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210-179
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. cQ I Q - j 7 Well History File Identifier Organizing(done) Two-sided 11111111111111 II111 ❑ Rescan Needed III II1lIII1II111111 RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: fr/ reyscale Items: Other, No/Type: G.7 NO. 1 Other Items Scannable by a Large Scanner ,I ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: /s/ ii • Project ProofingII 111111 IIII I III BY: 42. Date: /O /s/ il ? Scanning Preparation 4- x 30 = 1 a 0 + /5-- = TOTAL PAGES / 3 BY: 111125Date: 141 014 (Count does not include cover sheet) v4� /s/ Production Scanning III III1IIIIIII 11111 Stage 1 Page Count from Scanned File: 1 36 (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: 411, Date: LW I /4. /s/ IMP 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. III II 1111111 II 11111 ReScanned 111111111011111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 III II1l Ill § 1 » I 1...- c) w£ - ¥ » 3 § 2 ) i/ A E $ E Cil 71 �Ecƒ 0-CC u »= it- -0 , § 5 c do -- c o/ 0 0< 0 O � � (6 E 43 fil ::,-, E ..z\\/�) 0< << \/ \< ) 0 / /O 0O- 01- 0( \( °$ =CLWzoo 20 20 e0 /0 < \ § _ 0 (N § (N \ § / \ (N 0 \ 0 \ re \ § \ § 5 5 \ E & & & 4 $ = f ] \ -- I § c m [ c c c E § 11 § / \ E ° ° f o 0. 0 0. 0 0. o l / Ce ) \ \ 0.;2 co m m ® ° 0 CO § d k 3 § \ CO CO ) \ § § 0 ) Om % m § _ m z Ce o 0 / / / / V. / m co W o 2 Z0 co , I U) ° ° ) 2 J J Q CO a 1 a0 it' 1 m co CL z 7 ° 0 0 0 0 C•1 ; s m 0 \ © i 0 2 E0 CD 73 o o m m g m # 0 k1 CO— k 1 $ ® ! m / \ \ To 1 CO 2 ? 1 . c o \ k 0 ] n Q k - Q o• \ 6 f f f IL :!: o ; \ j % #�\ k ) k\ o o o G \ e & = = . m . \ \ e co Z m Q 2 o 2 G @ . _ £ _ n _ m 0 0 \ o _ \ 0 co � . x2 L o a z Zr) 2 � § R 2 o § ) woz ) § co -Z \ \ ƒ j / z © o o u £ u) 2 q \ ƒ H Uig ° . g £ - �_ \ l § . , \ < k ° 2 CO § j \ / / / E ° a � � � o w ■ -I0R � ---- -----. � a it O I, N IIiiI 9 it c z N IIIH r, o I'I o 5 1 0 N C Z a Q J_ O 0 Z_ Y = d cn I.L. J O Q T. O a. a 'S Z Z /� li J v0 C T it LU = �J d I Ce a 0 W 0 N I' H I • a �'-� 1 j U0co Z 8 u) ct• o Q o z F- s1 y o N_ O O II fl w6 = 1 i' 5 co o 11 E• I f IN r O III rI II S%--1 a I U 0 ', J l 0 1 5� Z CO • N N J J 5 to 0 0. Q 0 o I. al 1111 Q c a Z 0 O E U 1 Z �I d H CO I II M Z cn '1-`; 01 m C 2 >- t Ill I'I d N 0 ,I Z c•• d a) N Z N U P. Ii 0 a0+ N O N 0 I y is Q0 a ;,•2 I E o. a m co, 1 E E a 2 Q 5 0 QCe 1 U 1 0 ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 15,2012 � C) 1 '7 fig Commissioner Dan Seamount Alaska Oil&Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Dan Seamount: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU),and the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As 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 cement was pumped in the spring of 2012. The corrosion inhibitor/sealant was pumped in the months of April and May 2012. 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, Martin Walters ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 5/15/2012 WD,CD2,CD3,CD4,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 WD-02 50103202850000 1982580 2' n/a 2' n/a 13.6 4/11/2012 CD2-77 50103206290000 2101790 SF n/a 17" n/a 2.1 4/13/2012 CD3-128 50103206380000 2110370 21' n/a 21' n/a 90.7 4/13/2012 CD3-198 50103206370000 2110240 28" n/a 28" n/a 47.6 4/13/2012 CD3-199 50103206350000 2110100 SF n/a 11" n/a 2.9 4/13/2012 CD4-03 50103206410000 2111130 29" n/a 29" n/a 9.4 4/11/2012 CD4-298 50103206230000 2101300 28" n/a 28" n/a 28.9 4/11/2012 Halliburton Sperry Drilling 6900 Arctic Blvd Anchorage, AK 99518 August 23, 2011 AOGCC Christine Mahnken 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Sir or Madam: Subject: CD2-77 Definitive Survey Reports Enclosed are two hard copies (NAD83 and NAD27)of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge receipt by sending an email to Avinash.Ramjit@Halliburton.com or by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling ATTN: Avinash Ramjit 6900 Arctic Blvd Anchorage, AK ; 8/ Received by: / Date: l Please contact me at 907.263.4657with questions or concerns. Regards, Avinash Ramjit n . _ i --� n STATE OF ALASKA - ALASh )IL AND GAS CONSERVATION COMMI. )N ` REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate 17 Other r Atter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r = 210-179-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service • 50-103-20629-00—Q 0 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 380075,380077,384209M CD2-77 9. Field/Pool(s): Colville River Field/Alpine Oil Pool 10.Present Well Condition Summary: Total Depth measured 22658 feet Plugs(measured) None true vertical 7362 feet Junk(measured) None Effective Depth measured 22648' feet Packer(measured) 16906 true vertical 7362' feet (true vertucal) 7241 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3354 10.75 3391 2393 INTERMEDIATE 17310 7.625" 17344 7298 LINER 5742 3.5" 22648 7362' RECEIVED I , APR a. 4 2011 Perforation depth: Measured depth:`1wp5 J_a ., True Vertical Depth:lTgCle p] i "55 Alaska Oil a SOS COM Camera f „!°r t rage Tubing(size,grade,MD,and TVD) 4.5/3.5, L-80, 16891'/16953'MD, 7245 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER HRD ZXP LINER TOP PACKER @ 16906'MD/7245'TVD NIPPLE-4 1/2"Camco @ 2209 MD and 1930 TVD 11.Stimulation or cement squeeze summary: Intervals treated(measured): 17735'-22305' MD Treatment descriptions including volumes used and final pressure: 729233#of 16/30 sand 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation 3214 3050 701 -- 370 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 Service r Stratigraphic r 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG E GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 311-049 Contact Tim Schneider @ 265-6859 Printed Name Tim Schneider Title Staff Production Engineer Signature Phone:265-6859 Date dri RBDMS APR 14 2011j.I7 , Form 10-404 Revised 10/2010 6 i # Submit Original Only "� WNS CD2-77 ' COnocoPhithhps '' r„ Well Attributes Max Angle&MD 1D il(Bila [Well APUUWI Field Name Well Stats Incl I') i MD(ftKB) Act Btm(ftKB) ono d~ipwdti, 501032062900 ALPINE PROD 91.52 18,078.87 22 658.0 C ment H2S(ppm) Dab 'Annotation End Date 1 KB-Ord(ft) Rig Release Dab wex ina9QR�i 9NTpy_-gp7 40 u y-7I2411T0, p0 AM. SSS.-.. - __,_ _- Last W0: 43.80 2/9/2011 _...__.�..- dimJksc-Aowet _.. Annotation Depth(R103) _B) End Date Annotation Last Mod By End Date __ _.._ _ Last Tag: l Rev Reason:PULL ISO SLV,SET WRDP Imosbor 4/1/2011 ------- -- --- r Casing Strings Casing Description String 0... String ID...Top(MB) Set Depth(L..Set Depth(TVD)...String WL..String...String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Casing n-- - CONDUCTOR. 1 Casing Deserigion Siring 0... String ID...Top(lIKB) SA Depth(4.SN Depth(MD)-.String Wt...String_String Top Pint 37-114 I SURFACE 10 3/4 9.950 36.5 3,390.5 2,393.6 45.50 L80 BTCM WRDP,2,209� "' Casing Description String O._ String ID...Top MKS) set Depth(f...Set Depth(TVD)...Siring Wt...string...wing Top Thrd NIPPLE, INTERMEDIATE 75/8 6.875 34.0 17,344.0 7,297.5 29.70 L-80 BTCM o'. Casing Description String 0... String ID...Top(ftKB) SN Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd LINER 31/2 2.992 16,905.6 22,648.0 7,362.2 9.20 L-80 SUIT Liner Details SURFACE, e I . Top Depth 36-3,391 (ND) Top Incl Nomi... 1111, Top(ftKB) ( ) (1 Ihm Drrripibn _ ___ Comment ID(in) GAS LIFT, 16,905.6 7,241.3 79.07 PACKER Baker 5.5 by 7.625 HRD ZXP LINER TOP PACKER w/Hold Downs 4.950 6,148 --- 16,924.5 7,245.0 79.62 NIPPLE BAKER RS NIPPLE 4.870 16,927.3 7,245.5 79.70 HANGER BAKER 5.5"by 7.625"FLEX LOCK HANGER 4.830 16,938.9 7,248.7 82.37 SBE Baker 80-40 Seal Bore Extension(20') 4.000 GAS LIFT. }`,-1 16,996.7 7,256.6 82.86 NIPPLE HES XN NIPPLE 2.813"(2.75"No-Go) 2.750 12,262 --'" ' 17,400.2 7,303.8 84.07 Centralizer 3'h"Pup w/6 h"Centralizer SLHT Box X Pin 2.992 17,404.8 7,304.3 84.15 ECP Swell Packer(312"SLHT)OD 6.38"wilt'sealing element 2.992 GAS LIFT, -.- 17,415.7 7,303.3 84.60 Centralizer 3%"Pup w/6'4"Centralizer SLHT Box X Pin 2.992 16,312 17,735.3 7,315.2 88.63 SLEEVE-O 3 1/2"SLHT Ball Actuated Sleeve(2.000"Seat ID)(2.125"Ball) 2.000 NIPPLE,16,367-_. 18,058.1 7,316.8 91.93 Centralizer 3%'Pup w/6'/a"Centralizer SLHT Box X Pin 2.992 18,062.7 7,316.6 91.84 ECP Swell Packer(3 1/2"SLHT)OD 6.38"wI10'sealing element 2.992 GAUGE,16,416 .-J 18,073.6 7,3162 91.62 Centralizer 3%"Pup w/6 14"Centralizer SLHT Box X Pin 2.992 18,361.9 7,317.7 89.58 SLEEVE-0 3 1/2"SLHT Ball Actuated Sleeve(1.875"Seat ID)(2.000"Ball) 1.875 NIPPLE,16,508 r '�'-" ---- -- f _ 18,681.1 7,324.0 88.83 Centralizer 3'"Pup w/6'A"Centralizer SLHT Box X Pin 2.992 18,685.5 7,324.0 88.85 ECP Swell Packer(31/2"SLHT)OD 6.38"w/10'sealing element 2.992 18,696.4 7,324.2 88.91 Centralizer 3 Y"Pup w/6 h"Centralizer SLHT Box X Pin 2.992 -- r-t 19,013.5 7,333.0 90.84 Centralizer 3%"Pup wl 6 h55Centralizer SLHT Box X Pin 2.992 LOCATOR, 16,924 19,017.9 7,332.9 90.71 ECP Swell Packer(3 1/2"SLHT)OD 6.38"w/10'sealing element 2.992 SEAL ASSY. �_JT 19,028.8 7,332.8 90.40 Centralizer 3%"Pup w/6'A"Centralizer SLHT Box X Pin 2.992 16'934 �,- -'j 19,314.2 7,338.6 88.07 SLEEVE-0 3 1/2"SLHT Ball Actuated Sleeve(1.750"Seat ID)(1.875"Ball) 1.750 I 19,601.4 7,347-9 89.75 Centralizer 3 h'Pup w/6 K'Centralizer SLHT Box X Pin - 2.992 19,606.0 7,348.4 90.77 ECP Swell Packer(3 1/2"SLHT)OD 6.38"w/10'sealing element 2.992 19,616.9 7,348.3 90.81 Centralizer 3 h"Pup w/6%"Centralizer SLHT Box X Pin 2.992 19,905.8 7,343.0 90.73 SLEEVE-0 3 1/2"SLHT Ball Actuated Sleeve(1.625"Seat ID)(1.750"Ball) 1.625 20,191.9 7,342.6 88.41 Centralizer 3:4"Pup w/6%"Centralizer SLHT Box X Pin 2.992 20,196.5 7,342.7 88.45 ECP Swell Packer(3 12"SLHT)OD 6.38"w/10'sealing element 2.992 NTERMEDWTE, 34-17,344 20,207.5 7,343.1 88.52 Centralizer 3%"Pap w/6'A"Centralizer SLHT Box X Pin 2.992 20,495.6 7,347.3 89.40 SLEEVE-0 3 1/2"SLHT Ball Actuated Sleeve(1.500"Seat ID)(1.625"Ball) 1.500 4 ► _.._- -'--- ---- -- --- -- 20,784.8 7,348.7 89.53 Centralizer 3 h"Pup w/6 Y3"Centralizer SLHT Box X Pin 2.992 FRAC,17,735 I 20,7893 7,348.8 89.54 ECP Swell Packer(3 1/2"SLHT)OD 6.38"w/10'sealing element 2.992, 20,800.3 7,348.9 89.58 Centralizer 3'r3"Pup w/6 h"Centralizer SLHT Box X Pin 2.992 4r 21,087.3 7,349.0 90.05 SLEEVE-0 3 1/2"SLHT Ball Actuated Sleeve(1.375 Seat ID)(1.500"Ball) 1.375 21,405.6 7,348.4 91.16 Centralizer 3%"Pup w/6 h"Centralizer SLHT Box X Pin 2.992 FRAC,18,362 1 I 21,410.2 7348 3 91.01 ECP Swell Packer(3 12"SLHT)OD 6.38"w/10 sealing element 2.992 21,421.1 7,348.2 90.64 Centralizer 3%"Pup w/6'h'Centralizer SLHT Box X Pin 2.992 21,710.0 7,353.9 89.71 SLEEVE-0 3 112"SLHT Ball Actuated Sleeve(1.250"Seat ID)(1.375"Ball) 1.250 21 4 ► - ....--- - 21,998.0 7,358.1 88.64 Centralizer 3%"Pup wl 6%"Centralizer SLHT Box ox X Pin 2.992 Al ► 22,002.6 7,358.2 88.66 ECP Swell Packer(3 1/2"SLHT)OD 6-38"w/10'sealing element 2.992 iti a. 22,013 6 7,358 5 88.691 Centralizer 3%"Pup w/6%"Centralizer SLHT Box X Pin 2.992 Tubing Strings FRAC,19,314 Tubing D pt n 'String 0... ID...Top(ftKB) ISet Depth(f...ISet Depth(ND) String Wt.. Strng...String Top Thrd TUBING i 41/2..-.',String_ 3958..' 31.0 _-_1_16,953.9 J_ 7,250.9 12.60 'L-80 IBTM 41 III I. Completion Details Top Depth (TVD) Top Incl Rami... FRAC,19,905 I I Top(RKB) (ftKBI (°) Hon Description Comment ID(in) 31.0 31.0 -0.02 HANGER Tubing hanger 4.000 : : 2,209.2 1,930.4 58.83 NIPPLE 4 12"Camco BP-6i(5.591"O.D.)W/3.813"DB-profile 3.812 /1 16,367.1 7,077.8 68.99 NIPPLE HES x NIPPLE 3.813"X-profile 3.812 16,415.9 7,095.5 69.15 GAUGE Camco 4 12"Gauge Mandrel(See Below) 3.879 FRAC.20.496 ! , 16,507.6 7,127.8 69.46 NIPPLE HES XN NIPPLE 3.813"(3.725"NoGo) 3.812 16,890.9 7,238.2 78.65'XO-Reducing XO,4 1/2"12.6#IBT-M X 3 1/2"9.3#/R EUE-M 2.992 • ► 16,923.9 7,244.8 79.60 LOCATOR Pup Joint-3 1/2",9.3#.EUE w/LOCATOR 2.990 All P. 16,934.4 7,248.1 82.33 SEAL ASSY SEAL ASSEMBLY,80-40 GBH-22 2 1/2 Mule Shoe(Below Locator) 2.990 Qther In Hole(Wirelinepl retrevableug-s,valves,pumpszfish,etc.) FRAC,21,087 Top Depth (ND) Top Incl Top NIKE) (ftKB) (•) Description Comment Run Date ID(in) • ► 2,209.2 1,930.4 58.83 WRDP 3.81"WRDP-2 ON DB LOCK(HABS-0556) 3/31/2011 FRAC,21,710 I Mandrel Details a`2T Top Depth Top -I '.. _ _. Port • r (ND) 1001 OD Valve Latch Sine TRO Run Stn Top IRKS) (ftKB) (') Make Model (in) Sery Type Type (in) (psi) Run Date Co._ FRAC,22,296 I I II 1 6,148.2 3,401.0 68.81 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/62011 LINER, 2 12,261.6 5,598.4 69.39 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,739.0 3/14/2011 18,908-22.648 - --------- -_- -- TD,22,estt _ 3 16,311.8 7,058.7 69.43 CAMCO KBMG 1 GAS LIFT OV IBK 0.250 0.0 3/13/2011 WNS CD2-77 ' ConocoPhilrips - ..141.4. Alaska.Inc. ... I -1KB-God Rebase Date _...1!60-Cern :ri4R44d?PJ,e.9k2-rlr/7.LLUL14M949M_,. -- -- 43(/t)80_ Rig_21912011 MANGER,31 � Stimulations&Treatments ..,i:i:-:' 1.` �r�. �, __ Bottom Min Top Max Bim Top Depth Depth Depth Depth {ND) (TVD) CONDUCTOR, (aKB) (RKB) (itKB) (ftKB)7-114 TYP°. _ Wb Comment WROP,2.2091 i. 17,735.0 22,305.0 7,315.2 7,315.4 FRAC 3/10/2011 FRAC THRU SLEEVES-pumped 729,233#of 16/30 NIPPLE.2.209' — River Sand total;-91,000#sand @ each of 8 zones 17,735.0 22,305.0 7,317.7 7,317.8 FRAC 3/10/2011 FRAC THRU SLEEVES-pumped 729,233#of 16/30 River Sand total;'91,000#sand each d 8 zones 17,735.0 22,305.0 7,338.6 7,338.7 FRAC 3/10/2011 FRAC THRU SLEEVES-pumped 729,233#of 16/30 SURFACE, River Sand total;-91,000#sand @ each of 8 zones 36-3,391 17,735.0 22,305.0 7,343.0 7,342.9 FRAC 3/10/2011 FRAC THRU SLEEVES-pumped 729,233#of 16/30 ,:. River Sand total;-91,000#sand @ each of 8 zones GAS LIFT' 6,14e AV. 17,735.0 22,305.0 7,347.3 7,347.3 FRAC 3/10/2011 FRAC THRU SLEEVES-pumped 729,233#of 16/30 River Sand total;-91,000#sand @ each of S zones 17,735.0 22,305.0 7,349.0 7,349.0 FRAC 3/10/2011 FRAC THRU SLEEVES-pumped 729,233#of 16/30 River Sand total;-91,000#sand @ each of 8 zones 17,735.0 22,305.0 7,353.9 7,353.9 FRAC 3/10/2011 FRAC THRU SLEEVES-pumped 729,233#of 16/30 River Sand total;' 91,000#sand @ each of 8 zones GAS LIFT,_-- ,,,_--�5, 17,735.0 22,305.0 7,363.5 7,363.6 FRAC 3/10/2011 FRAC THRU SLEEVES-pumped 729,233#of 16/30 12,262 I __ _ t River Sand total,'91,000#sand @ each of 8 zones Notes:Genera)&Safety *, End Date Annotation � 16,312 2/11/2011 NOl E VIEW SCHEMATIC w/Alaska Schematic9.0 3/10/2011 NO1 E"PIECES OF FLASHLIGHT THAT FELL DOWNHOLE DURING COMPLETION STILL IN HOLE" NIPPLE,16,367- --- r_ GAUGE,16,416 -.__.--_.. }L^3 NIPPLE,16,508----- k' LOCATOR, 16,924 SEAL ASSY. 16.936 NTE RM EDWTE._ J ` 34-17,344 • a A A A FRAC,17,735 1 1 a1►a FRAC,18,362 Al Al a FRAC,19,314 1 1 laa ► ► FRAC,19,905 1 1 .1► FRAC.20,496 1 I FRAC,21,087 r 411 ► FRAC,21,710 a ►F FRAC,22,296 , F.',',, i LINER, 16,906-22,648 TD,22,658 CD2-77 Well Work Summary DATE SUMMARY 3/2/11 PULL ISO SLEEVE ON DB LOCK @ 2209' RKB, TBG OPEN 3.78 TO 16507' rcKB, SET 4 1/2 CATCHER SUB @ 16507' RKB. IN PROGRESS. 3/5/11 PULLED SOV AND SET DV @ 16,312' RKB. MIT-IA @ 3500 PSI. **PASSED** PULLED CATCHER @ 16,496' SLM. IN PROGRESS. 3/6/11 PULLED B&R AND RHC @ 16,507' RKB. PERFORMED SBHPS @ 16,507' RKB AND GRADIENT STOP @ 15,500' RKB. ((TEMP=159* PSI=3384)) COMPLETE. 3/10/11 Performed Alpine C-sand frac consisting of 8 main stages utilizing_Packers Plus StackFRAC, system. Each stage placed approximately 91,000#of 16/30 White Sand using 25#crosslink gel at 20 bpm, for a job total of 729,233#sand and 9708-bbl total volume pumped. First stage was pumped through a 10' perforated joint, with subsequent stages initiated by dropping frac balls (1.375"-2.125", in 0.125" increments)that open specific ports along the horizontal liner. The prop fracture treatment was preceded by a breakdown and DataFRAC using 25#linear and crosslinked gel at 20 bpm. (Note: All seven frac balls recovered in choke during production by 4/2/11.) 3/12/11 RECOVER PARTS OF TREE SAVER ELEMENTS. SET CAT SV @ 16,508' RKB. IN PROGRESS. 3/13/11 PULLED DV AND SET OV(.25") @ 16,312' RKB. ATTEMPTED TO PULL DV @ 12,262' RKB. IN PROGRESS. 3/14/11 PULLED DV AND SET GLV(3/16" TRO=1739 PSI) @ 12,262' RKB. PULLED ST VLV @ 16,508' RKB. SET ISO SLEEVE @ 2209' RKB. COMPLETE. 3/31/11 PULLED 3.81" DB LOCK w/ISO SLEEVE @ 2209' RKB. SET 3.81" DB LOCK w/WRDP-2 (NABS-0556) @ 2209' RKB. PASSED CLOSURE TEST. COMPLETE. SIETE ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND AS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Tim Schneider Staff Production Engineer ConocoPhillips Alaska, Inc. II9P.O. Box 100360 alto r Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2-77 Sundry Number: 311-049 Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Daniel T. Seamount, Jr. 71- Chair DATED this 2 Sday of February, 2011. Encl. I •., STATE OF ALASKA vl - j ALASK IL AND GAS CONSERVATION COMMISS ,. ' l OSY Z011 APPLICMTION FOR SUNDRY APPROVMLS'��;• 2 20 AAC 25.280 SSce n0.Cp�I1(1>1SSIon r 1.Type of Request: AbandonRug for Redrill r Perforate New Pool r Repair w ell 100 f kroved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r ion r Operational Shutdown r Re-enter Susp.Well r Stimulate . Alter casing ,`- Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 ' Exploratory 1 210-179-0 3.Address: Stratigraphic " Service [ " 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20629-00 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No CD2-77 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380075,380077,384209' Colville River Field/Alpine Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 22658 , 7362 . 22648' 7362' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3354 10.75 3391' 2393' INTERMEDIATE 17310 7.625" 17344' 7298' LINER 5742 3.5" 22648' 7362' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 4.5/3.5 L-80 16891'/16953' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER HRD ZXP LINER TOP PACKER MD=16906 TVD=7241 NIPPLE-4 1/2"Camco BP-6i(5.591"O.D.)w/3.813"DB-profile MD=2209 TVD=1930 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development Service " 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/28/2011 Oil 17 • Gas r WDSPL E Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider©265-6859 Printed Name Tim hn-'der Title: Staff Production Engineer Signature / -, / - Phone:265-6859 Date 2 /C—(�. Commission Use Only Sundry Number:3 ( 0.4c Conditions of approval: Notify Commission so that a representative may witness 111111 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: /6 uO 11 APPROVED BY / / Approved by: '/ COMMISSIONER THE COMMISSION Date: Z l R 2.2 3-J/ Form 10-40 2 Submit in Du licate C �' 25 1011 IGINq ,:i) p 2;3 (, r, WNS CD2-77 ConocClP11llIska.p5 a Y�►&U.Atttibutes Max Angle&MD TD "1 Walkers APYUWI Field Borne Well Status Mel(°) MD(kKB) Act Btm(MOB) �` 501032062900 'ALPINE PROD 9152 ' 18,078.88 22,658.0 csxxacdt+amps` ^ Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ep Confi HOR T_ CQg Y{,2(1{y20tt 9,5726 AM SSSV-NIPPLE ' Last WO: 43,80 2/9/2011 9 '� Annotation De h OMB) End Date Annotation Last Mod ByEnd Date $rt,oL 0S ,77,/15 Pt l ) Last Tag: ' � 'Rev Reason:NEW WELL 1 Imosbor 2/10!2011 HANGER,31----_..- h.N • Casing Strings ~ ` Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15 250 37.0 114.0 114.0 62.50 H-40 Welded mommenomminninimmas I l: yam;.;„1 g.l Casing Description String 0... String ID...Top(ftKB) Set Depth(f..,Set Depth(TVD)...String Wt...String.,String Top Thrd CONDUCTOR, SURFACE 103/4 9.950 36.5 3,390.5 2,393.6 45.50 L80 BTCM 37-114 Casing Description String 0... String ID...Top(kKB) Set Depth(f,,,Set Depth(TVD)...String Wt...String...String Top Thrd iit NIPPLE,2,209 ,;t INTERMEDIATE 75/8 6.875 34.0 17,344.0 7,297.5 29.70 L-80 BTCM Casing Description String 0... String ID...Top(kKB) Set Depth(f,,.Set Depth(TVD)...String Wt...String...String Top Thrd LINER 31/2 2.992 16,905.6 22,648.0 7,362.2 9.20 L-80 SLHT Liner Details Top Depth SURFACE, 1 (TVD) Top Incl Nomi,,, 36-3.391 . Top(kKB) (ftKB) (°) Item Description __- G Comment ID(In) 16.905 6 7,241.3 79.07 PACKER Baker 5.5 by 7.625 HRD ZXP LINER TOP PACKER w/Hold Downs 4.950 IRE GAS LIFT, 16,924.5 7,245.0 79.62 NIPPLE BAKER RS NIPPLE 4.870 6,148Ili 16,927 3 7,245.5 79.70 HANGER BAKER 5.5"by 7,625"FLEX LOCK HANGER 4.830 I16,938.9 7,248.7 82.37 SEE Baker 80-40 Seal Bore Extension(20') 4.000 16,958.0 7,251.4 82.53 XO Reducing XO 5"Hydril 521 Box by 3.5"SLHT Pin 16,996.7 7,256.6 82.86 NIPPLE HES XN NIPPLE 2.813"(2.75"No-Go) 2.750 GAS LIFT, 17,400.2 7,303.8 84.07 Centralizer i 3%"Pup w/6 W Centralizer SLHT Box X Pin 2.992 12,262 .. 17,404.8 7,304.3 84.15 ECP 'Swell Packer(3 1/2"SLHT)OD 6,38"w/10'sealing element 2.992 111, 17,415.7 7303.3 84.60 Centralizer 3 h"Pup w/6 h"Centralizer SLHT Box X Pin 2.992 GAS16.312 LIFT,_ 17,735 3 7.315.2- 88.63 SLEEVE-C 3 12"SLHT Bat Actuated Sleeve(2.000"Seat ID)(2.125"Ball) 2,000 18,058.1 7,316.8 91.93 Centralizer 3 1/2"Pup w/6'h"Centralizer SLHT Box X Pin 2.992 NIPPLE,16,367 18,062.7 7,316.6 91.84 ECP Swell Packer(3 12"SLHT)OD 6.38"w/10'sealing element 2.992 MIK. 18,073.6 7,316.2 91.66 'A "Pup Centralizer 3 "Pup w/6 h"Centralizer SLHT Box X Pin 2.992 iiiiiGAUGE.16s16 ---- '�' 87 18,361.9 7,317.7 89.58 SLEEVE-C 3 1/2"SLHT Ball Actuated Sleeve(1.875"Seat ID)(2.000"Ball) 1. 5 l,. 18,681,1 7,324.0 88.83 Centralizer 13%"Pup w/6 Ya"Centralizer SLHT Box X Pin 2.992 NIPPLE,16,508 18,685.5 7,324,0 88.85 ECP Swell Packer(3 12"SLHT)OD 6.38"w/10'sealing element 2.992 � 18,696.4 7,324.2 88.81 Centralizer 3 1/2"Pup w/6 h"Centralizer SLHT Box X Pin 2.992 .- -: - 19,013.5 7,333-0 90.84 Centralizer 3%"Pup w/6 W Centralizer SLHT Box X Pm 2.992 ,""- 19,017,9 7,332.9 90,71 ECP Swell Packer(3 12"SLHT)OD 6.38"w/10'sealing element 2.992 LOCATOR, ` 19,028-8 7,332.8 90.40 Centralizer 3 "Pup w!6 h'Centralizer SUIT Box X Pm - 2.992 16,924 !� }.6t1 19,314.2 7,338.6 88.07 SLEEVE-C 3 1/2'SLHT Ball Actuated Sleeve(1.750"Seat ID)(1.875"Ball) 1.750 SEAL ASSY, WI 19,601.4 7,347.9 89.75 Centralizer 3 h"Pup w/6 Yr"Centralizer SLHT Box X Pin 2.992 1x,964 .,.- 19,606-0 7,348.4 90.77 ECP Swell Packer(3 1/2"SLHT)OD 6.38"w/10'sealing element 2.992 19,616.9 7,348.3 90.81 Centralizer 3 h"Pup w/6'A"Centralizer SLHT Box X Pin 2.992 1 19,905.8 7,343.0 90.73 SLEEVE-C 3 12"SLHT Ball Actuated Sleeve(1.625"Seat ID)(1.750"Ball) 1.625 • 20,191.9 7,342.6 88.41 Centralizer 3 55"Pup w/6 h"Centralizer SLHT Box X Pin 2.992 20,196.5 7,342,7 88.45 ECP Swell Packer(312"SLHT)OD 6.38"w/10'sealing element 2.992 20,207.5 7,343.1 88,52 Centralizer 3 h"Pup w/6 W Centralizer SLHT Bee X Pin 2.992 20,495.6 7,347.3 89.40 SLEEVE-C 3 1/2"SLHT Bat Actuated Sleeve(1,500"Seat ID)(1.625"Ball) 1.500 NTERMEDIATE, • 20,784.8 7,348,7 89.53 Centralizer 3 h"Pup w/6 W Centralizer SLHT Box X Pin 2.992 34-17,344 ► 20,789.3 7,348.8 89.54 ECP Swell Packer(312"SUIT)OD 6.38'w/10'sealing element 2.992 I. 20,800.3 7,348,9 89.58 Centralizer 3 1/2"Pup w/612"Centralizer SUIT Box X Pin 2.992 4- _ 21,087.3 7,349.0 90.04 SLEEVE-C 3 1/2'SLHT Ball Actuated Sleeve(1.375"Seat ID)(1.500"Ball) 1.375 21,405.6 7,348.3 90.70 Centralizer 3%"Pup w/6'h"Centralizer SLHT Box X Pin 2.992 4 ► 21,410.2 7,348.3 90.74 ECP Swell Packer(312'SLHT)OD 6.38"w/10'sealing element 2.992 4 p 21,421.1 7,343.1 85.98 Centralizer 3 1/2"Pup w/6'h"Centralizer SLHT Box X Pin 2.992 21,710.0 7,353.4 89.47 SLEEVE-C 3 12"SLHT Ball Actuated Sleeve(1.250"Seat ID)(1.375"Ball) 1.250 21,998.0 7,358.6 89.05 Centralizer 3'"Pup w/6'h"Centralizer SLHT Box X Pin 2.992 422,002.6 7,358.6 89.05 ECP Swell Packer(312'SLHT)OD 6.38'w/10'sealing element 2.992 4 Iv 22013.6 7,358.8 89.03 Centralizer 3%"Pup w/6'A"Centralizer SLHT Box X Pin 2.992 4 ► Tubing Strings Tubing Description String 0... String ID...Top(kKB) Set Depth(i...Set Depth(TVD)...String WI...String...String Top Thrd 4 10 TUBING ' 41/2 3.958 ' 31.0 ' 16,953.9, ' 7,250.9 ' 12.60 ' L-80 I IBTM Completion Details Top Depth I 4 (TVD) Top Incl Nomi... Top I6(KB) (kKB) (") N.,Description Comment ID tin) el ► 31.0 31.0 -0.08 HANGER Tubing hanger 4.000 2,209.2 1,930.4 58.83 NIPPLE 4 12'Camco BP-6i(5.591"0.D.)W1 3.813"DB-profile 3.812 "T6-367.1 7 077,8 68.99 NIPPLE HES x NIPPLE 3.813"X-profile 3.812 A 14 16,415:9 7,095.5 69.15 GAUGE Camco 4 1/2"Gauge Mandrel(See Below) 3.879 16,507.6 7,127,8 69.46 NIPPLE HES XN NIPPLE 3.813"(3.725"NoGo)with RHC plug 3,812 _- 16,890.9 7,238.2 78.65 XO-Reducing X0,4 1/2"12.68 IBT-M X 3 1l2"9.3#Ik EUE-M 2.992 •ell► 16,923.9 7,244.8 79.60 LOCATOR Pup Joint-3 1/2",9.3#,EUE w/LOCATOR 2.990 16,934.4 7,248.1 82.33 SEAL ASSY SEAL ASSEMBLY,80-40 GBH-22 2 12 Mule Shoe(Below Locator) 2.990 Notes General&Safety End Date Annotation ► 2/112011 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 4 Mandrel Dotails 4 ► Top Depth Top Port (TVD) Ind OD Valve Latch Size TRO Run 4 ► Sir TopittiO3), MB) I") Maks Model (In) Sere Type Type (in) (pm) Run Date Com,,, 1 6,148.2 3,401.0 68.81 CAMCO KBMG 1 GAS UFT IDMY BK 0.000 0.0 2/62011 LINER, 2 12,261 6 5,598.4 69.39 CAMCO KBMG 1 GAS UFT DMY BK 0.000 0.0 2162011 16,90622,648 _- TD,22,658 • 3 16,311 8 7,058/6943 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 2,500,0 2/62011 • i Overview: CD2-77 was drilled and completed on 7-Feb-11. A fracture stimulation is planned prior to putting the well on production. A 3-1/2" ported sleeve system was run in the openhole section with swell packers. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU sixteen clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 4000 bbls are required for the treatment) 2. Rig up Schlumberger equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 250 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 15-20 BPM with a maximum pressure of 4750 psi, add breaker as per lab results. Maintain 3000 psi on the IA during the treatment. • 30Q bbls YF125ST Pad • 951 bbls YF125ST w/ 1 ppa 16/30 White Sand • 95 bbls YF125ST w/2 ppa 16/30 White Sand • 180 bbls YF125ST w/4 ppa 16/30 While • 140 bbls YF125ST w/6 ppa 16/30 White Sand • 110 bbls YF 125ST w/7 ppa 16/30 White Sand • Drop ball and repeat 7 more times • Flush with linear fluid and freeze protect Total Sand: —800,000 lbs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. RECEIV5D STATE OF ALASKA FEB 1 7 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION RffiDdiffalliellistainomrnission la.Well Status: Oil Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended V lb.Well ClassAnchwBMM 20AAC 25.105 20AAC 25.110 Development 2rvExploratory ❑ GINJ INJ WAG ❑ WDSPL No.of Completionss:irvi. (VII ' C1 WCI ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp" 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: February'2011 210-179/ • 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 January 3,2011 • 50-103-20629-00• 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2220'FNL,2083'FEL,Sec.2,T11N, R4E, UM January 31,2011 CD2-77 Top of Productive Horizon: 8.KB(ft above MSL): p 15.6'RKBh.,15.Field/Pool(s): 274'FSL,2109'FEL,Sec. 13,T11 N,R4E,UM GL(ft above MSL):• 452'AMSL FYil Colville River Field Total Depth: 9.Plug Back Depth(MD+TVD): I.I1 126'FSL,96'FEL,Sec.24,T11 N,R4E,UM 22648'MD/7362'TVD Alpine Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: • Surface: x-371150.5 • y- 5974147. Zone-4 • 22658'MD/7362'TVD • ADL 380075,380077,384209' TPI: x-376187 y- 5960715 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-378112 y- 5955255 Zone-4 2209'MD/1930'TVD Tobin 932034,932036,932087 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1633'MD/1552'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 ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 36' 114' 36' 114' 24" 5.5 sx Portland Ill „t,.k 10.75" 45.5# L-80 36' 3390' / 36' 2393' 13.5" 529 sx AS Lite,275 sx Class G tqT• 7.625" 29.7# L-80 34' 17344' 34' 7298' 9.875" 450 sx Class G,290 sx Class G Prot 3.5" 9.3# L-80 16905' 22648' 7241' 7362' 6.75" liner 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5"/3.5" 16891'/16953' 16906'MD/7241'TVD none 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on post-rig work Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> 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 a Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. ar ... IONE VALf RBDMS FEB 17 2011 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only2/6 3 •Ltif 1)"1.1(1l( ,,,e 1 G 28. GEOLOGIC MARKERS(List all formations and markers .'countered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ 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 1633' 1552' needed,and submit detailed test information per 20 AAC 25.071. C-30 3435' 2410' C-20 4449' 2781' K-3 7387' 3847' K-2 8036' 4082' Nanuq 13848' 6172' K-1 16089' 6981' Kuparuk 16230' 7030' Alpine 16817' 7222' N/A Formation at total depth: Alpine C 30. LIST OF ATTACHMENTS i Summary of Daily Operations,schematic,final directional survey yitm - Ido Zo I t 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Winfree @ 265-6820 Printed Name q.L.Alvord Title: Alaska Drilling Manager ' / Signature /(� Phone 263-4619 Date 2_f(612.0e 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 1a: 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 '.. WNS CD2-77 t� Conocorhi llips ( Well_Attributes Max Angle&MD TD Alaska1fN- I I Wellbore APUUWI Field Name Well Status Inc!(1 I MD(BOB) Act Bim(ftKB) 501032062900 ,ALPINE PROD 91.52 18078.88 22.658.0 Comment H25(ppm) Date An solation End Date KB-Card(ft) Rig Release Date We1.C4.n69.I109SAN.TN,,.n.S .Z.5/182811$9736 AM SSSV:NIPPLE Last WO- 43.80 2/9/2011 _SV _Rrf. -_ swamps,Almrl Annotation (Depth(ftKB) End Date (Annotation Last Mod By End Date Last.Tag _.. Rev Reason:NEW WELL Imosbor 2/10/2011 HANGER,31 --__- '- -. - __ ___.. Casing Strings Casing Description String 0 String ID...Top(ftKB) Set Depth(t...Set Depth(TVD) String Wt...String String Top Thrd -_-- r CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 Hd0 Welded _ C- - -- - W Casing Deuription Sting 0... String ID...Top(BOB) Set Depth(i...Set Depth(TVD) String Wt...String...String Top Thrd CONDUCTOR• SURFACE 10 3/4 9.950 36.5 3,390.5 2 393.6 45.50 L80 BTCM 37-111 _ - -Casing Description Description Sting 0." String ID._Top(ftKB) Set Depth(t Set Depth(TVD) String Wt...String...String Tap Thrd NIPPLE,2,209 INTERMEDIATE 7 5/8 6.875 34.0 17,344.0 7,297.5 29.70 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(TVD)...String Wt...String...String Top Thrd LINER 312 2.992 16,905.6 22,648.0 7,362.2 9.20 L-80 SLHT Liner Details Top Depth SURFACE,_ ., ' MO) Top Ind Nomi... 363,391 Top(rlO6). (ftKB) 0 Rent Description Comment ID(in) 1 16,905.6 7,241.3 79.07 PACKER Baker 5.5 by 7.625 HRO ZXP LINER TOP PACKER w/Hold Downs 4.950 GAsur,118 Alli. 16,924.5 7,245.0 79.62 NIPPLE BAKER RS NIPPLE 4.870 6 'lk> 16,927.3 7,245.5 79.70 HANGER BAKER 5.5"by T625"FLEX LOCK HANGER 4.830 16,938.9 7,248.7 82.37 SBE Baker 80-40 Seal Bore Extension(20') 4.000 16,958.0 7,251.4 82.53 XO-Reducing XO 5"Hydril 521 Box by 3.5"SLHT Pin 16,996.7 7,256.6 82.86 NIPPLE HES XN NIPPLE 2.813"(2.75"No-Go) 2.750 GAS UFT, *"' . 17,400.2 7,303.8 84.07 Centralizer 37:"Pup w/62 Centralizer SLHT Box X Pin 2.992 GAS, 2.262 q ,�,,,f 17,404.8 7,304.3 84-15 ECP Swell Packer(3 1/2"SLHT)OD 6.38"w/10'sealing element 2.992 )--� 17,415.7 7,303.3 84-60 Centralizer 315"Pup w/6%"Centralizer SLHT Box X Pin 2.992 GAS UFT, _. 17,735.3 7,315.2 88.63 SLEEVE-C 3 12"SLHT Ball Actuated Sleeve(2.000"Seat ID)(2.125"Ball) 2.000 16.312 y�._._.; 18,058.1 7,316.8 91.93 Centralizer 3'A"Pup w/6%"Centralizer SLHT Box X Pin 2.992 NIPPLE.11,307 --- --T"I 18,062.7 7,316.6 91.84 ECP Swell Packer(3 1/2"SLHT)OD 6.38"w/10'sealing element 2.992 !--j 18,073.6 7,316.2 91.63 Centralizer 3 14"Pup w/6%"Centralizer SLHT Box X Pin 2.992 L. GAUGE,16,416- 4 K___.1 ( 18,361.9 7,317.7 89.58 SLEEVE-C 3 1/2"SLHT Ball Actuated Sleeve(1.875"Seat ID)(2.000"Ball) 1.875 'rt-i.:: 18,681.1 7,324.0 88.83 Centralizer 3Y"Pup wl 6'ACentralizer SLHT Box X Pin 2.992 NIPPLE,16,608-- - 18,685 5 7,324.0 88.85 ECP Swell Packer(3 12"SLHT)OD 6.38"w/10'sealing element 2.992 k- - '-^.§ 18,696.4 7,3242 88.91 Centralizer 3%'Pup w/6 Si"Centralizer SLHT Box X Pin 2.992 19,013.5 7,333.0 90.84 Centralizer 3%'Pup w/6 h"Centralizer SUIT Box X Pin 2.992 19,017.9 7,332.9 90.71 ECP Swell Packer(3 12"SLHT)OD 6.38"w/10'sealing element 2.992 LOCA16,921 TOR._,_. 19,028.8 7,332.8 90.40 Centralizer 3'/,"Pup w/6''A"Centralizer SLHT Box X Pin 2.992 ,7 19,314.2 7,338.6 88.07 SLEEVE- 3 1/2"SLHT Ball Actuated Sleeve(1.750"Seat ID)(1.875"Ball) 1.750 SEAL ASSY, 0 19,601.4 7,347.9 89.75 Centralizer 3 WPup w/6 54"Centralizer SLHT Box X Pin 2.992 6,931 19,606.0 7,348.4 90.77 ECP Swell Packer(3 1/2"SLHT)OD 6.38"w/10'sealing element 2.992 I ( 19,616.9 7,348.3 90.81 Centralizer 3%"Pup w/6'A"Centralizer SLHT Box X Pin 2.992 MI 19,905.8 7,343.0 90.73 SLEEVE-C 3 12"SLHT Ball Actuated Sleeve(1.625"Seat ID)(1.750"Ball) 1.625 20,191.9 7,342.6 88.41 Centralizer 3 h"Pup w/6 h"Centralizer SLHT Box X Pin 2.992 I 20,196.5 7,342.7 88.45 ECP Swell Packer(3 1/2"SLHT)OD 6.38"w/10'sealing element 2.992 20,207.5 7,343.1 88.52 Centralizer 3 fa"Pup w/6%"Centralizer SLHT Box X Pin 2.992 1 20,495.6 7,347.3 89.40 SLEEVE- 3 1/2"SLHT Ball Actuated Sleeve(1.500"Seat ID)(1.625"Ball) 1.500 NTEEDw 20,784.8 7,348.7 89.53 Centralizer 3 h"Pup w/6 hPin"Centralizer SLHT Box X 2.992 34.17,344 4. I. 20,789.3 7,348.8 89.54 ECP Swell Packer(3 1/2"SLHT)OD 6.38"w/10'sealing element 2.992 4 ► 20,800.3 7,348.9 89.58 Centralizer 31/2"Pup w/611"Centralizer SLHT Box X Pin 2.992 21,087.3 7,349.0 90.04 SLEEVE-C 3 1/2"SLHT Ball Actuated Sleeve(1.375"Seat ID)(1.500"Ball) 1.375 21,405.6 7,348.3 90.70 Centralizer 3%'Pup wl 6'A"Centralizer SLHT Box X Pin 2.992 21,410.2 7,348.3 90.74 ECP Swell Packer(3 12 SLHT)OD 6.38"w/10 sealing element 2.992 4 ► 21,421.1 7,343.1 85.98 Centralizer .3'22'Pup w/6 2 Centralizer SLHT Box X Pin 2.992 21,710.0 7,353.4 89.47 SLEEVE-C 3 1/2"SLHT Ball Actuated Sleeve(1.250 Seat ID)(1.375"Ball) 1.250 21,998.0 7,358.6 89.05 Centralizer �'13 h"Pup w/6%"Centralizer SLHT Box X Pin 2.992 .111P 22,002.6 7,358_6 89.05 ECP Swell Packer(3 1/2"SLHT)OD 6.38"w/10'sealing element 2.992 r ► 22,013.6 7,358.8 89.03 Centralizer 3%"Pup w/6'A"Centralizer SLHT Box X Pin 2.992 • 4 Tubing Strings tr - Tubing Description String 0.... String ID...Top(ftKB) Sat Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 4 ► TUBING I 41/2 3.958 I 31.0 16,953. 9 I 7,250.9 12.60 L-80 IBTM Completion Details Top Depth r ► (TND) Top Incl Top(iftu99 (ftKB) C) Mem Description Comment ID(in) 4 ► 31.0 31.0 -0.08 HANGER Tubing hanger 4.000 2,209.2 1,930.4 58.83 NIPPLE 4 12"Camco BP-6i(5.591"0.0.)w/3.813"DB-prole 3.812 16,367.1 7,077.8 68.99 NIPPLE HES x NIPPLE 3.813"X-profile 3.812 16,415.9 7,095.5 69.15 GAUGE Camco4 1/2"Gauge Mandrel(See Below) 3.879 II► 16,507.6 7,127.8 69.46 NIPPLE HES XN NIPPLE 3.813"(3.725"NoGo)with RHC plug 3.812 16,890.9 7,238.2 78.65 X01 Reducing XO.4 1/2'12.68 IBT-M X 3 1/2"9.3#/ft EUE-M 2.992 4 ► 16,923.9 7,244.8 79.60 LOCATOR Pup Joint-3 12"9.311,EUE w/LOCATOR 2.990 10934.4 7,248.1 82.33 SEAL ASSY SEAL ASSEMBLY,80-40 GBH-22 2 1/2 Mule Shoe(Below Locator) 2.990 ► Notes:General&Safety End Date Annotation r1r. ► 2/11/2011 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 r Mandrel Details ` ,.,,V""''1 . _ 4 ► Top Depth Top 1 Pod } (TVD) Incl OD Valve Latch Size TRO Run 4 I. Sin Top(ftKB)_ (BOB) (") Make Model (in) i Sery 1 Type Type (in) (ps0 Run Date Com... 1 6,148.2 3,401.0 68.81 CAMCO KBMG 1 GAS LIFT IDMY BK 0.000 0.0 2/6/2011 • LINER, 2 12,261.6 5,5984 69.39 CAMCO KBMG 1IGAS LIFT DMY BK 0.000 0.0 2/6/2011 16,906.22,610\ - ^---- - - • TD,22,666 3 16,311.8 7,058.7 69.43 CAMCO KBMG 1'GAS LIFT ',SOV BEK 0.000 2,500.0 2/6/2011 . I u • w • A Uga 4 4,?,a 14 tf t 4 • rk ConocoPhillips(Alaska) Inc w 8 Western North Slope CD2 Alpine Pad ri CD2-77 501032062900 4 Ai tiO g Sperry Drilling • r x Definitive SurveyRe ort p • p 441 11 February, 2011 0 2 4 r k �W HALLIBURTON Sperry Drilling ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD2-77 Project: Western North Slope TVD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) • Site: CD2 Alpine Pad MD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Well: CD2-77 North Reference: True • Wellbore: CD2-77 Survey Calculation Method: Minimum Curvature Design: CD2-77 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 CD2-77 Well Position +N/-S 0.00 ft Northing: 5,974,146.93 ft • Latitude: 70°20'15.268 N +E/-W 0.00 ft Easting: 371,150.53 ft • Longitude: 151"2'43.773W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0 15.60ft Wellbore CD2-77 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 12/10/2010 20.83 80.72 57,642 Design CD2-77 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.60 I Vertical Section: Depth From(TVD) +N/-S +E/-W Direction I (ft) (ft) (ft) (°) 36.60 0.00 0.00 160.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 356.00 CD2-77 Gyro(R100)(CD2-77) CB-GYRO-SS Camera based gyro single shot 1/4/2011 12:0C 448.00 448.00 CD2-77 Gryo(R200)(CD2-77) CB-GYRO-SS Camera based gyro single shot 1/4/2011 12:0C 541.00 818.00 CD2-77 Gyro(R100)(CD2-77) CB-GYRO-SS Camera based gyro single shot 1/4/2011 12:0C 912.00 912.00 CD2-77 Gyro(R200)(CD2-77) CB-GYRO-SS Camera based gyro single shot 1/4/2011 12:0C 967.99 3,353.55 CD2-77 MWD(R300)(CD2-77) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/4/2011 12:0C 3,411.89 17,328.70 CD2-77 MWD(R400)(CD2-77) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/9/2011 12:0C 17,409.25 22,589.98 CD2-77 MWD(R600)(CD2-77) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/26/2011 12:C 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 36.60 0.00 0.00 36.60 -15.60 0.00 0.00 5,974,146.93 371,150.53 0.00 0.00 UNDEFINED 100.00 0.17 74.85 100.00 47.80 0.02 0.09 5,974,146.95 371,150.62 0.27 0.01 CB-GYRO-SS(1) 171.00 0.24 112.26 171.00 118.80 0.00 0.33 5,974,146.92 371,150.86 0.21 0.12 CB-GYRO-SS(1) 263.00 0.67 162.77 263.00 210.80 -0.59 0.67 5,974,146.33 371,151.19 0.60 0.78 CB-GYRO-SS(1) 356.00 1.41 179.86 355.98 303.78 -2.25 0.83 5,974,144.66 371,151.32 0.85 2.40 CB-GYRO-SS(1) 448.00 1.82 183.25 447.94 395.74 -4.85 0.75 5,974,142.07 371,151.20 0.46 4.81 CB-GYRO-SS(2) 541.00 3.14 192.55 540.86 488.66 -8.81 0.11 5,974,138.13 371,150.49 1.48 8.31 CB-GYRO-SS(3) 633.00 7.39 198.64 632.45 580.25 -16.88 -2.33 5,974,130.10 371,147.92 4.65 15.06 CB-GYRO-SS(3) 726.00 9.16 193.55 724.48 672.28 -29.74 -5.97 5,974,117.30 371,144.05 2.06 25.90 CB-GYRO-SS(3) 2/11/2011 2:38:14PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD2-77 Project: Western North Slope TVD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Site: CD2 Alpine Pad MD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Well: CD2-77 North Reference: True Wellbore: CD2-77 Survey Calculation Method: Minimum Curvature Design: CD2-77 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 818.00 13.06 185.54 814.74 762.54 -47.21 -8.69 5,974,099.88 371,141 03 4.55 41.39 CB-GYRO-SS(3) 912.00 15.25 182.82 905.88 853.68 -70.13 -10.33 5,974,076.99 371,139.00 2.43 62.37 CB-GYRO-SS(4) 967.99 16.72 178.29 959.71 907.51 -85.54 -10.45 5,974,061.59 371,138.62 3.44 76.81 MWD+IFR-AK-CAZ-SC(5) 1,061.65 20.14 177.56 1,048.55 996.35 -115.13 -9.36 5,974,031.99 371,139.20 3.66 104.98 MWD+IFR-AK-CAZ-SC(5) 1,157.13 21.77 177.58 1,137.71 1,085.51 -149.24 -7.91 5,973,997.86 371,140.06 1.71 137.54 MW D+I FR-AK-CAZ-SC(5) 1,251.98 23.34 176.56 1,225.30 1,173.10 -185.57 -6.04 5,973,961.50 371,141.30 1.71 172.32 MWD+I FR-AK-CAZ-SC(5) 1,346.89 26.06 173.49 1,311.53 1,259.33 -225.06 -2.55 5,973,921.96 371,144.12 3.17 210.62 MWD+IFR-AK-CAZ-SC(5) 1,441.46 30.77 170.94 1,394.68 1,342.48 -269.62 3.62 5,973,877.31 371,149.52 5.14 254.59 MWD+IFRAK-CAZ-SC(5) 1,489.11 32.43 170.27 1,435.27 1,383.07 -294.25 7.70 5,973,852.62 371,153.17 3.56 279.14 MWD+IFR-AK-CAZ-SC(5) 1,535.55 34.02 170.05 1,474.11 1,421.91 -319.32 12.05 5,973,827.48 371,157.09 3.43 304.18 MWD+IFR-AK-CAZ-SC(5) 1,629.75 37.10 168.44 1,550.74 1,498.54 -373.12 22.30 5,973,773.51 371,166.41 3.42 358.25 MWD+IFR-AK-CAZ-SC(5) 1,725.46 40.89 166.67 1,625.11 1,572.91 -431.91 35.31 5,973,714.51 371,178.41 4.13 417.94 MWD+IFR-AK-CAZ-SC(5) 1,819.72 44.96 165.87 1,694.12 1,641.92 -494.25 50.56 5,973,651.92 371,192.59 4.36 481.74 MWD+IFR-AK-CAZ-SC(5) 1,914.21 49.69 166.86 1,758.15 1,705.95 -561.75 66.91 5,973,584.16 371,207.77 5.06 550.75 MWD+IFR-AK-CAZ-SC(5) 1,959.37 51.16 166.97 1,786.92 1,734.72 -595.65 74.79 5,973,550.13 371,215.07 3.26 585.31 MWD+IFR-AK-CAZ-SC(5) 2,004.09 52.16 167.30 1,814.66 1,762.46 -629.85 82.60 5,973,515.81 371299.29 2.31 620.11 MWD+IFR-AK-CAZ-SC(5) 2,103.12 55.52 166.65 1,873.09 1,820.89 -707.73 100.62 5,973,437.63 371,238.97 3.43 699.46 MWD+IFR-AK-CAZ-SC(5) 2,196.87 58.63 165.24 1,924.04 1,871.84 -784.05 119.75 5,973,361.00 371,256.78 3.55 777.72 MWD+I FR-AK-CAZ-SC(5) 2,288.55 60.11 163.60 1,970.75 1,918.55 -860.03 140.94 5,973,284.67 371,276.66 2.23 856.37 MWD+IFR-AK-CAZ-SC(5) 2,384.59 61.78 162.62 2,017.39 1,965.19 -940.36 165.34 5,973,203.95 371,299.67 1.95 940.20 MWD+IFR-AK-CAZ-SC(5) 2,475.98 63.73 163.63 2,059.23 2,007.03 -1,018.11 188.92 5,973,125.81 371,321.91 2.35 1,021.32 MWD+IFR-AK-CAZ-SC(5) 2,572.43 67.48 164.33 2,099.06 2,046.86 -1,102.52 213.15 5,973,041.00 371,344.68 3.94 1,108.93 MWD+IFR-AK-CAZ-SC(5) 2,669.24 69.77 165.73 2,134.34 2,082.14 -1,189.61 236.42 5,972,953.54 371,366.46 2.72 1,198.73 MWD+IFR-AK-CAZ-SC(5) 2,761.52 68.19 164.02 2,167.44 2,115.24 -1,272.76 258.89 5,972,870.02 371,387.49 2.43 1,284.55 MWD+IFR-AK-CAZ-SC(5) 2,858.24 66.90 162.61 2,204.39 2,152.19 -1,358.38 284.55 5,972,783.98 371,411.67 1.90 1,373.78 MWD+IFR-AK-CAZ-SC(5) 2,953.38 69.60 162.78 2,239.64 2,187.44 -1,442.74 310.83 5,972,699.18 371,436.50 2.84 1,462.04 MWD+IFR-AK-CAZ-SC(5) 3,048.23 69.99 162.26 2,272.40 2,220.20 -1,527.64 337.57 5,972,613.84 371,461.77 0.66 1,550.97 MWD+IFR-AK-CAZ-SC(5) 3,142.99 69.71 162.57 2,305.04 2,252.84 -1,612.44 364.44 5,972,528.60 371,487.19 0.43 1,639.85 MWD+IFR-AK-CAZ-SC(5) 3,237.26 69.21 162.39 2,338.12 2,285.92 -1,696.62 391.02 5,972,443.98 371,512.31 0.56 1,728.04 MWD+IFR-AK-CAZ-SC(5) 3,327.66 68.86 162.49 2,370.46 2,318.26 -1,777.10 416.49 5,972,363.08 371,536.39 0.40 1,812.38 MWD+IFR-AK-CAZ-SC(5) 3,353.55 68.38 162.65 2,379.90 2,327.70 -1,800.11 423.71 5,972,339.96 371,543.21 1.94 1,836.46 MWD+IFR-AK-CAZ-SC(5) 3,411.89 68.32 163.04 2,401.42 2,349.22 -1,851.92 439.70 5,972,287.88 371,558.31 0.63 1,890.62 MWD+IFR-AK-CAZ-SC(6) 3,505.17 67.96 163.40 2,436.16 2,383.96 -1,934.80 464.70 5,972,204.59 371,581.88 0.53 1,977.06 MWD+IFR-AK-CAZ-SC(6) 3,600.99 67.77 163.75 2,472.26 2,420.06 -2,019.94 489.79 5,972,119.04 371,605.51 0.39 2,065.64 MWD+IFR-AK-CAZ-SC(6) 3,696.57 67.96 164.67 2,508.27 2,456.07 -2,105.13 513.88 5,972,033.45 371,628.13 0.91 2,153.94 MWD+IFR-AK-CAZ-SC(6) 3,790.32 68.50 165.27 2,543.04 2,490.84 -2,189.22 536.46 5,971,949.00 371,649.25 0.83 2,240.67 MWD+IFR-AK-CAZ-SC(6) 3,884.79 68.69 165.24 2,577.52 2,525.32 -2,274.27 558.85 5,971,863.57 371,670.17 0.20 2,328.26 MWD+IFR-AK-CAZ-SC(6) 3,979.70 68.56 166.16 2,612.11 2,559.91 -2,359.92 580.68 5,971,777.58 371,690.53 0.91 2,416.20 MWD+IFR-AK-CAZ-SC(6) 4,072.25 68.65 165.63 2,645.88 2,593.68 -2,443.49 601.68 5,971,693.66 371,710.09 0.54 2,501.92 MWD+IFR-AK-CAZ-SC(6) 4,168.82 69.41 164.76 2,680.44 2,628.24 -2,530.67 624.72 5,971,606.11 371,731.63 1.15 2,591.72 MWD+IFR-AK-CAZ-SC(6) 2/11/2011 2:38:14PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD2-77 Project: Western North Slope TVD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Site: CD2 Alpine Pad MD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Well: CD2-77 North Reference: True Wellbore: CD2-77 Survey Calculation Method: Minimum Curvature Design: CD2-77 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 00') (ft) Survey Tool Name 4,263.50 69.36 163.24 2,713.77 2,661.57 -2,615.85 649.15 5,971,520.53 371,754.58 1.50 2,680.12 MWD+IFR-AK-CAZ-SC(6) 4,357.73 68.49 162.80 2,747.66 2,695.46 -2,699.94 674.82 5,971,436.01 371,778.81 1.02 2,767.92 MWD+IFR-AK-CAZ-SC(6) 4,452.78 68.12 162.67 2,782.79 2,730.59 -2,784.28 701.03 5,971,351.24 371,803.57 0.41 2,856.14 MWD+IFR-AK-CAZ-SC(6) 4,547.23 68.61 162.38 2,817.62 2765.42 -2,868.02 727.40 5,971267.06 371,828.49 0.59 2,943.85 MWD+IFR-AK-CAZ-SC(6) 4,641.93 68.63 162.30 2,852.14 2,799.94 -2,952.05 754.15 5,971,182.60 371,853.79 0.08 3,031.96 MWD+IFR-AK-CAZ-SC(6) 4,736.13 68.68 162.76 2,886.43 2834.23 -3,035.74 780.49 5,971,098.47 371,878.68 0.46 3,119.61 MWD+IFR-AK-CAZ-SC(6) 4,831.35 68.50 162.76 2,921.19 2,868.99 -3,120.41 806.76 5,971,013.37 371,903.50 0.19 3,208.15 MWD+IFR-AK-CAZ-SC(6) 4,924.42 68.76 162.88 2,955.10 2,902.90 -3,203.21 832.36 5,970,930.15 371,927.67 0.30 3,294.72 MWD+IFR-AK-CAZ-SC(6) 5,019.49 68.91 163.71 2,989.43 2,937.23 -3,288.13 857.85 5,970,844.82 371,951.69 0.83 3,383.23 MWD+IFR-AK-CAZ-SC(6) 5,113.82 68.52 163.49 3,023.67 2,971.47 -3,372.45 882.66 5,970,760.09 371,975.05 0.47 3,470.95 MWD+IFR-AK-CAZ-SC(6) 5,208.64 68.64 163.95 3,058.30 3,006.10 -3,457.18 907.41 5,970,674.95 371,998.33 0.47 3,559.04 MWD+IFR-AK-CAZ-SC(6) 5,303.40 69.04 163.80 3,092.50 3,040.30 -3,542.07 931.95 5,970,589.66 372,021.41 0.45 3,647.20 MWD+1FR-AK-CAZ-SC(6) 5,398.02 69.02 164.03 3,126.37 3,074.17 -3,626.97 956.43 5,970,504.36 372,044.43 0.23 3,735.35 MWD+IFR-AK-CAZ-SC(6) 5,492.72 68.90 164.00 3,160.37 3,108.17 -3,711.93 980.77 5,970,418.99 372,067.30 0.13 3,823.52 MWD+IFR-AK-CAZ-SC(6) 5,587.58 68.56 164.25 3,194.78 3,142.58 -3,796.96 1,004.95 5,970,333.57 372,090.01 0.43 3,911.69 MWD+IFR-AK-CAZ-SC(6) 5,681.58 68.30 164.45 3,229.33 3,177.13 -3,881.14 1,028.53 5,970,249.01 372,112.14 0.34 3,998.86 MWD+IFR-AK-CAZ-SC(6) 5,777.33 68.30 163.86 3,264.74 3,212.54 -3,966.72 1,052.82 5,970,163.03 372,134.96 0.57 4,087.59 MWD+IFR-AK-CAZ-SC(6) 5,871.05 68.50 163.59 3,299.24 3,247.04 -4,050.37 1,077.24 5,970,078.98 372,157.94 0.34 4,174.54 MWD+IFR-AK-CAZ-SC(6) 5,965.43 68.37 164.48 3,333.93 3,281.73 -4,134.75 1,101.39 5,969,994.20 372,180.62 0.89 4,262.09 MWD+IFR-AK-CAZ-SC(6) 6,059.83 68.37 164.40 3,368.73 3,316.53 -4,219.29 1,124.93 5,969,909.28 372,202.71 0.08 4,349.58 MWD+IFR-AK-CAZ-SC(6) 6,151.92 68.83 164.36 3,402.33 3,350.13 -4,301.87 1,148.01 5,969,826.32 372,224.37 0.50 4,435.07 MWD+IFR-AK-CAZ-SC(6) 6,249.05 69.08 163.84 3,437.21 3,385.01 -4,389.05 1,172.85 5,969,738.74 372,247.70 0.56 4,525.49 MWD+IFR-AK-CAZ-SC(6) 6,343.29 69.16 163.37 3,470.80 3,418.60 -4,473.52 1,197.70 5,969,653.86 372,271.09 0.47 4,613.37 MWD+IFR-AK-CAZ-SC(6) 6,437.55 69.16 163.28 3,504.33 3,452.13 -4,557.91 1,222.98 5,969,569.05 372,294.92 0.09 4,701.31 MWD+IFR-AK-CAZ-SC(6) 6,532.21 68.77 163.21 3,538.31 3,486.11 -4,642.51 1,24845 5,969,484.03 372,318.93 0.42 4,789.52 MWD+IFR-AK-CAZ-SC(6) 6,627.48 68.70 163.51 3,572.86 3,520.66 -4,727.57 1,273.87 5,969,398.55 372,342.88 0.30 4,878.16 MWD+IFR-AK-CAZ-SC(6) 6,717.28 68.82 164.11 3,605.39 3,553.19 -4,807.95 1,297.21 5,969,317.79 372,364.83 0.64 4,961.67 MWD+I FR-AK-CAZ-SC(6) 6,815.36 69.02 162.95 3,640.67 3,588.47 -4,895.71 1,323.15 5,969,229.60 372,389.27 1.12 5,053.01 MWD+IFR-AK-CAZ-SC(6) 6,910.09 69.02 162.57 3,674.59 3,622.39 -4,980.19 1,349.37 5,969,144.70 372,414.02 0.37 5,141.36 MWD+IFR-AK-CAZ-SC(6) 7,004.54 69.09 162.74 3,708.35 3,656.15 -5,064.39 1,375.67 5,969,060.07 372,438.87 0.18 5,229.47 MWD+IFR-AK-CAZ-SC(6) 7,097.48 68.91 162.49 3,741.66 3,689.46 -5,147.19 1,401.59 5,968,976.84 372,463.36 0.32 5,316.15 MWD+IFR-AK-CAZ-SC(6) 7,193.53 68.71 162.31 3,776.38 3,724.18 -5,232.55 1,428.67 5,968,891.03 372,488.97 0.27 5,405.63 MWD+IFR-AK-CAZ-SC(6) 7,288.06 68.51 162.57 3,810.85 3,758.65 -5,316.47 1,455.23 5,968,806.67 372,514.08 0.33 5,493.56 MWD+IFR-AK-CAZ-SC(6) 7,383.59 68.64 163.76 3,845.75 3,793.55 -5,401.59 1,480.98 5,968,721.14 372,538.36 1.17 5,582.36 MWD+IFR-AK-CAZ-SC(6) 7,478.12 69.22 165.58 3,879.74 3,827.54 -5,486.65 1,504.30 5,968,635.69 372,560.21 1.90 5,670.27 MWD+IFR-AK-CAZ-SC(6) 7,572.77 69.01 166.59 3,913.48 3,861.28 -5,572.49 1,525.56 5,968,549.51 372,580.00 1.02 5,758.20 MW D+I FR-AK-CAZ-SC(6) 7,667.49 68.84 163.85 3,947.54 3,895.34 -5,657.94 1,548.11 5,968,463.69 372,601.07 2.71 5,846.21 MWD+IFR-AK-CAZ-SC(6) 7,761.90 68.50 162.31 3,981.89 3,929.69 -5,742.07 1,573.70 5,968,379.14 372,625.21 1.56 5,934.02 MWD+IFR-AK-CAZ-SC(6) 7,855.93 68.76 159.61 4,016.16 3,963.96 -5,824.83 1,602.26 5,968,295.90 372,652.35 2.69 6,021.56 MWD+IFR-AK-CAZ-SC(6) 7,950.22 68.78 156.13 4,050.31 3,998.11 -5,906.24 1,635.37 5,968,213.95 372,684.05 3.44 6,109.37 MWD+IFR-AK-CAZ-SC(6) 2/11/2011 2:38:14PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD2-77 Project: Western North Slope TVD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Site: CD2 Alpine Pad MD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Well: CD2-77 North Reference: True Wellbore: CD2-77 Survey Calculation Method: Minimum Curvature Design: CD2-77 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) (°1100') (ft) Survey Tool Name 8,045.06 68.30 152.53 4,085.02 4,032.82 -5,985.77 1,673.59 5,968,133.77 372,720.89 3.57 6,197.19 MWD+IFR-AK-CAZ-SC(6) 8,139.82 68.12 152.62 4,120.19 4,067.99 -6,063.87 1,714.12 5,968,054.99 372,760.07 0.21 6,284.44 MWD+IFR-AK-CAZ-SC(6) 8,233.98 68.11 152.28 4,155.29 4,103.09 -6,141.34 1,754.53 5,967,976.85 372,799.14 0.34 6,371.06 MWD+IFR-AK-CAZ-SC(6) 8,326.61 69.34 152.08 4,188.90 4,136.70 -6,217.68 1,794.81 5,967,899.84 372,838.10 1.34 6,456.57 MWD+IFR-AK-CAZ-SC(6) 8,423.21 69.03 152.33 4,223.23 4,171.03 -6,297.56 1,836.92 5,967,819.25 372,878.83 0.40 6,546.03 MWD+IFR-AK-CAZ-SC(6) 8,517.40 68.56 152.97 4,257.29 4,205.09 -6,375.55 1,877.26 5,967,740.58 372,917.82 0.81 6,633.12 MWD+IFR-AK-CAZ-SC(6) 8,612.33 69.23 153.44 4,291.48 4,239.28 -6,454.60 1,917.18 5,967,660.86 372,956.38 0.84 6,721.06 MWD+IFR-AK-CAZ-SC(6) 8,706.66 69.29 151.83 4,324.88 4,272.68 -6,532.95 1,957.73 5,967,581.84 372,995.57 1.60 6,808.55 MWD+IFR-AK-CAZ-SC(6) 8,799.43 69.56 152.19 4,357.49 4,305.29 -6,609.64 1,998.49 5,967,504.47 373,035.00 0.47 6,894.56 MWD+IFR-AK-CAZ-SC(6) 8,894.85 69.31 154.20 4,391.01 4,338.81 -6,689.37 2,038.78 5,967,424.06 373,073.91 1.99 6,983.26 MWD+IFR-AK-CAZ-SC(6) 8,990.37 68.83 154.80 4,425.13 4,372.93 -6,769.90 2,077.19 5,967,342.89 373,110.93 0.77 7,072.07 MWD+IFR-AK-CAZ-SC(6) 9,084.73 68.85 155.72 4,459.19 4,406.99 -6,849.82 2,114.02 5,967,262.36 373,146.37 0.91 7,159.76 MWD+IFR-AK-CAZ-SC(6) 9,180.37 69.49 156.32 4,493.20 4,441.00 -6,931.49 2,150.34 5,967,180.08 373,181.29 0.89 7,248.93 MWD+IFR-AK-CAZ-SC(6) 9,274.27 69.37 156.05 4,526.19 4,473.99 -7,011.92 2,185.84 5,967,099.06 373,215.40 0.30 7,336.65 MWD+IFR-AK-CAZ-SC(6) 9,369.04 69.24 154.65 4,559.69 4,507.49 -7,092.49 2,222.82 5,967,017.87 373,250.98 1.39 7,425.01 MWD+IFR-AK-CAZ-SC(6) 9,463.40 68.95 154.34 4,593.36 4,541.16 -7,172.05 2,260.77 5,966,937.68 373,287.56 0.43 7,512.75 MWD+IFR-AK-CAZ-SC(6) 9,557.69 68.90 154.69 4,627.26 4,575.06 -7,251.47 2,298.63 5,966,857.62 373,324.04 0.35 7,600.33 MWD+IFR-AK-CAZ-SC(6) 9,652.21 69.02 154.59 4,661.20 4,609.00 -7,331.19 2,336.41 5,966,777.27 373,360.45 0.16 7,688.17 MWD+IFR-AK-CAZ-SC(6) 9,746.83 68.91 153.89 4,695.16 4,642.96 -7,410.73 2,374.79 5,966,697.10 373,397.45 0.70 7,776.03 MWD+IFR-AK-CAZ-SC(6) 9,842.00 68.89 153.44 4,729.42 4,677.22 -7,490.30 2,414.18 5,966,616.86 373,435.47 0.44 7,864.28 MWD+IFR-AK-CAZ-SC(6) 9,936.41 69.21 152.93 4,763.18 4,710.98 -7,568.99 2,453.96 5,966,537.51 373,473.88 0.61 7,951.83 MWD+IFR-AK-CAZ-SC(6) 10,030.66 68.97 153.10 4,796.81 4,744.61 -7,647.45 2,493.91 5,966,458.38 373,512.47 0.31 8,039.22 MWD+IFR-AK-CAZ-SC(6) 10,125.27 68.90 152.62 4,830.82 4,778.62 -7,726.01 2,534.18 5,966,379.14 373,551.39 0.48 8,126.82 MWD+IFR-AK-CAZ-SC(6) 10,219.78 69.02 152.30 4,864.75 4,812.55 -7,804.23 2,574.97 5,966,300.25 373,590.82 0.34 8,214.26 MWD+IFR-AK-CAZ-SC(6) 10,314.62 68.97 153.01 4,898.75 4,846.55 -7,882.87 2,615.64 5,966,220.92 373,630.13 0.70 8,302.08 MWD+IFR-AK-CAZ-SC(6) 10,408.84 69.23 153.21 4,932.36 4,880.16 -7,961.37 2,655.45 5,966,141.75 373,668.58 0.34 8,389.46 MWD+IFR-AK-CAZ-SC(6) 10,503.59 69.43 153.14 4,965.80 4,913.60 -8,040.48 2,695.45 5,966,061.97 373,707.22 0.22 8,477.48 MWD+IFR-AK-CAZ-SC(6) 10,598.02 69.02 153.05 4,999.30 4,947.10 -8,119.22 2,735.40 5,965,982.57 373,745.81 0.44 8,565.13 MWD+IFR-AK-CAZ-SC(6) 10,692.78 68.43 154.05 5,033.68 4,981.48 -8,198.27 2,774.73 5,965,902.86 373,783.77 1.16 8,652.87 MWD+IFR-AK-CAZ-SC(6) 10,787.36 68.37 153.85 5,068.50 5,016.30 -8,277.28 2,813.35 5,965,823.21 373,821.02 0.21 8,740.32 MWD+IFR-AK-CAZ-SC(6) 10,881.72 68.29 154.86 5,103.34 5,051.14 -8,356.33 2,851.30 5,965,743.52 373,857.61 1.00 8,827.59 MWD+IFR-AK-CAZ-SC(6) 10,976.54 69.16 154.99 5,137.75 5,085.55 -8,436.36 2,888.75 5,965,662.87 373,893.67 0.93 8,915.60 MWD+IFR-AK-CAZ-SC(6) 11,070.83 70.10 155.75 5,170.57 5,118.37 -8,516.71 2,925.59 5,965,581.90 373,929.12 1.25 9,003.70 MWD+IFR-AK-CAZ-SC(6) 11,165.66 69.42 155.43 5,203.38 5,151.18 -8,597.73 2,962.36 5,965,500.27 373,964.49 0.78 9,092.41 MWD+IFR-AK-CAZ-SC(6) 11,260.36 69.10 156.71 5,236.91 5,184.71 -8,678.68 2,998.28 5,965,418.72 373,999.01 1.31 9,180.76 MWD+IFR-AK-CAZ-SC(6) 11,354.81 69.17 153.45 5,270.56 5,218.36 -8,758.71 3,035.46 5,965,338.08 374,034.81 3.23 9,268.68 MWD+IFR-AK-CAZ-SC(6) 11,449.15 68.82 152.17 5,304.38 5,252.18 -8,837.04 3,075.70 5,965,259.06 374,073.69 1.32 9,356.06 MWD+IFR-AK-CAZ-SC(6) 11,544.12 68.64 152.34 5,338.83 5,286.63 -8,915.37 3,116.90 5,965,180.05 374,113.54 0.25 9,443.75 MWD+IFR-AK-CAZ-SC(6) 11,638.75 68.50 152.65 5,373.40 5,321.20 -8,993.50 3,157.58 5,965,101.24 374,152.87 0.34 9,531.08 MWD+IFR-AK-CAZ-SC(6) 11,733.21 68.43 154.27 5,408.08 5,355.88 -9,072.10 3,196.84 5,965,021.98 374,190.77 1.60 9,618.37 MWD+IFR-AK-CAZ-SC(6) 2/11/2011 2:38:14PM Page 5 COMPASS 2003.16 Build 69 s ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD2-77 Project: Western North Slope TVD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Site: CD2 Alpine Pad MD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Well: CD2-77 North Reference: True Wellbore: CD2-77 Survey Calculation Method: Minimum Curvature Design: CD2-77 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,827.28 68.95 154.60 5,442.27 5,390.0/ -9,151.16 3,234.66 5,964,942.29 374,227.22 0.64 9,705.60 MWD+IFR-AK-CAZ-SC(6) 11,921.65 68.83 154.66 5,476.25 5,424.05 -9,230.71 3,272.38 5,964,862.11 374,263.56 0.14 9,793.25 MWD+IFR-AK-CAZ-SC(6) 12,016.57 68.70 155.28 5,510.63 5,458.43 -9,310.87 3,309.81 5,964,781.32 374,299.61 0.62 9,881.38 MWD+IFR-AK-CAZ-SC(6) 12,111.52 69.04 155.75 5,544.86 5,492.66 -9,391.47 3,346.52 5,964,700.11 374,334.92 0.58 9,969.68 MWD+IFR-AK-CAZ-SC(6) 12,205.60 69.23 155.79 5,578.37 5,526.17 -9,471.64 3,382.60 5,964,619.34 374,369.62 0.21 10,057.35 MWD+IFR-AK-CAZ-SC(6) 12,300.58 69.17 155.44 5,612.10 5,559.90 -9,552.51 3,419.26 5,964,537.86 374,404.88 0.35 10,145.88 MWD+IFR-AK-CAZ-SC(6) 12,394.85 68.64 155.29 5,646.03 5,593.83 -9,632.46 3,455.92 5,964,457.30 374,440.16 0.58 10,233.54 MWD+IFR-AK-CAZ-SC(6) 12,489.24 68.45 154.87 5,680.55 5,628.35 -9,712.13 3,492.93 5,964,377.01 374,475.80 0.46 10,321.07 MWD+IFR-AK-CAZ-SC(6) 12,583.64 67.78 154.61 5,715.74 5,663.54 -9,791.35 3,530.31 5,964,297.17 374,511.80 0.75 10,408.29 MWD+IFR-AK-CAZ-SC(6) 12,678.15 68.65 154.34 5,750.81 5,698.61 -9,870.54 3,568.13 5,964,217.34 374,548.25 0.96 10,495.65 MWD+IFR-AK-CAZ-SC(6) 12,772.36 69.37 156.13 5,784.56 5,732.36 -9,950.41 3,604.97 5,964,136.86 374,583.71 1.93 10,583.30 MWD+IFR-AK-CAZ-SC(6) 12,867.25 69.76 153.44 5,817.70 5,765.50 -10,030.84 3,642.85 5,964,055.79 374,620.20 2.69 10,671.84 MWD+IFR-AK-CAZ-SC(6) 12,961.90 69.09 152.02 5,850.96 5,798.76 -10,109.60 3,683.45 5,963,976.35 374,659.43 1.57 10,759.73 MWD+IFR-AK-CAZ-SC(6) 13,056.96 68.82 152.99 5,885.10 5,832.90 -10,188.30 3,724.40 5,963,896.97 374,699.03 0.99 10,847.69 MWD+IFR-AK-CAZ-SC(6) 13,151.31 68.71 152.65 5,919.27 5,867.07 -10,266.53 3,764.58 5,963,818.06 374,737.85 0.36 10,934.95 MWD+IFR-AK-CAZ-SC(6) 13,245.97 69.04 152.56 5,953.39 5,901.19 -10,344.93 3,805.20 5,963,738.99 374,777.12 0.36 11,022.51 MWD+IFR-AK-CAZ-SC(6) 13,340.37 68.82 153.47 5,987.33 5,935.13 -10,423.43 3,845.18 5,963,659.82 374,815.74 0.93 11,109.94 MWD+IFR-AK-CAZ-SC(6) 13,434.93 68.58 152.61 6,021.68 5,969.48 -10,501.95 3,885.12 5,963,580.63 374,854.32 0.88 11,197.39 MWD+IFR-AK-CAZ-SC(6) 13,530.01 68.30 152.43 6,056.62 6,004.42 -10,580.40 3,925.92 5,963,501.50 374,893.76 0.34 11,285.07 MWD+IFR-AK-CAZ-SC(6) 13,624.66 68.62 153.34 6,091.37 6,039.17 -10,658.76 3,966.05 5,963,422.46 374,932.53 0.96 11,372.43 MWD+IFR-AK-CAZ-SC(6) 13,718.93 68.84 153.92 6,125.56 6,073.36 -10,737.47 4,005.06 5,963,343.10 374,970.19 0.62 11,459.74 MWD+IFR-AK-CAZ-SC(6) 13,813.56 69.22 154.53 6,159.43 6,107.23 -10,817.04 4,043.49 5,963,262.89 375,007.24 0.72 11,547.65 MWD+IFR-AK-CAZ-SC(6) 13,907.70 69.50 155.52 6,192.62 6,140.42 -10,896.90 4,080.68 5,963,182.41 375,043.05 1.03 11,635.41 MWD+IFR-AK-CAZ-SC(6) 14,002.49 69.75 154.77 6,225.62 6,173.42 -10,977.53 4,118.03 5,963,101.16 375,079.01 0.79 11,723.95 MWD+IFR-AK-CAZ-SC(6) 14,096.29 69.37 154.18 6,258.38 6,206.18 -11,056.84 4,155.91 5,963,021.21 375,115.51 0.72 11,811.44 MWD+IFR-AK-CAZ-SC(6) 14,191.79 68.78 153.24 6,292.48 6,240.28 -11,136.82 4,195.41 5,962,940.58 375,153.63 1.11 11,900.10 MWD+IFR-AK-CAZ-SC(6) 14,286.60 68.29 153.41 6,327.18 6,274.98 -11,215.66 4,235.02 5,962,861.07 375,191.88 0.54 11,987.74 MWD+IFR-AK-CAZ-SC(6) 14,381.18 68.67 153.57 6,361.87 6,309.67 -11,294.40 4,274.30 5,962,781.68 375,229.79 0.43 12,075.16 MWD+IFR-AK-CAZ-SC(6) 14,475.88 68.30 153.71 6,396.60 6,344.40 -11,373.34 4,313.41 5,962,702.08 375,267.55 0.41 12162.72 MWD+IFR-AK-CAZ-SC(6) 14,570.71 67.97 153.72 6,431.92 6,379.72 -11,452.25 4,352.39 5,962,622.52 375,305.15 0.35 12,250.19 MWD+IFR-AK-CAZ-SC(6) 14,665.02 68.77 153.99 6,466.68 6,414.48 -11,530.94 4,391.02 5,962,543.18 375,342.42 0.89 12,337.36 MWD+IFR-AK-CAZ-SC(6) 14,759.71 69.64 153.78 6,500.30 6,448.10 -11,610.43 4,429.98 5,962,463.05 375,380.01 0.94 12,425.38 MWD+IFR-AK-CAZ-SC(6) 14,854.02 68.96 153.15 6,533.64 6,481.44 -11,689.36 4,469.39 5,962,383.46 375,418.06 0.95 12,513.02 MWD+IFR-AK-CAZ-SC(6) 14,947.53 68.26 154.21 6,567.74 6,515.54 -11,767.40 4,508.00 5,962,304.77 375,455.32 1.29 12,599.56 MWD+IFR-AK-CAZ-SC(6) 15,042.64 67.71 154.40 6,603.39 6,551.19 -11,846.85 4,546.23 5,962,224.68 375,492.17 0.61 12,687.30 MWD+IFR-AK-CAZ-SC(6) 15,137.64 68.04 154.66 6,639.17 6,586.97 -11,926.30 4,584.07 5,962,144.60 375,528.64 0.43 12,774.90 MWD+IFR-AK-CAZ-SC(6) 15,232.88 68.90 155.33 6,674.13 6,621.93 -12,006.59 4,621.52 5,962,063.68 375,564.70 1.12 12,863.16 MWD+IFR-AK-CAZ-SC(6) 15,326.51 68.78 154.37 6,707.92 6,655.72 -12,085.63 4,658.63 5,961,984.02 375,600.44 0.96 12,950.12 MWD+IFR-AK-CAZ-SC(6) 15,421.42 69.04 154.61 6,742.08 6,689.88 -12,165.55 4,696.77 5,961,903.47 375,637.20 0.36 13,038.27 MWD+IFR-AK-CAZ-SC(6) 15,516.74 69.24 154.58 6,776.02 6,723.82 -12,246.01 4,734.98 5,961,822.37 375,674.02 0.21 13,126.94 MWD+IFR-AK-CAZ-SC(6) 2/11/2011 2:38:14PM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD2-77 Project: Western North Slope TVD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Site: CD2 Alpine Pad MD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Well: CD2-77 North Reference: True Wellbore: CD2-77 Survey Calculation Method: Minimum Curvature Design: CD2-77 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nt-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°I100') (ft) Survey Tool Name 15,610.47 68.69 154.70 6,809.66 6,757.46 -12,325.06 4,772.45 5,961,742.69 375,710.12 0.60 13,214.04 MWD+IFR-AK-CAZ-SC(6) 15,705.37 68.75 154.77 6,844.10 6,791.90 -12,405.03 4,810.19 5,961,662.09 375,746.48 0.09 13,302.10 MWD+IFR-AK-CAZ-SC(6) 15,799.04 68.96 153.92 6,877.89 6,825.69 -12,483.78 4,848.02 5,961,582.71 375,782.95 0.88 13,389.04 MWD+IFR-AK-CAZ-SC(6) 15,894.12 69.01 152.87 6,911.99 6,859.79 -12,563.14 4,887.76 5,961,502.69 375,821.32 1.03 13,477.20 MWD+IFR-AK-CAZ-SC(6) 15,988.27 68.77 153.53 6,945.90 6,893.70 -12,641.54 4,927.36 5,961,423.63 375,859.57 0.70 13,564.42 MWD+IFR-AK-CAZ-SC(6) 16,081.56 69.83 155.06 6,978.88 6,926.68 -12,720.16 4,965.21 5,961,344.37 375,896.05 1.91 13,651.25 MWD+IFR-AK-CAZ-SC(6) 16,177.55 69.82 154.87 7,011.98 6,959.78 -12,801.80 5,003.34 5,961,262.09 375,932.77 0.19 13,741.00 MWD+IFR-AK-CAZ-SC(6) 16,271.81 69.63 154.93 7,044.65 6,992.45 -12,881.87 5,040.85 5,961,181.40 375,968.89 0.21 13,829.07 MWD+IFR-AK-CAZ-SC(6) 16,365.75 69.15 154.78 7,077.71 7,025.51 -12,961.46 5,078.21 5,961,101.18 376,004.88 0.53 13,916.64 MWD+I FR-AK-CAZ-SC(6) 16,460.73 69.30 154.93 7,111.40 7,059.20 -13,041.85 5,115.94 5,961,020.16 376,041.22 0.22 14,005.09 MWD+IFR-AK-CAZ-SC(6) 16,553.56 69.61 154.12 7,143.98 7,091.78 -13,120.33 5,153.33 5,960,941.06 376,077.25 0.88 14,091.62 MWD+I FR-AK-CAZ-SC(6) 16,649.94 71.38 152.92 7,176.16 7,123.96 -13,201.64 5,193.84 5,960,859.08 376,116.36 2.18 14,181.88 MWD+IFR-AK-CAZ-SC(6) 16,744.39 74.03 152.74 7,204.24 7,152.04 -13,281.86 5,235.02 5,960,778.17 376,156.14 2.81 14,271.35 MWD+IFR-AK-CAZ-SC(6) 16,838.89 77.16 153.30 7,227.74 7,175.54 -13,363.42 5,276.53 5,960,695.91 376,196.25 3.36 14,362.18 MWD+IFR-AK-CAZ-SC(6) 16,933.28 79.87 153.07 7,246.54 7,194.34 -13,445.96 5,318.26 5,960,612.67 376,236.55 2.88 14,454.02 MWD+IFR-AK-CAZ-SC(6) 17,027.86 83.12 152.24 7,260.52 7,208.32 -13,529.04 5,361.22 5,960,528.88 376,278.07 3.54 14,546.78 MWD+IFR-AK-CAZ-SC(6) 17,122.35 83.92 151.92 7,271.19 7,218.99 -13,611.99 5,405.18 5,960,445.18 376,320.60 0.91 14,639.77 MWD+IFR-AK-CAZ-SC(6) 17,217.14 82.98 151.57 7,282.00 7,229.80 -13,694.94 5,449.76 5,960,361.49 376,363.74 1.06 14,732.97 MWD+IFR-AK-CAZ-SC(6) 17,310.13 82.93 151.44 7,293.40 7,241.20 -13,776.05 5,493.79 5,960,279.64 376,406.37 0.15 14,824.24 MWD+IFR-AK-CAZ-SC(6) 17,328.70 82.92 151.85 7,295.69 7,243.49 -13,792.27 5,502.54 5,960,263.27 376,414.84 2.19 14,842.47 MWD+I FR-AK-CAZ-SC(6) 17,409.25 84.22 151.68 7,304.71 7,252.51 -13,862.79 5,540.41 5,960,192.12 376,451.49 1.63 14,921.69 MWD+IFR-AK-CAZ-SC(7) 17,504.98 87.38 152.99 7,311.72 7,259.52 -13,947.33 5,584.73 5,960,106.83 376,494.34 3.57 15,016.30 MWD+IFR-AK-CAZ-SC(7) 17,600.27 90.35 153.19 7,313.61 7,261.41 -14,032.28 5,627.84 5,960,021.17 376,535.99 3.12 15,110.86 MWD+IFR-AK-CAZ-SC(7) 17,697.03 88.80 154.48 7,314.33 7,262.13 -14,119.12 5,670.51 5,959,933.62 376,577.15 2.08 15,207.06 MWD+IFR-AK-CAZ-SC(7) 17,792.27 88.37 154.91 7,316.68 7,264.48 -14,205.19 5,711.20 5,959,846.86 376,616.36 0.64 15,301.86 MWD+IFR-AK-CAZ-SC(7) 17,887.99 89.17 156.27 7,318.73 7,266.53 -14,292.33 5,750.75 5,959,759.06 376,654.40 1.65 15,397.27 MWD+IFR-AK-CAZ-SC(7) 17,983.77 91.27 157.41 7,318.37 7,266.17 -14,380.39 5,788.42 5,959,670.38 376,690.55 2.49 15,492.90 MWD+IFR-AK-CAZ-SC(7) 18,078.88 91.52 157.43 7,316.05 7,263.85 -14,468.18 5,824.93 5,959,581.98 376,725.54 0.26 15,587.88 MWD+1FR-AK-CAZ-SC(7) 18,174.64 89.61 155.10 7,315.11 7,262.91 -14,555.83 5,863.46 5,959,493.69 376,762.56 3.15 15,683.42 MWD+IFR-AK-CAZ-SC(7) 18,270.44 88.80 154.62 7,316.44 7,264.24 -14,642.54 5,904.16 5,959,406.30 376,801.76 0.98 15,778.83 MWD+IFR-AK-CAZ-SC(7) 18,365.36 89.61 152.13 7,317.75 7,265.55 -14,727.38 5,946.69 5,959,320.75 376,842.82 2.76 15,873.10 MWD+IFR-AK-CAZ-SC(7) 18,461.09 88.93 154.03 7,318.97 7,266.77 -14,812.73 5,990.03 5,959,234.68 376,884.68 2.11 15,968.12 MWD+IFR-AK-CAZ-SC(7) 18,556.48 88.56 156.33 7,321.06 7,268.86 -14,899.28 6,030.05 5,959,147.46 376,923.21 2.44 16,063.14 MWD+IFR-AK-CAZ-SC(7) 18,652.11 88.68 156.84 7,323.37 7,271.17 -14,987.01 6,068.05 5,959,059.09 376,959.69 0.55 16,158.57 MWD+IFR-AK-CAZ-SC(7) 18,747.53 89.17 156.56 7,325.16 7,272.96 -15,074.63 6,105.78 5,958,970.84 376,995.91 0.59 16,253.82 MWD+IFR-AK-CAZ-SC(7) 18,842.11 87.88 156.98 7,327.59 7,275.39 -15,161.51 6,143.07 5,958,883.34 377,031.70 1.43 16,348.21 MWD+IFR-AK-CAZ-SC(7) 18,936.58 87.81 157.95 7,331.14 7,278.94 -15,248.70 6,179.25 5,958,795.55 377,066.37 1.03 16,442.52 MWD+I FR-AK-CAZ-SC(7) 19,033.18 90.28 163.76 7,332.75 7,280.55 -15,339.90 6,210.91 5,958,703.82 377,096.46 6.53 16,539.05 MWD+IFR-AK-CAZ-SC(7) 19,080.84 88.93 164.61 7,333.08 7,280.88 -15,385.76 6,223.90 5,958,657.76 377,108.65 3.35 16,586.58 MWD+IFR-AK-CAZ-SC(7) 19,128.22 89.11 165.20 7,333.89 7,281.69 -15,431.50 6,236.24 5,958,611.82 377,120.20 1.30 16,633.78 MWD+IFR-AK-CAZ-SC(7) 2/11/2011 2:38:14PM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD2-77 Project: Western North Slope TVD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Site: CD2 Alpine Pad MD Reference: Rig:CD2-77 @ 52.20ft(D19(36.60+15.60)) Well: CD2-77 North Reference: True Wellbore: CD2-77 Survey Calculation Method: Minimum Curvature Design: CD2-77 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) (°1100') (ft) Survey Tool Name 19,223.62 88.50 163.95 7,335.88 7,283.68 -15,523.44 6,261.60 5,958,519.46 377,143.99 1.46 16,728.85 MWD+IFR-AK-CAZ-SC(7) 19,319.68 88.06 162.97 7,338.77 7,286.57 -15,615.48 6,288.94 5,958,426.97 377,169.73 1.12 16,824.69 MWD+IFR-AK-CAZ-SC(7) 19,414.90 87.94 159.32 7,342.09 7,289.89 -15,705.52 6,319.69 5,958,336.42 377,198.93 3.83 16,919.82 MWD+IFR-AK-CAZ-SC(7) 19,511.24 87.63 157.00 7,345.81 7,293.61 -15,794.87 6,355.50 5,958,246.48 377,233.19 2.43 17,016.03 MWD+IFR-AK-CAZ-SC(7) 19,605.70 89.85 156.50 7,347.89 7,295.69 -15,881.63 6,392.77 5,958,159.09 377,268.97 2.41 17,110.31 MWD+IFR-AK-CAZ-SC(7) 19,702.09 91.09 156.83 7,347.10 7,294.90 -15,970.13 6,430.95 5,958,069.96 377,305.62 1.33 17,206.53 MWD+IFR-AK-CAZ-SC(7) 19,796.02 91.40 156.37 7,345.06 7,292.86 -16,056.32 6,468.25 5,957,983.15 377,341.43 0.59 17,300.28 MWD+IFR-AK-CAZ-SC(7) 19,891.54 90.90 154.30 7,343.14 7,290.94 -16,143.10 6,508.10 5,957,895.70 377,379.78 2.23 17,395.45 MWD+IFR-AK-CAZ-SC(7) 19,986.91 89.79 154.08 7,342.57 7,290.37 -16,228.95 6,549.62 5,957,809.16 377,419.81 1.19 17,490.33 MWD+IFR-AK-CAZ-SC(7) 20,083.01 89.98 153.95 7,342.76 7,290.56 -16,315.34 6,591.73 5,957,722.07 377,460.42 0.24 17,585.91 MWD+IFR-AK-CAZ-SC(7) 20,175.82 89.30 153.57 7,343.34 7,291.14 -16,398.58 6,632.76 5,957,638.14 377,500.02 0.84 17,678.16 MWD+IFR-AK-CAZ-SC(7) 20,272.41 88.99 152.13 7,344.79 7,292.59 -16,484.52 6,676.83 5,957,551.47 377,542.60 1.52 17,773.99 MWD+IFR-AK-CAZ-SC(7) 20,367.29 89.67 154.68 7,345.90 7,293.70 -16,569.35 6,719.30 5,957,465.93 377,583.60 2.78 17,868.23 MWD+IFR-AK-CAZ-SC(7) 20,463.72 89.05 156.07 7,346.97 7,294.77 -16,657.00 6,759.47 5,957,377.60 377,622.26 1.58 17,964.33 MWD+IFR-AK-CAZ-SC(7) 20,559.34 90.10 154.63 7,347.68 7,295.48 -16,743.90 6,799.35 5,957,290.04 377,660.64 1.86 18,059.63 MWD+IFR-AK-CAZ-SC(7) 20,655.60 89.73 155.72 7,347.82 7,295.62 -16,831.26 6,839.77 5,957,202.00 377,699.54 1.20 18,155.55 MWD+IFR-AK-CAZ-SC(7) 20,750.65 89.42 157.54 7,348.53 7,296.33 -16,918.51 6,877.47 5,957,114.13 377,735.74 1.94 18,250.43 MWD+IFR-AK-CAZ-SC(7) 20,846.69 89.73 160.06 7,349.24 7,297.04 -17,008.04 6,912.19 5,957,024.02 377,768.92 2.64 18,346.44 MWD+IFR-AK-CAZ-SC(7) 20,942.24 90.04 160.63 7,349.43 7,297.23 -17,098.02 6,944.33 5,956,933.51 377,799.50 0.68 18,441.99 MWD+IFR-AK-CAZ-SC(7) 21,036.46 90.41 161.82 7,349.06 7,296.86 -17,187.23 6,974.66 5,956,843.80 377,828.29 1.32 18,536.18 MWD+IFR-AK-CAZ-SC(7) 21,131.90 89.73 161.94 7,348.95 7,296.75 -17,277.93 7,004.34 5,956,752.61 377,856.40 0.72 18,631.57 MWD+IFR-AK-CAZ-SC(7) 21,227.22 90.04 161.46 7,349.14 7,296.94 -17,368.43 7,034.27 5,956,661.61 377,884.77 0.60 18,726.85 MWD+IFR-AK-CAZ-SC(7) 21,322.76 90.16 160.12 7,348.97 7,296.77 -17,458.65 7,065.70 5,956,570.88 377,914.65 1.41 18,822.38 MWD+IFR-AK-CAZ-SC(7) 21,416.97 90.78 159.23 7,348.20 7,296.00 -17,546.99 7,098.42 5,956,482.00 377,945.85 1.15 18,916.58 MWD+IFR-AK-CAZ-SC(7) 21,513.15 87.57 162.42 7,349.58 7,297.38 -17,637.80 7,130.00 5,956,390.66 377,975.86 4.70 19,012.71 MWD+IFR-AK-CAZ-SC(7) 21,609.30 89.23 165.48 7,352.27 7,300.07 -17,730.15 7,156.57 5,956,297.88 378,000.83 3.62 19,108.58 MWD+IFR-AK-CAZ-SC(7) 21,702.95 89.48 166.57 7,353.32 7,301.12 -17,821.02 7,179.19 5,956,206.64 378,021.88 1.19 19,201.71 MWD+IFR-AK-CAZ-SC(7) 21,800.50 89.30 167.99 7,354.36 7,302.16 -17,916.17 7,200.66 5,956,111.14 378,041.72 1.47 19,298.46 MWD+IFR-AK-CAZ-SC(7) 21,896.10 88.87 171.25 7,355.89 7,303.69 -18,010.18 7,217.88 5,956,016.86 378,057.32 3.44 19,392.70 MWD+IFR-AK-CAZ-SC(7) 21,991.36 88.62 174.70 7,357.98 7,305.78 -18,104.69 7,229.53 5,955,922.17 378,067.34 3.63 19,485.49 MWD+IFR-AK-CAZ-SC(7) 22,086.61 88.93 176.43 7,360.01 7,307.81 -18,199.63 7,236.89 5,955,827.13 378,073.07 1.84 19,577.22 MWD+IFR-AK-CAZ-SC(7) 22,179.81 88.80 175.57 7,361.86 7,309.66 -18,292.58 7,243.39 5,955,734.08 378,077.97 0.93 19,666.79 MWD+IFR-AK-CAZ-SC(7) 22,274.96 89.36 175.32 7,363.39 7,311.19 -18,387.42 7,250.95 5,955,639.14 378,083.90 0.64 19,758.49 MWD+IFR-AK-CAZ-SC(7) 22,372.18 89.54 175.78 7,364.32 7,312.12 -18,484.34 7,258.49 5,955,542.11 378,089.77 0.51 19,852.15 MWD+IFR-AK-CAZ-SC(7) 22,427.06 89.67 175.61 7,364.70 7,312.50 -18,539.06 7,262.61 5,955,487.33 378,092.95 0.39 19,904.98 MWD+IFR-AK-CAZ-SC(7) 22,467.65 89.91 174.97 7,364.85 7,312.65 -18,579.52 7,265.95 5,955,446.82 378,095.59 1.68 19,944.13 MWD+IFR-AK-CAZ-SC(7) II, 22,562.92 91.15 173.56 7,363.97 7,311.77 -18,674.30 7,275.46 5,955,351.90 378,103.48 1.97 20,036.46 MWD+IFR-AK-CAZ-SC(7) 22,589.98 91.21 174.15 7,363.41 7,311.21 -18,701.20 7,278.36 5,955,324.96 378,105.91 2.19 20,062.73 MWD+IFR-AK-CAZ-SC(7) 22,658.00 91.21 174.15 7,361.97 7,309.77 -18,768.85 7,285.29 5,955,257.20 378,111.68 0.00 20,128.67 PROJECTED to TD 2111/2011 2:38:14PM Page 8 COMPASS 2003.16 Build 69 ConocoPhillips Time Log & Summary Wel!view Web Reporting Report Well Name: CD2-77 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 1/2/2011 12:00:00 AM Rig Release: 2/9/2011 10:00:00 AM j Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 12/27/2010 24 hr Summary Prepare to move rig f/CD4-298 to CD2-77.Waiting on ambient temperatures to warm up(-42 to-44 deg now, WC to-70),Working on work orders and action items list. Repair service loop wire line cable. 12:00 00:00 12.00 MIRU MOVE DMOB T Prepare to move rig f/CD4-298 to CD2-77.Waiting on ambient temperatures to warm up(-42 to-44 deg now,WC to-70),Working on work orders and action items list. Repair service loop wire line cable. 12/28/2010 Prepare to move rig f/CD4-298 to CD2-77.Waiting on ambient temperatures to warm up(-44 deg to-49,WC to-99),Working on work orders and action items list. Repair service loop wire line cable,inspect slings. 00:00 00:00 24.00 MIRU MOVE DMOB T Prepare to move rig f/CD4-298 to CD2-77.Waiting on ambient temperatures to warm up(-42 to-49 deg now,WC to-99),Working on work orders and action items list. 12/29/2010 Continue to Wait on Weather;Ambient Temperatures Too Low(Previous 24 hr Range,-38°to-48°F)- Continue to Work on Work Orders and Miscellaneous Maintenance Items 00:00 00:00 24.00 MIRU MOVE DMOB T Continue to Wait on Weather; Ambient Temperatures Too Low (Previous 24 hr Range,-38°to-48° F)-Continue to Work on Work Orders and Miscellaneous Maintenance Items 12/30/2010 Continue to Wait on Weather-Position Rig Mats at CD2-Hang Tarps on Pipe Shed and Pull Support Equipment Away from the Rig 00:00 16:45 16.75 MIRU MOVE DMOB T Continue to Wait on Weather 16:45 00:00 7.25 MIRU MOVE MOB P Transport and Position Rig Mats on CD2-Move Miscellaneous Support Equipment Away f/the Rig-Prep the Shop,STP and Camp to Move to CD2-Prep Rig Modules for Separation and Transport to CD2 12/31/2010 Blow Down Steam and Water Lines-Disconnect High Line Power-Disconnect Electrical Cables/Service Lines-Hold PJSM and Move Ball Mill f/Drilling Position-Separate Motor Module f/the Pit Module and the Pit Module f/the Sub-Jack Rig Floor Into Transport Position-Move Camp,Shop, STP,Casing Shed, Pipe Shed and Sub to CD2 Page 1 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 MIRU MOVE MOB P Blow Down Steam and Water Lines- Disconnect High Line Power- Disconnect Electrical Cables/Service Lines-Hold PJSM and Move Ball Mill f/Drilling Position-Separate Motor Module f/the Pit Module and the Pit Module f/the Sub-Jack Rig Floor Into Transport Position-Move Camp,Shop,STP,Casing Shed, Pipe Shed and Sub to CD2 01/01/2011 Continue to Move Rig U CD2-Spot, Level and Connect Modules-Connect All Service Lines-Connect Hi-Line Power @ 2010 hrs-N/U Riser-R/U to P/U 5"DP via the Mouse Hole 00:00 12:00 12.00 MIRU MOVE MOB P Continue to Move f/CD4 to CD2 12:00 20:45 8.75 MIRU MOVE RURD P Spot&Level Sub-Move Floor Into Drilling Position-Connect Pit and Motor Complexes-Move Pit/Motor Module Into Position-Connect Steam/Water/Air and Mud Lines- Connect Hi-Line Power @ 2010 20:45 23:15 2.50 MIRU WHDBO NUND P N/U Surface Riser&Connect All Associated Lines/Hardware 23:15 00:00 0.75 MIRU DRILL RURD P R/U to P/U 5"DP via Mouse Hole 01/02/2011 R/U to P/U 5"DP-P/U 15 Stands of 5"DP-Hold for Phase 3 Weather-Continue to P/U Remaining 16 Stands of 5"DP,8 Stands 5"HWDP,2 8"NMFDC's and Jars;Stand Back in the Derrick-P/U BHA#1 U 35' MD 00:00 02:30 2.50 0 0 MIRU DRILL RURD P Continue to R/U to P/U 5"DP f/the Pipe Shed-Remove Thread Protectors&Thaw Brake Coolant Lines 02:30 05:00 2.50 0 0 MIRU DRILL PULD P P/U and Stand Back 8 Stds of 5" HWDP,and 31 Stands of 5"DP- Had to Steam Pipe to Get Rabbit Through 05:00 05:30 0.50 0 0 MIRU RIGMNTSVRG P Service Rig 05:30 07:00 1.50 0 0 MIRU DRILL PULD P Continue to P/U 5"DP f/the Shed (15 Stands Total) 07:00 19:15 12.25 0 0 MIRU DRILL OTHR T Suspend Operations-Phase III Conditions 19:15 19:30 0.25 0 0 MIRU DRILL SFTY P PJSM on P/U 5"HWDP&DP 19:30 23:00 3.50 0 0 MIRU DRILL PULD P Continue to P/U 16 Stds of 5"DP, 8 Stds of 5"HWDP,2-8"NMFDC's and Jars via the Mouse Hole 23:00 23:15 0.25 0 0 SURFA( DRILL SFTY P Pre-Spud Safety Meeting w/Crew& Support Personnel 23:15 00:00 0.75 0 0 SURFA( DRILL PULD P P/U 13 1/2'Bit, Motor and Float Sub U35'MD 01/03/2011 P/U BHA#1 -Orient MWD, Motor and UBHO-R/U E-Line-Fill Riser and Pressure Test Surface Lines U 3500 Psi-Drill 13'/2'Hole U 550'MD-POOH to Increase Motor Deflection f/1.5°to 2.12°to Comply w/Anti Collision Policy-RIH U 550'MD-Drill U 920'MD 00:00 01:30 1.50 0 0 SURFA( DRILL PULD P Continue to P/U BHA#1 U 90'MD as Follows: DM, EWR,TM and UBHO 01:30 02:00 0.50 0 0 SURFA( DRILL OTHR P Orient MWD to the Motor and Motor to DM Page 2 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:00 02:15 0.25 0 0 SURFA( DRILL SFTY P PJSM on Hanging E-Line Sheave 02:15 03:00 0.75 0 0 SURFA( DRILL RURD P Hang E-Line Sheave in Derrick and R/U E-Line 03:00 04:30 1.50 0 0 SURFA( DRILL PRTS P Fill Riser and Check for and Repair Leaks-Pressure Test Mud Lines t/ 3500 Psi 04:30 06:00 1.50 0 259 SURFA( DRILL DDRL P Spud 13'/"surface interval and drill U 259'MD,Taking Gyro's Every Stand. ART-.97 hrs.AST-0.0 hrs.ADT .97 hrs. rotate @ 40 rpm,flow rate- 450 gpm,pressure off-570 psi. Pressure on 720 psi.Torque off 3500 ft/lbs.torque on 4,500 ft/lbs. Up weight 95k Down weight 95K Rotating weight 95K 06:00 11:30 5.50 259 550 SURFA( DRILL DDRL P Drill 13%2'Hole U 550'MD Taking Gyros Every Stand ADT 2.34,ART.47,AST 1.87 P/U 107,S/O 107,Rot 107 Torque On/Off 4/3.5 RPM 40,WOB 10-15 485 GPM @ 1010 Psi 11:30 15:45 4.25 550 550 SURFA( DRILL TRIP T Surveys Showed that the Anti-Collision Policy Would be Violated if Drilling Continued w/ Current Motor Bent Housing Set to 1.5°-POOH- Increase Motor Deflection to 2.12°-Reorient UBHO/MWD/Motor-RIH U 550'MD 15:45 18:00 2.25 550 642 SURFA( DRILL DDRL P Drill 13'/2'Hole t/642'MD w/2.12° Motor Bend Taking Gyros Every Stand ADT.86,ART 0.0,AST.86 P/U 107,S/O 107, Rot 107 WOB 10-15, RPM 0 Torque On/Off-(Sliding) 485 GPM @ 1020 Psi 18:00 00:00 6.00 642 920 SURFA( DRILL DDRL P Drill 13 1/2'Hole U 920'MD w/2.12° Motor and Taking Gyros Every Stand ADT 2.46,ART.85,AST 1.61 P/U 125,S/O 117, Rot 120 Torque On/Off 5.5/4 RPM 15,WOB 15-20 480 GPM @ 1100 Psi 01/04/2011 POOH and Motor Bent Housing U 1.83°-RIH-Drill 13'/2'Hole U 2,622'MD 00:00 00:30 0.50 920 828 SURFA( DRILL CIRC T CBU While Standing 1 Stand Back U 828'MD @ 480 GPM w/1020 Psi 00:30 01:45 1.25 828 0 SURFA( DRILL TRIP T POOH on Elevators U Surface 01:45 03:00 1.25 0 0 SURFA( DRILL OTHR T Change Bend on Motor f/2.12°to 1.83°-Inspect Bit&Float-Reorient Motor to MWD&UBHO Page 3 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03:00 04:00 1.00 0 920 SURFA( DRILL TRIP T RIH t/920'MD 04:00 06:00 2.00 920 1,014 SURFA( DRILL DDRL P Drill 13%"surface interval F/920- T/1014 MD TVD=1,004' ART-.35 hrs.AST-.41 hrs.ADT .76 hrs.Total Bit&Jar hrs=7.39/ Rotate @ 60 rpm,flow rate-480 gpm, pressure off-1,010 psi. Pressure on 1,220 psi.Torque off 4,000 ft/lbs.torque on 7,000 ft/lbs. Up weight 125k Down weight 125K Rotating weight 125K 06:00 12:00 6.00 1,014 1,581 SURFA( DRILL DDRL P Drill 13'/i"Hole U 1,581'MD ADT 3.35,AST 1.41,ART 1.94 P/U 132,S/O 127, Rot 128 Torque On/Off 7/4.5 WOB 15-25, RPM 60 500 GPM @ 1300 Psi 12:00 18:00 6.00 1,581 2,193 SURFA( DRILL DDRL P Drill 13%"Hole t/2193'MD ADT 4.47,AST 1.81,ART 2.66 P/U 144,S/O 125, Rot 133 Torque On/Off 8.5/6 WOB 20-30, RPM 60 600 GPM @ 1730 Psi 18:00 00:00 6.00 2,193 2,622 SURFA( DRILL DDRL P Drill 13%"Hole t/2,622'MD ADT 4.14,AST.75,ART 3.39 P/U 141,S/O 125, Rot 132 Torque On/Off 8.5/6.5 RPM 60,WOB 15-30 600 GPM @ 1900 Psi 01/05/2011 Drilled 13%"Hole t/3,400'MD,2,397'TVD(TD)-CBU X2-BROOH U 924'MD-OWFF-RIH t/3,400'MD on Elevators-Circ&Condition Mud While Weichting Up t/9.8+PPG-OWFF-POOH on TT t/185'MD 00:00 06:00 6.00 2,622 2,918 SURFA( DRILL DDRL P Drill 13%"Hole t/2,918'MD ADT 5.14,AST 1.2,ART 3.94 P/U 141,S/O 124, Rot 131 700 GPM @ 2650 Psi Torque On/Off 9/6.5 RPM 65/WOB 15-30 06:00 12:45 6.75 2,918 3,400 SURFA( DRILL DDRL P Drill 13%"Hole U 3.400'MD(TD)- nn 2,397'TVD V ADT 4.79,AST 0.00,ART 4.79 P/U 141,S/O 124, Rot 131 700 GPM @ 2800 Psi Torque On/Off 9/6 RPM 60/WOB 10-25 12:45 13:45 1.00 3,400 3,400 SURFA( DRILL CIRC P CBU X2 @ 700 GPM w/2600 Psi& 60 RPM 13:45 18:15 4.50 3,400 924 SURFA( DRILL REAM P OWFF(Static)-BROOH U 924'MD, 700 GPM @ 2500 Psi(Below Permafrost)&500 GPM @ 1300 Psi (In Permafrost) 18:15 19:15 1.00 924 3,400 SURFA( DRILL TRIP P OWFF(Static)-RIH t/3,400'MD Page 4 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 19:15 20:45 1.50 3,400 3,400 SURFA( DRILL CIRC P Circ&Condition Mud While Increasing MW t/9.8 PPG 695 GPM @ 2700 Psi RPM 60 20:45 21:00 0.25 3,400 3,400 SURFA( DRILL OWFF P Blow Down Top Drive-OWFF (Static) 21:00 00:00 3.00 3,400 185 SURFA( DRILL TRIP P POOH on TT t/186'MD(26 Stds 5" DP and 8 Stds 5"HWDP) 01/06/2011 Continue to UD BHA#3-R/U, Run&Cement 10'/;'Casing t/3,990'MD-R/D Casing Running/Cement Tools-Flush&N/D Riser 00:00 03:15 3.25 185 0 SURFA( DRILL PULD P Download MWD and UD BHA#3 03:15 06:15 3.00 0 0 SURFA( CASING RURD P Clean&Clear the Rig Floor-R/U to Run 10%"Casing 06:15 06:30 0.25 0 0 SURFA(CASING SFTY P PJSM on Running 10%"Casing 06:30 09:45 3.25 0 820 SURFA( CASING RNCS P Run 10 3/4",45.5", L-80 BTC-M casing-Silver bullet FS,2 joints, Halliburton FC,2 jts of casing-(all connections w/Bakerloc)Fill pipe- check floats, ok.-Ran 16 jts. of casing, hit tight spot @ 820' 09:45 11:15 1.50 820 1,227 SURFA(CASING RNCS P Wash down 10 joints of casing from 816'to 1227'-4 bpm/240 psi- Observed several tight spots with pressure increase to 300 psi and up to 10K reduction in SOW-last 4 joints-no problems 11:15 12:15 1.00 1,227 2,051 SURFA(CASING RNCS P Run 10 3/4",45.5", L-80 BTC-M casing from 1227'to 2051'(50 jts total) 12:15 12:45 0.50 2,051 2,051 SURFA(CASING CIRC P Establish circulation-staged pumps up to 6.2 bpm-CBU-FCP=440 psi -PUW 150K SOW 127K 12:45 15:00 2.25 2,051 3,390 SURFA( CASING RNCS P Run 10 3/4",45.5", L-80 BTC-M casing from 2051'to 3351'(82 jts. total)-MU FMC fluted hanger&LJ- land casing with FS @ 3390', FC @ 3304' 15:00 15:30 0.50 3,390 3,390 SURFA( CEMEN-RURD P Rig down fill up tool-blow down top drive-MU 10 3/4"Cement head 15:30 17:30 2.00 3,390 3,390 SURFA( CEMEN"CIRC P Circ and Condition Mud to Lower YP Prior to Cementing-7 BPM @ 300 Psi 17:30 18:00 0.50 3,390 3,390 SURFA( CEMEN'SFTY P PJSM on Surface Cement Operations Page 5 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:15 3.25 3,390 3,390 SURFA(CEMEN"CMNT P Cement 10'/4'Casing as Follows: Pumped 120 Bbls of 9.8 PPG Mud Spacer w/Nut Plug&35 Bbls 9.8 PPG Biozan Spacer w/Nut Plug- Pressure Test Cement Lines U 2500 S� Psi-Pump 53 Bbls 10.5 PPG Mud Push II, Dropped the Lower Plug, Pumped 426.7 Bbls 10.7 ASL Lead and 58.4 Bbls Alpine Surface Tail Cement-Dropped Upper Plug- Pumped 20 Bbls Water then Displaced w/295 Bbls 9.8 PPG Mud @ 7 BPM w/700 Psi-Held 1200 Psi on Floats-Bled Pressure, Floats Held-CIP 2030 hrs Full Returns Throughout Job-160 Bbls of Cement Returned to Surface -Observed Cement in Casing and Annulus for 45 Minutes(Level Steady) 21:15 21:45 0.50 3,390 3,390 SURFA(CEMEN"RURD P Drain/Flush Riser-R/D Casing Running&Cementing Equipment 21:45 00:00 2.25 3,390 3,390 SURFA(WHDBO NUND P N/D Surface Riser and Adapter Flange 01/07/2011 N/U Well Head and Test U 1000 Psi f/10 Minutes-N/U BOPE Stack and Associated Lines/Hardware-P/U 5"DP,Tested BOPE 00:00 01:15 1.25 0 0 SURFA(WHDBO NUND P N/U Well Head and Test U 1000 Psi f/10 Minutes 01:15 03:15 2.00 0 0 SURFA(WHDBO NUND P N/U BOPE Stack, Bell Nipple and Flow Line 03:15 04:30 1.25 0 0 SURFA( DRILL PULD P PJSM-P/U 5"DP 04:30 05:00 0.50 0 0 SURFA( RIGMNT SVRG P Serviced Rig 05:00 18:45 13.75 0 0 SURFA( DRILL PULD P P/U 5"DP and stood back 18:45 00:00 5.25 0 0 SURFA(WHDBO BOPE P R/U and tested BOPE,choke valves 1-16, HCR&Manifold and choke& kill,4"DEMCO,TIW&Dart,auto and man, IBOP,upper and lower blind rams,tested to 250 psi low and (3° 3500 psi high,Tested annular to 250 psi low and 2500 psi high,ACC tested,function tested remote station, restriction test on super and man.choke, (IBOP failed) 01/08/2011 Completed Remaining BOPE Test Items-Replaced Auto IBOP and Tested U 250/3500 Psi-Installed Bales, Elevators and Clamps-P/U BHA#4-Single In Hole U 3,352'MD-Performed Casing Test U 3500 Psi- Tagged FC at 3,308'MD-Drilled Shoe Track U 3,390'MD AOGCC Inspector Jeff Jones Waived Witnessing the Test 00:00 01:45 1.75 0 0 SURFA(WHDBO BOPE P Continue to Test BOPE-Test Blind Rams U 250/3500 01:45 05:45 4.00 0 0 SURFA(WHDBO RGRP T Replace Auto IBOP for Failed Test 05:45 06:45 1.00 0 0 SURFA(WHDBO BOPE T R/U and Test Auto IBOP U 250/3500 Psi Page 6 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 07:00 0.25 0 0 SURFA(WHDBO BOPE T Installed Bales and Elevators while bringing BHA components to rig floor 07:00 09:30 2.50 0 95 SURFA( DRILL PULD P PU BHA#4 as per the directional driller 09:30 14:30 5.00 95 190 SURFA( DRILL PULD P Continued to PU BHA#4 as per the directional driller,plugged in and up loaded MWD, pulsed tested MWD, .loaded sources 14:30 15:15 0.75 190 2,874 SURFA( DRILL TRIP P RIH picking up singles to 2,874' 15:15 17:00 1.75 2,874 2,874 SURFA( RIGMNT SLPC P Slipped and cut drill line and serviced rig 17:00 19:00 2.00 2,874 3,308 SURFA( DRILL TRIP P RIH with stands to 3,252',then washed and reamed to 3,308' 19:00 19:30 0.50 3,308 3,308 SURFA( DRILL PRTS P Tested surface casing to 3500 psi for 30 minutes 19:30 00:00 4.50 3,308 3,400 SURFA(CEMEN"DRLG P Drilled float collar,shoe track and cement to 3,400'MD(original TD for surface hole),observed some difficulty working through shoe track 01/09/2011 Performed LOT to 16.7 ppg MWE,drilled ahead to 5,741'MD 00:00 00:30 0.50 3,400 3,420 SURFA( DRILL DDRL P Drilled 20 feet of new hole to 3420'MD 00:30 01:30 1.00 3,420 3,420 SURFA( DRILL LOT P Circulated and performed LOT with a L U l final leakoff of 16.7 ppq MWE / 01:30 12:00 10.50 3,420 4,482 INTRM1 DRILL DDRL P Directional drilled form 3420'to 4,482',SPR#1:30 SPM=110 psi,40 SPM=160 psi,SPR#2:30 SPM=110 psi,40 SPM=160 psi, Torque:9K on,7K Off, 150 RPM, 5-10 K on bit,750 GPM @ 2600 psi, ECD: 10.56 ppg, PU: 150K,SO: 128K, Rot: 138K 12:00 00:00 12.00 4,482 5,741 INTRM1 DRILL DDRL P Continued to directional drill from 4,482'to 5741',SPR#1:30 SPM=180 psi,40 SPM=250 psi Torque: 11K on, 10K off, 150 RPM, 5-10K WOB, 750 gpm @ 2740 psi, ECD: 10.62 ppg, PU:175K,SO: 128K, Rot: 145K • 01/10/2011 Continued directional drilling f/5,741-8,358'MD 00:00 12:00 12.00 5,741 7,121 INTRM1 DRILL DDRL P Drilled from 3,752'to 7,121' SPR#1, 30 SPM=200 psi,40 SPM=280 psi, SPR#2,30 SPM=200 psi,40 SPM=270 psi @ 6562'MD PU Wt:168K,SOW: 145K, RTW: 155K, TQ on 10K,TQ off:7K @ 7,034'MD, ECD's: 10.65 ppg,backreaming every connection Page 7 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 00:00 12.00 7,121 8,358 INTRM1 DRILL DDRL P Drilled from 7,121'to 8,358' SPR#1, 30 SPM=190 psi,40 SPM=270 psi, SPR#2,30 SPM=190 psi,40 SPM=280 psi @ 8,358'MD PU Wt:180K,SOW: 150K, RTW: 165K, TQ on 11.5K,TQ off:9K @ 8,359' MD, ECD's: 10.61 ppg,backreaming every connection 01/11/2011 Continued directional drilling f/8,358'to 11,684', mud pump#2 had washout, repairing same at report time 00:00 12:00 12.00 8,358 9,907 INTRM1 DRILL DDRL P Continued directional drilling from 8,359'to 9,907', PUW=200K, SOW=158K, RTW=175K,TQ on=14, TQ off=10 @ 9,871'MD,SPR#1:30 SPM=190 psi,40 SPM=230 psi, SPR#2:30 SPM=180 psi,40 SPM= 240 psi @ 9,682'MD,Continued to backream each stand on connections 12:00 23:30 11.50 9,907 11,684 INTRM1 DRILL DDRL P Continued directional drilling from 9,907'MD to 11,684'MD, PUW=208K,SOW=165K, RTW=180K,TQ on=16,TQ off=11.5 @ 10,439', SPR#1:30 SPM=150psi,40 SPM=210 psi,SPR #2:30 SPM=150 psi,40 SPM=220 psi @ 10,900' 23:30 00:00 0.50 11,684 11,684 INTRM1 RIGMNT RGRP T Lost pump pressure and discovered washout on mud pump#2 manifold, started backreaming out at 1 stand every thirty minutes with pump#1 while repairs are being made. 01/12/2011 Continued to repair mud pump,pressure tested same and drilled ahead to 14,033'MD/6236'TVD 00:00 08:00 8.00 11,684 11,684 INTRM1 RIGMNT RGRP T Continued repairs on mud pump while circulating at 8 bbls/min @ 800 psi and 120 RPM, backreamed out at 1 stand/30 minutes from 11684'to 10,533' 08:00 08:15 0.25 11,684 11,684 INTRM1 RIGMNT RGRP T Pressure tested pump#2 to 4500 psi,test was good 08:15 09:15 1.00 11,684 11,684 INTRM1 DRILL TRIP T RIH from 10,533'MD to 11,573'MD, precautionary reamed from 11,573'to 11,684'@ 780 gpm and 2680 psi and 150 RPM @ 13.5 ft-#'s torque 09:15 12:00 2.75 11,684 12,046 INTRM1 DRILL DDRL P Continued to directionally drill with geo-pilot from 11,684'MD to 12,046' MD/5,521'TVD ADT:1.26 ECD:10.6 ppg with 9.6 ppg mud RPM:150, WOB:25K GPM: 800 @ 3000 psi String Wts: PUW:233K, SOW:165K, Rot: 193K Torque on/off bottom: 17,500 ft-#'s/15,000 ft-#'s Page 8 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 12,046 14,033 INTRM1 DRILL DDRL P Continued to directionally drill with Geo-pilot f/12046'MD to 14,033' MD/6,236'TVD ADT:8.15 ECD: 10.8 ppg w/9.6 ppg mud RPM: 120 WOB 15K GPM:800 @ 3450 psi, PUW:250K, SOW: 170K, Rot: 200K, Torque on/off bottom:20K/16K 01/13/2011 Directionally drilled the 9 7/8"intermediate hole to 15,167'MD/6651'ND,wiped hole back to the surface shoe 00:00 08:45 8.75 14,033 15,167 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GeoPilot f/ 14,033'to 15,167'MD 6651'TVD ADT=5.17 hrs. WOB 15/20 K RPM 150 GPM 800 @ 3320 PSI String wt. PU 290 SO 170 Rot 213 Torque on/off btm-23,500/19,500 ft/lbs. ECD=10.62 Mud wt.9.7 ppg SPR#1 30 spm @ 230 psi-40 spm @310 psi 08:45 11:30 2.75 15,167 14,883 INTRM1 DRILL CIRC P Pump HiVis sweep w/nutplug-CBU X2.5-800 gpm/3340 psi/150 RPM @ 20 K torque-Set back 1 std./45 min.to 14,883'-flow check well,static 11:30 16:45 5.25 14,883 9,414 INTRM1 DRILL TRIP P Pulled on elevators 57 stands from 14,883'to 9414',encountered tight spot with 60K over, 16:45 17:45 1.00 9,414 9,214 INTRM1 DRILL REAM P Dropped down and backreamed 3 stands from 9498'to 9214'with 700 gpm and 2300 psi and 100 rpm(Qannik Zone) 17:45 18:15 0.50 9,214 8,458 INTRM1 DRILL TRIP P Pulled 8 stands from 9214'to 8458' and encountered tight spot with 75K over, 18:15 19:45 1.50 8,458 7,797 INTRM1 DRILL REAM P Backreamed 7 stands from 8,458'to 7,797'with 700 gpm at 2300 psi and 100 rpm,observed intermitent tight spots during reaming first four stands 19:45 20:15 0.50 7,797 7,039 INTRM1 DRILL TRIP P Pulled on elevators 8 stands from 7797'to 7039',encountered tight spot with 60K over 20:15 21:15 1.00 7,039 6,755 INTRM1 DRILL REAM P Backreamed 3 stands from 7,039'to 6755'with 700 gpm and 2250 psi and 100 rpm 21:15 21:45 0.50 6,755 6,283 INTRM1 DRILL TRIP P Pulled 5 stands on elevators from 6,755'to 6283',encountered tight spot with 75K over 21:45 23:00 1.25 6,283 5,810 INTRM1 DRILL REAM P Backreamed 5 stands from 6,283'to 5810'with 700 gpm and 2200 psi at 100 rpm 23:00 00:00 1.00 5,810 4,576 INTRM1 DRILL TRIP P Pulled 14 stands from 5,810'to 4,576'at report time Page 9 of 31 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01/14/2011 24 hr Summary Continued to POOH from 4576'to 3914',precautionary backreamed to the surface shoe to 3536',slipped and cut drillng line, RIH washing reaming tight spots,drilled ahead from 15,167'to 15,800'MD/5,890'TVD 00:00 00:30 0.50 4,576 3,914 INTRMI DRILL TRIP P Continued to POOH from 4,576'to 3,914' 00:30 01:45 1.25 3,914 3,502 INTRM1 DRILL TRIP P Precautionary backreamed from 3,914'to 3,502'with 700 gpm @2200 psi,and 90 rpm 01:45 04:00 2.25 3,502 3,502 INTRMI RIGMNT SLPC P Slipped and cut drilling line-Service top Drive and drawworks 04:00 12:00 8.00 3,502 14,205 INTRM1 DRILL TRIP P RIH from 3502'to a tight spot at 14,205'-Filled pipe every 20 stands- obtained PU/SO data every 20 stands **Pressure tested#1 pump to 4000 psi 12:00 13:00 1.00 14,205 14,316 INTRMI DRILL REAM P Wash and ream from 14,205'to 14,316' 640 gpm/2750 psi/120 rpm @ 18 K ft/lbs PUW 275K SOW 158 K Rot wt. 204K 13:00 13:30 0.50 14,316 14,550 INTRM1 DRILL TRIP P RIH from 14,316'to 14,550' lost 15 K SOW 13:30 16:45 3.25 14,505 15,167 INTRMI DRILL REAM P Wash and ream from 14,505'to 15,167'-slight effort to ream hole intermitent 5-10k WOB-very little torque variation no pump pressure increase observed, reamed with 650 gpm @ 2820 psi, 120 RPM and 18K torque 16:45 00:00 7.25 15,167 15,800 INTRM1 DRILL DDRL P Drilled ahead from 15,167'to 15,800'MD/5,890'TVD with PUW: 295K,SOW: 168K, ROT:221K, 150 RPM,740 gpm @ 3950 psi, ECD=11.63 ppg,commenced weighting mud up to 11.0 ppg at 15,750'MD 01/15/2011 Directionally drilled from 15,800'to 16,000'MD while weighting up mud from 10.5 ppg to 11.0 ppg,drilled to 16,136'and started losing returns at 1 bbl/min.,stopped drilling and circulated,treated mud with LCM and reduced pumps to 300 gpm, cut mud weight back to 10.8 ppg, increased pump rate to 600 gpm and continued to drill maintaining losses at 30 bbls/hour eventually going to+/-15 bbls/hr.. Drilled to 16,923'MD/ 7,244'ND. 00:00 03:45 3.75 15,800 16,136 INTRM1 DRILL DDRL P Directional drilling from 15,800'to 16,136',started weighting up mud at 15,750'and 11.0 ppg mud around by 16,000',700 gpm @ 4000 psi, ECD=11.8 ppg,ADT:2.54 hrs, WOB:20K, RPM: 150, PUW:304K, SOW: 165K, Rot:220,torque on/off bottom:22K/17K, Page 10 of 31 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 09:00 5.25 16,136 16,136 INTRM1 DRILL CIRC T Experienced lost returns at 1 bbl/min.,stopped drilling,shut down pumps and observed the hole, losses slowed considerably,started working pipe and pumping at 300 gpm while pumping LCM,called town and consensus was to reduce the mud weight back to 10.8 ppg Circulate and lower mud wt.from 11.0 to 10.8 ppg 300 gpm/1050 psi /100 rpm Staged pumps up to 420 gpm/1810 psi/100 rpm and continued to lower mud wt.-adding—1 ppb of Dyna Red LCM to suction pit 09:00 10:00 1.00 16,136 16,136 INTRM1 DRILL OWFF T With 10.8 ppg mud around-shut down pumps and monitor well- Observed well breathing-Circ @ 3 bpm to move mud in kelly hose(-15 degrees) shut down pumps-taking returns to trip tank-gained 1 bbl in 4.25 minutes-well static in 7.5 minutes-observed fluid level dropping slowly in annulus-total gain to trip tank 1.2 bbls.total mud losses to well 234 bbls. Circulate at 600 gpm/3080 psi/140 rpm @ 22K-ECD=11.49 ppg- Observe loss rate for 15 minutes- appx.25 bph losses 10:00 12:00 2.00 16,136 16,221 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GeoPilot f/ 16,136'to 16,221'MD 7027'TVD ADT=0.89 hrs. WOB 10/12 K RPM 140 GPM 600 @ 2870 PSI String wt. PU 320 SO 155 Rot 220 Torque on/off btm-23,000/21,000 ft/lbs. ECD=11.38 Mud wt. 10.8 ppg SPR#1 30 spm @ 300 psi-40 spm @ 440 psi @ 16,207' 12:00 00:00 12.00 16,221 16,923 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GeoPilot f/ 16,221'to 16,923'MD 7244'ND ADT=7.48 hrs. WOB 10/12 K RPM 140 GPM 600 @ 3130 PSI String wt. PU 320 SO 155 Rot 220 Torque on/off btm-23,000/21,000 ft/lbs. ECD=11.45 Mud wt. 10.8 ppg SPR#1 30 spm @ 320 psi-40 spm @ 430 psi @ 16,774' Mud losses at+/-15 bbls/hr. 01/16/2011 Drilled to 17,359'MDTD/7,299'TVD, BROOH to 16,963',circulated and conditioned mud, POOH with pump to 14,411'at 10 bpm,flow checked well,OK, RIH on elevators to 17,359'(no problems),pumping out while spotting casing pill at report time. Page 11 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 08:00 8.00 16,923 17,359 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GeoPilot f/ 16,923'to 17,359'MD 7299'TVD ADT=5.67 hrs. WOB 10/20 K RPM 140 GPM 600 @ 3100 PSI String wt. PU 335 SO 155 Rot 225 Torque on/off btm-24,500/19,500 ft/lbs. ECD=11.36 Mud wt. 10.8 ppg SPR#1 30 spm @ 320 psi-40 spm @ 430 psi @ 16,901' 08:00 08:30 0.50 17,359 17,359 INTRM1 DRILL CIRC P Circulate and condition mud-600 gpm/3080 psi/140 rpm @ 22K ft/lbs 08:30 09:30 1.00 17,359 16,963 INTRMI DRILL TRIP P Backream from 17,359'to 16,963' 600 gpm/3080 psi/140 rpm @ 22K ft/lbs 09:30 10:45 1.25 16,963 16,869 INTRM1 DRILL CIRC P CBU-600 gpm/3100 psi/140 rpm @ 23K ft/lbs-reciprocated pipe from 16,950'to 16,869' 10:45 12:00 1.25 16,869 16,207 INTRMI DRILL TRIP P POOH w/pump from 16,869'to 16,207'-420 gpm/1740 psi-1000- 1200 fph pulling speed PUW 300-325K Max PUW 340K 12:00 14:45 2.75 16,207 14,789 INTRMI DRILL TRIP P Backream from 16,207'to 14,789'- 600 gpm/2850 psi/130 rpm-no problems 14:45 17:30 2.75 14,789 14,411 INTRMI DRILL CIRC P Circulate 2 x BU-600 gpm/2850 psi/140 rpm @ 19K ft/lbs Set back one std./30 min.to 14,316' Mud wt. 10.8 ppg ECD=11.27 ppg 17:30 22:45 5.25 14,411 17,359 INTRMI DRILL TRIP P Flow checked well,well static with slight losses,trip in hole on elevators from 14,411'to 17,359'(trip went well)SOW averaged 160-165K throughout trip. 22:45 00:00 1.25 17,359 16,302 INTRM1 DRILL TRIP P Pumped out of hole while spotting casing running fluid from 17,359 TD to 16,302,MD,pumped out with 3 bpm while pulling drill string at 1800 ft/hr.A total of 240 bbls of casing fluid was mixed which will place the top of the fluid at+/-14950' 01/17/2011 POOH to run 7 5/8"intermediate casing 00:00 01:30 1.50 16,302 15,356 INTRM1 DRILL TRIP P POOH from 16,302'to 15356' spotting casing running pill into open hole 3bpm/440 psi/1800 fph Flow check well-static 01:30 08:00 6.50 15,356 9,588 INTRM1 DRILL TRIP P POOH on elevators from15,356'to 9588'-wiped several tight spot clean -12,900', 12,621', 12545', 12,446', 10,300', 10,035' 08:00 08:30 0.50 9,588 9,588 INTRM1 RIGMN1 RGRP T Work on Iron roughneck-would not break out pipe Page 12 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 10:00 1.50 9,588 9,588 INTRM1 DRILL CIRC P Circulate and condition mud-520- 600 gpm/2370 psi/120 rpm @ 15K ft/lbs-Diluted mud system with 250 bbls of 10.8 ppg new mud-observed moderate amount of solids back at BU-circulated untill shakers cleaned up 10:00 11:00 1.00 9,588 9,588 INTRM1 RIGMNI RGRP T Attempt to repair Iron roughneck-no good(pipe spinners functional) Reduced pump rate to 4 bpm/250 psi-reciprocated pipe **PJSM-Discussed using manual tongs to break out drill pipe for remainder of trip out. 11:00 11:30 0.50 9,588 9,304 INTRMI DRILL TRIP P Blow down top drive-line up to trip tank POOH from 9588'-attempt to work past tight spot @ 9467'pulling 60K over-unable-back ream from 9493' to 9460'-500 gpm/1740 psi/100 rpm-reduced rate to 4 bpm and pulled with pump from 9460'to 9304' 11:30 12:30 1.00 9,304 8,264 INTRMI DRILL TRIP P POOH on elevators from 9,304'to 8264'-wiped tight spot @ 8622', 8570'8499',8307' 12:30 13:30 1.00 8,264 7,981 INTRM1 DRILL REAM P Precautionary ream from 8264'to 7981'to bring BHA across Qannik sands-500 gpm/1680 psi 100 rpm @ 14K ft/lbs Spotted 35 bbls Lcm pill(20 ppb) across and above Qannik 13:30 15:30 2.00 7,981 7,129 INTRM1 DRILL REAM P Flow checked well and then BROOH r/7,981'to 7,129'with 550 gpm, 120 rpm and 12K torque 15:30 16:15 0.75 7,129 7,034 INTRM1 DRILL TRIP P POOH on elevators f/7,129'to 7,034',experienced tight hole 16:15 00:00 7.75 7,034 3,820 INTRM1 DRILL REAM P BROOH f/7,034'to 3,820'with 550 gpm, @ 1600 psi, 120 RPM and 10K torque 01/18/2011 BROOH from 3820'to 3442',circulated and conditioned mud, POOH on elevators to surface, LD BHA, RU and ran 7 5/8"intermediated casing to 3,647'MD. 00:00 01:30 1.50 3,820 3,441 INTRMI DRILL TRIP P BROOH f/3820'to 3441'@ 550 gpm @ 1300 psi/120 rpm @ 7.5 k torque (observed tight spot @ 3635'-pulled 15-20 k over) 01:30 02:15 0.75 3,441 3,441 INTRMI DRILL CIRC P Circ btms up @ 3441'-pumped bit balling pill @ 500 gpm @ 1330 psi w/ 70 rpm's @ 6.5 k torque 02:15 02:30 0.25 3,441 3,536 INTRM1 DRILL TRIP P -Blow down TD-RIH f/3441'to 3536'-string wt PU 140 k SO 125 k 02:30 04:30 2.00 3,536 786 INTRM1 DRILL TRIP P Flow ck-POOH on TT f/3536'to 786' 04:30 05:30 1.00 786 224 INTRM1 DRILL TRIP P Flow Ck @ BHA-(static)-POOH f/ 786'to 224' 05:30 05:45 0.25 224 133 INTRM1 DRILL SFTY P PJSM-LD NM flex DC's Page 13 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 09:45 4.00 133 0 INTRMI DRILL PULD P PJSM on handling RA sources- Down load RA sources f/MWD tool- LD BHA 09:45 10:00 0.25 0 0 INTRMI DRILL OTHR P Pull wear bushing 10:00 10:30 0.50 0 0 INTRM1 DRILL PULD P Clean up&clear rig floor of excess equipment 10:30 12:30 2.00 0 0 INTRM1 WHDBO NUND P PJSM on changing rams-Changed top pipe rams f/3 1/2"x 6"VBR to 7 5/8"pipe rams 12:30 13:30 1.00 0 0 INTRM1 WHDBO BOPE P RU&test 7 5/8"pipe rams to 250& 3500 psi RD 13:30 14:00 0.50 0 0 INTRM1 WHDBO RURD P Pull test plug-Set thin wall wear bushing 14:00 17:00 3.00 0 0 INTRMI CASING RURD P Held PJSM for running the 7 5/8" intermediate casing,then R/U casing tongs and elevators and preparation for running pipe 17:00 22:15 5.25 0 3,388 INTRM1 CASING RNCS P Ran 7 5/8",29.7#, L-80, BTC-M to 3388'MD.(shoe track consisting of shoe,two joints,float collar,one joint and landing collar)PUW: 140K, SOW: 120K @ 3388' Installed 1 straight blade cent.on jt# 1 &1 Volant Hydroform cent. per jt f/ jt#2to#4 22:15 23:00 0.75 3,388 3,388 INTRMI CASING CIRC P Circulated and conditioned mud starting with 2 BPM @ 170 psi and staging up 7 BPM @3388 psi, maintained good returns throughout circulation, 23:00 00:00 1.00 3,388 3,647 INTRM1 CASING RNCS P Continued RIH with 7 5/8"casing from 3,388'to 3,647' Installing 1 Hydroform cent. perjt. 01/19/2011 Continued running the 7 5/8"intermediate casing,circulated and conditioned hole at 5403',7,401', 9,394', 11,404',experienced some tight hole at 12,872',preparing to circulate and condtion mud at report 00:00 01:45 1.75 3,647 5,403 INTRMI CASING RNCS P Continued running 7 5/8"casing from 3,647'to 5,403'(126 jts total in hole) Installed 1 Hydroform cent perjt. 01:45 02:30 0.75 5,403 5,403 INTRM1 CASING CIRC P Circulated and conditioned mud by staging up from 2 bpm to 7 bpm for one bottoms up(215 bbls)no losses observed-PU wt. 165 SO wt 135 02:30 05:30 3.00 5,403 7,401 INTRM1 CASING RNCS P Continued running 7 5/8"casing from 5,403 to 7401'(173 jts total in hole) Installed 1 Hydroform cent perjt. 05:30 06:45 1.25 7,401 7,401 INTRM1 CASING RURD T Flow ck(static)blow down TD- PJSM on changing fill up tool- Changed out fill up tool(bad packer cup) 06:45 08:15 1.50 7,401 7,401 INTRM1 CASING CIRC P Circ&condition mud(made 250 bbl whole mud dilution)staged pump up to 7 bbls/min @ 480 psi-PU wt 205 SO wt 145-No losses observed Page 14 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 11:30 3.25 7,401 9,394 INTRM1 CASING RNCS P Continued RIH w/7 5/8'29.7#L-80 BTCM csg f/7401'to 9394'(219 jts total in hole)Installed 1 Hydroform cent per jt, (installed Halliburton stage collar on top of joint#204) 11:30 14:30 3.00 9,394 9,394 INTRM1 CASING CIRC P Circ&condition mud-attempt to stage pump up to 6 bbls/min-@ 3.4 bbls/min hole began to take fluid- flow out&pump pressure dropped off -Slowed pump back to 2.3 bbl/min& circ btms up-PU wt.230 SO wt 135 14:30 18:00 3.50 9,394 11,404 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"csg f/9394'to 11,404'(266 jts total in hole) Installed 1 Hydroform cent/jt f/#220 to#230(230 total Hydroform cent.used) Began installing 1 EZ gluider cent per/jt f/#231 to#266 18:00 21:00 3.00 11,404 11,404 INTRM1 CASING CIRC P Circ&condition mud-attempt to stage pump up to 6 bbls/min-@ 3.0 bbls/min hole began to take fluid- flow out&pump pressure dropped off -Slowed pump back to 2.5 bbl/min& circ btms up-PU wt.265 SO wt 155 12 bbls lost during circulation 21:00 00:00 3.00 11,404 12,872 INTRM1 CASING CIRC P Cont. RIH w/7 5/8"csg f/11404'to 12,872'(300 jts total in hole) observed tight hole and prepared to circulate and condtion mud early to the program PUW:300k, SOW: 155K Installed 1 EZ glider cent per/jt f/# 266 to#300 01/20/2011 With casing a 12,872'circulation could not be established,pulled 14 joints of casing in an effort to regain circulation,decision made to run to bottom, ran 7 5/8"casing to 17,344',attempted to circulate bottoms up with partial success, RU to cement at report time. 00:00 00:15 0.25 12,872 12,872 INTRM1 CASING CIRC P Commenced circulating and conditioning mud sooner then programmed,circulated 15 minutes at 2 bpm and lost circulation 00:15 01:30 1.25 12,872 12,785 INTRM1 CASING CIRC T Worked pipe and couldn't get returns, pumped out one joint, attempted to pull second joint and pulled to 380K maximum,was force to pick up joint laid down and run back in hole, pipe was free going down,worked pipe and pulled first joint again,attempted to pull second joint and was successful with over pull of 310K,with SO at 155K,could not regain circulation,pumped out two more joints of 7 5/8"casing to 12,785 at 2 bpm in an effort to clean up hole to regain returns,worked pipe the length of one joint, no good Page 15 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 04:30 3.00 12,785 12,614 INTRM1 CASING CIRC T Pumped out an additional four joints of casing joints to 12,614',pumping at 2 bpm, pulling as high as 310K up, attempted to work pipe while establishing circulation at 2 bpm and 350 psi,observed slight returns with 275K up weight 04:30 07:15 2.75 12,614 12,528 INTRM1 CASING CIRC T Pumped out and additional two casing joints to 12528'while pumping 2 bpm @ 350 psi,working pipe to try and regain circulation, no good, PUW:275K,SOW: 150K 07:15 08:30 1.25 12,528 12,310 INTRM1 CASING CIRC T Pumped out six more joints of casing to 12,310', 08:30 09:30 1.00 12,310 12,310 INTRM1 CASING CIRC T Flow checked well,attempted to circulate at 12,310'with 1.5 bpm 330 psi,observed slight returns 09:30 18:45 9.25 12,310 17,310 INTRM1 CASING RNCS P Decision made to run casing to bottom, RIH with 7 5/8"casing from 12.310'to 17,310'without returns 18:45 19:00 0.25 17,344 17,344 INTRM1 CASING RNCS P MU fluted casing hanger and landed 7 5/8"casing with shoe at 17,344' 19:00 19:30 0.50 17,344 17,344 INTRM1 CEMEN"CMNT P Installed cementing head on 7 5/8" casing 19:30 22:00 2.50 17,344 17,344 INTRM1 CEMEN'CMNT P Attempted to circulate bottoms up prior to cementing, pumped at 1/2 bpm and staged up to 2 1/2 bpm, j,oSY able to get returns with+/-20% cIr losses,circulated 250 bbls 22:00 23:00 1.00 17,344 17,344 INTRM1 CEMEN'CMNT P Lost returns and made attempt to reestablish circulation by staging back up again on pump rate, regained circulation with 2 bpm,able to get returns with 60%losses, mud engineer calculated mud losses to great to continue circulating due to volume needed for cement displacement 23:00 23:30 0.50 17,344 17,344 INTRM1 CEMEN"CMNT P Performed PJSM with rig crew concerning cement operation for the 7 5/8"casing string 23:30 00:00 0.50 17,344 17,344 INTRM1 CEMEN'CMNT P RU Schlumberger Cementers and prepared to.pump the 7 5/8" intermediate cement job. 01/21/2011 Performed primary cement operation on the 7 5/8"casing,did not bump the plug and waited on cement until the casing could be pressured up to shear out the stage collar,sheared out same and performed the secondary cement operation across the Qannik bumping the plug,performed LOT on the 10 3/4"X 7 5/8" annulus,and started freeze protecting down the annulus Page 16 of 31 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 17,344 17,344 INTRM1 CEMEN"CMNT P Continued to RU Schlumberger Dowell for 7 5/8"casing cement operation, Pumped 5 bbls ofCW100 ahead,tested lines to 3700 psi, C pumped 35 bbls of CW100,followed by 35 bbls of 12.5 ppg mud push, dropped bottom plug,pumped 5 bbls of 12.5 ppg mud push, loaded top plug,mixed and pumped 92 bbls of 15.8 ppg Class"G"with .2%D46, .3%D65, .11%8155, .4%D167, dropped top wiper plug,pumped 20 bbls of cement wash water,switched to rig pumps and displaced with 770.3 bbls of mud,did not bump plug,pumped an additional 2.9 bbls (1/2 volume of shoe joint),total displacement was 793 bbls,did not bump plug,displacement pressure was 390 psi until cement turned corner and pressure increased to 850 psi by end of job. 03:00 12:00 9.00 17,344 17,344 INTRM1 CEMEN"WOC T Didn't bump plug on displacement, WOC(performed rig maintenance- worked on TD blower switch-Change out disc brake pads,-worked on iron roughneck,changed oil in TD 12:00 12:15 0.25 17,344 17,344 INTRM1 CEMEN'SFTY P PJSM on 2nd stage cement operation 12:15 13:15 1.00 17,344 17,344 INTRM1 CEMEN'CIRC P Bled of pressure on cement head and checked floats,OK,-Loaded closing plug for 2nd stage job,, Pressured up on casing to 3270 opsi and opened stage collar at 8601'- Established circulation at 4 bbls/min. @ 300 psi and circulated-hole taking fluid @ 168 bbls/hr.slowing to 145 bbls after 60 minutes Page 17 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:15 15:30 2.25 17,344 17,344 INTRMI CEMEN"CIRC P Pumped 2nd stage cement job as �aPits follows: Pumped 2 bbls of CW-100- (�( Tested lines to 4800 psi3OK,- 2„� Pumpedremaining 18 bbsl of k,,,t3' CW-100 @ 3 bpm and 300 psi, S a Mixed and pumped30 bbls of 12.5 ppg MudPush @ 5 bpm @ 380 psi, Mixed and pumped 60 bbls-(290 sks Alpine Surface tail cement)@ 15.8 ppg @5bpm and 340psi- Shut down and dropped closing plug w/20 bbls of water from Dowell- Switched over to rig pumps and diplaced cement@ 6 bpm and 340 psi for the first 365 bbls-slowed pump to 3 bpm for the next 11 bbls and to 2 bpm for the last 2 bbls- Bumped plug w/1600 psi and increased pressure to 2500 psi- Bleed off pressure to 2500 psi and held for 5 minutes to close stage collar-bleed off pressure to confirm stage collar closed OK-CIP @ 1505 hrs-Pumped job with partial returns through out job Lost total of 185 bbls during circulating before job and during ent job 15:30 16:45 1.25 17,344 17,344 INTRM1 CEMEN-CMNT P R/D cement equipment and cleared floor 16:45 18:00 1.25 17,344 17,344 INTRM1 WHDBO PULL P Pulled wear bushing with some difficulty due to the lip on the top edge of one side being bent in 18:00 19:00 1.00 17,344 17,344 INTRM1 WHDBO PRTS P Set 7 5/8"packoff in wellhead and tested same to 5,000 psi for 10 80p minutes,OK 19:00 19:30 0.50 17,344 17,344 INTRM1 WHDBO OTHR P Installed new wear bushing 19:30 21:30 2.00 17,344 17,344 INTRM1 WHDBO SFTY P PJSM for changing over upper rams to 3.5"X 6"variables 21:30 23:00 1.50 17,344 17,344 INTRM1 DRILL LOT P Performed LOT down the 10 3/4"X 7 5/8"annulus,pumped water at.75 bpm taking pressures at every 1/4 °P L..the pressure started to p� increase but very slowly,expected L leak off pressures were 1000 to 1200 ,1 psi and after pumping 23 bbls the maximum pressure was 300 psi, shut down job and observed the pressure to bleed down to 153 psi after 10 minutes,started preparing to perform freeze protection of the 10 3/4"X 7 5/8"casing annulus Page 18 of 31 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 17,344 17,344 INTRM1 DRILL FRZP P Commenced freeze protecting the well down the 10 3/4"X 7 5/8" annulus with 300 bbls of water to be followed with 68 bbls of diesel,the rig crew slipped and cut the drilling line as the freeze protect was being pumped. 01/22/2011 Concluded the LOT on the 10 3/4"X 7 5/8"annulus,freeze protected same,performed BOP test,OK, LD 5" drill pipe 00:00 01:30 1.50 0 0 INTRMI CEMEN"SFTY P Continued with freeze protection of the 10 3/4"X 7 5/8"casing annulus, pumped a total of 300 bbls of water ahead at 4 bpm and 850 psi followed by 68 bbls of diesel at 2.2 bpm and 750 psi,shut in annulus and RD Schlumberger,While pumping freeze protection,the rig performed a PJSM on LD drill pipe,then installed the drilling bales and 5"drill pipe elevators 01:30 04:30 3.00 0 0 INTRM1 CEMEN"PULD P LD 5"drill pipe via mouse hole 04:30 05:00 0.50 0 0 INTRM1 CEMEN"SVRG P Service rig 05:00 07:00 2.00 0 0 INTRM1 CEMEN"PULD P Cont. LD 5"Dp via mouse hole 07:00 07:15 0.25 0 0 INTRM1 CEMEN"SFTY T PJSM on repairing grap blocks 07:15 09:00 1.75 0 0 INTRM1 CEMEN"RGRP T Repair grab die block holes&install 4"save sub&die blocks 09:00 09:15 0.25 0 0 INTRM1 CEMEN"SFTY P PJSM on rig up for BOPE test 09:15 11:15 2.00 0 0 INTRM1 CEMEN"BOPE P Pull wear bushing-Set test plug- Grease IBOP-Fill lines w/water for BOP test 11:15 11:30 0.25 0 0 INTRM1 CEMEN"BOPE P PJSm on testing BOPE 11:30 18:00 6.50 0 0 INTRM1 CEMEN'BOPE P Test BOPE as follows:Tested Annular to 250&2560 psi-tested pipe rams,choke manifold, kill& choke line valves to 250&3500 psi- Tested TD IBOP's,floor safety&dart �P valves to 250&3500 psi-performed accumulator recovery test- functioned remote BOP pannel in boiler room-Tested blind rams to 250&3500 psi(alll tests done with 4"test jt.)tested annulrar w/3 1/2'& 4 1/2'test jts to 250&2500 psi- Tested pipe rams w/3 1/2'&4 1/2' test jts.to 250&3500 psi-Test witnessed&approved by Bob Noble AOGCC 18:00 18:30 0.50 0 0 INTRMI CEMEN"BOPE P Pulled test plug and set wear bushing 18:30 19:00 0.50 0 0 INTRM1 CEMEN"BOPE P B/D kill and choke lines 19:00 00:00 5.00 0 0 INTRMI CEMEN"PULD P Continued to LD 5"drill pipe out of derrick Page 19 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/23/2011 24 hr Summary Continued to LD 5"drill pipe, MU cleanout BHA and RIH with BHA while singling in with 4"drill pipe 00:00 11:30 11.50 0 0 INTRMI CEMEN"PULD P Continued to LD 5"drill pipe 11:30 12:30 1.00 0 0 INTRMI CEMEN"PULD P MU seven stands of 4"DP and stood back in derrik 12:30 13:00 0.50 0 0 INTRM1 CEMEN"PULD P Changed out elevators for handing the cleanout BHA 13:00 14:30 1.50 0 306 INTRM1 CEMEN"PULD P MU cleanout BHA 14:30 19:30 5.00 306 6,058 INTRM1 CEMEN"PULD P Continued to PU 4"drill pipe singles and RIH with cleanout BHA 19:30 20:00 0.50 6,058 6,058 INTRMI CEMEN"SVRG P Serviced rig 20:00 23:00 3.00 6,058 8,411 INTRM1 CEMEN"PULD P Continued to PU 4"drill pipe singles and RIH with cleanout BHA 23:00 00:00 1.00 8,411 8,411 INTRM1 CEMEN"CIRC P Circulating bottoms up at 6 bpm and 1450 psi in preparation for casing test, PUW: 160K,SOW: 115K 01/24/2011 RIH with cleanout assembly,tested 7 5/8"casing to 1000 psi for 30 minutes OK,drilled out stage collar at 8600', retested 7 5/8"casing to 1000 psi for 30 minutes OK, POOH, MU BHA#6, RIH to drill 6 3/4" production hole 00:00 01:00 1.00 8,411 8,411 INTRM1 CEMEN"PRTS P Blow down top drive,MU head pin, closed variable pipe rams and pressure tested casing to 1000 psi for 10 minutes(prior to drilling out stage collar)-OK 01:00 01:45 0.75 8,411 8,600 INTRM1 CEMEN"WASH P Bled off pressure, RD head pin, Wash down w/DP f/derrick f/8411 to top of stage collar at 8600'-6 bbls/min-1250 psi w/30 rpm's-8 k torque 01:45 02:30 0.75 8,600 8,602 INTRMI CEMEN"DRLG P Drill out wiper plug&stage collar f/ 8600'to 8602'-6 bbls/min-1320 psi w/30 rpm's-8.5 k toruqe-Rot wt. 133 k 02:30 04:00 1.50 8,602 9,078 INTRMI CEMEN"WASH P Wash&ream f/8602'to 9078'-6 bbls/min @ 1250 psi-30 rpm's-9 k torque 04:00 04:45 0.75 9,078 9,078 INTRM1 CEMEN"CIRC P Circ btms up @ 9078'-6 bbls/min- 1220 psi-for pressure test 04:45 05:30 0.75 9,078 9,078 INTRM1 CEMEN"PRTS P Blow down TD-RU&tested casing to 1000 psi for 10 mins(after drilling stage collar)OK-RD&blow down lines 05:30 10:30 5.00 9,078 117 INTRM1 CEMEN"TRIP P POOH on TT f/9078'to 117'-PU wt 170 So wt 117 10:30 12:00 1.50 117 0 INTRM1 CEMEN"PULD P Change DP elevators-Std back NM flex DC's-LD float sub,motor&bit 12:00 17:00 5.00 0 396 INTRM1 DRILL PULD P MU BHA#6-6 3/4"bit(FXG54D)- 5200 Geo-Pilot-NM Geo-Flex collar -NM sleeve stab-ADR collar-NM sleeve stab-DM collar-GM collar- PWD-TM pulser-NM float collar-3 NM flex DC's-XO-Jars-1 jt 4" HWDP-drilling bumper sub-4 jts 4" HWDP-total BHA 396.35' Page 20 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 00:00 7.00 396 7,357 INTRM1 DRILL PULD P RIH with BHA#6 on 4"DP from 396' to 7,357' 01/25/2011 Cont. RIH w/BHA#6 picking up 4"DP f/pipe shed f/7357'to 15,188'-RIH w/17 stds DP f/derrick to 16,810'-Slip&cut drill line&service TD-Wash down f/16810'to 16935'(Tagged up 282'above baffle collar) Circ btms up-RU&Test casing to 3500 psi for 30 mins OK-Change well over f/10.8 ppg LSND to 9.0 ppg MOBM-Clean out cmt f/16,935'to 17,096'MD 00:00 07:00 7.00 7,357 15,188 INTRM1 DRILL TRIP P Cont. RIH w/BHA#6 f/7357'to 15,188'picking up 4"DP f/pipe shed (fill pipe every 20 stds)PU wt.252 SO wt. 125 07:00 08:00 1.00 15,188 16,810 INTRM1 DRILL TRIP P RIH w/17 stds f/derrick f/15,188'to 16,810'-PU wt.275 SO wt. 125 08:00 08:15 0.25 16,810 16,810 INTRMI RIGMNTSFTY P Held PJSM on slip&cut drill line 08:15 10:15 2.00 16,810 16,810 INTRMI RIGMNT SLPC P Slip&cut drill line&service TD 10:15 11:15 1.00 16,810 16,905 INTRM1 DRILL WASH P Wash down f/16,810'to 16935'( tagged up on cmt 282'High)@ 240 gpm @ 2450 psi-PU wt.260 SO wt 125-Stad back 1 std DP to 16905' 11:15 12:45 1.50 16,905 16,905 INTRM1 DRILL CIRC P Circ btms up for casing test @ 240 gpm @ 2240 psi 12:45 14:30 1.75 16,905 16,905 INTRM1 DRILL PRTS P RU&pressure test 7 5/8"casing to 3500 psi for 30 mins.Good test-RD 14:30 14:45 0.25 16,905 16,905 INTRM1 DRILL SFTY P PJSM on mud change over 14:45 17:15 2.50 16,905 16,905 INTRM1 DRILL CIRC P PU single of 4"DP-Displace well over f/10.8 ppg LSND mud to 9.0 ppg MOBM-LD 1 single 4"DP 17:15 00:00 6.75 16,905 17,096 INTRM1 CEMEN"COCF P Clean Out Cement to 17,096'MD (FC @ 17,260'MD)-Managing Parameters in Attempt to Keep BHA Vibration Alarms in Check RPM 60-75,Torque 12.5-13 250-270 GPM @ 3300-3050 Psi 01/26/2011 Continue to Clean Out Cement&Drill Shoe Track f/17,096'MD U 17,359-Drill 20'of New Hole for FIT Test- Circ&Condition Mud Prior to FIT-R/U and Perform FIT t/12.5 PPG-Drill 6%"Hole f/17,379'to 18,337'MD 00:00 04:30 4.50 17,096 17,260 INTRMI CEMEN"COCF P Continue to clean out cement to the baffle collar @ 17,217'MD-Drill baffle collar&cmt to FC @ 12,260'- Drill Shoe Track( FC @ 12,260'-FS @ 17,342'to 17,344') Rat Hole t/ 17,359'MD-250 gpm @ 2910 psi- 75 rpm's-14 k torque-PU wt.230 SO wt. 145 Rot wt. 189 04:30 05:15 0.75 17,359 17,379 INTRM1 DRILL DDRL P Drill 20'new hole f/17,359'to 17,379' MD 7302'TDV WOB 10/12 k RPM 120 GPM 270 gpm @ 3390 psi Stirng wt-PU 230 SO 145 Rot 189 Torque-14 k ADT-0.4 hrs. 05:15 06:45 1.50 17,379 17,379 INTRM1 DRILL CIRC P Circ&Condition Mud Prior to LOT @ 250 gpm @ 2970 psi-60 rpm's-13 k torque Page 21 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:451 07:45 1.00 17,379 17,379 INTRMI DRILL FIT P Blow down TD-RU&perform FIT to / I 12.5 ppg EMW w/9.0 ppg @ 7297' I/ ffi ND w/1340 psi applied pressure- RD-blow down kill line 07:45 12:00 4.25 17,379 17,609 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/17,379'to 17,609'MD 7314'ND ADT-2.75 hrs ECD-10.05 ppg Footage-230' WOB 10/12 k RPM 120 GPM 270 @ 3390 psi String wt. PU 245 SO 145 Rot 187 Torque on/off btm.-14/12.5 k 12:00 00:00 12.00 17,609 18,337 PROD1 DRILL DDRL P Drilled 6'/."Hole U 18,337'MD ADT 10.66 P/U 250,S/0 145, Rot 187 WOB 10-12, RPM 120 Torque On/Off 14.5/13.5 270 GPM @ 3310 Psi; ECD 10.19 01/27/2011 Continue to Drill 6'/."Hole U 19,196'MD-Draw Works Electromagnetic Brake Failed-POOH w/Pumps U 17,286'MD-Monitor the Well on the TT While Working the Draw Works Brake 00:00 12:00 12.00 18,337 19,036 PROD1 DRILL DDRL P Drill 6%"Hole U 19,036'MD ADT 9.25 P/U 253,S/O 135, Rot 185 Torque On/Off 14.5/13.5 RPM 120 WOB 10-13 270 GPM @ 3490 Psi; ECD 10.29 12:00 15:30 3.50 19,036 19,196 PROD1 DRILL DDRL P Drill 6%"Hole t/19,196'MD ADT 1.71 P/U 253,S/O 135, Rot 185 Torque On/Off 14.5/13.5 RPM 120 WOB 10-13 270 GPM @ 3700 Psi; ECD 10.24 15:30 16:00 0.50 19,196 19,196 PROD1 RIGMN1SVRG P Rig Service-Lubricate Draw Works and Troubleshoot Electromagnetic Brake 16:00 18:00 2.00 19,196 19,196 PROD1 DRILL CIRC T Draw Works(Electromagnetic) Brakes Failed-CBU Prior to Pulling to Shoe-Take SPR's 270 GPM @ 3620 Psi;60 RPM 18:00 22:00 4.00 19,196 17,286 PROD1 DRILL TRIP T Pump Out of Hole to 17,286'MD 270 GPM @ 3300 Psi 22:00 00:00 2.00 17,286 17,286 PROD1 RIGMNT RGRP T Blow Down the Top Drive-Monitor Hole on Trip Tank While Repairing Draw Works"Dyna-Matic"Brakes 01/28/2011 Continue to Repair Draw Works Brake-RIH U 19,100'MD-Wash U 19,196'MD-Drill 6%"Hole U 20,003 Page 22 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 08:30 8.50 17,286 17,286 PROD1 RIGMNT RGRP T Continue to Repair the Draw Works Brake-Pull Bolts f/the Wind Wall and Move Equipment for Pick w/ Crane-Swap Fittings-Pick New Brake Up and Install Through Hole in Wind Walls-Mount,Shim and Connect Brake Monitor Well on TT then Circulated Conventionally @ 4 BPM w/1340 Psi to Save MWD Batteries-Static Loss Rate%BPH 08:30 09:45 1.25 17,286 19,100 PROD1 DRILL TRIP T Blow down TD-RIH f/17,286'to 19,100'-PU wt 250 So wt. 138 09:45 10:00 0.25 19,100 19,196 PROD1 DRILL WASH T Wash down f/19,100'to 19,196'@ 270 gpm @ 3700 psi w/110 rpm's- 13.5 k torque 10:00 12:00 2.00 19,196 19,291 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/19,196'to 19,291'MD 7337'TVD ADT-1.31 hrs ECD-10.36 ppg Footage-96' WOB 10/12 k RPM's 120 GPM 270 @ 3810 psi String wt. PU 250 SO 135 Rot 188 Torque on/off btm.-14.5/13.5 k 12:00 00:00 12.00 19,291 20,003 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/19,291'to 20,003'MD ADT 8.84 P/U 255, S/O 130, 185 RPM 120,WOB 10-14 Torque On/Off 15.5/16 260 GPM @ 3,780 Psi; ECD 10.41 01/29/2011 Continue to Drill 6'/:'Hole t/21,225'MD 00:00 12:00 12.00 20,003 20,627 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/20003'to 20627'MD 7347'TVD ADT-8.95 hrs. ECD-10.38 ppg Footage-624' WOB 12/14 k RPM 120 GPM 260 @ 3730 psi String wt. PU 260 SO 137 Rot 185 Torque on/off btm.-15.5/14.5 k 12:00 00:00 12.00 20,627 21,225 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/20,627'to 21,225'MD ADT 8.24 P/U 265,S/O 135, Rot 183 Torque On/Off 16.5/16.5 RPM 120,WOB 10-15 250 GPM @ 3780, ECD 10.53 01/30/2011 Continue to Drill 6' "Hole t/22,354'MD Page 23 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 08:45 8.75 21,225 21,581 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/21,225'to 21,581'MD 7352'TVD ADT-5.92 hrs ECD 10.52 ppg Footage-356' WOB 14 k RPM 120 GPM 250 @ 3700 psi String wt. PU 260 SO 130 Rot 185 Torque on/off btm.-16/15.5 k 08:45 09:15 0.50 21,581 21,581 PROD1 RIGMNT SVRG P Service TD&travel block 09:15 12:00 2.75 21,581 21,677 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/21581'to 21,677'MD 7353'TVD ADT-1.27 hrs. ECD-10.52 ppg Footage-96' WOB 14 k RPM 120 GPM 250 @ 3700 psi String wt- PU 260 SO 130 Rot 185 Torque on/off btm.-16/15.5 k 12:00 00:00 12.00 21,677 22,354 PROD1 DRILL DDRL P Drill 6 3/:'Hole U 22,354'MD ADT 7.48 P/U 270,S/O 125, Rot 183 WOB 15, RPM 120 Torque On/Off 17.5/16 245 GPM @ 3620 Psi; ECD 10.68 01/31/2011 Continue to Drill 6 3/."Hole U 22,495'MD-GeoPilot RPM Sensor Failed-Conversed w/Anchorage Based Geologist/Engineer, Decided to Drill Ahead-Continue to Drill 6 3/"Hole U 22,658'MD-CBU X3-OWFF (Static)-BROOH U 19,291'MD(25 Stands) 00:00 02:00 2.00 22,354 22,495 PROD1 DRILL DDRL P Drill 6 3/"Hole U 22,495'MD (Geo-Pilot RPM Sensor Failed) ADT 1.5 P/U 270,S/O 125, Rot 183 RPM 120,WOB 10-15 Torque On/Off 18/16 245 GPM @ 3630 Psi; ECD 10.68 02:00 03:30 1.50 22,495 22,495 PROD1 DRILL SVRG T Troubleshoot Geo-Pilot-Contact Town Based Geologist/Engineer- Discussed Options-While Waiting for Plan Forward Decided to Change Circuit Card on Electro-Magnetic Brake Controller-Plan to Drill Ahead with Reduced Capability; Unable to Steer but All Other Data Okay 03:30 11:00 7.50 22,495 22,658 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/22.495'to 22,658'MD 7362'ND • ADT-3.99 hrs ECD-10.61 ppg Footage-163' WOB 14 k RPM 120 GPM 250 @ 3870 psi String wt PU 270 SO 120 Rot 188 Torque on/off btm.-17/17.5 k TD called @ 22,658'by town Geologist Page 24 of 31 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 11:00 18:00 7.00 22,658 21,867 PROD1 CASING CIRC P Stand back 1 stand DP-Pu 1 single of 4"DP-Began to circ 3 X btms up @ 250 gpm @ 3860 psi w/120 rpm's -15 k toruqe-Std back 1 std DP every 30 mins.f/22,658'to 21,867' MD 18:00 19:15 1.25 21,867 21,294 PROD1 DRILL REAM P OWFF(Static)-BROOH t/21,294' MD(6 Stands)250 GPM w/3500 Psi and 120 RPM 19:15 20:15 1.00 21,294 21,294 PROD1 RIGMNT RGRP T Change Swivel Packing-Pressure Test Lines U 3500 Psi-OWFF (Static) 20:15 00:00 3.75 21,294 19,291 PROD1 DRILL REAM P Continue to BROOH U 19,291'MD (19 Stands); 120 RPM,250 GPM w/ 3400 Psi 02/01/2011 Continue to BROOH U 17,286'MD-CBU-OWFF(Static)-POOH w/Pumps U 16,333'MD-POOH on TT U 396'MD-Read MWD Data and UD BHA#6-R/U to Run 31/2"SLHT Liner 00:00 03:30 3.50 19,291 17,286 PROD1 DRILL REAM P Continue to BROOH U 17,286'MD (21 Stands)-90 RPM,250 GPM @ 3100 Psi 03:30 05:15 1.75 17,286 17,286 PROD1 DRILL CIRC P OWFF(Static)-CBU @ 270 GPM w/3700 Psi&60 RPM-OWFF (Static) 05:15 06:30 1.25 17,286 16,333 PROD1 DRILL TRIP P Drop Rabbit-Pump Out of Hole U 16,333'MD 06:30 18:30 12.00 16,333 396 PROD1 DRILL TRIP P POOH on TT t/396(167 Stands) 18:30 19:00 0.50 396 105 PROD1 DRILL PULD P Stand Back HWDP and Jars-UD NMFDC's 19:00 20:00 1.00 105 105 PROD1 DRILL PULD P Plug In and Read MWD Data 20:00 21:00 1.00 105 0 PROD1 DRILL PULD P UD the Remainder of BHA#6- NOTE:GoePilot Housing Rotated by Hand,Oil Level Low 21:00 22:00 1.00 0 0 PROD1 DRILL PULD P Clean and Clear the Rig Floor-UD Geo-Span-Work On Link Tilt Air Leak and MP2 Rheostat 22:00 23:15 1.25 0 0 COMPZ CASING RURD P R/U to Run 3/2'SLHT Lower Completion 23:15 00:00 0.75 0 0 COMPZ CASING OTHR P Wait on Crew Change Prior to PJSM 02/02/2011 Run 3/2"Liner,9 Packers,7 Frac Sleeves, Flex Lock Hanger and ZXP Liner Top Packer on 4"DP U 17,389' MD-Circ Liner/DP Volume 00:00 00:15 0.25 0 0 COMPZ CASING SFTY P PJSM on Running 3 1/2'Liner and Jewelry Page 25 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:15 14:30 14.25 0 5,743 COMPZ CASING PULD P P/U 3/2"SLHT Liner per Detail as Follows: 3/2'Orange Peeled Shoe, 11 Jts Liner, 10'Perforated Pup Jt,9 )1' Jts Liner,TAM Swell Packer w/6/2' SW L 4,L Centralizers,9 Jts Liner, Ball Pi-G Actuated Frac Sleeve,9 Jts Liner, I TAM Swell Packer w/6/2' � 6r`" Centralizers, 10 Jts Liner, Ball 5 1�r. Actuated Frac Sleeve,9 Jts Liner, ll TAM Swell Packer w/6/2' Centralizers,9 Jts Liner, Ball Actuated Frac Sleeve,9 Jts Liner, TAM Swell Packer w/6/2' Centralizers,9 Jts Liner, Ball Actuated Frac Sleeve,9 Jts Liner, TAM Swell Packer w/6/2' Centralizers,9 Jts Liner,TAM Swell Packer w/6/2'Centralizers,9 Jts Liner, Ball Actuated Frac Sleeve,9 Jts Liner,TAM Swell Packer w/6%" Centralizers, 10 Jts Liner,TAM Swell Packer w/6/2'Centralizers, 10 Jts Liner, Ball Actuated Frac Sleeve,9 Jts Liner,TAM Swell Packer w/6/2' Centralizers, 10 Jts Liner, Ball Actuated Frac Sleeve, 10 Jts Liner, TAM Swell Packer w/6.4"Poly Centralizers, 13 Jts Liner,XN Nipple w/2.75"No-Go, 1 Jt Liner, Baker 80-40 SBE, Flex Lock Liner Hanger and ZXP Packer-Mixed/Applied Pal Mix and Allowed to Cure for 30 Minutes Frac Sleeves Ran(Deepest to Shallowest)in the Following Order: Ball Seat ID, 1.25", 1.375", 1.5", 1.625", 1.75", 1.875",2.0"-Verified Two Shear Screws Installed on Sleeves 14:30 15:00 0.50 5,743 5,743 COMPZ CASING CIRC P Circulate Liner Volume @ 4 BPM w/ 850 Psi-Established Rotation w/ 4.5K Torque @ 10 RPM P/U 104,S/O 95 15:00 22:30 7.50 5,743 17,389 COMPZ CASING RUNL P RIH w/3 1/2'SLHT Liner on 4"DP t/ 17,389'MD(122 Stands) P/U 227,S/O 125 22:30 00:00 1.50 17,389 17,389 COMPZ CASINGCIRC P Circ Liner/DP Volume @ 3.5 BPM w/ 1400 Psi-Blow Down the Top Drive- OWFF(Static) 02/03/2011 Continue to RIH w/Liner on 4"DP t/20,941'MD(Unable to Go Lower)-Work Liner,Attempt to Circulate- Rotate Liner to Set Depth of 22,648'MD-Set Liner Hanger, inflate Packer and Test to 3300 Psi f/10 Minutes -POOH to Free Liner Running Tools from Components-OWFF(Flowing)-Flash Light Fell Into Hole- Circulate Pumping High Vis Sweeps and"Super Sweep"(Unsuccessful)-OWFF(Static, Falling)-POOH t/ 16,500'MD on TT Page 26 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 02:15 2.25 17,389 20,941 COMPZ CASING RUNL P Continue to RIH w/3 1/2'SLHT Liner on 4"DP t/20,941'MD(37 Stands) 02:15 07:00 4.75 20,941 20,941 COMPZ CASING RUNL T Took Weight(Unable to Move Down) -Worked Pipe Able to Move Up but Not Down&Losing Ground-Attempt to Circulate @ 1 BPM w/1420 Psi (Partial Returns 50%Increasing Over, Time t0 100%)-Attempt to Work Pipe Down(Unable)-Attempt to Regain Circulation Only Able to Attain 50%Returns-Call Town and Discuss Options-Continue Working Pipe-Lost Ground t/20,826'MD- Increase Torque Limiter to 22K-P/U to Free Weight and Rotate String @ 10 RPM-Stopped Moving Pipe, Continued Rotating and Torque was 16 @ 10 RPM-Able to Rotate String Down to Original Point of 20,941'MD 07:00 15:00 8.00 20,941 22,648 COMPZ CASING RUNL P Rotate Liner Down t/22,648'MD(17 'V Stands)-20 RPM w/16-17K Torque and Rotating Weight of 180K 15:00 17:45 2.75 22,648 22,648 COMPZ CASING HOSO P Drop Baker 1.75"Ball-Work Pipe f/ 30 Minutes-Circ Ball Down @ 205 BPM w/19000 Psi-Ball On Seat at 73.8 Bbls Pumped-Set Liner Hanger and ZXP Packer 17:45 18:15 0.50 22,648 22,648 COMPZ CASING PRTS P Test Packer @ 3300 Psi f/10 Minutes 18:15 19:15 1.00 22,648 16,799 COMPZ CASING OWFF P Pulled Above Liner Hanger and Packer w/Running Tools U 16,799' MD-OWFF(Well Flowing but Flow Decreased to.08 BPH Over 1 Hour) 19:15 23:00 3.75 16,799 16,799 COMPZ CASING CIRC T Circ Bottoms Up, High Vis and "Super Sweep"in Hole in Attempt to Retrieve Flash Light(Unsuccessful) 6.5 BPM @ 2650 Psi(Reciprocating Pipe) 23:00 00:00 1.00 16,799 16,500 COMPZ CASING TRIP P OWFF(Static, Dropping Slightly)- POOH on TT f/16,799'to 16,500'MD 02/04/2011 Continue to POOH w/Liner Running Tools t/190'MD-Circulate a High Vis/Weighted Sweep, Recovered Flashlight Casing but Still Have 4 AA Batteries, Bezel and Lens in the Hole-POOH and L/D liner Running Tools-Place"Junk Catcher"in Bottom of Stack and Function Rams, Flashlight Not Retrieved-Test BOPE, AOGCC Inspector Jeff Jones Waived Witnessing the Test-M/U Fishing BHA(6"Magnet)and RIH t/3,820' MD(40 Stands)-POOH w/Magnet t/1,721'MD @ Midnight 00:00 09:30 9.50 16,500 190 COMPZ CASING TRIP P Continue to POOH w/Liner Running Tools U 190'MD 09:30 09:45 0.25 190 190 COMPZ CASING OWFF P OWFF(Static) 09:45 11:00 1.25 190 190 COMPZ CASING CIRC T Change Shaker Screens-Mix and Pump Viscosified/Weighted Sweep 600 GPM @ 550 Psi-Recovered Flash Light Housing,4-AA Batteries, Bezel and Lens Remain in the Hole 11:00 12:00 1.00 190 0 COMPZ CASING TRIP P Blow Down the Top Drive and POOH -L/D Liner Running Tools Page 27 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:45 0.75 0 0 COMPZ WHDBOOTHR P Pull Wear Ring-Set Junk Catcher Wear Ring-Function Rams-Pull Junk Catcher-Recovered Pieces of Cement Plug but No Flashlight 12:45 13:15 0.50 0 0 COMPZ WHDBO RURD P R/U to Test BOPE 13:15 20:30 7.25 0 0 COMPZ WHDBO BOPE P Test BOPE w/3 1/2"and 4"Test Joints as Follows:Test Annular Preventer V 250/2500 Psi,Test Upper Rams, Lower Rams,Choke Manifold Valves and 4"DEMCO to 4 250/3500 Psi,Test Blind Rams, Dart,TIW,Auto/Manual IBOP, lS� Manual and HCR Choke and Kill Lines to 250/3500 Psi-Perform Accumulator Draw Down Test- Witness of the Test Waived by AOGCC Inspector Jeff Jones 20:30 21:00 0.50 0 0 COMPZ WHDBO RURD P R/D BOPE Testing Equipment-Set Wear Ring 21:00 21:30 0.50 0 0 COMPZ FISH PULD T M/U Fishing BHA;6"Magnet, Bit Sub w/Float, and XO 21:30 23:00 1.50 0 3,820 COMPZ FISH FISH T RIH w/Magnet t/3,820'MD(40 Stands),Attempt to Recover Batteries 23:00 00:00 1.00 3,820 1,721 COMPZ FISH TRIP T OWFF(Static)-POOH w/Magnet t/ 1,721 MD 02/05/2011 Continue to POOH w/Magnet, Recovered 3 AA Batteries-P/U Reverse Circulating Basket and RIH V 3,348' MD-Circ 80 Bbls @ 8 BPM w/1650 Psi Through Reverse Basket-RIH U 5,264'MD-Circ 100 Bbls @ 7.5 BPM w/1860 Psi Through Reverse Basket-OWFF(Static)-POOH w/Fishing BHA, Recovered Lens and Cap(1 AA Battery and Bezel Left in Hole)-Slip/Cut 113'of Drill Line-R/U and Run Upper Completion V 5,600'MD per Detail 00:00 00:45 0.75 1,721 0 COMPZ FISH TRIP T POOH w/Magnet to Surface-3 AA Batteries Recovered-OWFF(Static) 00:45 01:45 1.00 0 0 COMPZ FISH PULD T LID Magnet-P/U&M/U Reverse Circulating Junk Basket BHA 01:45 03:15 1.50 0 3,348 COMPZ FISH TRIP T RIH w/Reverse Circulating BHA t/ 3,348'MD(35 Stands) 03:15 04:00 0.75 3,348 3,348 COMPZ FISH CIRC T Circulate 80 Bbls Through Reverse Sub @ 8 BPM w/1650 Psi-Unsure if Ball Remained On Seat-Dropped 2nd Ball-Circ Again @ 8 BPM w/ 1650 Psi-Blow Down Top Drive 04:00 05:00 1.00 3,348 5,264 COMPZ FISH TRIP T RIH w/Reverse Circulating Sub V 5,264'MD(20 Stands-55 Total) 05:00 05:30 0.50 5,264 5,264 COMPZ FISH CIRC T Circulate 100 Bbls Through Reverse Sub @ 7.5 BPM w/1860 Psi- OWFF(Static) 05:30 08:15 2.75 5,264 0 COMPZ FISH TRIP T Blow Down the Top Drive-POOH U Surface 08:15 09:00 0.75 0 0 COMPZ FISH PULD T LID Fishing BHA 09:00 10:00 1.00 0 0 COMPZ FISH OTHR T Clean and Clear the Rig Floor 10:00 12:00 2.00 0 0 COMPZ RIGMN1SLPC P Slip and Cut 113'of Drill Line 12:00 14:15 2.25 0 0 COMPZ RPCOM RURD P R/U to Run Upper Completion Page 28 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:15 15:15 1.00 0 525 COMPZ RPCOM RCST P Run Upper Completion as Follows: 80-40 Seal Assembly,3%"EUE Tubing w/Locator, 1 Jt 3 1/2'EUE Tubing,XO, 10 Jts 4'/2'IBTM Tubing, HES"XN"Nipple w/RHC Plug and 2 Jts Tubing U 525'MD 15:15 15:45 0.50 525 530 COMPZ RPCOM PULD P P/U Gauge Mandrel Test t/5,000 Psi , M/U TEC Line and Test 15:45 00:00 8.25 530 5,600 COMPZ RPCOM RCST P Continue to Run Upper Completion as Follows: 1 Jt Tubing,"X"Nipple, 1 Jt Tubing, KBGM GLM w/DCK SOV Installed,99 Jts Tubing, KBMG GLM w/Dummy Installed,24 Jts Tubing (TEC Line Tested Every 30 Jts) 02/06/2011 Continue to Run upper Completion Tubing t/16,841'MD-Circulate 1 Tubing Volume of Mud-Wash Down and Sting Seal into SBE-Tag No Go @ 16,939'MD-Pull to above ZXP Liner Top and Displace Wellbore f/ MOBM to 9.2 PPG Brine-M/U Remaining Tubing and Tubing Hanger-Terminate Control Lines and Test t/ 5,000 Psi f/5 Minutes-Land Tubing w/Tail @ 16,954'MD(4.5'from Fully Located Position)-R/D Tubing Equipment-Clear the Rig Floor-R/U Hard Lines and Displacement Manifold-Test IA and Seals t/1,000 Psi to Verify Seal Engagement-Drop Ball 7 Rod and R/U Remaining Hard Lines 00:00 09:15 9.25 5,600 14,721 COMPZ RPCOM RCST P Continue to Run Upper Completion as Follows: 131 Jts of Tubing, KBMG GLM w/Dummy Installed,94 Jts Tubing 09:15 10:15 1.00 14,721 14,721 COMPZ RPCOM PRTS P R/U and M/U BP-6i Nipple and Test U 5,000 Psi f/15 Minutes 10:15 13:00 2.75 14,721 16,841 COMPZ RPCOM RCST P Continue to RIH w/52 Jts of 4 1/2' Tubing U 16841'MD(Cannon Clamps on Every Joint) 13:00 13:30 0.50 16,841 16,841 COMPZ RPCOM RURD P M/U 4'/2'IBTM by 4"XT 39 XO-R/D Tubing Equipment and R/U to Handle 4"DP for Space Out 13:30 14:15 0.75 16,841 16,841 COMPZ RPCOM CIRC P Circ 1 Tubing Volume @ 6 BPM w/ 1,000 Psi 14:15 15:00 0.75 16,841 16,903 COMPZ RPCOM WASH P Wash Down and Observe Seals Enter Hanger-Tag No Go @ 16,839' MD-Pull Above ZXP t/16,903'MD 15:00 19:00 4.00 16,903 16,903 COMPZ RPCOM CIRC P Displace Wellbore Fluids Above Hanger t/9.2 PPG Inhibited KCL as Follows: Pumped 25 Bbls of LVT 200, 70 Bbls of 11.2 PPG Transition Spacer,35 Bbls Cleaning Spacer (ECF1840),35 Bbls of Viscosified Brine(9.2 PPG),200 Bbls of Clean 9.2 PPG Brine,585 Bbls of 9.2 PPG Inhibited Brine and 10 Bbls of Clean Brine 6 BPM w/870-600 Psi 19:00 21:45 2.75 16,903 16,954 COMPZ RPCOM HOSO P M/U 2 Jts of Tubing-Pull Wear Ring -M/U Tubing Hanger and Terminate Control Lines-Test Voids U 5,000 Psi f/5 Minutes-Land Tubing Hanger w/Tubing Tail @ 16,954'MD (4.5'Above Fully Located Position) 21:45 23:00 1.25 16,954 16,954 COMPZ DRILL OTHR P Clean and Clear the Rig Floor-R/U Displacement Manifold Hard Lines Page 29 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 23:30 0.50 16,954 16,954 COMPZ DRILL PRTS P Pressure Test annulus to 1,000 Psi to Verify Seals Holding-Drop 1 7/8" Ball and 9'Rod w/5-2"Rollers 23:30 00:00 0.50 16,954 16,954 COMPZ DRILL RURD P R/U Hard Lines-Crew Change 02/07/2011 Pressure Test Tubing t/3500 Psi f/30 Minutes-Pressure Test IA t/3,500 Psi f/30 Minutes-Install TWC- Test TWC and Tubing Hanger t/5000 Psi f/Above and 3,000 Psi f/Below f/10 Minutes-Wash BOPE Stack -N/D BOPE-N/U Tree. Pull TWC. RU hard line. Pump 100 bbls diesel to tbg and U tube to IA to FP to 2000' TVD. Install BPV and secure well. RU and LDDP from derrick.OAP=300 psi. IAP=100 psi.Tubing pressure=100 psi. 00:00 02:00 2.00 16,954 16,954 COMPZ DRILL PRTS P Pressure Test Tubing U 3500 Psi f/ 30 Minutes-Bleed Tubing U 2300 Psi-Pressure Test IA U 3500 Psi f/ a fib. 30 Minutes-Bleed Tubing Pressure I U 600 Psi and Observe GLM Shear- Bleed Both IA and Tubing U 0 02:00 02:45 0.75 16,954 16,954 COMPZ DRILL PRTS P Install TWC and M/U Landing Jt B- Test TWC and Tubing Hanger U 5000 Psi f/Above and 3,000 Psi f/Below for 10 Minutes 02:45 03:15 0.50 16,954 16,954 COMPZ DRILL RURD P R/D Hard Lines 03:15 04:45 1.50 16,954 16,954 COMPZ WHDBOOTHR P Wash BOPE Stack.Blow down top drive, mud lines, kill&choke lines. 04:45 05:30 0.75 16,954 16,954 COMPZ WHDBO OTHR P Clear&clean rig floor. 05:30 08:00 2.50 16,954 0 COMPZ WHDBO NUND P PJSM. ND BOPE.Change out TD saver sub to 4 1/2"IF. 08:00 11:30 3.50 0 0 COMPZ WHDBO NUND P Terminate control lines.NU tbg head adaptor and tree.Test to 5000 psi for 10 min-OK. 11:30 12:45 1.25 0 0 COMPZ WHDBO RURD P RU lubricator. Pull TWC. RD lubricator and RU hard line to tubing and annulus. 12:45 13:45 1.00 0 0 COMPZ DRILL FRZP T Attempt to test surface lines. Lines under floor frozen-thaw out same. 13:45 17:30 3.75 0 0 COMPZ DRILL FRZP P Test lines to 2000 psi-OK. Load tubing with 100 bbls diesel.Monitor pressure while allowing diesel to U tube to IA for 45 min. Bleed off pressure and shut in tubing and annulus. Blow down lines and RD same. 17:30 18:30 1.00 0 0 COMPZ WHDBO NUND P RU FMC lubricator. Install BPV. Secure wellhead and tree valves. 18:30 00:00 5.50 0 0 COMPZ DRILL PULD P RU to LD 4"DP from derrick. PJSM LDDP via mousehole. 144 jts laid down at midnight. 02/08/2011 LDDP from derrick.Clean mud pits- Clean MOBM from pipe racks and under rotary table. 00:00 20:30 20.50 0 0 COMPZ DRILL PULD P Continue LDDP from derrick-534 jts total laid down. 20:30 00:00 3.50 0 0 COMPZ DRILL DMOB P Clean rig floor,drip pan and pipe racks of MOBM prior to rig move. 02/09/2011 Finish LDDP. Clean MOBM from under rotary table and drip pan under floor.Clean out drillpipe racks of MOBM prior to move to CD3-127. Release rig at 10:00 hrs. Page 30 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 10:00 10.00 0 COMPZ DRILL DMOB P Continue cleaning MOBM from under rig floor and rotary table.Clean out mud from pipe racks. Prepare rig for pad to pad move. Release rig at 10:00 hrs. Page 31 of 31 HAL.LIBLJRTDN '31-w a, D"1419 WELL LOG TRANSMITTAL To: State of Alaska February 17, 2011 Alaska Oil and Gas Conservation Commission Attn.: Christine Shartzer 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-77 AK-MW-0007740437 CD2-77 50-103-20629-00 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5"ND TRIPLE COMBO Logs: 1 Color Log 2"x 5" MD BAT SONIC Logs: 1 Color Log 2"x 5"ND BAT SONIC Logs: 1 Color Log Digital Log Images& LWDG-formatted LIS Data w/verification listing: 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY 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 _ Bryan.Burinda@hailiburto om 010 _ .}C� 0-02,53 -!ECEIVE Date: FEB 2 4. 2011 Signed: • ..jos&Gss Coos.Commission Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, February 02, 2011 8:51 AM To: 'Anderson, Nina M' Subject: RE: CD2-77 Completion Changes f- -TD '2- Nina, Normally tubing size changes or packer upgrades don't require a change of program sundry to be submitted. By using a ZXP liner top packer(over the Premier) you actually move the packer closer to the production zone which is better anyway. In this case an email explaining the reasoning is sufficient for the commission. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Wednesday, February 02, 2011 8:23 AM To: Schwartz, Guy L(DOA) Subject: CD2-77 Completion Changes Guy— Currently on D19 we are running our completion for CD2-77. Changes have been made to the completion including upsized tubing and packer type and placement. Below is a summary on why these changes to CD2-77 were implemented. The original schematic submitted in the PTD along with an updated schematic with changes is attached with this email. Please let me know if you have any further questions or if a sundry needs to be submitted for these changes. Thanks. CD2-77 Completion Design Change: The CD2-77 original tubing configuration had 2 joints of 4-1/2"tubing near surface (because the tree is 4-1/2") and 3-1/2"tubing below. The current configuration has 4-1/2"tubing all the way down to the packer. All tubing jewelry was changed from 3-1/2"to 4-1/2". This was done because 1) desire to frac the well at 15+ BPM w/6PPA (11.58 ppg), 2) high friction calculated for 3-1/2"tubing at frac conditions, 3) predicted failure of L-80 tubulars during frac screenout case, 4) unavailability of higher strength material for tubulars that are NACE qualified, 5)4- 1/2"tubing is available and would result in lower treating and screen-out pressures that can be handled by L-80 tubulars. Baker Premier Packer(item 16)was removed. In its stead, a Baker ZXP (item 19)liner top packer was added to the lower completion. This was done because, at the lower fracture pressures predicted for 4-1/2"tubing, a Premier packer is no longer necessary to hold down the tubing. Addition of pre-perforated pup and XN nipple in liner. The XN nipple was added to allow for a plug to be set in the liner top to isolate the formation for a tubing swap (future cost savings); this option was not available until the tubing was upsized to 4.5"and the liner top packer was added. The pre-perforated pup was added so a orange peel can be run to reduce possible problems with running the liner. 2/2/2011 Page 2 of 2 Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907)229-4008 ! \�&f) , \\\¥ /) \ CE {k \ 2 [ 82 §\ k\ / kt.� $ \ ) � 3 0pD \ k \/_ co g 3 CD .4=\ �\ Z \ ƒ wm & 0) r /f C { § § %Cl_ I to_ 7 ] * 2 ( \ } \ L .0 \ \ 2 ) { ; \ ) ) 2 _c 3_ § \ £ -0 j ) � ° [ as o / k ? ° ° ! 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PKWis Pp°P�,V Y°Ye Pp;':ip; '� P9PmX g �, Al -3,- ,,, x'.^ m�.x `R x 3Wx.,x. `°_ x 3 1x .,,,,,T,wx� N °K C O O 4 3 ���2 � 4 � �x� �<f � � 4 ��� 3 � < � (II © w w,ax_ 3� gGw li w w� wq� w wq€ TI 494 = � 5 ~ =a 7y =3 ~ l~ =T5l~ =" w g E alma 0 g a o ra ; gl? ; rig _ g;F ?am SS ; ra p m . g zN (�OQS S NS r � S ggQw � qq ~ p $ y 90 " o I (,e a _ a a _ a B a ., a _ a a 1 O 0 l 8 ma AO `�' 00000ogo0 0 08 z ��,� 0 4 o yw A N 4 W g N g : osl r 5 F MIiir ii■ISI■'I o $ 0 a V trn �� Q Q °v31 ?o.-7'g gm$'. �Y3 ,E a O oS� � < Nga � iopg `°� I!O - 7 �.n _ — * m Z VN n F IIn v, Lk3ke_ _xcs _sms tzss x�e1u gSea ng�a gag =n. a o ` o a D110 gppg wnWt Wrw4l!WrYf gwrYf33Yr Wf WrWn n .0 SWrwg �. u:odpn 10 R ....1.; ' ;,,, 3s �4p i0 x3ixxa1i� .114 � ! 1p FIT II 0 wi4i141€1145:1ag4 -114:iliirA a il!Iii3issvitif J•`^s O :.17111 IL_A !, 1 141_ _.,P_t3.- ._„= 3 44 a ia,[p ���xo�a S : p�e��o r xog:oxo a o~ €�nl�- O Sa gad a / ma P Mill S 3 dininkg i; q ni i`) i 4 i f p a 4 C i s o ' 4 g a g il al ii al al al a E 10 a a a ea s sa g Q q I 0 14 14 ; 4 � l ~ 11 14 1 S g RT 210 I R E f g l g nYg.a I .f0 , o0 0g og og og og og o ga sl • PO m m m o og og og og o0 0g gg o ,Ig 1 N Colombie, Jody J (DOA) d 1 0- riot_ From: Regg, James B (DOA) Sent: Tuesday, January 04, 2011 3:17 PM To: Kanady, Randall B Cc: Kirby, Dennis; Roberts, Bowen E; Schwartz, Guy L (DOA) Subject: RE: Alpine Wells CD4-298 and CD2-77 SSV Location As discussed this afternoon, we will defer well specific approvals pending the submittal of the field-wide variance requests that address the location of SSV(incorporated in the horizontal run of a well's tree). You may proceed with well startup of CD4-298 and CD2-77. Jim Regg AOGCC 333 W.7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 From: Kanady, Randall B [mailto:Randall.B.Kanady@conocophillips.com] Sent: Tuesday, January 04, 2011 2:55 PM To: Regg, James B (DOA) Cc: Kirby, Dennis; Roberts, Bowen E Subject: Alpine Wells CD4-298 and CD2-77 SSV Location Jim, Alpine wells CD4-298 and CD2-77 are new wells at Alpine Field that have the Surface Safety Valve in the horizontal run of the wells tree. The new Safety Valve System regulation require the Surface Safety Valve be located in the"vertical run of the well's tree" (20AAC25.265( c)(1)). I am currently preparing a field by field variance for ConocoPhillips Alaska for wells that have the surface safety valve in the horizontal run. These two wells will be included in that variance request. Since these wells will be able to be brought on-line before these variances are approved by the AOGCC, I am requesting approval to bring these wells on production in the interim period before the variance is approved. Please let me know if you have any question. Randall Kanady, P.E. Drilling and Wells ConocoPhillips Alaska Office: 907-263-4126 Cell: 907-830-0742 randall.b.kanadvconocophillips.com 1 SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMmIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD2-77 ConocoPhillips Alaska, Inc. Permit No: 210-179 Surface Location: 2219' FNL, 2083' FEL, SEC. 2, T11N, R4E, UM Bottomhole Location: 825' FNL, 1.23 FEL, SEC. 25, T11N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, • Daniel T. Seamount, Jr. Chair DATED thisi3 day of December, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED DEC 072010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Chi &Gas Cons.Commission PERMIT TO DRILL Anchorage 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil E Service-Winj ❑ Single Zone Q lc.Specify if well is'proposed for: Drill E Re-drill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket u Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' CD2-77 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:23603' TVD: 7267' Colville River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Numb r: ' 2219'FNL,2083'FEL, Sec.2,T11N, R4E, UM ' ADL 380075,380077,3 ' /5- Alpine Oil Pool Top of Productive Horizon: 8.Land Use Permit: /2,y.tc 13.Approximate Spud Date: 5216'FNL,2001'FEL,Sec. 13,T11N, R4E, UM Tobin 932034, 932036, 932087 1/6/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 825'FNL, 1.23'FEL,Sec. 25,T11N, R4E, UM • 2560 1958'from Alpine PA 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 51.9 feet 15.Distance to Nearest Well Open Surface:x- 371150.5 • y- 5974146.9 • Zone- 4 GL Elevation above MSL: 36.3 feet to Same Pool: CD2-58,867' 16.Deviated wells: Kickoff depth: 250 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) .03.to Maximum Hole Angle: 90.1° deg Downhole:3288 psig • Surface:2559 psig • 18.Casing Pro ram: t' Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing eight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5 H-40 Welded 77 37 37 114 114 Pre Installed 13.5" /9,76 45 L-80 BTC 3359 37 37 3396 2400 632 sx AS Lite 3,270 sx 15.8'G' 9.875" 7 4,z5-" 24.7 L-80 BTC-M 17015 37 37 17052 7261 1st-360 sx 15.8'G' 2nd-271 sx 15.8 G 3.5" 9.3 L-80 EUE 16928 32 32 16960 7250 Tubing 6.75" 3.5" 9.3 L-80 IBT-M 16353 16900 7240 23593 7267 Liner w/Ball drop Actuated Sleeves 19 PRESENT WELL CONDITION SUMMARY (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❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑✓ 21.Verbal Approval: Commission Representative: Date: i 7 -2/i e 22. I hereby certify that the foregoing is true and correct. Contact Nina Anderson 265-6403 14 Printed Name Chip Alvord Title Alaska Drilling Manager Signature ,/ /( Phone 265-6120 Date 12..(6, (L0 (0 ((�^ ( ' Commission Use Only Permit to Drill API Number: Permit A ro al See cover letter Number: f C I-7? 50-/(' --2. )(q-(f) Date: \a i3 Ia) IQ , for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed mQthane,gas hydrates,or gas contained in shales: i❑ �` 500 s � Lr✓Ji '.3 � /�� �c•Sf Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No Er Other: 4-Zs-a,,, (51, Ann... Ie-T 4" H2S measures: Yes ❑ No 0 Directional svy req'd: Yes Er No ❑ - b i ue r{t.r Gt)4-1.04.1 et-tr Z o A ' S.v 3 5 Lk)(z.) �� APPROVED BY THE COMMISSION { 3 liga DATE: .� COMMISSION( / `Q Form 10-401 (Revi ed 7!2009) This permit is valid f r •- �n. -f . t a'-.f pproval(20 AAC 25.005J��bj „�Submit,jh Duplicate �y ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 December 2, 2010 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100RECEiVED Anchorage, Alaska 99501 2.01°3EC 0 7 Re: Application for Permit to Drill CD2-77 Coli" Ala¢ a Litt&Gas CON. Dear Sir or Madam: pIIChOfOQe ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD2 drilling pad. The intended spud date for this well is 01/06/2011. It is intended that Doyon Rig 19 be used to drill the well. After setting 7-5/8" intermediate casing, the horizontal section will be drilled in the Alpine C sand. The lower completion will consist of a blank liner and ball actuated sleeves; the upper completion will be tubing and packer. At the end of the rig work program, the well will be flowed back for 2-3 days to -- mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities connection that will allow the well to begin production. It is very likely that due to ice road timing for CD3, operations on CD2-77 could be suspended at a casing point. In the case, a 10-403 package will be sent to the state indicating an operational shutdown. It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. After running 7-5/8" casing, it is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 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. At CD2, there has not been a significant show of shallow gas or gas hydrates through the V 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. 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 is: 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. Riser setup If you have any questions or require further information, please contact Nina Anderson at 265-6403, or Mike Winfree at 265-6820. Sincerely, ' <--(......-7 l(iv irf- , Nina Anders n Drilling Engineer Attachments: cc: CD2-77 Well File / Sharon Allsup Drake ATO 1530 Liz Galiunas ATO 1500 Mike A. Winfree ATO 1704 Tim Schnieder ATO 1768 Lanston Chin Kuukpik Corporation ORIGINAL CD2-77 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots, traveling cylinder diagrams Gas Hydrates Low Monitor well at base of permafrost, increased mud • weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low • Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud weight. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. No over pressured zones. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-3/4" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7-5/8" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density(ECD) monitoring, 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. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers ORIGINAL Procedure 1. Move on Doyon 19. kdr 9, 2. Rig up riser, dewater cellar as needed. 3. Drill 13-1/2" hole to the surface casing point as per the directional plan. (Directional/MWD/GR/Res). 4. Run and cement 10-3/4" surface casing. 5. Install and test BOPE to 3500 psi. 6. Pressure test casing to 2500 psi.' 7. Pick up and run in hole with 9-7/8" drilling BHA. 8. Drill out 20' of new hole. Perform leak off test. oT 9. Drill 9-7/8" hole to intermediate casing point in the Alpine A. (LWD Program: GR/RES/PWD/Dens/Sonic) 10. Run and cement 7-5/8" casing as per program. Pressure test casing to 3500 psi. Carry out a leak off test down the 10-3/4"x7-5/8" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. BOPE test to 3500 psi. 12. Drill out 7-5/8" shoe track. Drill 20' of new hole. Perform formation integrity test. f�T 13. Drill 6-3/4" horizontal section to well TD (LWD Program: GR/RES/PWD; ADR for directional). 14. Circulate the hole clean and pull out of hole. 15. Run lower completion with 3-1/2" blank liner with ball actuated sleeves and liner hanger. 16. Run 3-'/2, 9.3#, L-80 tubing with SCSSSV, gas lift mandrels, packer, XN nipple and stinger assembly. 17. Drop ball and rod, set packer. Displace fluids. 18. Sting in, space out and land hanger. 19. Install 2 way check and pressure test hanger seals to 5000 psi. Pull TWC. 20. Test tbg to 3500 psi for 30 minutes. Bleed down tbg to 2000 psi and pressure test annulus to 3500 psi for 30 minutes. Bleed tbg to 0 psi to sheer casing to tbg DCK-2 SOV. Bleed tubing and annulus pressure to zero. 21. Install TWC and pressure test through SOV to 1000 i in the direction of flow. Nipple down BOP. k(` 22. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 23. Circulate tubing to diesel and install freeze protection in the annulus. 24. Set BPV and secure well. Move rig off. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-75 is the closest existing well. Ellipse to ellipse separation is 7.22' @ 745' MD. Drilling Area Risks: There are no high-risk events anticipated. (e.g. over-pressures zones) Unstable Shales: Intermediate hole sections in this area have shown shale instability at lower mud weights. Plan to use mud weight sufficient to stabilize shales based on offset data. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. 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 CD2-77 will be injected into a permitted annulus on CD2, or the class 1 disposal well on CD1 pad. The CD2-77 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Qannik reservoir and there will be 500' of cement fill above the top of the Qannik as per regulations. Upon completion of CD2-77 form 10-403, Application for Sundry Operations, will 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) *(Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) *(0.052) *(2400') + 1,500 psi = 2997 psi Pore Pressure = 1086 psi Therefore Differential = 2997— 1086 = 1911 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 10-3/4" 45.5 L-80 3 BTC-M 2480 2108 psi 3580 psi 3043 psi 7-5/8" 29.7 L-80 3 BTC-M 4790 psi 4071 psi 6890 psi 5856 psi ORIGINAL DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7- Production Hole 10-3/4°surface casing 5/8— casing point—9-7/8" Section—6 3/4" point— 13-1/2" Density 8.8—9.6 ppg 9.6— 10.0 ppg 9.0—9.4 PV 10—25 15—22 YP 20—60 15—25 25—30 Funnel Viscosity 100—200 Initial Gels 4—8 9— 12 10 minute gels <18 10 - 14 API Filtrate NC— 10 cc/30 min 4— 12 cc/30 min (drilling) HPHT Fluid Loss at 160 <5 cc/30 min PH 8.5-9.0 9.0- 10.0 OWR 80/20 Surface Hole: A standard high viscosity fresh water/ gel spud mud is recommended for the surface interval. Keep flow line viscosity at±200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight< 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight at or below 9.8 ppg and plan to weight up mud system for lower shale stability. Be prepared to add loss circulation material. Good filter cake quality, hole • cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section : The drill-in fluid for Alpine producer wells will be an 80/20 oil/water ratio VERSAPRO mineral oil based drill- in fluid designed to minimize filter cake lift off pressure. The base fluid will be high flashpoint(>200° F), low aromatics, LVT-200 mineral oil. The internal phase will consist of 33% by weight CaCl2 brine with • emulsifiers and wetting agents. SAFE-CARB 2 and S-200 calcium carbonate will be used as a bridging agent for proper filter cake building and fluid loss control. ORIGINAL Completion Schematic Colville River Field CD2-77 Production Well Completion Updated 12/1/2010 16"Conductor to 114' Sperry Drilling Services • `N Packer Fluid mix: CD2 77wpO5 Inhibited Kill weight Pape 1 of 2 6%KCI Brine with 2000'TVD diesel cap Upper Completion MD TVD 0 1)Tubing Hanger 36' 36' • 10 3/:'45.5 ppf L-80 BTC Mod 2)4-''/z"12.6#/ft IBT-Mod Tubing(2 jts),XO Surface Casing 3)3-%"9.3#/ft EUE-Mod Tubing @ 3396'MD/2400'TVD 4)Camco TRMAXX-5E SSSV(2.812"ID) 2200' 1915' with control to surface TOC @+/- 6 GL J cemented to surface 3-W 9.3#/ftIne EUE-Mod Tubing 7502'MD! 6)3-W x 1"Camco KBMG GLM w/DV 6149' 3400' 3839'TVD 7)3-'/z"9.3#/ft EUE-Mod Tubing Qannik Interval 8)3-W x 1"Camco KBMG GLM w/DV 12252' 5600' Top+/- 8002'MD!4072'TVD 9)3-%"9.3#/ft EUE-Mod Tubing 10)Camco KBMG GLM(2.867"ID)w/DCK2 16,320' 7062' Pinned for 2500 psi casing to tbg shear i.C) 0 0 11)3-'/z'Tubing Joints EUE-Mod (1 joints) ES Cementer 12)HES 2.813"X Profile +/-8557'MD/ 13)3-W Tubing Joints EUE-Mod (1 joints) 4271'TVD 14)Camco 3-W Gauge Mandrel L-80 with 16,400' 7039 Sapphire digital Pressure and Temperature gauge Connected to surface withV4"x 0.035" Encapsulated I-Wire 15)3-'/z"Tubing Joints EUE-Mod (1 joint) 16)Baker Premier Packer 16450' 7109' 8 GL J 17)3-W tubing 1 joint 18)HES XN 2.813"(2.75"NoGo)-with RHC Plug 16500' 7127' 19)3-1/2"Tubing Joints EUE-Mod • 3-1/2" 9.3 ppf L-80 EUE M 20)BOT Stinger w/Fluted WLEG stinger 16960' 7250' • • tubing run with Jet Lube Run'n'Seal • • pipe dope • TOC Calculated 0 @+/-15763'MD/ 6855'TVD (300'above Packer • &500'MD above Kuparuk) _ MI II • . 11111zo :C Top Kuparuk C 16263'MD/7041'TVD €. -� -_-_� ■ ■ ■______■ Top Alpine C 6-3/4" Hole TD at 16,939'MD/7246'TVD 7-5/8"29.7 ppf L-80 BTC Mod Production Casing @ 17,052'MD/7262'TVD at 23,603'MD/ 7,267'TVD ORIGINAL Completion Schematic-Page 2 Colville River Field CD2-77 Production Well Completion Updated 12/1/2010 Sperry Drilling Services . ,16 "Conductor to 114' CD2-77wp05 Packer Fluid mix: Page 2 of 2 • Inhibited Kill weight Lower Completion MR DLQ 6%KCI Brine i with 2000'TVD 21)Baker 5'A"X 7-5/8"Flex Lock Hanger w/Sealbore Extension 16900" 7240' MV. 22)X0 5-1/"Hydril 521 X 3-1/2"SLHT .++.w diesel cap 23)3-1/2",9.3#/ft,SLHT Tubing 24)3-1/2"x 6-1/2"Centralizers SLHT Box x Box 25)Swell Packer(3-%"SLHT)OD 6.38"w/10'sealing element TBD TBD . ,],,,i------,,0-3A 45.5 ppf L-80 BTC-Mod 26)3-% x 6-1/2"Centralizers SLHT Box x Pin Surface Casing 27)3-1/2",9.3 ti/Ft,SLHT Tubing @ 3396'MD/2400'TVD 28)3-%"SLHT Ball Actuated Sleeve(2.000"Seat ID)(2.125"Ball) TBD TBD cemented to surface 29)3-1/2",9.2#/ft,SLHT Tubing TOC @+/- GL J 30)3-1/2"x 6-W Centralizers SLHT Box x Box 7502'MD/ 31)Swell Packer(3-1/2"SLHT)OD 6.38"w/10'sealing element TBD TBD 3839'TVD 32)3-W x 6-W Centralizers SLHT Box x Pin 33)3-W,9.3#/ft,SLHT Tubing Qannik Interval 34)3-1/2"SLHT Batt Actuated Sleeve(1.875"Seat ID)(2.000"Ball) TBD TBD Top+/- 8002'MD/4072'TVD 35)3-1/2",9.3#/ft,SLHT Tubing 36)3-1/2"x 6-1/"Centralizers SLHT Box x Box r ,,` 37)Swell Packer(3-1/2"SLHT)OD 6.38"w/10'sealing element TBD TBD O ! 38)3-1/2"x 6-1/2"Centralizers SLHT Box x Pin } r ES Cementer 39)3-1/2",9.3#/ft,SLHT Tubing +/-8557'MD/ 40)3-1/2"SLHT Ball Actuated Sleeve(1.750"Seat ID)(1.875"Ball) TBD TBD • 4271'TVD 41)3-1/2",9.3#/ft,SLHT Tubing • 42)3-W x 6-1/:"Centralizers SLHT Box x Box 43)Swell Packer(3-1/2"SLHT)OD 6.38"w/10'sealing element TBD TBD • 44)3-1/2"x 6-14"Centralizers SLHT Box x Pin • • 45)3-1/2",9.3#/tt,SLHT Tubing • • • • 46)3-1/:"SLHT Ball Actuated Sleeve(1.625"Seat ID)(1.750"Bat) TBD TBD 47)3-1/2",9.3 ft/ft,SLHT Tubing 48)3-14"x 6-1/2"Centralizers SLHT Box x Box • 49)Swell Packer(3-14"SLHT)OD 6.38"w/10'sealing element TBD TBD GL .J 50)3-14"x 6-W Centralizers SLHT Box x Pin • 51)3-',",9.3#/ft,SLHT Tubing 3 1/2" 9.3 ppf L-80 EUE M 52)3-14"SLHT Ball Actuated Sleeve(1.500"Seat ID)(1.625"Ball) TBD TBD 53)3-1/:",9.3#/ft,SLHT Tubing tubing run with Jet Lube Run'n'Seal 54)3-W x 6-14"Centralizers SLHT Box x Box • pipe dope 55)Swell Packer(3-14"SLHT)OD 6.38"w/10'sealing element TBD TBD • 56)3-14"x 6-16"Centralizers SLHT Box x Pin • 57)3-114",9.3#/ft,SLHT Tubing • 58)3-14"SLHT Ball Actuated Sleeve(1.375"Seat ID)(1.500"Ball) TBD TBD' 59)3-1/2",9.3#/ft,SLHT Tubing 60)3-1/2"x 6-14"Centralizers SLHT Box x Box • • 61)Swell Packer(3-114"SLHT)OD 6.38"w/10'sealing element TBD TBD 62)3-1/2"x 6-1/2"Centralizers SLHT Box x Pin 63)3-1/2",9.3#18,SLHT Tubing 64)3-14"SLHT Ball Actuated Sleeve(1.250"Seat ID)(1.375"Ball) TBD TBD % 65)3-1/2",9.3#/ft,SLHT Tubing • 66)3-'A"x 6-14"Centralizers SLHT Box x Box TOC Calculated 67)Swell Packer(3-114"SLHT)OD 6.38"w/10'sealing element TBD TBD @+/-15763'MD 68)3-14"x 6-1/:"Centralizers SLHT Box x Pin 6855'TVD -::: 69)3-1/2",9.3#/ft,SLHT Tubing (300'above Packer 70)3-1/2"SLHT Mule Shoe 23593' 7267" &500'MD above Kuparuk) 'ilti.:••••• :-.7.--.---.7-411 _ 1 zfi ® 31 011101111 37 40 0000000400 3 49 62 55 61 67 ` 21 .4:0 46 =�■ 58 111114 70 'I\ al 1 .1.) iV iV iV V Top Kuparuk C 16263'MD/7041'TVD ■ , ,, , El Il II 11111 Top Alpine C 6'/4" Hole 16,939'MD/7246'TVDTD at 7-5/8"29.7 ppf L-80 BTC Mod Production Casing @ 17,052'MD/7262'ND at 23,603' MD/7267' TVD ORIGINAL PRESSURE INFORMATION (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: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (lbs. /gal) (psi) (psi) 16 114/ 114 10.9 52 53 10-3/4" 3396/2400 14.5 1086 1570 7-5/8" 17052/7262 16.0 3286 2562 N/A 23603/7267 16.0 3288 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 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 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) = 1086—(0.1 x 2400') = 846 psi 2. Drilling below surface casing (10-3/4") ASP= [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1]x 2400 = 1569 psi OR ASP= FPP—(0.1 x D) = 3321 —(0.1 x 7262) = 2559 psi 3. Drilling below intermediate casing (7-5/8") ASP= FPP—(0.1 x D) = 3288—(0.1 x 7267') =2561 psi ORIGINAL Cementing Program: 10-3/4" Surface Casing run to 3396' MD/2400' TVD. Cement from 3396' MD to 2896' (500' of fill)with Class G +Adds @ 15.8 PPG, and from 2896'to surface with Arctic Set Lite 3.Assume 250% excess annular volume in permafrost and 50% excess below the permafrost(1700' MD). Lead slurry: (2896-1700')X 0.3637 ft3/ft X 1.5 (50% excess) = 652 ft3 below permafrost 1700' X 0.3637 ft3/ft X 3.5 (250% excess) = 2164 ft3 above permafrost Total volume=652 +2164 =2816 ft3=> 632 Sx @ 4.45 ft3/sk System: 632 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G Tail slurry: 500' X 0.3637 ft3/ft X 1.5 (50% excess) = 272.8 ft3 annular volume 80'X 0.5397 ft3/ft=43.1 ft3 shoe joint volume Total volume= 272.8 +43.1 = 315.9 ft3=>270 Sx @ 1.17 ft3/sk System: 270 Sx Class G + 0.2% D046 antifoamer, + 1%52, 0.2%D46, 0.3%D65 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7-5/8" Intermediate Casing run to 17052 MD/7262' TVD First Stage: Cement from 17052' MD to 15763' MD (500' of Class G+ adds @ 15.8 PPG and minimum 300' MD above the packer).Assume 40%excess annular volume. Lead: (17052' - 15763)X 0.2146 ft3/ft X 1.4 (40% excess) = 387 ft3 annular vol. 120' X 0.2577 ft /ft= 30.9 ft3 shoe joint volume Total volume = 387 + 30.9 =418 ft3=> 360 Sx @ 1.16 ft3/sk System: 360 Sx Class G + Class G + 1%52, 0.2%D46, 0.3%D65 @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a Stage tool set 500' below the K2 interval to+/-500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (8557'-7502')X 0.2146 ft3/ft X 1.4 (40% excess) = 317 ft3 annular vol. Total Volume = 317 ft3=> 271 Sk @ 1.17 ft3/sk ,� PpNLL System: 271 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk �� _ , 6313811/t- w 1�a(' ConocoPhillips(Alaska) Inc. Western North Slope CD2 Alpine Pad Plan: CD2-77 Plan: CD2-77 Plan: CD2-77wp05 REVISED E 51:09 pm, Dec 01, 2010 Standard Proposal Report Permit Pacic 111 NAD 27 02 December, 2010 Changed production hole liner size to 3-1/2". 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CL " I I I ( I I I IsiI I i' l 11 I I I 0 %A CU ?PA . i § U I 1 tt a5M ow 000s)indea polpaA ORIGINAL III • c. c) - ) N- ,- a) (0 .0 •IN= > = 71- , x co = ti 13 hr C\I C) c=) Om X co 1 0 N- = 1 co 0 0 S '.: CV 0 , 00 c4 0 -, co — 0 0 cp <-• A 0, 00, 00 —,o e -A ..r) o x 00 c..'eg e o ix) 9, -6-.? 00 -EA <- 0 0 <- --- o 9 N- -) 0 -e (NI 0 - .e• u, 0 0 0 0 Cr) cr3 0 0 0 (5) 0 0 0 0 cP LLI 0 0 0 ,—, CP 0 -rt -.-, Cl) cP co a) ,-,c`l c,41 -O lan CD o o a -in ce) I . o I o -o NI r-7- C.) c. c. _in c. 7 I I I I I I co co co co co co co o co co co Li) co in co in cr) N- o 71- r--- . . ..-- ,-- •,-- (UVII 009 ) (+)LOON/(-)LIMOS I . rv, 1 L ORIG1N/A ------- 0 7r- co CD2-77wp05 - 13 604 v 3604 IP 3000 & c) -c) ao° c) 92000 ''') c\r a) •_ ,1-000 > c) Q -IL) C '0000 r-- , O . r.gboo .. 4-11 (..) 06 16000 c) c) - CD ooOL i. - ao c) LU CO 00091 -1r-,, -- X -c- Opo,i Eo S* CV c) 4- c) cp 000 r-L -L.0 ..-- C\I 0006,, 0 CD 00429 c) (1) c) ' c) Opoil .- c o o 000n,'it 0 cn , (7) rt 0006 _(7) 0 Ln *-E > 0009 1.0 0 000z , cp Ca. 0 0009 , -cp Lo Nu 0009, NE _c) Ln c\J I:3 000 ,, ,. - , _ - —--__ x cp„,80, =,, .,,) . c) -c) { I 1 I 1 1 C c) c), (7) (7), c, (7) (7) o o c) L.r) is-) (7) in o Lc) I-- c) ,- (uvu. 009Z) Liidea leopeA am_ ORIG1NA , Conoco Phillips HALLIBURTON Standard Proposal Report lsr,l'IL L - ,,,, ,„, ,'ONIIIIIIIIIMEMIIIIPM1=8311011PU :fl'11101011,1,11,::!1'3're, ''.: ±= ='0,10010111000100111V 0 Database: 1 IIIII EDM v16 Prod '," ". - :1' .=cord-:- -KereFpnce:„„v Well Plan.CD2-77 11,, , Company: ',:_±.,ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Project: - Western North Slope MD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Site: CD2 Alpine Pad North Reference: True Well: Plan:CD2-77 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD2-77 Design: CD2-77wp05 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 CD2 Alpine Pad Site Position: Northing: 758.08ft Latitude: 53°45 41.250 N From: Map Easting: -1,140,581.34ft Longitude: 157°35'22.095 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: -6.11° Well Plan:CD2-77 Well Position +NI-S 0.00 ft Northing: 5,974,146.93ft Latitude: 70°20'15.268 N , +E/-W 0.00 ft Easting: 371,150.53 ft Longitude: 151°2'43.773 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 15.60ft Wellbore Plan:CD2-77 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) ( ) (nT) BGGM2009 12/1/2010 16.36 79.66 57,355 Design CD2-77wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 , 1 1 1 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction , , (ft) (ft) (ft) C) 36.30 0.00 0.00 160.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) ("/100ft) ("1100ft) ("/100ft) C) 36.30 0.00 0.00 36.30 -15.60 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 198.10 0.00 0.00 0.00 0.00 0.00 0.00 400.04 2.25 185.00 400.00 348.10 -2.94 -0.26 1.50 1.50 0.00 185.00 905.51 13.37 185.00 900.00 848.10 -71.26 -6.23 2.20 2.20 0.00 0.00 2,538.81 68.70 163.72 2,088.50 2,036.60 -1,071.73 208.17 3.45 3.39 -1.30 -23.97 7,549.69 68.70 163.72 3,908.52 3,856.62 -5,553.19 1,516.98 0.00 0.00 0.00 0.00 8,002.31 69.07 154.02 4,071.90 4,020.00 -5,946.43 1,669.00 2.00 0.08 -2.14 -89.43 8,009.73 68.93 154.07 4,074.56 4,022.66 -5,952.66 1,672.03 2.00 -1.90 0.66 161.96 16,547.59 68.93 154.07 7,144.14 7,092.24 _13,117.68 5,155.60 0.00 0.00 0.00 0.00 , 17,052.15 84.00 152.62 7,261.90 7,210.00 _13,554.73 5,375.20 3.00 2.99 -0.29 -5.55 17,338.89 90.00 152.62 7,276.90 7,225.00 -13,808.88 5,506.84 2.09 2.09 0.00 0.02 17,493.78 90.09 155.72 7,276.78 7,224.88 -13,948.28 5,574.32 2.00 0.06 2.00 88.40 20,736.69 90.09 155.72 7,271.90 7,220.00 -16,904.25 6,907.96 0.00 0.00 0.00 0.00 21,604.94 90.10 173.08 7,270.46 7,218.56 -17,737.32 7,140.57 2.00 0.00 2.00 89.93 23,603.99 90.10 173.08 7,266.90 7,215.00 -19,721.81 7,381.37 0.00 0.00 0.00 0.00 , 12/2/2010 11:06:58AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTIONStandard Proposal Report 1111111V1111111111111111111111111111111111V111111111111INIMIIMPINIIIIIVIIIIIIIIIIIIIIIMPUIREMZOLIERMIDICIPM lIMPIIIDIIPTIrnT - ,11:11111111MMINN VirlIIIIIVIIMMINCIIN ...,,,,,MEMBOPEMSEMOMMIIIVIIVM11221122=M1110===1,,"" Database: EDM v16 Prod 'Local Co-ordinate Reference' "' Well Plan:CD2-77 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Site: CD2 Alpine Pad North Reference: True Well: Plan:CD2-77 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD2-77 Design: CD2-77wp05 ... Planned Survey 7:°70100 0 00r0000010000D Wr PC1,1":51:71 I 'I I A '1g3F,,11110101110 MON"717Z751411 11 ' ''' 1111111, ,1111*,,1,,,11,1r,stoo 11 1 , il ,,,1,11,,11,111, Measured Vertical Lm 11,11,1j1 '!1:4114 ,lb ' 1 ap, , Depth Inclination Azimuth Depth TVDss +N/-5 +EI-W 'I, NO n l'"' ' " St.ihg, DLS Vert Section , , , „ (ft) (*) (°) (ft) ft (ft) (ft) (ft) M(ft)"-q;::=" -15.60 I 36.30 0.00 0.00 36.30 -15.60 0.00 0.00 5,974,146.93 371,150.53 0.00 0.00 1 100.00 0.00 0.00 100.00 48.10 0.00 0.00 5,974,146.93 371,150.53 0.00 0.00 200.00 0.00 0.00 200.00 148.10 0.00 0.00 5,974,146.93 371,150.53 0.00 0.00 1 250.00 0.00 0.00 250.00 198.10 0.00 0.00 5,974,146.93 371,150.53 0.00 0.00 Start Build 1.50 300.00 0.75 185.00 300.00 248.10 -0.33 -0.03 5,974,146.61 371,150.50 1.50 0.30 400.00 2.25 185.00 399.96 348.06 -2.93 -0.26 5,974,144.00 371,150.22 1.50 2.67 400.04 2.25 185.00 400.00 348.10 -2.94 -0.26 5,974,144.00 371,150.22 1.50 2.67 Start DLS 2.20 TFO 0.00 500.00 4.45 185.00 499.78 447.88 -8.75 -0.77 5,974,138.19 371,149.61 2.20 7.96 600.00 6.65 185.00 599.31 547.41 -18.39 -1.61 5,974,128.58 371,148.61 2.20 16.73 1 700.00 8.85 185.00 698.39 646.49 -31.82 -2.78 5,974,115.17 371,147.20 2.20 28.95 800.00 11.05 185.00 796.88 744.98 -49.03 -4.29 5,974,097.98 371,145.40 2.20 44.61 900.00 13.25 185.00 894.63 842.73 -70.00 -6.12 5,974,077.06 371,143.21 2.20 63.68 905.51 13.37 185.00 900.00 848.10 -71.26 -6.23 5,974,075.79 371,143.07 2.20 64.83 Start DLS 3.45 TFO-23.97 1,000.00 16.40 180.31 991.31 939.41 -95.49 -7.26 5,974,051.59 371,141.63 3.45 87.25 1,100.00 19.69 176.90 1,086.38 1,034.48 -126.44 -6.42 5,974,020.63 371,141.94 3.45 116.62 1,200.00 23.02 174.44 1,179.50 1,127.60 -162.73 -3.62 5,973,984.30 371,144.12 3.45 151.68 , 1,300.00 26.38 172.58 1,270.34 1,218.44 -204.24 1.15 5,973,942.72 371,148.17 3.45 192.31 1,400.00 29.76 171.11 1,358.56 1,306.66 -250.81 7.85 5,973,896.05 371,154.07 3.45 238.37 1,500.00 33.16 169.92 1,443.85 1,391.95 -302.27 16.48 5,973,844.45 371,161.81 3.45 289.68 1,600.00 36.56 168.92 1,525.90 1,474.00 -358.44 27.00 5,973,788.11 371,171.36 3.45 346.05 1,632.61 37.67 168.63 1,551.90 1,500.00 -377.73 30.82 5,973,768.75 371,174.86 3.45 365.50 , Base Permafrost 1,700.00 39.97 168.08 1,604.40 1,552.50 -419.11 39.36 5,973,727.24 371,182.68 3.45 407.29 1,800.00 43.38 167.34 1,679.09 1,627.19 -484.06 53.53 5,973,662.06 371,195.73 3.45 473.18 1,900.00 46.80 166.69 1,749.67 1,697.77 -553.06 69.45 5,973,592.80 371,210.46 3.45 543.46 2,000.00 50.23 166.12 1,815.90 1,764.00 -625.87 87.06 5,973,519.71 371,226.82 3.45 617.90 2,100.00 53.65 165.59 1,877.54 1,825.64 -702.20 106.31 5,973,443.07 371,244.75 3.45 696.21 2,200.00 57.08 165.11 1,934.37 1,882.47 -781.79 127.12 5,973,363.13 371,264.18 3.45 778.12 , 2,300.00 60.51 164.67 1,986.17 1,934.27 -864.35 149.41 5,973,280.21 371,285.06 3.45 863.33 2,400.00 63.94 164.26 2,032.77 1,980.87 -949.58 173.11 5,973,194.59 371,307.29 3.45 951.52 2,500.00 67.37 163.87 2,073.99 2,022.09 -1,037.17 198.13 5,973,106.59 371,330.79 3.45 1,042.39 2,538.81 68.70 163.72 2,088.50 2,036.60 -1,071.73 208.17 5,973,071.87 371,340.24 3.45 1,078.30 2,538.82 68.70 163.72 2,088.51 2,036.61 -1,071.74 208.18 5,973,071.85 371,340.25 0.00 1,078.31 Start 5011.12 hold at 2538.82 MD 2,600.00 68.70 163.72 2,110.73 2,058.83 -1,126.46 224.16 5,973,016.88 371,355.28 0.00 1,135.19 ' 2,700.00 68.70 163.72 2,147.05 2,095.15 -1,215.89 250.28 5,972,927.02 371,379.86 0.00 1,228.17 2,800.00 68.70 163.72 2,183.37 2,131.47 -1,305.33 276.40 5,972,837.15 371,404.44 0.00 1,321.14 , 2,900.00 68.70 163.72 2,219.69 2,167.79 -1,394.76 302.52 5,972,747.29 371,429.01 0.00 1,414.12 3,000.00 68.70 163.72 2,256.01 2,204.11 -1,484.20 328.64 5,972,657.43 371,453.59 0.00 1,507.09 3,100.00 68.70 163.72 2,292.33 2,240.43 -1,573.63 354.75 5,972,567.56 371,478.17 0.00 1,600.06 3,200.00 68.70 163.72 2,328.65 2,276.75 -1,663.07 380.87 5,972,477.70 371,502.74 0.00 1,693.04 3,300.00 68.70 163.72 2,364.98 2,313.08 -1,752.50 406.99 5,972,387.84 371,527.32 0.00 1,786.01 12/2/2010 11:06:58AM Page 3 COMPASS 2003.16 Build 69 npir:_, Itski AI ConocoPhillips HALLIBLIRTON Standard Proposal Report - Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD2-77 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+15.6 @ 51.9011(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+15.6 @ 51.9011(Doyon 19) Site: CO2 Alpine Pad North Reference: True Well: Plan:CD2-77 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD2-77 Design: CD2-77wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting OLS Vert Section (ft) (°) (*) (ft) ft (ft) (ft) (ft) , (ft) 2,348.10 3,396.43 68.70 163.72 2,400.00 2,348.10 -1,838.74 432.18 5,972,301.18 371,551.02 0.00 1,875.67 10-3/4"x 13-1/2" 3,400.00 68.70 163.72 2,401.30 2,349.40 -1,841.94 433.11 5,972,297.97 371,551.90 0.00 1,878.99 3,429.19 68.70 163.72 2,411.90 2,360.00 -1,868.04 440.74 5,972,271.74 371,559.07 0.00 1,906.13 C-30 3,500.00 68.70 163.72 2,437.62 2,385.72 -1,931.37 459.23 5,972,208.11 371,576.47 0.00 1,971.96 3,600.00 68.70 163.72 2,473.94 2,422.04 -2,020.81 485.35 5,972,118.25 371,601.05 0.00 2,064.94 3,700.00 68.70 163.72 2,510.26 2,458.36 -2,110.24 511.47 5,972,028.39 371,625.63 0.00 2,157.91 3,800.00 68.70 163.72 2,546.58 2,494.68 -2,199.67 537.59 5,971,938.52 371,650.20 0.00 2,250.88 3,900.00 68.70 163.72 2,582.90 2,531.00 -2,289.11 563.71 5,971,848.66 371,674.78 0.00 2,343.86 4,000.00 68.70 163.72 2,619.22 2,567.32 -2,378.54 589.83 5,971,758.80 371,699.36 0.00 2,436.83 4,100.00 68.70 163.72 2,655.55 2,603.65 -2,467.98 615.95 5,971,668.93 371,723.93 0.00 2,529.81 4,200.00 68.70 163.72 2,691.87 2,639.97 -2,557.41 642.07 5,971,579.07 371,748.51 0.00 2,622.78 4,300.00 68.70 163.72 2,728.19 2,676.29 -2,646.85 668.19 5,971,489.21 371,773.09 0.00 2,715.76 4,400.00 68.70 163.72 2,764.51 2,712.61 -2,736.28 694.31 5,971,399.35 371,797.66 0.00 2,808.73 4,447.88 68.70 163.72 2,781.90 2,730.00 -2,779.10 706.81 5,971,356.32 371,809.43 0.00 2,853.25 C-20 ' 4,500.00 68.70 163.72 2,800.83 2,748.93 -2,825.72 720.42 5,971,309.48 371,822.24 0.00 2,901.70 4,600.00 68.70 163.72 2,837.15 2,785.25 -2,915.15 746.54 5,971,219.62 371,846.82 0.00 2,994.68 4,700.00 68.70 163.72 2,873.47 2,821.57 -3,004.59 772.66 5,971,129.76 371,871.39 0.00 3,087.65 4,800.00 68.70 163.72 2,909.80 2,857.90 -3,094.02 798.78 5,971,039.89 371,895.97 0.00 3,180.63 1 4,900.00 68.70 163.72 2,946.12 2,894.22 -3,183.45 824.90 5,970,950.03 371,920.55 0.00 3,273.60 5,000.00 68.70 163.72 2,982.44 2,930.54 -3,272.89 851.02 5,970,860.17 371,945.12 0.00 3,366.58 5,100.00 68.70 163.72 3,018.76 2,966.86 -3,362.32 877.14 5,970,770.31 371,969.70 0.00 3,459.55 5,200.00 68.70 163.72 3,055.08 3,003.18 -3,451.76 903.26 5,970,680.44 371,994.28 0.00 3,552.53 5,300.00 68.70 163.72 3,091.40 3,039.50 -3,541.19 929.38 5,970,590.58 372,018.85 0.00 3,645.50 5,400.00 68.70 163.72 3,127.72 3,075.82 -3,630.63 955.50 5,970,500.72 372,043.43 0.00 3,738.47 5,500.00 68.70 163.72 3,164.04 3,112.14 -3,720.06 981.62 5,970,410.85 372,068.01 0.00 3,831.45 5,600.00 68.70 163.72 3,200.37 3,148.47 -3,809.50 1,007.74 5,970,320.99 372,092.58 0.00 3,924.42 5,700.00 68.70 163.72 3,236.69 3,184.79 -3,898.93 1,033.86 5,970,231.13 372,117.16 0.00 4,017.40 5,800.00 68.70 163.72 3,273.01 3,221.11 -3,988.37 1,059.98 5,970,141.27 372,141.74 0.00 4,110.37 1 5,900.00 68.70 163.72 3,309.33 3,257.43 -4,077.80 1,086.10 5,970,051.40 372,166.31 0.00 4,203.35 6,000.00 68.70 163.72 3,345.65 3,293.75 -4,167.24 1,112.21 5,969,961.54 372,190.89 0.00 4,296.32 6,100.00 68.70 163.72 3,381.97 3,330.07 -4,256.67 1,138.33 5,969,871.68 372,215.47 0.00 4,389.29 6,200.00 68.70 163.72 3,418.29 3,366.39 -4,346.10 1,164.45 5,969,781.81 372,240.04 0.00 4,482.27 6,300.00 68.70 163.72 3,454.61 3,402.71 -4,435.54 1,190.57 5,969,691.95 372,264.62 0.00 4,575.24 , 6,400.00 68.70 163.72 3,490.94 3,439.04 -4,524.97 1,216.69 5,969,602.09 372,289.20 0.00 4,668.22 ' 6,500.00 68.70 163.72 3,527.26 3,475.36 -4,614.41 1,242.81 5,969,512.22 372,313.77 0.00 4,761.19 ' 6,600.00 68.70 163.72 3,563.58 3,511.68 -4,703.84 1,268.93 5,969,422.36 372,338.35 0.00 4,854.17 6,700.00 68.70 163.72 3,599.90 3,548.00 -4,793.28 1,295.05 5,969,332.50 372,362.93 0.00 4,947.14 6,800.00 68.70 163.72 3,636.22 3,584.32 -4,882.71 1,321.17 5,969,242.64 372,387.50 0.00 5,040.11 6,900.00 68.70 163.72 3,672.54 3,620.64 -4,972.15 1,347.29 5,969,152.77 372,412.08 0.00 5,133.09 7,000.00 68.70 163.72 3,708.86 3,656.96 -5,061.58 1,373.41 5,969,062.91 372,436.66 0.00 5,226.06 7,100.00 68.70 163.72 3,745.18 3,693.28 -5,151.02 1,399.53 5,968,973.05 372,461.23 0.00 5,319.04 7,200.00 68.70 163.72 3,781.51 3,729.61 -5,240.45 1,425.65 5,968,883.18 372,485.81 0.00 5,412.01 12/2/2010 1106:58AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALL!BURTON Standard Proposal Report Database: EDM v16 Prod . Local Co-ordinate Reference: Well Plan:CD2-77 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+15.6 @ 51.90f1(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Site: CD2 Alpine Pad North Reference: True Well: Plan.CD2-77 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD2-77 Design: CD2-77wp05 Planned Survey I ' Measured Vertical Map Map , Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (*) (1 (ft) ft (ft) (ft) (ft) (ft) 3,765.93 7,300.00 68.70 163.72 3,817.83 3,765.93 -5,329.88 1,451.77 5,968,793.32 372,510.39 0.00 5,504.99 7,366.28 68.70 163.72 3,841.90 3,790.00 -5,389.16 1,469.08 5,968,733.76 372,526.68 0.00 5,566.61 K-3 Marker 7,400.00 68.70 163.72 3,854.15 3,802.25 -5,419.32 1,477.88 5,968,703.46 372,534.97 0.00 5,597.96 7,500.00 68.70 163.72 3,890.47 3,838.57 -5,508.75 1,504.00 5,968,613.60 372,559.54 0.00 5,690.94 7,549.69 68.70 163.72 3,908.52 3,856.62 -5,553.19 1,516.98 5,968,568.95 372,571.75 0.00 5,737.13 7,549.94 68.70 163.71 3,908.61 3,856.71 -5,553.42 1,517.05 5,968,568.72 372,571.82 2.00 5,737.37 Start DLS 2.00 TFO-89.43 7,600.00 68.72 162.64 3,926.79 3,874.89 -5,598.06 1,530.55 5,968,523.85 372,584.54 2.00 5,783.94 7,700.00 68.76 160.49 3,963.05 3,911.15 -5,686.47 1,560.01 5,968,434.96 372,612.48 2.00 5,877.09 7,800.00 68.84 158.35 3,999.22 3,947.32 -5,773.75 1,592.78 5,968,347.14 372,643.74 2.00 5,970.31 7,900.00 68.94 156.21 4,035.24 3,983.34 -5,859.79 1,628.81 5,968,260.50 372,678.29 2.00 6,063.49 7,929.69 68.97 155.57 4,045.90 3,994.00 L5,885.08 1,640.13 5,968,235.02 372,689.17 2.00 6,091.12 Basal K-3 8,000.00 69.07 154.07 4,071.08 4,019.18 -5,944.49 1,668.05 5,968,175.14 372,716.07 2.00 6,156.50 8,002.26 69.07 154.02 4,071.88 4,019.98 -5,946.39 1,668.98 5,968,173.22 372,716.96 2.00 6,158.61 Start DLS 2.00 TFO 164.07 8,002.31 69.07 154.02 4,071.90 4,020.00 -5,946.43 1,669.00 5,968,173.18 372,716.98 2.00 6,158.65 CD2-77 30Aug10 Qannik 8,007.89 68.96 154.06 4,073.90 4,022.00 -5,951.12 1,671.28 5,968,168.46 372,719.18 2.00 6,163.83 K-2(Qannik) 8,009.61 68.93 154.07 4,074.52 4,022.62 -5,952.56 1,671.98 5,968,167.01 372,719.85 2.00 6,165.43 Start 8537.90 hold at 8009.61 MD 8,009.73 68.93 154.07 4,074.56 4,022.66 -5,952.66 1,672.03 5,968,166.91 372,719.90 2.00 6,165.54 8,100.00 68.93 154.07 4,107.01 4,055.11 -6,028.42 1,708.86 5,968,090.53 372,755.42 0.00 6,249.32 8,200.00 68.93 154.07 4,142.97 4,091.07 -6,112.34 1,749.66 5,968,005.93 372,794.77 0.00 6,342.14 8,280.48 68.93 154.07 4,171.90 4,120.00 -6,179.87 1,782.50 5,967,937.85 372,826.44 0.00 6,416.83 Basal K-2 8,300.00 68.93 154.07 4,178.92 4,127.02 -6,196.26 1,790.46 5,967,921.33 372,834.12 0.00 6,434.95 8,400.00 68.93 154.07 4,214.87 4,162.97 -6,280.18 1,831.27 5,967,836.73 372,873.47 0.00 6,527.77 8,500.00 68.93 154.07 4,250.82 4,198.92 -6,364.10 1,872.07 5,967,752.12 372,912.82 0.00 6,620.58 8,600.00 68.93 154.07 4,286.78 4,234.88 -6,448.02 1,912.87 5,967,667.52 372,952.17 0.00 6,713.40 8,700.00 68.93 154.07 4,322.73 4,270.83 -6,531.94 1,953.67 5,967,582.92 372,991.52 0.00 6,806.21 8,800.00 68.93 154.07 4,358.68 4,306.78 -6,615.86 1,994.47 5,967,498.32 373,030.87 0.00 6,899.02 8,900.00 68.93 154.07 4,394.63 4,342.73 -6,699.78 2,035.27 5,967,413.71 373,070.22 0.00 6,991.84 9,000.00 68.93 154.07 4,430.59 4,378.69 -6,783.70 2,076.07 5,967,329.11 373,109.58 0.00 7,084.65 9,100.00 68.93 154.07 4,466.54 4,414.64 -6,867.62 2,116.88 5,967,244.51 373,148.93 0.00 7,177.47 9,200.00 68.93 154.07 4,502.49 4,450.59 -6,951.54 2,157.68 5,967,159.91 373,188.28 0.00 7,270.28 9,300.00 68.93 154.07 4,538.45 4,486.55 -7,035.46 2,198.48 5,967,075.30 373,227.63 0.00 7,363.10 9,400.00 68.93 154.07 4,574.40 4,522.50 -7,119.38 2,239.28 5,966,990.70 373,266.98 0.00 7,455.91 9,500.00 68.93 154.07 4,610.35 4,558.45 -7,203.30 2,280.08 5,966,906.10 373,306.33 0.00 7,548.72 9,600.00 68.93 154.07 4,646.30 4,594.40 -7,287.22 2,320.88 5,966,821.50 373,345.68 0.00 7,641.54 9,700.00 68.93 154.07 4,682.26 4,630.36 -7,371.14 2,361.68 5,966,736.89 373,385.03 0.00 7,734.35 9,800.00 68.93 154.07 4,718.21 4,666.31 -7,455.07 2,402.49 5,966,652.29 373,424.38 0.00 7,827.17 9,900.00 68.93 154.07 4,754.16 4,702.26 -7,538.99 2,443.29 5,966,567.69 373,463.73 0.00 7,919.98 12/2/2010 11:06:58AM Page 5 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTO 144 Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD2-77 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+15.6 @ 51.906(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+15.6 @ 51.906(Doyon 19) Site: CD2 Alpine Pad North Reference: True Well: Plan:CO2-77 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD2-77 Design: CD2-77wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section _ , (ft) (*) (*) (ft) ft (ft) (ft) (ft) (ft) 4,738.21 10,000.00 68.93 154.07 4,790.11 4,738.21 -7,622.91 2,484.09 5,966,483.09 373,503.08 0.00 8,012.80 10,100.00 68.93 154.07 4,826.07 4,774.17 -7,706.83 2,524.89 5,966,398.49 373,542.43 0.00 8,105.61 10,200.00 68.93 154.07 4,862.02 4,810.12 -7,790.75 2,565.69 5,966,313.88 373,581.78 0.00 8,198.43 10,300.00 68.93 154.07 4,897.97 4,846.07 -7,874.67 2,606.49 5,966,229.28 373,621.13 0.00 8,291.24 10,400.00 68.93 154.07 4,933.92 4,882.02 -7,958.59 2,647.29 5,966,144.68 373,660.48 0.00 8,384.05 10,500.00 68.93 154.07 4,969.88 4,917.98 -8,042.51 2,688.09 5,966,060.08 373,699.83 0.00 8,476.87 10,600.00 68.93 154.07 5,005.83 4,953.93 -8,126.43 2,728.90 5,965,975.47 373,739.18 0.00 8;569.68 10,700.00 68.93 154.07 5,041.78 4,989.88 -8,210.35 2,769.70 5,965,890.87 373,778.53 0.00 8,662.50 10,800.00 68.93 154.07 5,077.73 5,025.83 -8,294.27 2,810.50 5,965,806.27 373,817.88 0.00 8,755.31 10,900.00 68.93 154.07 5,113.69 5,061.79 -8,378.19 2,851.30 5,965,721.67 373,857.23 0.00 8,848.13 11,000.00 68.93 154.07 5,149.64 5,097.74 -8,462.11 2,892.10 5,965,637.06 373,896.58 0.00 8,940.94 11,100.00 68.93 154.07 5,185.59 5,133.69 -8,546.03 2,932.90 5,965,552.46 373,935.93 0.00 9,033.76 11,200.00 68.93 154.07 5,221.54 5,169.64 -8,629.95 2,973.70 5,965,467.86 373,975.28 0.00 9,126.57 11,300.00 68.93 154.07 5,257.50 5,205.60 -8,713.87 3,014.51 5,965,383.26 374,014.63 0.00 9,219.38 11,400.00 68.93 154.07 5,293.45 5,241.55 -8,797.79 3,055.31 5,965,298.65 374,053.98 0.00 9,312.20 11,500.00 68.93 154.07 5,329.40 5,277.50 -8,881.71 3,096.11 5,965,214.05 374,093.33 0.00 9,405.01 11,600.00 68.93 154.07 5,365.35 5,313.45 -8,965.64 3,136.91 5,965,129.45 374,132.68 0.00 9,497.83 11,700.00 68.93 154.07 5,401.31 5,349.41 -9,049.56 3,177.71 5,965,044.85 374,172.03 0.00 9,590.64 . 11,800.00 68.93 154.07 5,437.26 5,385.36 -9,133.48 3,218.51 5,964,960.25 374,211.38 0.00 9,683.46 11,900.00 68.93 154.07 5,473.21 5,421.31 -9,217.40 3,259.31 5,964,875.64 374,250.73 0.00 9,776.27 12,000.00 68.93 154.07 5,509.17 5,457.27 -9,301.32 3,300.12 5,964,791.04 374,290.08 0.00 9,869.09 12,100.00 68.93 154.07 5,545.12 5,493.22 -9,385.24 3,340.92 5,964,706.44 374,329.43 0.00 9,961.90 12,200.00 68.93 154.07 5,581.07 5,529.17 -9,469.16 3,381.72 5,964,621.84 374,368.78 0.00 10,054.71 12,300.00 68.93 154.07 5,617.02 5,565.12 -9,553.08 3,422.52 5,964,537.23 374,408.13 0.00 10,147.53 12,400.00 68.93 154.07 5,652.98 5,601.08 -9,637.00 3,463.32 5,964,452.63 374,447.48 0.00 10,240.34 12,500.00 68.93 154.07 5,688.93 5,637.03 -9,720.92 3,504.12 5,964,368.03 374,486.83 0.00 10,333.16 12,536.08 68.93 154.07 5,701.90 5,650.00 -9,751.20 3,518.84 5,964,337.50 374,501.03 0.00 10,366.64 , Albian 97 12,600.00 68.93 154.07 5,724.88 5,672.98 -9,804.84 3,544.92 5,964,283.43 374,526.18 0.00 10,425.97 12,700.00 68.93 154.07 5,760.83 5,708.93 -9,888.76 3,585.73 5,964,198.82 374,565.53 0.00 10,518.79 12,800.00 68.93 154.07 5,796.79 5,744.89 -9,972.68 3,626.53 5,964,114.22 374,604.88 0.00 10,611.60 12,900.00 68.93 154.07 5,832.74 5,780.84 -10,056.60 3,667.33 5,964,029.62 374,644.23 0.00 10,704.42 13,000.00 68.93 154.07 5,868.69 5,816.79 -10,140.52 3,708.13 5,963,945.02 374,683.58 0.00 10,797.23 13,100.00 68.93 154.07 5,904.64 5,852.74 -10,224.44 3,748.93 5,963,860.41 374,722.93 0.00 10,890.04 13,200.00 68.93 154.07 5,940.60 5,888.70 -10,308.36 3,789.73 5,963,775.81 374,762.28 0.00 10,982.86 13,300.00 68.93 154.07 5,976.55 5,924.65 -10,392.28 3,830.53 5,963,691.21 374,801.63 0.00 11,075.67 13,400.00 68.93 154.07 6,012.50 5,960.60 -10,476.20 3,871.34 5,963,606.61 374,840.98 0.00 11,168.49 13,500.00 68.93 154.07 6,048.45 5,996.55 -10,560.13 3,912.14 5,963,522.00 374,880.33 0.00 11,261.30 13,600.00 68.93 154.07 6,084.41 6,032.51 -10,644.05 3,952.94 5,963,437.40 374,919.68 0.00 11,354.12 13,700.00 68.93 154.07 6,120.36 6,068.46 -10,727.97 3,993.74 5,963,352.80 374,959.03 0.00 11,446.93 13,787.73 68.93 154.07 6,151.90 6,100.00 -10,801.59 4,029.53 5,963,278.58 374,993.55 0.00 11,528.35 Albian 96(Nanuq) 13,800.00 68.93 154.07 6,156.31 6,104.41 -10,811.89 4,034.54 5,963,268.20 374,998.38 0.00 11,539.74 13,900.00 68.93 154.07 6,192.26 6,140.36 -10,895.81 4,075.34 5,963,183.60 375,037.73 0.00 11,632.56 14,000.00 68.93 154.07 6,228.22 6,176.32 -10,979.73 4,116.14 5,963,098.99 375,077.08 0.00 11,725.37 12/2/2010 11:06:58AM Page 6 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBLJPTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD2-77 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Site: CD2 Alpine Pad North Reference: True Well: Plan:CD2-77 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD2-77 Design: CD2-77wp05 , .Planned Survey _ Measured Vertical Map Map , [ Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Basting DLS Vert Section i (ft) (*) (*) (ft) ft (ft) (ft) (ft) (ft) 6,212.27 , 14,100.00 68.93 154.07 6,264.17 6,212.27 -11,063.65 4,156.95 5,963,014.39 375,116.43 0.00 11,818.19 14,200.00 68.93 154.07 6,300.12 6,248.22 -11,147.57 4,197.75 5,962,929.79 375,155.78 0.00 11,911.00 14,300.00 68.93 154.07 6,336.07 6,284.17 -11,231.49 4,238.55 5,962,845.19 375,195.13 0.00 12,003.82 14,400.00 68.93 154.07 6,372.03 6,320.13 -11,315.41 4,279.35 5,962,760.58 375,234.48 0.00 12,096.63 1 14,500.00 68.93 154.07 6,407.98 6,356.08 -11,399.33 4,320.15 5,962,675.98 375,273.83 0.00 12,189.45 1 14,600.00 68.93 154.07 6,443.93 6,392.03 -11,483.25 4,360.95 5,962,591.38 375,313.18 0.00 12,282.26 14,700.00 68.93 154.07 6,479.89 6,427.99 -11,567.17 4,401.75 5,962,506.78 375,352.53 0.00 12,375.07 14,800.00 68.93 154.07 6,515.84 6,463.94 -11,651.09 4,442.55 5,962,422.17 375,391.88 0.00 12,467.89 14,900.00 68.93 154.07 6,551.79 6,499.89 -11,735.01 4,483.36 5,962,337.57 375,431.24 0.00 12,560.70 15,000.00 68.93 154.07 6,587.74 6,535.84 -11,818.93 4,524.16 5,962,252.97 375,470.59 0.00 12,653.52 15,100.00 68.93 154.07 6,623.70 6,571.80 -11,902.85 4,564.96 5,962,168.37 375,509.94 0.00 12,746.33 15,200.00 68.93 154.07 6,659.65 6,607.75 -11,986.77 4,605.76 5,962,083.76 375,549.29 0.00 12,839.15 15,300.00 68.93 154.07 6,695.60 6,643.70 -12,070.70 4,646.56 5,961,999.16 375,588.64 0.00 12,931.96 15,400.00 68.93 154.07 6,731.55 6,679.65 -12,154.62 4,687.36 5,961,914.56 375,627.99 0.00 13,024.78 15,500.00 68.93 154.07 6,767.51 6,715.61 -12,238.54 4,728.16 5,961,829.96 375,667.34 0.00 13,117.59 15,512.22 68.93 154.07 6,771.90 6,720.00 -12,248.79 4,733.15 5,961,819.62 375,672.15 0.00 13,128.93 HRZ 15,600.00 68.93 154.07 6,803.46 6,751.56 -12,322.46 4,768.97 5,961,745.35 375,706.69 0.00 13,210.40 15,700.00 68.93 154.07 6,839.41 6,787.51 -12,406.38 4,809.77 5,961,660.75 375,746.04 0.00 13,303.22 15,800.00 68.93 154.07 6,875.36 6,823.46 -12,490.30 4,850.57 5,961,576.15 375,785.39 0.00 13,396.03 15,876.59 68.93 154.07 6,902.90 6,851.00 -12,554.57 4,881.82 5,961,511.35 375,815.53 0.00 13,467.12 Base HRZ 15,900.00 68.93 154.07 6,911.32 6,859.42 -12,574.22 4,891.37 5,961,491.55 375,824.74 0.00 13,488.85 16,000.00 68.93 154.07 6,947.27 6,895.37 -12,658.14 4,932.17 5,961,406.95 375,864.09 0.00 13,581.66 16,049.04 68.93 154.07 6,964.90 6,913.00 -12,699.29 4,952.18 5,961,365.46 375,883.38 0.00 13,627.18 K-1 Marker 16,100.00 68.93 154.07 6,983.22 6,931.32 -12,742.06 4,972.97 5,961,322.34 375,903.44 0.00 13,674.48 16,200.00 68.93 154.07 7,019.17 6,967.27 -12,825.98 5,013.77 5,961,237.74 375,942.79 0.00 13,767.29 ' 16,263.21 68.93 154.07 7,041.90 6,990.00 -12,879.03 5,039.57 5,961,184.26 375,967.66 0.00 13,825.96 Kuparuk C 16,277.12 68.93 154.07 7,046.90 6,995.00 -12,890.70 5,045.24 5,961,172.50 375,973.13 0.00 13,838.87 LCU-Miluveach 16,300.00 68.93 154.07 7,055.13 7,003.23 -12,909.90 5,054.58 5,961,153.14 375,982.14 0.00 13,860.11 16,400.00 68.93 154.07 7,091.08 7,039.18 -12,993.82 5,095.38 5,961,068.54 376,021.49 0.00 13,952.92 16,500.00 68.93 154.07 7,127.03 7,075.13 -13,077.74 5,136.18 5,960,983.93 376,060.84 0.00 14,045.73 16,547.51 68.93 154.07 7,144.11 7,092.21 -13,117.61 5,155.56 5,960,943.74 376,079.53 0.00 14,089.83 Start DLS 3.00 TFO-5.52 16,547.59 68.93 154.07 7,144.14 7,092.24 -13,117.68 5,155.60 5,960,943.67 376,079.57 0.00 14,089.91 16,600.00 70.49 153.91 7,162.31 7,110.41 -13,161.86 5,177.15 5,960,899.13 376,100.36 3.00 14,138.79 16,700.00 73.48 153.61 7,193.23 7,141.33 -13,247.15 5,219.19 5,960,813.14 376,140.92 3.00 14,233.32 16,800.00 76.47 153.32 7,219.16 7,167.26 -13,333.54 5,262.34 5,960,726.02 376,182.57 3.00 14,329.26 16,848.46 77.91 153.18 7,229.90 7,178.00 -13,375.74 5,283.60 5,960,683.47 376,203.11 3.00 14,376.18 Alpine D 16,900.00 79.45 153.04 7,240.01 7,188.11 -13,420.81 5,306.46 5,960,638.02 376,225.19 3.00 14,426.35 12/2/2010 11:06:58AM Page 7 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTON Standard Proposal Report ,...._,„,„,MrlITINIUMM,..- 1 ;:''--n-=-- RIVII1111111,=-.--,...,41777' 77,91PRIUMNIVIM7179FIRI411MTE7=1131EM°7=manomIdellEMEISI=TIMIENV= Database: ' EDM v16 Prod Local Co-ordinate Reference: 'Well Plan:CD2-77 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Site: CO2 Alpine Pad North Reference: True Well: Plan:CD2-77 SurY9f; 10 P9p1,101ettig.' 1"ii Minimum Curvature Wellbore: Plan:CD2-77 1,1ii,I;i11111,„11,„Pl„,,01,1h1 11 ,:,l'olori;;,,1;11,,h, 1 1 Design: CD2-77wp05 Planned Survey Measured Vertical Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (*) (1 (ft) ft (ft) (ft) (ft) (ft) 7,195.00 16,939.86 80.65 152.93 7,246.90 7,195.00 -13,455.79 5,324.29 5,960,602.74 376,242.41 3.00 14,465.32 Alpine C 17,000.00 82.44 152.76 7,255.74 7,203.84 -13,508.71 5,351.44 5,960,549.36 376,268.65 3.00 14,524.34 17,052.05 84.00 152.62 7,261.89 7,209.99 -13,554.64 5,375.16 5,960,503.04 376,291.57 3.00 14,575.61 Start DLS 2.09 TFO 0.02 17,052.15 84.00 152.62 7,261.90 7,210.00 -13,554.73 5,375.20 5,960,502.95 376,291.61 3.00 14,575.71 7-5/8"X 9-7/8"-CD2-77wp03 Heel 17,100.00 85.00 152.62 7,266.49 7,214.59 -13,597.02 5,397.11 5,960,460.29 376,312.79 2.09 14,622.94 17,200.00 87.09 152.62 7,273.38 7,221.48 -13,685.60 5,442.99 5,960,370.94 376,357.13 2.09 14,721.87 17,300.00 89.19 152.62 7,276.62 7,224.72 -13,774.34 5,488.95 5,960,281.43 376,401.56 2.09 14,820.98 17,338.79 90.00 152.62 7,276.90 7,225.00 -13,808.79 5,506.79 5,960,246.69 376,418.81 2.09 14,859.45 Start DLS 2.00 TFO 88.40 17,338.89 90.00 152.62 7,276.90 7,225.00 -13,808.88 5,506.84 5,960,246.60 376,418.85 2.09 14,859.55 1 I 17,400.00 90.03 153.84 7,276.88 7,224.98 -13,863.44 5,534.36 5,960,191.58 376,445.43 2.00 14,920.23 I 17,493.37 90.09 155.71 7,276.78 7,224.88 -13,947.90 5,574.15 5,960,106.45 376,483.76 2.00 15,013.21 Start 3243.19 hold at 17493.37 MD 17,493.78 90.09 155.72 7,276.78 7,224.88 -13,948.28 5,574.32 5,960,106.07 376,483.92 2.00 15,013.62 1 17,500.00 90.09 155.72 7,276.77 7,224.87 -13,953.94 5,576.88 5,960,100.36 376,486.38 0.00 15,019.82 17,600.00 90.09 155.72 7,276.62 7,224.72 -14,045.09 5,618.00 5,960,008.52 376,525.93 0.00 15,119.54 17,700.00 90.09 155.72 7,276.47 7,224.57 -14,136.25 5,659.13 5,959,916.69 376,565.48 0.00 15,219.26 17,800.00 90.09 155.72 7,276.32 7,224.42 -14,227.40 5,700.25 5,959,824.85 376,605.03 0.00 15,318.98 17,900.00 90.09 155.72 7,276.17 7,224.27 -14,318.55 5,741.38 5,959,733.01 376,644.58 0.00 15,418.70 18,000.00 90.09 155.72 7,276.02 7,224.12 -14,409.70 5,782.50 5,959,641.17 376,684.13 0.00 15,518.42 18,100.00 90.09 155.72 7,275.87 7,223.97 -14,500.85 5,823.63 5,959,549.34 376,723.68 0.00 15,618.14 18,200.00 90.09 155.72 7,275.72 7,223.82 -14,592.01 5,864.75 5,959,457.50 376,763.23 0.00 15,717.86 18,300.00 90.09 155.72 7,275.57 7,223.67 -14,683.16 5,905.88 5,959,365.66 376,802.78 0.00 15,817.58 18,400.00 90.09 155.72 7,275.42 7,223.52 -14,774.31 5,947.00 5,959,273.82 376,842.33 0.00 15,917.30 I 18,500.00 90.09 155.72 7,275.27 7,223.37 -14,865.46 5,988.13 5,959,181.98 376,881.88 0.00 16,017.03 18,600.00 90.09 155.72 7,275.12 7,223.22 -14,956.61 6,029.25 5,959,090.15 376,921.42 0.00 16,116.75 ' 18,700.00 90.09 155.72 7,274.97 7,223.07 -15,047.77 6,070.38 5,958,998.31 376,960.97 0.00 16,216.47 18,800.00 90.09 155.72 7,274.82 7,222.92 -15,138.92 6,111.50 5,958,906.47 377,000.52 0.00 16,316.19 18,900.00 90.09 155.72 7,274.67 7,222.77 -15,230.07 6,152.63 5,958,814.63 377,040.07 0.00 16,415.91 19,000.00 90.09 155.72 7,274.52 7,222.62 -15,321.22 6,193.75 5,958,722.79 377,079.62 0.00 16,515.63 19,100.00 90.09 155.72 7,274.36 7,222.46 -15,412.38 6,234.88 5,958,630.96 377,119.17 0.00 16,615.35 19,200.00 90.09 155.72 7,274.21 7,222.31 -15,503.53 6,276.00 5,958,539.12 377,158.72 0.00 16,715.07 19,300.00 90.09 155.72 7,274.06 7,222.16 -15,594.68 6,317.13 5,958,447.28 377,198.27 0.00 16,814.79 19,400.00 90.09 155.72 7,273.91 7,222.01 -15,685.83 6,358.25 5,958,355.44 377,237.82 0.00 16,914.51 19,500.00 90.09 155.72 7,273.76 7,221.86 -15,776.98 6,399.38 5,958,263.60 377,277.37 0.00 17,014.23 19,600.00 90.09 155.72 7,273.61 7,221.71 -15,868.14 6,440.50 5,958,171.77 377,316.92 0.00 17,113.95 19,700.00 90.09 155.72 7,273.46 7,221.56 -15,959.29 6,481.63 5,958,079.93 377,356.47 0.00 17,213.67 19,8-00.00 90.09 155.72 7,273.31 7,221.41 -16,050.44 6,522.75 5,957,988.09 377,396.02 0.00 17,313.39 19,900.00 90.09 155.72 7,273.16 7,221.26 -16,141.59 6,563.88 5,957,896.25 377,435.57 0.00 17,413.11 , 20,000.00 90.09 155.72 7,273.01 7,221.11 -16,232.75 6,605.00 5,957,804.42 377,475.12 0.00 17,512.83 20,100.00 90.09 155.72 7,272.86 7,220.96 -16,323.90 6,646.13 5,957,712.58 377,514.67 0.00 17,612.55 20,200.00 90.09 155.72 7,272.71 7,220.81 -16,415.05 6,687.25 5,957,620.74 377,554.21 0.00 17,712.28 12/2/2010 11:06:58AM Page 8 COMPASS 2003.16 Build 69 (-0),.. RIGINAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD2-77 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) . Site: CD2 Alpine Pad North Reference: True Well: Plan:CD2-77 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD2-77 Design: CD2-77wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (ft) (°) (`) (ft) ft (ft) (ft) (ft) (ft) 7,220.66 20,300.00 90.09 155.72 7,272.56 7,220.66 -16,506.20 6,728.38 5,957,528.90 377,593.76 0.00 17,812.00 20,400.00 90.09 155.72 7,272.41 7,220.51 -16,597.35 6,769.50 5,957,437.06 377,633.31 0.00 17,911.72 20,500.00 90.09 155.72 7,272.26 7,220.36 -16,688.51 6,810.63 5,957,345.23 377,672.86 0.00 18,011.44 20,600.00 90.09 155.72 7,272.11 7,220.21 -16,779.66 6,851.75 5,957,253.39 377,712.41 0.00 18,111.16 20,700.00 90.09 155.72 7,271.96 7,220.06 -16,870.81 6,892.88 5,957,161.55 377,751.96 0.00 18,210.88 20,736.56 90.09 155.72 7,271.90 7,220.00 -16,904.13 6,907.91 5,957,127.98 377,766.42 0.00 18,247.33 Start DLS 2.00 TFO 89.93 20,736.69 90.09 155.72 7,271.90 7,220.00 -16,904.25 6,907.96 5,957,127.85 377,766.47 0.00 18,247.47 CD2-77 26Oct10 Mid 20,800.00 90.09 156.98 7,271.80 7,219.90 -16,962.25 6,933.36 5,957,069.44 377,790.87 2.00 18,310.65 20,900.00 90.09 158.98 7,271.65 7,219.75 -17,054.95 6,970.85 5,956,976.11 377,826.75 2.00 18,410.58 21,000.00 90.09 160.98 7,271.49 7,219.59 -17,148.90 7,005.08 5,956,881.59 377,859.36 2.00 18,510.57 21,100.00 90.09 162.98 7,271.33 7,219.43 -17,243.99 7,036.00 5,956,785.99 377,888.65 2.00 18,610.51 21,200.00 90.10 164.98 7,271.16 7,219.26 -17,340.11 7,063.60 5,956,689.43 377,914.58 2.00 18,710.26 21,300.00 90.10 166.98 7,270.99 7,219.09 -17,437.12 7,087.82 5,956,592.02 377,937.13 2.00 18,809.71 21,400.00 90.10 168.98 7,270.82 7,218.92 -17,534.93 7,108.63 5,956,493.88 377,956.26 2.00 18,908.74 21,500.00 90.10 170.98 7,270.65 7,218.75 -17,633.40 7,126.03 5,956,395.13 377,971.96 2.00 19,007.22 21,600.00 90.10 172.98 7,270.47 7,218.57 -17,732.41 7,139.97 5,956,295.90 377,984.20 2.00 19,105.03 21,604.88 90.10 173.08 7,270.46 7,218.56 -17,737.26 7,140.57 5,956,291.05 377,984.71 2.00 19,109.79 Start 1998.95,hold at 21604.88 MD 21,604.94 90.10 173.08 7,270.46 7,218.56 -17,737.32 7,140.57 5,956,290.98 377,984.72 2.00 19,109.85 21,700.00 90.10 173.08 7,270.29 7,218.39 -17,831.69 7,152.02 5,956,196.44 377,994.54 0.00 19,202.44 21,800.00 90.10 173.08 7,270.11 7,218.21 -17,930.96 7,164.07 5,956,096.99 378,004.88 0.00 19,299.84 21,900.00 90.10 173.08 7,269.94 7,218.04 -18,030.23 7,176.11 5,955,997.53 378,015.22 0.00 19,397.25 22,000.00 90.10 173.08 7,269.76 7,217.86 -18,129.50 7,188.16 5,955,898.07 378,025.55 0.00 19,494.65 22,100.00 90.10 173.08 7,269.58 7,217.68 -18,228.77 7,200.21 5,955,798.62 378,035.89 0.00 19,592.06 22,200.00 90.10 173.08 7,269.40 7,217.50 -18,328.04 7,212.25 5,955,699.16 378,046.23 0.00 19,689.46 22,300.00 90.10 173.08 7,269.22 7,217.32 -18,427.32 7,224.30 5,955,599.71 378,056.56 0.00 19,786.87 22,400.00 90.10 173.08 7,269.05 7,217.15 -18,526.59 7,236.34 5,955,500.25 378,066.90 0.00 19,884.27 22,500.00 90.10 173.08 7,268.87 7,216.97 -18,625.86 7,248.39 5,955,400.79 378,077.24 0.00 19,981.68 22,600.00 90.10 173.08 7,268.69 7,216.79 -18,725.13 7,260.43 5,955,301.34 378,087.57 0.00 20,079.08 22,700.00 90.10 173.08 7,268.51 7,216.61 -18,824.40 7,272.48 5,955,201.88 378,097.91 0.00 20,176.49 22,800.00 90.10 173.08 7,268.33 7,216.43 -18,923.68 7,284.52 5,955,102.43 378,108.25 0.00 20,273.89 22,900.00 90.10 173.08 7,268.15 7,216.25 -19,022.95 7,296.57 5,955,002.97 378,118.58 0.00 20,371.30 23,000.00 90.10 173.08 7,267.98 7,216.08 -19,122.22 7,308.61 5,954,903.51 378,128.92 0.00 20,468.70 0.00 20,566.11 23,100.00 90.10 173.08 7,267.80 7,215.90 -19,221.49 7,320.66 5,954,804.06 378,139.26 23,200.00 90.10 173.08 7,267.62 7,215.72 -19,320.76 7,332.70 5,954,704.60 378,149.60 0.00 20,663.51 23,300.00 90.10 173.08 7,267.44 7,215.54 -19,420.03 7,344.75 5,954,605.15 378,159.93 0.00 20,760.91 23,400.00 90.10 173.08 7,267.26 7,215.36 -19,519.31 7,356.79 5,954,505.69 378,170.27 0.00 20,858.32 23,500.00 90.10 173.08 7,267.09 7,215.19 -19,618.58 7,368.84 5,954,406.23 378,180.61 0.00 20,955.72 23,600.00 90.10 173.08 7,266.91 7,215.01 -19,717.85 7,380.89 5,954,306.78 378,190.94 0.00 21,053.13 23,603.83 90.10 173.08 7,266.90 7,215.00 -19,721.65 7,381.35 5,954,302.97 378,191.34 0.00 21,056.86 TD at 23603.83-3-1/2"x 6-3/4" 23,603.99 - 90.10 173.08 7,266.90 - 7,215.00 -19,721.81 - 7,381.37 , 5,954,302.81 378,191.36 0.00 21,057.02 CD2-77 26Oct10 Toe 12/2/2010 11:06:58AM Page 9 COMPASS 2003.16 Build 69 ConocoPhillips Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD2-77 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Site: CD2 Alpine Pad North Reference: True Well: Plan:CD2-77 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD2-77 Design: CD2-77wp05 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (0) (0) (ft) (ft) (ft) (ft) (ft) CD2-77 30Aug10 Qannik 0.00 0.00 4,071.90 -5,946.43 1,669.00 5,968,173.18 372,716.98 -plan hits target center -Point CD2-77 26Oct10 Mid 0.00 0.00 7,271.90 -16,904.25 6,907.96 5,957,127.85 377,766.47 -plan hits target center -Point CD2-77 26Oct10 Toe 0.00 0.00 7,266.90 -19,721.81 7,381.37 5,954,302.81 378,191.36 -plan hits target center -Point CD2-77wp03 Heel 0.00 0.00 7,261.90 -13,554.73 5,375.20 5,960,502.95 376,291.61 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name („) C') 3,396.43 2,400.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 17,052.15 7,261.90 7-5/8"X 9-7/8" 7-5/8 9-7/8 23,603.83 7,266.90 3-1/2"x 6-3/4" 3-1/2 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (1 (0) 7,366.28 3,841.90 K-3 Marker 16,049.04 6,964.90 K-1 Marker 13,787.73 6,151.90 Albian 96(Nanuq) 8,280.48 4,171.90 Basal K-2 8,007.89 4,073.90 K-2(Qannik) 12,536.08 5,701.90 Albian 97 1,632.61 1,551.90 Base Permafrost 0.00 15,876.59 6,902.90 Base HRZ 16,277.12 7,046.90 LCU-Miluveach 3,429.19 2,411.90 C-30 0.00 16,848.46 7,229.90 Alpine D 4,447.88 2,781.90 C-20 15,512.22 6,771.90 HRZ 16,939.86 7,246.90 Alpine C 16,263.21 7,041.90 Kuparuk C 7,929.69 4,045.90 Basal K-3 12/2/2010 11:06:58AM Page 10 COMPASS 2003.16 Build 69 0R1GINA .1.,.. ConocoPhillips Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD2-77 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+15.6 @ 51.90ft(Doyon 19) Site: CD2 Alpine Pad North Reference: True Well: Plan:CD2-77 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD2-77 Design: CD2-77wp05 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 250.00 250.00 0.00 0.00 Start Build 1.50 400.04 400.00 -2.94 -0.26 Start DLS 2.20 TFO 0.00 905.51 900.00 -71.26 -6.23 Start DLS 3.45 TFO-23.97 2,538.82 2,088.51 -1,071.74 208.18 Start 5011.12 hold at 2538.82 MD 7,549.94 3,908.61 -5,553.42 1,517.05 Start DLS 2.00 TFO-89.43 8,002.26 4,071.88 -5,946.39 1,668.98 Start DLS 2.00 TFO 164.07 8,009.61 4,074.52 -5,952.56 1,671.98 Start 8537.90 hold at 8009.61 MD 16,547.51 7,144.11 -13,117.61 5,155.56 Start DLS 3.00 TFO-5.52 17,052.05 7,261.89 -13,554.64 5,375.16 Start DLS 2.09 TFO 0.02 17,338.79 7,276.90 -13,808.79 5,506.79 Start DLS 2.00 TFO 88.40 17,493.37 7,276.78 -13,947.90 5,574.15 Start 3243.19 hold at 17493.37 MD 20,736.56 7,271.90 -16,904.13 6,907.91 Start DLS 2.00 TFO 89.93 21,604.88 7,270.46 -17,737.26 7,140.57 Start 1998.95 hold at 21604.88 MD 23,603.83 7,266.90 -19,721.65 7,381.35 TD at 23603.83 12/2/2010 11:06:58AM Page 11 COMPASS 2003.16 Build 69 1 m 0 is 0) C 03 8.. 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N N O en F= `0' U V O �/��� 4 �, 2,SWV=3,7sq.avnngir.q. 11a l�1,*, I NOON�mAOJNO)rn Ol nlhajm .®'v -111Ml pv F- m N m m m °° 'ir.p U e�N,i-j ryg3.::�'' i:G U or000m0000orno 000 ( /'a�� i��' .,ali i rn Joo�Nv,0000000000 0 .l ''•4 , �v' llfR 7 ONNOMN NONO • 1 ® f t � OmMAV mm�MA N�-NA CG.7( TrqT ®A/ � �..'� o r1110\ W OONNNmm.nOlYlYfmMN R �I\ �'� @�b�/� u Zl�l OOO '''- 7N<oroSti343NM (O �� .��I�y'/�-r''o"AmAoAoamO p N V * � � dm uN�mme-M mbpr�M �.�` �� p � O Nin u�wmAA NW fnOOVmNnmMVMMSsL M� �.G' ♦ W 8SIRIP Nt700NMan1 Y ���1� �' IvArlf O �-�ZOON�w-nimNlhatOA mp �_II+ "`ovoirnm7voi N O �,,, 1•�� a0 Ot0+1000,NOMinOOm OmO r `�Fm 'ommo �mmrnaarnv:rom�omMvoiSomotiAo � \N VO,On100� NNNNN � r'ryM�VAAAAAAA � ,}.p OOn-,-NAANN.-•-mm r`` : ✓9 OOOOAAOOOmmAA00 AO <st O N Nin 6 CICI 1¢" A1ES �v0000inAooAMMoom,aoo M �•��-.� / .7 OONOi tmn mtmn fmOmma OOi�TnOi� allegk 4016-40• �� I ; T Q28&7414‘7, 222 �OV�NV �YJ Amm � 0• 4 , , to 00 m Ntn vJOl�MmmaO AWAMMO cpOCvicOni<Vn1A Nm MtGVM -w-� ';.14'��♦e{ O C ..0.2n00..nMWM00 NOnfNAmminOMa Om m'1 #‘11 - .4 N mA��NNN G to 41WOh0 A' N V E- 0�NMOVImA mnfO.-NMVVr U 4Op /N y T FIFA" 8 N cm 2 V.I. cm j r >> r ^g a 0" > ; 3E ; HALLIBURTON ConocoPhillips CD2-77wp05 Alaska Sperry Drilling ANTI-COLLISION SETTINGS 13:13,December 012010 Interpolation Method: MD, interval:25.00 Depth Range From: 36.30 To 23603.83 Results Limited By: Centre Distance:2556.75 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1000.00 CD2-77wp05(Plan:CD2-77) CB-GYRO-SS 1000.00 3396.40 CD2-77wp05(Plan: CD2-77) MWD+IFR-AK-CAZ-SC 3396.40 17052.05 CD2-77wp05(Plan: CD2-77) MWD+IFR-AK-CAZ-SC 17052.05 23603.83 CD2-77wp05(Plan: CD2-77) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2400.00 3396.40 10-3/4"x 13-1/2" 10-3/4 7261.90 17052.05 7-5/8"X 9-7/8" 7-5/8 7266.90 23603.83 3-1/2"x 6-3/4" 3-1/2 &Rlm Iii, J }( C N Tri G 2 p U U U - / iJ ' / 1 ` 1 i j60- \ )II 1 Nj C_) - \ / II o 30- `1 ami --->-F=' I , • U 0 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 0 500 1000 1500 2000 2500 3000 3500 Measured Depth LEGEND -9- CD2-36,CD2-36,CD2-36 V2 CD2-47,CD2-47,CD2-47 V2 -e- CD2-60,CD2-60A,CD2-60A VO CD4-12,CD4-12PB1,CD4-12PB1 VO ---- -e- CD2-36,CD2-36P81,CD2-36PB1 V11 -9- CD2470,CO2-470,CD2470 VO -0- CD2-60,CD2-60PB1,CO2-60PB1 V8 0 CD4-208,CD4-208,CD4-208 V7 X( CD2-37,CD2-37,CD2-37 V17 Q CD2-54,CO2-54,CO2-54 V6 -s- CD2-72,CD2-72,CD2-72 V1 ❑ CD4-208,CD4-208PB1,CD4-208PB1 V6 - CD2-43,CD2-43,CD2-43 V15 -e- CD2-54,CD2-54L1,CD2-54L1 V4 -0- CD2-73,CD2-73,CD2-73 VO -0- CD4-208,Plan:CD4-08,CD4-08wp08 VO - CD2-43,CD2-43PB1,CD2-43PB1 V12 -9-- CD2-55,CD2-55,CO255 V9 -X- CD2-73,CD2-73PB1,CD2-73P61 VO ---X-- CD4-209,CD4-209,CD4-209 V4 CD2-43,Prelim:CO2-43A,CD243Awp02 V1 -I- CD2-56,CD2-56,CD2-56 V8 Q CD2-74,CD2-74,CD2-74 VO - CD4-210,CD4-210,CD4-210 V3 X CD2-464,CD2-464,CD2-464 VO 0 CD2-56,CD2-56L1,CD2-56L1 V10 CD2-75,CD2-75,CD2-75 VO -A- CD4-211,CD4-211,CD4-211 V2 --X- CD2-465,CD2-465,CD2-465 VO --X- CD2-57,CD2-57,CO2-57 V2 - CD2-76,CD2-76,CD2-76 VO ❑ CD4-320,CD4-320,CD4-320 V7 -A- CD2-466,CD2-466,CD2-466 VO -9- CD2-58,CD2-58,CO258 V12 [] CD2-76,CD2-76PB1,CD2-76PB1 VO 0 CD4-320,CD4-320PB1,CD4-320PB1 V4 $- 002467,002-467,CO2467 VO -I- CD2-58,CD2-58L1,CD2-58L1 V7 -A- CD2-76,CD2-76PB2,CD2-76PB2 VO -e- Plan:CD4-303,Plan:CD4-303,CD4-303wp06 V7 -e- 002467,CD2467PB1,CD2-467PB1 VO -e- CD2-59,CD2-59,CD2-59 V12 CD2-78,002-78,CD2-78 VO -X- Plan:004-303,Plan:CD4-303PB1,CD4-303PB1wp06 V8 002468,002468,002468 VO -0- CD2-59,CD2-59PB1,CD2-59PB1 V5 -X- Plan:002471,Plan:CD2-471,CD2471wp04 V4-- Nanuk 1,Nanuk 1,Nanuk 1 V2 ❑ CD2-469,CD2-469,002469 VO -X- CD2-60,CD2-60,CO2-60 V9 -A- CD4-12,CD4-12,C04-12 VO -9- CD2-77wp05 •e 5 Northing (6500 ft/in) ikklkikk111 1 1 1 111111111111 1 1 1 1 1 1 1 1 1 1 .. - • . _ Lo c)- 0 co- •:1" CD N , 9- CD CI CO CV 0 ,cr •cr - v__•- -_ 0 . N a Lit.8 re. , osl CO — CO LC) ta.;'''. ••000."6 VI' — 0 ra ...000.176 IP' _ CO - 0 • (5) C1 - N _ 00 ----------_____ a 0 7 ••• ••••-- •,. i" - 71- ' l'• - .- = N 102 cN - 0 0_ 8 Aggitiitt .. 0 1 E co r•-. co 0 ix) - 0 in tO - tO ' 0 0 .1 0, c Cn 03 la - LLI - , , •, ,—, IS / CV 1 - • a., 0 - C 0 .1 CVN-.1 i , 10 N- , CV 7 a c...) . ,--- . _ N 0 - 0 . - C.) _ — . . _ ...-...= CO _ O3 W 0. OS 4.• tl) - al .... C Z 42' = — 0.i 2 41)0 - a.1.) _ o.,. . — C.) - o C - o - (..) - ii , 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 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 11 1 1 1 1 1 1 II 11 1 1 1 1 1 (UM/0099) 6LIKIP°N ?, O ssa o g 0 H, 0 ii l- Awl .c5.�a cao gd.v mo,a6cScZ O1p8p88p8p 0 ^ nil O W G G G YI O Q &0000 Nt a .f ccc,- 8 OWNOW i8,l8 m O am oma 0 ~ py — 0 W iNZF>NNm N D t�A7_O W i' 28888 I- ooR W 4'nnn a O m lei O 0 % \ cp ' foo o. C J lin el i el sass CO20000 i O '' 4 WVIIII64 C) N ._.„,,,, ,,,,,„.„,..41,p, co ...... A *. illilirlAiik 4-1 0 r. .016.0.41 I I I la ..- W 0 oo c4 410111.1111.1111 -14111ril 0 O > 'mss 'VA 10, , o J Ove . L A. O v Aca O Cr 0 ea A o `a0 O 0 r O N '-- 0 O 0 O O O 0 0 N 0 0 0 0 0 0 O 0 0 0 0 0 0 N co 00 O N e6 .- .- r- N N en r (L101 I OOOZ) +),gpoN/(-)ulnoS 0 a N N Q 8 8 8 8 8 8 8 8 8 8 8 8 8 8 o P P N P P P P P P P P P FA' N h N N N N N h N N Vl h I f' °°°9z9L 1 11 1 t 1 1 1 1 1 1 1 1 ^ g 0007L91 I I 008E 6 000Illy I `III £291 8 000L1S1• I 0099z I 1 G3 0001 N 1 t 0000zS1 1 u 00552 ■ 0006181 0009191 1 �� 4111111. f 3 CX v �► G 0z Iy I i i a € 000L191 �'� I I W i i v 100SEz 00091914 I • _ 0004191 �, • 000714110.1i.11.11°? (X I I i c 000£191' f I _..._.._.. 9 R 8 S $ 0008191 I I 004LZ 5 _ 0;_001 1 • I uG g, 1 I I I I I I I I 8GI 00�Z s 1- S U • N $ C • 00461 y d S N o FS t i > S D 01 N gco 3 U U 3 oO > s ■ 00481 CI ■ M ■■ O --- - - —' iJ-- _.__ -004L1 (vj N 0 0 8 LD c N l� 0 NV) 0 Z UI i O ❑ ❑ ❑ ❑ ❑ ❑ ❑ I ■ 00491 O a . • M M M in N ■ < O 00 M CO O r O 7.c— • o 1 1 . 2 a tO M Tr t0 O N h g r o M tr-. Cr- - I` x- 3 00551 " % O O O O O O O °j o CI- inNih cin "vin U 0 0 1 to N Mr N O 01 r To. r CO lA r C7 M r J , '----..— _— 005171 N N C) N t0 h 00 IL 3 r r r ..r of too a ,r 9s CO • N- 00 •N- (0 M O O N e —I 1I U? In M3 N N M .. .4 x s 0 N N N N C O ❑ ❑ ❑ ❑ CO ❑ ❑ ❑ > o — • — 004£1 CL 0 000 Z0 00 c 8 4.' O • c U b E H • tl yydea 1001.00A erul weySAg oo4z1 Q ' i iU ORIGiNAL Closest in POOL Closest Approach: Reference Well: CD2-77wp05 Plan Offset Well: CD2-58 Cads.- I Cmw.- ASP View ASP View 30 ctrctr Mem. Incl. TRUE Subset N(+y5(-) VS Mea. Incl. TRUE Subsea N(4y54) VS Distce. Depth Angle Azi. ND E(+yW(-) (1601 Comments Depth Angle An. ND E(s(W(-) (1601 Cameros Distxce(867.37 R) Distance(867.378) in POOL(10348- inPOOL(18M8- 231303.9M3)to 236083 ND). CO2-88(12129- CD2-77wp05 Plan 867.37 168484 77.91 15318 717801 5960129 1516236 14376.1 16389 M3) 16389 97.14 150.87 718447 5981216 1515870 135134(12129-16389MD( Closest Approach: Reference Well: CD2-77wp05 Plan Offset Well: CD4-208 Corms.- Corms.- ASP View ASP View 3-0 ace Meas. Ind. TRUE Subsea N(+ys(-) VS Meas. Incl. TRUE Subsea N(+ys(-) VS Duce. Depth Angle At. ND E(+MW(-) (1601 Comments Dep. Angle An. ND E(+yW(-) (1601 Canzrad. Distance(1301 36 Distance(1301.38 ft)in POOL(6100- fl)inPOOL(6100- Nanuq cut depth 62WNDaa)to 6200 NDss)to CD4-208(7314- 002-7751305 Plan 1301.4 14050 88.93 154.07 619438 59628521 1515130 11771.8 12792 M3( 12792 88.75 330.23 612133 5961506 1515210 13023.8(7314-12792 113) Closest Approach: Reference Well: CD2-77wp05 Plan Offset Well: Nanuk 1 Cads- Cones.- ASP View ASP View 30 cad Max. Ind. TRUE Subsea N(+)'S(-) VS Maas. 802 TRUE Subsea 6(+)5(-) VS Metros. Depth Angle An. ND E(+y9(-) (1601 Convents Depth Ar19e An. ND E(+yi(-( (1W) Cmnaib Tsnn ism POOL Mn Distance(152726 Distance(1527.26 8)in POOL(18848 ft)in POOL(16843 Alpine1'cut depth 23603.83 M3)to 23603.63 M3 j to CD2-7/51305 Plan Nand,1(710)- (7100-7330 -.3 20700 90.09 15571 721985 5956907 1517785 182109 7300 72055) 724767 0.48 4855 721846 5957507 7519189 .492 NDss) Closest Approach: Reference Well: CD2-77wp05 Plan Offset Well: CD2-57 team.- Goads.- ASP ad.- ASP View ASP View 30 ad Mme. Incl. 1RUE Subsea Nuys(-) VS Meas. Incl. TRUE Stem Nuys(-) vs Distance. Depth Angle An. ND E(+yW(-) (1607 Garments Depth Angle An. ND E4yW(-j (1801 Cunnerrs Distance(1547.25 Distance(1547.25 5(in POOL(16848- R)in POOL)1%48- 23E03.83 ND)to 23603.83 M3)to CO257(12642- CD2-77wp05 Plan '.3 168484 7791 153.18 7178.01 5980429 1518236 14376.1 1649 M3) 18433 8872 151.32 7243.07 5961497 1517356 137309(12642-16433 MD) Closest Approach: Reference Well: CD2-77wp05 Plan Offset Well: CD2-36 Cpam.- Cpam.- ASP View ASP View 343 td Mas. Ind. TRUE Subsea 5(+)54) VS Mam. Incl. TRUE Subsea N(+)S(4 VS sabre Depth Arae Azi. ND E(5W)-) (1601 Cameo Depth Angle AR. ND 6(5),W)-) (1501 Comments Distance(1598.65 Distance(1598.60 tt)in POOL(16848- 1t)in POOL(10848 2350383 M3)to 23803.83 1.43)03 CD286(13523- CD2-7751305 Plan 1598.7 16648.4 7791 153.18 717601 596045 1516236 14376.1 17663''C') 17663 86.11 150.74 729.71 5960148 1514867 14132.8(13521-1750 3 13) Closest Approach: Reference Well: CD2-77wp05 Plan Offset Well: CD4-320 Cads- Cpam.- ASP View ASP View V's 3-0 ctrl Meas. Incl. TRUE Subsea N(+)S(-) VS Was, Incl. TRUE Subsea Nuys(-) VS Distance. Depth Argle Azi. ND E(e(W(-) (1501 Comments Depth Ange Azi. ND E(+yW(-) (1601 Corrrents Distance(4332.96 eistce(4332.96 ft)in POOL(W W- 2)In POOL(895- Kuparuk cut depth 7000 NDss)to 7000 NDss)to CD4321(8145- CD2-77wp05 Plan 4333 16277 6893 154.07 699501 596091811515006 13838.8 14471 M3) 8120.08 90.95 188.22 6934.76 597548 1518729 52.31 (8145-14471 LD) Closest Approach: Reference Well: CD2.77wp05 Plan Offset Well: CD4-209 Caxm.- Cam.- ( ASP View ASP View 30 ctrl Mea. Incl. TRUE Subsea N(+y5(-) VS Meas. Incl. TRUE Subsea N(+yS(-) VS Distance. Depth Angle An. ND E(+MW(-) (1801 0011111ets Depth Ar9e An. ND 6(5(W)-) (1607 Comments Distance(8177.34 Disace(8171.34 Nanuq cut depth tin POOL n0 POOL 6200 CD4-209(6995- CD277wp05 Plan 8177.3 14050 6893 15407 6196.38 5962802 1515130 11771.8 13215 153) 6970.14 60.38 153.23 8141.18 5355133 1517965 1959.34 0'95-1321"0( CD2-7751305 Pp4Surm a y.xls 1222010 10:28 AM OR\ GNAL O N O d M f 0 m o_ 0 E ¢' a Op N N v 0 p H U U U U O O1 moomm nv� �uminr'Nr�m O ��\ - O NOONy mA666L66MApim ,-11,111 ` > {OAmmmmAm�VOm oAGOmm ONUo ,�\ /!� Fy mmmV V VmmmN \\\ /Iry//I N tml o 0 0 0 A o m A O N N o 0 m 0 y oo oomoaoomo v,omo 1�. /. o ty LLOOmOmOm4C OmOm0 rr�� X777 r m N m m m " 3'ri_ y m0000m00000m0000 ��� � I'` a m O O m N?0 0 0 0 0 0 0 0 0 0 J pOO�NmONOmNNONO I .�� d r W 300NNNmmNm H ,Vni '���,•�•� p '''60 jo�anumi�ongvm __________ U i OZ + N�mIONNmNNAP o `4'. 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IL` PIN"' i I.:2JECT \ �' ,,,,,,,,ivi THIS SURVEY 2 DRILL SITE CD-2 \-'� /_/ T7 ///J� ® Z � -Z- 0 ( ( )' ALPINE SATELLITE DEVELOPMENT ( VICINITY vAP r,,,,An NOT TO SCALE ASPC f\ 4 yo�iii l PLANT N I'j'1 iii c1 06'03'45" ` j41 11. �ll qR a LCAIF CD—2f- ...� U PAD Elia.t� tcc o a ILtiII \ 5 ; " .w N 41' — QANNIK 1:41'i CONDUCTORS 1 ET (TYP) sa imiu, __-, ' i-r 1"1— ar. 1 • • • • ....................• •3iJej I NN O j l I cV NNN p., ,p4,p4 V V U U U 'U U V U U U U U U U DESIGN SHOULDER QANNIK PAD LEGEND: � I.CMF KUUKPIK O PROPOSED CONDUCTOR 'ydLLC • EXISTING CONDUCTOR WY E61tAr•. AMopwAW 1111309 (Y07)670-B39 Apiere Om�x I98])6Soa]39 Alpine Survey Office y/ ALPINE MODULE:CD20 UNIT:QNK ConocePhil lips ALPINE PROJECT QANNIK WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CADD FILE NO. 1 DRAWING NO: PART: REV: 07-02-18-1 41/07 CE—CD20-139 I 1 of 3 I 2 REV DATE BY CK APP _ DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 4/18/07 CZ DB C.A. ISSUED PER K07041ACS 2 4/21/08 CZ GD C.A. UPDATED PER K080010ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.2, T 11 N, R 4 E, U.M. SEC.LINE 0/S EXIST WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND 'PAD CD2-461 5,973,927.48 1,511,501.61 70' 20' 14.465" 151' 02' 45.814" 3099' 1765' 8.3 15.7 CD2-462 5,973,925.28 1,511,481.66 70' 20' 14.440" 151' 02' 46.395" 3096' 1785' 8.3 15.7 CD2-463 5,973,923.32 1,511,461.85 70' 20' 14.417" 151' 02' 46.973" 3094' 1805' 8.3 15.7 CD2-464 5,973,921.12 1,511,442.08 70' 20' 14.392" 151' 02' 47.549" 3091' 1825' 8.3 15.7 CD2-465 5,973,919.18 1,511,422.01 70' 20' 14.370" 151' 02' 48.134" 3089' 1845' 7.8 15.7 CD2-466 5,973,916.76 1,511,402.40 70' 20' 14.343" 151' 02' 48.706" 3086' 1864' 7.8 15.7 CD2-467 5,973,915.01 1,511,382.20 70' 20' 14.322" 151' 02' 49.295" 3084' 1884' 7.9 15.7 CD2-468 5,973,912.62 1,511,362.41 70' 20' 14.295" 151' 02' 49.872" 3081' 1904' 7.9 15.6 CD2-469 5,973,910.54 1,511,342.61 70' 20' 14.271" 151' 02' 50.449" 3079' 1924' 8.0 15.6 CD2-470 5,973,908.62 1,511,322.72 70' 20' 14.249" 151' 02' 51.029" 3077' 1944' 8.0 15.6 CD2-471 5,973,906.37 1,511,302.77 70' 20' 14.224" 151' 02' 51.610" 3074' 1964' 8.1 15.6 CD2-72 5,973,904.22 1,511,282.90 70' 20' 14.199" 151' 02' 52.189" 3072' 1984' 8.1 15.6 CD2-73 5,973,902.15 1,511,262.95 70' 20' 14.175" 151' 02' 52.771" 3069' 2003' 8.2 15.6 CD2-74 5,973,899.86 1,511,243.06 70' 20' 14.150" 151' 02' 53.351" 3067' 2023' 8.3 15.6 CD2-75 5,973,897.83 1,511,223.26 70' 20' 14.126" 151' 02' 53.928" 3064' 2043' 8.4 15.6 _ CD2-x76 5.793.895.84 1.511.203.39 70'20' 14.103" 151' 02' 54.507" 306 2063' 8.4 15.6 CD2-x77 5,973,893.62 1,511,183.28 70' 20' 14.078" 151' 02' 55.094" 3059 2083' 8.4 15.6 CD2-x/8 5,9/3,891.66 1,511,165.81 /0" 20 14.055 151" 02 55.661- 305/ 2105 8.4 15.b 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.) KUUKPIK WIN N + % wu*M..MINIM MINIM•e.)s►wM Alpine Survey Office y� ALPINE MODULE:CD20 UNIT:ONK C.noc•Phillips ALPINE PROJECT QANNIK WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 07-02-18-1 4/2/07 CE-CD20-139 2 OF 3 2 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME ae6( (j(J 2 ` 77 PTD# 2 i r) ( � V Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: a 7;'6 &_ POOL: CA77�� t y C/ lJ 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 (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to 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. 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: 1/11/2008 ❑ P To0 0) o a) a 0 0 a) o Q v; 0 c L O @ ui > L .0 ° LO ° E p 0 M g as L c, E 0-a C J a)R. �- O a) ° M E O 0 o c O °c) a. 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C L o # ° c = _ 0 a)a) 3 E _ 3 0 O a) co 0 U > 0_ C C ',- O CI O w a) a) @ Q i) cococn rn 2 E o N '@o @ Q) V) 0 a N °U li N a J c > C L ,t a 7 0 a) 7 `O T c 7 0) y @ 0- C -o V) V) CO II ! °TD a) N !; 1I -rn 0 >- @ 0 ° o c�)- 3 o m@ m T .. p E a) @ .5 ° M o O 7 w n L U a@ 7 3 cn c 0) L V) Q LO c < co Z o a` o m -o o a) c a@ a) `0 D o c ° CO 0 ° p) ° a L C a)a' c °, M E E "° c C E @ `) o C C V) au _ -C E N 1 ) a c a) L m �- N L a C C YC./) o 0 0 -0 ° m °) n o 0 0 ° °) 7 U 'n a a) - 0 ai a ° 3 0 a cn Y Q o .0 o a) a) c > o a@ C m —c° 0 0 a) @ O E .� — — < m o rn o m J E a ° ° a)c — ..-. -C -0 0 o a) C — a Z o E 3 0 2 a) L m 3 !.. S1) E E m a ami 0 N m a o. @ L r @@ 7o ami v@i E c m `� @ N v ° w 0 0 m a>i o C o o a o a D .c .0 22 -° 3 3 > ° °) .. '° w 0 7 a oo c� n 'Q C@ ° 3 o L Z U d c ° c ° ° > ° a) a ° ° o@ o ° 0 o o C 0- 0 w a a) @ o ° c a aCO 7 a) ° -o @ C @ L U O a) N Y a) O E E E L o a) ° C J U ° a -0 a) a) O N 7 7 CL C V ° a o 0 "° a) `- N -p 2 E o) O 7 C O 0 atS L a o a s a V) N a L @ @ o) C U 3 N -o V! O c L -0 = U@ E@ o o m 3 m@@ .� c 03 o @ n N _� o m a = C ( o @ 0 .N a N CL O) �6 a) C .0 a a a) V) T N Q 3 L -° L C 0 0 > D) c @ a) O' °_ c,.,' U p OU a) 4.) >. N a @ L — 'o 'O "o U ' c @ 'o a) 7) .N �6 L N V) U L C @ C E U C E. 0. 0 0 @ -0 0 L c c = a 0 @ -° -° UO W — 3 0 V) .c 0 U (0 C a) C. o @ F- O > ) 7 3 0 @ CO c a) 0) 0) E @ 3 -70 0 ° @ @ _ -00 •,_ °: a) = 'O E @ = c 2 @ V) @ U C Z C C U U U ` o 'RU cn i) ai o o @ - @ a E a) C U o U -0 CO O ° .-r j O O O .� ICI) !' .'E E O ° 7 U > > 3 7 7 N W W a) 3 V) @ a 'La) 6 >, 0 aa) aa)) 'c a) a) a) a -00 0. a aa.) a`) m ° 3 m 0 3 2 2 2 m -oo @ -00 -o = O O r ° ° a°) a`) c a a@) o p V C z a J D S co 4- O O a a U Q d U cn U U U U Q taQ = o m m O g a a cn cn U W a r N co V LU co N- CO 0) O • N M V Ut0 CO 0) O N N M 7 UNC) O rN NN 0N O M N M A M COM cr.', M M0) UO O O L.. d Oa) ON 0 O C O c R N 10 p co N U o 1i a) o 0 C O .- G a0 00) C � J o N a4) rn 0 0 o aL J ° a oW E Clo) — Q a U ` < ' � a Ua wc Well History File AP .1" E N X 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 Feb 09 14:55:27 2011 Reel Header Service name LISTPE Date 11/02/09 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 11/02/09 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: CD2-77 API NUMBER: 501032062900 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 09-FEB-11 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: AK-MW-776043 AK-MW-776043 AK-MW-776043 LOGGING ENGINEER: PAUL ORTH PAUL ORTH JESSE BOBBIT OPERATOR WITNESS: DAVE BURLEY DAVE BURLEY DAVE BURLEY MWD RUN 4 MWD RUN 6 JOB NUMBER: AK-MW-776043 AK-MW-776043 LOGGING ENGINEER: JESSE BOBBIT PAUL ORTH OPERATOR WITNESS: DAVE BURLEY DON MICKEY SURFACE LOCATION SECTION: 2 TOWNSHIP: 11N RANGE: 4E FNL: 2219 FSL: 0/0 — tq9 00%3 FEL: 2083 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 52.20 GROUND LEVEL: 15.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 24 .000 114.0 2ND STRING 9.880 10.750 3390.0 3RD STRING 6.750 7.625 17344.0 PRODUCTION STRING 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 RUNS 1-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase4) , DRILLSTRING DYNAMICS SENSOR (DDSr) , AND AT-BIT INCLINATION RUN BEHIND A PERFORMANCE DRILL MOTOR (PDM) . 4. MWD RUN 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase4) , AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , DRILLSTRING DYNAMICS SENSOR (DDSr) , PRESSURE WHILE DRILLING (PWD) , AND BI-MODAL ACOUSTIC (BAT)RUN BEHIND A GEOPILOT ROTARY-STEERABLE BHA (GP) . 4. MWD RUN 5 NO FOOTAGE DRILLED - NO DATA ARE PRESENTED. 5. MWD RUN 6 COMPRISED DIRECTIONAL, GAMMA MODULE (GM) UTILIZING SCINLATION DETECTORS, AZIMUTHAL DEEP RESISTIVITY (ADR) , PRESSURE WHILE DRILLING (PWD) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) , RUN BEHIND A GEOPILOT ROTARY-STEERABLE BHA (GP) . 6. 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. 7. MWD RUNS 1-4, 6 REPRESENT WELL CD2-77 WITH API#: 50-103-20629-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 22658'MD, 7361'TVD. MNEMONIC CURVE DESCRIPTION R09P 9in Phase Resistivity R15P 15in Phase Resistivity R27P 27in Phase Resistivity R39P 39in Phase Resistivity EWXT EWR Formation Exp Time ROPA Avg Rate of Penetration DGRC DGR Combined Gamma Ray APEL ALD LCRB Pe Factor ACDL ALD LCRB Comp Density ADCL ALD LCRB Den Correction TNPS CTN Porosity Sandstone TNFA CTN Far Avg Count Rate TNNA CTN Near Avg Count Rate BTCS BAT Comp Slowness BCSS BAT Comb Shear Slowness BVPS BAT VP/VS Ratio AM3P Avg 48in 500k Phase Res AM3A Avg 48in 500k Atten Res AM2P Avg 32in 500k Phase Res AM2A Avg 32in 500k Atten Res AM1P Avg 16in 500k Phase Res AL3P Avg 48in 125k Phase Res AL3A Avg 48in 125k Atten Res AH3P Avg 48in 2M Phase Res AH3A Avg 48in 2M Atten Res AH2P Avg 32in 2M Phase Res AH2A Avg 32in 2M Atten Res AH1P Avg 16in 2M Phase Res PARAMETERS USED IN POROSITY LOG PROCESSING: PARAMETER MWD RUN 4 HOLE SIZE: FIXED 9.875" MUD WEIGHT: 9.6 - 10.5 PPG MUD SALINITY: 400-700 PPM CL FORMATION WATER SALINITY: 23000 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2. 65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR ROPA AND DGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. EXCEPT FOR BTCS, BCSS, BVPS. THESE CURVES ARE SMOOTHED WITH A 2.0 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 11/02/09 Maximum Physical Record65535 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 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 104 .5 17318.5 RPX 104.5 17318.5 FET 104.5 22613.5 RPS 104.5 17318.5 RPM 104.5 17318.5 GR 104.5 22583.0 ROP 114.5 22658.0 RHOB 3380.5 17279.0 NPHI 3380.5 17265.5 PEF 3380.5 16872.5 DRHO 3380.5 16872.5 NCNT 3380.5 17265.5 FCNT 3380.5 17265.5 CALN 3380.5 16872.5 DTC 3399.0 17250.0 SCRA 4521.0 17250.0 DTSH 4521.0 17250.0 AH2A 17334.0 22612.5 AL3A 17334.0 22612.5 AH3P 17334.0 22612.5 AH3A 17334.0 22612.5 AH2P 17334.0 22612.5 AH1P 17334.0 22612.5 AM3A 17334.0 22612.5 AM2P 17334.0 22612.5 AM2A 17334.0 22612.5 AM1P 17334.0 22612.5 AL3P 17334.0 22612.5 AH1A 17334.0 22612.5 AM1A 17334.0 22612.5 AM3P 17334.0 22612.5 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 1 114 .0 550.0 MWD 2 550.0 920.0 MWD 3 920.0 3400.0 MWD 4 3400.0 17359.0 MWD 6 17359.0 22658.0 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 RHOB MWDMW G/CC 4 1 68 4 2 DRHO MWDMW G/CC 4 1 68 8 3 CALN MWDMW IN 4 1 68 12 4 PEF MWDMW B/E 4 1 68 16 5 AH1A MWDMW OHMM 4 1 68 20 6 AH1P MWDMW OHMM 4 1 68 24 7 AH2A MWDMW OHMM 4 1 68 28 8 AH2P MWDMW OHMM 4 1 68 32 9 AH3A MWDMW OHMM 4 1 68 36 10 AH3P MWDMW OHMM 4 1 68 40 11 AL3A MWDMW OHMM 4 1 68 44 12 AL3P MWDMW OHMM 4 1 68 48 13 AM1A MWDMW OHMM 4 1 68 52 14 AM1P MWDMW OHMM 4 1 68 56 15 AM2A MWDMW OHMM 4 1 68 60 16 AM2P MWDMW OHMM 4 1 68 64 17 AM3A MWDMW OHMM 4 1 68 68 18 AM3P MWDMW OHMM 4 1 68 72 19 DTC MWDMW USPF 4 1 68 76 20 DTSH MWDMW USPF 4 1 68 80 21 SCRA MWDMW NONE 4 1 68 84 22 GR MWDMW API 4 1 68 88 23 FET MWDMW HR 4 1 68 92 24 RPX MWDMW OHMM 4 1 68 96 25 RPS MWDMW OHMM 4 1 68 100 26 RPM MWDMW OHMM 4 1 68 104 27 RPD MWDMW OHMM 4 1 68 108 28 ROP MWDMW FPH 4 1 68 112 29 FCNT MWDMW CP30 4 1 68 116 30 NCNT MWDMW CP30 4 1 68 120 31 NPHI MWDMW PU 4 1 68 124 32 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 104 .5 22658 11381.3 45108 104.5 22658 RHOB MWDMW G/CC 0.74 3.029 2.39899 27786 3380.5 17279 DRHO MWDMW G/CC -2.132 0.299 0.0296113 26985 3380.5 16872.5 CALN MWDMW IN 8.25 16.66 9.65022 26985 3380.5 16872.5 PEF MWDMW B/E 1. 91 13.46 3.5001 26985 3380.5 16872.5 AH1A MWDMW OHMM 0.03 33 14.2855 10558 17334 22612.5 AH1P MWDMW OHMM 0.02 3252.06 11.749 10558 17334 411 22612.5 AH2A MWDMW OHMM 0.44 5000 22.402 10558 17334 22612.5 AH2P MWDMW OHMM 0.02 2345. 63 7.54401 10558 17334 22612.5 AH3A MWDMW OHMM 0. 15 5000 23.8736 10558 17334 22612.5 AH3P MWDMW OHMM 0.02 5000 15.9704 10558 17334 22612.5 AL3A MWDMW OHMM 0.14 2000 39.8443 10558 17334 22612.5 AL3P MWDMW OHMM 0.02 2000 14.2678 10558 17334 22612.5 AM1A MWDMW OHMM -1 2000 22.4769 10558 17334 22612.5 AM1P MWDMW OHMM 3.3 1622.45 11.6193 10558 17334 22612.5 AM2A MWDMW OHMM 0.04 2000 625.496 10558 17334 22612.5 AM2P MWDMW OHMM 0.02 2000 67.6616 10558 17334 22612.5 AM3A MWDMW OHMM 1.72 2000 17.7638 10558 17334 22612.5 AM3P MWDMW OHMM 0.04 2000 15.3599 10558 17334 22612.5 DTC MWDMW USPF 71.7756 136.47 94.7961 27703 3399 17250 DTSH MWDMW USPF 132.362 227.975 175.812 25241 4521 17250 SCRA MWDMW NONE 1.4968 2.7012 1. 90145 25241 4521 17250 GR MWDMW API 20.8 472 97.8228 44952 104 .5 22583 FET MWDMW HR 0.12 216.71 0.899217 44885 104 .5 22613.5 RPX MWDMW OHMM 0. 97 1433. 93 6.27996 34338 104 .5 17318.5 RPS MWDMW OHMM 0.53 1754.8 7.06275 34338 104.5 17318.5 RPM MWDMW OHMM 0.08 1436.02 8.11967 34338 104.5 17318.5 RPD MWDMW OHMM 0.07 2000 9.9565 34338 104.5 17318.5 ROP MWDMW FPH 0 573.63 173.766 45088 114.5 22658 FCNT MWDMW CP30 495.36 2075.6 883.821 27771 3380.5 17265.5 NCNT MWDMW CP30 109041 176430 138034 27771 3380.5 17265.5 NPHI MWDMW PU 11.31 60.86 28.6938 27771 3380.5 17265.5 First Reading For Entire File 104.5 Last Reading For Entire File 22658 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/09 Maximum Physical Record65535 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 11/02/09 Maximum Physical Record65535 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH R15P 104 .5 484 .5 RO9P 104 .5 484.5 R27P 104.5 484.5 R39P 104.5 484.5 EWXT 104.5 484.5 DGRC 104.5 492.5 ROPA 114 .5 550.0 $ LOG HEADER DATA DATE LOGGED: 03-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 550.0 TOP LOG INTERVAL (FT) : 114.0 BOTTOM LOG INTERVAL (FT) : 550.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .4 MAXIMUM ANGLE: 2.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 230386 EWR4 EWR-Phase 4 113423 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 13.500 DRILLER'S CASING DEPTH (FT) : 114.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 8.70 MUD VISCOSITY (S) : 60.0 MUD PH: 9.2 MUD CHLORIDES (PPM) : 600 FLUID LOSS (C3) : 16.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.300 79.0 MUD AT MAX CIRCULATING TERMPERATURE: 2. 940 60.2 MUD FILTRATE AT MT: 2.100 79.0 MUD CAKE AT MT: 2.750 79.0 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 GR MWD010 API 4 1 68 4 2 FET MWD010 HR 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 104.5 550 327.25 892 104 .5 550 GR MWD010 API 20.8 90.24 45.7264 777 104 .5 492.5 FET MWD010 HR 0.38 216.71 6.24767 761 104.5 484.5 RPX MWD010 OHMM 1.8 63.55 17.9359 761 104.5 484.5 RPS MWD010 OHMM 1.9 146.94 29.4057 761 104.5 484.5 RPM MWD010 OHMM 1.85 312.91 46.2702 761 104.5 484 .5 RPD MWD010 OHMM 2.09 1906. 65 75.4805 761 104 .5 484.5 ROP MWD010 FPH 0 573. 63 146.464 872 114 .5 550 First Reading For Entire File 104 .5 Last Reading For Entire File 550 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/09 Maximum Physical Record65535 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 11/02/09 Maximum Physical Record65535 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH EWXT 485.0 854.0 R09P 485.0 854.0 R39P 485.0 854.0 R27P 485.0 854.0 R15P 485.0 854.0 DGRC 493.0 862.0 ROPA 550.5 920.0 LOG HEADER DATA DATE LOGGED: 03-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 920.0 TOP LOG INTERVAL (FT) : 550.0 BOTTOM LOG INTERVAL (FT) : 920.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .4 MAXIMUM ANGLE: 2.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 230386 EWR4 EWR-Phase 4 113423 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 13.500 DRILLER'S CASING DEPTH (FT) : 114.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 8.80 MUD VISCOSITY (S) : 60.0 MUD PH: 9.2 MUD CHLORIDES (PPM) : 600 FLUID LOSS (C3) : 16.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.300 79.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.804 102.6 MUD FILTRATE AT MT: 2.100 79.0 MUD CAKE AT MT: 2.750 79.0 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 GR MWD020 API 4 1 68 4 2 FET MWD020 HR 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 485 920 702.5 871 485 920 GR MWD020 API 21.59 100. 98 48.9505 739 493 862 FET MWD020 HR 0.51 6.87 2.26806 739 485 854 RPX MWD020 OHMM 1.23 36.43 13.3482 739 485 854 RPS MWD020 OHMM 1.16 70.83 21.6276 739 485 854 RPM MWD020 OHMM 1.11 256.3 34.1786 739 485 854 RPD MWD020 OHMM 1.07 1760.5 45.8733 739 485 854 ROP MWD020 FPH 0 257. 63 123.29 740 550.5 920 First Reading For Entire File 485 Last Reading For Entire File 920 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/09 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/09 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 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 R15P 854.5 3334.5 R39P 854.5 3334.5 R27P 854.5 3334.5 R09P 854.5 3334.5 EWXT 854.5 3334.5 DGRC 862.5 3343.0 ROPA 920.5 3400.0 $ LOG HEADER DATA DATE LOGGED: 05-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 3400.0 TOP LOG INTERVAL (FT) : 920.0 BOTTOM LOG INTERVAL (FT) : 3400.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 145. 6 MAXIMUM ANGLE: 70.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 230386 EWR4 EWR-Phase 4 113423 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 13.500 DRILLER'S CASING DEPTH (FT) : 114.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 9.00 MUD VISCOSITY (S) : 300.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.300 78.8 MUD AT MAX CIRCULATING TERMPERATURE: 1.800 102. 6 MUD FILTRATE AT MT: 2.000 78.8 MUD CAKE AT MT: 2.800 78.8 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 GR MWD030 API 4 1 68 4 2 FET MWD030 HR 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 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 854.5 3400 2127.25 5092 854.5 3400 GR MWD030 API 24.63 203.52 111.506 4962 862.5 3343 FET MWD030 HR 0.3 5.38 0.983072 4961 854.5 3334 .5 RPX MWD030 OHMM 1.26 24.08 3.42022 4961 854.5 3334.5 RPS MWD030 OHMM 1.21 42 3. 92548 4961 854 .5 3334.5 RPM MWD030 OHMM 1.18 74.39 4.51643 4961 854 .5 3334.5 RPD MWD030 OHMM 1.24 92.63 4.82132 4961 854 .5 3334.5 ROP MWD030 FPH 0.02 510.49 140.27 4960 920.5 3400 First Reading For Entire File 854.5 Last Reading For Entire File 3400 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/09 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/09 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 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 DGRC 3345.5 17354.0 ADCL 3380.5 16872.5 R39P 3380.5 17318.5 APEL 3380.5 16872.5 EWXT 3380.5 17318.5 R27P 3380.5 17318.5 AHSI 3380.5 16872.5 TNFA 3380.5 17265.5 R15P 3380.5 17318.5 R09P 3380.5 17318.5 TNPS 3380.5 17265.5 TNNA 3380.5 17265.5 ACDL 3380.5 17279.0 BTCS 3399.0 17250.0 ROPA 3400.5 17359.0 BCSS 4521.0 17250.0 BVPS 4521.0 17250.0 LOG HEADER DATA DATE LOGGED: 16-JAN-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 17359.0 TOP LOG INTERVAL (FT) : 3400.0 BOTTOM LOG INTERVAL (FT) : 17359.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 67.8 MAXIMUM ANGLE: 83.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 218745 EWR4 EWR-Phase 4 10505932 CTN Compensated Thermal 245542 ALD Azimuthal Litho 10603721 BAT Bi-Modal Acoustic 11492328 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.875 DRILLER'S CASING DEPTH (FT) : 3390.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) : 9. 60 MUD VISCOSITY (S) : 16.0 MUD PH: 10.1 MUD CHLORIDES (PPM) : 600 FLUID LOSS (C3) : 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.600 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 18.144 162.6 MUD FILTRATE AT MT: 1.300 70.0 MUD CAKE AT MT: 2.200 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 .lIN 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 RHOB MWD040 G/CC 4 1 68 4 2 DRHO MWD040 G/CC 4 1 68 8 3 CALN MWD040 IN 4 1 68 12 4 PEF MWD040 B/E 4 1 68 16 5 DTC MWD040 USPF 4 1 68 20 6 DTSH MWD040 USPF 4 1 68 24 7 SCRA MWD040 NONE 4 1 68 28 8 GR MWD040 API 4 1 68 32 9 FET MWD040 HR 4 1 68 36 10 RPX MWD040 OHMM 4 1 68 40 11 RPS MWD040 OHMM 4 1 68 44 12 RPM MWD040 OHMM 4 1 68 48 13 RPD MWD040 OHMM 4 1 68 52 14 ROP MWD040 FPH 4 1 68 56 15 FONT MWD040 CP30 4 1 68 60 16 NCNT MWD040 CP30 4 1 68 64 17 NPHI MWD040 PU 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3345.5 17359 10352.3 28028 3345.5 17359 RHOB MWD040 G/CC 0.74 3.029 2.39899 27786 3380.5 17279 DRHO MWD040 G/CC -2. 132 0.299 0.0296113 26985 3380.5 16872.5 CALN MWD040 IN 8.25 16. 66 9.65022 26985 3380.5 16872.5 PEF MWD040 B/E 1. 91 13.46 3.5001 26985 3380.5 16872.5 DTC MWD040 USPF 71.7756 136.47 94.7961 27703 3399 17250 DTSH MWD040 USPF 132.362 227.975 175.812 25241 4521 17250 SCRA MWD040 NONE 1.4968 2.7012 1.90145 25241 4521 17250 GR MWD040 API 42.21 472 116.123 28018 3345.5 17354 FET MWD040 HR 0.12 85.26 0.639166 27877 3380.5 17318.5 RPX MWD040 OHMM 0.97 1433. 93 6.28332 27877 3380.5 17318.5 RPS MWD040 OHMM 0.53 1754.8 6. 62502 27877 3380.5 17318.5 RPM MWD040 OHMM 0.08 1436.02 7.02864 27877 3380.5 17318.5 RPD MWD040 OHMM 0.07 2000 8.12952 27877 3380.5 17318.5 ROP MWD040 FPH 1.38 418.83 216.737 27918 3400.5 17359 FONT MWD040 CP30 495.36 2075.6 883.821 27771 3380.5 17265.5 NCNT MWD040 CP30 109041 176430 138034 27771 3380.5 17265.5 NPHI MWD040 PU 11.31 60.86 28.6938 27771 3380.5 17265.5 First Reading For Entire File 3345.5 Last Reading For Entire File 17359 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/09 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 Physical EOF File Header Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/09 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH AM1P 17334.0 22612.5 AH1A 17334.0 22612.5 AH1P 17334 .0 22612.5 AH2A 17334 .0 22612.5 AH2P 17334.0 22612.5 AH3A 17334 .0 22612.5 AH3P 17334 .0 22612.5 AL3P 17334 .0 22612.5 AM1A 17334.0 22612.5 AM2A 17334.0 22612.5 AM2P 17334.0 22612.5 AM3A 17334.0 22612.5 AM3P 17334.0 22612.5 AL3A 17334.0 22612.5 EWXT 17340.5 22613.5 DGRC 17354 .5 22583.0 ROPA 17359.5 22658.0 LOG HEADER DATA DATE LOGGED: 31-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 22658.0 TOP LOG INTERVAL (FT) : 17359.0 BOTTOM LOG INTERVAL (FT) : 22658.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 84.2 MAXIMUM ANGLE: 91.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Gamma Module 93091 ADR Azimuthal Deep Res 11425890 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.750 DRILLER'S CASING DEPTH (FT) : 17344.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Bas MUD DENSITY (LB/G) : 9.00 MUD VISCOSITY (S) : 63.0 MUD PH: .0 MUD CHLORIDES (PPM) : 55000 FLUID LOSS (C3) : .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 176.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 AH1A MWD060 OHMM 4 1 68 4 2 AH1P MWD060 OHMM 4 1 68 8 3 AH2A MWD060 OHMM 4 1 68 12 4 AH2P MWD060 OHMM 4 1 68 16 5 AH3A MWD060 OHMM 4 1 68 20 6 AH3P MWD060 OHMM 4 1 68 24 7 AL3A MWD060 OHMM 4 1 68 28 8 AL3P MWD060 OHMM 4 1 68 32 9 AM1A MWD060 OHMM 4 1 68 36 10 AM1P MWD060 OHMM 4 1 68 40 11 AM2A MWD060 OHMM 4 1 68 44 12 AM2P MWD060 OHMM 4 1 68 48 13 AM3A MWD060 OHMM 4 1 68 52 14 AM3P MWD060 OHMM 4 1 68 56 15 GR MWD060 API 4 1 68 60 16 FET MWD060 HR 4 1 68 64 17 ROP MWD060 FPH 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 17334 22658 19996 10649 17334 22658 AH1A MWD060 OHMM 0.03 33 14 .2855 10558 17334 22612.5 AH1P MWD060 OHMM 0.02 3252.06 11.749 10558 17334 22612.5 AH2A MWD060 OHMM 0.44 5000 22.402 10558 17334 22612.5 AH2P MWD060 OHMM 0.02 2345.63 7.54401 10558 17334 22612.5 AH3A MWD060 OHMM 0.15 5000 23.8736 10558 17334 22612.5 AH3P MWD060 OHMM 0.02 5000 15. 9704 10558 17334 22612.5 AL3A MWD060 OHMM 0.14 2000 39.8443 10558 17334 22612.5 AL3P MWD060 OHMM 0.02 2000 14.2678 10558 17334 22612.5 AM1A MWD060 OHMM -1 2000 22.4769 10558 17334 22612.5 AM1P MWD060 OHMM 3.3 1622.45 11.6193 10558 17334 22612.5 AM2A MWD060 OHMM 0.04 2000 625.496 10558 17334 22612.5 AM2P MWD060 OHMM 0.02 2000 67.6616 10558 17334 22612.5 AM3A MWD060 OHMM 1.72 2000 17.7638 10558 17334 22612.5 AM3P MWD060 OHMM 0.04 2000 15.3599 10558 17334 22612.5 GR MWD060 API 31. 13 106.89 49. 6168 10456 17354 .5 22583 FET MWD060 HR 0.37 19.41 1.0653 10547 17340.5 22613.5 ROP MWD060 FPH 1.23 546.04 82.0182 10598 17359.5 22658 First Reading For Entire File 17334 Last Reading For Entire File 22658 File Trailer Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/09 Maximum Physical Record65535 File Type LO Next File Name STSLIB.007 Physical EOF Tape Trailer Service name LISTPE Date 11/02/09 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 11/02/09 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
