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210-164
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. LJ Q - I Well History File Identifier Organizing(done) Two-sided III 11 E I III II III ❑ Rescan Needed liii I 11111 TRE AN DIGITAL DATA OVERSIZED (Scannable) C for Items: ❑ Diskettes, No. ❑ Map Greyscale Items: ❑ Other, No/Type: they Items Scannable by a Large Scanner ©GtS ❑ Poor Quality Originals: X11 OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: _r - Date: 5-) 1 /4L /s/ viqp Project Proofing II IIIIIIIII1 11111 BY: C Maria Date: 1Vitt /s/ 4 Scanning Preparation 14 x 30 = I cO + I� = TOTAL PAGES 131+ ( ount does not include cover sheet) BY: _ Maria Date: E pit l q." is, Production Scanning II IIIIIIIII1 11111 Stage 1 Page Count from Scanned File: I 3-SP (count does include cover sheet) Page Count Matches Number in Scanning Pre aration: VES NO BY: 4OP Date:31 14' /t /s/ r14 r 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. II 11111111 1111 ReScanned II 111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked MINIM o c j .@ j a_00 u_ )c> t> is o 9 -gym♦- ce O> O> C y p >. co (0 _ U a) 0 W Ca) m n o� N m Cl_ _O w W 3 a) 0 m 0 CO rn co _ m - W 0 E v = W o O _ _ J N i - 1-aw0 - ce a0 as;? Q0 (a coa -) C rn 0 c c0 co co 0 Nl pp c W Zhu 0 Q NaZS NQ ° f9 3 U O J J .O Q N a) dU� to 0 d0 - 5 0 E N = 7 o E as 14 E act c) c y 6 w? E (/� Li. 0 12J J p Cr CD 0 w CT CD a) CO E E E N - .0 N `n 0 E w��cCL OQ rtQ -W(71°.- 'SW0 Q a 0 � o 0 m _ ma C a 0 2z0 0_ Z 0Z m �a y.>. m c «4 u)2" Ii 0 0 0 0 0 o m Z Z V CC O 0 a m0 1- 1- c o a) 2 (a c o ca E WI Li- 0 > 0 > 0 0 )0 a cj ° 0tz 3 p) 20 I-U ii00a0 ii000 01- 2 1- 2 1- 2 2 a2 0 a) v J U d U N N N N O O O 0 0 0 O 0 N N W y N N N N N N N N O 0 2 N N N N N N N N N N M O ...) NN N N N N N N I Z ti ! o •- •- Q 7 j c C C c C C C C c C C C a) �[ 'c 2 2 1 a) a) a) a) a) a) a) a) a) a) a) a) H Q �° 0010 0 0 0 0 0 0 0 0 0 0 0 0 �/ 1i a C ca ca 0.jN N N N N 0 N O N N (O co p )n )n )n u� )n CO )n CO In CO )n In 0 p, 7 r M co M CO CO M M CO CO (0 CO M a J coco0) J W 2 0 0 — t ICD- C v v O o O O O O i) o o 0 NIN NCO co co O O a0 W z a ✓ 0 U D Z 8 � ' c 7 O 41:t 71 C4 7 0 w co 0 0 0 a)ii o 0 0 0 0 0 0 0 0 A L� N c ZI III J 2 0 0 0 0 0 0 0 0 0 g N y U) a) OQ (ClLoIn1.0 0 U N 0E E I J N N N N N N N N N 0) N CO J `Q` N 1--' Z O C 5� I- N /G� N W CC N Cl) 0 a) V� rx Q a Q a 0 a) Quct Z E W >_ >_ > Tum ID 0 pCC ! C N N 1 > > E J O Cl) U) N Z 3 CO �' �' Q' C C C w C C C W if_ O) 0) 0) 0) 0) 0) N 7 7 > 7 7 7 p. 0 -o D -o -o -o -o t (o Z co D U 0 a) y 7 7 7 7 7 7 a) )n CO J c c c d CI 0 ZJ w 0 .0 C)to )a O E o 0 TcE) i- I z 0 p W 0 Z N N N r0 2 o 14 € 0 v 0 M 0 0 0 a 2 O) w LL a) \ii E 5 a d _ �, 1 \ \0 y O u' a y all a 0 0 0 0 0 0 0 0) 0 0) O o a 1�''.,1 W Q I- 7. J O 1- �' W J J w J J J J J J J Q' 0 co 9 E oo o.J m o N N Co Z v 0 o 5 IIw NU j I, CIOC N Na) (6dp O I o y y Z o o= a la_IEl: Q O JN M Z A 16- c a) 1 Q E 2 � E R cn U o O CIQ E co O g o z z Q et 0 N w 0 V O U cn > �' cu m m Zy Ce Cl. Q CO O Ce Z Fo- y = o o O 6 = m O CO c a. Csi m 2 S N D ti 0 O 0_ '%1'• CB" N U J M Q J N N 10 G N d CO re N 5 Q p N 0 QEI Ci ID Z 01 z 1 C, ,II '"' O rte O C I N COO 0_ r. I cu Z o p °' € O . / m co r � r v N m p d E u. m z I m re o OMi, Z N N C CC �f' I o 0 o fy y o a) _ 0 = a N 0. W °' a 0 < CL 1 U 0 ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 15,2012 Commissioner Dan Seamount f ki-,)Alaska Oil& Gas CommissionI 333 West 7th Avenue, Suite 100 ..31 Anchorage,AK 99501 �1 L 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, Etietse_ 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) Kuparuk Field Date 5/15/2012 1C,1D,1E,2L,3H PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name APIA PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal -1C-133 50029230130000 2010770 16" 3.9 12" 5/8/2012 6.8 5/14/2012 1D-116 50029229150000 1981720 10" 1.2 10" 5/8/2012 4.3 5/15/2012 1E-123 50029232080000 2040740 5" n/a 18" n/a 5.1 4/9/2012 2L-304 50103206130000 2100110 31" 0.30 20" 3/30/2012 4.3 5/14/2012 2L-306 50103206300000 2101820 8" n/a 8" n/a 3.4 5/14/2012 2L-310 50103206160000 2100280 25" 0.25 12" 3/30/2012 2.6 5/14/2012 2L-312 50103206260000 2101640 13" n/a 13" n/a 2.5 5/14/2012 2L-319 50103205520000 2071120 112" 1.00 20" 3/30/2012 6 5/14/2012 2L-320 50103206270000 2101660 36' 1.00 50" 3/30/2012 3.4 5/14/2012 • 3H-17 50103200810000 1870990 19" n/a 19" n/a 3.4 4/9/2012 WELL LOG TRANSMITTAL D: Alaska Oil and Gas Conservation Comm. May 16, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 E: Perforating Record/Bottom Hole Pressure Survey: 2L-312 Run Date: 5/12/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2L-312 Digital Data in LAS format, Digital Log Image file LiI S1 Ck 1 CD Rom 50-103-20626-00 l Bottom Hole Pressure Survey Log 1 Color Log 50-103-20626-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: I Signed: lj A_ l u -( (P`f STATE OF ALASKA t I ALASKA._AND GAS CONSERVATION COMMISSI,. REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate F Other r Alter Casing r Pull Tubing r Pbrforate New Fool r Waiver r Time Extension E 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 �' Exploratory r ...210-164-0 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20626-00 00 7. Property Designajion(Lease Number): 8.Well Name and Number: ADL 380052,280051 r 2L-312 9.Field/Pool(s): Kuparuk River Field/Tarn Oil Pool 10.Present Well Condition Summary: Total Depth measured 9352 feet Plugs(measured) None true vertical 5629 feet Junk(measured) None Effective Depth measured 9344 feet Packer(measured) 8785 true vertical 5632 feet (true vertucal) 5262 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 120' 120' SURFACE 3029 10.75 3071 2402 PRODUCTION 9305 7.625 9344 5624 Perforation depth: Measured depth: 9040'-9060' I's True Vertical Depth: 5426-5439' JUN 0 7 7110 Tubing(size,grade,MD,and ND) 3.5, L-80,8847 MD,5302 TVD {01}h3 t�1it 8t Jaz Ct�ll6. stY11111S31011 Ancnf3rage Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 8785 MD and 5262 ND NIPPLE-Camco DS Nipple w/2.875"profile @ 482 MD and 482 ND 11.Stimulation or cement squeeze summary: Intervals treated(measured): 9040'-9060' Treatment descriptions including volumes used and final pressure: 242846#of 16/20 Carbolite 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 shut-in 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development J. • Service r Stratigraphic r 15.Well Status after work: WOii 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPI-UG 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: none Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer Signature (ti '—•--- Phone:265-6471 Date /671- / /�j 4/e/4 c. fir /6 DMS JUN 0 7101yd 6.7-c( Form 10-404 Revised 10/2010 ‘7° Submit Original Only 2L-312 Well Work Summary DATE SUMMARY 3/25/11 TAGGED @ 9130' SLM. SET CATCHER. PULLED SOV @ 8600' RKB & REPLACED WITH DV. MITT 3500 PSI, PASSED. ATTEMPTED MITIA 3500 PSI, FAILED. TBG INCREASED 175 PSI IN 30 MIN. PULLED DV @ 8600' RKB, PKG IN GOOD SHAPE. IN PROGRESS. 3/26/11 SET DV @ 8600' RKB. TESTED IA 2500 PSI, TBG GAINED 300 PSI IN 15 MIN. PULLED CATCHER. SET 2.75" CA-2 PLUG @ 8833' RKB. TEST IA, SAME RESULT. EXCERCISED CMU @ 8706' RKB. TEST IA, SAME RESULT. SET 2.81"CSA-2 PLUG IN CMU @ 8706' RKB. TEST IA, SAME RESULT. IN PROGRESS. 3/27/11 SET 2.875"CSA-2 PLUG @ 481' RKB. TESTED IA 3500 PSI, TBG COMMUNICATING. R/D SLICKLINE. FMC REP ON LOC'N. TESTED TBG HEAD ADAPTER VOID 5000 PSI, GOOD. TESTED IA 3500 PSI, MIT PASSED, TBG REMAINED @ 900 PSI. IN PROGRESS. 3/28/11 PULLED 2.875" CSA-2 PLUG @ 481' RKB. TEST IA 3500 PSI, TBG COMMUNICATING. PULLED DV @ 8600' RKB @ SET A-1 INJ VALVE @ 481' RKB TO PREP FOR VIDEO LOG. TESTED IA 3000 PSI; TBG ABOVE INJ VALVE @ 75 PSI, NO PRESSURE INCREASE ON TBG. IN PROGRESS. 3/29/11 MITIA 3500 PSI WITH A-1 INJ VALVE @ 481' RKB: PASSED. PULLED INJ VALVE @ 481' RKB. SET DV @ 8600' RKB. MITT AGAINST 2.81"CSA-2 PLUG @ 8706' RKB: PASSED. MITIA AGAINST 2.81"CSA-2 PLUG @ 8706' RKB: FAILED, TBG COMMUNICATING. PULLED 2.81" CSA-2 PLUG @ 8706' RKB. OPEN/CLOSE CMU @ 8706' RKB. IN PROGRESS. 3/30/11 REPLACE&TESTED INDIVIDUALLY DVs @ 7759', 6046' &3270' RKB. DIRECTIONAL LEAK f/IA TO TBG CONTINUES. OPENED CMU @ 8706' RKB. SET A-1 INJ VALVE ON 2.81"CS LOCK IN CMU @ 8706' RKB. TESTED IA TO 3000 PSI AGAINST A-1 INJ VLV @ 8706' RKB; CONFIRMED COMMUNICATION. READY FOR VIDEO. 4/3/11 RUN EXPRO HAWKEYE III CAMERA ON HES ELINE TO FIND LEAK. POSITIVE IDENTIFICATION OF LEAK @ 8656' IN THE CHEMICAL INJ MANDREL. RECORDED VIDEO OF LEAK. 5/7/11 LOAD TBG & IA W/380 BBLS DIESEL. PULL 2.81"A-1 INJ VLV IN CMU @ 8707' RKB. CLOSE CMU @ 8707' RKB. PT TBG TO 1500 PSI. IN PROGRESS 5/8/11 REPLACED 1" CIV @ 8656' RKB W/DV. PULL 2.75"CA-2 PLUG @ 8834' RKB. DRIFT TO 9109' RKB W/ 2.5"X 20' DMY PERF GUNS. MITIA 3500 PSI, PASSED. READY FOR E-LINE. 5/12/11 PERFORATED AT A DEPTH OF 9040'-9060' USING A 2.5"x20', 60 DEG PHASED, 6 SPF, GUN WITH 11 GRAM PROSPECTOR DEEP PENETRATING CHARGES (EHD= 0.41"). TUBING WAS PRESSURED UP TO 2700 PSI BEFORE PERFORATING AND DROPPED TO 400 PSI AFTER PERFORATING. PERFORMED 30 MINUTE STOP CHECKS AT 9052'AND 8600'TO OBTAIN BOTTOM HOLE PRESSURE. BOTTOM HOLE PRESSURE AND TEMPERATURE RECORDED AT 9052'WAS 2356 PSI AND 142 DEG F. BOTTOM HOLE PRESSURE AND TEMPERATURE RECORDED AT 8600'WAS 2232 PSI AND 133 DEG F. 5/17/11 TARN FRAC: PUMPED A TOTAL OF 244.191 LBS OF 16/20 CARBOLITE, PLACING 242,846 LBS BEHIND PIPE. COMPLETED FRAC WITH 9 PPA ON FORMATION. FRAC PUMPED TO 110% DESIGN. FLUSHED JOB TO COMPLETION WITH 18 BBL X-LINK GEL, 18 BBL OF LINEAR GEL AND 44 BBL OF DIESEL FREEZE PROTECT. 5/22/11 RIH, CLEAN OUT FILL W/SD TO 9175' CTMD, HARD TAG, POOH, COMPLETE WIPER TRIP SLOWING AT GLM, FP, READY FOR SLICKLINE 5/24/11 TAGGED 9067' SLM, EST. 9096' RKB. SET 2.75" CAT SV AT 8806' SLM. TESTED 2000 PSI, GOOD. PULLED DV FROM 8600' RKB. IN PROGRESS. 5/25/11 DISPLACED CSG TO TBG WITH DSL. SET OV @ 8600' RKB. PULLED 2.75" D CAT SV @ 8833' RKB. READY FOR FLOW BACK. . . KUP 2L-312 ConocoPhillips " 11Nell Attributes Max Angle&MD TD Wellbore APUD WI Field Name Well Status Incl(1 IMO(ftKB) Act Ben(ftKB) Alaska.tnc (arclmPh9k[a 501032062600 TARN PARTICIPATING AREA PROD 9,352.0 "" ,Comment IH23(ppm) Date An oration l-E dDate KB-Grd(ft) Rig Release Date '•' Wet Contig DEVIATED-JL ,$/781203'733322 AM SSSV'NIPPLE Last 0/0: 40.00 12/28/2011) Schemes-AoL,,. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 9,130.0 1 3/25/2011 Rev Reason:FRAC __ _ Imosb_or 5/18/2011 Casing Strings �-�c Casing Description String 0... String ID .Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String.. String Top Thrd HANGER.37--- -•.nit '. CONDUCTOR _ 16 15.750 40.0 110.0 110.0 164.00 1.031 WELDED_ �-1 Casing Desedption Sting 0... String ID...Top(PIKE) Set Depth(...Sat Depth(ND)...String Wt...String_.String Top Thrd I'' SURFACE 10 3/4 9.950 42.0 3,070.9 2,401.7 45.50 L-80 BTC C Casing Description String 0... String ID...Top(MB) s«Depth(f_.Set Depth(ND)...Siring Wt...String_.String Top ThN PRODUCTION 75/8 6.875 38.9 9,344.3 5,624.4 29.70 L-80 BTCM Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND) 'String Wt Shing... String Top Thrd TUBING 31/2 2.992 36.6 88483 I 5,302.5 I 9.30 L-80 j EUE8rdABMOD 7 Completion Details Top Depth ((TVD) Top Incl hong... t Top MKS) (ftKB) ('1 Item Description Comment ID(In) PuPups,71 36.6 36.6 -0.01 HANGER FMC TUBING HANGER 2.992 CONDUCTOR, 491-7 481.7 2.21 NIPPLE Cance DS Nipple w/2.875 profile 2.875 40-1108,706.9 5,210.9 49.64 SLEEVE-C Baker CMU sliding sleeve w/2.813"DS profile(CLOSE 5/7/2011) 2.812 NIPPLE,482 r- 8,754.3 5,241.6 49.67 SEAL ASSY Seal Assembly spaced above PBR 2.990 f' 8,762.3 5,246.8 49.68 PBR Baker 80-40 SEE and PBR 4.000 j 8,785.3 5,261.7 49.70 PACKER BAKER FHL PACKER 2.940 8,833.8 5,293.1 49.73 NIPPLE CAMCO'D'NIPPLE w/2.75 PROFILE 2.750 8,847.4 5,301.9 49.74 WLEG WIRELINE ENTRY GUIDE 2.950 Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) SURFACE. • 42-3,071 Top Depth (ND) Top Incl Top(ftKB) (PIKE) (1) _ Daacdpton Comment _ Run Date _ID(in) -_ 36.7 36.7 -0.01 INJ LINE CHEMICAL INJECTION LINE FROM MANDEL#5 TO 12/14/2010 0.049 TUBING HANGER GAs-3,271 Perforations&Slots Top(TVD) Btm(TVD) Shot Dena IPU LINE,37- Top(fIKB),Btnl(PIKB) (MB) (MB) _-_Zone Date (sh... Type Comment - 9,040.0 9,060.0 5,426.3 5,439.3 5/12/2011 6.0 IPERF 2.5"Guns,60 deg phase,11 gm RDX DP Prospector charges GAS LIFT, ..r ..1�titt ,,.,..` ti1ert5 I 6,617 , _.. Bottom ": Min Top Max!Sim Top Depth Depth (ftKB) (PI B) (11KB) MKS) Type Dab Comment 9,040.0 9,060.0 5,426.3 5,439.3 FRAC 5/17/2011 TARN FRAC:Pumped 242,846#of 16/20 Carbolate into Perfs _ Notes:General&Safety GAS LIFT, ''.- End Date Annotation 1.759 __ ---... 1/24/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 4/3/2011 NOTE CONFIRMED LEAK @ 8656'RKB CHEMICAL INJECTION MANDREL w/EXPRO VIDEO LOG GAS LIFT, 8,600 WiL CHEMICAL, 8,656 I SLEEVE-C, _-__ 8,707 SELL ASSY, 8.754 - PACKER,8,785 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run NIPPLE,9.834 :0... Ste Top(ftKB) (ftKB) (") Make model (in) Sere Type Type (in) (psi) Ron Dab Com... 1 3,270.6 2,490.2 64.30 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 3/30/2011 WLEG,8.847- ...1 2 6,046.8 3,801.4 62.37 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/3012011 3 7,759.5 4,618.8 55.24 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/30/2011 (PERF, 4 8,600.0 5,139.4 48.13 CAMCO MMG 1 12 GAS LIFT DMY RKP 0.000 0.0 3292011 9.010-9,080 FRAC,9.919 a 5 8,656.3 5,177.2 48.60 CAMCO KBMG-LTS 1 CHEM DMY BK 0.000 0.0 5/8/2011 PRODUCTION, 39-9,344 d TD,9,352 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, April 05, 2011 1:21 PM To: 'Nugent, David (Swift Technical Services LLC)' Subject: RE: 2L-312 (PTD 210-164) Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Nugent, David (Swift Technical Services LLC) [mailto:David.Nugent@contractor.conocophillips.com] Sent: Tuesday, April 05, 2011 11:46 AM To: Schwartz, Guy L (DOA) Subject: 2L-312 Guy, I checked with the asset team on the status of the 2L-312 well. It has not been perforated as of yet. It has a leaky chemical injection valve, and the asset team is trying to decide whether to replace or repair it, and then how they will accomplish that. They don't want to do it with open perfs, so they are holding off perforating the well until they solve the problem. Let me know if you have any other questions. David A. Nugent Swift Technical Services ConocoPhillips Alaska ATO 1502 Anchorage, AK 907-263-4228 4/5/2011 ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT01808 TO: Christine Shartzer ConocoPhillips Alaska, Inc. State of Alaska-AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: KRU 2L-312 AOGCC permit: 210-164-0 c90 6,96 DATE: 2/01/201T"---- Tr.n /01/201Tr.n mitt- •: Kuparuk River Unit, North Slope, Alaska 2L-312 Hardcopy and CDROM Final Well report, Mud logging report, Canrig;well 2L-312 (501032062600). Equipment,well data, geological data, pressure/formation strength, drilling data, daily reports,formation logs color prints; Formation log (MD) Formation log(TVD) , Gas ratio (MD) Gas ratio (TVD) ' LWD Combo (MD) _ LWD Combo (TVD) Drilling dynamics (MD) °"�� , v,,, CDROM contains; daily reports, DML data, final well report, LAS files, m'dog PDF files, remarks and tiff files Sign, scan and return in .pdf format if applicable to Sandra.D.LemkeC)aConocophillipscom CC: CD4-298 production well files, eSearch Receipt: c ... Date: 1 1 ' GIS-Technical Data Management ] conccoPh/!lips I Anchorage, Alaska (Ph: 907 265 6947 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION W 1a.WeIlStatus: ,Oil WELL COMPLETION OR RECOMPLETION REPORT AND LOG ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended`ig 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., o oifl) 12.Permit to Drill Number: ConocoPhillips Alaska,Inc. orAband.: December` ,2010 210-164/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 December 2,2010 50-103-20626-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number. Surface: 174'FNL,675'FEL,Sec.22,T1ON,R7E,UM December 15,2010 2L-312 Top of Productive Horizon: 8.KB(ft above MSL): 154.9'RKB 15.Field/Pool(s): 976'FNL,244'FWL,Sec.24,T1ON, R7E,UM GL(ft above MSL): 114.8'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1316'FNL,4922'FEL,Sec.24,T1ON,R7E, UM 9344'MD/5632'ND Tarn Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-460976 y- 5927671 Zone-4 9352'MD/5629'ND ADL 380052,380051 -- TPI: x-467171 y- 5926840 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit • Total Depth: x-467284 y- 5926499 Zone-4 nipple @ 482'MD/482'ND 4600,4599 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) 1431'MD/1400'ND 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 N. GR/Res not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 164.8# B-35 Surf. 120' Surf. 120' 24" Driven 10.75" 45.5# L-80 Surf. 3071' / Surf. 2402' 13.5" 1377 sx AS Lite,386 sx DeepCRETE 7.625" 29.7# L-80 Surf. 9344' Surf. 5632' 9.875" 730 sx GasBLOK Class G 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) 3.5" 8848'MD 8785'MD/5262'ND to be perfd ata later dateA+'4 P Y +` 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED s.A� 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up 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 0 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. NONE CEI JAN 3 1 2011 Form 10-407 Revised 12/2009 R%DMS JAN I IONTINUED ON REV SE a ON&G Cons"ctffi'rfiit`i g n�lonly 1011 An nerage 3•Z/• !t ,„, ��,/ 7-2 28. GEOLOGIC MARKERS(List all formations and market.encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes 2 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 1431' 1400' needed,and submit detailed test information per 20 AAC 25.071. C-80 3280' 2494' C-50 6062' 3807' C-40 6913' 4208' T-5 8533' 5077' Top Bermuda 8880' 5323' T-2 9006' 5404' Base Bermuda 9133' 5474' C-35 9145' 5495' K-3 9209' 5537' N/A Formation at total depth: Bermuda 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alike Greener @ 263-4820 /H /dr✓ Printed Name G.C.Alvord Title: Alaska Drilling Manager q - ) Signature _.( Phone 265-6120 Date /�cra+' 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 Conoco Phillips Time Log & Summary WelMew Web Reporting Report • Well Name: 2L-312 Rig Name: DOYON 15 Job Type: DRILLING ORIGINAL Rig Accept: 11/30/2010 12:00:00 PM Rig Release: Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11/27/2010 24 hr Summary Finish prepping rig for move to 3L-312. 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Move rig from 1B-19 to 2L-312. 11/28/2010 Moving rig to 2L-312 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Move rig from 1B-19 to 2L-312 11/29/2010 Continue move rig to 2L-312. 00:00 00:00 24.00 0 MIRU MOVE MOB P Continue Move rig to new location 2L-312 11/30/2010 Continue move rig to 2L-312. Lay herculite and matting boards.Spot rig over well.Spot modules. Rig up Lines and hoses. Nipple up diverter system with knife valave.Take on Spud Mud. Load pipe shed. Rig Accepted at 1200 HRS. Rig on Hi-line power at 1800 HRS 00:00 04:30 4.50 0 0 MIRU MOVE MOB P Continue Move rig to new location 2L-312.Continue spot&rig up camp. 04:30 12:00 7.50 0 0 MIRU MOVE MOB P Lay herculite. Install matting boards. Spot rig.Spot module.Skid rig floor. Berm&install Rockwasher,and cuttings tanks.Crew Change 12:00 13:30 1.50 0 0 MIRU DRILL NUND P Nipple up Diverter system with Knife valve.Attch&test Koomey lines. 13:30 15:30 2.00 0 0 MIRU DRILL OTHR P Take on 590 BBLS of Spud mud. Load pipe shed. Function test diverter system hydril and knife valve. (OK)Make up diverter line. Insulating areas around sub structure. 15:30 16:30 1.00 0 0 MIRU DRILL RURD P PJSM-Change out saver sub on topdrive from XT-39-to 4-1/2"IF 16:30 18:00 1.50 0 0 MIRU DRILL RURD P Dress rig floor-Bring up handling equipment,floor safety valves. Load pipeshed with BHA components, Motor,MWD collars etc. Complete making up diverter line. 18:00 22:00 4.00 0 0 MIRU DRILL RURD P Load 100 joints 5"drillpipe and 15 joints HWDP into pipeshed. Continuing to rig up in all areas. 22:00 00:00 2.00 0 0 MIRU DRILL RURD P Spot cuttings tank for rock washer, Berm cuttings tank.Conduct rig audit. Prep to pick up drillpipe and rack in derrick Crew Change 12/01/2010 Performed rig audit, Prepped rig for spud. Diverter system test performed.Witness of test waved by AOGCC rep Jeff Jones.33 stands drillpipe picked up&3 stands HWDP all racked in derrick. Pre-Spud meeting and pre job on picking up BHA held. Partial BHA picked up.Tag @ 72'and Clean out conductor and drill enough footage to pick up remaining BHA. All mud lines pressure tested to 3,000 psi. No leaks.All rig monitoring equipment calibrated(Quadco)Spud well @ midnight. Page 1 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 0 MIRU DRILL RURD P Continue rig up on 2L-312 Prep for spud.Organize rig floor.Conduct Rig Audit 01:30 08:30 7.00 0 0 MIRU DRILL PULD P PJSM, Pick up 5"drillpipe and rack back in derrick. Continue rig up and general housekeeping 08:30 12:00 3.50 0 0 MIRU DRILL RURD P Completed berming around rig,Trim all excess herculite,Set grating at bottom of all stairs Organize cellar area.Check all safety mechanisms in place and functioning properly. Calibrate PVT systems w/Quadco. Rig up Epoch mud loggers. 12:00 14:00 2.00 0 0 MIRU DRILL RURD P Continue rigging up and preparing rig for spud.Check all stairs and exits are clear.Verify all lines made up and proper valve alignment.Continue general housekeeping all rig areas. 14:00 16:00 2.00 0 0 MIRU DRILL PULD P Pick up stand 5"drillpipe function test diverter system annular and knife valve. Diverter test witness waved by AOGGC rep Jeff Jones. Tag up 72'from rkb. Fill diverter stack with water. Knife valve leaking attempted to adjust knife valve paddle without success. 16:00 19:30 3.50 0 0 MIRU DRILL RURD P Rig up Gyro wireline.Change matting configuration in front of rockwasher and provide ramp for super suckers. Changed out knife valve on diverter system. Finalize rig audit all areas of rig ready to spud. 19:30 20:30 1.00 0 0 MIRU DRILL RURD P Function test knife valve on diverter system, Fill diverter stack with water check for leaks. No leaks 20:30 21:30 1.00 0 0 SURFA( DRILL SFTY P Hold Pre-Spud meeting with rig crew, Mud eng, Directional,MWD personnel. Discussed plan forward. 21:30 23:30 2.00 0 0 SURFA( DRILL PULD P Make up partial BHA. Bit,Motor, UBHO,Crossover.Scribe motor to UBHO.Pick up 1 stand HWDP to clean out conductor. 23:30 00:00 0.50 0 0 SURFA( DRILL PRTS P Pressure test surface lines to 3.000 psi.Good test no leaks. 12/02/2010 Spud well at 0000 HRS. Drill to 304'and POOH fro MU remaining BHA#1.Worked through obstruction @ 160'.Washed and reamed to 253'.circulated hole and conditioned mud. Directional drilled from 304'MD to 1,078'MD utilizing Gyro surveys. (Midnight depth) 00:00 02:15 2.25 0 216 SURFA( DRILL DDRL P_Spud 21-312 at 0000 HRS.Tag up @ 72',and drill to 216'with 500 GPM's- 750 PSI,50 RPM's. UP WT=90K, SO WT=90K. 02:15 02:45 0.50 216 216 SURFA( DRILL CIRC P Circulate&rotate while clean and adjust scalper shakers.Adjust auger speed. 02:45 04:00 1.25 216 304 SURFA( DRILL DDRL P Continue drill from 216' to 304'with 500 GPM's-750 PSI,50 RPM's. UP WT=90K,SO WT=90K. Page 2 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:30 0.50 304 304 SURFA( DRILL TRIP P POOH to make up remaining BHA# 1.Trip out 3 stands HWDP.Lay down crossover sub and UBHO. Pulled up and checked bit condition. Condition of bit was good with no significant amount of clay on cutting structure. 04:30 08:00 3.50 304 304 SURFA( DRILL PULD P c _Pick up MWD tools-Directional, Gamma/res, Pulser and UBHO. Upload MWD data. 08:00 09:00 1.00 304 304 SURFA( DRILL REAM P Encountered obstruction at 160' (Bridged over)Picked up stand of drillpipe and reamed area until satisfied hole condition was good. Washed and reamed from 160'to 276'Racked pipe back in derrick 09:00 09:30 0.50 304 304 SURFA( DRILL PULD P Pick up remaining BHA to HWDP. Flex collar,Jars,crossover and Heavywall 09:30 10:30 1.00 304 304 SURFA( DRILL REAM P Washed and reamed from 253'to 304'. Heavy clay and coarse sand at shakers. Flow rate 600 gpm with 1,250 psi. Rotary speed 50 rpm. 10:30 11:00 0.50 304 362 SURFA( DRILL DDRL P Drill F/304'-T/362'TVD=362' Flow rate 500 gpm, Pressure on 1,250 psi -Off 1,250 psi. Flow out 33%, RPM- 50,Torque off/on=1k Bit wt 0-10K. Up, Down and rotating wt=105K. ADT=.4 hr.ART=.4 hr AST=0. Total bit/jar hrs=1.31 Max gas units observed=26 units(Epoch) 11:00 12:45 1.75 362 362 SURFA( DRILL CIRC P Rotate and reciprocate while cleaning hole and conditioning mud. 200 qpm,50 rpm,Torque 3K. 12:45 18:00 5.25 362 796 SURFA( DRILL DDRL P Drill F/362'-T/796'TVD=794' Flow rate 490 gpm, Pressure on 1,080 psi -Off 1,080 psi. Flow out 35%, RPM- 50,Torque off/on=3k Bit wt 5-20K. Up wt 108K Down wt 100K rot wt= 105K.ADT=1.85 hr.ART=.60 hr AST=1.25.Total bit and jar hrs= 3.16 Max gas units observed=14 units(Epoch) 18:00 00:00 6.00 796 1,078 SURFA( DRILL DDRL P Drill F/796'-T/1078'TVD=1071' Flow rate 520 gpm, Pressure on 1,320 psi-Off 1,180 psi. Flow out 35%, RPM-50,Torque on=4k/off= 2k Bit wt 20K. Up wt 118K Down wt 118K rot wt=117K.ADT=3.14 hr. ART=.1.28 hr AST=1.86.Total bit and jar hrs=6.3 Max gas units observed=14 units(Epoch) Page 3 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/03/2010 24 hr Summary Directional drill from 1,708 MD. to 1,402'.drilling discontinued due to excessive dogleg 6.91°.Washed and reamed interval reducing dogleg to 3.2°.Continued drilling from 1,402'to 1,704'.Shakers blinded off due to large amounts of clay.Rockwasher and cuttings tanks overloaded. Discontinued drilling emptied cuttings tank and rockwasher. Pumped mud back into pits over shakers from vac truck to restore mud volume.Waited for super suckers to be emptied and ready to continue. Held meeting with crew in doghouse to capture lessons learned. Resumed drilling from 1,704'to midnight depth of 2,286'MD 2,038'TVD. 00:00 07:00 7.00 1,078 1,402 SURFA( DRILL DDRL P Drill F/1,078'MD-T/1,402'MD, 1,369'TVD Flow rate 605 gpm, pressure on 1,630 psi pressure off 1,500 psi.Flow out 36%, RPM=50, torque on=4K torque off=2.5K, Bit wt 15-20K, Up wt 122k Down wt 122k, Rot wt 122k. Max gas 484 units(Epoch) 07:00 09:00 2.00 1,402 1,402 SURFA( DRILL REAM P Survey taken showed 6.9°dogleg. Drilling stopped area washed and reamed to reduce dogleg to 3.2° Flow rate 800 gpm,2,480 psi w/50 rpm.Sim op-rig down Sperry gyro 09:00 12:00 3.00 1,402 1,681 SURFA( DRILL DDRL P Drill F/1,402'MD-T/1,681'MD, 1,612'TVD Flow rate 603 gpm, pressure on 1,630 psi pressure off 1,540 psi. Flow out 33%, RPM=50, torque on=4-5K torque off=3-4K, Bit wt 10K, Up wt 125k Down wt 122k, Rot wt 124k.Max gas 963 units(Epoch) Drilling hrs from 00:00 to 12:00 ADT-7.94,ART-5.16,AST-2.78 Bit and jar hrs 11.52. 12:00 13:30 1.50 1,681 1,800 SURFA( DRILL DDRL P Drill F/1,681'MD-T/1,800'MD 1,704'TVD. Flow rate 610 gpm, t. / pressure on 1,780 pressure off 1,640. Flow out 34%, RPM-50.Torq on 5-6k torq off 3-4k. Bit wt 12-16k. Up wt 130k down wt 125k, rot wt 128k.Max gas observed-104 units. ADT-.81 hrs.ART-.28 hrs.AST- .53. Bit and jar hrs=12.31 13:30 16:00 2.50 1,800 1,800 SURFA( DRILL CIRC P Reciprocate at reduced rate 60 gpm 150 psi due to high volume of mud to rockwasher and cuttings tank.Very heavy clays blinding shakers. Rockwasher and cuttings tank overloaded super sucker trucks full. Clean pits and reorganize while waiting on super sucker trucks. Pumped mud off of vac trucks back to pits across shakers to regain mud volume.(PJSM and crew meeting held in doghouse with new crew by company rep) Page 4 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 18:00 T 2.00 1,800 1,911 SURFA( DRILL DDRL P Drill F/1,800'MD-T/1,911'MD 1,787'TVD. Flow rate 610 gpm, pressure on 1,780 pressure off 1,640. Flow out 33%, RPM-50.Torq on 5-6k torq off 3-4k. Bit wt 16-18k. Up wt 130k down wt 125k, rot wt 128k. Max gas observed-104 units. ADT-1.19hrs.ART-.26 hrs.AST- .93. Bit and jar hrs=13.5 hrs 18:00 00:00 6.00 1,911 2,286 SURFA( DRILL DDRL P Drill F/1,911'MD-T/2,286'MD 2,038'TVD. Flow rate 625 gpm, pressure on 1,950 pressure off 1,800. Flow out 31%, RPM-50.Torq on 6-7k torq off 5-6k. Bit wt 20-22k. Up wt 135k down wt 125k,rot wt 128k.Max gas observed-77 units. ADT-3.54hrs.ART-1.78 hrs.AST- 1.78. Bit and jar hrs=17.04 hrs 12/04/2010 Directional Drill from 2286'to TD @ 3,081'.Circulate, Backream to 1,390'.Trip into 3,081'on elevators w/no problems,Circulate @ 700 gpm.pump hi-vis weighted sweep, circulate hole clean @ 800 gpm.Trip out to 1,488'on elevators with no indications of hole problems and hole taking •ood fill. No swabbing. 00:00 06:00 6.00 2,286 2,653 SURFA( DRILL DDRL P Drill F/2286'MD-T/2,653'MD 2,223' TVD. Flow rate 658 gpm,pressure on 2,250 pressure off 2,030'. Flow out 33%, RPM-50.Torq on 7k torq off 4-5k. Bit wt 20-25k. Up wt 131k down wt 125k, rot wt 129k.Max gas observed-87 units. ADT-3.9 hrs.ART-1.82 hrs.AST- 2.08. Bit and jar hrs=20.55 hrs 06:00 12:00 6.00 2,653 3,030 SURFA( DRILL DDRL P Drill F/2,653'MD-T/3,030'MD 2,384'ND. Flow rate 650 gpm, pressure on 2,300 pressure off 2,060'. Flow out 39%, RPM-50. Torq on 7k torq off 4-5k. Bit wt 20-25k. Up wt 131k down wt 121k, rot wt 128k. Max gas observed-87 units. ADT-2.61 hrs.ART-2.21 hrs.AST- .40. Bit and jar hrs=23.79 hrs 12:00 13:00 1.00 3,030 3,081 SURFA( DRILL DDRL P Drill F/3,030'MD-T/3,081'MD S 2,407'ND. Flow rate 458 gpm, p pressure on 1,350 pressure off 1,250'.Flow out 29%, RPM-50. Torq on 5-6k torq off 4-5k. Bit wt 16-18k. Up wt 140k down wt 128k, rot wt 130k.Max gas observed-25 units. ADT-.87 hrs.ART-.87 hrs.AST-0. Bit and jar hrs=24.66hrs.TD section w/#1 pump while changing liner gasket on#2 pump. 13:00 14:30 1.50 3,081 3,081 SURFA( DRILL CIRC P Circulate hole clean at 500 gpm 2,100 psi. Rotary speed 50 rpm.Torq =4-5k. Up wt 140k down wt 128k. rot wt 130k.Max gas observed 62 units.Total strokes 10,500 Page 5 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 18:00 3.50 3,081 1,390 SURFA( DRILL TRIP P Back ream out of hole f/3,081'-t/ 1,500'w/650 gpm 1,590 psi.torq 3-4k,up wt 125k down wt 122k,rot wt 125k.max gas observed 115 units.Continue backreaming from 1,500'to 1,390'at reduced pump rate of 500 gpm and 1,100 psi.Total strokes 4,500. 18:00 19:30 1.50 1,390 3,081 SURFA( DRILL TRIP P Trip in hole from 1,390'to bottom 3,081'with no indication of hole problems.On bottom-up wt 140 k down wt 128k. 19:30 21:30 2.00 3,081 3,081 SURFA( DRILL CIRC P Circulate bottoms up @ 700 gpm 2,130 psi. Pump 50 bbl weighted sweep with nutplug.sweep weight 11.2 ppg.Vis 241. Nut plug to surface at 5,550 strokes.(Moderate increase of cutting over shakers 50% but much of this was nutplug) Calculated hole washout 8%.Sweep out of hole increase flow rate to 800 gpm 2,610 psi,36%flow.Circulated until shakers clean. Max gas units= 209.Total strokes 9,600. 21:30 22:00 0.50 3,081 3,081 SURFA( DRILL OWFF P Monitor well(Static)Blow down top drive. 22:00 00:00 2.00 3,081 1,488 SURFA( DRILL TRIP P Trip out of hole on elevators from 3,081'to 2,632'No hole problems. Pumped 10 bbl dry job.Continued trip out of hole from 2,632'to 1,488' with no indication of hole problems. Pulled slick-took good fill with no swabbing. 12/05/2010 Continue POOH with SLM to BHA. Rack back HWDP.Breakout&lay down BHA. Inspect&grade bit to 1/1/CT/G/1/1/NO/TD.Clear&clean rig floor. Rig up DDI Casing crew to run 10 3/4"casing. Held PJSM.Make up shoe track&check floats-good. Run 10 3/4"casing as per detail. Run 73 jnts. MU casing hanger& landing joint.Observed no hole issues while RIH with casing. Break Circulation at 1200',2272'and at TD. Circulate&condition mud for cement properties staging rates to 7 BPM-330 PSI.SIMOPS:Spot&rig up all needed trucks for cement Job. RU Schlumberger cementers. 00:00 01:00 1.00 1,488 543 SURFA( DRILL TRIP P Trip out to BHA-Flex Drill collars. Good fill, Racked back 3 stands HWDP. No hole problems encountered 01:00 05:30 4.50 543 0 SURFA( DRILL PULD P Lay down BHA,2 HWDP,Jars,3 Flex drill collars,Download MWD data(1/2hr)Lay down remaining BHA. Bit inspected and graded 1-1-CT-G-I-E-NO-TD. 05:30 09:00 3.50 0 0 SURFA( DRILL RURD P Clean&clear rig floor area.Send tools&equipment out. 09:00 09:45 0.75 0 0 SURFA( CASING SFTY P Held PJSM with crew,and DDI casing rep. Discuss safety&hazard recognition issues. Discuss procedure to rig up and run 10 3/4" casing. Page 6 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:45 11:30 1.75 0 0 SURFA(CASING RURD P Rig up DDI casing crew,power tongs,elevators and slips.MU Franks fill up tool. Double check floor equipment. 11:30 12:00 0.50 0 0 SURFA(CASING RNCS P Make up 10 3/4"shoe joint& threadlock joint with Hydroforms installed as per well plan.Baker lock connections.MU Torque=11K ft/lbs.Crew change. 12:00 15:00 3.00 0 1,276 SURFA( CASING RNCS P Continue MU remaining shoe track with Float collar joint. Fill pipe and check floats.Good.Continue RIH with 10 3/4"casing fillinq each joint _ and topping off every 10 jnts. Observed proper displacement . 15:00 16:00 1.00 1,276 1,276 SURFA( CASING CIRC P Break circulation at 1276'staginig to 3 BPM-160 PSI. Reciprocate casing string. UP WT=140K,SO WT=120K. 16:00 18:00 2.00 1,276 2,272 SURFA(CASING RNCS P Continue run 10 3/4"casing from 1276'-2272'.Observed good hole conditions,and proper displacement. 18:00 19:00 1.00 2,272 2,272 SURFA(CASING CIRC P Break circulation at 2272'staginig to 3 BPM-180 PSI. Reciprocate casing string. UP WT=140K,SO WT=120K. Pump 1500 stks. 19:00 20:30 1.50 2,272 3,066 SURFA(CASING RNCS P Continue run 10 3/4"casing from 2272'-3066'.Observed good hole conditions,and proper displacement. 20:30 22:30 2.00 3,066 3,071 SURFA(CASING RNCS P Make up casing hanger andl landing_ joint. RIH to tag bottom at 3081' Pull up, lay down 1 joint.Shoe at 3071' MD. 22:30 00:00 1.50 3,071 3,071 SURFA(CASING CIRC P Circulate&condition mud staging pumps to 3 BPM-230 PSI.UP WT =215K,SO WT=150K.Circulated 2000 stks with no issues,using Franks fill up tool. RKB=41.30' Crew Change 12/06/2010 Continue lay down 1 jnt of casing.MU casing hanger and landing joint.Make up Cement Head and lines. Spot all trucks and RU lines.Cement surface casing per program.Clear floor of casing and cementing equipment, Nipple down surface diverter system,Set well head orientate with pad operator.Start nippling up BOPE. 00:00 01:30 1.50 3,071 3,071 SURFA( CASING RNCS P Continue lay down 1 jnt of casing. Make up casing hanger and landing joint. Make up cement head,and lines. 01:30 04:00 2.50 3,071 3,071 SURFA( CEMEN-CIRCP Circulate&condition mud to cement properties of 9.4 PPG,Viscosity 78, PV=29.YP=33.While batch up Mud Push. Prime pumps. Rig up lines in cellar. Held PJSM with entire crew including truck drivers,and cement crew. Discuss safety& hazard recognition issues. Discuss procedure to mix and pump cement job. Page 7 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 08:00 4.00 3,071 3,071 SURFA(CEMEN"CMNT P Turn over to Schlumberger. Pump 5 BBLS of fresh water.pressure test !J lines to 3000 PSI-good test.Mix and pump 50 bbls CW 100 Chem (.A1 Wash,Pump 55 BBLs of 10.5 PPG Mud push with Red Dye.Turn over to 10.85 PPG Lead Cement,pump 487 bbls'Lead Cement,Switch To Tail Cement 111.5 bbl's pumped 12.0 (/Z �6 Tail Cement.Switch to rig pumps b and displace with Oil Base Mud. Bumped plug at 2,707 strokes 267 ! bbl's pumped for displacement.267 ( bbl's cement to surface CIP 07:38. Reciprocated casing string 20'-30' increments with good movement during cementing operations. 08:00 12:00 4.00 3,071 3,071 SURFA( CEMEN"RURD P Blow down cement lines. Rig down cement equipment,cement head. Vac out landing jt, Break out cross over and landing joint. Flush diverter stack.Clear and organize rig floor. 12:00 14:00 2.00 3,071 3,071 SURFA( CASING RURD P Remove 10-3/4" casing handling egipment&Cementing equipment from floor, Elevators,Slips,Casing tongs,Scaffold,Cement head, Long bales. 14:00 18:00 4.00 3,071 3,071 SURFA(WHDBO NUND P Nipple down surface diverter stack, Hydril, Riser, Knife valve and diverter line. 18:00 23:00 5.00 3,071 3,071 SURFA(WHDBO NUND P Spot wellhead equipment in cellar. Install casing and tubing head. Confirm orientation of wellhead with Pad operator.Tested metal to metal seal on casing head 1,000 psi/10 min.Good test. 23:00 00:00 1.00 3,071 3,071 SURFA(WHDBO NUND P Nipple up 11"X 13-5/8"crossover and 13-5/8"High pressure riser. 12/07/2010 Continue NU BOP stack.Change out rams installing 5"rams.Test BOP.Witness of test waived by Chuck Sheive AOGCC. 00:00 12:00 12.00 3,071 3,071 SURFA(WHDBO NUND P PJSM Held at crew change. Nipple up BOPE.calibrate and test rig gas alarms. Simultaneous operations during nipple up- Continue cleaning pits and prep for oilbase mud. Load 192 joints 5" drillpipe into pipe shed.Strap pipe in shed. 12:00 13:30 1.50 3,071 3,071 SURFA(WHDBO NUND P Change lower pipe rams to 5"/ Continue prepping pits for oil base mud. Crew change. 13:30 16:00 2.50 3,071 3,071 "SURFA(WHDBO NUND P Complete nipple up of BOPE(Bell , nipple,choke lines,flow line, kill line and instal turn buckles. Page 8 of 26 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 16:00 19:30 3.50 3,071 3,071 SURFA(WHDBO BOPE P Rig up BOP test equipment, High pressure hose,test manifold,floor valves,topdrive and chart recorder. Check rams. 19:30 20:30 1.00 3,071 3,071 SURFA(WHDBO RURD P Put slop tank in cellar for oil base mud. Rig up to pump tank out to pits. 20:30 22:30 2.00 3,071 3,071 SURFA(WHDBO BOPE P Make up test plug and headpin to 5" test joint.Set test plug, Fill stack and choke manifold with water 22:30 00:00 1.50 3,071 3,071 SURFA(WHDBO BOPE P Test BOPE 250 psi low 5,000 psi high.Test 3"demco valve,choke manifold valves#16, n „D 17-18-12-13-14-5-6-10-11,Test !I I manual kill HCR kill, Lower IBOP and upper IBOP.All tests charted.Witness of BOPE test waived by AOGCC rep Chuck Sheave 12/08/2010 Complete testing BOP's.Witness of test waived by Chuck Sheive AOGCC.RD test equipment. Install WB- RILDS. Pick up and rack back 5"DP to TD section. Pull tools to rig floor. Held PJSM.Make up BHA#2,9 7/8" assembly for intermediate section. 00:00 06:00 6.00 3,071 3,071 SURFA(WHDBO BOPE P Continue test BOP's.Test Top pipe rams(31/2"x 6"VBR's), Bottom Rams 95"),and Blind rams.Test all floor safety valves including dart valve.test Choke manifold and valves #1-4,#7-9 and#15. Perform Koomey test with first 200 PSI in 45 secs and full 3000 PSI in 3 minutes-10 secs. Observed 16 bottles with avg PSI of 1000 PSI.5 Nitrogen precharge bottles with avg PSI of 2350 PSI. Witness of test waived by Chuck Shelve AOGCC. 06:00 07:00 1.00 3,071 3,071 SURFA(WHDBO BOPE P Rig down all BOP test equipment. Pull tesst plug. Install wear ring. RILDS(2). 07:00 07:30 0.50 3,071 3,071 SURFA( DRILL SFTY P Held PJSM with crew. Discuss safety&hazrd recognition issues. Discuss procedure to pick up 5"DP from shed,make up stands and rack back same. 07:30 11:00 3.50 3,071 3,071 SURFA( DRILL PULD P Install dummy mouse hole in rotary table. Pick up 5"drill pipe from shed, making up stands and racking back in derrick. 11:00 12:00 1.00 3,071 3,071 SURFA( DRILL PULD P Lay down 8"handling tools from rig floor.pull 6 3/4"tools to rig floor. Crew change 12:00 12:30 0.50 3,071 3,071 SURFA( RIGMNT SVRG P Service rig, Inspect&grease top drive and draw works. 12:30 19:30 7.00 3,071 3,071 SURFA( DRILL PULD P Continue pick up 5"drill pipe from shed,making up stands and racking back in derrick. Page 9 of 26 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 19:30 20:30 1.00 3,071 3,071 SURFA( DRILL RURD P Pull mouse hole from rotary table. Prep rig floor to pick up BHA,Attach snub lines to tongs.Check equipment. 20:30 21:00 0.50 3,071 3,071 SURFA( DRILL SFTY P Pre job safety meeting on picking up BHA with Neutron density sources. 21:00 23:30 2.50 3,071 3,071 SURFA( DRILL PULD P Pick Up 9-7/8"BHA.(Bit,Motor, Float sub,Stabilizer,MWD Directional collar,MWD Logging tools, Pulser, Rotating survey tool. 23:30 00:00 0.50 3,071 3,071 SURFA( DRILL PULD P Download MWD Tools 12/09/2010 Continue Upload MWD assembly,and make up remaining BHA with MI Well Commander. Perform Shallow pulse test-Good. Load sources.TIH to wash down and tag cement at 2940'MD.Wash down to Float collar @ 2986'MD.CBU. Rig up-Perform casing test to 3000 PSI-30 minutes. Drill cement and shoe track to 3071'MD.Continue drill out formation to 3101'for 20'of new hole.CBU. Perform LOT to 15.2 EMW.Change out Top Drive saver Sub. Drill from 3101'-3239'MD.TVD=2478'. Repair failed liner seal in mud pump. Continue drill from 3239'-3549'MD.ND=2611'.ADT=2.68 HRS. AST=.46 HRS.Total Bit HRS=2.68 HRS.Total Jar Hrs=2.68 00:00 00:30 0.50 3,071 3,071 SURFA( DRILL PULD P Continue Upload MWD assembly. 00:30 01:30 1.00 3,071 3,071 SURFA( DRILL PULD P Make up 6 3/4" Flex drill collars. Screw in and perform Shallow pulse test. Blow down Top drive. 01:30 02:00 0.50 3,071 3,071 SURFA( DRILL PULD P Held PJSM with crew,Sperry Sun reps. Discuss safety&hazard recognition issues. Discuss procedure to install Nukes in the BHA. 02:00 03:00 1.00 3,071 3,071 SURFA( DRILL PULD P Load Nuke sources in BHA. 03:00 04:30 1.50 3,071 3,071 SURFA( DRILL PULD P Continue make up remainder of BHA including MI Swaco Well Commander valve. Function test Well commander valve observing proper opening and closing. 04:30 06:00 1.50 3,071 3,071 SURFA( DRILL TRIP P Trip in hole to 2864'MD.Observed proper displacement. 06:00 07:30 1.50 3,071 3,071 SURFA( DRILL WASH P Break circulation.Obtain parameters.Wash down to tag cement at 2940'MD.Continue washing green cememnt to tag Float collar on depth at 2986'DPM. 07:30 09:00 1.50 3,071 3,071 SURFA( DRILL CIRC P CBU. Rig up lines,and perform casing test to 3000 PSI. Record on chart.good test. 09:00 11:15 2.25 3,071 3,071 SURFA( CEMEN-DRLG P Drill out shoe track and cement from 2986'-3071'DPM. Pumps at 650 GPM's-2375 PSI. RPM's-50.TQ= 3-4K.with 7K WOB. 11:15 11:30 0.25 3,081 3,101 SURFA( DRILL DRLG P Continue drill formation with same parameters as above from 3081'- 3101'DPM for 20'of new hole.ND= 2416'. 11:30 12:00 0.50 3,101 3,101 SURFA( DRILL CIRC P Circulate&condition mud for LOT test.Crew Change Page 10 of 26 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 12:00 12:30 0.50 3,101 3,101 SURFA( DRILL CIRC P Circulate&condition mud for LOT test.Obtain SPR's Mud pump#1 -20 SPM-110 PSI. 30 SPM-180 PSI. Mud Pump#2-20 SPM-130 PSI. 30 SPM-190 PSI. Blow down Top Drive. 12:30 14:00 1.50 3,101 3,101 SURFA( DRILL LOT P Rig up lines and 2000 PSI gauge for LOT.Circulate to remove air from system. Pump to perform LOT to 15.2 calculated EMW.Rig down and blow down lines. 14:00 17:00 3.00 3,101 3,101 PROD1 RIGMNT SVRG P Service top drive and draw works. Inspect saver sub. Held PJSM with crew. Discuss safety&hazard recognition issues. Discuss procedure with new crew to change out saver sub.Change out saver sub. 17:00 19:00 2.00 3,101 3,239 PROD1 DRILL DDRL P Directional drill from 3101'-3239' MD.TVD=2478'. Pumps at 650 GPM's-2400 PSI.WOB-5-6K.On bottom TQ-5-6K. ECD's @ 9.51 PPG.Max Gas observed=20 Units. AST=0 Hrs.ART=.86 HRS.ADT= .86 hRS.Total Jar Hrs=.86.Total Bit HRS-.86. 19:00 20:30 1.50 3,239 3,239 PROD1 RIGMNTRGRP T Observed failed liner gasket on mud pump#1.Shut down pumps. Reciprocate drill string while making repairs to mud pump. 20:30 00:00 3.50 3,239 3,549 PROD1 DRILL DDRL P Directional drill from 3239'-3,549' MD.TVD=2,610'. Flow rate 780 GPM's-3,550 PSI on 3,225 PSI off. WOB-5K.On bottom TQ-6K.Off bottom torq 5K ECD's @ 9.57 PPG. Max Gas observed=30 Units.AST =.46 Hrs.ART=1.32 HRS.ADT= 1.82 HRS.Total Jar Hrs=2.68.Total Bit HRS-2.68.Camp sands • encountered at 3,433'MD,2,560' TVD. Max gas units in camp sand 22 units.Camp sand thickness 2'per logs. 12/10/2010 Change out mud pump liner gasket on mud pump#2. Directional Drill from 3549'-3601'MD.TVD=2635'. Change out Liner gasket.Continue Directional Drill form 3601'-3714'MD.TVD=2687'.Change out Liner gasket on Mud pump. Continue Directional Drill from 3714'-4425'MD.TVD=3027'.Change out liner,gasket and wear plate on mud pump#2. Continue Directional Drill from 4425'-4,774'TVD=3,027' ADT=1.79 HRS. AST=0.0 HRS.Total Bit HRS=9.78 HRS.Total Jar Hrs=9.78.Accumulated rotating hrs=9.02 Accumulated Sliding hrs=.76 Slide percentage total from 3,081'to 4,774'=6% 00:00 01:30 1.50 3,549 3,549 PROD1 RIGMNI RGRP T Change out liner gasket on Mud pump#2. Reciprocate&rotate drill string with one pump at 420 GPM's- 1060 PSI-80 RPM's Page 11 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01:30 02:00 0.50 3,549 3,601 PROD1 DRILL DDRL P Directional drill from 3,549'-3601' MD.TVD=2,635'. Flow rate 780 GPM's-3,550 PSI on 3,225 PSI off. WOB-4K.On bottom TQ-6K.Off bottom torq 5K ECD's @ 9.57 PPG. Max Gas observed=25 Units.AST =0 Hrs.ART=.42 HRS.ADT=.42 HRS.Total Jar Hrs=3.10.Total Bit HRS-3.10. 02:00 02:45 0.75 3,601 3,601 PROD1 RIGMNT RGRP T Change out liner gasket on Mud pump#2.Reciprocate&rotate drill string with one pump at 420 GPM's- 1000 PSI-80 RPM's 02:45 04:30 1.75 3,601 3,714 PROD1 DRILL DDRL P Directional drill from 3601'-3714' MD.TVD=2,687'. Flow rate 780 GPM's-3,150 PSI on 3,250 PSI off. WOB-6K.On bottom TQ-4-6K. Off bottom torq 4-5K ECD's @ 9.61 PPG.Max Gas observed=20 Units. AST=0 Hrs.ART=.67 HRS.ADT= .67 HRS.Total Jar Hrs=3.77.Total Bit HRS-3.77. 04:30 05:00 0.50 3,714 3,714 PROD1 RIGMNT RGRP T Change out liner gasket on Mud pump#2. Reciprocate&rotate drill string with one pump at 420 GPM's- 1060 PSI-80 RPM's 05:00 12:00 7.00 3,714 4,313 PROD1 DRILL DDRL P Directional drill from 3714'-4313' MD.ND=2,972'. Flow rate 780 GPM's-3,100 PSI on 3,180 PSI off. WOB-6K.On bottom TQ-6-7K.Off bottom torq 5-6K ECD's @ 9.39 PPG. Max Gas observed=30 Units. AST=.20 Hrs.ART=3.32 HRS. ADT=3.52 HRS.Total Jar Hrs= 7.29.Total Bit HRS-7.29. 12:00 13:00 1.00 4,313 4,426 PROD1 DRILL DDRL P Directional drill from 4313'-4426', MD.ND=3027'. Flow rate 784 GPM's-3,140 PSI on 3,090 PSI off. WOB-6K.On bottom TQ-6-7K.Off bottom torq 5-6K ECD's @ 9.39 PPG.Max Gas observed=17 Units. AST=.10 Hrs.ART=.60 HRS.ADT =.70 HRS.Total Jar Hrs=7.99. Total Bit HRS-7.99. 13:00 20:00 7.00 4,426 4,426 PROD1 RIGMNT RGRP T Change out liner gasket. liner and wear plate on Mud pump#2. Reciprocate&rotate drill string with one pump at 420 GPM's-1060 PSI- 80 RPM's Rack back one stand of DP.Change out flowline air boot.Trip back in hole 2 stands. Page 12 of 26 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 4,426 4,774 PROD1 DRILL DDRL P Directional drill from 4426'-4,774' MD.TVD=3,189'. Flow rate 780 GPM's-3,350 PSI on 3,300 PSI off.RPM-100,WOB-6K.On bottom TQ-7K.Off bottom torq 6K ECD's @ 9.54 PPG.Max Gas observed=17 Units.AST=0.0 Hrs.ART= .1.79 HRS.ADT=1.79 HRS.Total Jar Hrs =9.78.Total Bit HRS-9.78. 12/11/2010 Directional Drill 9 7/8"hole from 4774'-5040'MD.TVD=3318'. Drop ball,open Well Commander valve, circulating bottoms up at 920 GPM's-2410 PSI. Drop ball closing commander valve. Flow check well.Short trip pulling on elevators back to 3052'MD.Service rig.TIH back to 5040'MD,continue directional drilling to 5,743'ADT=5.56 HRS. 24 Hr = AST=.37 HRS.ART=5.19.Total Bit HRS=15.34 HRS.Total Jar Hrs= 15.34.Accumulated rotating hrs=14.51 Accumulated Sliding hrs=1.13 Slide percentage total from 3081'to 5,743=6%.Work on#2 mudpumo change out seats and valves. 00:00 02:45 2.75 4,774 5,040 PROD1 DRILL DDRL P Directional drill from 4,774'-5040' MD.ND=3,318'. Flow rate 780 GPM's-3,350 PSI on 3,300 PSI off. RPM-100,WOB-6K.On bottom TQ-7K.Off bottom torq 6K ECD's @ 9.51 PPG.Max Gas observed=17 Units.AST=0.0 Hrs.ART= 1.58 HRS.ADT=1.58 HRS.Total Jar Hrs =11.36.Total Bit HRS-11.36. 02:45 04:00 1.25 5,040 5,040 PROD1 DRILL CIRC P Held PJSM. Drop ball in drill string to land in Well commander valve.Allow to land pumping @ 2 BPM-210 PSI.Observe pressure increase to open valve @ 2500 PSI.Continue reciprocate&rotate drill string. Continue circulate&condition mud with pumps at 920 GPM's-2410 PSI.Observed considrable increase in cuttings over shakers.Monitor well -static. 04:00 04:45 0.75 5,040 5,040 PROD1 DRILL CIRC P Drop closing ball to land in well commander valve.Allow to land pumping @ 2 BPM-170 PSI. Observe pressure increase to 2780 PSI,closing valve.Clean up accumulated cuttings in trough for Trip in hole. Blow down Top Drive& lines. 04:45 07:30 2.75 5,040 3,052 PROD1 DRILL TRIP P Held PJSM. POOH on elevators form 5040'-to 3052'(inside shoe). Observed clean hole conditions. UP WT=145K,SO WT=120K. Flow check well-static. 07:30 08:30 1.00 3,052 3,052 PROD1 RIGMNT SVRG P Service Top Drive&Draw works. Change out last liner gasket on mud pump. 08:30 10:00 1.50 3,052 4,948 PROD1 DRILL TRIP P Held PJSM.Trip in hole form 3052'- 4948'MD. Observed good hole conditions with proper displacement. Page 13 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:45 0.75 4,948 5,040 PROD1 DRILL REAM P Screw into Top drive.Wash&ream from 4948'-5040'MD,with pumps at 780 GPM's-3450 PSI. 100 RPM's& 6500 ft/lbs of TQ. 10:45 12:00 1.25 5,040 5,137 PROD1 DRILL DDRL P Directional drill from 5040'-5137' MD.ND=3,363'. Flow rate 780 GPM's-3,530 PSI on 3,430 PSI off. RPM-100,WOB-6K.On bottom TQ-7K.Off bottom torq 6K ECD's @ 9.39 PPG.Max Gas observed=400 Units.AST=.13 Hrs.ART= .4 HRS.ADT=.53 HRS.Total Jar Hrs =11.89.Total Bit HRS-11.89.Crew Change 12:00 18:30 6.50 5,137 5,743 PROD1 DRILL DDRL P Directional drill from 5,137'-5,743' MD.ND=5,655'. Flow rate 774 GPM's-3,560 PSI on 3,460 PSI off. RPM-100,WOB-8K.On bottom TQ-8-9K.Off bottom torq 6K ECD's @ 9.56 PPG.Max Gas observed= 25 Units.AST=.24 Hrs.ART=3.21 HRS.ADT=3.45 HRS.Total Jar Hrs =15.34.Total Bit HRS-15.34. 18:30 00:00 5.50 5,743 5,743 PROD1 RIGMNT RGRP T Change out valves and seats on#2 mudpump.Circulate and riciprocate from 5,703'to 5,611'with#1 pump at 417 gpm, 1,200 psi,80 rpm. Torque 7-8 k, Rot wt 155k. racked stand back and continue reciprocating with same parameters while fixing mudpump.Change out auger motor in rockwasher while pump work going on. PJSM held before work undertaken. 12/12/2010 Circulate,Trip to shoe on elevators with no hole problems or swabbing. Replace fluid end on#2 mudpump# 1 cylinder,Service top drive,Slip and cut drill line.Trb to bottom to 5,977'Drill to 6,378' 00:00 01:30 1.50 5,742 5,742 PROD1 DRILL CIRC T Circulate and condition @ 5,611' while troubleshooting#2 mud pump. Flow rate 420 gpm, 1,260 psi,80 rpm.Torq 8k, Up wt 198k,do wt 132k, rot wt 160k.Checked valves and seats on#2 mud pump. 01:30 01:45 0.25 5,742 5,742 PROD1 DRILL TRIP T Trip in hole from 5,611'to 5,742' ✓ 01:45 04:00 2.25 5,743 5,977 PROD1 DRILL DDRL P Drill from 5,742'-to 5,977'ND= 3,766'. Flow rate 780 gpm,3,250 psi, rpm=100,torq on 8.5k torq off 7.5k, ECD-9.59,ADT-1.33,ART- 1.33,AST-0.0.Jar and bit hours= 16.67 04:00 06:00 2.00 5,977 5,977 PROD1 DRILL CIRC T Circulate and condition mud while troubleshooting#2 mud pump. Flow rate 400 gpm, 1,250.00 psi, rpm-80, torq on 8k, Fluid end washed on#1 cylinder of#2 mudpump. Page 14 of 26 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06:00 09:00 3.00 5,977 5,977 PROD1 DRILL TRIP T Flow check well(Static)PJSM,Trip out of hole on elevators from 5,977'to 3,527'.No hole problems encountered and no swabbing. 09:00 09:45 0.75 5,977 5,977 PROD1 DRILL REAM T Tool box safety meeting prior to backreaming through camp sands. Backream from 3,527'to 3,147' (Camp sands @ 3,433')flow rate 400 gpm,psi-1,050, rpm-80,torq-6k, Up wt 155k,do wt 120k, rot wt 135k 09:45 10:30 0.75 5,977 5,977 PROD1 DRILL CIRC T Circulate bottoms up after reaming through camp sands and trip out to 3,147'.Check gas units at bottoms up. No significant gas units detected (11 units) flow rate 400 gpm,psi- 1,050, rpm-80,torq-6k, Up wt 155k,do wt 120k, 10:30 11:00 0.50 5,977 5,977 PROD1 DRILL TRIP T Pull to shoe from 3,147'to 3,052' while pumping. units) flow rate 400 gpm,psi-1,050, rpm-80,torq-6k, Up wt 155k,do wt 120k, Flow check well(Static)Blow down topdrive and mud lines. 11:00 12:00 1.00 5,977 5,977 PROD1 DRILL OWFF T Monitor well via trip tank while changing out fluid end on#2 mudpump#1 cylinder. 12:00 14:30 2.50 5,977 5,977 PROD1 RIGMNT RGRP T Continue changing out fluid end on# 2 mudpump#1 cylinder.Slip and cut drill line, Inspect draworks chains and brakes. Run#2 mudpump 80 spm and pressure test pump to 3,600 psi. Good test. 14:30 15:30 1.00 5,977 5,977 PROD1 RIGMNT RGRP T Service top drive,crown sheaves, blocks and draworks. Check top drive for safety alert on dropped nut from top drive roller guide. 15:30 18:30 3.00 5,977 5,977 PROD1 DRILL TRIP T Trip in hole slow to avoid surging. from 3,052'to 5,977'. No hole problems encountered. Pipe filled at 5,422' 18:30 00:00 5.50 5,977 6,378 PROD1 DRILL DDRL P Drill from 5,977'to 6.378'TVD= 3,956'Flow rate 780 gpm,psi on 3,870,psi off-3,760. rpm-100, bIT WT 8K,torque on-8-9k,torq off- 7-8. ECD's-9.87, Max gas units observed-33.AST-.34,ART-1.93, ADT-2.27. Bit and Jar hrs=18.94 12/13/2010 Continue Directional Drill 9 7/8"hole from 6378'-7597'MD.TVD=4529'.Observed pump pressure steadily decrease from 3460 PSI to 2780 PSI.Trouble shoot surface equipment. Decision to POOH looking for possible washout. POOH on elevators.Good hole conditions.Observed washout 2'above tool joint in 13th stand pulled. Bit depth=6171'.Continue pull back above last short trip depth to 5800'MD.Change out DP joint.Check pump pressures against previous parameters with pumps at 780 GPM's-3640 PSI.Trip back in hole to 7597'MD. Continue drill 9 7/8"hole from 7597'-7,691'TVD-4,580' Total Bit&Jar HRS-26.83. Page 15 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 01:00 1.00 6,378 6,444 PROD1 DRILL DDRL P Directional drill from 6378'-6444' MD.TVD=3550'. Flow rate 750 GPM's-3,550 PSI on 3,460 PSI off. RPM-100,WOB-6-8K.On bottom TQ-9K.Off bottom torq 8K ECD's @ 9.81 PPG. Max Gas observed=84 Units.AST=0 Hrs.ART=.42 HRS. ADT=.42 HRS.Total Jar Hrs= 19.36.Total Bit HRS-19.36. 01:00 03:00 2.00 6,444 6,444 PROD1 RIGMNT RGRP T Circulate&Condition mud while reciprocate drill string.trouble shoot auger issues in rockwasher. Pumps @ 177 GPM's-420 PSI.50 RPM's. UP WT=209K,SO WT=134K. ROT WT= 164K. 03:00 06:00 3.00 6,444 6,741 PROD1 DRILL DDRL P Directional drill from 6444'-6741' MD.ND=4127'. Flow rate 760 GPM's-3,230 PSI on 3,300 PSI off. RPM-100,WOB-6-8K.On bottom TQ-9K.Off bottom torq 8K ECD's @ 9.75 PPG. Max Gas observed=98 Units.AST=0 Hrs.ART= 1.51 HRS.ADT= 1.51 HRS.Total Jar Hrs =20.87.Total Bit HRS-20.87. 06:00 12:00 6.00 6,741 7,149 PROD1 DRILL DDRL P Directional drill from 6741'-7149' MD.ND=4315'. Flow rate 780 GPM's-2890 PSI on 2990 PSI off. RPM-100,WOB-6-8K.On bottom TQ-9.5K.Off bottom torq 8.5K ECD's @ 9.71 PPG. Max Gas observed=160 Units.AST=.39 Hrs.ART=2.02 HRS.ADT=2.41 HRS.Total Jar Hrs=23.28.Total Bit HRS-23.28. Observed pump pressure decrease @ 0600 HRS-400 PSI. Obtained SPR's at 6932'MD ND= 4203' Mud pump#1 -30 SPM-230 PSI,40 SPM-280 PSI Mud pump#2-30 SPM-240 PSI,40 SPM-290 PSI 12:00 16:30 4.50 7,149 7,597 PROD1 DRILL DDRL P Directional drill from 7149'-7597' MD.ND=4529'.Flow rate 784 GPM's-2800 PSI on 2910 PSI off. RPM-100,WOB-4-6K.On bottom TQ-9.5K.Off bottom torq 9K ECD's @ 9.73 PPG.Max Gas observed= 560 Units.AST=.31 Hrs.ART= 2.32 HRS.ADT=2.63 HRS. Total Jar Hrs=25.91.Total Bit HRS- 25.91. Observed pump pressure decrease @ 0600 HRS-400 PSI,with continuing trends dropping to 2800 PSI w/780 GPM's.Suspect washout after checking surface equipment. Page 16 of 26 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:30 1.00 7,597 7,597 PROD1 DRILL CIRC T Circulate&conditionmud while prep to POOH.Observed 580 units of gas at surface. Flow check well. Static.Blow down Top drive&lines. 17:30 20:30 3.00 7,597 5,800 PROD1 DRILL TRIP T No Dry Job. POOH at 30-50 ft/minute.Observed good hole conditions with proper displacement. Pulled to bit depth of 6171'MD. Observed a washout 2'above the tool joint on a joint of drill pipe.Washout approximately 1 1/2"wide, 1/4"slot. Allow to drain.Continue to POOH above last short trip depth to 5800' MD. 20:30 22:00 1.50 5,800 7,597 PROD1 DRILL TRIP T Change out drill pipe joint.Screw into Top drive and check pump pressures to earlier parameters. Pumps at 780 GPM's-3640 PSI.Trip back in hole to 7597'MD.Observed good hole condtions,and proper displacement. 22:00 00:00 2.00 7,597 7,691 PROD1 DRILL DDRL P Directional drill from 7,597'-7.691' MD.ND=4,580'. Flow rate 757 GPM's-3,910 PSI on 3,790 PSI off. RPM-100,WOB-6K.On bottom TQ-10K.Off bottom torq 9K ECD's @ 9.89 PPG.Max Gas observed= 107 Units.AST=.8 0 Hrs.ART=.12 HRS.ADT=.92 HRS.Total Jar&Bit HRS-26.83. 12/14/2010 Drill from 7691'to 9165'(5508'ND)Top of Bermuda at 8897'MD 00:00 06:00 6.00 7,691 8,121 PROD1 DRILL DDRL P Drill from 7691'to 8121'(ND= 4841') SPP=3690 psi on/3550 off. Flowrate=725 gpm, TD RPM=100,Torque=14k on/ 13k off. WOB=8-10 k, P/U=260k,S/O= 133k, ROT=185k, ADT=3.05,ART=1.75,AST=1.3 Bit Hrs=29.88,Jar Hrs=29.88, Max Gas=69 units 06:00 12:00 6.00 8,121 8,476 PROD1 DRILL DDRL P Drill from 8121'to 8476'(ND= 5060') SPP=3900 psi on/3720 off. Flowrate=725 gpm, TD RPM=100,Torque=14k on/ 13k off. WOB=8-10 k, P/U=275k, S/O= 130k, ROT=190k, ADT=2.68,ART=1.23,AST=1.45 Bit Hrs=32.56,Jar Hrs=32.56, Max Gas=109 units Page 17 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 00:00 12.00 8,476 9,165 PROD1 DRILL DDRL P Drill from 8476'to 9165'(ND= 5508') SPP=4000 psi on/3950 off. Flowrate=770 gpm, TD RPM=90,Torque=12k on/13k off. WOB=2 k, P/U=275k,S/O= 130k, ROT=190k, ADT=6.29,ART=4.10,AST=2.19 Bit Hrs=38.85,Jar Hrs=38.85, Max Gas=121 units 12/15/2010 Drill from 9165'to 9352'(5629'ND). Open Commander and CBU. Close Commander and make wiper trip to 7501'. Open Commander and CBU. RIH and CBU. POOH and lay down BHA. 00:00 03:30 3.50 9,165 9,352 PROD1 DRILL DDRL P Drill from 9165'to 9352'(5629'ND) Pump pressure 3950 psi on/3870 psi off.Pump rae 750 gpm, Flow 10%) show 29%. Top drive 100 rpm,Torque= 13k on/ 12k off. WOB=6-8k, P/U=300k,S/O= 147k, Rot=200k ADT=3.83,ART=3.51,AST=.32, Bit hrs=42.68,Jar hrs=42.68 Max gas=346 units 03:30 04:00 0.50 9,352 9,352 PROD1 DRILL CIRC P Drop ball and pump down at 2 bpm 290 psi. Pressure up to 2750 psi and open Commander tool 04:00 05:00 1.00 9,352 9,352 PROD1 DRILL CIRC P Rotate and reciprocate while CBU at 910 gpm,3370 psi 05:00 05:30 0.50 9,352 9,352 PROD1 DRILL CIRC P Drop ball and pump down at 2 bpm 210 psi. Pressure up to 3170 psi to close well compander. Monitor well- -static 05:30 07:45 2.25 9,352 7,597 PROD1 DRILL WPRT P Pull out of the hole on elevators from 9352'to 7597' 07:45 08:00 0.25 7,597 7,597 PROD1 DRILL CIRC P Drop ball and pump down to open Commander tool w/3000 psi 08:00 08:45 0.75 7,597 7,597 PROD1 DRILL CIRC P Circulate at 850 gpm 2640 psi for 6000 strokes 08:45 09:15 0.50 7,597 7,597 PROD1 DRILL CIRC P Drop ball and pump down to close Commander tool with 3100 psi. Blow down top drive and monitor well- -static 09:15 10:15 1.00 7,597 9,352 PROD1 DRILL WPRT P RIH from 7597'to 9352'. 10:15 12:00 1.75 9,352 9,352 PROD1 DRILL CIRC P Circulate at 750 gpm 3900 psi for 9350 strokes. Blow down top drive and monitor well--static 12:00 13:30 1.50 9,352 8,263 PROD1 DRILL TRIP P POOH on elevators from 9352'to 8263'. P/U 220k S/O 140k 13:30 14:00 0.50 8,263 8,263 PROD1 DRILL CIRC P Pump dry job and install stripper rubbers. Blow down top drive 14:00 17:30 3.50 8,263 3,052 PROD1 DRILL TRIP P POOH on elevators from 8263'to 3052' P/U= 145k,S/O)=130k, Reduce pullilng spped to 20 fpm across Camp Sand 17:30 18:00 0.50 3,052 3,052 PROD1 DRILL OWFF P Pull rubbers and monitor well—static Page 18 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:00 2.00 3,052 683 PROD1 DRILL TRIP P POOH from 3052'to 683'. P/U= 110k S/O=110k 20:00 20:30 0.50 683 683 PROD1 DRILL OWFF P Monitor well--static 20:30 23:00 2.50 683 134 PROD1 DRILL PULD P Handle BHA. Stand back 4 stands HWDP, L/D Well Commander,2 jts HWDP,Jars and 2 non-mag collars 23:00 23:30 0.50 134 134 PROD1 DRILL PULD P PJSM and stage around doors and stairways. Remove Nuke sources from BHA 23:30 00:00 0.50 134 0 PROD1 DRILL PULD P Down load MWD and clean rig floor. SLM no change 12/16/2010 Finish down loading MWD and laying down BHA. Change upper pipe rams to 7-5/8"casing rams and test to 004' 250/5000 psi. Rig up and run 7-5/8"casing to 3102'. CBU. Run casing to 4732' 00:00 01:00 1.00 0 0 PROD1 DRILL PULD P Dowloand MWD tools and clear floor 01:00 03:45 2.75 0 0 PROD1 DRILL PULD P Continue laying down BHA#2. Laly down flex collars, DM HOC, Pulsar, HCIM. Break bit and laydown stab, float sub,and motor. Clear floor 03:45 04:30 0.75 0 0 COMPZ WHDBO RURD P Make up wear ring running tool and pull wear ring. Laydown landing joint 04:30 06:00 1.50 0 0 COMPZ WHDBO NUND P Change upper PR's to 7-5/8"casing .1g rams 06:00 06:30 0.50 0 0 COMPZ WHDBO BOPE P Make up 7-5/8"test joint and set test plug 06:30 09:15 2.75 0 0 COMPZ WHDBO BOPE P Rig up and test 7-5/8"pipe rams to 250/5000 psi. Rig down test equipment and blow down lines 09:15 12:00 2.75 0 0 COMPZ CASING RURD P Rig up and casing tools and pick up franks fill up tool. Change bales and rig up scaffolding 12:00 12:30 0.50 0 0 COMPZ CASING SFTY P Pre-job safety meeting on running 7-5/8"casing 12:30 20:30 8.00 0 3,012 COMPZ CASING RNCS P Run 7-5/8"29.7#L-80 BTCM casing per program to 3012' P/U=145k, S/O= 135k 20:30 21:30 1.00 3,012 3,012 COMPZ CASING CIRC P Circulate bottoms up staging rate up to 6 bpm @ 340 psi w/14%returns 21:30 00:00 2.50 3,012 4,732 COMPZ CASING RNCS P Continue running 7-5/8"csing from 3012'to 4732' P/U= 185k,S/O= 130k 12/17/2010 Run casing from 4732'to 5390'. CBU. Run casing from 5390'to 6906'. Hit tight spot at 6906 and attempted to circulate but hole packing off.Attempt to establish circulation without success and laid down casing to 6300'. Established circulation of 6 bpm 440 psi without packing off. Washed casing from 6300'to 6654'and began packing off. Established circulation of 5 bpm 400 psi and tried to wash to 6555'. Hole tight and packing off. Pulled pipe free. Rigged up to lay down casing and laid down casing from 6526'to 5600'. 00:00 01:00 1.00 4,732 5,390 COMPZ CASING RNCS P Continue running 7-5/8"casing from 4732'to 5390' P/U=200k, S/0=130k 01:00 01:45 0.75 5,390 5,390 COMPZ CASING CIRC P Circulate bottoms up at 5390'at 6 bpm,510 psi, 01:45 05:15 3.50 5,390 6,906 COMPZ CASING RNCS P Continue running casing from 5390' to 6906'. Had tight spot at 6127', 6300',6384',6727'. Tight and packing off 6906' Page 19 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 09:30 4.25 6,906 6,906 COMPZ CASING CIRC T Attempt to establish circulation at 6906'at 1.5 bpm,230 psi. continuing to pack off. Work pipe and continue to try to establish circulation 09:30 12:45 3.25 6,906 6,300 COMPZ CASING PULL T Safety meeting. Lay down casing from 6906'to 6300' 12:45 14:00 1.25 6,300 6,300 COMPZ CASING CIRC T Work string w/P/U=220k,S/O= 150k,and break circulation at 2 bpm 200 psi. Increase rate to 6 bpm @ 440 psi w/no packoff 14:00 15:30 1.50 6,300 6,609 COMPZ CASING RNCS T Run in hole with casing from 6300'to 6609'. Circulate casing down at 5.5 bpm at 400 psi 15:30 17:00 1.50 6,609 6,530 COMPZ CASING RNCS T Run in hole from 6609'to 6654'and began packing off. Laid down 3 joints 17:00 18:00 1.00 6,530 6,530 COMPZ CASING CIRC T Work string and break circulation at 2 bpm 200 psi. Increase rate to 5 bpm 400 psi 18:00 21:00 3.00 6,530 6,555 COMPZ CASING RNCS T Run in hole with casing from 6530'to 6555'while circulating at 5 bpm 400 psi and packed off. Pulled joint free with 275k and attempted to establish circulation 21:00 22:00 1.00 6,555 6,555 COMPZ CASING RURD T Rig down fill up tool,350 T elevators and long bales. R/U short bales and 150 elevators. Change out power tongs 22:00 00:00 2.00 6,555 5,600 COMPZ CASING PULL T Lay down 7-5/8"casing from 6526'to 5600' 12/18/2010 Finish POOH and laying down 7-5/8"casing. Lost one bowspring centralizer in hole. Changed upper pipe rams to 3-1/2"x 6"VBR's. Pulled wear ring and set test plug. Tested upper pipe rams to 250/5000 psi. Made up clean out BHA. 00:00 12:45 12.75 5,600 0 COMPZ CASING PULL T Finish pulling out of the hole with r(iD 7-5/8"casing. Back out Baker-locked connections.Clear floor 12:45 13:15 0.50 0 0 COMPZ CASING RURD T Rig down casing tongs and elevators. 13:15 13:30 0.25 0 0 COMPZ WHDBO SFTY T Safety meeting on changing pipe rams 13:30 15:00 1.50 0 0 COMPZ WHDBO RURD T Change top pipe rams to 3-1/2"x 6" VBR's 15:00 17:00 2.00 0 0 COMPZ WHDBO RURD T Pull wear ring and rig up to test pipe rams with 5"test joint. 17:00 18:00 1.00 0 0 COMPZ WHDBO BOPE T Test upper Pipe rams to 250/5000 psi 18:00 18:30 0.50 0 0 COMPZ WHDBO RURD T Rig down test equipment and install wear bushing 18:30 19:30 1.00 0 0 COMPZ CASING OTHR T Finish cleaning rig floor 19:30 22:00 2.50 0 134 COMPZ CASING PULD T Make up cleanout BHA 22:00 23:30 1.50 134 233 COMPZ CASING TRIP T Run in the hole with BHA to 233' 23:30 00:00 0.50 233 233 COMPZ RIGMNT RGRP T Trouble shoot rod wash pump on mud pumps Page 20 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/19/2010 24 hr Summary Pulse test MWD.Continue picking up BHA and run in the hole to 6445'where string took 20k weight. Wash and ream from 6445'to 7900'at 750 gpm,3350 psi, 100 rpm,torque=9.5k ft-lbs. Run in the hole from 7900' to 9130'. Wash and ream from 9130'to 9352'at 750 gpm,3650 psi, 100 rpm, 10k ft-lbs torque. Pumpout of the hole from 9352'to 4114'. 00:00 01:00 1.00 233 607 COMPZ CASING PULD T Pulse tested MWD.Continued picking up BHA and jars, HWDP and Commander sub. 01:00 05:00 4.00 607 6,445 COMPZ CASING TRIP T RIH from 607'to 6,445'.String took 20 to 30 K down weight @ 6,445'. 05:00 10:45 5.75 6,445 7,900 COMPZ CASING REAM T Washed and reamed from 6,445'to 6,546'j_: stuck on the Backream Aa 6,546'.Worked pipe free going down.Continued Working up and down. Possible contact with the Bowspring centralizer left in hole. Continued to ream in to 7,900'hole conditions good last 300'. RPM 100, GPM 750, PP 3350 psi,Top Drive Torque 9,500 Ft Lbs. 10:45 11:30 0.75 7,900 9,130 COMPZ CASING TRIP T RIH from 7,900'to 9,252'. 11:30 12:30 1.00 9,130 9,352 COMPZ CASING REAM T Precautionary wash from 9,130'to 9,352'hole conditions good last 300'. RPM 100,GPM 750, PP 3650 psi, Top Drive Torque 10,000 Ft Lbs. 12:30 00:00 11.50 9,352 4,114 COMPZ CASING TRIP T Pump out of the hole from 9352'to 4114'MW, Pump @ 600 gpm/3800 psi, 100 rpm, Torque=15-16k ft-lbs, P/U=270-160k,S/O=120-170k Lost 53 bbl mud while pumping out of the hole. 12/20/2010 Back ream out of the hole from 4114'to 3068'. Open commander tool and circulate hole clean. Close commander tool. RIH to 4017'. Back ream out of the hole from 4017'to 3353'. CBU. Pull out of the hole on elevators from 3353'to 2510'. Pulled tight. Jarred and worked pipe free. Reamed down to 3070'. RIH to 9259'. Washed and reamed to 9352'for safety. Opened commander tool and circulated hole clean at 950 gpm. Monitored well--static. Pull out of the hole on elevators from 9352'to 8370'. 00:00 02:45 2.75 4,114 3,068 COMPZ CASING TRIP T Back ream out of the hole from 4114' to 3068', Pump at 600 gpm, 1750 psi, 100 rpm,torque=5k ft-lbs, P/U = 155k,S/O=120k, Rot=133k, Tight spot at 3742' Monitored well- -static 02:45 03:00 0.25 3,068 3,068 COMPZ CASING CIRC T Drop ball to open well commander- -Pump ball down at 2 bpm 120 psi, Pressure up to 3050 psi to open 03:00 04:15 1.25 3,068 3,068 COMPZ CASING CIRC T Circulate until hole clean. Unloaded large amount of cuttings. Monitored well--static 04:15 05:15 1.00 3,068 3,068 COMPZ RIGMN1SVRG T Service rig and top drive. Grease crown. Change out EDMS on PVT system. Monitored well--static 05:15 06:30 1.25 3,068 3,068 COMPZ CASING CIRC T Continue circulating through commander tool. Monitored well-v.slight flow which died Page 21 of 26 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06:30 07:30 1.00 3,068 3,068 COMPZ CASING CIRC T Drop ball and close commander tool. Insure tool closed by pumping at 600 gpm 1790 psi 07:30 08:00 0.50 3,068 4,017 COMPZ CASING TRIP T Run in hole from 3068'to 4017' Tight spot at 3817', P/U= 147k,3/0= 125k 08:00 10:45 2.75 4,017 3,353 COMPZ CASING TRIP T Back ream out of the hole from 4017' to 3053'at 500 gpm, 1280 psi, 100 rpm, Observed packing off at 3817'. Work through tight spots to insure cleaned up 10:45 12:00 1.25 3,353 3,353 COMPZ CASING CIRC T CBU at 750 gpm,2660 psi,100 rpm, Monitor well--static 12:00 12:30 0.50 3,353 2,510 COMPZ CASING TRIP T Pull out of hole on elevators from 3353'to 2510' P/U= 128k,s/0= 120k 12:30 15:00 2.50 2,510 2,545 COMPZ CASING OTHR T Pulled tight at 2510'. P/U 250= 250k,S/0=70k,Attempt to jar free. Break circulation at 2 bpm--no returns. Attempt to rotate and slack off. Broke free w/25 rpm. Continue to work pipe. P/U single and continue to work pipe 15:00 16:00 1.00 2,545 3,070 COMPZ CASING REAM T L/D single and ream down to 2600'. RIH to 3070'. Circulate at 200 gpm, 420 psi, P/U=130k,S/0-120k, Monitor well--static. Blowdown top drive 16:00 19:30 3.50 3,070 9,259 COMPZ CASING TRIP T Run in hole from 3070'to 9259' 19:30 20:00 0.50 9,259 9,352 COMPZ CASING REAM T Wash and ream to bottom from 9259' to 9352'. drop bal and pump down at 2 bpm, Opened circ sub with 3300 psi 20:00 22:00 2.00 9,352 9,352 COMPZ CASING CIRC T Circulate hole clean. Work string from 9352'to 9262'. Pump at 950 gpm, P/U=250k,S/0=160k, • Monitor well--static. Lost 40 bbl mud while circulating 22:00 00:00 2.00 9,352 8,370 COMPZ CASING TRIP T Pull out of the hole on elevators from 9352'to 8370' Pump dry job and continue to POOH on elevators. 12/21/2010 Finish POOH. Laydown BHA. Change upper pipe rams to 7-5/8"casing rams. Test 7-5/8"casing rams to 250/5000 psi. Rig up and run 7-5/8"casing to 3070'. CBU. Run casing to 5086'. CBU. Run casing to 7227'. CBU 00:00 04:45 4.75 8,370 607 COMPZ CASING TRIP T Continue POOH on elevators from 8370'to 607'. Monitor well—static 04:45 06:00 1.25 607 0 COMPZ CASING TRIP T Handle BHA 06:00 08:00 2.00 0 0 COMPZ CASING PULD T Laydown flex collar,pulsar,stab and MWD components. Clear rig floor 08:00 09:15 1.25 0 0 COMPZ WHDBO NUND T Change upper pipe rams to 7-5/8" casing rams 09:15 09:45 0.50 0 0 COMPZ WHDBO NUND T Pull wearring and set test plug. 09:45 11:15 1.50 0 0 COMPZ WHDBO BOPE T Rig up and test 7-5/8"casing rams 11‘7°C°C to 250/5000 psi D Page 22 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11:15 13:00 1.75 0 0 COMPZ CASING RURD T Rig up to run 7-5/8"casing 13:00 17:00 4.00 0 3,070 COMPZ CASING RNCS T Rig up and run casing to 3070'. Pick up shoe track and check floats. Fill casing every 10 jts. P/U=141k,s/O =130k. 17:00 17:30 0.50 3,070 3,070 COMPZ CASING CIRC T Break circulation and circulate bottoms up at 4 bpm, 180 psi. 17:30 20:00 2.50 3,070 5,086 COMPZ CASING RNCS T Continue RIH with casing from 3070' to 5086'. Fill casing every 10 jts. P/U=180k,S/O=140k 20:00 21:00 1.00 5,086 5,086 COMPZ CASING CIRC T Break circulation and circulate bottoms up at 4 bpm 250 psi. Reciprocate casing while circulating 21:00 23:00 2.00 5,086 7,227 COMPZ CASING RNCS T Continue RIH with casing crom 5086' to 7227'. Fill casing every 10 jts. P/U=240k.S/O=160k. 23:00 00:00 1.00 7,227 7,227 COMPZ CASING CIRC P Break circulation and circulate bottoms up at 4 bpm,225 psi. Reciprocate casing while circulating 12/22/2010 Finish running 7-5/8"casing to 9344'. Circulate and condition mud. Rig up and pump 40 bbl CW8 followed by 40 MudPush II at 13.0 ppf. Drop bottom plug. Mix and pump 171 bbl Tail slurry at 15.8 ppg. Drop top plug and pump 10 bbl CW8. Displace with 416 bbl seawater with rig pump. Did not bump plug. Checked floats-ok. Rig down cementing equipment and casing tools. Lay down landing joint and set packoff. Test packoff to 250/5000 psi for 15 minutes--ok. Set test plug and change upper pipe rams to 3-1/2"x 6"VBR's. Rig up and begin testing BOPE. Jeff Jones,AOGCC,waived witnessing BOPE test. 00:00 03:15 3.25 7,227 9,344 COMPZ CASING RNCS P Continued running 7-5/8"casing. Landing casing on hanger with shoe at 9344.30' P/U=275k S/O= 178k 03:15 04:00 0.75 9,344 9,344 COMPZ CEMEN-RURD P Rig down Frank's fillup tool and casing equipment. Rig up cement head ✓ 04:00 08:45 4.75 9,344 9,344 COMPZ CEMEN-CIRC P Circulate and condition mud at 6 bpm,430 psi, While reciprocating casing 08:45 09:00 0.25 9,344 9,344 COMPZ CEMEN"SFTY P Pre-job safety meeting with rig, cement crew and truck drivers to discuss cement job 09:00 12:30 3.50 9,344 0 COMPZ CEMEN"PUCM P Mix and pump 10 bbl CW8. �SJ�" Pressure test lines to 3500 psi. Mix // and pump 30 bbl CW8 and 40 bbl G�� MudPush II at 13.0 ppg. Drop bottom plug. Mix and pump 147 bbl Tail cement at 15.8 ppg(730 sx). Drop top plug and pump 10 bbl CW8 followed by 4158 strokes of seawater with rig pump. Plug did not bump. Check floats-OK. Bled back 2.5 bbl 12:30 14:45 2.25 0 0 COMPZ CEMEN"RURD P Rig down cement head. Back out landing joint and crossover. Lay down cement head and casing swedge. Lay down long bales. Rig up short bales and connect linkage. Clear floor 14:45 16:30 1.75 0 0 COMPZ WHDBO NUND P Make up 5"test joint and FMC (�4 running tool. Install packoff and test to 5000 psi for 15 minutes Page 23 of 26 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 16:30 17:00 0.50 0 0 COMPZ WHDBO NUND P Pick up test joint and set test plug 17:00 17:15 0.25 0 0 COMPZ WHDBO SFTY P Pre-job safety meeting on changing BOP rams 17:15 19:15 2.00 0 0 COMPZ WHDBO RURD P Change upper pipe rams to 3.5"x 6" VBR's 19:15 19:30 0.25 0 0 COMPZ WHDBO SFTY P Pre-job safety meeting on testing BOPE 19:30 21:00 1.50 0 0 COMPZ WHDBO RURD P Rig up to test BOPE , 11 /) 21:00 00:00 3.00 0 0 COMPZ WHDBO BOPE P Test BOPE Test annular to 25/3500 psi. Jeff Jones,AOGCC,waived witnessing the test -02/ 12/23/2010 Finish testing all BOPE components to 250/5000 psi except for annular which was tested to 250/3500 psi. Rig up tubing equipment and chemical injection line spooler. Run 3-1/2"completion string and jewelry to 5610'. Little Red flushed the OA with 290 bbl seawater and freeze protected it with 122 bbl diesel. 00:00 09:00 9.00 0 0 COMPZ WHDBO BOPE P Continue BOP test. Test all manifold valves and rams to 250/5000 psi. Test annular to 250/3500 psi. Perform Koomey test. Rig down and blow down all lines. Clean and clear floor 09:00 12:30 3.50 0 0 COMPZ RPCOM RURD P Safety meeting on rigging up. Rig up tubing tongs.elevators,and slips. Rig up Camco chemical injection line spooler. 12:30 00:00 11.50 0 5,610 COMPZ RPCOM PUTB P Pick up 3-1/2"9.3#L-80 EUE-8rd-mod tubing from the pipe shed and run in the hole to 5610'. P/U=105k,S/O=100k 12/24/2010 Finish running 3-1/2"completion string with bottom of WLEG at 8850'MD. Pump 90 bbl inhibitted seawater down tubing(tubing volume =76 bbl). Drop 2"steel setting ball and let fall for 30 minutes. Pump 76 bbl sseawater down tubing in attempt to get setting ball on seat without success. Rig up slickline and chase ball down to 8850'. Rig down slickline. Pressure up on tubing to 2500 psi and hold for 5 minutes to set packer. Increase tubing pressure to 3100 psi and sheared ball seat in WLEG. Bled tubing pressure to 1000 psi and picked up on tubing to shear seals out of PBR. Bled off pressure. Spaced out tubing and hanger. Made connection with chem injection line through tubing hanger and tested same to 5000 psi--ok. Landed hanger and ran in lockdown screws. Tested tubing to 3500 psi for 30 minutes--ok. Bled tubing pressure to 2000 psi and tested 7-5/8"x 3-1/2"annulus to 3000 psi for 30 minutes--ok. Bled tubing pressure off to shear SOB in GLM#4 w/o success had to pressure up and bleed off annulus pressure two times with tubing pressure at 0 psi to get SOV to shear. Rig down test equipment and crossovers. Back out landing joint and lay down. 00:00 04:45 4.75 5,610 8,850 COMPZ RPCOM PUTB P Continue picking up tubing and running in the hole from 5610'to 8850'. 04:45 05:30 0.75 8,850 8,850 COMPZ RPCOM RURD P Rig up to circulate inhibited seawater 05:30 06:45 1.25 8,850 8,850 COMPZ RPCOM CIRC P Pump 90 bbl inhibitted seawater at 2 bpm 06:45 10:30 3.75 8,850 8,850 COMPZ RPCOM PACK T Drop 2"setting ball and attempt to pump ball on seat without success. Wait on slickline unit 10:30 10:45 0.25 8,850 8,850 COMPZ RPCOM SFTY T Pre job safety meeting with crew and slick line personnel 10:45 12:30 1.75 8,850 8,850 COMPZ RPCOM RURD T Rig up slickline 12:30 15:00 2.50 8,850 8,850 COMPZ RPCOM SLKL T Run in hole with slick line to 8862' SLM to chase setting ball on seat Page 24 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 15:30 0.50 8,850 8,850 COMPZ RPCOM RURD T Rig down slickline 15:30 19:30 4.00 8,850 8,850 COMPZ RPCOM HOSO P Pump down tubing and insure setting ball was on seat. Pressure up on tubing to 2500 psi to set the packer and hold for 5 minutes. Increase tubing pressure to shear ball seat out of WLEG and seat sheared at 3000 psi. Bled tubing pressure to 1000 psi and picked up on string to shear pins in PBR. Sheared at 30K over string weight. Bled off tubing pressure and laid down 3 joints for space out. Picked up hanger and space out pup. Made up hanger and made connection with chemical injection line. Test injection line connection to 5000 psi--OK. Land hanger and run in LDS's. 19:30 20:30 1.00 8,850 8,850 COMPZ RPCOM RURD P Rig up to test tubing and annulus 20:30 23:00 2.50 8,850 8,850 COMPZ RPCOM PRTS P Test tubing to 3500 psi for 30 minutes--ok. Bleed tubing pressure to 2000 psi and test annulus to 3000 e psi for 30 minutes--ok. Bleed tubing \ 0. pressure to 0 psi to shear SOV in `l ` GLM#4 w/o success. Pressured7,„44' up on tubing and bled tubing pressure to 0 psi several times w/o success. Left tubing pressure at 0 psi and bled annulus pressure to 0 psi. Pressured up on annulus to 3000 psi and bled to 0 two times before SOV sheared. 23:00 00:00 1.00 8,850 8,850 COMPZ RPCOM RURD P Rig down cross overs and head pin. Backed out and laid down landing joint.. Installed TWC in tubing hanger 12/25/2010 Clear rig floor. Nipple down BOPE and nipple up Xmas tree. Test tree and tubing head adapter to 5000 psi. Cut and slip 120'of drilling line. Freeze protect well by pumping 98 bbl diesel down IA taking returns up tubing. Shutdown and put IA and tubing in communication to U-tube. Slip and cut 120'of drilling line. Set BPV. Tubing pressure=40 psi, IA=40 psi,OA=600 psi. Lay down drill pipe out of derrick 00:00 06:30 6.50 8,850 0 COMPZ DRILL OTHR P Clear rig floor. Change elevators. Blow down choke and kill lines. Blow down choke manifold. Clean pits and rock washer. Bleed off accumulator pressure. Clean drip pans. 06:30 13:00 6.50 0 0 COMPZ WHDBO NUND P Nipple down BOPE. 13:00 17:00 4.00 0 0 COMPZ WHDBO NUND P Install tubing head adapter and test to 5000 psi. Nipple up tree and test to 5000 psi. Pull BPV. 17:00 20:00 3.00 0 0 COMPZ DRILL FRZP P Freeze protect well by pumping 98 bbl of diesel down IA taking returns up tubing. Max rate 1 bpm. Shut down and put IA and tubing in communication. Page 25 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:00 22:00 2.00 0 0 COMPZ RIGMNT SVRG P Cut and slip 120'of drilling line. Inspect brakes and linkage. 22:00 23:00 1.00 0 0 COMPZ DRILL OTHR P Check pressure on well: TP=40 psi, IA=40 psi,OA=600 psi. Rig up lubricator and set BPV. Rig down lubricator 23:00 00:00 1.00 0 0 COMPZ DRILL PULD P Transfer pipe in derrick and lay down 5"drill pipe out of the derrick 12/26/2010 Finished laying down 5"drillpipe out of the derrick. Released rig at 12:00 hrs, 12/26/2010 to move to 2L-320 00:00 04:30 4.50 0 0 COMPZ DRILL PULD P Continue laying down 5"drillpipe from derrick. Stage rockwasher away from rig in preparation for rig move 04:30 05:30 1.00 0 0 COMPZ RIGMNTSVRG P Service rig and top drive 05:30 11:00 5.50 0 0 COMPZ DRILL PULD P Finish laying down drill pipe from derrick. Disconnect rig from highline 11:00 12:00 1.00 0 0 COMPZ DRILL OTHR P Clear and organize rig floor after laying down drillpipe. Released rig at 12:00 hrs 12/26/2010 to move to 2L-320 Page 26 of 26 ore,-..., KUP 2L-312 ConocoPh llips l'r x 'ted A Well..Attribute. Max/ Angle&MD TD ^fit } /''// Wellbore APUUWI I Field Name (Well Status llnel(°) I MD(ftKB) Act Btu(ROB) ,,,,,,,,,.11 501032062600 TARN PARTICIPATING AREA PROD i 9,352.0 • Comment H2S(ppm) Date Annotation 'End Date KB-Grd(ft) Rig Release Date •'- SSSV:NIPPLE I I Last WO: I 40.00 12/28/2010 WaL0v88g,O0.S/lA 272 A/?0i 1.3.4194 PM.,., Annotation Depth(ftKB) I End Date (Annotation Last Mod...I End Date Last Tag: Rev Reason:NEW WELL Imosbor 1/24/2011 Casing Strings p _ Casing Description String 0... String ID...Top(MKS) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd Are � HANGER,37 - �. CONDUCTOR 16 15.750 40.0 110.0 110.0 164.00 1031 WELDED ;M J _r _ ��•" - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Sat Depth(TVD)...String Wt...String...String Top Thad SURFACE 10 3/4 9.950 42.0 3,070.9 2,401.7 45.50 L-80 BTC � Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 5/8 6 875 38.9 9,344.3 5,624.4 29.70 L-80 BTCM 4, 'Sim, _tdti, N ` "> _ : 4/MO- ._._-. _..-.. Tubing Strings ! Tubing Description 'String 0... String ID--.Top IRKS) Depth(f...Set Depth(ND)..String Wt.. String..String Top Thrd TUBING 3 1/2 2.992 36.6 8,848.3 I 5,302.5 Set 9.30 I L-80 EUE8rdABMOD 7Completion Details "' Top Depth 1. III'� (ND) Top Incl NomL.. L ftKB) P ;:� Top(fe(B ( (1 Thar Description Comment ID(in) Pace out ups,71 § 'I 36.6 36.6 -0.01 HANGER FMC TUBING HANGER 2.992 481.7 481.7 2.21 NIPPLE Camco DS Nipple w/2.875"profile 2.875 CONDUCTOR, 110 � 8,706-9 5,210.9 49.64 SLEEVE Baker CMU sliding sleeve w/2 813"DS profile 2.812 - y 8,754.3 5,241.6 49.67 SEAL ASSY Seal Assembly spaced above PBR 2.990 NIPPLE,482 1 Ar., 8,762.3 5,246.8 49.68 PER Baker 80-40 SEE and PBR 4.000 f 8,785.3 5,261.7 49.70 PACKER BAKER FHL PACKER 2.940 8,833.8 5,293.1 49.73 NIPPLE CAMCO'D'NIPPLE w/2.75 PROFILE 2.750 8,8474 5,301.9 49.74 WLEG WIRELINE ENTRY GUIDE 2.950 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE, I. eI Top Depth' 42-3,011 . (MD) Top Incl Top(ftl(B) (ftKB) ICI Description Comment Run Date ID(ift.)_ 36.7 36.7 -0.01 INJ LINE CHEMICAL INJECTION LINE FROM MANDEL R5 TO 12/142010 0.049 1111, p: TUBING HANGER Notes:General&Safety GAS LIFT, I `.. End Date Annotation 3,271 ' 124/2010 NOTE:VIEW SCHEMATIC wiAlaska Schematic9.0 I INJ LINE,37 11 � I. ' 1 : GAS LIFT, =... 6,047 l I'. GAS]L,]5FT9I , y5 I I, I ;'h GAS LIFT, 6,800 at 1 . CHEMICAL, 6,656 1111 SLEEVE,8,707-- II SEAL ASSY, 8,754 1:11t 1 PACKER,8,785 'S- Mandrei�tail§Top Depth ndPort (ND) I I OD Valve Latch SR. TRO Run Sin Top(ftKB) (ROB) I.) Make Model (in) Sery Type Tyne Eel (psi) Run Data Com._1 3,270.7 2,490.2 64.30.CAMCO'MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/142010 NIPPLE,8,634 ----- i`. 2 6,046.9 3,801.4 62.37 CAMCOiIMMG 1 12 GAS LIFT DMY RK 0.000 0.0 12/142010 3 7,759.6 4,618.8 55.24 CAMCOI MMG 1 12 GAS LIFT DMY RK 0.000' 0.0 12)142010 I 5 8,656.4 5,177.2 48.60 CAMCO MMG 1 12 GAS LIFT SOV RKP 0.000 0.0 12/142010 WLEG,8,84]--- - -- KBMG-LTS 1 CHEM CHEM BK-5 0.000 0.0 121142010 PRODUCTION, :I 39-9,344 TO,9.352 N e, ;4, v. N 54 • 0 T.4 I y F1 s to r • k ConocoPhillips(Alaska) Inc. P Kuparuk River Unit 4 '4 Kuparuk 2L Pad il 1te gid § 2L-312 • N • 01 41 501032062600 4 da W Via _ p • 1 Sperry Drilling 1Definitive Survey Report it s, 4 A 0 10 January, 2011 • f , M I 4 4 h a R. 51 di 0 z to HALLIBURT©N Sperry Drilling 0 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-312(Cassidy) Project: Kuparuk River Unit TVD Reference: 2L-312 @ 154.90ft(D15(40.1+114.8)) Site: Kuparuk 2L Pad MD Reference: 2L-312 @ 154.90ft(D15(40.1+114.8)) Well: 2L-312(Cassidy) North Reference: True Wellbore: 2L-312 Survey Calculation Method: Minimum Curvature Design: 2L-312 Database: CPAI EDM Production Project Kuparuk River Unit 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 2L-312(Cassidy) Well Position +NI-S 0.00 ft Northing: 5,927,671.64 ft Latitude: 70° 12'48.036 N +EI-W 0.00 ft Easting: 460,976.08 ft Longitude: 150°18'53.001 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.80ft Wellbore 2L-312 Magnetics Model Name Sample Date Declination Dip Angle I' ' Field Strength ' (°) (0) (nT) BGGM2009 12/2/2010 21.14 80.71 57,650 Design 2L-312 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.10 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) 40.10 0.00 0.00 100.74 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 169.00 1,007.00 2L-312 Gryo(2L-312) CB-GYRO-SS Camera based gyro single shot 12/2/2010 12:C 1,082.50 3,032.01 2L-312(R100)(2L-312) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/2/2010 12:C 3,105.70 9,313.29 2L-312(R200)(2L-312) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/9/2010 12:C 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 40.10 0.00 0.00 40.10 -114.80 0.00 0.00 5,927,671.64 460,976.08 0.00 0.00 UNDEFINED 169.00 0.46 141.78 169.00 14.10 -0.41 0.32 5,927,671.23 460,976.39 0.36 0.39 CB-GYRO-SS(1) 258.00 0.45 352.28 258.00 103.10 -0.34 0.49 5,927,671.30 460,976.57 0.99 0.55 CB-GYRO-SS(1) 351.00 0.48 287.73 351.00 196.10 0.14 0.07 5,927,671.78 460,976.15 0.53 0.05 CB-GYRO-SS(1) 440.00 0.93 70.37 439.99 285.09 0.50 0.40 5,927,672.13 460,976.48 1.51 0.30 CB-GYRO-SS(1) 530.00 3.69 53.02 529.91 375.01 2.48 3.40 5,927,674.11 460,979.49 3.13 2.88 CB-GYRO-SS(1) 628.00 5.71 46.08 627.58 472.68 7.76 9.43 5,927,679.35 460,985.55 2.14 7.82 CB-GYRO-SS(1) 724.00 6.49 50.46 723.03 568.13 14.53 17.06 5,927,686.08 460,993.21 0.95 14.05 CB-GYRO-SS(1) 818.00 8.78 52.71 816.19 661.29 22.26 26.86 5,927,693.76 461,003.05 2.46 22.24 CB-GYRO-SS(1) 912.00 11.78 55.81 908.67 753.77 32.00 40.51 5,927,703.43 461,016.75 3.24 33.84 CB-GYRO-SS(1) 1,007.00 13.16 66.24 1,001.44 846.54 41.81 58.43 5,927,713.14 461,034.72 2.77 49.62 CB-GYRO-SS(1) 1,082.48 15.63 69.65 1,074.55 919.65 48.81 75.83 5,927,720.05 461,052.15 3.46 65.41 MWD+IFR-AK-CAZ-SC(2) 1/1012011 1:08;55PM Page 2 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-312(Cassidy) Project: Kuparuk River Unit TVD Reference: 2L-312 @ 154.90ft(D15(40.1+114.8)) Site: Kuparuk 2L Pad MD Reference: 2L-312 @ 154.90ft(D15(40.1+114.8)) Well: 2L-312(Cassidy) North Reference: True Wellbore: 2L-312 Survey Calculation Method: Minimum Curvature Design: 2L-312 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 1,158.36 18.85 68.98 1,147.01 992.11 56.76 96.87 5,927,727.90 461,073.22 4.25 84.59 MWD+IFR-AK-CAZ-SC(2) 1,248.69 21.63 69.55 1,231.75 1,076.85 67.81 126.09 5,927,738.80 461,102.50 3.09 111.25 MWD+IFR-AK-CAZ-SC(2) 1,345.34 24.28 72.12 1,320.75 1,165.85 80.14 161.70 5,927,750.94 461,138.17 2.93 143.93 MWD+IFR-AK-CAZ-SC(2) 1,387.50 25.45 72.37 1,359.00 1,204.10 85.55 178.58 5,927,756.25 461,155.08 2.79 159.51 MWD+IFR-AK-CAZ-SC(2) 1,435.11 26.13 72.40 1,401.86 1,246.96 91.81 198.33 5,927,762.42 461,174.86 1.43 177.74 MW D+IFR-AK-CAZ-SC(2) 1,531.07 29.93 72.41 1,486.55 1,331.65 105.44 241.30 5,927,775.83 461,217.90 3.96 217.43 MWD+IFR-AK-CAZ-SC(2) 1,625.57 34.77 74.08 1,566.36 1,411.46 119.97 289.72 5,927,790.10 461,266.38 5.21 262.29 MWD+IFR-AK-CAZ-SC(2) 1,725.25 37.91 76.86 1,646.65 1,491.75 134.73 346.89 5,927,804.56 461,323.62 3.56 315.71 MWD+IFR-AK-CAZ-SC(2) 1,820.32 40.91 80.35 1,720.11 1,565.21 146.59 406.04 5,927,816.12 461,382.83 3.92 371.61 MWD+IFR-AK-CAZ-SC(2) 1,912.44 43.04 83.99 1,788.60 1,633.70 154.94 467.06 5,927,824.15 461,443.88 3.51 430.00 MWD+IFR-AK-CAZ-SC(2) 2,007.81 45.92 88.55 1,856.66 1,701.76 159.22 533.70 5,927,828.08 461,510.54 4.51 494.68 MWD+IFR-AK-CAZ-SC(2) 2,104.02 48.31 92.74 1,922.14 1,767.24 158.38 604.16 5,927,826.88 461,580.98 4.04 564.06 MWD+IFR-AK-CAZ-SC(2) 2,198.61 50.37 95.35 1,983.77 1,828.87 153.29 675.71 5,927,821.42 461,652.51 3.02 635.31 MWD+IFR-AK-CAZ-SC(2) 2,288.99 54.28 96.09 2,039.00 1,884.10 146.15 746.88 5,927,813.91 461,723.63 4.37 706.56 MWD+IFR-AK-CAZ-SC(2) 2,380.40 57.72 94.40 2,090.11 1,935.21 139.25 822.33 5,927,806.62 461,799.03 4.06 781.98 MWD+IFR-AK-CAZ-SC(2) 2,479.44 60.69 92.13 2,140.82 1,985.92 134.43 907.25 5,927,801.36 461,883.92 3.59 866.31 MWD+IFR-AK-CAZ-SC(2) 2,576.77 61.97 92.58 2,187.51 2,032.61 130.92 992.57 5,927,797.41 461,969.22 1.38 950.79 MWD+IFR-AK-CAZ-SC(2) 2,668.31 63.46 93.30 2,229.48 2,074.58 126.74 1,073.82 5,927,792.82 462,050.43 1.77 1,031.39 MWD+IFR-AK-CAZ-SC(2) 2,764.88 65.85 94.53 2,270.81 2,115.91 120.77 1,160.88 5,927,786.40 462,137.45 2.73 1,118.04 MWD+IFR-AK-CAZ-SC(2) 2,861.75 64.88 94.72 2,311.19 2,156.29 113.67 1,248.64 5,927,778.85 462,225.17 1.02 1,205,59 MWD+I FR-AK-CAZ-SC(2) 2,954.78 64.31 94.40 2,351.10 2,196.20 106.99 1,332.41 5,927,771.74 462,308.89 0.69 1,289.13 MWD+IFR-AK-CAZ-SC(2) 3,032.01 64.03 94.85 2,384.75 2,229.85 101.39 1,401.70 5,927,765.77 462,378.14 0.64 1,358.25 MWD+IFR-AK-CAZ-SC(2) 3,105.70 63.50 95.69 2,417.33 2,262.43 95.32 1,467.52 5,927,759.36 462,443.92 1.25 1,424.05 MWD+IFR-AK-CAZ-SC(3) 3,201.03 63.78 97.30 2,459.66 2,304.76 85.65 1,552.38 5,927,749.26 462,528.73 1.54 1,509.23 MWD+IFR-AK-CAZ-SC(3) 3,296.15 64.33 96.17 2,501.27 2,346.37 75.63 1,637.32 5,927,738.80 462,613.61 1.21 1,594.55 MWD+IFR-AK-CAZ-SC(3) 3,391.17 64.45 96.56 2,542.34 2,387.44 66.13 1,722.48 5,927,728.86 462,698.71 0.39 1,679.99 MWD+IFR-AK-CAZ-SC(3) 3,486.93 64.40 94.56 2,583.69 2,428.79 57.76 1,808.45 5,927,720.05 462,784.62 1.88 1,766.00 MWD+IFR-AK-CAZ-SC(3) 3,580.62 62.62 94.68 2,625.47 2,470.57 51.00 1,892.02 5,927,712.86 462,868.15 1.90 1,849.38 MWD+IFR-AK-CAZ-SC(3) 3,676.13 62.50 94.94 2,669.49 2,514.59 43.90 1,976.49 5,927,705.32 462,952.57 0.27 1,933.69 MWD+IFR-AK-CAZ-SC(3) 3,770.60 61.82 94.09 2,713.61 2,558.71 37.32 2,059.76 5,927,698.31 463,035.80 1.07 2,016.73 MWD+IFR-AK-CAZ-SC(3) 3,865.11 61.61 94.23 2,758.39 2,603.49 31.28 2,142.77 5,927,691.85 463,118.77 0.26 2,099.41 MWD+IFR-AK-CAZ-SC(3) 3,959.77 61.26 94.66 2,803.65 2,648.75 24.84 2,225.66 5,927,684.97 463,201.61 0.54 2,182.04 MWD+IFR-AK-CAZ-SC(3) 4,055.47 61.00 94.99 2,849.86 2,694.96 17.79 2,309.17 5,927,677.50 463,285.08 0.41 2,265.40 MWD+IFR-AK-CAZ-SC(3) 4,149.18 61.68 94.87 2,894.80 2,739.90 10.72 2,391.09 5,927,670.01 463,366.96 0.73 2,347.21 MWD+IFR-AK-CAZ-SC(3) 4,244.50 61.62 95.11 2,940.07 2,785.17 3.43 2,474.66 5,927,662.28 463,450.48 0.23 2,430.67 MWD+IFR-AK-CAZ-SC(3) 4,338.98 61.31 95.52 2,985.20 2,830.30 -4.26 2,557.31 5,927,654.16 463,533.08 0.50 2,513.30 MWD+IFR-AK-CAZ-SC(3) 4,434.06 62.18 93.75 3,030.21 2,875.31 -11.02 2,640.78 5,927,646.97 463,616.50 1.88 2,596.57 MWD+IFR-AK-CAZ-SC(3) 4,528.54 62.13 94.09 3,074.34 2,919.44 -16.73 2,724.12 5,927,640.83 463,699.81 0.32 2,679.52 MWD+IFR-AK-CAZ-SC(3) 4,625.04 61.92 94.12 3,119.61 2,964.71 -22.83 2,809.13 5,927,634.29 463,784.77 0.22 2,764.18 MWD+IFR-AK-CAZ-SC(3) 4,718.37 61.68 94.92 3,163.71 3,008.81 -29.32 2,891.12 5,927,627.39 463,866.73 0.80 2,845.94 MWD+IFR-AK-CAZ-SC(3) 1/10/2011 1:08:55PM Page 3 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-312(Cassidy) Project: Kuparuk River Unit TVD Reference: 2L-312 @ 154.90ft(D15(40.1+114.8)) Site: Kuparuk 2L Pad MD Reference: 2L-312 @ 154.90ft(D15(40.1+114.8)) Well: 2L-312(Cassidy) North Reference: True Wellbore: 2L-312 Survey Calculation Method: Minimum Curvature Design: 2L-312 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,811.39 61.55 94.69 3,207.93 3,053.03 -36.17 2,972.67 5,927,620.11 463,948.23 0.26 2,927.34 MWD+IFR-AK-CAZ-SC(3) 4,906.53 61.30 94.89 3,253.44 3,098.54 -43.15 3,055.93 5,927,612.70 464,031.44 0.32 3,010.44 MWD+IFR-AK-CAZ-SC(3) 5,001.82 61.12 94.93 3,299.33 3,144.43 -50.30 3,139.14 5,927,605.13 464,114.60 0.19 3,093.52 MWD+IFR-AK-CAZ-SC(3) 5,095.28 61.42 93.67 3,344.26 3,189.36 -56.44 3,220.86 5,927,598.56 464,196.28 1.22 3,174.96 MWD+IFR-AK-CAZ-SC(3) 5,190.93 61.15 93.37 3,390.21 3,235.31 -61.59 3,304.59 5,927,592.98 464,279.98 0.39 3,258.18 MWD+IFR-AK-CAZ-SC(3) 5,285.90 60.88 93.77 3,436.23 3,281.33 -66.76 3,387.50 5,927,587.38 464,362.85 0.47 3,340.60 MWD+IFR-AK-CAZ-SC(3) 5,379.86 61.89 93.99 3,481.23 3,326.33 -72.34 3,469.79 5,927,581.37 464,445.11 1.09 3,422.49 MWD+IFR-AK-CAZ-SC(3) 5,474.88 61.62 93.94 3,526.20 3,371.30 -78.13 3,553.30 5,927,575.15 464,528.58 0.29 3,505.62 MWD+IFR-AK-CAZ-SC(3) 5,570.03 61.33 94.06 3,571.64 3,416.74 -83.96 3,636.70 5,927,568.89 464,611.93 0.32 3,588.64 MWD+IFR-AK-CAZ-SC(3) 5,664.64 60.86 94.66 3,617.37 3,462.47 -90.26 3,719.28 5,927562.17 464594.47 0.74 3,670.95 MWD+IFR-AK-CAZ-SC(3) 5,757.80 61.99 94.08 3,661.93 3,507.03 -96.49 3,800.85 5,927,555.52 464,776.01 1.33 3,752.25 MWD+IFR-AK-CAZ-SC(3) 5,853.85 61.62 94.34 3,707.31 3,552.41 -102.71 3,885.28 5,927,548.87 464,860.39 0.45 3,836.36 MWD+IFR-AK-CAZ-SC(3) 5,948.36 61.15 94.42 3,752.57 3,597.67 -109.04 3,968.00 5,927,542.10 464,943.07 0.50 3,918.81 MWD+IFR-AK-CAZ-SC(3) 6,041.59 60.98 94.34 3,797.68 3,642.78 -115.27 4,049.35 5,927,535.45 465,024.38 0.20 3,999.90 MWD+IFR-AK-CAZ-SC(3) 6,135.66 61.98 94.96 3,842.59 3,687.69 -121.98 4,131.73 5,927,528.33 465,106.72 1.21 4,082.09 MWD+IFR-AK-CAZ-SC(3) 6,231.11 61.56 94.99 3,887.74 3,732.84 -129.27 4,215.51 5,927,520.60 465,190.45 0.44 4,165.76 MWD+IFR-AK-CAZ-SC(3) 6,324.83 62.40 95.05 3,931.77 3,776.87 -136.51 4,297.93 5,927,512.94 465,272.82 0.90 4,248.08 MWD+IFR-AK-CAZ-SC(3) 6,419.76 62.17 95.26 3,975.92 3,821.02 -144.06 4,381.63 5,927,504.95 465,356.47 0.31 4,331.72 MWD+IFR-AK-CAZ-SC(3) 6,513.76 62.02 95.55 4,019.91 3,865.01 -151.88 4,464.33 5,927,496.70 465,439.12 0.32 4,414.43 MWD+IFR-AK-CAZ-SC(3) 6,602.76 61.84 95.70 4,061.79 3,906.89 -159.58 4,542.48 5,927,488.60 465,517.23 0.25 4,492.65 MWD+IFR-AK-CAZ-SC(3) 6,700.90 61.65 95.79 4,108.25 3,953.35 -168.23 4,628.50 5,927,479.51 465,603.19 0.21 4,578.77 MWD+IFR-AK-CAZ-SC(3) 6,798.03 61.49 95.65 4,154.49 3,999.59 -176.75 4,713.49 5,927,470.55 465,688.12 0.21 4,663.86 MWD+IFR-AK-CAZ-SC(3) 6,894.19 63.00 94.60 4,199.27 4,044.37 -184.34 4,798.24 5,927,462.52 465,772.83 1.84 4,748.54 MWD+IFR-AK-CAZ-SC(3) 6,986.61 62.99 94.31 4,241.24 4,086.34 -190.74 4,880.33 5,927,455.70 465,854.88 0.28 4,830.39 MWD+IFR-AK-CAZ-SC(3) 7.078.67 62.98 94.63 4,283.05 4,128.15 -197.13 4,962.10 5,927,448.89 465,936.60 0.31 4,911.91 MWD+IFR-AK-CAZ-SC(3) 7,178.92 61.92 94.97 4,329.42 4,174.52 -204.57 5,050.67 5,927,440.99 466,025.12 1.10 5,000.32 MWD+IFR-AK-CAZ-SC(3) 7,273.77 61.97 94.80 4,374.03 4,219.13 -211.70 5,134.07 5,927,433.44 466,108.48 0.17 5,083.58 MWD+IFR-AK-CAZ-SC(3) 7,367.92 61.85 95.06 4,418.36 4,263.46 -218.83 5,216.82 5,927,425.87 466,191.18 0.27 5,166.22 MWD+IFR-AK-CAZ-SC(3) 7,463.37 61.68 95.37 4,463.52 4,308.62 -226.48 5,300.57 5,927,417.80 466,274.88 0.34 5,249.92 MWD+IFR-AK-CAZ-SC(3) 7,558.42 59.67 99.00 4,510.08 4,355.18 -236.81 5,382.76 5,927,407.04 466,357.02 3.94 5,332.60 MWD+IFR-AK-CAZ-SC(3) 7,649.75 57.53 102.59 4,557.67 4,402.77 -251.38 5,459.32 5,927,392.07 466,433.49 4.09 5,410.53 MWD+IFR-AK-CAZ-SC(3) 7,744.68 55.72 105.49 4,609.90 4,455.00 -270.59 5,536.22 5,927,372.47 466,510.28 3.18 5,489.66 MWD+IFR-AK-CAZ-SC(3) 7,836.25 54.14 107.25 4,662.52 4,507.62 -291.70 5,608.12 5,927,350.99 466,582.06 2.33 5,564.24 MWD+IFR-AK-CAZ-SC(3) 7,935.02 52.72 110.41 4,721.37 4,566.47 -317.28 5,683.19 5,927,325.03 466,656.99 2.94 5,642.76 MWD+IFR-AK-CAZ-SC(3) 8,032.64 51.76 114.64 4,781.17 4,626.27 -346.81 5,754.45 5,927,295.13 466,728.10 3.56 5,718.28 MWD+IFR-AK-CAZ-SC(3) 8,125.23 50.74 118.30 4,839.13 4,684.23 -378.97 5,819.08 5,927,262.64 466,792.55 3.27 5,787.77 MWD+IFR-AK-CAZ-SC(3) 8,222.42 51.11 122.79 4,900.41 4,745.51 -417.31 5,884.03 5,927,223.97 466,857.29 3.61 5,858.72 MWD+IFR-AK-CAZSC(3) 8,316.99 51.61 127.41 4,959.48 4,804.58 -459.77 5,944.43 5,927,181.20 466,917.46 3.85 5,925.98 MWD+IFR-AK-CAZ-SC(3) 8,407.76 50.84 132.75 5,016.35 4,861.45 -505.29 5,998.55 5,927,135.41 466,971.34 4.66 5,987.63 MWD+IFR-AK-CAZ-SC(3) 8,504.39 49.68 138.22 5,078.16 4,923.26 -558.21 6,050.63 5,927,082.22 467,023.14 4.51 6,048.66 MWD+IFR-AK-CAZ-SC(3) 1/10/2011 1:08:55PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-312(Cassidy) Project: Kuparuk River Unit TVD Reference: 2L-312 @ 154.90ft(D15(40.1+114.8)) Site: Kuparuk 2L Pad MD Reference: 2L-312 @ 154.90ft(D15(40.1+114.8)) Well: 2L-312(Cassidy) North Reference: True Wellbore: 2L-312 Survey Calculation Method: Minimum Curvature Design: 2L-312 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting OLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,598.60 49.07 143.45 5,139.52 4,984.62 -613.61 6,095.77 5,927,026.60 467,067.99 4.26 6,103.34 MWD+IFR-AK-CAZ-SC(3) 8,693.83 48.91 148.14 5,202.03 5,047.13 -673.01 6,136.15 5,926,967.00 467,108.06 3.72 6,154.08 MWD+IFR-AK-CAZ-SC(3) 8,788.62 49.70 153.18 5,263.86 5,108.96 -735.63 6,171.32 5,926,904.20 467,142.91 4.12 6,200.31 MWD+IFR-AK-CAZ-SC(3) 8,882.99 49.77 158.79 5,324.88 5,169.98 -801.36 6,200.61 5,926,838.33 467,171.85 4.54 6,241.33 MWD+IFR-AK-CAZ-SC(3) 8,977.97 49.88 161.12 5,386.16 5,231.26 -869.52 6,225.48 5,926,770.04 467,196.37 1.88 6,278.46 MWD+IFR-AK-CAZ-SC(3) 9,073.65 49.31 160.50 5,448.18 5,293.28 -938.33 6,249.42 5,926,701.11 467,219.95 0.77 6,314.81 MWD+IFR-AK-CAZ-SC(3) 9,166.20 48.70 160.69 5,508.89 5,353.99 -1,004.22 6,272.63 5,926,635.12 467,242.82 0.68 6,349.89 MWD+IFR-AK-CAZ-SC(3) 9,263.32 49.92 163.62 5,572.22 5,417.32 -1,074.31 6,295.18 5,926,564.92 467,265.00 2.61 6,385.11 MWD+IFR-AK-CAZ-SC(3) 9,313.29 49.87 164.00 5,604.41 5,449.51 -1,111.01 6,305.84 5,926,528.16 467,275.47 0.59 6,402.42 MWD+IFR-AK-CAZ-SC(3) 9,352.00 49.87 164.00 5,629.36 5,474.46 -1,139.46 6,313.99 5,926,499.67 467,283.48 0.00 6,415.73 PROJECTED to TD 1/10/2011 1:08:55PM Page 5 COMPASS 2003.16 Build 69 WELL LOG TRANSMITTAL To: State of Alaska January 21, 2011 Alaska Oil and Gas Conservation Commission Attn.: Christine Shartzer 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 2L-312 AK-MW-0007742774 2L-312 50-103-20626-00 2"x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5" TVD TRIPLE COMBO 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 Brya B inda@ a11turto`.corn '`I Date: - Signed: �„ ft- z-3-1° 2L-312 Producer ConocoPhillips Of 3-1/2" Completion String F it) ConocoPhillips mi !iiii ;' ; 3 '/z' Camco'DS'Nipple w/2.875"No-Go Profile,EUE 8RD 16" 164.82# ':`:``:� s • mod,at—500'MD SCH100 ""�` ir- ,t` j iii... Drift tubing with 2.91"above DS Nipple @+/- 110'MD , 3 '/2"9.3#L-80 EUE 81W mod tubing alp lii ,i!v • 9-I ::M Arcticset Lite @ 10.7 ppg to surface Top of 12 ppg Tail Slurry @ 2,065'MD GLM# Type Setting Depth(TVD-RKB) Valve Type 1 MMG 2,500' Dummy 10-3/4"45.5#L-80 BTC @ 2 MMG 3,800' Dummy +/-3,065'MD/2,400'TVDCli 3 MMG 4,628' Dummy 2 MMG 5,128' SOV 5—I :-..-:-:-_.,:..:: TOC 15.8ppg@+/-6,935'MD _-_= 3-'/z' KBMG-LTS Chemical Injection Mandrel(Placed below bottom GLM)with 3/8"encapsulated control line to surface == —8,640'MD/5,163'MD S 3-1/2" Baker'CMU'Sliding Sleeve(closed)with Camco 2.813" DS'profile,EUE 8RD mod,located 1 joint above PBR—8,680' MD/5,189'MD e - - , ` 3-V2"x 7-5/8"Baker FHL Packer with PBR,EUE 8RD mod, placed<200'MD above the perforated interval :r 8,721'MD/5,216'TVD • - 3-1/2"Cameo'D'Nipple w/2.75"No-Go Profile and RHC plug, EUE 8RD mod,located 1 full joint below packer—8,830'MD/ ■ 5,288'TVD 3 'h"Wireline Entry Guide,EUE 8RD mod,located 50'MD above top of Bermuda —8,870'MD/5,312'TVD �_'�' Planned Perforations—8,904'to 8,920'MD 7-5/8"29.7#L-80 BTCM _ is3: 1:::::::: ` ' @ 9,433'MD/5,677'TVD "'I FF (k) ftflQ SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS / 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION / ALASKA 99501-3539 / PHONE (907)279-1433 / FAX (907)276-7542 G. C. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2L-312 ConocoPhillips Alaska, Inc. Permit No: 210-164 Surface Location: 174' FNL, 675' FEL, SEC. 22, T1ON, R7E, UM Bottomhole Location: 1376' FNL, 372' FWL, SEC. 24, T1ON, R7E, 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. Si - , Q DAP'.'. Sea. ount, Chair DATED this aday of November, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) Post Office Box 100360 Conoco Anchorage,Alaska 99510-0360 Chip Alvord Phone(907)265-6120 Email: Chip.Alvord@conocophillips.com November 8,2010 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7th Avenue,Suite 100 U Anchorage,Alaska 99501 2 0 1 0 sa 0`t �a:Cori Cem :; RE: Application for Permit to Drill 2L-312 ssioll Ar7wh3iag$ Dear Commissioners, ConocoPhillips Alaska,Inc hereby applies for a Permit to Drill for the onshore production well 2L-312. The well will be drilled and completed using Doyon Rig#15. The planned spud date for 2L-312 is November 28th,2010. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Steve Shultz 263-4297. Sincerely, Chip Alvord Drilling Manager ECE !- STATE -STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Nov 0 q 2010 PERMIT TO DRILLOil Si Gas Cons.Cumr3si Nara Oil 20 AAC 25.005 Anchorage 1a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑✓ Service-Winj El Single Zone ❑ 1c.Speif well is proposed for: Drill ❑✓ 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 ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' 2L-312 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:9433' • TVD: 5677 • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 174'FNL,675'FEL,Sec.22,T1ON,R7E,UM - ADL 380052,380051 Tarn Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1006'FNL,248'FWL,Sec.24,T1ON, R7E, UM 4600,4599 11/28/2010 Total Depth: 9.Acres in Property: 14.Distance to 1376'FNL,372'FWL,Sec.24,T1ON, R7E,UM • 2560 Nearest Prop: 1.25 mile to CRU boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 155 feet 15.Distance to Nearest Well Open Surface:x- 460976 ` y- 5927671 Zone- 4 GL Elevation above MSL: ' 115 feet to Same Pool: 2L-310,606'at 8021' 16.Deviated wells: Kickoff depth: 700 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 62' deg Downhole:4310 psig ./ Surface:3719 psig ...--- 18. ✓18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 164.8# B-35 Welded 120' Surf. Surf 120' 120' Driven 13.5" 10.75" 45.5# L-80 BTC 3059' Surf. Surf 3059' 2400' 550 sx ASLite,370 sx DeepCRETE ' 9.875" 7.625" 29.7# L-80 BTCM 9433' Surf. Surf 9433' 5677' 710 sx Ga5BLOK Class G 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 MC 25.050 requirements ❑✓ 21.Verbal Approval: Commission Representative: Date: /�J 22. I hereby certify that the foregoing is true and correct. Contact Mike Greener @ 263-4820 /"/' Printed Name G. C. Alvord Title Alaska Drilling Manager SignatureA. -(04,(__ Phon 265-6120 Date 1 (20(a Commission Use Only Permit to Drill API Number: , Permit Approval See cover letter 2-/ ! Number: �'I 50-/P r t� ;--(-‘or-16 Date: `t',1 't for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbedm ane,gas hydrates,or gas contained in shales: d Au?000 I.SI. BOPcs t" Samples req'd: Yes ❑ o ,Mud log req'd: Yes ❑ No [� Other: ZSo / test H2S measures: Yes +� No ❑ ' - onal svy req'd: Yes [✓j' No ❑ ..K v p5"' Afrin- JetS Com.+-) / APPROVED BY THE COMMISSION ‘5�' �1r° DATE: , /�,�' e. 1 ,' �( ,COMMISSIONER �A 1 �� f r % \� Form 10-401 (Revised 7/2009) This permit is vie d fair 24 inGsifr r ,tt�`e a>.of approval '0 , .C 25.005(8)) �/ Submit in Duphoate :ation for Permit to Drill,Well 2L-312 Saved:4-Nov-10 Permit It — Tarn Well 2L-312 Application for Permit to Drill Document rT a Mpximizi Well Valu ! Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements o 20 AAC 25.005(c)(2) 2 q .f Requirements of 20 AAC 25.050(b) 2 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005(c)(5) 3 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 4 Requirements of 20 AAC 25.005(c)(8) 4 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 10. Seismic Analysis 5 Requirements of 20 AAC 25.005(c)(10) 5 11. Seabed Condition Analysis 5 Requirements of 20 AAC 25.005 (c)(11) 5 12. Evidence of Bonding 5 Requirements of 20 AAC 25.005(c)(12) 5 13. Proposed Drilling Program 5 Requirements of 20 AAC 25.005(c)(13) 5 2L-312 APD Page 1 of 7 ORIGINAL Printed:4-Nov-10 I ation for Permit to Drill,Well 2L-312 Saved:4-Nov-10 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 6 Requirements of 20 AAC 25.005(c)(14) 6 15. Attachments 6 Attachment 1 Directional Plan 6 Attachment 2 Drilling Hazards Summary 6 Attachment 3 Well Schematic 6 Attachment 4 Cement Summary 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must he identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2L-312. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identiieing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 174'FNL, 675' FEL, Sec 22, T1ON,R7E,UM NAD 1927 RKB Elevation 154.8'AMSL Northings: 5,927,671.40 Eastings: 460,975.7 Pad Elevation 114.8'AMSL Location at Top of Productive Interval 1,006'FNL,248' FWL,Sec 24,T1ON,R7E,UM (Bermuda) Nad 1927 Measured Depth, RKB: 8,920' Northings: 5,926,810.68 Eastings:467,175.33 Total Vertical Depth,RKB: 5,345' Total Vertical Depth, SS: 5,190' Location at Total Depth 1,376'FNL, 372'FWL, Sec 24,T1ON,R7E,UM Nad 1927 Measured Depth,RKB: 9,433' - Northings: 5,926,439.77 Eastings: 467,298.30 Total Vertical Depth,RKB: 5,677' • Total Vertical Depth, SS: 5,522' and (D)other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(6) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 2L-312 APD Page 2 of 7 0 R I I N A L Printed:4-Nov-10 I ation for Permit to Drill,Well 2L-312 Saved:4-Nov-10 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(ROPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 15. 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The bottom hole pressures from the 2L-312's offset wells are: Well Type SIBHP MW Distance Direction Shut in Time 2L-307 Producer 1,994 psi 7.2 ppg 1,660' S 360 hrs 2L-305 Injector 4,307 psi 15.5 ppg 1,550' W/SW 235 hrs 2L-310 Producer 2,296 psi 8.3 ppg 1,442' E initial Given the above range of pressures,2L-312 is expected to have a BHP range of 2,000-4300 psi at the reservoir depth of 5,345'TVD. This gives a mud weight range of 8.3 ppg— 15.5 ppg for 2L-312. Equivalent Mud Weight @ TD=4,307/(5,347*.052)= 15.5 ppg=0.806 psi/ft The maximum potential surface pressure(MPSP)while drilling 2L-312 is calculated using the higher end of the predicted reservoir pressure 3,719 psi,a 0.11 psi/ft gas gradient,and a Bermuda sand top TVD of 5,347' (estimated top of reservoir in 2L-312). MPSP =(5,347 ft TVD)*(0.806-0.11 psi/ft) =3,719 psi • (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes qf hole problems such as abnormally geo pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill nmst be accompanied by each of the following items,except for an item already on.file with the commission and identified in the application: (5)a description of the procedure fOr conducting formation integrity tests,as required under 20 AAC 25.030('/); Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 2L-312 APD Page 3 of 7 OR I INA ! Printed:4-Nov-10 ation for Permit to Drill,Well 2L-312 Saved:4-Nov-10 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application fa'a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed; C a singand Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program Driven 16 24 164.8 B-35 Welded 120' Surf 120'/120' Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 BTC 3,059' Surf 3,059'/2,400' 550 sx ASLite Lead 10.7 ppg, 370 sx Tail Slurry 12.0 ppg Cement Top planned @ 6,935'MD/ 4 7-5/8 9-7/8 29.7 L-80 BTCM 9,433' Surf 9,433'/5,677' 4,218'TVD. Cemented w/ 710 sx GasBLOK Class"G"15.8 ppq 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application jOr a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 15. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; III Drilling will be done using mud systems having the following properties: Surface WBM 110'—3,059 ' Density(ppg) 8.8—9.5 Funnel Viscosity(seconds) 75—250 Yield Point(cP) 60—80 pH 9.0—9.5 API Filtrate(cc) NC—8.0 Chlorides(mg/l) <1000 Intermediate/Production OBM 3,059'—9,433' Density(ppg) 9.0— 15.5 / Yield Point(cP) 18—28 HTHP Fluid Loss(ml/30min) <5 OWR 75:25—80:20 Electrical Stability(my) >600 Diagram of Doyon 15 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 2L-312 APD Page 4 of 7 R t GIN = L Printed:4-Nov-10 ation for Permit to Drill,Well 2L-312 Saved:4-Nov-10 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application fir a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(/); N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (e)(11) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (I 1)for a well drilled.from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A-Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items,except far an item already on.file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025(Bonding/have been met; Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 15 on 2L-312 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Spud and directionally drill 13-1/2"hole to the 10-3/4" surface casing point(3,059'MD/2,400'TVD) according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. SP:•M 5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure _ 3760,0 cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. - youp �s 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3 psi. Notify f(,x.t6 state of BOP test. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20'minimum to 50'maximum of new hole.Perform LOT. i 9. Directionally drill 9-7/8"hole to 9,433'MD/5,677'TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. POOH with DP and rack back. Run 7-5/8"29.7#L-80 BTCM casing to 9,433'MD/5,677'TVD and cement. Cfo g,46•45 P 1" 2L-312 APD Page 5 of 7 r 1 1 ,,f p L Printed:4-Nov-10 ration for Permit to Drill,Well 2L-312 Saved:4-Nov-10 S 11> 11. Run 3-1/2"completion tubi with packer and set at+/-8,721' MD/5,216'TVD. 12. LD DP and associated equipment. 13. ND BOP and rig up tree. Test tree and freeze protect annulus. Rig down and move out rig. - 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: 0,0a general description of how the operator plans to dispose of drilling mud and cuttings and a statement ofwhether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary 2L-312 APD Page of 0RIGINAL0 Printed:4-Nov-10 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-312 (Cassidy) - Slot 2L-312* 2L-312 Plan: 2L-312 (wp04) Standard Proposal Report 02 November, 2010 HALLI BURTON Sperry Drilling Services 0 N ay - 0 ^ cn -- CO r o Q C' N w - O r N oa c fc o —o g usc _ z _- ! 0 ¢ =3 E Ea0o0nvMeOc�n `^� O - o LI ac Q 1Cli P a0000cnci 4=1- -N 0 W W N N s� ~ N�� C d = o C 0 0 ,oNNCOOMOO))0 a .ti-r-,-, -o 0 co 0 dccaovti0Noro w Z J = V u o ��fNo f002�WQ) 0 0-N F 0 Fr Z Z z o a O z 9 M iv —an at o Q .....0 0 0 0 0 Q OM a. a) M - A� 2 co0000000. 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Latitude: 70°12'48.034 N +E/-W 0.00 ft Easting: 460,975.70 ft • Longitude: 150°18'53.012 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.80ft Wellbore 2L-312 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 3/23/2010 21.46 80.70 57,627 Design 2L-312(wp04) ,Audit Notes: Version: Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From(ND) +N1-S +E/-W Direction (ft) (ft) (ft) (°) 40.00 0.00 0.00 100.73 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 40.00 0.00 0.00 40.00 -114.80 0.00 0.00 0.00 0.00 0.00 0.00 492.20 0.00 0.00 492.20 337.40 0.00 0.00 0.00 0.00 0.00 0.00 700.29 5.20 37.70 700.00 545.20 7.47 5.77 2.50 2.50 0.00 37.70 1,439.87 30.14 70.06 1,400.00 1,245.20 98.88 204.23 3.50 3.37 4.38 38.00 1,539.87 30.14 70.06 1,486.48 1,331.68 116.01 251.44 0.00 0.00 0.00 0.00 2,442.15 61.93 95.19 2,109.63 1,954.83 158.68 881.83 4.00 3.52 2.78 39.50 6,442.15 61.93 95.19 3,991.83 3,837.03 -160.56 4,396.85 0.00 0.00 0.00 0.00 6,466.48 62.02 94.37 4,003.27 3,848.47 -162.35 4,418.26 3.00 0.37 -3.37 -83.19 7,533.62 62.02 94.37 4,503.95 4,349.15 -234.13 5,357.92 0.00 0.00 0.00 0.00 8,920.37 49.66 161.36 5,344.80 5,190.00 -828.74 6,204.60 4.00 -0.89 4.83 121.61 9,183.00 49.66 161.36 5,514.80 5,360.00 -1,018.43 6,268.59 0.00 0.00 0.00 99.58 9,433.07 49.66 161.36 5,676.67 5,521.87 -1,199.05 6,329.50 0.00 0.00 0.00 0.00 11/2/2010 9:40:37AM Page 2 COMPASS 2003.16 Build 69 r t t t i t 1 't 4 \ L.. Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-312(Cassidy)-Slot 2L-312* Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Staked:2L-312 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Staked:2L-312 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-312(Cassidy) Survey Calculation Method: Minimum Curvature Wellbore: 2L-312 Design: 2L-312(wp04) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -114.80 40.00 0.00 0.00 40.00 -114.80 0.00 0.00 5,927,671.40 460,975.70 0.00 0.00 40.01 0.00 0.00 40.01 -114.79 0.00 0.00 5,927,671.40 460,975.70 0.00 0.00 Surface Location:174'FNL,675'FEL-Sec22,T10N,R07E 100.00 0.00 0.00 100.00 -54.80 0.00 0.00 5,927,671.40 460,975.70 0.00 0.00 200.00 0.00 0.00 200.00 45.20 0.00 0.00 5,927,671.40 460,975.70 0.00 0.00 300.00 0.00 0.00 300.00 145.20 0.00 0.00 5,927,671.40 460,975.70 0.00 0.00 400.00 0.00 0.00 400.00 245.20 0.00 0.00 5,927,671.40 460,975.70 0.00 0.00 492.20 0.00 0.00 492.20 337.40 0.00 0.00 5,927,671.40 460,975.70 0.00 0.00 500.00 0.19 37.70 500.00 345.20 0.01 0.01 5,927,671.41 460,975.71 2.50 0.01 600.00 2.69 37.70 599.96 445.16 2.01 1.55 5,927,673.40 460,977.26 2.50 1.15 700.00 5.19 37.70 699.72 544.92 7.45 5.76 5,927,678.82 460,981.49 2.50 4.27 700.29 5.20 37.70 700.00 545.20 7.47 5.77 5,927,678.84 460,981.51 2.50 4.28 800.00 8.24 52.87 799.03 644.23 15.36 14.23 5,927,686.68 460,990.01 3.50 11.13 900.00 11.54 59.69 897.53 742.73 24.73 28.59 5,927,695.98 461,004.41 3.50 23.48 1,000.00 14.93 63.49 994.86 840.06 35.54 48.76 5,927,706.68 461,024.64 3.50 41.29 1,100.00 18.37 65.89 1,090.65 935.85 47.73 74.67 5,927,718.74 461,050.61 3.50 64.49 1,200.00 21.82 67.56 1,184.56 1,029.76 61.26 106.24 5,927,732.11 461,082.24 3.50 92.98 1,300.00 25.28 68.79 1,276.21 1,121.41 76.09 143.33 5,927,746.74 461,119.41 3.50 126.67 1,400.00 28.76 69.74 1,365.28 1,210.48 92.15 185.82 5,927,762.58 461,161.98 3.50 165.42 1,416.60 29.33 69.88 1,379.80 1,225.00 94.93 193.39 5,927,765.32 461,169.56 3.50 172.34 ' Permafrost 1,439.87 30.14 70.06 1,400.00 1,245.20 98.88 204.23 5,927,769.22 461,180.42 3.50 182.26 1,500.00 30.14 70.06 1,452.00 1,297.20 109.18 232.62 5,927,779.37 461,208.85 0.00 208.23 1,539.87 30.14 70.06 1,486.48 1,331.68 116.01 251.44 5,927,786.10 461,227.71 0.00 225.45 1,600.00 32.03 72.95 1,537.97 1,383.17 125.83 280.88 5,927,795.77 461,257.20 4.00 252.55 1,700.00 35.30 77.12 1,621.20 1,466.40 140.06 334.42 5,927,809.72 461,310.81 4.00 302.51 1,800.00 38.69 80.65 1,701.07 1,546.27 151.58 393.45 5,927,820.93 461,369.89 4.00 358.36 1,900.00 42.17 83.70 1,777.19 1,622.39 160.35 457.67 5,927,829.37 461,434.15 4.00 419.83 2,000.00 45.72 86.35 1,849.19 1,694.39 166.32 526.79 5,927,834.97 461,503.29 4.00 486.63 2,100.00 49.32 88.70 1,916.71 1,761.91 169.45 600.45 5,927,837.73 461,576.96 4.00 558.42 2,200.00 52.97 90.81 1,979.44 1,824.64 169.74 678.30 5,927,837.62 461,654.81 4.00 634.86 2,300.00 56.65 92.73 2,037.06 1,882.26 167.18 759.97 5,927,834.64 461,736.45 4.00 715.57 2,400.00 60.36 94.49 2,089.30 1,934.50 161.79 845.05 5,927,828.81 461,821.49 4.00 800.17 2,442.15 61.93 95.19 2,109.63 1,954.83 158.68 881.83 5,927,825.50 461,858.25 4.00 836.88 2,500.00 61.93 95.19 2,136.86 1,982.06 154.06 932.67 5,927,820.62 461,909.06 0.00 887.70 2,600.00 61.93 95.19 2,183.91 2,029.11 146.08 1,020.54 5,927,812.19 461,996.88 0.00 975.52 2,700.00 61.93 95.19 2,230.97 2,076.17 138.10 1,108.42 5,927,803.76 462,084.71 0.00 1,063.35 2,800.00 61.93 95.19 2,278.02 2,123.22 130.12 1,196.30 5,927,795.32 462,172.53 0.00 1,151.17 2,900.00 61.93 95.19 2,325.08 2,170.28 122.14 1,284.17 5,927,786.89 462,260.36 0.00 1,239.00 3,000.00 61.93 95.19 2,372.13 2,217.33 114.16 1,372.05 5,927,778.45 462,348.18 0.00 1,326.82 3,059.01 61.93 95.19 2,399.90 2,245.10 109.45 1,423.90 5,927,773.48 462,400.01 0.00 1,378.65 10 3/4" 3,059.22 61.93 95.19 2,400.00 2,245.20 109.43 1,424.09 5,927,773.46 462,400.20 0.00 1,378.84 10 3/4"Casing @ 3059'MD,2400'TVD:65'FNL,749'FWL-Sec23,T10N,R07E 3,100.00 61.93 95.19 2,419.19 2,264.39 106.18 1,459.92 5,927,770.02 462,436.01 0.00 1,414.65 11/2/2010 9:40:37AM Page 3 COMPASS 2003.16 Build 69 ORLGU'4AL Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-312(Cassidy)-Slot 2L-312* Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Staked:2L-312 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Staked:2L-312 @ 154.808(015(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-312(Cassidy) Survey Calculation Method: Minimum Curvature Wellbore: 2L-312 Design: 2L-312(wp04) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W Northing Easting DLS Vert Section (ft) (0) (0) (ft) ft (ft) (ft) (ft) (ft) 2,311.44 3,200.00 61.93 95.19 2,466.24 2,311.44 98.19 1,547.80 5,927,761.58 462,523.83 0.00 1,502.47 3,281.94 61.93 95.19 2,504.80 2,350.00 91.66 1,619.80 5,927,754.67 462,595.80 0.00 1,574.44 C-80 3,300.00 61.93 95.19 2,513.30 2,358.50 90.21 1,635.67 5,927,753.15 462,611.66 0.00 1,590.30 3,400.00 61.93 95.19 2,560.35 2,405.55 82.23 1,723.55 5,927,744.72 462,699.48 0.00 1,678.13 3,500.00 61.93 95.19 2,607.41 2,452.61 74.25 1,811.42 5,927,736.28 462,787.31 0.00 1,765.95 1 3,600.00 61.93 95.19 2,654.46 2,499.66 66.27 1,899.30 5,927,727.85 462,875.13 0.00 1,853.78 3,700.00 61.93 95.19 2,701.52 2,546.72 58.29 1,987.18 5,927,719.41 462,962.96 0.00 1,941.60 3,800.00 61.93 95.19 2,748.57 2,593.77 50.31 2,075.05 5,927,710.98 463,050.78 0.00 2,029.43 3,900.00 61.93 95.19 2,795.63 2,640.83 42.33 2,162.93 5,927,702.54 463,138.60 0.00 2,117.25 4,000.00 61.93 95.19 2,842.68 2,687.88 34.35 2,250.80 5,927,694.11 463,226.43 0.00 2,205.08 4,100.00 61.93 95.19 2,889.74 2,734.94 26.37 2,338.68 5,927,685.68 463,314.25 0.00 2,292.90 4,200.00 61.93 95.19 2,936.79 2,781.99 18.39 2,426.55 5,927,677.24 463,402.08 0.00 2,380.73 4,300.00 61.93 95.19 2,983.85 2,829.05 10.40 2,514.43 5,927,668.81 463,489.90 0.00 2,468.56 4,400.00 61.93 95.19 3,030.90 2,876.10 2.42 2,602.31 5,927,660.37 463,577.73 0.00 2,556.38 4,500.00 61.93 95.19 3,077.96 2,923.16 -5.56 2,690.18 5,927,651.94 463,665.55 0.00 2,644.21 4,600.00 61.93 95.19 3,125.01 2,970.21 -13.54 2,778.06 5,927,643.51 463,753.38 0.00 2,732.03 4,700.00 61.93 95.19 3,172.07 3,017.27 -21.52 2,865.93 5,927,635.07 463,841.20 0.00 2,819.86 4,800.00 61.93 95.19 3,219.12 3,064.32 -29.50 2,953.81 5,927,626.64 463,929.03 0.00 2,907.68 4,900.00 61.93 95.19 3,266.18 3,111.38 -37.48 3,041.68 5,927,618.20 464,016.85 0.00 2,995.51 5,000.00 61.93 95.19 3,313.23 3,158.43 -45.46 3,129.56 5,927,609.77 464,104.68 0.00 3,083.33 5,100.00 61.93 95.19 3,360.29 3,205.49 -53.44 3,217.44 5,927,601.33 464,192.50 0.00 3,171.16 5,200.00 61.93 95.19 3,407.34 3,252.54 -61.42 3,305.31 5,927,592.90 464,280.32 0.00 3,258.99 5,300.00 61.93 95.19 3,454.40 3,299.60 -69.41 3,393.19 5,927,584.47 464,368.15 0.00 3,346.81 5,400.00 61.93 95.19 3,501.45 3,346.65 -77.39 3,481.06 5,927,576.03 464,455.97 0.00 3,434.64 5,500.00 61.93 95.19 3,548.51 3,393.71 -85.37 3,568.94 5,927,567.60 464,543.80 0.00 3,522.46 5,600.00 61.93 95.19 3,595.56 3,440.76 -93.35 3,656.81 5,927,559.16 464,631.62 0.00 3,610.29 5,700.00 61.93 95.19 3,642.62 3,487.82 -101.33 3,744.69 5,927,550.73 464,719.45 0.00 3,698.11 5,800.00 61.93 95.19 3,689.67 3,534.87 -109.31 3,832.57 5,927,542.29 464,807.27 0.00 3,785.94 5,900.00 61.93 95.19 3,736.73 3,581.93 -117.29 3,920.44 5,927,533.86 464,895.10 0.00 3,873.76 6,000.00 61.93 95.19 3,783.78 3,628.98 -125.27 4,008.32 5,927,525.43 464,982.92 0.00 3,961.59 6,055.29 61.93 95.19 3,809.80 3,655.00 -129.68 4,056.90 5,927,520.76 465,031.48 0.00 4,010.15 C-50 6,100.00 61.93 95.19 3,830.84 3,676.04 -133.25 4,096.19 5,927,516.99 465,070.75 0.00 4,049.42 6,200.00 61.93 95.19 3,877.89 3,723.09 -141.23 4,184.07 5,927,508.56 465,158.57 0.00 4,137.24 6,300.00 61.93 95.19 3,924.95 3,770.15 -149.21 4,271.94 5,927,500.12 465,246.40 0.00 4,225.07 6,400.00 61.93 95.19 3,972.00 3,817.20 -157.20 4,359.82 5,927,491.69 465,334.22 0.00 4,312.89 6,442.15 61.93 95.19 3,991.83 3,837.03 -160.56 4,396.85 5,927,488.13 465,371.23 0.00 4,349.91 6,466.48 62.02 94.37 4,003.27 3,848.47 -162.35 4,418.26 5,927,486.23 465,392.63 3.00 4,371.27 6,500.00 62.02 94.37 4,018.99 3,864.19 -164.60 4,447.78 5,927,483.83 465,422.13 0.00 4,400.69 6,600.00 62.02 94.37 4,065.91 3,911.11 -171.33 4,535.83 5,927,476.65 465,510.14 0.00 4,488.46 6,700.00 62.02 94.37 4,112.83 3,958.03 -178.06 4,623.88 5,927,469.47 465,598.15 0.00 4,576.23 6,800.00 62.02 94.37 4,159.75 4,004.95 -184.78 4,711.94 5,927,462.28 465,686.16 0.00 4,663.99 6,900.00 62.02 94.37 4,206.67 4,051.87 -191.51 4,799.99 5,927,455.10 465,774.17 0.00 4,751.76 11/2/2010 9:40:37AMCOMPASS 2003.16 Build 69 rMP g1 L4L \L Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-312(Cassidy)-Slot 2L-312* Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Staked:2L-312 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Staked:2L-312 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-312(Cassidy) Survey Calculation Method: Minimum Curvature Wellbore: 2L-312 Design: 2L-312(wp04) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 4,055.00 6,906.68 62.02 94.37 4,209.80 4,055.00 -191.96 4,805.87 5,927,454.62 465,780.04 0.00 4,757.62 C-40 7,000.00 62.02 94.37 4,253.58 4,098.78 -198.24 4,888.05 5,927,447.92 465,862.17 0.00 4,839.53 7,100.00 62.02 94.37 4,300.50 4,145.70 -204.96 4,976.10 5,927,440.74 465,950.18 0.00 4,927.29 7,200.00 62.02 94.37 4,347.42 4,192.62 -211.69 5,064.15 5,927,433.56 466,038.19 0.00 5,015.06 7,300.00 62.02 94.37 4,394.34 4,239.54 -218.42 5,152.21 5,927,426.38 466,126.20 0.00 5,102.83 7,322.30 62.02 94.37 4,404.80 4,250.00 -219.92 5,171.84 5,927,424.78 466,145.83 0.00 5,122.40 Top Pool @ 7322'MD,4405'TVD:396'FNL,784'FEL-Sec23,T10N,R07E-C-37 7,400.00 62.02 94.37 4,441.26 4,286.46 -225.14 5,240.26 5,927,419.20 466,214.21 0.00 5,190.59 7,500.00 62.02 94.37 4,488.17 4,333.37 -231.87 5,328.31 5,927,412.02 466,302.22 0.00 5,278.36 7,533.62 62.02 94.37 4,503.95 4,349.15 -234.13 5,357.92 5,927,409.60 466,331.81 0.00 5,307.87 7,600.00 60.65 96.96 4,535.79 4,380.99 -239.87 5,415.87 5,927,403.56 466,389.73 4.00 5,365.88 7,700.00 58.69 101.00 4,586.30 4,431.50 -253.31 5,501.10 5,927,389.68 466,474.88 4.00 5,452.12 7,800.00 56.86 105.21 4,639.64 4,484.84 -272.46 5,583.47 5,927,370.12 466,557.14 4.00 5,536.61 7,900.00 55.18 109.58 4,695.55 4,540.75 -297.21 5,662.57 5,927,344.96 466,636.10 4.00 5,618.94 8,000.00 53.66 114.13 4,753.75 4,598.95 -327.45 5,738.03 5,927,314.33 466,711.40 4.00 5,698.71 8,100.00 52.32 118.86 4,813.97 4,659.17 -363.03 5,809.47 5,927,278.39 466,782.65 4.00 5,775.52 8,200.00 51.17 123.74 4,875.91 4,721.11 -403.77 5,876.55 5,927,237.30 466,849.51 4.00 5,849.01 8,300.00 50.24 128.76 4,939.26 4,784.46 -449.49 5,938.94 5,927,191.27 466,911.65 4.00 5,918.82 8,400.00 49.52 133.91 5,003.73 4,848.93 -499.95 5,996.33 5,927,140.52 466,968.78 4.00 5,984.60 8,500.00 49.04 139.15 5,068.99 4,914.19 -554.91 6,048.45 5,927,085.29 467,020.60 4.00 6,046.04 8,600.00 48.80 144.45 5,134.73 4,979.93 -614.10 6,095.04 5,927,025.87 467,066.88 4.00 6,102.83 8,700.00 48.80 149.76 5,200.62 5,045.82 -677.24 6,135.87 5,926,962.53 467,107.39 4.00 6,154.70 8,800.00 49.05 155.06 5,266.35 5,111.55 -744.01 6,170.75 5,926,895.58 467,141.92 4.00 6,201.40 8,900.00 49.53 160.30 5,331.60 5,176.80 -814.10 6,199.51 5,926,825.35 467,170.31 4.00 6,242.70 8,904.93 49.56 160.56 5,334.80 5,180.00 -817.63 6,200.77 5,926,821.81 467,171.55 4.00 6,244.60 S-8 8,920.37 49.66 161.36 5,344.80 5,190.00 -828.74 6,204.60 5,926,810.68 467,175.33 4.00 6,250.44 S8 Target @ 8920'MD,5345'TVD:1006'FNL,248'FWL-Sec24,T1ON,R07E-2L-312(wp03)-S-8 9,000.00 49.66 161.36 5,396.35 5,241.55 -886.26 6,224.01 5,926,753.07 467,194.43 0.00 6,280.20 9,100.00 49.66 161.36 5,461.08 5,306.28 -958.49 6,248.37 5,926,680.73 467,218.42 0.00 6,317.59 9,183.00 49.66 161.36 5,514.80 5,360.00 -1,018.43 6,268.59 5,926,620.68 467,238.33 0.00 6,348.61 C-35-2L-312(wp03)-C-35 9,200.00 49.66 161.36 5,525.80 5,371.00 -1,030.71 6,272.73 5,926,608.38 467,242.40 0.00 6,354.96 9,300.00 49.66 161.36 5,590.53 5,435.73 -1,102.94 6,297.09 5,926,536.04 467,266.39 0.00 6,392.34 9,400.00 49.66 161.36 5,655.26 5,500.46 -1,175.17 6,321.45 5,926,463.69 467,290.37 0.00 6,429.71 1 : 9,433.07 49.66 161.36 . 5,676.67 5,521.87 -1,199.05 6,329.50 5,926,439.77 467,298.30 0.00 6,442.07 TD @ 9433'MD,5677'TVD:1376'FNL,372'FWL-Sec24,T1ON,R07E-7 5/8" , 11/2/2010 9:40:37AM Page 5 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTO J Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-312(Cassidy)-Slot 2L-312' Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Staked:2L-312 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Staked:2L-312 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-312(Cassidy) Survey Calculation Method: Minimum Curvature Wellbore: 2L-312 Design: 2L-312(wp04) Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape C) (°) (ft) (ft) (ft) (ft) (ft) 2L-312(wp03)-C-35 0.00 0.00 5,514.80 -1,018.43 6,268.59 5,926,620.68 467,238.33 -plan hits target center -Point 2L-312(wp03)-S-8 0.00 0.00 5,344.80 -828.74 6,204.60 5,926,810.68 467,175.33 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,059.01 2,399.90 10 3/4" 10-3/4 12-1/4 9,433.07 5,676.67 7 5/8" 7-5/8 9-7/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (0) (°) 1,416.60 1,379.80 Permafrost 0.00 9,183.00 5,514.80 C-35 0.00 8,904.93 5,334.80 S-8 0.00 7,322.30 4,404.80 C-37 0.00 6,906.68 4,209.80 C-40 0.00 3,281.94 2,504.80 C-80 0.00 6,055.29 3,809.80 C-50 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 40.01 40.01 0.00 0.00 Surface Location:174'FNL,675'FEL-Sec22,T1ON,R07E 3,059.22 2,400.00 109.43 1,424.09 10 3/4"Casing @ 3059'MD,2400'TVD:65'FNL,749'FWL-Sec23,T1ON,R07E 7,322.30 4,404.80 -219.92 5,171.84 Top Pool @ 7322'MD,4405'TVD:396'FNL,784'FEL-Sec23,T1ON,R07E 8,920.37 5,344.80 -828.75 6,204.61 S8 Target @ 8920'MD,5345'TVD:1006'FNL,248'FWL-Sec24,T1 ON,R107E 9,433.07 5,676.67 -1,199.05 6,329.50 TD @ 9433'MD,5677'TVD:1376'FNL,372'FWL-Sec24,T1ON,R07E 11/2/2010 9:40:37AMpage, ,2 , COMPASS 2003.16 Build 69 -p1- CO 0 N {? 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CO Q. 0 'C 0. co N o N 'o N a, N o V M ri M cY 4 M a M J w c.jJ w 0) w °) w (O J w cco N N N F N IC N 0 •• m N. m N = m N � m 0 = m 0 G1 Q Gi c) N 07 C N 47 Q) rn 0) L.17) a t0 a (o a v a v O C 0 C 0 C 0 C 0 C L O L co L co L O L O X o r r o ri • m 0 N n m n N- dm 0md o d m N. d 0. 0 ) 0. 0 m ce m o cL m o Ct m o Ce m O O E E M (o M 0 ;� C C o? C © co a Cm `"' a m �� 2 ,, m m o O N y .0 a. t c.a - .0 - y a a s 0 O ci 2L-312 Drilling Hazards Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Gravel/Sand Sloughing Moderate Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets), Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability in HRZ and K-1 Moderate Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills,PWD Tools,Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates,Mud rheology, LCM. Use GKA LC decision tree. 2L-312 Hazards.doc Prepared by Mike Greener .. Page 1 of 1 2L-312 Cassid Schlumberger CemCADE Preliminary Job Design 10-3/4" Surface Casin. WP-03 V2 Preliminary Job Desigi based on limted input data.For estimate purposes only. Rig: Volume Calculations and Cement Systems Location: Tarn Volumes are based on 300%excess in the permafrost and 50% excess below the Client:CPAI Revision Date: 09/30/2010 permafrost. The top of the tail slurry is designed to be at--2,065 MD. Prepared by:Mike Martin Location:Anchorage,AK Lead Slurry, Minimum pump time: 260 min. (pump time plus 120 min.) Phone: (907)263-4207 ARCTICSET Lite @ 10.7 ppg-4.51 ft3/sk Mobile:(907)748-6900 email: martin13@s1b.com 0.6381 ft3/ft x (80')x 1.00 (no excess) = 51 ft3 0.3637 ft3/ft x (1560'-80')x 4.00(300% excess) = 2153 ft3 < TOC at Surface 0.3637 ft3/ft x (2065'- 1560')x 1.50 (50% excess) = 275 ft3 51 ft3 +2153 ft3+ 275 ft3= 2479 ft3 2479 ft3/4.51 ft3/sk= 550 sks Round up to 550 sks Have additional ASL on location for Top Out stage, if necessary. Previous Csg. Tail Slurry Minimum pump time: 185 min. (pump time plus120 min.) < 16",62.6#casing 12.0 ppg DeepCRETE +additives- 1.64 ft3/sk at 80'MD 0.3637 ft3/ft x (3065-2065)x 1.50 (50%excess) = 546 ft3 0.53997 ft3/ft x 80' (Shoe Joint) = 43 ft3 546 ft3+ 43 ft3 = 589 ft3 589 ft3/ 1.64 ft3/sk = 360 sks Round up to 370 sks BHST = 77°F, Estimated BHCT = 73°F. < Base of Permafrost at (BHST calculated using a gradient of 2.0°F/100 ft. from surface) 1,560 MD(1,504'TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min Time (bbl) ) (min) CW 100 5.0 50.0 10.0 10.0 < Top of Tail at MUDPUSH II 5.0 50.0 10.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 2,065 MD ASL 6.0 441.7 73.6 98.6 DeepCRETE 6.0 104.9 17.5 116.1 Drop top plug 0.0 0.0 5.0 121.1 CW8 5.0 10.0 2.0. 123.1 Switch to rig 0.0 0 0 3.0 126.1 MOBM 8.0 268.1 33.5 159.6 Bump plug 3.0 9.0 3.0 162.6 < 10-3/4',45.5#casing in 13-1/2"OH MUD REMOVAL Expected Mud Properties: 9.6 ppg, Pv <25,Ty<20 TD at 3,065 MD (2,403'TVD) Spacer Properties: 10.5 ppg MudPUSH* II, Pv 20-25,Ty 30-35 Centralizers: As per CPAi program. Recommend minimal 3/2 joints from Shoe thru tail cement column • Mark of Schlumberger ORIGINAL 2L-312 (Cassidy) Schlumberger CemCADE Preliminary Job Design 7-5/8" Longstring (WP-03) V3 - OBM Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Location: Alpine Client:CPAI Revision Date: 10/06/2010 Volume Calculations and Cement Systems Prepared by:Mike Martin Volumes are based on 50% excess. The topof the tail slurryis designed to be Location:Anchorage,AK 9 Phone:(907)263-4207 6,935' MD. Mobile:(907)748-6900 email: martin13@slb.com Tail Slurry Minimum pump time: -210 min. (pump time plus 120 min.) 15.8 ppg Class G +2.0 gps D600G +0.2%D46, 0.6%D65, 0.03 gps D177- 1.17 ft3/sk 0.2148 ft3/ft x (9435-6935)x 1.50 (50% excess) = 806ft3 0.2578 ft3/ft x 80'(Shoe Joint) = 21 ft3 806 ft3+ 21 ft3 = 827 ft3 827 ft3/ 1.17 ft3/sk = 707 sks Previous Csg. Round up to 710 sks < 10-3/4",45.5.#casing at 3,065 MD BHST = 144°F, Estimated BHCT = 112°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min Time (bbl) } (min) CW101 5.0 40.0 8.0 8.0 MUDPUSH II 5.0 40.0 8.0 16.0 Drop bottom plub 0.0 0.0 5.0 2- 1.0 GasBLOK Slurry 6.0 147.1 24.5 45.5 Drop top plug 0.0 0.0 5.0 5- 0.5 CW8 5.0 10.0 2.0 52.5 Switch to rig 0.0 0.0 3.0 5- 5.5 Sea Water 8.0 413.5 51.7 107.2 < Top of Cement at Slow and bump plug 3.0 6.0 2.0 109.2 6,935 MD MUD REMOVAL Expected MOBM Properties:9.0 ppg, Pv < 15,Ty< 15. < 7-5/8",29.7#casing in 9-7/8"OH Spacer Properties: 11.5 ppg Mud PUSH* II, Pv = 20-25,Ty= 35-40 Centralizers: As per COP program TD at 9,435 MD (5,679'TVD) * Mark of Schlumberger 0 RI GINAL 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. TRANSMITTALL LETTER CHECKLIST WELL NAME / -/P/./ .2L -3/e/ PTD# 2-/o l�, /Development Service Exploratory Strati ra hic Test Non-Conventional Well FIELD: 61-6-1 POOL/* ( %17,c-C) ( V 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. 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(�cn 0 X27 0 3 N o 'O O '.Z Sll a (0 Ni 3 co 4•3-00 a r co0 O co co co j CT m a m a o_ -i r. O coED 0 = a cr N 7 7. (D O 0 m CA ? Co 0 00 CA O. N O N A r O o N O co co Q cn y- D o a O (31 01 O i (O 01 C 0 3 3 ° n O 0 c° 0 m 3 7- < C 0 a co 0 0 D O• m C c - ✓ Q 0 O m N o C 0 (A CD I Well History File APF DI Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history the. 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 Jan 19 15:05:25 2011 Reel Header Service name LISTPE Date 11/01/19 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 11/01/19 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 Tarn MWD/MAD LOGS WELL NAME: 2L-312 API NUMBER: 5010320626 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 19-JAN-11 JOB DATA MWD RUN 1 MWD RUN 2 JOB NUMBER: -MW-0007742774 -MW-0007742774 LOGGING ENGINEER: MICHAEL BUCK BEN SCHULZE OPERATOR WITNESS: SCOTT HEIM LARRY HILL SURFACE LOCATION SECTION: 22 TOWNSHIP: lON RANGE: 7E FNL: 174 FSL: FEL: 675 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 154.90 GROUND LEVEL: 114.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 16.000 110.0 2ND STRING 9.875 10.750 3071.0 3RD STRING PRODUCTION STRING OM-ivy 0 &y REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUNS 1,2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . MWD RUN 2 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL NEUTRON (CTN) , AND PRESSURE-WHILE-DRILLING (PWD) . MWD ALD DATA WERE REPLACED WITH MAD ALD DATA OVER THE SLIDE INTERVAL OF 9119'MD - 9172'MD. 4. LWD DATA ARE CONSIDERED PRIMARY DEPTH CONTROL PER E-MAIL FROM LISA WRIGHT (CPAI) TO BRYAN BURINDA (SD) DATED 12 JANUARY 2011. 5. MWD RUNS 1,2 REPRESENT WELL 2L-312 WITH API#: 50-103-20626-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9352'MD/5629'TVD. ROPA = AVERAGE RATE OF PENETRATION WHILE DRILLING DGRC = DGR COMBINED GAMMA RAY R09P = 9 INCH PHASE RESISTIVITY R15P = 15 INCH PHASE RESISTIVITY R27P = 27 INCH PHASE RESISTIVITY R39P = 39 INCH PHASE RESISTIVITY EWXT = EWR FORMATION EXPOSURE TIME TNPS = CTN POROSITY - SANDSTONE TNFA = CTN FAR AVERAGE COUNT RATE TNNA = CTN NEAR AVERAGE COUNT RATE ACDL = ALD LCRB COMPENSATED DENSITY ADCL = ALD LCRB DENSITY CORRECTION APEL = ALD LCRB Pe FACTOR AHSI = ALD HOLE SIZE INDICATOR ALRPM = ALD RPM (NON-SLIDE INDICATOR) PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: FIXED HOLE SIZE - 9.875" BIT MUD WEIGHT: 8.95 - 9.30 PPG MUD SALINITY: 49, 000 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR ROP, AND GAMMA RAY. THESE CURVES ARE SMOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/01/19 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 GR 235.5 9292.5 RPS 245.5 9302.5 FET 245.5 9302.5 RPD 245.5 9302.5 RPX 245.5 9302.5 RPM 245.5 9302.5 ROP 304.5 9352.0 NPHI 3061.0 9255.5 DRHO 3061.0 9269.0 NCNT 3061.0 9255.5 CALN 3061.0 9269.0 FCNT 3061.0 9255.5 PEF 3061.0 9269.0 RHOB 3061.0 9269.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 235.5 3081.0 MWD 2 3081.0 9352.0 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 MWD G/CC 4 1 68 4 2 DRHO MWD G/CC 4 1 68 8 3 CALN MWD IN 4 1 68 12 4 PEF MWD B/E 4 1 68 16 5 GR MWD API 4 1 68 20 6 FET MWD HR 4 1 68 24 7 RPX MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPM MWD OHMM 4 1 68 36 10 RPD MWD OHMM 4 1 68 40 11 ROP MWD FPH 4 1 68 44 12 FCNT MWD CP30 4 1 68 48 13 NCNT MWD CP30 4 1 68 52 14 NPHI MWD PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 235.5 9352 4793.75 18234 235.5 9352 RHOB MWD G/CC 0.851 2.82 2.30108 12417 3061 9269 DRHO MWD G/CC -2. 992 0.33 0.0577077 12417 3061 9269 CALN MWD IN 8.19 15.35 9.73861 10553 3061 9269 PEF MWD B/E 1.43 12.8 2.58126 12417 3061 9269 GR MWD API 15.04 235.44 106.513 18115 235.5 9292.5 FET MWD HR 0.14 125.09 1.38149 18038 245.5 9302.5 RPX MWD OHMM 0. 93 2000 26.2134 18038 245.5 9302.5 RPS MWD OHMM 0.91 2000 35.1201 18038 245.5 9302.5 RPM MWD OHMM 0.85 2000 33.2399 18038 245.5 9302.5 RPD MWD OHMM 0.79 2000 21.0321 18038 245.5 9302.5 ROP MWD FPH 0.15 5332.22 172.577 18096 304.5 9352 FCNT MWD CP30 327.38 1835.26 574.252 12390 3061 9255.5 NCNT MWD CP30 77490 127479 96447 12390 3061 9255.5 NPHI MWD PU 9.53 79.15 31.8977 12390 3061 9255.5 First Reading For Entire File 235.5 Last Reading For Entire File 9352 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/01/19 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 11/01/19 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 DGRC 235.5 3012.5 R15P 245.5 3022.0 R39P 245.5 3022.0 R27P 245.5 3022.0 R09P 245.5 3022.0 EWXT 245.5 3022.0 ROPA 304 .5 3081.0 $ LOG HEADER DATA DATE LOGGED: 04-DEC-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 3081.0 TOP LOG INTERVAL (FT) : 304.0 BOTTOM LOG INTERVAL (FT) : 3081.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 65.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 252384 EWR4 ELECTROMAG. RESIS. 4 077613 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 13.500 DRILLER'S CASING DEPTH (FT) : 110.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 9.30 MUD VISCOSITY (S) : 185.0 MUD PH: 9.2 MUD CHLORIDES (PPM) : 120 FLUID LOSS (C3) : 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.650 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.060 92.0 MUD FILTRATE AT MT: 1.900 70.0 MUD CAKE AT MT: 5.150 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 FET MWDO10 HR 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWDO10 OHMM 4 1 68 16 5 RPM MWDO10 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 235.5 3081 1658.25 5692 235.5 3081 GR MWDO10 API 15.04 135.18 76. 6426 5555 235.5 3012.5 FET MWDO10 HR 0.14 3.86 1.12346 5554 245.5 3022 RPX MWD010 OHMM 1.81 2000 75.132 5554 245.5 3022 RPS MWDO10 OHMM 1.59 2000 103.444 5554 245.5 3022 RPM MWDO10 OHMM 1.48 2000 95.9639 5554 245.5 3022 RPD MWDO10 OHMM 1.59 2000 54.5871 5554 245.5 3022 ROP MWD010 FPH 0.15 5332.22 172.41 5554 304.5 3081 First Reading For Entire File 235.5 Last Reading For Entire File 3081 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/01/19 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 11/01/19 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 DGRC 3013.0 9292.5 APEL 3061.0 9269.0 TNPS 3061.0 9255.5 R152 3061.0 9302.5 EWXT 3061.0 9302.5 R27P 3061.0 9302.5 R39P 3061.0 9302.5 R09P 3061.0 9302.5 AHSI 3061.0 9269.0 TNFA 3061.0 9255.5 ADCL 3061.0 9269.0 TNNA 3061.0 9255.5 ACDL 3061.0 9269.0 ROPA 3081.5 9352.0 LOG HEADER DATA DATE LOGGED: 15-DEC-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 9352.0 TOP LOG INTERVAL (FT) : 3081.0 BOTTOM LOG INTERVAL (FT) : 9352.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 48.7 MAXIMUM ANGLE: 64.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 269077 EWR4 ELECTROMAG. RESIS. 4 231951 CTN COMP THERMAL NEUTRON 244601 ALD Azimuthal Litho-Dens 125035 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.875 DRILLER'S CASING DEPTH (FT) : 3071.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) : 9.20 MUD VISCOSITY (S) : 68.0 MUD PH: 8.0 MUD CHLORIDES (PPM) : 57000 FLUID LOSS (C3) : .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 176.7 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 RHOB MWD020 G/CC 4 1 68 4 2 DRHO MWD020 G/CC 4 1 68 8 3 CALN MWD020 IN 4 1 68 12 4 • PEF MWD020 B/E 4 1 68 16 5 GR MWD020 API 4 1 68 20 6 FET MWD020 HR 4 1 68 24 7 RPX MWD020 OHMM 4 1 68 28 8 RPS MWD020 OHMM 4 1 68 32 9 RPM MWD020 OHMM 4 1 68 36 10 RPD MWD020 OHMM 4 1 68 40 11 ROP MWD020 FPH 4 1 68 44 12 FCNT MWD020 CP30 4 1 68 48 13 NCNT MWD020 CP30 4 1 68 52 14 NPHI MWD020 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3013 9352 6182.5 12679 3013 9352 RHOB MWD020 G/CC 0.851 2.82 2.29907 12417 3061 9269 DRHO MWD020 G/CC -2. 992 0.338 0.0587453 12417 3061 9269 CALN MWD020 IN 8.19 15.35 9.73861 10553 3061 9269 PEF MWD020 B/E 1.43 12.8 2.58126 12417 3061 9269 GR MWD020 API 39.77 235.44 119.724 12560 3013 9292.5 FET MWD020 HR 0.2 125.09 1.49628 12484 3061 9302.5 RPX MWD020 OHMM 0. 93 1827. 19 4.45004 12484 3061 9302.5 RPS MWD020 OHMM 0. 91 2000 4 .72341 12484 3061 9302.5 RPM MWD020 OHMM 0.85 2000 5.33475 12484 3061 9302.5 RPD MWD020 OHMM 0.79 2000 6.10382 12484 3061 9302.5 ROP MWD020 FPH 1. 91 975. 62 172.651 12542 3081.5 9352 FCNT MWD020 CP30 327.38 1835.26 574.252 12390 3061 9255.5 NCNT MWD020 CP30 77490 127479 96447 12390 3061 9255.5 NPHI MWD020 PU 9.53 79.15 31.8977 12390 3061 9255.5 First Reading For Entire File 3013 Last Reading For Entire File 9352 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/01/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 11/01/19 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 11/01/19 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services t • Physical EOF Physical EOF End Of LIS File ConocoPhil l l s Alaska, Inc. �1 FINAL WELL REPORT MUDLOGGING DATA TARN 2L-312 Provided by: CANRIG Approved by: Lisa M. Wright Compiled by: Daniel Grunwald Zach Beekman Distribution: December 28, 2010 Date: December 15, 2010 ConocoPPhillips Alaska.Inc. 2L-310 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT&CREW 2 1.1 EQUIPMENT SUMMARY 2 2 WELL DETAILS 3 2.1 WELL SUMMARY 3 2.2 HOLE DATA 3 2.3 DAILY ACTIVITY SUMMARY 4 3 GEOLOGICAL DATA 7 3.1 LITHOSTRATIGRAPHY 7 3.2 MUDLOG SUMMARY 8 3.3 CONNECTION GASES 14 3.4 TRIP(WIPER)GASES 14 3.5 GAS PEAKS 15 3.6 SAMPLING PROGRAM/SAMPLE DISPATCH 16 4 PRESSURE/FORMATION STRENGTH DATA 17 4.1 PORE PRESSURE GRADIENT EVALUATION 17 4.2 QUANTITATIVE METHODS 18 5 DRILLING DATA 19 5.1 SURVEY DATA 19 5.2 BIT RECORD 22 5.3 MUD RECORD 23 6 DAILY REPORTS 24 Enclosures 2"/100' Formation Log (MD/TVD) 2"/100' Drilling Dynamics Log (MD/TVD) 2"/100' Gas Ratio Log (MDITVD) 2"/100' LWD/Lithology Log (MD/TVD) Final Data CD 1 CANRIG Conoco Phillips Alaska.Inc. 2L-310 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type/Position Total Comments Downtime QGM agitator and gas trap Ditch gas Flame ionization total gas 0 and chromatography. Hook Load/Weight on bit Totco WITS Feed 0 Derived from Pump Stroke 0 Mud Flow In Rates*and Pump Output Mud Flow Out Totco WITS Feed* 0 Mudlogging unit HP Compaq Pentium 4 0 computer system (x2: DML& Rigwatch) Mudlogging unit In-unit data 0 Acromeg box collection/distribution center Pit Volumes, Pit Gain/Loss Totco WITS Feed* 0 Pump Pressure Totco WITS Feed* 0 Totco not Pump stroke counters Totco WITS Feed* 2%hours accumulating pump strokes over 2 stands Totco Well Totco computer networked 0 Monitoring Components within mudlogging unit* Totco block height and Derived from Totco depth depth tracking poorly Rate of penetration tracking components (block 0 calibrated, adjustments height*) made in RigWatch for production hole. RPM Totco WITS Feed* 0 Torque Totco WITS Feed* 0 *Sporadic loss of data for short periods of time during loss of internal communications within Totco Crew Unit Type : Arctic Unit Number : ML057 Mudloggers Years Days Sample Years Days Technician Days Catchers Daniel Grunwald 2 14 Josh Dubowski 2 9 Allen Williams 4 Zach Beekman 2 14 Josh Michaud 1 12 Doug Acker 1 5 Eric Jones 1 2 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well 2 CANRIG Iry ConocoPPhillips Alaska.Inc. 2L-310 2 WELL DETAILS 2.1 Well Summary Well: 2L-312 API Index#: 50-103-20626-00-00 Field: Kuparuk River Unit Surface Co-Ordinates: 174' FNL, 675' FEL, Sec 22, Tarn Oil Pool T10N, R7E, Umiat Meridian Borough: North Slope Primary Target Depth: 8897' MD/5334'TVD State: Alaska Total Depth: 9351' MD/5629'TVD Rig Name/Type: Doyon 15,Arctic Triple Suspension Date: N/A Primary Target: Bermuda Formation License: N/A Spud Date: December 2, 2010 Ground Elevation: 114.8'AMSL Completion Date: 12/23/2010 RT Elevation: 154.8'AMSL Completion Status: Completed Producer Secondary Target: None Depth: Classification: Oil TD Date: December 15, 2010 TD Formation: Seabee Fm. /equivalent Days Testing: N/A Days Drilling: 10 days 2.2 Hole Data Maximum Depth Mud Shoe Depth Hole TD Dev. Casing/ MD TVDSS LOT MD TVDSS Section Formation Weight (,,inc) Liner (ppg) (ft) (ft) (Ppg) (ft) (ft) Schrader 13'/" 3081' -2926' Bluff Fm./ 9.5 64° 10%" 3071' -2416' 15.2 equivalent 9'/e" 9052' -5629' Seabee Fm./ 9.2 50° 7%" 9344' -5740' (NA) equivalent 3 CANRIG ConocoPhillips Alaska.Inc. 2L-310 2.3 Daily Activity Summary 11/30/10 Connect Doyon 15 rig modules over 2L-312 well. 12/01/10 Continue to rig up. Replace knife valve. Hold pre-spud meeting in the dog house. Pick up BHA. Test surface lines. Begin circulating at 11:45 PM. 12/02/10 Drill from 110'to 304'. Pull out of hole with 3 stands HWDP to pick up BHA#1. Pick up BHA#1. Encountered bridge at 160'. Wash and ream with 1 stand drill pipe from 160'to 253'. Finish picking up BHA to 276'. Wash and ream from 253'to 304'. Continue drilling from 304'to 1081'. Max gas of 206u. 12/3/10 Drill ahead from 1081'to 1402'.At 1402' survey indicated a 6.9 deg dog leg. Worked pipe to knock down dog leg to 3.2 deg. Drill ahead from 1402'to 1800'. Reciprocate pipe from 1800'to 1770' due to excess mud to rock washer and cuttings tank. Continue drilling from 1800'to 2286'with no more issues as of midnight. 12/4/10 Drill ahead from 2286'to intermediate casing point at 3081'with no issues. Circulate multiple bottoms up. Back ream out of hole from 3081' to 1390'and circulated 1 bottoms up. Trip in hole from 1390'to 3081'. Once back on bottom, circulated and conditioned the hole. Monitored the well and blew down the top drive. Pull out of hole on elevators from 3081'to 1488'as of midnight. 12/5/10 Continue to pull out of the hole and lay down the BHA. Clear and clean the rig floor. Rig up casing crew and equipment and begin running 10'/"casing. Run in hole with 10'/"casing to 1276' and circulate a bottoms up. Continue to run in hole with casing to 2272' and circulate another bottoms up. Run casing to 3066' and pick up hanger and landing joint. Tagged bottom at 3081'and circulated bottoms up. Land casing on hanger as of midnight. 12/6/10 Condition the hole and mud. Rig up cementing equipment and perform cement job. Rig down cementing equipment. Clean and clear rig floor. Lay down 10'/<" casing equipment, cementing equipment, and nipple down the diverter. Nipple up BOP's as of midnight. 12/7/10 Continue to nipple up BOP stack. Change out rams. Make up test plug and head pin. Test BOP's as of midnight. 12/8/10 Finish testing BOP stack. Pick up 5"drill pipe. Pick up drill bit and start making up BHA#2 as of midnight. 12/9/10 Continue to pick up BHA#2 and run in the hole. Run in the hole with drill pipe. Tag cement at 2940'. Wash down to 2986'. Perform casing pressure test to 3000 psi. Drill out of the shoe and cement to 3081'. Drill 20'of new formation to 3101'. Circulate bottoms up. Perform LOT to 15.2 ppg EMW. Change out the saver sub. Drilling ahead to 3515'and repair pump as of midnight. 12/10/10 Change out liner gasket on pump#2. Drill ahead from 3549' to 3601'. Change out liner gasket. Drill ahead from 3601'to 3714'. Change out liner gasket. Drill ahead from 3714'to 4425'. Change out liner gasket and wear plate on pump#2. Drill ahead from 4425'to 4774' as of midnight. 12/11/10 Drill from 4774'to 5040'. Drop ball to open well commander. Circulate mud with large amount of cuttings on shakers. Drop ball to close well commander. Monitor well and pull out of the hole to the shoe. Run in hole. Wash and ream from 4948'to 5040'. Drilling ahead to 5700'. Repair pump and repair rock washer auger as of midnight. 4 CANRIG ConocoPhillips Alaska,Inc. 2L-310 12/12/10 Continue to repair mud pump. Drill ahead from 5741'to 5977'. Trouble shoot mud pump problem. Circulate bottoms up on one pump. Monitor the well. Pull out of hole to the shoe. Cut and slip drill line. Lubricate the rig and inspect the top drive and draw works. Complete the repairs on mud pump. Run in hole to 5977'. Drill ahead to 6377'as of midnight. 12/13/10 Drill ahead from 6377'to 6444'. Trouble shoot and repair pit room auger. Continue to drill ahead from 6444'to 7597'. A loss of pressure was observed, —500 psi. Circulate bottoms up. Pull out of the hole looking for a wash out. Found the wash out 13 stands out. Lay down the joint. Run in hole. Drill ahead to 7691' as of midnight. 12/14/10 Continue drilling ahead from 7691'to 8880'without any issues. At 8880' began controlled drilling at 50 ft/hr while going through the Bermuda. Drilled to 9166' as of midnight. 12/15/10 Continue drilling ahead to TD at 9352'. Open well commander and circulate then monitor the well. Pull out of the hole to 7597'. Circulate with well commander open. Run in hole to 9352'. Circulate with well commander open. Max gas was 1214u during circulation after running back to bottom. Pull out of the hole. Lay down the BHA as of midnight. 12/16/10 Continue to lay down the BHA. Change upper rams to 7 5/8" and test. Rig up and run in hole with 7 5/8"casing. Circulate at 3071'. Continue running in hole with casing to—4900' as of midnight. 12/17/10 Continue to run in hole with 7 5/8" casing from 4732'to 5390'. Circulate and condition mud. Continue to run in hole from 5390'to 6906'. At 6906' observed packing off. Continued to try to obtain circulation and to work pipe free. Decision made to lay down 7 5/8"casing. Laying down casing from 6906' to 5600' as of midnight. 12/18/10 Continue to pull out of the hole with 7 5/8" casing and lay down in pipe shed. Change and test top set of pipe rams for 5" pipe. Rig down test equipment and clean and clear the rig floor. Pick up and make up BHA. Begin running in hole with wiper BHA to 233'. Trouble shoot rod wash on mud pumps 1 and 2 as of midnight. 12/19/10 Continue picking up BHA for cleaner run. Run in hole from 607'to 6445'. Wash and ream down from 6445'to 7900'. Wash and ream down from 9130 to 9352'. Continue to wash and ream then circulate bottoms up at 9352'. Pump out of hole from 9352'to 4114' as of midnight. 12/20/10 Continue backreaming out of hole from 4114'to 3068'; open well commander—hole unloading cuttings; flow check well—well static; service rig—blow down top drive, grease drawworks and crown sheave; circulate bottoms-up; run in hole from 3068' to 4017', then backream out of hole to 3353'—well packing off at 3817'; circulate bottoms-up; pull out of hole from 3353'—pulled tight at 2510'; break free, work pipe, and ream down to 2600'; work drill string down to shoe at 3070', and flow check well—well static; wash down hole to bottom at 9352'; circulate hole clean, and flow check well—well static; pull out of hole from 9352'to 8370', pump dry job, and continue to pull out of hole. 12/21/10 Pulled out of hole. Laid down BHA. Changed and tested rams. Run in hole with 7 5/8"casing. Circulate bottoms up at shoe. 12/22/10 Pumped bottoms up to prep for cement @ 7,227' and looked good. Pumped cement job, no cement to surface and did not bump plug. Rig down cement tools, change and test BOP rams. 12/23/10 Run 3'/" production tubing and begin rig down. 5 CANRIG Iv ConocoPhillips Alaska,Inc. 2L-310 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops provided by ConocoPhillips Operations Geologist. HORIZON PROGNOSED LWD PICK MD TVD MD TVD (ft) (ft) (ft) (ft) Base of Permafrost 1417' 1380' - - 10'/" Casing Shoe 3059' 2400' 3071' 2402' C-80 (K10) 3281' 2504' 3273' 2491' Top of Campanian sand - - 3433' 2560' C-50 6055' 3809' 6069' 3811' C-40 6907' 4210' 6913' 4208' C-37 7322' 4405' 7323' 4397' S8-Top of Bermuda Sand 8905' 5335' 8897' 5334' T1.5-Base of Bermuda Sand - - 9130' 5485' C-35 9183' 5515' 9151' 5499' Total Depth 9433' 5677' 9352' 5629' 7 CANRIG ConocoPhillips Alaska.Inc. 2L-310 3.2 MudlogSummary Surface to top of C-80(0' MD to 3273' MD) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 930 7 150 912 0 26 This interval is comprised of thin interbedded clays,silty claystones,and silty sand with patchy cementation,all in varying proportions, along with minor organic material and sporadic conglomerates. Clays are pasty and light gray, while claystones are pale brown and largely pulverized; loose clay is hydrophilic, adhesive, and highly plastic when free of silt and sand; cuttings are subblocky to slightly tabular, with irregular,earthy fractures;fresh surfaces display a dull, earthy to waxy luster and a clayey to silty texture. Sands and conglomerates are light gray as a whole, and grain sizes are bimodal. A dominant,well sorted, very fine-grained fraction that grades to silt is interbedded with the silty claystone. Subordinate lenses and laminae of a moderately to poorly sorted,fine-to coarse-grained fraction are occasionally conglomeratic. The finer sand is primarily composed of very light gray quartz with trace to minor dark lithics. The coarser sand and pebbles are composed of very light gray to pale yellow quartz with lesser dark lithics which impart a salt and pepper appearance to the sands. The lithics mostly consist of dark gray to black, cryptocrystalline, siliceous grains with minor blue green glauconitic lithics. In both sands, the quartz is subangular to angular with moderate to poor sphericity. Quartz grain surfaces exhibit signs of etching and pitting,and coarser grains display older polished surfaces and fresher abraded surfaces. The lithics are generally subangular to subrounded with moderate sphericity, and coarser lithics also display older polished surfaces and fresher chipped surfaces. Woody and fibrous plant material is locally abundant, in the upper portion of this interval, and traces of shell fragments are present in the lower portion of the interval. Gas levels were generally low,with the exception of a peak over 200 units immediately above 1000' MD and peaks up to 1079 units associated with methane hydrates just above the base of the permafrost (1200' to 1400' MD). A weak show occurred in the sands from approximately 2860'to 2890' MD(-2310'——2325'TVD). Trace oil staining fluoresced bright yellow,and a streaming amber cut fluoresced bright white. No odor was detectable. Gas levels remained within background levels(20 to 25 units),but trace to minor amounts of ethane,propane, butane, and pentane emerged. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 996' 204u 40857 - - - - - - 1269' 486u 97616 - - - - - - 1292' 230u 46746 - - - - - - 1400' 1079u 266271 - - - - - - 2504' 101u 18634 - - - - - - 8 CANRIG Conoco✓Phillips Alaska.Inc. 2L-310 C-80 to top of Campanian sand (3273'to 3433' MD) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 632 55 229 30 1 13 The interval from the C-80 marker to the top of the Campanian sand is characterized by silty claystone with subordinate, interbedded clayey siltstone and trace to minor lenses and laminae of very fine sand. Medium gray to brownish gray cuttings are tabular and brittle to dense, with irregular fracture surfaces. The siltstones and claystones have an earthy luster and a silty to clayey texture. The sand is well sorted and predominantly very fine-grained,consisting of very light gray quartz with trace green lithics. Sand grains are subrounded to rounded with moderate sphericity. Gas levels were low and steady. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 3403' 30 5851 9 2 - - - - Top of Campanian sand to C50(3433'to 6069' MD) Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 999 19 187 41 1 13 The interval from the top of the Campanian sand to the C-50 marker is primarily comprised of siltstone with variable amounts of interbedded claystone and trace lenses and laminae of very fine sand. The upper 550 feet is more clayey than the remainder of the interval, grading into the clayey siltstone/silty claystone above. Otherwise,the bulk of the siltstone contains only minor to trace claystone beds. The Campanian sand in this well is similar to the other wispy sands immediately uphole; it consists of very fine-grained quartz sand and only trace green lithics, with relatively muted gas levels and no oil indicators. The siltstone is poorly indurated and medium brownish gray to exclusively medium gray, suggesting that the brownish tint is at least partly the result of oil-based mud staining. Cuttings are crunchy to brittle to dense,with a wedgelike to vaguely tabular habit and good parting along bedding in the upper half of the interval. Broken cuttings display irregular fractures,and fresh surfaces have a dull,earthy to waxy luster underlain by a smooth to silty texture. Very thin bedding is visible under magnification, along with microscopic, organic-rich black laminae. Samples are mildly to moderately calcareous, particularly in sandy patches. Rare thin wafers of precipitated calcite occur along bedding planes in the upper clay-rich portion of the interval. Loose sand in the samples consists of well sorted, lowermost very fine-grained quartz sand that grades to silt. The quartz is translucent and very light gray to pale yellow. Quartz grains are subrounded to subangular with moderate sphericity on average. Rare intact sandstone cuttings appear to be matrix supported in a silty, clayey matrix material and are weakly cemented by calcite. Gas levels were low, and no oil shows were observed. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 3700' 29u 5519 21 4 - - - - 4067' 42u 8406 26 - - - - - 5079' 29u 6167 82 - - - - - 9 CANRIG ConocoPhillips Alaska,Inc. 2L-310 C50 to top of C40(6069'to 6913' MD) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 778 40 199 41 0 16 The interval between these two markers is comprised of clayey siltstone that is interbedded with and grades into silty claystone. The amount of claystone gradually increases with depth until it becomes the predominant component of the samples at the base of the interval. Siltstones and claystones are brownish gray to medium gray;the brown tint is likely due in part to oil-based mud staining. The siltstone is poorly indurated while claystones are firm, and cuttings are brittle to dense depending on clay content. Siltstone cuttings are wedgelike to slightly tabular with irregular fractures, and claystone cuttings are subblocky with blocky fractures. Fresh surfaces display a dull, earthy to waxy luster underlain by a smooth,silty to clayey texture. Microscopic bedding is visible in the siltstones,but no structure is apparent within the claystone cuttings. Samples are moderately calcareous, siltstones more so than claystones. Gas levels were low,though measurable propane emerged in the lower 100 feet of the interval. No oil shows were observed. Peaks Depth (MD) TG _ Cl C2 C3 iC4 nC4 iC5 nC5 6166' 33u 6456 19 - - - - - 6869' 41u 7102 126 45 1 - - - C40 to C37(6913'to 7323' MD) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 431 27 200 46 15 30 The interval between these two markers is comprised of silty claystone with subordinate interbedded clayey siltstone and trace very fine quartz sand. The siltstone and sand increase very slightly throughout the interval. The claystone is medium to dark grayish brown, likely due at least in part to staining by oil-based mud. Cuttings are brittle and have a wedgelike to flaky habit. Fractures are irregular, and fresh surfaces exhibit a dull, earthy to waxy luster underlain by a smooth to silty texture. No structure is evident at the scale of the cuttings. The sand is lowermost very fine-grained quartz that grades into silt,along with traces of upper very fine sand grains. The quartz is very light gray to pale yellow and subangular with moderate to poor sphericity. Grain surfaces are etched and pitted. Clayey cuttings are only mildly calcareous, though silty cuttings effervesce slightly more when acid is applied. Gas levels were low, though the background level has risen to roughly double that of all previous intervals. Additionally, measurable amounts of butane and pentane have emerged. No oil indicators were observed. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 6933' 44u 8508 155 35 3 - - - 7118' 46u 8072 175 41 6 3 - - 7204' 39u 7746 180 52 4 5 - - 10 CANRIG Conoc Phillips Alaska.Inc. 2L-310 C37 to S8(7323'to 8897' MD) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 865 13 169 414 4 28 The interval between the C37 marker and the top of the Bermuda sand is mostly comprised of nearly equal amounts of interbedded clayey siltstones and silty claystones with trace amounts of very fine sand. Claystones constitute slightly more than half the samples atop the section, while a subtle reverse in the proportions is observed throughout the length of the entire interval. This sequence is sharply interrupted by conspicuous sand beds near the top of the interval between 7440'and 7640' MD(4450'to 4550'TVD). On a lesser note, thin, devitrified ash tuffs occur between 8650' and 8670' MD. The claystones and siltstones are medium grayish brown and poorly indurated. Coloration has likely been influenced by oil-based mud as samples have been ground to sand-sized cuttings. Cuttings are brittle with a wedgelike to flaky habit. Fractures are irregular, and fresh surfaces display a dull, earthy to waxy luster underlain by a smooth texture that is variably silty. No structure is evident in the microscopic cuttings. The rare ash tuffs are white, soft, somewhat tabular with rounded edges,and mushy to gelatinous when washed with water. The sands near the top of the interval are moderately to well sorted,with grain sizes ranging from upper very fine-grained through lower very fine-grained and grading into silt-sized particles. The sand is composed of very light gray to pale yellow quartz with rare lithics. Grains are subangular to angular with moderate to poor sphericity,and grain surfaces are etched and pitted. The sand is moderately calcareous,although this is likely due to crushed marble mud additive that is difficult to isolate from the quartz sand. Gas peaks associated with the sands are roughly 10 times above background levels; however, no oil indicators were observed in the sands. With the exception of the sands, gas is generally low, although a slight decrease is evident from below the sands to the base of the interval. No oil shows were observed. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 7452' 233u 47149 953 203 17 27 16 9 7561' 279u 55112 1326 285 19 35 3 5 7585' 415u 81482 2076 540 37 80 3 5 7622' 107u 20238 568 188 13 33 - - 8108' 48u 9478 317 145 26 43 8 1 8345' 40u 5875 152 79 22 35 11 - S8 to T1.5(8897'to 9130' MD) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 100 22 58 121 9 55 This interval is the target reservoir, the Bermuda sand; it is comprised of roughly equal proportions of interbedded silty claystone,clayey siltstone, and sandstone. Only traces of sandstone exist at the top of the interval. It increases in abundance to half of the samples through the middle of the interval,waning again to about a quarter of the samples at the base of the interval. The claystone and siltstone are brownish gray to medium gray, although the brown tint is likely due in part to 11 CANRIG Conoc Phillips Alaska.Inc. 2L-310 oil-based mud stain. Claystone cuttings are dense to brittle with a subblocky habit,while siltstone cuttings are brittle to crumbly with a similar but slightly more rounded subblocky habit. Cuttings break along irregular fractures,and broken surfaces expose a dull,earthy to waxy luster underlain by a clayey to silty texture. Rare, microscopic black laminae are visible in some cuttings, but structure is otherwise difficult to discern. The sandstone is light gray,firm to friable,moderately to well sorted,and matrix supported. Very fine-grained quartz sand is bound within an opaque white,silty matrix weakly cemented by calcite. Quartz grains are very light gray to pale yellow and subangular to subrounded,with moderate sphericity on average. Grain surfaces exhibit signs of etching. Gas levels were generally low,but peaks within the sandstone were five to ten times above background levels. However,any potential oil indicators were weak enough to be masked by oil-based mud overprinting. No oil stain was apparent, nor was there any petroliferous odor detectable beyond the residual oil-based mud scent. No sample fluorescence was emitted, and no cut was extracted. Peaks Depth (MD) TG Cl C2 C3 Ic4 nC4 iC5 nC5 8943' 98u 18006 1192 524 56 128 26 40 8978' 104u 18769 1387 591 66 155 39 51 8987' 111u 19486 1622 751 72 192 42 43 9020' 100u 18102 1130 574 66 170 30 29 9043' 121u 22228 1420 694 76 193 52 50 9094' 113u 20994 1244 667 79 205 56 62 T1.5 to C35(9130' to 9151' MD) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 69 31 48 21 11 16 The interval from the base of the Bermuda sand to the C35 marker is comprised of clayey siltstone with lesser interbedded silty claystone and very fine-grained sandstone. The siltstone and claystone are brownish gray to medium gray,with probable brown staining from oil-based mud. Cuttings are subblocky,though silty cuttings tend to be somewhat rounded. Siltstone cuttings are brittle to crumbly, while clayey cuttings are brittle to dense. Cuttings break along irregular fractures, and fresh surfaces exhibit a dull, earthy to waxy luster underlain by a smooth, silty to clayey texture. Wispy black laminae are visible on smooth, bit-polished surfaces, though structure is otherwise imperceptible. The sandstone is similar to the reservoir sandstone above. It is light gray and firm to friable,while the sand is moderately to well sorted. Very fine-grained quartz sand and trace black lithics are matrix supported in an opaque white, silty matrix weakly cemented by calcite. Quartz grains are very light gray to pale yellow and subangular to subrounded, with moderate sphericity on average. Grain surfaces are etched and pitted. Gas levels are generally low, and no shows were observed. Peaks _ Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 (MD) 9135' 22u 3808 236 165 30 66 27 27 12 CANRIG ConocoPPhillips Alaska.Inc. 2L-310 C35 to TD(9151'to 9352' MD) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 322 10 130 62 11 32 The interval from the C35 marker to the end of the well is comprised of clayey siltstone with subordinate interbedded silty claystone and trace to minor sandstone. The siltstone and claystone are brownish gray to dark brown and moderately indurated. Cuttings are subblocky to vaguely tabular and brittle to dense. Irregular fracture surfaces expose a dull, earthy to waxy luster underlain by a silty to clayey texture. Structure is difficult to discern aside from wispy black laminae that are visible on smooth, bit-polished surfaces. Sandstones are firm to hard,and they consist of well to moderately sorted,very fine-grained quartz sand with trace black lithics. Quartz grains are very light gray to pale yellow, subangular to subrounded, and lightly etched and pitted. The sand is matrix supported in an opaque,white,silty matrix with a weak calcite cement, and the sandstone is only mildly effervescent when acid is applied. Gas is generally low, and no oil shows were observed. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 9200' 39u 7372 365 213 26 67 24 40 9326' 62u 12278 409 186 18 68 35 44 13 CANRIG Conoc Phillips Alaska.Inc. 2L-310 3.3 Connection Gases 1 unit=0.05% Methane Equivalent Depth Gas over BGG (feet) (units) 1398' 555 1493' 46 3.4 Trip(Wiper)Gases 1 unit=0.05% Methane Equivalent Depth Trip to Gas (feet) (feet) (units) 3081' 1390' 212 (WG) 3081' SURFACE 34 5038' SHOE (<_ 3081') 1115 (gas from-3200') 5038' SHOE (<_3081') 52 (WG) 5974' SHOE (5 3081') 30 7600' 5800' 50 9352' 7600' 1214(WG) 9352' SURFACE 788 9352' SURFACE 458 14 CANRIG . ...... ..... . ConocoPhillips Alaska.Inc. 2L-310 3.5 Gas Peaks Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) (units) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) 996'/991' 204u 40857 - - - - - - 1269'/1250' 486u 97616 - - - - - - 1400'/1370' 1079u 266271 - - - - - - 2504'/2153' 101u 18634 - - - - - - 7585'/4524' 414u 81482 2076 539 37 80 2 4 7623'/4544' 108u 19286 532 169 12 29 7 6 8978'/5386' 104u 18768 1386 591 66 155 38 51 8988'/5393' 107u 18618 1570 733 69 187 40 40 9043'/5428' 121u 22228 1419 694 75 193 52 49 9094'/5461' 113u 20994 1244 667 79 205 55 62 15 CANRIG ConocoPPhillips Alaska.Inc. 2L-310 3.6 Sampling Program/Sample Dispatch Reference samples from water-based mud in the surface hole were collected in sample envelopes and stored in cardboard boxes; samples from oil-based mud in the production hole were collected in plastic vials and stored in trays with folding lids. Set Type/Purpose Frequency Interval* Dispatched to Washed, screened, and dried reference 50' 110'—8850' CPAI,ABV 100 samples in sample Bayview Warehouse A envelopes and 10' 8850'—9100' 619 E.Ship Creek Ave. Anchorage,AK 99501 plastic vials Attn:D.Przywojski/M.McCracken 50' 9100'—9352' (907)263-4859 Set owner: CPAI Washed, screened, and dried reference 50' 110'—8850' CPAI,ABV 100 samples in sample Bayview Warehouse B envelopes and 10' 8850'—9100' 619 E.Ship Creek Ave. Anchorage,AK 99501 plastic vials Attn:D.Przywojski/M.McCracken 50' 9100'—9352' (907)263-4859 Set owner: AOGCC Unwashed and screened wet 50' 110'—8850' CPAI,ABV 100 samples in plastic Bayview Warehouse C Whirl-Pak®bags 10' 8850'—9100' 619 E.Ship Creek Ave. Anchorage,AK 99501 Attn:D.Przywojski/M.McCracken Set owner: CPAI 50' 9100'—9352' (907)263-4859 *Sample frequency was locally altered according to drill rate constraints and zones of interest. 16 CANRIG u) 22 0 � � 0� 0� 02 O � O � O � (� O m2 m2 m2 m m2 m2 m2 m2 m2 -a z z z Et z z z z z 3 1- > > > � - > > > > > 2 w I- R a) v. -a U) U M M M co 4) N m C O O O O O O O O 0 N L V a - � L o c co v co M M M M c M a O O) d) a) 0) 6) O) O) a) II (a C N co Zo E0 is) in iN 0 `1= M a LO co O N '- CO M Cl) H N N M f I- In I-99 (A to -a C Nal co _3 a t—ao 1-- 0 o Co F� v a� a� ' ' v N N CO LO Nt Nr co U) U) co U) IX gN C - N 8 O m N L U Y i) in Zr) C') in i-- o iN u) Q 0 N CO CO 0) M apo CO LO M II CO CO CO CO f`- CO CO p p O ai C C o I >+ \ \o \ 0 0 0 0N o O o o O O p p .... — C9 'a 0 C') M NCD N to CO C) ii )— Z C) o J J J I— H 0 0 J w Ce C N J 0 co U U J J Z Z 0 U) CO w, (V C Z 3 CO O > o \ \° 0 0 0 U) 0 o O O o o O O O II > �' O CO (O CO LO 73 O O U CO 'IE' O o NN- Q HI- I- H H I- I- F- N Ll- J U) oO co0 U) m 0 0 U) U LL6N C L 0 w 0 -a cn as T co n m a N U R II a- W 0 R W E '9 co'T N- aLo 0 M o n Ce d U 3 U U U N F— U H U O. �i — p til a_ H T- 00 '1' 4 F— z CO C 2 g a 23 03 E W 0 $ 'k \ . ¥ ƒ V k�) k \ a ,13 � 0 kk - � = 7 •a.• c) a) E > $ \ ) \ _ & _ cal (1) ma, Ear 0 � � # 2 1 e = o \ 2 § � � k a =@ a 6 y a) a_ .a) G & w > \ G / / \ , % _. § a) 0 c cis 22f g / o ala 5- c k @ 7 : 2E # 73 k =j k CC E _ �£ � 2m C0 ,- _ . v\ \ � � _c -a \ \ .4 = QE = a £ c0 E 2 \a° o � %f t _a>" E � ~ \ / � � - / 0_ E\ 8 o 2c ° § r 2 / 7 U) § / 2E 0 o .� f 7 \ � 7 $ + $ \ x — ® o 2 c al \ c k / 0 � // @ \ / Em / u)N 7 % / 0 @ e § S = � w 0 2 / $ . 2f £ me \ L '> •� K $ / &f ao o ) a_ ..7, k = o ' ge / 0 E E E \ � \ U \ "_ \ � " ® Wo So 0 » S 0 \ 6) E kk ƒ \ k = = o ° 1_.. / / a % § § / \ # -co) c » f = § if 77 � ' 22 \ oW _cco § 0_ \ b: 2 c g \ 0 co 0, _ a 72@ f [ 7 $ E_ al o_ 1.- ...= 2 CO e @ m as .0) e E E C 0 0 0 ® = o 4 R : 0- < 2 era Conoc Phitlips Alaska,Inc. 2L-310 5 DRILLING DATA 5.1 Survey Data Measured Inclination Azimuth True N(+)/S(-) E(+)/W(-) Vertical Dogleg Vertical Section Rate D(ft)h (°) (°) Depth (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 40.10 0.00 0.00 40.10 0.00 0.00 0.00 0.00 169.00 0.46 141.78 169.00 0.41 0.32 0.39 0.36 258.00 0.45 352.28 258.00 0.34 0.49 0.55 0.99 351.00 0.48 287.73 351.00 0.14 0.07 0.05 0.53 440.00 0.93 70.37 439.99 0.50 0.40 0.30 1.51 530.00 3.69 53.02 529.91 2.48 3.40 2.88 3.13 628.00 5.71 46.08 627.58 7.76 9.43 7.82 2.14 724.00 6.49 50.46 723.03 14.53 17.06 14.05 0.95 818.00 8.78 52.71 816.19 22.26 26.86 22.25 2.46 912.00 11.78 55.81 908.67 32.00 40.51 33.84 3.24 1007.00 13.16 66.24 1001.44 41.81 58.43 49.63 2.77 1082.48 15.63 69.65 1074.55 48.81 75.83 65.42 3.46 1158.36 18.85 68.98 1147.01 56.76 96.87 84.60 4.25 1248.69 21.63 69.55 1231.75 67.81 126.09 111.26 3.09 1345.34 24.28 72.12 1320.75 80.14 161.70 143.95 2.93 1387.50 25.45 72.37 1359.00 85.55 178.58 159.53 2.79 1435.11 26.13 72.40 1401.86 91.81 198.33 177.76 1.43 1531.07 29.93 72.41 1486.55 105.44 241.30 217.45 3.96 1625.57 34.77 74.08 1566.36 117.97 289.72 262.32 5.21 1725.25 37.91 76.86 1646.65 134.73 346.89 315.74 3.56 1820.32 40.91 80.35 1720.11 146.59 406.04 371.65 3.92 1912.44 43.04 83.99 1788.60 154.94 467.06 430.04 3.51 2007.81 45.92 88.55 1856.66 159.22 533.70 494.73 4.51 2104.02 48.31 92.74 1922.14 158.38 604.16 564.11 4.04 2198.61 50.37 95.35 1983.77 153.29 675.71 635.36 3.02 2288.99 54.28 96.09 2039.00 146.15 746.88 706.61 4.37 2380.40 57.72 94.40 2090.11 139.25 822.33 782.03 4.06 2479.44 60.69 92.13 2140.82 134.43 907.25 866.36 3.59 2576.77 61.97 92.58 2187.51 130.92 992.57 950.84 1.38 2668.31 63.46 93.30 2229.48 126.74 1073.82 1031.45 1.77 2764.88 65.85 94.53 2270.81 120.77 1160.88 1118.10 2.73 2861.75 64.88 94.72 2311.19 113.67 1248.64 1205.65 1.02 2954.78 64.31 94.40 2351.10 106.99 1332.41 1289.20 0.69 3032.01 64.03 94.85 2384.75 101.39 1401.70 1358.31 0.64 19 CANRIG Conoco✓Phillips Alaska.Inc. 2L-310 Measured Inclination Azimuth True N(+)/S(-) E(+)/W(-) Vertical Dogleg Depth ° ° Vertical Section Rate (ft) ( ) ( ) Depth (ft) (ft) (ft) (ft) (°/100ft) 3105.70 63.50 95.69 2417.33 65.32 1467.52 1424.05 1.25 3201.03 63.78 97.30 2459.66 85.65 1552.38 1509.23 1.54 3296.15 64.33 96.17 2501.27 75.63 1637.32 1594.55 1.21 3391.17 64.45 96.56 2542.34 66.13 1722.48 1679.99 0.39 3486.93 64.40 94.56 2583.69 57.76 1808.45 1766.00 1.88 3580.62 62.62 94.68 2652.48 51.00 1892.02 1849.38 1.90 3676.13 62.50 94.94 2669.49 43.90 1976.49 1933.69 0.27 3770.60 61.82 94.09 2713.61 37.32 2059.76 2016.73 1.07 3865.11 61.61 94.23 2758.39 31.28 2142.77 2099.41 0.26 3959.77 61.26 94.66 2803.65 24.84 2225.66 2182.04 0.54 4055.47 61.00 94.99 2849.86 17.79 2309.17 2265.40 0.41 4149.18 61.68 94.87 2894.80 10.72 2391.09 2347.21 0.73 4244.50 61.62 95.11 2940.07 3.43 2474.66 2430.67 0.23 4338.98 61.31 95.52 2985.20 4.26 2557.31 2513.30 0.50 4434.06 62.18 93.75 3030.21 11.02 2640.78 2596.57 1.88 4528.54 62.13 94.09 3074.34 16.73 2724.12 2679.52 0.32 4625.04 61.92 94.12 3119.61 22.83 2809.13 2764.18 0.22 4718.37 61.68 94.92 3163.71 29.32 2891.12 2845.94 0.80 4811.39 61.55 94.69 3207.93 36.17 2972.67 2927.34 0.26 4906.53 61.30 94.89 3253.44 43.15 3055.93 3010.44 0.32 5001.82 61.12 94.93 3299.33 50.30 3139.14 3093.52 0.19 5095.28 61.42 93.67 3344.26 56.44 3220.86 3174.96 1.23 5190.93 61.15 93.37 3390.21 61.59 3304.59 3258.18 0.39 5285.90 60.88 93.77 3436.23 66.76 3387.50 3340.60 0.47 5379.86 61.89 93.99 3481.23 72.34 3469.79 3422.49 1.09 5474.88 61.62 93.94 3526.20 78.13 3553.30 3505.62 0.29 5570.03 61.33 94.06 3571.64 83.96 3636.69 3588.64 0.32 5664.64 60.86 94.66 3617.37 90.26 3719.28 3670.95 0.74 5757.80 61.99 94.08 3661.93 96.49 3800.85 3752.25 1.33 5853.85 61.62 94.34 3707.31 102.70 3885.28 3836.36 0.45 5948.36 61.15 94.42 3752.57 109.04 3968.00 3918.81 0.50 6041.59 60.98 94.34 3797.68 115.27 4049.35 3999.90 0.20 6135.66 61.98 94.96 3842.59 121.97 4131.73 4082.09 1.21 6231.11 61.56 94.99 3887.74 129.27 4215.51 4165.73 0.44 6324.83 62.40 95.05 3931.77 136.51 4297.93 4248.08 0.90 6419.76 62.17 95.26 3975.92 144.06 4381.63 4331.72 0.31 3513.76 62.02 95.55 4019.91 151.88 4464.33 4414.43 0.32 6602.76 61.84 95.70 4061.79 159.58 4542.48 4492.65 0.25 6700.90 61.65 95.79 4108.25 168.23 4628.49 4578.77 0.21 20 CANRIG Iv- Conocoi hiliips Alaska.Inc. 2L-310 Measured Inclination Azimuth True N(+)/S(-) E(+)/W(-) Vertical Dogleg Depth ° ° Vertical Section Rate (ft) ( ) ( ) Depth (ft) (ft) (ft) (ft) (°/100ft) 6798.03 61.49 95.65 4154.49 176.75 4713.49 4663.86 0.21 6894.19 63.00 94.60 4199.27 184.34 4798.24 4748.54 1.84 6986.61 62.99 94.31 4241.24 190.74 4880.33 4830.39 0.28 7078.67 62.98 94.63 4283.05 197.13 4962.10 4911.91 0.31 7178.92 61.92 94.97 4329.42 204.57 5050.67 5000.32 1.10 7273.77 61.97 94.80 4374.03 211.69 5134.07 5083.58 0.17 7367.92 61.85 95.06 4418.36 218.83 5216.82 5166.22 0.27 7463.37 61.68 95.37 4463.52 226.48 5300.57 5249.92 0.34 7558.42 59.67 99.00 4510.08 236.81 5382.76 5332.60 3.94 7649.75 57.53 102.59 4557.67 251.38 5459.32 5410.53 4.09 7744.68 55.72 105.49 4609.90 270.59 5536.21 5489.66 3.18 7836.25 54.14 107.25 4662.52 291.70 5608.12 5564.24 2.33 7935.02 52.72 110.41 4721.37 317.28 5683.19 5642.76 2.94 8032.64 51.76 114.64 4781.17 346.81 5754.45 5718.28 3.56 8125.23 50.74 118.30 4839.13 378.97 5819.08 5787.77 3.27 8222.42 51.11 122.79 4900.41 417.31 5884.03 5858.72 3.61 8316.99 51.61 127.41 4959.48 459.77 5944.43 5925.98 3.85 8407.76 50.84 132.75 5016.35 505.29 5998.55 5987.63 4.66 8504.39 49.68 138.22 5078.16 558.21 6050.63 6048.66 4.51 8598.60 49.07 143.45 5139.52 613.61 6095.77 6103.33 4.26 8693.83 48.91 148.14 5202.03 673.00 6136.15 6154.07 3.72 8788.62 49.70 153.18 5263.86 735.63 6171.32 6200.31 4.12 8882.99 49.77 158.79 5324.88 801.36 6200.61 6241.33 4.54 8977.97 49.88 161.12 5386.16 869.52 6225.48 6278.46 1.88 9073.65 49.31 160.50 5448.18 938.33 6249.42 6314.81 0.77 9166.20 48.70 160.69 5508.89 1004.22 6272.63 6349.89 0.68 9263.32 49.92 163.62 5572.22 1074.31 6295.18 6385.10 2.61 9313.29 49.87 164.00 5604.41 1111.01 6305.84 6402.42 0.59 9352.00 49.87 164.00 5629.36 1139.46 6313.99 6415.73 0.00 21 CANRIG I « t k N / CI k i iii \ \ I- 0 2 e 60. g $ S > Oa \ 7 Li j >aa \ 0 N0 < 2 1 ' ■ = co <0 2 < ƒ k ‘- o 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Tarn 2L-312 Daily Report Report for: Scott Heim Mark Brouillet Date: 12/2/2010 Time: 23:59 Current Depth (MD): 1081' Current Drilling ahead Current Depth (TVD): 1074' Operations: 24 hr Footage (MD): 971' Drilling Parameters not ROP: Current: 72 Max: 9045 Torque: Current: not available Max: available WOB: Current 14 Max: 22 RPM: Current: 55 Max: 55 PP: Current: 1409 Max: 1491 Lag: Strokes: 1610 Time: 12 min Surf-Surf: Strokes: 1748 Time: 13 min ECD: Current: Max: Mud Properties @ 992 MW: 8.9 FV: 264 PV: 32 YP: 59 FL: 11 Gels: 49/78/- Sol: 96 pH: 8.5 Cl- 100 Ca++: 20 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 35u Max: 206u Depth (MD/TVD): 1000'/997' Avg BG : 15u Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 996/991 202 40856 • Lithologies: Current: 40% claystone, 40%sand, 20%conglomeratic sand Last 24 hrs: 60% sand, 30%conglomeratic sand, 10%claystone Drill from 110'to 304'. Pull out of hole with 3 stands HWDP to pick up BHA#1. Operational Summary: Pick up BHA#1. Encountered bridge at 160'. Wash and ream with 1 stand drill pipe from 160'to 253'. Finish picking up BHA to 276'. Wash and ream from 253'to 304'. Continue drilling from 304'to 1081'. Max gas of 206u. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,135.00 CANRIG ConocoPhillips Alaska.Inc. Tarn 2L-312 Daily Report Report for: Scott Heim Mark Brouillet Date: 12/3/2010 Time: 23:59 Current Depth (MD): 2286' Current Drilling ahead Current Depth (TVD): 2038' Operations: 24 hr Footage (MD): 1205' Drilling Parameters not not ROP: Current: 48 Max: 9045 Torque: Current: available Max: available WOB: Current 10 Max: 45 RPM: Current: 50 Max: 55 PP: Current: 2021 Max: 2398 Lag: Strokes: 3478 Time: 24 min Surf-Surf: Strokes: 3677 Time: 25 min ECD: Current: 10.04 Max: - Mud Properties @ 1918 MW: 9.4 FV: 276 PV: 31 YP: 61 FL: 9.2 Gels: 50/83/- Sol: 7 pH: 8.9 Cl- 100 Ca'+: 20 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 20u Max: 912u Depth (MD/TVD): 1338'/1320' Avg BG : 65u Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases 555u (7u BG) 140271372' not avail. 46u (18u BG) 1487'/1448' 13292 Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 1338'/1320' 912u 182400 Lithologies: Current: 50%sand, 40%claystone, 10%siltstone Last 24 hrs: 50%sand, 50%claystone Drill ahead from 1081'to 1402'.At 1402'survey indicated a 6.9 deg dog leg.Worked pipe to Operational Summary: knock down dog leg to 3.2 deg. Drill ahead from 1402'to 1800'. Reciprocate pipe from 1800'to 1770'due to excess mud to rockwasher and cuttings tank. Continue drilling from 1800'to 2286'with no more issues as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,135.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Scott Heim Mark Brouillet Date: 12/4/2010 Time: 23:59 Current Depth (MD): 3081' Current Pulling out of hole Current Depth (TVD): 2406' Operations: 24 hr Footage (MD): 795' Drilling Parameters ROP: Current: 0 Max: 246 Torque: Current: 0 Max: 14932 WOB: Current 0 Max: 32 RPM: Current: 0 Max: 51 PP: Current: 0 Max: 2513 Lag: Strokes: 4674 Time: 31 min Surf-Surf: Strokes: 5217 Time: 34 min ECD: Current: Max: - Mud Properties @ 3801' MW: 9.5 FV: 185 PV: 29 YP: 56 FL: 6.8 Gels: 27/32/45 Sol: 6 pH: 9.2 Cr: 120 Ca++: 20 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 0 Max: 101u Depth (MD/TVD): 2504'/2152' Avg BG : 25u Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 212 3081'/2404' 36541 82 Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 2504'/2152' 101 18634 2609'/2202' 43 8404 12 5 2745'/2262' 56 13702 133 17 11 11 Lithologies: Current: 60%sand, 30%claystone, 10%siltstone Last 24 hrs: 60%sand, 40% claystone Drill ahead from 2286'to intermediate casing point at 3081' with no issues. Circulate multiple bottoms up. Back ream out of hole from 3081'to 1390' and Operational Summary: circulated 1 bottoms up. Trip in hole from 1390'to 3081'. Once back on bottom, circulated and conditioned the hole. Monitored the well and blew down the top drive. Pull out of hole on elevators from 3081'to 1488' as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,135.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Scott Heim Mark Brouillet Date: 12/5/2010 Time: 23:59 Current Depth (MD): 3081' Current Landing hanger Current Depth (TVD): 2406' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 4674 Time: 31 min Surf-Surf: Strokes: 5217 Time: 34 min ECD: Current: Max: - Mud Properties @ 3801' MW: 9.4 FV: 74 PV: 29 YP: 33 FL: 7.2 Gels: 19/23/31 Sol: 5 pH: 8.8 Cr: 120 Ca": 20 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 0 Max: 0 Depth (MD/TVD): Avg BG : 0 Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: 60% sand, 30%claystone, 10%siltstone Last 24 hrs: Continue to pull out of the hole and lay down the BHA. Clear and clean the rig floor. Rig up casing crew and equipment and begin running 10 3/4"casing. Run in Operational Summary: hole with 10 3/4'casing to 1276' and circulate a bottoms up. Continue to run in hole with casing to 2272' and circulate another bottoms up. Run casing to 3066' and pick up hanger and landing joint. Tagged bottom at 3081' and circulated bottoms up. Land casing on hanger as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,135.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Scott Heim Mark Brouillet Date: 12/6/2010 Time: 23:59 Current Depth (MD): 3081' Current Nipple up BOP's Current Depth (TVD): 2406' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 4674 Time: 31 min Surf-Surf: Strokes: 5217 Time: 34 min ECD: Current: Max: - Mud Properties @ 3801' MW: 9.4 FV: 74 PV: 29 YP: 33 FL: 7.2 Gels: 19/23/31 Sol: 5 pH: 8.8 Cr: 120 Ca++: 20 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 0 Max: 0 Depth (MD/TVD): Avg BG : 0 Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: 60% sand, 30%claystone, 10%siltstone Last 24 hrs: Condition the hole and mud. Rig up cementing equipment and perform cement job. Operational Summary: Rig down cementing equipment. Clean and clear rig floor. Lay down 10 3/4'casing equipment, cementing equipment, and nipple down the diverter. Nipple up BOP's as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,135.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Scott Heim Date: 12/7/2010 Time: 23:59 Current Depth (MD): 3081' Current Testing BOP's Current Depth (TVD): 2406' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 4674 Time: 31 min Surf-Surf: Strokes: 5217 Time: 34 min ECD: Current: Max: - Mud Properties @ 3801' MW: 9.0 FV: 52 PV: 13 YP: 12 FL: Gels: 13/18/19 Sol: 5.65 pH: - CF: 57500 Ca": MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 0 Max: 0 Depth (MD/TVD): Avg BG : 0 Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases • . (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: 60%sand, 30%claystone, 10% siltstone Last 24 hrs: Operational Summary: Continue to nipple up BOP stack. Change out rams. Make up test plug and head pin. Test BOP's as of midnight. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,070.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Scott Heim Date: 12/8/2010 Time: 23:59 Current Depth (MD): 3081' Current Making up BHA#2 Current Depth (TVD): 2406' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 4674 Time: 31 min Surf-Surf: Strokes: 5217 Time: 34 min ECD: Current: Max: - Mud Properties @ 3081' MW: 9.0 FV: 49 PV: 14 YP: 10 FL: Gels: 13/18/19 Sol: 5.67 pH: - Cr: 57000 Ca": MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 0 Max: 0 Depth (MD/TVD): Avg BG : 0 Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: 60%sand, 30%claystone, 10%siltstone Last 24 hrs: Operational Summary: Finish testing BOP stack. Pick up 5"drill pipe. Pick up drill bit and start making up BHA#2 as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,070.00 CANRIG DnuiTnii.nuno I ni. ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Scott Heim Date: 12/9/2010 Time: 23:59 Current Depth (MD): 3515' Current Drilling ahead Current Depth (TVD): 2567' Operations: 24 hr Footage (MD): 434' Drilling Parameters ROP: Current: 0 Max: 300 Torque: Current: 0 Max: 118211 WOB: Current 0 Max: 10 RPM: Current: 0 Max: 0 PP: Current: 95 Max: 3584 Lag: Strokes: 2440 Time: 13 min Surf-Surf: Strokes: 2997 Time: 16 min ECD: Current: 10 Max: - Mud Properties @ 3515' MW: 9.1 FV: 61 PV: 13 YP: 18 FL: Gels: 17/24/25 Sol: 5.68 pH: - CF: 57000 Ca++: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 2 Max: 30 Depth (MD/TVD): 3402/2550 Avg BG : 10 Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 3402/2550 30 5840 9 2 Lithologies: Current: 60% claystone, 40%siltstone Last 24 hrs: 50%claystone, 50%siltstone Continue to pick up BHA#2 and run in the hole. Run in the hole with drill pipe. Tag cement at 2940'. Wash down to 2986'. Perform casing pressure test to 3000 psi. Operational Summary: Drill out of the shoe and cement to 3081'. Drill 20' of new formation to 3101'. Circulate bottoms up. Perform LOT to 15.2 ppg EMW. Change out the saver sub. Drilling ahead to 3515' and repair pump as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Scott Heim Date: 12/10/2010 Time: 23:59 Current Depth (MD): 4774' Current Drilling ahead Current Depth (TVD): 3549' Operations: 24 hr Footage (MD): 1225' Drilling Parameters ROP: Current: 184 Max: 741 Torque: Current: 3370 Max: 118211 WOB: Current 3 Max: 11 RPM: Current: 75 Max: 100 PP: Current: 3502 Max: 3582 Lag: Strokes: 2622 Time: 14 min Surf-Surf: Strokes: 3224 Time: 17 min ECD: Current: 9.95 Max: - Mud Properties @ 4774' MW: 8.9 FV: 59 PV: 14 YP: 21 FL: 7.0 Gels: 17/24/27 Sol: 6.98 pH: - Cr: 51000 Ca++: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 8 Max: 41 Depth (MD/TVD): 4067/2894 Avg BG : 10 Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 4067/2894 41 8406 26 Lithologies: Current: 95%siltstone, 5%sand Last 24 hrs: 90%siltstone, 5%sand, 5%claystone Change out liner gasket on pump#2. Drill ahead from 3549'to 3601'. Change out Operational Summary: liner gasket. Drill ahead from 3601'to 3714'. Change out liner gasket. Drill ahead from 3714' to 4425'. Change out liner gasket and wear plate on pump#2. Drill ahead from 4425' to 4774' as of midnight. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,130.00 CANRIG I)w n11h,hurvni.e.,v Lm. ConocoPhiIiips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Scott Heim Date: 12/11/2010 Time: 23:59 Current Depth (MD): 5741' Current Pump repair Current Depth (TVD): 3653' Operations: 24 hr Footage (MD): 967' Drilling Parameters ROP: Current: 0 Max: 999 Torque: Current: 0 Max: 10149 WOB: Current 0 Max: 13 RPM: Current: 0 Max: 77 PP: Current: 0 Max: 3698 Lag: Strokes: 3998 Time: 21 min Surf-Surf: Strokes: 4948 Time: 26 min ECD: Current: 9.95 Max: - Mud Properties @ 5741' MW: 9.0 FV: 65 PV: 13 YP: 18 FL: 6.4 Gels: 22/23/24 Sol: 6.35 pH: - CF: 44000 Ca++: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 2 Max: 31 Depth (MD/TVD): 5108/3350 Avg BG : 10 Gas Events Trip Gas Depth (MD/TVD) C1 C2 C3 iC4 nC4 iC5 nC5 1115 3200/2459 52 (WG) 5038/3317 Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 5108/3350 31 6329 33 Lithologies: Current: 95% siltstone, 5%sand Last 24 hrs: 90%siltstone, 5%sand, 5% claystone Drill from 4774'to 5040'. Drop ball to open well commander. Circulate mud with large amount of cuttings on shakers. Drop ball to close well commander. Monitor Operational Summary: well and pull out of the hole to the shoe. Run in hole. Wash and ream from 4948' to 5040'. Drilling ahead to 5700'. Repair pump and repair rock washer auger as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG Da.,. ,Tr r, Irn_ ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Scott Heim Date: 12/12/2010 Time: 23:59 Current Depth (MD): 6377' Current Drilling ahead Current Depth (TVD): 3653' Operations: 24 hr Footage (MD): 636' Drilling Parameters ROP: Current: 153 Max: 431 Torque: Current: 3894 Max: 6896 WOB: Current 0 Max: 80 RPM: Current: 75 Max: 79 PP: Current: 187 Max: 3953 Lag: . Strokes: 4443 Time: 24 min Surf-Surf: Strokes: 5505 Time: 29 min ECD: Current: 9.95 Max: - Mud Properties @ 6377' MW: 9.1 FV: 69 PV: 14 YP: 19 FL: 6.0 Gels: 25/27/30 Sol: 6.59 pH: - Cr: 48000 Ca": MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 14 Max: 33 Depth (MD/TVD): 6166/3857 Avg BG : 18 Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 11 3200/2459 30 (Swab) 5974/3765 5709 15 Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 6166/3857 33 6456 18 Lithologies: Current: 80%siltstone, 20%claystone Last 24 hrs: 90%siltstone, 10%claystone Continue to repair mud pump. Drill ahead from 5741'to 5977'. Trouble shoot mud pump problem. Circulate bottoms up on one pump. Monitor the well. Pull out of Operational Summary: hole to the shoe. Cut and slip drill line. Lubricate the rig and inspect the top drive and draw works. Complete the repairs on mud pump. Run in hole to 5977'. Drill ahead to 6377' as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Scott Heim Date: 12/13/2010 Time: 23:59 Current Depth (MD): 7691' Current Drilling ahead Current Depth (TVD): 4580' Operations: 24 hr Footage (MD): 1314' Drilling Parameters ROP: Current: 242 Max: 778 Torque: Current: 6292 Max: 8140 WOB: Current 0 Max: 45 RPM: Current: 77 Max: 78 _PP: Current: 3985 Max: 3997 Lag: Strokes: 5361 Time: 30 min Surf-Surf: Strokes: 6655 Time: 37 min ECD: Current: 9.98 Max: - Mud Properties @ 7691' MW: 9.1 FV: 65 PV: 15 YP: 18 FL: 6.2 Gels: 24/25/25 Sol: 7.09 pH: - Cr: 48000 Ca': - MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 45u Max: 530u Depth (MD/TVD): Swab at 7585/4gas524' _Avg BG : 30u Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 50u 7597'/4530' Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases 14u (33 BG) 6934'/4217' 8507 154 34 3 Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 7585'/4524' 414u 81482 2076 539 37 80 2 4 7623'/4544' 108u 19286 532 169 12 29 7 6 Lithologies: Current: 50% claystone, 40%claystone, 10%sand Last 24 hrs: 70% claystone, 30%siltstone Drill ahead from 6377'to 6444'. Trouble shoot and repair pit room auger. Continue to drill ahead from 6444'to 7597'. A loss of pressure was observed, -500 psi. Operational Summary: Circulate bottoms up. Pull out of the hole looking for a wash out. Found the wash out 13 stands out. Lay down the joint. Run in hole. Drill ahead to 7691' as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Mark Brouillet Date: 12/14/2010 Time: 23:59 Current Depth (MD): 9166' Current Drilling ahead Current Depth (TVD): 5508' Operations: 24 hr Footage (MD): 1475' Drilling Parameters ROP: Current: 47 Max: 1055 Torque: Current: 10111 Max: 14047 WOB: Current 0 Max: 61 RPM: Current: 68 Max: 84 PP: Current: 3964 Max: 4123 Lag: Strokes: 6394 Time: 35 min Surf-Surf: Strokes: 7947 Time: 44 min ECD: Current: 9.85 Max: - Mud Properties @ 9166' MW: 9.2 FV: 56 PV: 17 YP: 14 FL: 5.8 Gels: 20/23/24 Sol: 7.51 pH: - Cr: 49000 Ca++: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 22u Max: 121u Depth (MD/TVD): 9043'/5428' Avg BG : 50u Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases 27u (49 BG) 9016'/5411' Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 9043'/5428' 121u 22228 1419 694 75 193 52 49 9094'/5461' 113u 20994 1244 667 79 205 55 62 8988'/5393' 107u 18618 1570 733 69 187 40 40 8978'/5386' 104u 18768 1386 591 66 155 38 51 Lithologies: Current: 40%claystone, 30%sandstone, 30%claystone Last 24 hrs: 40%claystone, 40%siltstone, 20%sandstone Continue drilling ahead from 7691'to 8880'without any issues. At 8880' began Operational Summary: controlled drilling at 50 ft/hr while going through the Bermuda. Drilled to 9166' as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,230.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Mark Brouillet Date: 12/15/2010 Time: 23:59 Current Depth (MD): 9352' Current Laying down BHA Current Depth (TVD): 5629' Operations: 24 hr Footage (MD): 186' Drilling Parameters ROP: Current: 0 Max: 321 Torque: Current: 0 Max: 13750 WOB: Current 0 Max: 43 RPM: Current: 0 Max: 78 PP: Current: 0 Max: 4113 Lag: Strokes: 6523 Time: 36 min Surf-Surf: Strokes: 8109 Time: 45 min ECD: Current: 9.78 Max: - Mud Properties @ 9352' MW: 9.1 FV: 51 PV: 18 YP: 14 FL: 5.8 Gels: 20/23/23 Sol: 7.51 pH: - CF: 48000 Ca.": MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data 9352'/5629' Ditch Gas: Current: Ou Max: 1214u Depth (MD/TVD): WG after wiper trip at TD Avg BG : 10u Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 1214 9352'/5629' 228287 16638 7002 667 1588 290 350 Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases 16u (18 BG) 9303'/5597' Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 9326'/5612' 62u 12278 409 186 18 67 35 43 Lithologies: Current: 70%siltstone, 30%claystone Last 24 hrs: 50%siltstone, 30%sandstone, 20%claystone Continue drilling ahead to TD at 9352'. Open well commander and circulate then monitor the well. Pull out of the hole to 7597'. Circulate with well commander open. Operational Summary: Run in hole to 9352'. Circulate with well commander open. Max gas was 1214u during circulation after running back to bottom. Pull out of the hole. Lay down the BHA as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Guy Whitlock Date: 12/16/2010 Time: 23:59 Current Depth (MD): 9352' Current RIH w/75/8"casing Current Depth (TVD): 5629' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 6523 Time: 36 min Surf-Surf: Strokes: 8109 Time: 45 min ECD: Current: - Max: - Mud Properties @ 9352' MW: 9.3 FV: 56 PV: 18 YP: 16 FL: 6.0 Gels: 20/23/24 Sol: 7.51 pH: - Cr: 48000 Ca++: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: Ou Depth (MD/TVD): Avg BG : Ou Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 70% siltstone, 30% claystone Last 24 hrs: Continue to lay down the BHA. Change upper rams to 7 5/8" and test. Rig up and Operational Summary: run in hole with 7 5/8"casing. Circulate at 3071'. Continue running in hole with casing to -4900' as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Guy Whitlock Date: 12/17/2010 Time: 23:59 Current Depth (MD): 9352' Current Lay down 7 5/8" casing Current Depth (TVD): 5629' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 6523 Time: 36 min Surf-Surf: Strokes: 8109 Time: 45 min ECD: Current: - Max: - Mud Properties @ 9352' MW: - FV: - PV: - YP: - FL: Gels: - Sol: - pH: - Cr: - Ca": MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Unable to Ditch Gas: Current: Ou Max: 243u Depth (MD/TVD): obtain depth of gas. Totco down. Avg BG : Ou Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 70% siltstone, 30%claystone Last 24 hrs: Continue to run in hole with 7 5/8"casing from 4732'to 5390'. Circulate and condition mud. Continue to run in hole from 5390' to 6906'. At 6906' observed Operational Summary: packing off. Continued to try to obtain circulation and to work pipe free. Decision made to lay down 7 5/8" casing. Laying down casing from 6906'to 5600' as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG Dn_.iv�Tn irv�n�,.n 1,1. ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Guy Whitlock Date: 12/18/2010 Time: 23:59 Current Depth (MD): 9352' Current Running in hole Current Depth (TVD): 5629' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 6523 Time: 36 min Surf-Surf: Strokes: 8109 Time: 45 min ECD: Current: - Max: - Mud Properties @ 9352' MW: - FV: - PV: - YP: - FL: Gels: - Sol: - pH: - CF: - Ca": MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: Ou Depth (MD/TVD): Avg BG : Ou Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Connection Depth (MDR-VD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 70% siltstone, 30%claystone Last 24 hrs: Continue to pull out of the hole with 7 5/8"casing and lay down in pipe shed. Operational Summary: Change and test top set of pipe rams for 5" pipe. Rig down test equipment and clean and clear the rig floor. Pick up and make up BHA. Begin running in hole with wiper BHA to 233'. Trouble shoot rod wash on mud pumps 1 and 2 as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Guy Whitlock Date: 12/19/2010 Time: 23:59 Current Depth (MD): 9352' Current Pumping out of hole Current Depth (TVD): 5629' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 6523 Time: 36 min Surf-Surf: Strokes: 8109 Time: 45 min ECD: Current: - Max: - Mud Properties @ 9352' MW: - FV: - PV: - YP: - FL: Gels: - Sol: - pH: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: 788u Depth (MD/TVD): 935275629' Avg BG : Ou Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 788u 9352'/5629' Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 70% siltstone, 30%claystone Last 24 hrs: Continue picking up BHA for cleaner run. Run in hole from 607' to 6445'. Wash Operational Summary: and ream down from 6445'to 7900'. Wash and ream down from 9130 to 9352'. Continue to wash and ream then circulate bottoms up at 9352'. Pump out of hole from 9352'to 4114' as of midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Guy Whitlock Date: 12/20/2010 Time: 23:59 Current Depth (MD): 9352' Current Backream out of hole Current Depth (TVD): 5629' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: N/A Max: N/A Torque: Current: N/A Max: N/A WOB: Current N/A Max: N/A RPM: Current: N/A Max: N/A PP: Current: N/A Max: N/A Lag: Strokes: 6523 Time: 36 min Surf-Surf: Strokes: 8109 Time: 45 min ECD: Current: - Max: - Mud Properties @ 9352' MW: 9.1 FV: 57 PV: 16 YP: 15 FL: 5.6 Gels: 8/19/24 Sol: 9 pH: NR CI-: 60000 Ca++: 2.86 (lime) MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: 53u Depth (MD/TVD): 9352'/5629' Avg BG : Ou Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 52u 9352'/5629' - - - - - - - Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases N/A Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 N/A Lithologies: Current: 70%siltstone, 30%claystone Last 24 hrs: N/A Continue backreaming out of hole from 4114'to 3068'; open well commander—hole unloading cuttings;flow check well—well static;service rig—blow down top drive, grease drawworks and crown sheave;circulate bottoms-up; run in hole from 3068'to 4017',then backream out of hole to 3353'—well packing off at 3817';circulate bottoms- Operational Summary: up; pull out of hole from 3353'—pulled tight at 2510'; break free, work pipe, and ream down to 2600';work drill string down to shoe at 3070', and flow check well—well static; wash down hole to bottom at 9352';circulate hole clean, and flow check well—well static;pull out of hole from 9352'to 8370', pump dry job, and continue to pull out of hole. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Guy Whitlock Date: 12/21/2010 Time: 23:59 Current Depth (MD): 9352' Current RIH Casing Current Depth (TVD): 5629' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: N/A Max: N/A Torque: Current: N/A Max: N/A WOB: Current N/A Max: N/A RPM: Current: N/A Max: N/A PP: Current: N/A Max: N/A Lag: Strokes: 6523 Time: 36 min Surf-Surf: Strokes: 8109 Time: 45 min ECD: Current: - Max: - Mud Properties @ 9352' MW: 9.1 FV: 59 PV: 22 YP: 13 FL: 5.6 Gels: 15/23/29 Sol: 8.3 pH: NR Cr: 62000 Ca": 2. 6 (lime) MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 6u Max: 331 u Depth (MD/TVD): 9352'/5629' Avg BG : Ou Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 1 iC5 nC5 331u 9352'/5629' - - - - - - Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases N/A Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 N/A Lithologies: Current: 70%siltstone, 30%claystone Last 24 hrs: N/A Operational Summary: Pulled out of hole. Laid down BHA. Changed and tested rams. Run in hole with 7 5/8" casing. Circulate bottoms up at shoe. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Guy Whitlock Date: 12/22/2010 Time: 2:00 Current Depth (MD): 9352' Current Testing rams Current Depth (TVD): 5629' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: N/A Max: N/A Torque: Current: N/A Max: N/A WOB: Current N/A Max: N/A RPM: Current: N/A Max: N/A PP: Current: N/A Max: N/A Lag: Strokes: 6523 Time: 36 min Surf-Surf: Strokes: 8109 Time: 45 min ECD: Current: - Max: - Mud Properties @ 9352' MW: 8.5 FV: - PV: - YP: - FL: Gels: - Sol: - pH: NR Cr: 15000 Ca++: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: 458u Depth (MDITVD): 9352'/5629' Avg BG : Ou Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 N/A 9352'/5629' - - - - - - Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases N/A Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 N/A Lithologies: Current: 70% siltstone, 30%claystone Last 24 hrs: N/A Pumped bottoms up to prep for cement @ 7,227' and looked good. Pumped cement Operational Summary: job, no cement to surface and did not bump plug. Rig down cement tools, change and test BOP rams. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG m 0 3 0 r 0 ca 0
