF CD-3 PAD .. i , X 0,..0111C10,4 -,,,Nl e S T PNo o0 M,x `o r o o " cA i • _ - ii � �'1S MOD 2 ��� p,TR `t/ �rrP)'�� NE F kA oGG 'u E S PLANT 001111 NG'< ASPC E O 61pRTE RS N 13'00'00" w w In ) LCMF LEGEND: ,, r 0 z O PROPOSED CONDUCTOR . w �° z z N ON • EXISTING CONDUCTOR -n ° N9 v O m 0 0 0 0 U U w W __ KUUKPIK LCMFI� N N - 130667etAve. • A,C:ttepe.Aee*e 6850. (607)27341830 (82,18 0080 (W7-1722 Alpine Survey Office IV.' ALPINE MODULE: CD30 UNIT: CD Conoc.PhIII1ps CD -3 ALPINE WELL CONDUCTORS Alaska, Inc. AS —BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03 -03 -1A 11/3/05 E- D30 -111 1 OF 3 6 0 nrritii/1 Y L.. 1-a, I o 1 4 '';' ,, L REV DATE BY CK APP I DESCRIPTION REV DATE BY 41. APP DESCRIPTION 6 4/8/07 AG DB C.A. ISSUED PER K07041ACS 7 4/13/09 AG DB C.A. UPDATED PER K090003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. SEC.LINE 0/S EXIST WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CD3 -X98 6,003,630.37 ,528,434.35 70' 25' 09.267" 150' 54' 44.278" 1392' 642' 7.3 12.5 CD3 -X99 6,003,625.99 ,528,415.38 70' 25' 09.221" 150° 54' 44.833" 1387' 661' 7.3 12.8 003 -301 6,003,621.33 ,528,395.58 70' 25' 09.172" 150' 54' 45.411" 1382' 680' 7.3 13.5 003 -302 6,003,616.72 ,528,376.38 70' 25' 09.124" 150' 54' 45.972" 1377' 700' 7.3 13.2 CD3 -303 6,003,612.52 ,528,356.72 70' 25' 09.080" 150' 54' 46.547" 1373' 719' 7.3 13.3 CD3 -304 6,003,607.82 ,528,337.04 70' 25' 09.031" 150' 54' 47.122" _ 1368' 739' 7.3 13.4 CD3 -305 6,003,603.48 ,528,317.56 70' 25' 08.985" 150' 54' 47.691" 1363' 758' 7.3 13.6 003 -106 6,003,599.43 ,528,298.37 70' 25' 08.942" _ 150' 54' 48.252" 1359' 777' 7.3 13.4 003 -107 6,003,594.38 ,528,278.93 70' 25' 08.890" 150' 54' 48.820" 1354' 797' 7.3 13.2 CD3 -108 6,003,589.85 ,528,259.61 70' 25' 08.842" 150' 54 49.385" 1349' 816' 7.3 13.1 003 -109 6,003,585.27 ,528,239.85 70' 25' 08.794" 150' 54' 49.962" 1344' 836' 7.3 13.1 CD3 -110 6,003,580.97 ,528,220.32 70' 25' 08.749" 150' 54' 50.533" 1339' 855' 7.3 13.0 CD3 -111 6,003,576.13 _ ,528,201.08 70' 25' 08.699" 150' 54' 51.095" 1334' 874' 7.3 12.9 CD3 -112 6,003,572.43 ,528,181.20 70' 25' 08.660" 150° 54' 51.676" 1330' 894' 7.3 13.1 003 -113 6,003,567.62 ,528,161.38 70' 25' 08.609" 150' 54' 52.255" 1325' 914' 7.3 13.1 CD3 -114 6,003,563.04 ,528,142.21 70' 25' 08.561" 150° 54' 52.815" 1320' 933' 7.3 13.3 CD3 -115 6,003,558.57 ,528,122.60 70' 25' 08.515" 150° 54' 53.388" 1315' 953' 7.3 13.2 0D3 -116 6,003,554.04 ,528,103.39 70' 25' 08.467" 150° 54' 53.950" 1311' 972' 7.3 13.2 0D3 -117 6,003,549.51 ,528,083.99 70' 25' 08.420" 150' 54' 54.516" 1306' 991' 7.3 13.1 0D3 -X18 6,003,544.88 ,528,064.44 70' 25' 08.372" 150° 54' 55.086" 1301' 1011' 7.3 12.8 CD3 -X19 6,003,540.17 ,528,044.86 70' 25' 08.322" 150' 54' 55.660" 1296' 1030' 7.3 12.8 1CD3 -X211 6.003,531.41 . 70' Z5' 5' 25' '' 1 54' 56.7941286' 1069' 7.3 12.5 . CD3 -X22 6,003,527.00 ,527,986.67 70' 25' 08.184" 150° 54' 57.360" 1282' 1088' 7.3 12.6 CD3 -X23 6,003,522.43 .527,967.12 70' 25' 08.136" 150° 54' 57.932" 1277' 1108' 7.3 12.6 0D3 -X24 6,003,518.17 ,527,947.59 _ 70° 25' 08.091" 150' 54' 58.502" 1272' 1127' 7.3 12.5 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) �✓ ALPINE MODULE: CD30 UNIT: CD ConocoPhillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03- 03 -1A -2 3 -17 -05 CE -CD30 - 111 2 OF 3 7 REV DATE BY CK APP • DESCRIPTION REV DATE BY APP DESCRIPTION 4 4/8/07 AG DB C.A. ISSUED PER K07041ACS 5 4/13/09 AG DB C.A. UPDATED PER K090003ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD -3 GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK /LCMF, MARCH 2005 4. DATES OF AS -BUILT SURVEYS: WELL CONDUCTORS CD3 -108, CD3 -109, CD3 -110, CD3 -111, 3/16/05, FB 2005 -08 PGS 52 -53; CD3 -301, CD3 -302, 3/19/05, FB 2005 -09 PGS. 24 -25; CD3 -304, 4/16/05, FB 2005 -12 PGS 35 -37. CD3 -303 2/10/06, FB 2006 -03 PG 11. CD3 -112, 2/23/06, FB 2006 -05 PGS 29 -31. CD3 -107, 3/26/06, FB 2006 -09, PGS.9,25 -27. CD3 -305, CD3 -106, CD3 -113, CD3 -114, CD3 -115, CD3 -116, CD3 -117, 5/2/06, FB 2006 -11 PGS 57 -61; CD3 -X18, 4/7/07, FB 2007 -07 PG. 67; CD3 -X98, CDX -99, CD3 -X19, CD3 -X20, CD3 -X21, CD3 -X22, CD3 -X23, CD3 -X24, 4/13/09, FB 2009.05 PGS. 70 -72. SURVEYOR'S CERTIFICATE 1 , I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED • ..44_\ P...... . qtq . AS -BUILT ICE REP ESENTS MADE BY MY DIRECT .� ` • • • °� • ' ° ' . 9 � SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST J * ,�' •• *• AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE • 49th ,4\ CORRECT. • / DATE: REGISTRATION NO. LS -5077 • • a Donald G. Bruce : o •' � No. LS -5077 .� i `e9 F ''• ••.. • • ••'� • ' KUUKPIK Essiota LICMF 13000.1 Are. Antlgny4 Af9W 90603 (907)273-0830 A Oflce 1907) 670.473E Alpine Survey Office ALPINE MODULE: CD30 UNIT: CD C.noc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03- 03 -1A -3 3 -17 -05 C F A - D30 - 111 3 OF 3 5 s " + - 7 • TRANSMITTAL LETTER CHECKLIST WELL NAME ( Cf22 --/2— ( PTD# 2- I C) (7% 2I Development (7 Exploratory Stratigraphic Test Non - Conventional Well FIELD: �1 /r'� �l� � /c �� POOL: �� . „'1 0/ 7 Circle 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 , Permit No. , (If last two digits in API No. . Production / injection should API number are continue to be reported as a function of the original API number between 60 -69) stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and 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. Should conventional core be acquired in this well, representative chip samples from each foot of core must be submitted to the Commission in accordance with 20 AAC 25.071. 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: 2/1/2010 ` ''•e <"Field & Pool COLVILLE RIVER, FIORD OIL - 120120 Well Name: , ,, $4 a _ COLVILLE RIV FIORD CD3-121 __— Program SER Well bore seg ❑ PTD #:2100220 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER / PEND Geo Area 890 — Unit 50360 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location and top prod interval in ADL 372105; TD in ADL 372104. 3 Unique well name and number Yes 4 Well located in a defined pool Yes COLVILLE RIVER, FIORD OIL - 120120 governed by CO 569 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 569 contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes Conservation Order No. 569 has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes Conservation Order No. 569 has no interwell spacing restrictions. Wellbore will be more than 500' from 1 8 If deviated, is wellbore plat included Yes external property line where ownership or landownership changes. 9 Operator only affected party Yes '10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes SFD 2/22/2010 1 13 Can permit be approved before 15 -day wait • Yes • 114 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes AIO 30, issued July 25, 2006 15 All wells within 1/4 mile area of review identified (For service well only) Yes None within 1/4 mile. Nearest well is currently CD3 -122, which is 2046' away in the Nechelik interval. 16 Pre- produced injector: duration of pre production less than 3 months (For service well only) No Limited duration flowback for clean up only 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided Yes Engineering 119 Surface casing protects all known USDWs Yes No Aquifers ... 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No TOC planned for 500' above Kuparuk zone 22 CMT will cover all known productive horizons Yes Intermediate casing cemented. 2nd stage to cover Qannik. Barefoot OH horizontal production section 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. All drilled wells pass major risk .. Closest well is CD3 -112 at 46 ft @ 1908' m 127 If diverter required, does it meet regulations NA Diverter waiver requested. No shallow gas issues in CRU 20 AAC 25.035(h) (2) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes max fm pressure = 3200 psi (8.7 ppg) Will drill with 9 ppg mud GLS 2/24/2010 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 2493 psi Will test BOP to 3500 psi • 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No H2S not reported at CRU. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) Yes No wells with 1/4 mile. AOR complete. 35 Permit can be issued w/o hydrogen sulfide measures Yes None expected, but H2S and gas detectors will be used during drilling. Mitigation measures in Hazards Geology 36 Data presented on potential overpressure zones Yes Summary. Expected reservoir pressure is 8.7 ppg EMW; will be drilled with 9.0 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA SFD 2/22/2010 38 Seabed condition survey (if off- shore) NA 139 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering 4 • c Commissioner: Date: • Commissioner: Date 1 ir,ner Date 2 -z5 /o 4 -., 4 =/4 • • Well History File APPENDX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar 31 12:35:08 2010 Reel Header Service name LISTPE Date 10/03/31 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 10/03/31 • Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River MWD /MAD LOGS WELL NAME: CD3 -121 API NUMBER: 501032061500 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 31- MAR -10 JOB DATA MWD RUN 3 MWD RUN 4 JOB NUMBER: -MW- 0006991485 -MW- 0006991485 LOGGING ENGINEER: E. QUAM J. BOBBITT OPERATOR WITNESS: D. BURLEY F. HERBERT SURFACE LOCATION SECTION: 5 TOWNSHIP: 12 RANGE: 5 E FNL: 3993 FSL: FEL: 1069 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 49.37 GROUND LEVEL: 12.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2723.0 2ND STRING 6.125 7.25 8878.0 3RD STRING PRODUCTION STRING fib -". 19 54141 • • REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL AND AT -BIT INCLINATION (ABI) WITH ELECTROMAGNETIC WAVE TELEMETRY (EM) - NO DATA ARE PRESENTED. 4. MWD RUNS 3 -4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR -P4), DRILLSTRING DYNAMICS SENSOR (DDSr), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 4 ALSO INCLUDED GEOPILOT ROTARY- STEERABLE BHA (GP). NO DATA WERE ACQUIRED ON MWD RUN 2. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIRE- MENTS AT CONOCO- PHILLIPS /VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1 -4 REPRESENT WELL CD3 -121 WITH API #: 50- 103 - 20615 -00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15,081'MD /7014'TVD. SROP = RATE OF PENETRATION WHILE DRILLING. SGRC = DUAL GAMMA RAY COMBINED. SEXP = EWR PHASE -4 9" 2 MHZ PHASE SHIFT RESISTIVITY. SESP = EWR PHASE -4 15" 2 MHZ PHASE SHIFT RESISTIVITY. SEMP = EWR PHASE -4 27" 2 MHZ PHASE SHIFT RESISTIVITY. SEDP = EWR PHASE -4 39" 1 MHZ PHASE SHIFT RESISTIVITY. SFXE = FORMATION EXPOSURE TIME EWR- PHASE -4. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/31 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 - . III FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2687.0 15033.0 RPD 2720.5 15040.0 FET 2720.5 15040.0 RPS 2720.5 15040.0 RPM 2720.5 15040.0 RPX 2720.5 15040.0 ROP 2733.5 15081.0 $ BASELINE CURVE FOR SHIFTS: . CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 2687.0 8888.0 MWD 4 8888.0 15081.0 $ REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record _ Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR _MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2687 15091 8884 24789 2687 15081 RPD MWD OHMM 0.13 2000 9.23621 24560 2720.5 15040 RPM MWD OHMM 0.15 1643.14 8.14056 24560 2720.5 15040 RPS MWD OHMM 0.25 2000 8.0155 24560 2720.5 15040 RPX MWD OHMM 0.34 1834.65 7.68195 24560 2720.5 15040 FET MWD HR 0.25 118.49 1.04962 24560 2720.5 15040 1 GR MWD API 22.32 386.82 83.5675 24693 2687 15033 ROP MWD FPH 0.41 313.55 123.967 24696 2733.5. 15081 First Reading For Entire File 2687 Last Reading For Entire File 15081 File Trailer Service name STSLIB.001 • Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/31 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/31 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 2687.0 8841.0 SFXE 2720.5 8833.5 SEXP 2720.5 8833.5 SESP 2720.5 8833.5 SEMP 2720.5 8833.5 SEDP 2720.5 8833.5 SROP 2733.5 8888.0 LOG HEADER DATA DATE LOGGED: 19- MAR -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 8888.0 TOP LOG INTERVAL (FT): 2733.0 BOTTOM LOG INTERVAL (FT): 8888.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 26.0 MAXIMUM ANGLE: 80.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2723.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 9.80 MUD VISCOSITY (S): 42.0 MUD PH: 9.7 4 i MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): 2.6 RESISTIVITY (OHMM) AT TEMPERATURL (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.000 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .570 144.9 MUD FILTRATE AT MT: 1.300 70.0 MUD CAKE AT MT: 1.450 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # , TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2687 8888 5787.5 12403 2687 8888 RPD DEPT_ OHMM 0.13 2000 6.24539 12227 2720.5 8833.5 RPM MWD030 OHMM 0.15 1461. 4.7682 12227 2720.5 8833.5 RPS MWD030 OHMM 0.25 2000 4.96859 12227 2720.5 8833.5 RPX MWD030 OHMM 0.34 1834.55 4.75167 12227 2720.5 8833.5 FET MWD030 HR 0.25 65.93 1.09532 12227 2720.5 8833.5 GR MWD030 API 47.85 386.82 118.106 12309 2687 8841 ROP MWD030 FPH 0.41 313.55 154.879 12310 2733.5 8888 First Reading For Entire File 2687 Last Reading For Entire File 8888 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/31 Maximum Physical Record 65535 ,, File Type LO Next File Name STSLIB.003 • • Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/31 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 8841.5 15033.0 SEXP 8874.0 15040.0 SEDP 8874.0 15040.0 SEMP 8874.0 15040.0 SFXE 8874.0 15040.0 SESP 8874.0 15040.0 SROP 8888.5 15081.0 LOG HEADER DATA DATE LOGGED: 28- MAR -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 15081.0 TOP LOG INTERVAL (FT): 8888.0 BOTTOM LOG INTERVAL (FT): 15081.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.1 MAXIMUM ANGLE: 94.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 8878.0 # I BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.00 MUD VISCOSITY (S): 40.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 22500 FLUID LOSS (C3): 4.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MP,): .280 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .120 173.2 MUD FILTRATE AT MT: .280 70.0 MUD CAKE AT MT: .340 70.0 e • • # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX.. MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8841.5 15081 11961.3 12480 8841.5 15081 RPD MWD040 OHMM 7.52 1222.01 12.2013 12333 8874 15040 RPM MWD040 OHMM 5.63 1643.14 11.4839 12333 8874 15040 RPS MWD040 OHMM 0.71 106 11.0362 12333 8874 15040 RPX MWD040 OHMM 3.47 964.18 10.587 12333 8874 15040 FET MWD040 HR 0.34 118.49 1.00432 12333 8874 15040 GR MWD040 API 22.32 129.26 49.2378 12384 8841.5 15033 ROP _MWD040 FPH 0.68 142.84 93.2451 12386 8888.5 15081 First Reading For Entire File 8841.5 Last Reading For. Entire File 15081 1 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/31 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 10/03/31 i Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 10/03/31 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File .s"
