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HomeMy WebLinkAbout210-166New Plugback Esets 6/26/2024 Well Name API Number PTD Number ESet Number Date 2L-320 PB1 50-103-20627-70-00 210-166 T39025 3-8-2011 2L-320 PB2 50-103-20627-71-00 210-166 T39026 3-8-2011 CD4-23 PB1 50-103-20621-70-00 210-067 T39027 8-30-2010 CD4-23 PB2 50-103-20621-71-00 210-067 T39028 8-30-2010 ODSK-13 PB1 50-703-20607-70-00 209-146 T39029 11-18-2011 ODSK-13 PB2 50-703-20607-71-00 209-146 T39030 11-18-2011 ODSK-14 PB1 50-703-20610-70-00 209-155 T39031 3-24-2010 ODSK-14 PB2 50-703-20610-71-00 209-155 T39032 3-24-2010 OP05-06 PB1 50-029-23427-70-00 210-080 T39033 10-28-2010 OP05-06 PB2 50-029-23427-71-00 210-080 T39034 10-28-2010 P2-22A PB1 50-029-22850-71-00 209-161 T39035 6-4-2010 P2-22A PB2 50-029-22850-72-00 209-161 T39036 6-4-2010 S-129 PB1 50-029-23433-70-00 210-132 T39037 5-12-2011 S-129 PB2 50-029-23433-71-00 210-132 T39038 5-12-2011 W-219 PB1 50-029-23429-70-00 210-105 T39039 1-27-2011 W-219 PB2 50-029-23429-71-00 210-105 T39040 1-27-2011 W-220 PB1 50-029-23432-70-00 210-126 T39041 3-27-2013 W-220 PB2 50-029-23432-71-00 210-126 T39042 3-27-2013 2L-320 PB1 50-103-20627-70-00 210-166 T39025 3-8-2011 2L-320 PB2 50-103-20627-71-00 210-166 T39026 3-8-2011 PrP a 10-/64 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Thursday, January 30, 2020 10:03 AM To: Well Integrity Compliance Specialist CPF1 & 2 Cc: Regg, James B (CED) Subject: Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) OA SCP Dusty, Approval is granted for an increase of OA not to exceed pressure to 1800 psi for the purpose of evaluating the nature of pressurization for an undefined period. Once the evaluation is complete, an update will be sent to the AOGCC addressing mitigation or further evaluation. Please ensure that an internal waiver has been posted at the well. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCo)alaska.cov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or VIctorla.LOeaDQalaska aov From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Wednesday, January 29, 2020 4:23 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL)RE: Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) Victoria - Due to the slow nature of the pressure build up, CPAI is anticipating a longer-term pressure build up period to reach stabilization than the approved 2 -week period. Currently 2L-314 and 2L -320s OAs are in the following conditions; 2L-314 ■ OA pressure is currently 822 psi. • OA fluid level was 1020' as of 10 Jan 20 • Pumped 100 bbls of diesel into OA on 17 December 2019. • Average buildup rate of approximately 4 psi/day since July of 2019. ■ With the current OA pressure and build up rate the OA will not reach the ONE of 1000 psi for at least 44 days. 2L-320 • OA pressure is currently 855 psi • OA fluid level was 1368' on 27 Jan 20 ■ Pumped 100 bbls of diesel into OA on 2 Jan 2019. • Average buildup rate of approximately 1 psi/day since August of 2019. • With the current OA pressure and build up rate the OA will not reach the DNE of 1000 psi for at least 145 days. To fully understand the capability of the charging source, CPAI would like to request an undefined time period to allow pressure stabilization up to 1800 psi. The request for the undefined pressure stabilization time period is based on the fact that CPAI does not have the data to estimate the stabilization point, nor the time it will take to reach. Once stabilization is established CPAI will allow the OA pressure to remain at the stabilization point for no more than 2 weeks for data collection purposes. At that point in time the AOGCC will be notified with the plan for mitigation or further evaluation. Please feel free to call to discuss if you need further details of the plans. Thank you. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 ELLS TEAM WM conocoVMOlps From: Loepp, Victoria T (CED) <victoria.foe pp@alaska.gov> Sent: Tuesday, January 28, 2020 2:04 PM To: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: [EXTERNAL]RE: Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) Dusty, Approval is granted for an increase of OA not to exceed pressure to 1800 psi for the purpose of evaluating the nature of pressurization for a period of two weeks. Once the evaluation is complete, an update will be sent to the AOGCC addressing mitigation or further evaluation. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp()alaska. oov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria LoeaD@alaska gov From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, January 25, 2020 5:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska. > Cc: CPA Wells Supt <n1030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocoph11l]ps.com> Subject: Tarn gas lifted producers 2L-314 (PTD #214-023) and 21--320 (PTD #210-166) Jim & Victoria, Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) are exhibiting an increase in OA pressure and fluid level fall out. CPA[ has managed these wells by occasionally loading the OA with liquids to maintain the OA pressure within Conservation Order 494 Rule 3(b). The initial OA gas sampling does not indicate the presence of lift gas or injection gases. However, a more extensive gas sample evaluation is in progress on 2L-314. CPA] is seeking permission to allow the outer annuli to exceed the Conservation Order 494 Rule 3(b) of 1000 psi to identify the stabilization point up to 1800 psi and better understand the nature of pressurization. Both wells are equipped with 10 %" 45.5 Ib L-80 surface casing which has a burst rating of 5210 psi. Once the evaluation of the re -pressurization has been completed, an update will be sent to inform the AOGCC of CPAI's next step toward mitigation or further evaluation. Attached are copies of the current 90 -day TIO trends and well bore schematics. Dusty Freebom/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM CMOCK; hmiips P TP 2 d o—( 41(y, Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Tuesday, January 28, 2020 2:04 PM To: Well Integrity Compliance Specialist CPF1 & 2 Cc: Regg, James B (CED) Subject: RE: Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) Follow Up Flag: Follow up Flag Status: Flagged Dusty, Approval is granted for an increase of OA not to exceed pressure to 1800 psi for the purpose of evaluating the nature of pressurization for a period of two weeks. Once the evaluation is complete, an update will be sent to the AOGCC addressing mitigation or further evaluation. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loeog o)alaska.gov CONFIDENTIAUTI' NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907) 79 3-1 247 or Victoda.Loeipp@alaska.gov From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, January 25, 2020 5:23 PM To: Regg, lames B (CED) <jim.regg@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n 1617@conocophi I I ips.com> Subject: Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) Jim & Victoria, Tarn gas lifted producers 2L-314 (PTD #214-023) and 2L-320 (PTD #210-166) are exhibiting an increase in OA pressure and fluid level fall out. CPAI has managed these wells by occasionally loading the OA with liquids to maintain the OA pressure within Conservation Order 494 Rule 3(b). The initial OA gas sampling does not indicate the presence of lift gas or injection gases. However, a more extensive gas sample evaluation is in progress on 2L-314. CPAI is seeking permission to allow the outer annuli to exceed the Conservation Order 494 Rule 3(b) of 1000 psi to identify the stabilization point up to 1800 psi and better understand the nature of pressurization. Both wells are equipped with 10 %" 45.5 Ib L-80 surface casing which has a burst rating of 5210 psi. Once the evaluation of the re -pressurization has been completed, an update will be sent to inform the AOGCC of CPAI's next step toward mitigation or further evaluation. Attached are copies of the current 90 -day TIO trends and well bore schematics. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. 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Lco G 0 J • • 'J d• 0 0 OOO O CM OO 0 O CO O CO O O CO CO O O CO O O O CO a 2 ,W J J J J J J J J J J J J J J J J J J J J J J J J W O '1 1 9o 9 /'( N CO 0 z N r) U O 5 o I N 6 z ? tO az C I m E y aco I . < v) 0 1 0 Li < p2 U 1 0 a 5 " „ a z z co 3C)W = u) z 1 OC o � U v W z °' J U U 0 d N m Zy Q co O Z' 1- o m 7 O II ° •C' 't •i 1 O co C 7 CL N d c O 5 rg y D li O N N E O O o U J N M Q N I Z O. II " cco F u) N II Tr • N r COW co C I V/ Q p N Q a Y o I • cu— 4:C ciz O 76 0 E 1 i i z m 1I 3 co c 1 N. o in g z p .. E O 1 liCS>- t r l' r co F— C Hce ., N d O I!1, ,, m G y Z c, E E o 14 Z Z U P C V O O O w a) I d to �j f- 0 .> i E I a 0 0 a m y E E a Q > 0 < 0 0 401 • • ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 15,2012 Commissioner Dan Seamount Alaska Oil& Gas Commission a,10 ' 333 West 7th Avenue, Suite 100 D Anchorage,AK 99501 l'-. 3 O Commissioner Dan Seamount: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU),and the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor,engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped in the spring of 2012. The corrosion inhibitor/sealant was pumped in the months of April and May 2012. The attached spreadsheet presents the well name,top of cement depth prior to filling,and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043,if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor NO • 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 API# 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 11-(J( ZL -3u prb Z10/66,0 Regg, James B (DOA) From: Regg, James B (DOA) ee 4-+7,31(z✓ Sent: Monday, April 23, 2012 8:45 AM To: 'NSK Problem Well Supv' Subject: RE: 2L-320 (PTD 2101660) report of OA SCP (4-21-12) Proceed as planned. When pressures have stabilized, please update and provide results of gas analysis and decision to write an internal waiver or proceed with repairs. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-7934236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Saturday, April 21, 2012 7:01 PM To: Regg, James B (DOA) Subject: 2L-320 (PTD 2101660) report of OA SCP (4-21-12) Jim, Tarn gas lifted producer 2L-320 (PTD 2101660) has SCP on the OA which is suspected to be from formation due to an open shoe. The current TIO is 238/795/1003. The OA has been slowly building over several months. It appears the well is being charged from the formation based on the IA maintaining a differential pressure below that of the OA for the last several weeks (as can be seen in the attached 90 day plot) and an inability to bleed the OA down. An IC-POT also — passed testing on 11/25/11. ConocoPhillips requests the well be allowed to remain on line, allowing the OA pressure to climb until stabilized. Since the build up rate is quite slow, it is undetermined how long it will take to reach the stabilization period. The stabilization pressure will determine whether the well can be internally waivered or if alternate methods of repair need to be taken, such as attempting to pump a cement shoe. In the meantime, gas samples will be obtained to help better identify the source of pressure. The well was constructed with 10-3/4"45.5# L-80 grade surface casing with an internal yield pressure of 5210 psi. And the 7-5/8" 29.7# L-80 grade production casing has a collapse pressure of 4790 psi. Attached are the schematic and 90 day TIO plot. 'v A monthly update on the well can be provided if you would like while we assess the well's condition. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons Problem Wells Supervisor 451,,,L k - i 0 )4." L-( = 2344p,' , ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 5/ k Pager(907)659-7000 pgr 909 Z 344 psi is t OF 7 B 1-66) et os:� OLL ---4.3 l i.. GL.leek oyk. t rr e A-0 Acker-A(4 f to a. 5 ,L i(i ie- . 1 0 0 0 0 Sap m v ni 0 0 0 0 0 r r CO CD e} N 0 I I I I I I G ri N � L J CA a c o2 aom _ aa Q Q III I i a , I N N N .'t CID M3 f/3 "47. a> R C? u 3 o a o C. v U L ii; ag d _a Z a (Ni N O 'r NO O — c N S'`:I S•1 r j' 111\ Jf N N r ▪ 4. 41 0 0 0 0 0 d 0 0 0 0 0 ' o M. .F. M 0 CO0�6 [�D 0 000 COCNN v, o Z G Q N 04118.(1A314 O Id 3 � oW KUP 2L-320 COttt?COPllll1p5 ifi, p Weal Attributes Max Angle&MD TD • AIBSkB IncWellbore API/UWI Field Name Well Status Inst(°) MD(ftKB) Act Btm(ftKB) ,..„,,,,„,p, ,' 501032062700 TARN PARTICIPATING AREA PROD 15,049.0 Comment 825(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date •••Well Confi9:HORIZONTAL.2L320.71/7/10118:58:04 AM SSSV:NIPPLE Last WO: 2/26/2011 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod..,End Date . ux q ua r , < x°.....- Last Tag:SLM 14242.0 9/21/2011 Rev Reason:PULL PLUG ninam 11/7/2011 Ill • Casing Strings HANGER.36 , Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD).. String Wt...String.. String Top Thrd ill ( ,��,-' ) CONDUCTOR 16 14.969 41.9 100.0 100.0 164.00 1.03 WELDED 1 "r--t'• 1 Casing Description String 0... String ID...Top(ftKB) Set Depth(f,..Set Depth(TVD)...String Wt...String...String Top Thrd - - '' SURFACE _ 10 3/4 9.794 41.9 2,745.6 2,375.5 45.50 L-80 BTC t $2-1°/' , / z-4 7o ' Casing Description String 0... String ID.,Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd ; PRODUCTION7 5/8 6.875 38.7 15,027.0 5,771.6 29.70 L 80 BTCM (2t3o/Dom:/ 4 7710 , Tubing Strings Tubing Description String 0... String ID..,Top(500) Set Depth(f...Set Depth(TVD)...String Wt.. String...String Top Thrd CONDUCTOR. TUBING 3 1/2 2.992 36.5 14,120.4 5,453.1 9.30 L-80 EUE 8RD 42-100 Completion Details I i Top Depth 1 NIPPLE,492 v` (TVD) Top Incl Komi... Top(ftKB) (ftKB) (•) Item Description Comment ID(in) 36.5 36.5 -0.02 HANGER FMC HANGER w/PUP JT 3.500 ilk 492.2 492.1' 2.30 NIPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 : 13,957.7 5,405.5 72.59 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.813"DS PROFILE(CLOSED) 2.812 GAS Z e, i ,;-- 14,005.2' 5,419.7' 72.82 PBR PBR 8 LOCATOR 2.990 (i 14,028.5 5,426.6 72.93 PACKER BAKER FHL PACKER 3.000 _. 14,077.0 5,440.7 73.18 NIPPLE CAMCO D NIPPLE w/2.875"PROFILE 2.750 14,119.5 5,452.9 73.60 SOS SOLID SEAT SHEAR OUT SUB ' 2.970 Perforations&Slots Shot Top(TVD) Btm(TVD) Dem Top(ftKB) Btm(MB) (BBB) (11KB) Zone Date (•h-•• Type Comment 14,390 14,405 5,534.8 5,540.0 3/22/2011 6.0 IPERF 2.5"PROSPECTOR RDX SURFACE, CHARGES,6 SPF,60 DEG 42-2746 PHASING. lir 14,420 14,435 5,545.2 5,550.0 3/24/2011 6.0 IPERF 2.5"PROSPECTOR RDX CHARGES.6 SPF,60 DEG GAS LIFT, 3,072 it PHASING. AI Stimulations&Treatments aim Bottom Min Top Mao Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 14,390.0 14,435.0 5,534.8 5,550.0 FRAC 5/15/2011 TARN FRAC-pumped 242,271#of 16/20 Carbolite, 210,305#behind pipe;9 ppa on formation;85%of design. I , GAS LIFT, 2ft -_' 7.975 GAS LIFT. e: 11,877 it , GAS LIFT. 13,750 1 Ili CHEMICAL, (.--- 136)40 lir a SLEEVE-C, 13,958 111 it it PBR.14.005 } PACKER. liGimmammiTill 14,029 NIPPLE,14,077 `. Mandrel Details Top Depth Top Port GAS LIFT, (TVD) Incl OD Valve Latch Size TRO Run 14,094 Stn Top(ftKB) (ftKB) C) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,481.2 2,250.7 56.26 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/15/2011 SOS,14,120 f(:' 2 3,072.0 2,490.2 72.19 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/28/2011 3 7,975.0 3,793.5 73.94 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/28/2011 IPERF, , 4 11,877.2 4,830.9 73.92 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/28/2011 11,39414,405 r „i FRAC,14,390 5 13,750.4 5,341.7 71.76 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 6/29/2011 IPERF, M 6 13,840.4 5,369.7 71.70 CAMCO KBMG 1 CHEM DMY BK 0.000 0.0 1/28/2011 14,420.14,435 7 14,094.4 5,445.7 73.31 CAMCO MMG RG-2 1 1/2 GAS LIFT CV RKP 0.000 0.0 1/28/2011 PRODUCTION, 39-15.027 15,019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ - Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ El WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: March 24,2011 ' 210-166/ 3.Address: 6.Date Spudded: 13.API Number: 50-103-20627-00, P.O.Box 100360,Anchorage,AK 99510-0360 December 31,2010 50-103-20627-70,50-103-20627-71 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 202'FNL,792'FEL,Sec.22,T1ON,R7E,UM February 18,2011 2L-320,2L-320PB1,2L-320PB2 Top of Productive Horizon: 8. KB(ft above MSL): 41'RKB 15.Field/Pool(s): 225'FSL,623'FEL,Sec.24,T1ON, R7E, UM GL(ft above MSL): 114'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 556'FNL, 166'FEL,Sec.25,T1ON,R7E,UM 15027'MD/5772'TVD Tarn Oil Pool ' ' • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total De +TVD): 16.Property Designation: Surface: x-460859 y- 5927644 Zone-4 , 15049'11 /5780'ND• ADL 380052,-380051,380053 TPI: x-471569 y- 5922744 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-472022 y- 5921962 Zone-4 nipple @ 492'MD/492'ND 4600,4599,4601 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) 1213'MD/1195'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 MDTIVD 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. 100' Surf. 100' 24" driven 10.75" 45.5# L-80 Surf. 2745' Surf. 2376' 13.5" 992 sx Class G,296 sx Class G 7.625" 29.7# L-80 Surf. 15027' Surf. 5772' 9.875" 735 sx Class G GasBLOK 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" 14120' 14028'MD/5427'ND 14390'-14405'MD 5535'-5540'ND 6 spf✓ 14420'-14435'MD 5545'-5551'ND 6 spf r/ +""1�rJ�� tl:- ii 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ei.34144 1 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED iF 7566-7966' 331 sx Class G ga- l6879'-7366' 331 sx Class G : .., i 3100'-3600' 516 sx Class G 2500'-3100' 439 sx Class G 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 ❑✓ Sidewall Cores Acquired? Yes ❑ No a 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. RECEIVED' NONE :.1 ?Oil RBDMS APR 0 8 2011 kaskh Jit a Fags Cana. Form 10-407 Revised 12/2009 CONTINUED ON REVERSE k, mit original only . [t 71� / n2o o J i;iN:�fil8� (s 6 28. GEOLOGIC MARKERS(List all formations and markers a tered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1213' 1195' needed,and submit detailed test information per 20 AAC 25.071. C-37 10518' 4467' Top Bermuda 14172.5' 5468' Base Bermuda 14610.8' 5616' C-35 14876.1' 5715' 2L-320PB1 Total Depth 11446' 4520' N/A 2L-320PB2 Total Depth 11247' 4438' 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: David Nugent @ 263-4228 Printed Name G.C.Alvord Title: Alaska Drilling Manager Signature /tai t�V"r� Phone 263-4619 Date 4(6(20 UU v 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 KUP 2L-320 Concio3PhUhps .,t> Well Attributes Max Angle&MD TD 01 Wellbore APUUWI 'Field Name (Well Status Inc!CI IMD OMB) Act Btm(0KB) 501032062700 'Field PARTICIPATING AREA EXPEND 15,049.0 �Ikp;' --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Gonfig H9RIZONTAL 24320,3/100011 10,51 22 AM SSSV:NIPPLE , I Last WO: 2/26/2011 Date Actual Annotation Depth(8KB) End Date Annotation Last Mod. E d Date Last Tag: J L_ I Rev Reason: NEW WELL I ninam I 3/8/2010 `"1 Casing Strings HANGER,36 '� -*:i:. Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 14.969 41.9 100.0 100.0 164.00 1.03 WELDED Casing Description String 0... String ID...Top(ftKB) Se Depth(L..Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 10 3/4 9.794 41.9 2,745.6 2,375.5 45.50 L-80 BTC j ---- -- ---- !' Casing Description String0... String ID...Top Set Depth(f...SM String Wt...String Shing Top Thrd 9 Depth(TVD)... g g... PRODUCTION 7 5/8 6 875 38.7 15,027.0 5,771.6 29.70 L-80 BTCM Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f..Set Depth(TVD)..String Wt.. String...String Top ThM CONDUCTOR, TUBING I 31/2 1 2992 I 36.5 I 14,1204 I 5,453.1 9.30 L-80 EUE 800 42-100 11 Completion Details Top Depth I (TVD) Top Incl Nomi... NIPPLE,492 Toy(ftK6� ( B) (') Item Description Comment ID(in) 36.5 36.5 -0.02 HANGER FMC Hanger w/pup jt Hanger=.75',Pup=2.65 3.500 492.2 492.1 2.30 NIPPLE Cameo"DS"Nipple with 2.875"Profile 2.875 13,957.7 5,405.5 72.59 SLEEVE Baker CMU sliding sleeve w/2.813 DS profile 2.812 14,005.2 5,419.7 72.82 PBR PER and Locater(22.88+ 32) 2.990 GAS LIFT, }?.. 2,481 - 14,028.5 5,426.6 72.93 PACKER Baker FHL Pkr 3 1/2"x 7 5/8" 3.000 14,077.0 5,440.7 73-18 NIPPLE Camco"D"Nipple with 2.75"Profile wl RHC plug 2.750 14,119.5 5,452.9 73.60 SOS Solid Seat Shear out Sub 2.970 I SURFACE,_ 42-2,748 GAS LIFT, 3,072 GAS LIFT, 7,975 GAS LIFT,----. 11,877 w GAS LIFT, -_-. .:_ 13,750 i: lig CHEMICAL, 13.840 I ar SLE3,EVE, Illf _ - - 1956 PBR,14,005--. -- 1 PACKER, _-L- 14,029 .MfndteiDetails __--_--- Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run rSin Top(111(8) (SKIM r) Make Model (in)_ Sera Type TY'. (In) (pa0 Run Date Con._ 1 2,481.2 2,250.7 56.26 CAMCO KBMG 1 GAS LIFT SOV BK-5 0.000 0.0 128)2011 14077NIPPLE,ta -..- _ -2-,490.2 2 3,072.0 2,490.2 72.19 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/28/2011 GAS LIFT, 3 7,975.0 3,793.5 73.94 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/28/2011 1g094 4 11,8772 4,830.9 73.92 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/28/2011 5 13,750.4 5,341.7 71.76 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 128/2011 SOS,14,120 -_-.. -IF - 6 13,840.4 5,369.7 71.70 CAMCO KBMG 1 CHEM SOV BEK 0.000 0.0 12812011 7 14,094.4 5,445.7 73.31 CAMCO MMG RG-2 1 1/2 GAS LIFT CV RKP 0.000 0.0 1/28/2011 1 PRODUCTION, 72(921L-12%-\ 15,049 0 P • NY�r & A r ConocoPhilli s(Alaska) Inc. Kuparuk River Unit I 07 Kuparuk 2L Pad 2L-320 • 0 501032062700 g P' A M to 14 Sperry Drilling PA Definitive Survey Report 05 April, 2011 '31 kg gi I t 44 I • `"' 1. • HALLIBURTON amssoiminamingimummommimummummum Sperry Drilling conocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit ND Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad MD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320 Survey Calculation Method: Minimum Curvature Design: 2L-320 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-320 Well Position +N/-S 0.00 ft Northing: 5,927,644.53 ft Latitude: 70° 12'47.763 N +E/-W 0.00 ft Easting: 460,858.89 ft Longitude: 150°18'56.399 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.90ft Wellbore 2L-320 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 2/2/2011 20.96 80.75 57,602 Design 2L-320 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,706.47 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 40.95 0.00 0.00 115.66 i Survey Program Date 11 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,483.00 2L-320 Gyro(2L-320PB1) CB-GYRO-SS Camera based gyro single shot 12/31/2010 12. 1,526.44 2,706.47 2L-320 MWD(R100)(2L-320PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/1/2011 12:0C 2,746.00 9,022.43 2L-320(R600)(2L-320) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2011 12:0C 9,119.44 11,588.96 2L-320(R700)(2L-320) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/10/2011 12:C 11,677.13 14,999.37 2L-320(R800)(2L-320) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/15/2011 12:C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section r (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) 0001 (ft) Survey Tool Name 40.95 0.00 0.00 40.95 -114.90 0.00 0.00 5,927,644.53 460,858.89 0.00 0.00 UNDEFINED 100.00 0.33 84.28 100.00 -55.85 0.02 0.17 5,927,644.55 460,859.06 0.56 0.15 CB-GYRO-SS(1) 165.00 1.15 107.76 164.99 9.14 -0.16 0.98 5,927,644.37 460,859.87 1.32 0.95 CB-GYRO-SS(1) 254.00 1.32 121.22 253.97 98.12 -0.97 2.70 5,927,643.55 460,861.59 0.38 2.86 CB-GYRO-SS(1) 351.00 1.62 121.02 350.94 195.09 -2.25 4.83 5,927,642.26 460,863.72 0.31 5.33 CB-GYRO-SS(1) 440.00 2.18 111.76 439.89 284.04 -3.53 7.48 5,927,640.97 460,866.36 0.72 8.27 C8-GYRO-SS(1) 535.00 2.59 108.96 534.81 378.96 -4.90 11.19 5,927,639.58 460,870.06 0.45 12.21 CB-GYRO-SS(1) 627.00 3.22 118.88 626.69 470.84 -6.82 15.42 5,927,637.64 460,874.28 0.87 16.85 CB-GYRO-SS(1) 724.00 4.73 124.16 723.46 567.61 -10.38 21.12 5,927,634.04 460,879.95 1.60 23.53 CB-GYRO-SS(1) 819.00 8.46 127.81 817.81 661.96 -16.87 29.88 5,927,627.51 460,888.69 3.95 34.24 CB-GYRO-SS(1) 4/5/2011 12:53:42PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit 1 VD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad MD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320 Survey Calculation Method: Minimum Curvature Design: 2L-320 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S ±E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 915.00 14.69 132.07 911.81 755.96 -29.3,, 44.51 5,927,614.94 460,903.25 6.55 52.84 CB-GYRO-SS(1) 960.00 15.36 131.75 955.28 799.43 -37.16 53.19 5,927,607.11 460,911.89 1.50 64.04 CB-GYRO-SS(1) 1,007.00 14.59 132.53 1,000.68 844.83 -45.30 62.20 5,927,598.91 460,920.85 1.69 75.68 CB-GYRO-SS(1) t 1,102.00 13.97 129.16 1,092.74 936.89 -60.63 79.91 5,927,583.49 460,938.48 1.09 98.28 CB-GYRO-SS(1) 1,197.00 13.71 129.77 1,184.99 1,029.14 -75.08 97.45 5,927,568.96 460,955.95 0.31 120.35 CB-GYRO-SS(1) 1,292.00 14.90 126.21 1,277.04 1,121.19 -89.49 115.96 5,927,554.45 460,974.38 1.56 143.28 CB-GYRO-SS(1) 1,388.00 17.10 121.82 1,369.32 1,213.47 -104.23 137.92 5,927,539.60 460,996.26 2.61 169.45 CB-GYRO-SS(1) 1,483.00 18.33 123.05 1,459.81 1,303.96 -119.74 162.31 5,927,523.97 461,020.56 1.35 198.15 CB-GYRO-SS(1) 1,526.44 18.21 120.12 1,501.06 1,345.21 -126.87 173.90 5,927,516.77 461,032.12 2.13 211.69 MWD+IFR-AK-CAZ-SC(2) 1,625.40 21.61 121.51 1,594.10 1,438.25 -144.16 202.82 5,927,499.34 461,060.95 3.47 245.25 MWD+IFR-AK-CAZ-SC(2) 1,724.63 26.65 120.77 1,684.63 1,528.78 -165.11 237.55 5,927,478.21 461,095.56 5.09 285.62 MWD+IFR-AK-CAZ-SC(2) 1,821.04 32.12 120.40 1,768.60 1,612.75 -189.16 278.26 5,927,453.95 461,136.14 5.68 332.73 MWD+IFR-AK-CAZ-SC(2) 1,865.48 33.22 121.66 1,806.01 1,650.16 -201.53 298.81 5,927,441.48 461,156.63 2.91 356.61 MWD+IFR-AK-CAZ-SC(2) 1,915.34 34.45 122.10 1,847.43 1,691.58 -216.19 322.39 5,927,426.70 461,180.12 2.52 384.21 MWD+IFR-AK-CAZ-SC(2) 2,009.93 37.07 124.24 1,924.18 1,768.33 -246.46 368.63 5,927,396.20 461,226.20 3.07 439.00 MWD+IFR-AK-CAZ-SC(2) 2,104.95 39.99 122.44 1,998.51 1,842.66 -278.96 418.08 5,927,363.44 461,275.49 3.29 497.65 MWD+IFR-AK-CAZ-SC(2) I I 2,198.85 43.73 120.23 2,068.43 1,912.58 -311.49 471.61 5,927,330.63 461,328.84 4.28 559.99 MWD+IFR-AK-CAZ-SC(2) 2,292.79 49.05 118.82 2,133.21 1,977.36 -344.97 530.79 5,927,296.85 461,387.84 5.77 627.82 MWD+IFR-AK-CAZ-SC(2) 2,336.84 49.65 118.67 2,161.90 2,006.05 -361.04 560.09 5,927,280.63 461,417.05 1.39 661.20 MWD+IFR-AK-CAZ-SC(2) 2,387.60 50.51 119.09 2,194.47 2,038.62 -379.84 594.18 5,927,261.65 461,451.04 1.81 700.06 MWD+IFR-AK-CAZ-SC(2) 2,432.85 52.56 118.18 2,222.62 2,066.77 -396.82 625.28 5,927,244.52 461,482.04 4.80 735.44 MWD+IFR-AK-CAZ-SC(2) 2,483.66 56.45 118.10 2,252.12 2,096.27 -416.32 661.75 5,927,224.83 461,518.41 7.66 776.77 MWD+IFR-AK-CAZ-SC(2) 2,530.68 58.11 117.70 2,277.53 2,121.68 -434.83 696.71 5,927,206.14 461,553.27 3.60 816.29 MWD+IFR-AK-CAZ-SC(2) 2,575.11 59.23 117.16 2,300.63 2,144.78 -452.31 730.39 5,927,188.49 461,586.86 2.73 854.23 MWD+IFR-AK-CAZ-SC(2) 2,665.45 64.61 115.86 2,343.14 2,187.29 -487.86 801.70 5,927,152.58 461,657.98 6.09 933.89 MWD+IFR-AK-CAZ-SC(2) 2,706.47 66.33 114.91 2,360.17 2,204.32 -503.85 835.41 5,927,136.41 461,691.60 4.69 971.21 MWD+IFR-AK-CAZ-SC(2) 2,746.00 67.53 115.85 2,375.66 2,219.81 -519.44 868.27 5,927,120.65 461,724.37 3.74 1,007.57 MWD+IFR-AK-CAZ-SC(3) 2,782.07 67.65 116.26 2,389.41 2,233.56 -534.09 898.23 5,927,105.85 461,754.25 1.10 1,040.92 MWD+IFR-AK-CAZ-SC(3) 2,876.40 69.24 116.63 2,424.07 2,268.22 -573.16 976.78 5,927,066.38 461,832.59 1.72 1,128.64 MWD+IFR-AK-CAZ-SC(3) 2,966.96 69.46 116.76 2,456.01 2,300.16 -611.23 1,052.49 5,927,027.92 461,908.09 0.28 1,213.37 MWD+IFR-AK-CAZ-SC(3) 3,066.90 71.66 117.82 2,489.27 2,333.42 -654.44 1,136.23 5,926,984.28 461,991.60 2.42 1,307.57 MWD+IFR-AK-CAZ-SC(3) 3,160.02 73.45 117.68 2,517.18 2,361.33 -695.80 1,214.85 5,926,942.51 462,070.00 1.93 1,396.34 MWD+IFR-AK-CAZ-SC(3) 3,255.54 74.82 116.51 2,543.29 2,387.44 -737.64 1,296.64 5,926,900.25 462,151.57 1.86 1,488.19 MWD+IFR-AK-CAZ-SC(3) 3,347.46 74.62 116.92 2,567.52 2,411.67 -777.51 1,375.85 5,926,859.98 462,230.56 0.48 1,576.84 MWD+IFR-AK-CAZ-SC(3) 3,439.93 75.01 116.93 2,591.74 2,435.89 -817.92 1,455.41 5,926,819.16 462,309.91 0.42 1,666.06 MWD+IFR-AK-CAZ-SC(3) 3,538.95 74.64 117.23 2,617.66 2,461.81 -861.42 1,540.50 5,926,775.22 462,394.76 0.47 1,761.60 MWD+IFR-AK-CAZ-SC(3) . 3,633.61 74.18 117.35 2,643.10 2,487.25 -903.23 1,621.53 5,926,733.00 462,475.56 0.50 1,852.74 MWD+IFR-AK-CAZ-SC(3) 3,729.70 74.55 117.31 2,669.00 2,513.15 -945.71 1,703.74 5,926,690.10 462,557.54 0.39 1,945.24 MWD+IFR-AK-CAZ-SC(3) 3,818.10 73.71 116.82 2,693.17 2,537.32 -984.40 1,779.46 5,926,651.02 462,633.05 1.09 2,030.24 MWD+IFR-AK-CAZ-SC(3) 3,916.63 73.86 116.73 2,720.68 2,564.83 -1,027.02 1,863.92 5,926,607.97 462,717.29 0.18 2,124.83 MWD+IFR-AK-CAZ-SC(3) 4/5/2011 12:53:42PM Page 3 COMPASS 2003.16 Build 69 LonocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit TVD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad MD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320 Survey Calculation Method: Minimum Curvature Design: 2L-320 Database: CPAI EDM Production Survey Map Map Vertical 1 MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) ( ) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,011.86 74.21 115.97 2,746.88 2,591.03 -1,067.66 1,945.97 5,926,566.91 462,799.11 0.85 2,216.38 MWD+IFR-AK-CAZ-SC(3) 4,106.94 74.48 114.50 2,772.54 2,616.69 -1,106.69 2,028.78 5,926,527.45 462,881.71 1.52 2,307.93 MWD+IFR-AK-CAZ-SC(3) 4,201.28 74.28 113.63 2,797.94 2,642.09 -1,143.74 2,111.74 5,926,489.98 462,964.47 0.91 2,398.75 MWD+IFR-AK-CAZ-SC(3) 4,296.05 74.35 112.47 2,823.56 2,667.71 -1,179.46 2,195.69 5,926,453.83 463,048.23 1.18 2,489.89 MWD+IFR-AK-CAZ-SC(3) 4,390.96 74.69 112.62 2,848.89 2,693.04 -1,214.53 2,280.17 5,926,418.32 463,132.51 0.39 2,581.23 MWD+IFR-AK-CAZ-SC(3) 4,484.34 75.05 110.77 2,873.27 2,717.42 -1,247.85 2,363.92 5,926,384.57 463,216.09 1.95 2,671.15 MWD+IFR-AK-CAZ-SC(3) 4,578.89 75.37 109.47 2,897.40 2,741.55 -1,279.29 2,449.76 5,926,352.69 463,301.75 1.37 2,762.14 MWD+IFR-AK-CAZ-SC(3) 4,672.50 75.68 109.58 2,920.80 2,764.95 -1,309.59 2,535.19 5,926,321.95 463,387.01 0.35 2,852.26 MWD+IFR-AK-CAZ-SC(3) 4,764.26 76.03 109.57 2,943.23 2,787.38 -1,339.40 2,619.02 5,926,291.71 463,470.68 0.38 2,940.73 MWD+IFR-AK-CAZ-SC(3) 4,863.26 74.69 110.51 2,968.25 2,812.40 -1,372.22 2,709.01 5,926,258.43 463,560.48 1.64 3,036.05 MWD+IFR-AK-CAZ-SC(3) 4,957.36 74.98 110.38 2,992.86 2,837.01 -1,403.94 2,794.11 5,926,226.26 463,645.41 0.34 3,126.50 MWD+IFR-AK-CAZ-SC(3) 5,052.31 74.17 110.47 3,018.12 2,862.27 -1,435.88 2,879.88 5,926,193.88 463,731.01 0.86 3,217.65 MWD+IFR-AK-CAZ-SC(3) 5,144.57 74.42 110.50 3,043.09 2,887.24 -1,466.97 2,963.08 5,926,162.37 463,814.04 027 3,306.10 MWD+IFR-AK-CAZ-SC(3) 5,240.30 74.57 110.89 3,068.68 2,912.83 -1,499.57 3,049.38 5,926,129.33 463,900.16 0.42 3,398.00 MWD+IFR-AK-CAZ-SC(3) 5,336.14 74.07 111.46 3,094.59 2,938.74 -1,532.90 3,135.42 5,926,095.56 463,986.02 0.77 3,489.99 MWD+IFR-AK-CAZ-SC(3) 5,431.05 74.33 112.07 3,120.43 2,964.58 -1,566.76 3,220.23 5,926,061.26 464,070.64 0.68 3,581.10 MWD+IFR-AK-CAZ-SC(3) 5,525.73 74.61 112.09 3,145.78 2,989.93 -1,601.05 3,304.76 5,926,026.53 464,154.99 0.30 3,672.15 MWD+IFR-AK-CAZ-SC(3) 5,619.93 74.75 111.82 3,170.67 3,014.82 -1,635.02 3,389.03 5,925,992.13 464,239.07 0.31 3,762.81 MWD+IFR-AK-CAZ-SC(3) 5,715.00 74.69 112.02 3,195.72 3,039.87 -1,669.25 3,474.11 5,925,957.46 464,323.96 0.21 3,854.33 MWD+IFR-AK-CAZ-SC(3) 5,808.23 74.94 112.19 3,220.14 3,064.29 -1,703.11 3,557.47 5,925,923.17 464,407.14 0.32 3,944.13 MWD+IFR-AK-CAZ-SC(3) 5,902.59 74.75 110.94 3,244.81 3,088.96 -1,736.59 3,642.17 5,925,889.26 464,491.65 1.29 4,034.97 MWD+IFR-AK-CAZ-SC(3) 5,997.20 74.25 110.23 3,270.09 3,114.24 -1,768.64 3,727.52 5,925,856.77 464,576.83 0.90 4,125.78 MWD+IFR-AK-CAZ-SC(3) 6,092.99 74.68 109.87 3,295.75 3,139.90 -1,800.28 3,814.21 5,925,824.68 464,663.35 0.58 4,217.63 MWD+IFR-AK-CAZ-SC(3) II 6,187.97 74.72 110.34 3,320.81 3,164.96 -1,831.77 3,900.24 5,925,792.75 464,749.21 0.48 4,308.81 MWD+IFR-AK-CAZ-SC(3) 6,282.41 74.82 109.87 3,345.62 3,189.77 -1,863.10 3,985.81 5,925,760.98 464,834.61 0.49 4,399.51 MWD+IFR-AK-CAZ-SC(3) 6,376.37 75.00 109.61 3,370.08 3,214.23 -1,893.74 4,071.20 5,925,729.90 464,919.83 0.33 4,489.74 MWD+IFR-AK-CAZ-SC(3) 6,467.88 73.93 109.70 3,394.59 3,238.74 -1,923.39 4,154.23 5,925,699.82 465,002.69 1.17 4,577.43 MWD+IFR-AK-CAZ-SC(3) 6,564.36 74.17 109.76 3,421.10 3,265.25 -1,954.71 4,241.55 5,925,668.06 465,089.84 0.26 4,669.69 MWD+IFR-AK-CAZ-SC(3) 6,658.47 73.66 111.53 3,447.18 3,291.33 -1,986.59 4,326.17 5,925,635.74 465,174.28 1.89 4,759.77 MWD+IFR-AK-CAZ-SC(3) 6,757.84 74.12 110.84 3,474.75 3,318.90 -2,021.09 4,415.18 5,925,600.79 465,263.11 0.81 4,854.95 MWD+IFR-AK-CAZ-SC(3) 6,850.16 74.29 110.96 3,499.88 3,344.03 -2,052.78 4,498.17 5,925,568.67 465,345.92 0.22 4,943.47 MWD+IFR-AK-CAZ-SC(3) 6,945.81 74.55 110.96 3,525.57 3,369.72 -2,085.74 4,584.21 5,925,535.27 465,431.78 027 5,035.30 MWD+IFR-AK-CAZ-SC(3) 7,040.72 74.79 111.25 3,550.66 3,394.81 -2,118.69 4,669.60 5,925,501.87 465,516.99 0.39 5,126.54 MWD+IFR-AK-CAZ-SC(3) 7,134.53 74.98 111.51 3,575.13 3,419.28 -2,151.71 4,753.94 5,925,468.42 465,601.14 0.34 5,216.85 MWD+IFR-AK-CAZ-SC(3) 7,229.30 75.19 111.26 3,599.52 3,443.67 -2,185.10 4,839.21 5,925,434.59 465,686.23 0.34 5,308.18 MWD+IFR-AK-CAZ-SC(3) 7,325.00 75.24 111.37 3,623.94 3,468.09 -2,218.74 4,925.41 5,925,400.51 465,772.25 0.12 5,400.44 MWD+IFR-AK-CAZ-SC(3) 7,418.73 75.47 111.62 3,647.64 3,491.79 -2,251.97 5,009.79 5,925,366.85 465,856.45 0.36 5,490.89 MWD+IFR-AK-CAZ-SC(3) 7,511.74 74.62 111.12 3,671.64 3,515.79 -2,284.71 5,093.47 5,925,333.68 465,939.95 1.05 5,580.49 MWD+IFR-AK-CAZ-SC(3) 7,606.16 74.69 111.50 3,696.63 3,540.78 -2,317.80 5,178.29 5,925,300.15 466,024.60 0.40 5,671.29 MWD+IFR-AK-CAZ-SC(3) 7,699.13 74.81 111.65 3,721.08 3,565.23 -2,350.78 5,261.71 5,925,266.74 466,107.83 0.20 5,760.75 MWD+IFR-AK-CAZ-SC(3) 4/5/2011 12:53:42PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit TVD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad MD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320 Survey Calculation Method: Minimum Curvature Design: 2L-320 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 7,794.08 74.93 111.19 3,745.86 3,590.01 -2,384.26 5,347.03 5,925,232.83 466,192.97 0.48 5,852.16 MWD+IFR-AK-CAZ-SC(3) 7,887.70 74.96 111.68 3,770.18 3,614.33 -2,417.30 5,431.19 5,925,199.35 466,276.94 0.51 5,942.32 MWD+IFR-AK-CAZ-SC(3) 7,984.06 73.97 111.45 3,795.99 3,640.14 -2,451.42 5,517.53 5,925,164.79 466,363.10 1.05 6,034.92 MWD+IFR-AK-CAZ-SC(3) 8,074.74 74.24 111.79 3,820.82 3,664.97 -2,483.55 5,598.60 5,925,132.24 466,444.00 0.47 6,121.92 MWD+IFR-AK-CAZ-SC(3) 8,172.77 74.63 112.15 3,847.13 3,691.28 -2,518.88 5,686.18 5,925,096.46 466,531.38 0.53 6,216.16 MWD+IFR-AK-CAZ-SC(3) 8,266.89 75.07 112.19 3,871.73 3,715.88 -2,553.17 5,770.31 5,925,061.74 466,615.33 0.47 6,306.84 MWD+IFR-AK-CAZ-SC(3) 8,361.26 74.49 111.15 3,896.50 3,740.65 -2,586.79 5,854.93 5,925,027.68 466,699.77 1.23 6,397.68 MWD+IFR-AK-CAZ-SC(3) 8,452.52 74.49 111.53 3,920.90 3,765.05 -2,618.79 5,936.84 5,924,995.26 466,781.50 0.40 6,485.36 MWD+IFR-AK-CAZ-SC(3) 8,548.32 74.16 110.19 3,946.79 3,790.94 -2,651.64 6,023.03 5,924,961.97 466,867.51 1.39 6,577.27 MWD+IFR-AK-CAZ-SC(3) 8,644.57 74.21 110.67 3,973.02 3,817.17 -2,683.96 6,109.81 5,924,929.20 466,954.11 0.48 6,669.49 MWD+IFR-AK-CAZ-SC(3) 8,738.61 74.16 110.72 3,998.65 3,842.80 -2,715.94 6,194.45 5,924,896.79 467,038.58 0.07 6,759.64 MWD+IFR-AK-CAZ-SC(3) 8,833.33 74.18 109.91 4,024.49 3,868.64 -2,747.57 6,279.91 5,924,864.71 467,123.86 0.82 6,850.37 MWD+IFR-AK-CAZ-SC(3) 8,927.94 74.36 110.08 4,050.14 3,894.29 -2,778.71 6,365.49 5,924,833.14 467,209.27 0.26 6,940.99 MWD+IFR-AK-CAZ-SC(3) 9,022.43 74.51 110.43 4,075.49 3,919.64 -2,810.23 6,450.89 5,924,801.18 467,294.49 0.39 7,031.61 MWD+IFR-AK-CAZ-SC(3) 9,119.44 75.68 111.12 4,100.44 3,944.59 -2,843.48 6,538.53 5,924,767.48 467,381.96 1.39 7,125.01 MWD+IFR-AK-CAZ-SC(4) 9,214.82 75.72 110.89 4,124.00 3,968.15 -2,876.61 6,624.82 5,924,733.91 467,468.06 0.24 7,217.13 MWD+IFR-AK-CAZ-SC(4) 9,309.63 74.51 110.24 4,148.36 3,992.51 -2,908.79 6,710.60 5,924,701.28 467,553.67 1.44 7,308.40 MWD+IFR-AK-CAZ-SC(4) 9,404.70 75.76 110.26 4,172.75 4,016.90 -2,940.60 6,796.81 5,924,669.03 467,639.70 1.31 7,399.87 MWD+IFR-AK-CAZ-SC(4) 9,500.74 75.84 109.63 4,196.31 4,040.46 -2,972.36 6,884.33 5,924,636.82 467,727.05 0.64 7,492.51 MWD+IFR-AK-CAZ-SC(4) 9,595.74 74.33 109.52 4,220.76 4,064.91 -3,003.11 6,970.82 5,924,605.62 467,813.37 1.59 7,583.79 MWD+IFR-AK-CAZ-SC(4) 9,691.49 74.44 110.28 4,246.53 4,090.68 -3,034.50 7,057.53 5,924,573.79 467,899.91 0.77 7,675.54 MWD+IFR-AK-CAZ-SC(4) 9,784.56 74.95 111.53 4,271.10 4,115.25 -3,066.53 7,141.39 5,924,541.32 467,983.59 1.41 7,765.00 MWD+IFR-AK-CAZ-SC(4) 9,873.82 75.34 111.70 4,293.98 4,138.13 -3,098.31 7,221.60 5,924,509.13 468,063.62 0.47 7,851.06 MWD+IFR-AK-CAZ-SC(4) 9,972.47 74.65 111.49 4,319.52 4,163.67 -3,133.38 7,310.20 5,924,473.61 468,152.03 0.73 7,946.11 MWD+IFR-AK-CAZ-SC(4) 10,068.50 73.69 111.90 4,345.72 4,189.87 -3,167.54 7,396.04 5,924,439.01 468,237.69 1.08 8,038.28 MWD+IFR-AK-CAZ-SC(4) 10,164.51 73.97 112.00 4,372.46 4,216.61 -3,202.00 7,481.57 5,924,404.11 468,323.03 0.31 8,130.29 MWD+IFR-AK-CAZ-SC(4) 10,259.29 74.37 111.88 4,398.31 4,242.46 -3,236.07 7,566.15 5,924,369.60 468,407.42 0.44 8,221.29 MWD+IFR-AK-CAZ-SC(4) 10,352.17 74.60 111.86 4,423.15 4,267.30 -3,269.41 7,649.20 5,924,335.84 468,490.29 0.25 8,310.59 MWD+IFR-AK-CAZ-SC(4) 10,445.83 74.96 111.79 4,447.74 4,291.89 -3,303.01 7,733.10 5,924,301.81 468,574.01 0.39 8,400.76 MWD+IFR-AK-CAZ-SC(4) 10,541.32 73.99 110.33 4,473.30 4,317.45 -3,336.07 7,818.95 5,924,268.30 468,659.68 1.79 8,492.46 MWD+IFR-AK-CAZ-SC(4) 10,636.42 74.18 109.98 4,499.38 4,343.53 -3,367.58 7,904.81 5,924,236.35 468,745.36 0.41 8,583.50 MWD+IFR-AK-CAZ-SC(4) 10,735.31 74.81 110.25 4,525.82 4,369.97 -3,400.36 7,994.29 5,924,203.12 468,834.66 0.69 8,678.34 MWD+IFR-AK-CAZ-SC(4) 10,829.65 75.56 110.41 4,549.94 4,394.09 -3,432.04 8,079.81 5,924,170.99 468,920.01 0.81 8,769.15 MWD+IFR-AK-CAZ-SC(4) 10,923.36 74.31 110.19 4,574.29 4,418.44 -3,463.44 8,164.68 5,924,139.16 469,004.70 1.35 8,859.24 MWD+IFR-AK-CAZ-SC(4) 11,019.31 74.82 110.02 4,599.83 4,443.98 -3,495.23 8,251.53 5,924,106.92 469,091.38 0.56 8,951.30 MWD+IFR-AK-CAZ-SC(4) 11,114.05 75.26 109.92 4,624.29 4,468.44 -3,526.49 8,337.55 5,924,075.22 469,177.24 0.48 9,042.38 MWD+IFR-AK-CAZ-SC(4) 11,205.83 74.69 110.93 4,648.08 4,492.23 -3,557.42 8,420.62 5,924,043.86 469,260.13 1.23 9,130.65 MWD+IFR-AK-CAZ-SC(4) 11,304.75 75.25 111.10 4,673.73 4,517.88 -3,591.68 8,509.80 5,924,009.14 469,349.13 0.59 9,225.87 MWD+IFR-AK-CAZ-SC(4) 11,392.60 74.88 111.06 4,696.37 4,540.52 -3,622.21 8,589.00 5,923,978.20 469,428.16 0.42 9,310.48 MWD+IFR-AK-CAZ-SC(4) 11,491.91 74.12 111.72 4,722.91 4,567.06 -3,657.11 8,678.11 5,923,942.85 469,517.08 1.00 9,405.91 MWD+IFR-AK-CAZ-SC(4) 4/5/2011 12:53:42PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit TVD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad 100 Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320 Survey Calculation Method: Minimum Curvature Design: 2L-320 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S -E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,588.96 74.30 111.62 4,749.32 4,593.47 -3,691.60 8,764.90 5,923,907.92 469,603.68 0.21 9,499.07 MWD+IFR-AK-CAZ-SC(4) 11,677.13 74.00 111.36 4,773.40 4,617.55 -3,722.67 8,843.82 5,923,876.44 469,682.43 0.44 9,583.66 MWD+IFR-AK-CAZ-SC(5) 11,775.28 73.45 111.02 4,800.91 4,645.06 -3,756.72 8,931.67 5,923,841.93 469,770.09 0.65 9,677.59 MWD+IFR-AK-CAZ-SC(5) 11,870.25 72.90 111.03 4,828.40 4,672.55 -3,789.34 9,016.52 5,923,808.88 469,854.76 0.58 9,768.20 MWD+IFR-AK-CAZ-SC(5) 11,965.39 74.21 112.55 4,855.33 4,699.48 -3,823.21 9,101.24 5,923,774.57 469,939.30 2.06 9,859.24 MWD+IFR-AK-CAZ-SC(5) 12,059.64 74.52 112.06 4,880.73 4,724.88 -3,857.66 9,185.21 5,923,739.69 470,023.08 0.60 9,949.84 MWD+IFR-AK-CAZ-SC(5) 12,153.99 74.84 112.40 4,905.66 4,749.81 -3,892.09 9,269.44 5,923,704.83 470,107.13 0.49 10,040.68 MWD+IFR-AK-CAZ-SC(5) 12,249.75 75.38 112.22 4,930.27 4,774.42 -3,927.22 9,355.06 5,923,669.26 470,192.55 0.59 10,133.06 MWD+IFR-AK-CAZ-SC(5) 12,341.93 74.44 111.56 4,954.27 4,798.42 -3,960.40 9,437.64 5,923,635.65 470,274.95 1.23 10,221.87 MWD+IFR-AK-CAZ-SC(5) 12,437.35 74.34 111.35 4,979.94 4,824.09 -3,994.01 9,523.18 5,923,601.60 470,360.30 0.24 10,313.52 MWD+IFR-AK-CAZ-SC(5) 12,531.36 74.64 110.96 5,005.08 4,849.23 -4,026.71 9,607.66 5,923,568.47 470,444.60 0.51 10,403.83 MWD+IFR-AK-CAZ-SC(5) 12,624.83 74.96 111.24 5,029.59 4,873.74 -4,059.18 9,691.81 5,923,535.57 470,528.58 0.45 10,493.74 MWD+IFR-AK-CAZ-SC(5) 12,723.63 75.57 111.34 5,054.72 4,898.87 -4,093.87 9,780.84 5,923,500.42 470,617.42 0.63 10,589.02 MWD+IFR-AK-CAZ-SC(5) 12,817.22 75.93 111.02 5,077.76 4,921.91 -4,126.64 9,865.42 5,923,467.21 470,701.82 0.51 10,679.45 MWD+IFR-AK-CAZ-SC(5) 12,914.72 73.78 110.32 5,103.23 4,947.38 -4,159.87 9,953.47 5,923,433.54 470,789.69 2.31 10,773.20 MWD+IFR-AK-CAZ-SC(5) 13,008.88 74.22 110.12 5,129.18 4,973.33 -4,191.15 10,038.40 5,923,401.82 470,874.45 0.51 10,863.31 MWD+IFR-AK-CAZ-SC(5) 13,103.27 74.73 110.24 5,154.45 4,998.60 -4,222.52 10,123.77 5,923,370.00 470,959.64 0.55 10,953.84 MWD+IFR-AK-CAZ-SC(5) 13,197.41 74.80 112.07 5,179.19 5,023.34 -4,255.30 10,208.47 5,923,336.79 471,044.17 1.88 11,044.38 MWD+IFR-AK-CAZ-SC(5) 13,289.56 74.26 115.48 5,203.77 5,047.92 -4,291.10 10,289.73 5,923,300.58 471,125.24 3.61 11,133.13 MWD+IFR-AK-CAZ-SC(5) 13,388.01 74.09 118.43 5,230.63 5,074.78 -4,334.03 10,374.15 5,923,257.22 471,209.42 2.89 11,227.81 MWD+IFR-AK-CAZ-SC(5) 13,480.94 72.93 122.54 5,257.01 5,101.16 -4,379.21 10,450.93 5,923,211.64 471,285.95 4.42 11,316.58 MWD+IFR-AK-CAZ-SC(5) 13,578.39 71.34 127.84 5,286.93 5,131.08 -4,432.62 10,526.70 5,923,157.84 471,361.45 5.43 11,408.01 MWD+IFR-AK-CAZ-SC(5) 13,622.88 71.45 129.78 5,301.12 5,145.27 -4,459.05 10,559.56 5,923,131.25 471,394.16 4.14 11,449.07 MWD+IFR-AK-CAZ-SC(5) 13,669.61 71.10 132.51 5,316.13 5,160.28 -4,488.16 10,592.88 5,923,101.96 471,427.33 5.58 11,491.72 MWD+IFR-AK-CAZ-SC(5) 13,721.10 71.73 134.05 5,332.54 5,176.69 -4,521.62 10,628.41 5,923,068.32 471,462.68 3.09 11,538.23 MWD+IFR-AK-CAZ-SC(5) 13,764.25 71.78 136.82 5,346.05 5,190.20 -4,550.81 10,657.16 5,923,038.98 471,491.28 6.10 11,576.79 MWD+IFR-AK-CAZ-SC(5) 13,813.63 71.90 138.97 5,361.44 5,205.59 -4,585.62 10,688.62 5,923,004.02 471,522.55 4.14 11,620.22 MWD+1FR-AK-CAZ-SC(5) 13,862.49 71.93 142.29 5,376.61 5,220.76 -4,621.52 10,718.08 5,922,967.97 471,551.82 6.46 11,662.31 MWD+IFR-AK-CAZ-SC(5) 13,910.32 72.42 143.63 5,391.25 5,235.40 -4,657.87 10,745.51 5,922,931.48 471,579.05 2.86 11,702.78 MWD+1FR-AK-CAZ-SC(5) 13,951.10 72.46 145.69 5,403.56 5,247.71 -4,689.58 10,767.99 5,922,899.66 471,601.38 4.82 11,736.78 MWD+IFR-AK-CAZ-SC(5) 14,005.19 72.82 146.84 5,419.70 5,263.85 -4,732.51 10,796.66 5,922,856.58 471,629.82 2.14 11,781.21 MWD+IFR-AK-CAZ-SC(5) 14,046.89 73.02 147.34 5,431.95 5,276.10 -4,765.98 10,818.32 5,922,823.01 471,651.30 124 11,815.22 MWD+IFR-AK-CAZ-SC(5) 14,099.51 73.35 148.36' 5,447.17 5,291.32 -4,808.62 10,845.12 5,922,780.23 471,677.88 1.96 11,857.85 MWD+IFR-AK-CAZ-SC(5) 14,14463 73.70 150.62 5,459.97 5,304.12 -4,845.90 10,867.09 5,922,742.84 471,699.65 4.87 11,893.79 MWD+IFR-AK-CAZ-SC(5) 14,195.02 73.90 153.13 5,474.03 5,318.18 -4,888.57 10,889.89 5,922,700.06 471,722.23 4.80 11,932.83 MWD+IFR-AK-CAZ-SC(5) 14,241.15 72.94 156.33 5,487.19 5,331.34 -4,928.54 10,908.77 5,922,659.99 471,740.90 6.97 11,967.15 MWD+IFR-AK-CAZ-SC(5) 14,284.13 72.24 157.85 5,500.05 5,344.20 -4,966.32 10,924.73 5,922,622.14 471,756.66 3.75 11,997.90 MWD+IFR-AK-CAZ-SC(5) 14,334.85 70.79 158.13 5,516.13 5,360.28 -5,010.91 10,942.76 5,922,577.46 471,774.46 2.91 12,033.46 MWD+IFR-AK-CAZ-SC(5) 14,428.77 69.09 157.76 5,548.35 5,392.50 -5,092.68 10,975.89 5,922,495.53 471,807.15 1.85 12,098.72 MWD+IFR-AK-CAZ-SC(5) 14,523.72 68.02 157.32 5,583.06 5,427.21 -5,174.35 11,009.65 5,922,413.69 471,840.49 1.21 12,164.52 MWD+IFR-AK-CAZ-SC(5) 4/5/2011 12:53:42PM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit TVD Reference: Rig:2L:320 @ 155.856(D15(40.95+114.90)) Site: Kuparuk 2L Pad MD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320 Survey Calculation Method: Minimum Curvature Design: 2L-320 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,620.51 67.94 157.79 5,619.35 5,463.50 -5,257.28 11,043.91 5,922,330.59 471,874.31 0.46 12,231.31 MWD+IFR-AK-CAZ-SC(5) 14,712.61 67.95 157.80 5,653.93 5,498.08 -5,336.31 11,076.16 5,922,251.40 471,906.16 0.01 12,294.61 MWD+IFR-AK-CAZ-SC(5) 14,808.14 67.91 158.06 5,689.83 5,533.98 -5,418.35 11,109.43 5,922,169.20 471,939.00 0.26 12,360.12 MWD+IFR-AK-CAZ-SC(5) 14,904.19 67.94 157.78 5,725.93 5,570.08 -5,500.83 11,142.89 5,922,086.55 471,972.02 0.27 12,426.00 MWD+IFR-AK-CAZ-SC(5) 14,999.37 68.29 158.21 5,761.40 5,605.55 -5,582.72 11,175.98 5,922,004.50 472,004.69 0.56 12,491.28 MWD+IFR-AK-CAZ-SC(5) 15,049.00 68.29 158.21 5,779.76 5,623.91 -5,625.54 11,193.10 5,921,961.60 472,021.58 0.00 12,525.25 PROJECTED to TD 4/5/2011 12.53:42PM Page 7 COMPASS 2003.16 Build 69 1 0• kit iti "sem • A • 4 �l ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2L Pad 2L-320PB1 P 501032062770 A P Sperry Drilling •L • Definitive Survey Report / ',t k IA 41 Al gl 1 05 April, 2011 . U 0 *i u I 4 1 o1slr4 fa N i PI 4 fir R P n:- • a }41 1 0 3 f• 4 Sf L C4 HALLIBURTON Sperry Drilling • I: ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit TVD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad MD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320PB1 Survey Calculation Method: Minimum Curvature Design: 2L-320PB1 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-320 Well Position +N/-S 0.00 ft Northing: 5,927,644.53 ft Latitude: 70°12'47.763 N +EI-W 0.00 ft Easting: 460,858.89 ft Longitude: 150°18'56.399 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.90ft Wellbore 2L-320PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 12/31/2010 16.70 79.66 57,369 Design 2L-320PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.95 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 40.95 0.00 0.00 115.66 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,483.00 2L-320 Gyro(2L-320PB1) CB-GYRO-SS Camera based gyro single shot 12/31/2010 12: 1,526.44 2,706.47 2L-320 MWD(R100)(2L-320PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/1/2011 12:0C 2,790.11 11,408.96 2L-320 MWD(R200)(2L-320PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/8/2011 12:0C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 40.95 0.00 0.00 40.95 -114.90 0.00 0.00 5,927,644.53 460,858.89 0.00 0.00 UNDEFINED 100.00 0.33 84.28 100.00 -55.85 0.02 0.17 5,927,644.55 460,859.06 0.56 0.15 CB-GYRO-SS(1) 165.00 1.15 107.76 164.99 9.14 -0.16 0.98 5,927,644.37 460,859.87 1.32 0.95 CB-GYRO-SS(1) 254.00 1.32 121.22 253.97 98.12 -0.97 2.70 5,927,643.55 460,861.59 0.38 2.86 CB-GYRO-SS(1) 351.00 1.62 121.02 350.94 195.09 -2.25 4.83 5,927,642.26 460,863.72 0.31 5.33 CB-GYRO-SS(1) 440.00 2.18 111.76 439.89 284.04 -3.53 7.48 5,927,640.97 460,866.36 0.72 8.27 CB-GYRO-SS(1) 535.00 2.59 108.96 534.81 378.96 -4.90 11.19 5,927,639.58 460,870.06 0.45 12.21 CB-GYRO-SS(1) 627.00 3.22 118.88 626.69 470.84 -6.82 15.42 5,927,637.64 460,874.28 0.87 16.85 CB-GYRO-SS(1) 724.00 4.73 124.16 723.46 567.61 -10.38 21.12 5,927,634.04 460,879.95 1.60 23.53 CB-GYRO-SS(1) I 819.00 8.46 127.81 817.81 661.96 -16.87 29.88 5,927,627.51 460,888.69 3.95 34.24 CB-GYRO-SS(1) 915.00 14.69 132.07 911.81 755.96 -29.36 44.51 5,927,614.94 460,903.25 6.55 52.84 CB-GYRO-SS(1) 960.00 15.36 131.75 955.28 799.43 -37.16 53.19 5,927,607.11 460,911.89 1.50 64.04 CB-GYRO-SS(1) 4/5/2011 12:57:02PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. IL..ocal Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit TVD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad MD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320PB1 Survey Calculation Method: Minimum Curvature Design: 2L-320PB1 Database: CPAI EDM Production Survey 1. Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +1:-/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 1,007.00 14.59 132.53 1,000,68 844.83 -45.30 62.20 5,927,598.91 460,920.85 1.69 75.68 CB-GYRO-SS(1) 1,102.00 13.97 129.16 1,092.74 936.89 -60.63 79.91 5,927,583.49 460,938.48 1.09 98.28 CB-GYRO-SS(1) 1,197.00 13.71 129.77 1,184.99 1,029.14 -75.08 97.45 5,927,568.96 460,955.95 0.31 120.35 CB-GYRO-SS(1) I 1,292.00 14.90 126.21 1,277.04 1,121.19 -89.49 115.96 5,927,554.45 460,974.38 1.56 143.28 CB-GYRO-SS(1) r 1,388.00 17.10 121.82 1,369.32 1,213.47 -104.23 137.92 5,927,539.60 460,996.26 2.61 169.45 CB-GYRO-SS(1) 1,483.00 18.33 123.05 1,459.81 1,303.96 -119.74 162.31 5,927,523.97 461,020.56 1.35 198.15 CB-GYRO-SS(1) 1,526.44 18.21 120.12 1,501.06 1,345.21 -126.87 173.90 5,927,516.77 461,032.12 2.13 211.69 MWD+IFR-AK-CAZ-SC(2) 1,625.40 21.61 121.51 1,594.10 1,438.25 -144.16 202.82 5,927,499.34 461,060.95 3.47 245.25 MWD+IFR-AK-CAZ-SC(2) 1,724.63 26.65 120.77 1,684.63 1,528.78 -165.11 237.55 5,927,478.21 461,095.56 5.09 285.61 MWD+IFR-AK-CAZ-SC(2) 1,821.04 32.12 120.40 1,768.60 1,612.75 -189.16 278.26 5,927,453.95 461,136.14 5.68 332.73 MWD+IFR-AK-CAZ-SC(2) 1,865.48 33.22 121.66 1,806.01 1,650.16 -201.53 298.81 5,927,441.48 461,156.63 2.91 356.61 MWD+IFR-AK-CAZ-SC(2) 1,915.34 34.45 122.10 1,847.43 1,691.58 -216.19 322.39 5,927,426.70 461,180.12 2.52 384.21 MWD+IFR-AK-CAZ-SC(2) 2,009.93 37.07 124.24 1,924.18 1,768.33 -246.46 368.63 5,927,396.20 461,226.20 3.07 439.00 MWD+IFR-AK-CAZ-SC(2) c 2,104.95 39.99 122.44 1,998.51 1,842.66 -278.96 418.08 5,927,363.44 461,275.49 3.29 497.65 MWD+IFR-AK-CAZ-SC(2) 2,198.85 43.73 120.23 2,068.43 1,912.58 -311.49 471.61 5,927,330.63 461,328.84 4.28 559.99 MWD+IFR-AK-CAZ-SC(2) 2,292.79 49.05 118.82 2,133.21 1,977.36 -344.97 530.79 5,927,296.85 461,387.84 5.77 627.82 MWD+IFR-AK-CAZ-SC(2) 2,336.84 49.65 118.67 2,161.90 2,006.05 -361.04 560.09 5,927,280.63 461,417.05 1.39 661.20 MWD+IFR-AK-CAZ-SC(2) 2,387.60 50.51 119.09 2,194.47 2,038.62 -379.84 594.18 5,927,261.65 461,451.04 1.81 700.06 MWD+IFR-AK-CAZ-SC(2) 2,432.85 52.56 118.18 2,222.62 2,066.77 -396.82 625.28 5,927,244.52 461,482.04 4.80 735.44 MWD+IFR-AK-CAZ-SC(2) 2,483.66 56.45 118.10 2,252.12 2,096.27 -416.32 661.75 5,927,224.83 461,518.41 7.66 776.76 MWD+IFR-AK-CAZ-SC(2) 2,530.68 58.11 117.70 2,277.53 2,121.68 -434.83 696.71 5,927,206.14 461,553.27 3.60 816.29 MWD+IFR-AK-CAZ-SC(2) 2,575.11 59.23 117.16 2,300.63 2,144.78 -452.31 730.39 5,927,188.49 461,586.86 2.73 854.22 MWD+IFR-AK-CAZ-SC(2) 2,665.45 64.61 115.86 2,343.14 2,187.29 -487.86 801.70 5,927,152.58 461,657.98 6.09 933.89 MWD+IFR-AK-CAZ-SC(2) 2,706.47 66.33 114.91 2,360.17 2,204.32 -503.85 835.41 5,927,136.41 461,691.60 4.69 971.21 MWD+IFR-AK-CAZ-SC(2) 2,790.11 68.87 116.88 2,392.05 2,236.20 -537.63 904.96 5,927,102.27 461,760.97 3.74 1,048.52 MWD+IFR-AK-CAZ-SC(3) 2,886.54 72.87 117.07 2,423.64 2,267.79 -578.95 986.14 5,927,060.54 461,841.92 4.15 1,139.58 MWD+IFR-AK-CAZ-SC(3) 2,980.63 76.90 117.14 2,448.17 2,292.32 -620.33 1,066.98 5,927,018.75 461,922.54 4.28 1,230.37 MWD+IFR-AK-CAZ-SC(3) 3,075.46 76.97 117.09 2,469.61 2,313.76 -662.43 1,149.20 5,926,976.22 462,004.54 0.09 1,322.72 MWD+IFR-AK-CAZ-SC(3) 3,170.09 76.74 117.50 2,491.13 2,335.28 -704.69 1,231.09 5,926,933.55 462,086.20 0.49 1,414.83 MWD+IFR-AK-CAZ-SC(3) 3,265.06 76.63 117.46 2,513.00 2,357.15 -747.33 1,313.08 5,926,890.48 462,167.96 0.12 1,507.20 MWD+IFR-AK-CAZ-SC(3) 3,359.55 77.11 116.41 2,534.46 2,378.61 -789.01 1,395.12 5,926,848.38 462,249.77 1.20 1,599.20 MWD+IFR-AK-CAZ-SC(3) 3,452.77 76.56 116.61 2,555.70 2,399.85 -829.53 1,476.35 5,926,807.45 462,330.77 0.63 1,689.96 MWD+IFR-AK-CAZ-SC(3) 3,547.24 76.27 116.88 2,577.89 2,422.04 -870.85 1,558.35 5,926,765.70 462,412.55 0.41 1,781.77 MWD+IFR-AK-CAZ-SC(3) 3,642.29 76.49 114.99 2,600.27 2,444.42 -911.25 1,641.42 5,926,724.88 462,495.41 1.95 1,874.14 MWD+IFR-AK-CAZ-SC(3) 3,737.88 76.39 115.26 2,622.68 2,466.83 -950.70 1,725.55 5,926,684.99 462,579.32 0.29 1,967.06 MWD+IFR-AK-CAZ-SC(3) 3,832.19 76.63 113.53 2,644.68 2,488.83 -988.58 1,809.07 5,926,646.69 462,662.64 1.80 2,058.74 MWD+IFR-AK-CAZ-SC(3) 3,926.35 76.66 114.22 2,666.43 2,510.58 -1,025.66 1,892.84 5,926,609.18 462,746.21 0.71 2,150.31 MWD+IFR-AK-CAZ-SC(3) 4,020.84 76.55 114.51 2,688.32 2,532.47 -1,063.58 1,976.57 5,926,570.83 462,829.73 0.32 2,242.20 MWD+IFR-AK-CAZ-SC(3) 4,116.18 76.59 112.61 2,710.47 2,554.62 -1,100.65 2,061.57 5,926,533.33 462,914.53 1.94 2,334.87 MWD+IFR-AK-CAZ-SC(3) 4,210.92 76.38 112.58 2,732.61 2,576.76 -1,136.04 2,146.62 5,926,497.50 462,999.38 0.22 2,426.86 MWD+IFR-AK-CAZ-SC(3) 4/5/2011 12:57:02PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit 1rVD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad Ii IID Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320PB1 Survey Calculation Method: Minimum Curvature Design: 2L-320PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,305.97 76.36 112.88 2,755.01 2,599.16 -1,171.73 2,231.82 5,926,461.37 463,084.39 0.31 2,519.11 MWD+IFR-AK-CAZ-SC(3) 4,401.06 76.18 112.82 2,777.58 2,621.73 -1,207.60 2,316.94 5,926,425.06 463,169.32 0.20 2,611.37 MWD+IFR-AK-CAZ-SC(3) 4,492.57 76.08 113.02 2,799.51 2,643.66 -1,242.20 2,398.77 5,926,390.04 463,250.96 0.24 2,700.11 MWD+IFR-AK-CAZ-SC(3) 4,584.88 76.00 113.22 2,821.78 2,665.93 -1,277.37 2,481.16 5,926,354.44 463,333.15 0.23 2,789.61 MWD+IFR-AK-CAZ-SC(3) 4,682.94 75.90 113.30 2,845.59 2,689.74 -1,314.94 2,568.55 5,926,316.43 463,420.34 0.13 2,884.65 MWD+IFR-AK-CAZ-SC(3) 4,778.33 75.86 113.49 2,868.86 2,713.01 -1,351.67 2,653.46 5,926,279.26 463,505.05 0.20 2,977.08 MWD+IFR-AK-CAZ-SC(3) 4,868.88 75.84 113.53 2,891.00 2,735.15 -1,386.70 2,733.97 5,926,243.82 463,585.37 0.05 3,064.82 MWD+IFR-AK-CAZ-SC(3) 4,968.35 75.80 113.13 2,915.36 2,759.51 -1,424.89 2,822.52 5,926,205.17 463,673.72 0.39 3,161.18 MWD+IFR-AK-CAZ-SC(3) 5,061.70 75.69 113.38 2,938.35 2,782.50 -1,460.61 2,905.65 5,926,169.02 463,756.65 0.29 3,251.58 MWD+I FR-AK-CAZ-SC(3) 5,155.29 75.69 113.27 2,961.48 2,805.63 -1,496.52 2,988.92 5,926,132.69 463,839.73 0.11 3,342.19 MWD+I FR-AK-CAZ-SC(3) 5,248.63 75.62 113.62 2,984.61 2,828.76 -1,532.50 3,071.89 5,926,096.28 463,922.49 0.37 3,432.55 MWD+IFR-AK-CAZ-SC(3) 5,346.43 75.42 112.05 3,009.06 2,853.21 -1,569.25 3,159.16 5,926,059.09 464,009.56 1.57 3,527.13 MWD+IFR-AK-CAZ-SC(3) 5,440.48 75.43 112.44 3,032.73 2,876.88 -1,603.70 3,243.40 5,926,024.20 464,093.62 0.40 3,617.99 MWD+IFR-AK-CAZ-SC(3) 5,536.87 75.36 112.53 3,057.04 2,901.19 -1,639.38 3,329.59 5,925,988.08 464,179.61 0.12 3,711.12 MWD+IFR-AK-CAZ-SC(3) 5,628.95 75.31 113.17 3,080.35 2,924.50 -1,673.97 3,411.68 5,925,953.07 464,261.51 0.67 3,800.09 MWD+IFR-AK-CAZ-SC(3) 5,726.48 75.55 111.56 3,104.88 2,949.03 -1,709.88 3,498.97 5,925,916.70 464,348.61 1.62 3,894.33 MWD+IFR-AK-CAZ-SC(3) 5,818.80 75.63 111.58 3,127.86 2,972.01 -1,742.76 3,582.12 5,925,883.40 464,431.58 0.09 3,983.52 MWD+IFR-AK-CAZ-SC(3) 5,913.82 75.58 111.35 3,151.48 2,995.63 -1,776.43 3,667.78 5,925,849.29 464,517.05 0.24 4,075.31 MWD+IFR-AK-CAZ-SC(3) 6,008.39 75.54 111.49 3,175.06 3,019.21 -1,809.88 3,753.03 5,925,815.40 464,602.13 0.15 4,166.64 MWD+IFR-AK-CAZ-SC(3) 6,103.26 75.31 111.76 3,198.94 3,043.09 -1,843.72 3,838.39 5,925,781.13 464,687.30 0.37 4,258.23 MWD+IFR-AK-CAZ-SC(3) 6,198.22 75.10 112.01 3,223.19 3,067.34 -1,877.94 3,923.58 5,925,746.47 464,772.30 0.34 4,349.84 MWD+IFR-AK-CAZ-SC(3) 6,293.47 75.25 110.80 3,247.56 3,091.71 -1,911.54 4,009.31 5,925,712.42 464,857.85 1.24 4,441.66 MWD+IFR-AK-CAZ-SC(3) 6,388.43 75.12 111.48 3,271.84 3,115.99 -1,944.65 4,094.93 5,925,678.87 464,943.29 0.71 4,533.18 MWD+IFR-AK-CAZ-SC(3) 6,483.51 75.09 111.50 3,296.28 3,140.43 -1,978.31 4,180.43 5,925,644.77 465,028.60 0.04 4,624.82 MWD+IFR-AK-CAZ-SC(3) 6,578.07 75.75 111.27 3,320.08 3,164.23 -2,011.68 4,265.64 5,925,610.96 465,113.63 0.74 4,716.08 MWD+IFR-AK-CAZ-SC(3) 6,672.52 75.66 111.91 3,343.41 3,187.56 -2,045.36 4,350.75 5,925,576.85 465,198.55 0.66 4,807.38 MWD+IFR-AK-CAZ-SC(3) 6,766.95 75.57 111.60 3,366.87 3,211.02 -2,079.26 4,435.70 5,925,542.51 465,283.32 0.33 4,898.63 MWD+IFR-AK-CAZ-SC(3) 6,860.96 75.44 111.85 3,390.40 3,234.55 -2,112.95 4,520.25 5,925,508.39 465,367.69 0.29 4,989.44 MWD+IFR-AK-CAZ-SC(3) 6,951.67 75.49 111.83 3,413.16 3,257.31 -2,145.62 4,601.76 5,925,475.30 465,449.02 0.06 5,077.05 MWD+IFR-AK-CAZ-SC(3) 7,050.17 75.44 112.28 3,437.88 3,282.03 -2,181.42 4,690.13 5,925,439.05 465,537.19 0.45 5,172.21 MWD+IFR-AK-CAZ-SC(3) 7,144.69 75.56 111.28 3,461.55 3,305.70 -2,215.37 4,775.11 5,925,404.66 465,621.98 1.03 5,263.51 MWD+IFR-AK-CAZ-SC(3) 7,241.87 76.45 111.14 3,485.05 3,329.20 -2,249.49 4,863.01 5,925,370.09 465,709.70 0.93 5,357.52 MWD+IFR-AK-CAZ-SC(3) 7,332.25 76.44 111.13 3,506.23 3,350.38 -2,281.17 4,944.96 5,925,337.99 465,791.48 0.02 5,445.11 MWD+IFR-AK-CAZ-SC(3) 7,429.12 76.43 111.67 3,528.95 3,373.10 -2,315.53 5,032.64 5,925,303.18 465,878.97 0.54 5,539.01 MWD+IFR-AK-CAZ-SC(3) 7,524.14 76.32 111.61 3,551.34 3,395.49 -2,349.58 5,118.48 5,925,268.68 465,964.62 0.13 5,631.13 MWD+IFR-AK-CAZ-SC(3) 7,616.26 76.46 111.95 3,573.02 3,417.17 -2,382.80 5,201.62 5,925,235.03 466,047.58 0.39 5,720.46 MWD+IFR-AK-CAZ-SC(3) 7,707.87 76.48 111.73 3,594.45 3,438.60 -2,415.94 5,284.29 5,925,201.47 466,130.07 0.23 5,809.33 MWD+IFR-AK-CAZ-SC(3) 7,803.76 76.37 110.82 3,616.96 3,461.11 -2,449.76 5,371.15 5,925,167.21 466,216.75 0.93 5,902.27 MWD+IFR-AK-CAZ-SC(3) 7,899.20 76.30 111.08 3,639.50 3,483.65 -2,482.92 5,457.76 5,925,133.60 466,303.17 0.27 5,994.69 MWD+IFR-AK-CAZ-SC(3) 7,988.14 76.25 110.99 3,660.60 3,504.75 -2,513.93 5,538.40 5,925,102.18 466,383.65 0.11 6,080.81 MWD+IFR-AK-CAZ-SC(3) 4/5/2011 12:57:02PM Page 4 COMPASS 2003.16 Build 69 LonocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit TVD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad Ih4D Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320PB1 Survey Calculation Method: Minimum Curvature Design: 2L-320PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,087.05 76.16 111.75 3,684.19 3,528.34 -2,548.93 5,627.85 5,925,066.71 466,472.91 0.75 6,176.60 MWD+IFR-AK-CAZ-SC(3) 8,180.93 76.08 111.82 3,706.71 3,550.86 -2,582.76 5,712.48 5,925,032.46 466,557.35 0.11 6,267.53 MWD+IFR-AK-CAZ-SC(3) 8,276.68 75.93 111.53 3,729.87 3,574.02 -2,617.07 5,798.82 5,924,997.70 466,643.50 0.33 6,360.21 MWD+IFR-AK-CAZ-SC(3) 8,371.14 75.82 111.57 3,752.92 3,597.07 -2,650.72 5,884.02 5,924,963.61 466,728.52 0.12 6,451.58 MWD+IFR-AK-CAZ-SC(3) 8,462.99 75.75 111.52 3,775.47 3,619.62 -2,683.42 5,966.84 5,924,930.49 466,811.16 0.09 6,540.39 MWD+IFR-AK-CAZ-SC(3) 8,554.24 75.68 111.46 3,797.99 3,642.14 -2,715.81 6,049.12 5,924,897.67 466,893.26 0.10 6,628.58 MWD+IFR-AK-CAZ-SC(3) 8,653.05 75.68 11128 3,822.43 3,666.58 -2,750.70 6,138.28 5,924,862.33 466,98223 0.18 6,724.06 MWD+IFR-AK-CAZ-SC(3) 8,747.68 75.50 111.49 3,845.98 3,690.13 -2,784.12 6,223.62 5,924,828.47 467,067.39 0.29 6,815.45 MWD+IFR-AK-CAZ-SC(3) 8,841.78 75.48 111.98 3,869.55 3,713.70 -2,817.85 6,308.24 5,924,794.30 467,151.83 0.50 6,906.34 MWD+IFR-AK-CAZ-SC(3) 8,938.54 75.59 111.86 3,893.72 3,737.87 -2,852.83 6,395.16 5,924,758.87 467,238.55 0.17 6,999.83 MWD+IFR-AK-CAZ-SC(3) 9,033.60 75.49 112.27 3,917.46 3,761.61 -2,887.41 6,480.47 5,924,723.86 467,323.67 0.43 7,091.70 MWD+IFR-AK-CAZ-SC(3) 9,129.01 75.31 112.59 3,941.51 3,785.66 -2,922.63 6,565.81 5,924,688.19 467,408.82 0.38 7,183.88 MWD+IFR-AK-CAZ-SC(3) 9,225.37 75.13 113.07 3,966.09 3,810.24 -2,958.78 6,651.68 5,924,651.60 467,494.50 0.52 7,276.94 MWD+IFR-AK-CAZ-SC(3) 9,319.51 74.92 112.77 3,990.42 3,834.57 -2,994.20 6,735.45 5,924,615.75 467,578.07 0.38 7,367.78 MWD+IFR-AK-CAZ-SC(3) 9,415.52 75.24 111.45 4,015.14 3,859.29 -3,029.12 6,821.40 5,924,580.39 467,663.83 1.37 7,460.37 MWD+1FR-AK-CAZ-SC(3) 9,510.28 75.22 111.65 4,039.30 3,883.45 -3,062.78 6,906.62 5,924,546.30 467,748.87 0.21 7,551.76 MWD+1FR-AK-CAZ-SC(3) 9,604.17 75.20 112.18 4,063.27 3,907.42 -3,096.66 6,990.84 5,924,511.98 467,832.90 0.55 7,642.35 MWD+IFR-AK-CAZ-SC(3) 9,699.37 75.95 110.42 4,086.98 3,931.13 -3,130.14 7,076.74 5,924,478.06 467,918.61 1.96 7,734.28 MWD+IFR-AK-CAZ-SC(3) 9,794.51 75.89 110.76 4,110.13 3,954.28 -3,162.60 7,163.12 5,924,445.16 468,004.82 0.35 7,826.20 MWD+IFR-AK-CAZ-SC(3) 9,889.41 76.16 110.56 4,133.05 3,977.20 -3,195.09 7,249.29 5,924,412.22 468,090.81 0.35 7,917.94 MWD+IFR-AK-CAZ-SC(3) 9,984.03 75.70 111.14 4,156.05 4,000.20 -3,227.76 7,335.06 5,924,379.12 468,176.41 0.77 8,009.39 MWD+IFR-AK-CAZ-SC(3) 10,079.22 75.57 111.37 4,179.67 4,023.82 -3,261.18 7,421.00 5,924,345.25 468,262.16 0.27 8,101.34 MWD+IFR-AK-CAZ-SC(3) 10,174.34 75.49 111.32 4,203.43 4,047.58 -3,294.71 7,506.79 5,924,311.28 468,347.77 0.10 8,193.18 MWD+IFR-AK-CAZ-SC(3) 10,269.34 75.48 111.45 4,227.24 4,071.39 -3,328.24 7,592.42 5,924,277.31 468,433.22 0.13 8,284.89 MWD+IFR-AK-CAZ-SC(3) 75.54111.79 4 251.07 4 95.22 -3,362.21 7 678.14 24 42. 468,518.75 5 8 7 MWD+IFR-AK- AZ- C 10,364.57 ,05.9 ,2 890 3 ,3 6.86 C S 3 10,458.17 75.42 111.93 4,274.54 4,118.69 -3,395.95 7,762.23 5,924,208.72 468,602.66 0.19 8,467.27 MWD+IFR-AK-CAZ-SC(3) 10,553.92 75.45 112.30 4,298.62 4,142.77 -3,430.84 7,848.09 5,924,173.39 468,688.32 0.38 8,559.77 MWD+IFR-AK-CAZ-SC(3) 10,649.23 75.44 112.56 4,322.57 4,166.72 -3,466.04 7,933.36 5,924,137.76 468,773.40 0.26 8,651.87 MWD+I FR-AK-CAZ-SC(3) 10,743.87 75.46 112.46 4,346.35 4,190.50 -3,501.11 8,017.99 5,924,102.25 468,857.84 0.10 8,743.34 MWD+IFR-AK-CAZ-SC(3) 10,839.20 75.78 111.16 4,370.02 4,214.17 -3,535.42 8,103.72 5,924,067.51 468,943.38 1.36 8,835.47 MWD+IFR-AK-CAZ-SC(3) 10,933.42 75.74 111.31 4,393.20 4,237.35 -3,568.49 8,188.84 5,924,033.99 469,028.32 0.16 8,926.53 MWD+IFR-AK-CAZ-SC(3) 11,028.70 75.75 111.09 4,416.66 4,260.81 -3,601.89 8,274.94 5,924,000.15 469,114.24 0.22 9,018.59 MWD+IFR-AK-CAZ-SC(3) 11,122.29 75.79 111.12 4,439.67 4,283.82 -3,634.55 8,359.57 5,923,967.05 469,198.69 0.05 9,109.02 MWD+IFR-AK-CAZ-SC(3) 11,218.46 75.74 111.02 4,463.31 4,307.46 -3,668.07 8,446.56 5,923,933.09 469,285.49 0.11 9,201.94 MWD+IFR-AK-CAZ-SC(3) 11,309.40 75.70 111.73 4,485.75 4,329.90 -3,700.19 8,528.62 5,923,900.55 469,367.39 0.76 9,289.83 MWD+IFR-AK-CAZ-SC(3) 11,408.96 75.59 111.29 4,510.43 4,354.58 -3,735.55 8,618.36 5,923,864.72 469,456.93 0.44 9,386.02 MWD+IFR-AK-CAZ-SC(3) 11,446.00 75.59 111.29 4,519.65 4,363.80 -3,748.58 8,651.78 5,923,851.53 469,490.28 0.00 9,421.79 PROJECTED to TD 4/'V2011 12:57:02PM Page 5 COMPASS 2003.16 Build 69 4 la ce .14 . Ffi g 15 ConocoPhilli ps(Alaska) Inc. I 4y. Kuparuk River Unit fi Kuparuk 2L Pad 2L-320PB2 I 501032062771 I1' UI g I Sperry Drilling I Definitive Survey Report ti g 05 April, 2011 i E H ' sv I I 4.0 LIg i4u� a .u. 3 a HALLIBURTON Sperry Drifting 4,1 fi k Y ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit TVD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site Kuparuk 2L Pad MD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320PB2 Survey Calculation Method: Minimum Curvature Design: 2L-320PB2 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-320 Well Position +N/-S 0.00 ft Northing: 5,927,644.53 ft Latitude: 70°12'47.763 N +EI-W 0.00 ft Easting: 460,858.89 ft Longitude: 150°18'56.399 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.90ft j Wellbore 2L-320PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 1/18/2011 16.68 79.67 57,371 Design 2L-320PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,144.69 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 40.95 0.00 0.00 115.66 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,483.00 2L-320 Gyro(2L-320PB1) CB-GYRO-SS Camera based gyro single shot 12/31/2010 12. 1,526.44 2,706.47 2L-320 MWD(R100)(2L-320PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/1/2011 12:0C 2,790.11 7,144.69 2L-320 MWD(R200)(2L-320PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/8/2011 12:0C 7,246.00 11,219.48 2L-320(R400)(2L-320PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/26/2011 12:C Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°11001 (ft) Survey Tool Name 40.95 0.00 0.00 40.95 -114.90 0.00 0.00 5,927,644.53 460,858.89 0.00 0.00 UNDEFINED 100.00 0.33 84.28 100.00 -55.85 0.02 0.17 5,927,644.55 460,859.06 0.56 0.15 CB-GYRO-SS(1) 165.00 1.15 107.76 164.99 9.14 -0.16 0.98 5,927,644.37 460,859.87 1.32 0.95 CB-GYRO-SS(1) 254.00 1.32 121.22 253.97 98.12 -0.97 2.70 5,927,643.55 460,861.59 0.38 2.86 CB-GYRO-SS(1) 351.00 1.62 121.02 350.94 195.09 -2.25 4.83 5,927,642.26 460,863.72 0.31 5.33 CB-GYRO-SS(1) I I 440.00 2.18 111.76 439.89 284.04 -3.53 7.48 5,927,640.97 460,866.36 0.72 8.27 CB-GYRO-SS(1) 535.00 2.59 108.96 534.81 378.96 -4.90 11.19 5,927,639.58 460,870.06 0.45 12.21 CB-GYRO-SS(1) 627.00 3.22 118.88 626.69 470.84 -6.82 15.42 5,927,637.64 460,874.28 0.87 16.85 C8-GYRO-SS(1) 1 724.00 4.73 124.16 723.46 567.61 -10.38 21.12 5,927,634.04 460,879.95 1.60 23.53 CB-GYRO-SS(1) 819.00 8.46 127.81 817.81 661.96 -16.87 29.88 5,927,627.51 460,888.69 3.95 34.24 CB-GYRO-SS(1) 915.00 14.69 132.07 911.81 755.96 -29.36 44.51 5,927,614.94 460,903.25 6.55 52.84 CB-GYRO-SS(1) 4/5/2011 12:59:43PM Page 2 COMPASS 2003.16 Build 69 GonocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit TVD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad MWD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320PB2 Survey Calculation Method: Minimum Curvature Design: 2L-320PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 960.00 15.36 131.75 955.28 799.43 -37.16 53.19 5,927,607.11 460,911.89 1.50 64.04 CB-GYRO-SS(1) P 1,007.00 14.59 132.53 1,000.68 844.83 -45.30 62.20 5,927,598.91 460,920.85 1.69 75.68 CB-GYRO-SS(1) 1,102.00 13.97 129.16 1,092.74 936.89 -60.63 79.91 5,927,583.49 460,938.48 1.09 98.28 CB-GYRO-SS(1) h 1,197.00 13.71 129.77 1,184.99 1,029.14 -75.08 97.45 5,927,568.96 460,955.95 0.31 120.35 CB-GYRO-SS(1) 1,292.00 14.90 126.21 1,277.04 1,121.19 -89.49 115.96 5,927,554.45 460,974.38 1.56 143.28 CB-GYRO-SS(1) 1,388.00 17.10 121.82 1,369.32 1,213.47 -104.23 137.92 5,927,539.60 460,996.26 2.61 169.45 CB-GYRO-SS(1) 1,483.00 18.33 123.05 1459.81 1,303.96 -119.74 162.31 5,927,523.97 461,020.56 1.35 198.15 CB-GYRO-SS(1) 1,526.44 18.21 120.12 1,501.06 1,345.21 -126.87 173.90 5,927,516.77 461,032.12 2.13 211.69 MWD+IFR-AK-CAZ-SC(2) 1,625.40 21.61 121.51 1,594.10 1,438.25 -144.16 202.82 5,927,499.34 461,060.95 3.47 245.25 MWD+IFR-AK-CAZ-SC(2) 1,724.63 26.65 120.77 1,684.63 1,528.78 -165.11 237.55 5,927,478.21 461,095.56 5.09 285.62 MWD+IFR-AK-CAZ-SC(2) 1,821.04 32.12 120.40 1,768.60 1,612.75 -189.16 278.26 5,927,453.95 461,136.14 5.68 332.73 MWD+IFR-AK-CAZ-SC(2) 1,865.48 33.22 121.66 1,806.01 1,650.16 -201.53 298.81 5,927,441.48 461,156.63 2.91 356.61 MWD+IFR-AK-CAZ-SC(2) 1,915.34 34.45 122.10 1,847.43 1,691.58 -216.19 322.39 5,927,426.70 461,180.12 2.52 384.21 MWD+IFR-AK-CAZ-SC(2) 2,009.93 37.07 124.24 1,924.18 1,768.33 -246.46 368.63 5,927,396.20 461,226.20 3.07 439.00 MWD+IFR-AK-CAZ-SC(2) 2,104.95 39.99 122.44 1,998.51 1,842.66 -278.96 418.08 5,927,363.44 461,275.49 329 497.65 MWD+IFR-AK-CAZ-SC(2) 2,198.85 43.73 120.23 2,068.43 1,912.58 -311.49 471.61 5,927,330.63 461,328.84 4.28 559.99 MWD+IFR-AK-CAZ-SC(2) 2,292.79 49.05 118.82 2,133.21 1,977.36 -344.97 530.79 5,927,296.85 461,387.84 5.77 627.82 MWD+IFR-AK-CAZ-SC(2) 2,336.84 49.65 118.67 2,161.90 2,006.05 -361.04 560.09 5,927,280.63 461,417.05 1.39 661.20 MWD+IFR-AK-CAZ-SC(2) 2,387.60 50.51 119.09 2,194.47 2,038.62 -379.84 594.18 5,927,261.65 461,451.04 1.81 700.06 MWD+IFR-AK-CAZ-SC(2) 2,432.85 52.56 118.18 2,222.62 2,066.77 -396.82 625.28 5,927,244.52 461,482.04 4.80 735.44 MWD+IFR-AK-CAZ-SC(2) 2,483.66 56.45 118.10 2,252.12 2,096.27 -416.32 661.75 5,927,224.83 461,518.41 7.66 776.77 MWD+IFR-AK-CAZ-SC(2) 2,530.68 58.11 117.70 2,277.53 2,121.68 -434.83 696.71 5,927,206.14 461,553.27 3.60 816.29 MWD+IFR-AK-CAZ-SC(2) 2,575.11 59.23 117.16 2,300.63 2,144.78 -452.31 730.39 5,927,188.49 461,586.86 2.73 854.23 MWD+IFR-AK-CAZ-SC(2) 2,665.45 64.61 115.86 2,343.14 2,187.29 -487.86 801.70 5,927,152.58 461,657.98 6.09 933.89 MWD+IFR-AK-CAZ-SC(2) 2,706.47 66.33 114.91 2,360.17 2,204.32 -503.85 835.41 5,927,136.41 461,691.60 4.69 971.21 MWD+IFR-AK-CAZ-SC(2) 2,790.11 68.87 116.88 2,392.05 2,236.20 -537.63 904.96 5,927,102.27 461,760.97 3.74 1,048.52 MWD+IFR-AK-CAZ-SC(3) 2,886.54 72.87 117.07 2,423.64 2,267.79 -578.95 986.14 5,927,060.54 461,841.92 4.15 1,139.59 MWD+IFR-AK-CAZ-SC(3) 2,980.63 76.90 117.14 2,448.17 2,292.32 -620.33 1,066.98 5,927,018.75 461,922.54 4.28 1,230.37 MWD+IFR-AK-CAZ-SC(3) 3,075.46 76.97 117.09 2,469.61 2,313.76 -662.43 1,149.20 5,926,976.22 462,004.54 0.09 1,322.72 MWD+IFR-AK-CAZ-SC(3) 3,170.09 76.74 117.50 2,491.13 2,335.28 -704.69 1,231.09 5,926,933.55 462,086.20 0.49 1,414.83 MWD+IFR-AK-CAZ-SC(3) 3,265.06 76.63 117.46 2,513.00 2357.15 -747.33 1,313.08 5,926,890.48 462,167.96 0.12 1,507.20 MWD+IFR-AK-CAZ-SC(3) 3,359.55 77.11 116.41 2,534.46 2,378.61 -789.01 1,395.12 5,926,848.38 462,249.77 1.20 1,599.20 MWD+IFR-AK-CAZ-SC(3) 3,452.77 76.56 116.61 2,555.70 2,399.85 -829.53 1,476.35 5,926,807.45 462,330.77 0.63 1,689.96 MWD+IFR-AK-CAZ-SC(3) 3,547.24 76.27 116.88 2,577.89 2,422.04 -870.85 1,558.35 5,926,765.70 462,412.55 0.41 1,781.77 MWD+IFR-AK-CAZ-SC(3) 3,642.29 76.49 114.99 2,600.27 2,444.42 -911.25 1,641.42 5,926,724.88 462,495.41 1.95 1,874.14 MWD+IFR-AK-CAZ-SC(3) 3,737.88 76.39 115.26 2,622.68 2,466.83 -950.70 1,725.55 5,926,684.99 462,579.32 0.29 1,967.06 MWD+IFR-AK-CAZ-SC(3) 3,832.19 76.63 113.53 2,644.68 2,488.83 -988.58 1,809.07 5,926,646.69 462,662.64 1.80 2,058.74 MWD+IFR-AK-CAZ-SC(3) 3,926.35 76.66 114.22 2,666.43 2,510.58 -1,025.66 1,892.84 5,926,609.18 462,746.21 0.71 2,150.31 MWD+IFR-AK-CAZ-SC(3) 4,020.84 76.55 114.51 2,688.32 2,532.47 -1,063.58 1,976.57 5,926,570.83 462,829.73 0.32 2,242.21 MWD+IFR-AK-CAZ-SC(3) 4,116.18 76.59 112.61 2,710.47 2,554.62 -1,100.65 2,061.57 5,926,533.33 462,914.53 1.94 2,334.87 MWD+IFR-AK-CAZ-SC(3) 4/5/2011 12:59:43PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit TVD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad PMD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320PB2 Survey Calculation Method: Minimum Curvature Design: 2L-320PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,210.92 76.38 112.58 2,732.61 2,576.76 -1,136.04 2,146.62 5,926,497.50 462,999.38 0.22 2,426.86 MWD+IFR-AK-CAZ-SC(3) 4,305.97 76.36 112.88 2,755.01 2,599.16 -1,171.73 2,231.82 5,926,461.37 463,084.39 0.31 2,519.11 MWD+IFR-AK-CAZ-SC(3) 4,401.06 76.18 112.82 2,777.58 2,621.73 -1,207.60 2,316.94 5,926,425.06 463,169.32 0.20 2,611.37 MWD+IFR-AK-CAZ-SC(3) 4,492.57 76.08 113.02 2,799.51 2,643.66 -1,242.20 2,398.77 5,926,390.04 463,250.96 0.24 2,700.11 MWD+IFR-AK-CAZ-SC(3) 4,584.88 76.00 113.22 2,821.78 2,665.93 -1,277.37 2,481.16 5,926,354.44 463,333.15 0.23 2,789.61 MWD+IFR-AK-CAZ-SC(3) 4,682.94 75.90 113.30 2,845.59 2,689.74 -1,314.94 2,568.55 5,926,316.43 463,420.34 0.13 2,884.65 MWD+IFR-AK-CAZ-SC(3) 4,778.33 75.86 113.49 2,868.86 2,713.01 -1,351.67 2,653.46 5,926,279.26 463,505.05 0.20 2,977.09 MWD+IFR-AK-CAZ-SC(3) 4,868.88 75.84 113.53 2,891.00 2,735.15 -1,386.70 2,733.97 5,926,243.82 463,585.37 0.05 3,064.83 MWD+IFR-AK-CAZ-SC(3) 4,968.35 75.80 113.13 2,915.36 2,759.51 -1,424.89 2,822.52 5,926,205.17 463,673.72 0.39 3,161.19 MWD+IFR-AK-CAZ-SC(3) 5,061.70 75.69 113.38 2,938.35 2,782.50 -1,460.61 2,905.65 5,926,169.02 463,756.65 0.29 3,251.58 MWD+IFR-AK-CAZ-SC(3) 5,155.29 75.69 113.27 2,961.48 2,805.63 -1,496.52 2,988.92 5,926,132.69 463,839.73 0.11 3,342.19 MWD+IFR-AK-CAZ-SC(3) 5,248.63 75.62 113.62 2,984.61 2,828.76 -1,532.50 3,071.89 5,926,096.28 463,922.49 0.37 3,432.55 MWD+IFR-AK-CAZ-SC(3) 5,346.43 75.42 112.05 3,009.06 2,853.21 -1,569.25 3,159.16 5,926,059.09 464,009.56 1.57 3,527.13 MWD+IFR-AK-CAZ-SC(3) 5,440.48 75.43 112.44 3,032.73 2,876.88 -1,603.70 3,243.40 5,926,024.20 464,093.62 0.40 3,617.99 MWD+IFR-AK-CAZ-SC(3) 5,536.87 75.36 112.53 3,057.04 2,901.19 -1,639.38 3,329.59 5,925,988.08 464,179.61 0.12 3,711.12 MWD+IFR-AK-CAZ-SC(3) 5,628.95 75.31 113.17 3,080.35 2,924.50 -1,673.97 3,411.68 5,925,953.07 464,261.51 0.67 3,800.10 MWD+IFR-AK-CAZ-SC(3) 5,726.48 75.55 111.56 3,104.88 2,949.03 -1,709.88 3,498.97 5,925,916.70 464,348.61 1.62 3,894.33 MWD+IFR-AK-CAZ-SC(3) 5,818.80 75.63 111.58 3,127.86 2,972.01 -1,742.76 3,582.12 5,925,883.40 464,431.58 0.09 3,983.52 MWD+IFR-AK-CAZ-SC(3) 5,913.82 75.58 111.35 3,151.48 2,995.63 -1,776.43 3,667.78 5,925,849.29 464,517.05 0.24 4,075.31 MWD+IFR-AK-CAZ-SC(3) 6,008.39 75.54 111.49 3,175.06 3,019.21 -1,809.88 3,753.03 5,925,815.40 464,602.13 0.15 4,166.64 MWD+IFR-AK-CAZ-SC(3) 6,103.26 75.31 111.76 3,198.94 3,043.09 -1,843.72 3,838.39 5,925,781.13 464,687.30 0.37 4,258.23 MWD+IFR-AK-CAZ-SC(3) 6,198.22 75.10 112.01 3,223.19 3,067.34 -1,877.94 3,923.58 5,925,746.47 464,772.30 0.34 4,349.84 MWD+IFR-AK-CAZ-SC(3) 6,293.47 75.25 110.80 3,247.56 3,091.71 -1,911.54 4,009.31 5,925,712.42 464,857.85 1.24 4,441.66 MWD+IFR-AK-CAZ-SC(3) 6,388.43 75.12 111.48 3,271.84 3,115.99 -1,944.65 4,094.93 5,925,678.87 464,943.29 0.71 4,533.18 MWD+IFR-AK-CAZ-SC(3) 6,483.51 75.09 111.50 3,296.28 3,140.43 -1,978.31 4,180.43 5,925,644.77 465,028.60 0.04 4,624.82 MWD+IFR-AK-CAZ-SC(3) 6,578.07 75.75 111.27 3,320.08 3,164.23 -2,011.68 4,265.64 5,925,610.96 465,113.63 0.74 4,716.08 MWD+IFR-AK-CAZ-SC(3) 6,672.52 75.66 111.91 3,343.41 3,187.56 -2,045.36 4,350.75 5,925,576.85 465,198.55 0.66 4,807.38 MWD+IFR-AK-CAZ-SC(3) 6,766.95 75.57 111.60 3,366.87 3,211.02 -2,079.26 4,435.70 5,925,542.51 465,283.32 0.33 4,898.63 MWD+IFR-AK-CAZ-SC(3) 6,860.96 75.44 111.85 3,390.40 3,234.55 -2,112.95 4,520.25 5,925,508.39 465,367.69 0.29 4,989.44 MWD+IFR-AK-CAZ-SC(3) 6,951.67 75.49 111.83 3,413.16 3,257.31 -2,145.62 4,601.76 5,925,475.30 465,449.02 0.06 5,077.05 MWD+IFR-AK-CAZ-SC(3) 7,050.17 75.44 112.28 3,437.88 3,282.03 -2,181.42 4,690.13 5,925,439.05 465,537.19 0.45 5,172.21 MWD+IFR-AK-CAZ-SC(3) 7,144.69 75.56 111.28 3,461.55 3,305.70 -2,215.37 4,775.11 5,925,404.66 465,621.98 1.03 5,263.51 MWD+IFR-AK-CAZ-SC(3) 7,246.00 73.24 110.69 3,488.79 3,332.94 -2,250.32 4,866.20 5,925,369.24 465,712.89 2.36 5,360.75 MWD+IFR-AK-CAZ-SC(4) 7,336.47 73.99 109.12 3,514.31 3,358.46 -2,279.87 4,947.81 5,925,339.27 465,794.33 1.86 5,447.11 MWD+IFR-AK-CAZ-SC(4) 7,430.72 74.75 108.16 3,539.71 3,383.86 -2,308.87 5,033.81 5,925,309.82 465,880.18 1.27 5,537.19 MWD+IFR-AK-CAZ-SC(4) 7,525.07 76.09 106.43 3,563.46 3,407.61 -2,336.01 5,120.99 5,925,282.23 465,967.21 2.27 5,627.52 MWD+IFR-AK-CAZ-SC(4) 7,613.74 76.60 104.61 3,584.39 3,428.54 -2,359.07 5,204.01 5,925,258.75 466,050.10 2.08 5,712.34 MWD+IFR-AK-CAZ-SC(4) 7,709.52 76.86 104.68 3,606.38 3,450.53 -2,382.64 5,294.20 5,925,234.72 466,140.16 0.28 5,803.84 MWD+IFR-AK-CAZ-SC(4) 7,804.47 76.80 105.47 3,628.01 3,472.16 -2,406.68 5,383.47 5,925,210.21 466,229.29 0.81 5,894.72 MWD+IFR-AK-CAZ-SC(4) 7,900.00 76.86 105.82 3,649.78 3,493.93 -2,431.77 5,473.05 5,925,184.67 466,318.72 0.36 5,986.32 MWD+IFR-AK-CAZ-SC(4) 4/5/2011 12:59:43PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-320 Project: Kuparuk River Unit TVD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Site: Kuparuk 2L Pad MD Reference: Rig:2L:320 @ 155.85ft(D15(40.95+114.90)) Well: 2L-320 North Reference: True Wellbore: 2L-320PB2 Survey Calculation Method: Minimum Curvature Design: 2L-320PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 7,993.24 76.93 106.24 3,670.92 3,515.07 -2,456.84 5,560.33 5,925,159 14 466,405.86 0.45 6,075.85 MWD+IFR-AK-CAZ-SC(4) 8,089.13 76.48 107.00 3,692.97 3,537.12 -2,483.53 5,649.75 5,925,131.99 466,495.14 0.90 6,168.01 MWD+IFR-AK-CAZ-SC(4) 8,183.88 76.55 108.52 3,715.07 3,559.22 -2,511.64 5,737.49 5,925,103.43 466,582.72 1.56 6,25927 MWD+IFR-AK-CAZ-SC(4) 8,277.10 77.10 109.29 3,736.31 3,580.46 -2,541.05 5,823.36 5,925,073.58 466,668.43 1.00 6,349.41 MWD+IFR-AK-CAZ-SC(4) 8,367.43 77.18 109.36 3,756.42 3,600.57 -2,570.19 5,906.46 5,925,044.01 466,751.37 0.12 6,436.93 MWD+IFR-AK-CAZ-SC(4) 8,462.75 76.67 109.34 3,777.98 3,622.13 -2,600.95 5,994.07 5,925,012.80 466,838.81 0.54 6,529.22 MWD+IFR-AK-CAZ-SC(4) 8,554.32 76.60 109.66 3,799.15 3,643.30 -2,630.69 6,078.05 5,924,982.63 466,922.62 0.35 6,617.79 MWD+IFR-AK-CAZ-SC(4) 8,651.92 77.05 109.88 3,821.40 3,665.55 -2,662-84 6,167.47 5,924,950.02 467,011.88 0.51 6,712.32 MWD+IFR-AK-CAZ-SC(4) 8,747.01 77.05 109.69 3,842.71 3,686.86 -2,694.20 6,254.68 5,924,918.21 467,098.91 0.19 6,804.51 MWD+IFR-AK-CAZ-SC(4) 8,840.76 76.73 109.81 3,863.97 3,708.12 -2,725.06 6,340.61 5,924,886.91 467,184.67 0.36 6,895.33 MWD+IFR-AK-CAZ-SC(4) 8,936.91 76.54 109.74 3,886.20 3,730.35 -2,756.71 6,428.64 5,924,854.81 467,272.53 0.21 6,988.38 MWD+IFR-AK-CAZ-SC(4) 9,024.94 76.61 110.10 3,906.63 3,750.78 -2,785.88 6,509.14 5,924,825.22 467,352.87 0.41 7,073.58 MWD+IFR-AK-CAZ-SC(4) 9,124.47 76.15 110.04 3,930.07 3,774.22 -2,819.08 6,600.00 5,924,791.56 467,443.54 0.47 7,169.85 MWD+IFR-AK-CAZ-SC(4) 9,222.00 75.85 110.45 3,953.67 3,797.82 -2,851.82 6,688.79 5,924,758.36 467,532.15 0.51 7,264.06 MWD+IFR-AK-CAZ-SC(4) 9,319.84 76.22 110.37 3,977.28 3,821.43 -2,884.93 6,777.77 5,924,724.79 467,620.96 0.39 7,358.61 MWD+IFR-AK-CAZ-SC(4) 9,414.67 76.61 110.83 3,999.55 3,843.70 -2,917.37 6,864.06 5,924,691.91 467,707.06 0.63 7,450.43 MWD+IFR-AK-CAZ-SC(4) 9,510.44 76.67 110.46 4,021.68 3,865.83 -2,950.22 6,951.25 5,924,658.61 467,794.07 0.38 7,543.25 MWD+IFR-AK-CAZ-SC(4) 9,605.72 76.98 110.59 4,043.40 3,887.55 -2,982.75 7,038.13 5,924,625.64 467,880.78 0.35 7,635.65 MWD+IFR-AK-CAZ-SC(4) 9,701.01 76.49 110.47 4,065.26 3,909.41 -3,015.27 7,124.99 5,924,592.67 467,967.46 0.53 7,728.02 MWD+IFR-AK-CAZ-SC(4) 9,795.52 76.47 110.75 4,087.36 3,931.51 -3,047.62 7,211.00 5,924,559.88 468,053.29 0.29 7,819.56 MWD+IFR-AK-CAZ-SC(4) 9,890.32 76.22 110.36 4,109.74 3,953.89 -3,079.96 7,297.25 5,924,527.09 468,139.37 0.48 7,911.31 MWD+IFR-AK-CAZ-SC(4) 9,985.25 75.96 109.88 4,132.56 3,976.71 -3,111.66 7,383.78 5,924,494.95 468,225.72 0.56 8,003.03 MWD+IFR-AK-CAZ-SC(4) 10,081.33 75.85 110.26 4,155.96 4,000.11 -3,143.64 7,471.30 5,924,462.52 468,313.07 0.40 8,095.77 MWD+IFR-AK-CAZ-SC(4) 10,175.24 75.72 110.31 4,179.02 4,023.17 -3,175.20 7,556.69 5,924,430.52 468,398.28 0.15 8,186.40 MWD+IFR-AK-CAZ-SC(4) 10,270.15 75.59 110.12 4,202.53 4,046.68 -3,206.97 7,642.98 5,924,398.30 468,484.40 0.24 8,277.94 MWD+IFR-AK-CAZ-SC(4) 10,365.25 75.46 109.85 4,226.30 4,070.45 -3,238.44 7,729.52 5,924,366.39 468,570.76 0.31 8,369.57 MWD+IFR-AK-CAZ-SC(4) 10,460.48 76.16 110.24 4,249.65 4,093.80 -3,270.09 7,816.25 5,924,334.29 468,657.32 0.84 8,461.45 MWD+IFR-AK-CAZ-SC(4) 10,555.26 76.28 109.69 4,272.22 4,116.37 -3,301.52 7,902.77 5,924,302.42 468,743.66 0.58 8,553.05 MWD+IFR-AK-CAZ-SC(4) 10,650.04 76.16 109.42 4,294.80 4,138.95 -3,332.33 7,989.51 5,924,271.16 468,830.24 0.30 8,644.58 MWD+IFR-AK-CAZ-SC(4) 10,745.12 75.97 109.41 4,317.70 4,161.85 -3,363.00 8,076.54 5,924,240.04 468,917.10 0.20 8,736.31 MWD+IFR-AK-CAZ-SC(4) 10,839.85 76.15 109.66 4,340.52 4,184.67 -3,393.75 8,163.19 5,924,208.85 469,003.58 0.32 8,827.73 MWD+IFR-AK-CAZ-SC(4) 10,934.56 76.29 109.34 4,363.08 4,207.23 -3,424.45 8,249.90 5,924,177.70 469,090.12 0.36 8,919.18 MWD+IFR-AK-CAZ-SC(4) 11,029.46 76.23 109.33 4,385.62 4,229.77 -3,454.97 8,336.88 5,924,146.73 469,176.94 0.06 9,010.80 MWD+IFR-AK-CAZ-SC(4) 11,124.65 75.97 110.28 4,408.49 4,252.64 -3,486.28 8,423.82 5,924,114.98 469,263.70 1.01 9,102.72 MWD+IFR-AK-CAZ-SC(4) 11,219.48 76.11 111.06 4,431.36 4,275.51 -3,518.77 8,509.92 5,924,082.05 469,349.63 0.81 9,194.40 MWD+IFR-AK-CAZ-SC(4) 11,247.00 76.11 111.06 4,437.97 4,282.12 -3,528.37 8,534.85 5,924,072.32 469,374.51 0.00 9,221.03 PROJECTED to TD 4/5/2011 12:59:43PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2L-320 Rig Name: DOYON 15 Job Type: DRILLING ORIGINAL Rig Accept: 12/28/2010 12:00:00 AM Rig Release: 2/26/2011 4:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/26/2010 24 hr Summary Disconnect modules and skid rig floor back. Raise stompers and windwalls. Move sub complex away from well. Move rig mats and lay new herculite. 12:00 15:00 3.00 0 0 MIRU MOVE DMOB P Skid rig floor back. 15:00 16:00 1.00 0 0 MIRU MOVE DMOB P Move pit complex away from sub complex 16:00 17:00 1.00 0 0 MIRU MOVE DMOB P Raise stompers and windwalls 17:00 19:00 2.00 0 0 MIRU MOVE DMOB P Back sub complex away from well 19:00 21:00 2.00 0 0 MIRU MOVE DMOB P Move rig mats and dispose of old herculite 21:00 22:00 1.00 0 0 MIRU MOVE DMOB P Set new herculite down 22:00 00:00 2.00 0 0 MIRU MOVE MOB P Set rig mats down 12/27/2010 Move rig over 2L-320. Skid derrick over well. Hook up diverter lines and berm up around rig 00:00 02:30 2.50 0 0 MIRU MOVE MOB P Lay rig mats 02:30 11:30 9.00 0 0 MIRU MOVE MOB P Move rig to 2L-320. Set derrick complex in position and align pit complex. Begin hooking up lines 11:30 12:00 0.50 0 0 MIRU MOVE SFTY P Safety meeting on skidding derrick 12:00 14:00 2.00 0 0 MIRU MOVE RURD P Replace plywood under stompers with 3"x 12"s 14:00 15:00 1.00 0 0 MIRU MOVE RURD P Skid derrick section into place 15:00 17:00 2.00 0 0 MIRU MOVE RURD P Work in cellar hooking up lines and diverter. Work in pits getting ready to take on mud 17:00 18:00 1.00 0 0 MIRU MOVE RURD P Install top drive guard and continue _working in pits 18:00 00:00 6.00 0 0 MIRU MOVE RURD P Pull master bushing and run 20"riser through rotary table. Make up to hydril. Hook up hole fill line and • drain hoses. Berm up around rig. 12/28/2010 Rig Accepted 0000 HRS 12/28/2010.Wait on weather-45 Deg. Continue rig up with minimal movement of rolling stock,and rig. Perform PM on rig. 00:00 12:00 12.00 0 0 MIRU MOVE RURD T Continue rig up cutting tanks, and winterizing rig with minimal rolling stock movement because of the weather. Perform PM on rig. Held Fire Drill.Crew Change Page 1 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 0 MIRU MOVE RURD T Continue rig up,and winterizing rig with minimal rolling stock movement because of the weather. Perform PM on rig. Inspect wear plate on#2 Mud Pump.Maintenance on Scalper Shakers. Install pipe guide on Top Drive. Crew Change 12/29/2010 Wait on weather-45 Deg.Continue rig up with minimal movement of rolling stock,and rig. Perform PM on rig. 00:00 12:00 12.00 MIRU MOVE RURD T Continue rig up,and winterizing rig with minimal rolling stock movement because of the weather. Perform PM on rig.Crew Change 12:00 00:00 12.00 MIRU MOVE RURD T Continue rig up,and winterizing rig with minimal rolling stock movement because of the weather. Perform PM on rig.Crew Change 12/30/2010 Wait on weather-45 Deg.Continue rig up with minimal movement of rolling stock,and rig. Perform PM on rig.Tempertaure warmed to-35 Deg. Call for trucks. Load Pits with 580 BBLS of 9.0 PPG Spud Mud.Make up 8 stands of 5"DP and rack back same.Spot Halliburton GYRO truck. 00:00 12:00 12.00 0 0 MIRU MOVE RURD T Continue rig up,and winterizing rig with minimal rolling stock movement because of the weather. Perform PM on rig.Crew Change 12:00 19:00 7.00 0 0 MIRU MOVE RURD T Continue rig up,and winterizing rig with minimal rolling stock movement because of the weather. Perform PM on rig. 19:00 20:00 1.00 0 0 MIRU MOVE RURD P Weather warmed to-35 Deg.Call for vac trucks and Gyro. Pull tools to rig --MIRU floor. 20:00 22:45 2.75 0 0 MIRU MOVE RURD P Load pits with 580 BBLS of 9.0 PPG spud mud.Transfer DP stands in derrick. Strap drill pipe. Pick up 24 joints of drill pipe making up stands and racking back same. (8 stands) 22:45 00:00 1.25 0 0 MIRU MOVE RURD P Spot GYRO unit. Prep rig floor,and Koomey for Diverter test.Crew Change 12/31/2010 11. continue soot GYRO unit. Rio up for diverter function test. Knife valve opened in 21 secs.Witness of test r1;��'' waived by AOGCC rep-Chuck Sheve.Tagged on ice plug at 46'from Rotary table.Clean out conductor from 11✓✓�� y 46'to 16"shoe depth of 141 ft from rotary table. Continnue directional drill from 141'-452'MD.TVD-452'. �S`\ Obtain GYRO surveys as planned.ADT=1.63 HRS.AST=.58 HRS Total Bit HRS=2.06 HRS.Total Jar HRS=26.76 HRS. Page 2 of 57 Time Logs, Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 MIRU WHDBO BOPE P Make up one stand of drill pipe. RIH to tag bottom"ice plug"at 46'from rotary table. Pick up verify depth. RIH to locate tool joint. Load hydraulic lines on Kommey to Diverter system. Function to remove air from lines. Perfom Diverter function test with annular closed and knife valve opened in 21 seconds. Perform Koomey test with first 200 PSI in 34 Seconds,and full 3000 PSI in 2 min- 19 seconds.A total of 5 nitrogen bottles with an avg PSI of 2325. 03:00 03:15 0.25 0 0 MIRU DRILL SFTY P Held PJSM with GYRO reps. Discuss safety&hazard recognition issues. Discuss procedure to hang sheaves in derrick,and complete rig up of GYRO unit with tools. Discuss Halliburton JSA. 03:15 04:15 1.00 0 0 MIRU DRILL RURD P Hang sheaves in derrick for GYRO. RU lower sheave. Hang tool string on floor for warm up.Continue spotting Vac trucks and Super suckers for Spud. Load riser with water and verify no leaks with annular or knife valve. Tighten leaks on riser and annular. 04:15 06:30 2.25 0 0 MIRU DRILL RURD P Load lines with mud.Troubleshoot PVT system.Check all alarms. Circulate mud system. Pressure test surface equipment to 2500 PSI. 06:30 07:00 0.50 0 0 MIRU DRILL SFTY P Held PJSM with crew,MI, DD& MWD reps. Discuss safety&hazard recognition issues. Discuss procedure to make up 13 1/2"BHA for spud. 07:00 09:00 2.00 0 0 SURFA( DRILL PULD P MU 13 1/2"Hughes MXL-1X bit jetted for.875 TFA.Make up 8"Sperry Lobe 4/5-5.3 stg motor&UBHO sub and orient to sub. 09:00 09:30 0.50 0 0 SURFA( DRILL WASH P Tag Ice plug @ 46'and wash& rotate through 16"conductor to 141' (shoe depth). 09:30 11:30 2.00 0 215 SURFA( DRILL DDRL P Directional Drill 13 1/2"Hole from 141'-215'MD.TVD=215'. Pumps at 500 GPM's-650 PSI.50 RPM's. Torque on=2K. UP WT=85K.SO WT=85K. ROT WT=85K.ADT= .43 HRS.AST=0 HRS.ART=.43 HRS.Total Bit HRS=.43.Total Jar HRS=25.31. Max gas observed=0 Units. 11:30 12:00 0.50 215 215 SURFA( DRILL SRVY P Blow down Top Drive. Run Gyro Survey. Crew Change 12:00 12:30 0.50 215 215 SURFA( DRILL SFTY P Held PJSM-Pre Spud with new crew, DD&MWD, and MI Rep. Discuss safety&Hazard recognition. Discuss drilling 13 1/2"Surface hole. Page 3 of 57 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 12:30 13:30 1.00 215 303 SURFA( DRILL DDRL P Directional Drill 13 1/2"Hole from 215'-303'MD.TVD=303'. Pumps at 500 GPM's-650 PSI. 50 RPM's. WOB= 10 K.Torque on=2K. UP WT=85K. SO WT=85K. ROT WT =85K.ADT=.43 HRS.AST=0 HRS.ART=.43 HRS.Total Bit HRS = .43.Total Jar HRS=25.31. Max gas observed=0 Units. 13:30 14:30 1.00 303 0 SURFA( DRILL TRIP P POOH rack back 3 stands of HWDP. Pull to bit&inspect same. Lay down UBHO sub. 14:30 18:30 4.00 303 303 SURFA( DRILL PULD P Make up remaining BHA#1 with MWD assembly. 18:30 20:30 2.00 303 303 SURFAC DRILL PULD P Orient Bit to motor with a 246.15 Deg Tool face offset. Plug in and Upload MWD assembly. 20:30 21:30 1.00 303 303 SURFAC DRILL PULD P Continue make up NM Flex DC's and Jars with HWDP. Perform Shallow pulse test with 550 GPM's-1250 PSI. 21:30 00:00 2.50 303 452 SURFA( DRILL DDRL P Directional Drill 13 1/2"Hole from 303'-452'MD.TVD=452'. Pumps at 500 GPM's-1080 PSI. 50 RPM's. WOB= 10 K.Torque on=2K. UP WT= 100K. SO WT=103K. ROT WT=100K.ADT=1.63 HRS.AST =.58 HRS.ART=1.05 HRS.Total Bit HRS=2.06.Total Jar HRS= 26.76. Max gas observed=24 Units. Crew Change 01/01/2011 Continue directional Drill 13 1/2"Surface hole form 452'-1872'MD.TVD= 1786'.Obtain Gyro surveys as needed through depth of 1483'.Qbserveduo to 4000iJnit&of hydrates from 1300-1500'MD,and heavy clay balls on shakers.ADT=11.01 HRS.AST=4.36 HRS.Total Bit HRS= 11.01.Total Jar HRS=35.71. Phase 2 Weather Conditions 00:00 06:00 6.00 452 826 SURFA( DRILL DDRL P Directional Drill 13 1/2"Hole from 453'-826'MD.TVD=824'. Pumps at 500 GPM's-1000 PSI. 50 RPM's. WOB=10 K.Torque on=2K. UP WT= 112K. SO WT=112K. ROT WT=112K.ADT=2.68 HRS.AST =1.46 HRS.ART=1.22 HRS.Total Bit HRS=4.74.Total Jar HRS= 29.44. Max gas observed=76 Units. 06:00 12:00 6.00 826 1,112 SURFA( DRILL DDRL P Directional Drill 13 1/2"Hole from 826'-1112'MD.TVD= 1100'. Pumps at 550 GPM's-1200 PSI. 50 RPM's.WOB=10-18 K.Torque on =3K. UP WT= 120K.SO WT= 120K. ROT WT= 120K.ADT= 1.15 HRS.AST= .14 HRS.ART= 1.01 HRS.Total Bit HRS=6.4.Total Jar HRS=31.1. Max gas observed= 3628 Units.Crew Change Page 4 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 1,112 1,490 SURFAt DRILL DDRL P Directional Drill 13 1/2"Hole from 1112'-1490'MD.ND= 1466'. Pumps at 550 GPM's-1590 PSI.50 RPM's.WOB=18-20 K.Torque on =4K. UPWT= 123K. SOWT= 123K. ROT WT= 123K.ADT=2.56 HRS.AST=.74 HRS.ART=1.82 HRS.Total Bit HRS=8.96.Total Jar HRS=33.66.Max gas observed= 2252 Units. 18:00 00:00 6.00 1,490 1,872 SURFAt DRILL DDRL P Directional Drill 13 1/2"Hole from 1490'-1872'MD.ND= 1786'. Pumps at 550 GPM's-1650 PSI. 50 RPM's.WOB=18-25 K.Torque on =4-5K. UP WT= 130K.SO WT= 128K. ROT WT= 128K.ADT=2.05 HRS.AST=.93 HRS.ART=1.12 HRS.Total Bit HRS=11.01.Total Jar HRS=35.71. Max gas observed =454 Units.Crew Change 01/02/2011 Continue directional Drill 13 1/2"Surface hole from 1872'-2248'MD.ND=2102'.Gyro survey Unit released at 0130 HRS,at depth of 1800'.Observed up to 1131 Units with continued heavy clay balls on shakers.ADT =3.3 HRS.AST=1.22 HRS.Total Bit HRS=14.31.Total Jar HRS=39.01. Observed Phase 3 Weather& Road conditions.Truck movement stopped. Stopped drilling at 0700 HRS. Circulate to clean hole and slow pumps to 3 BPM while slowly reciprocate drill string. Rack back stand#17&#18 and repeat. Perform tabletop drills,and review guidelines. 00:00 07:00 7.00 1,872 2,248 SURFAt DRILL DDRL P Directional Drill 13 1/2"Hole from 1872'-2248'MD.TVD=2102'. Pumps at 650 GPM's-2250 PSI.50 RPM's.WOB= 15-20 K.Torque on =6-8K. UP WT=131K.SO WT= 130K. ROT WT=130K.ADT=3.30 HRS.AST= 1.22 HRS.ART=2.08 HRS.Total Bit HRS=14.31.Total Jar HRS=39.01.Max gas observed =1131 Units. 07:00 12:00 5.00 2,248 2,248 SURFA( DRILL CIRC T Observed Phase 3 weather&road conditions.Support truck movement stopped. Pull one stand,circulate hole clean,then slow pumps to 3 BPM-200 PSI while reciprocate drill string. Perform Tabletop Drills and review guidelines. Crew Change 12:00 00:00 12.00 2,248 2,248 SURFAt DRILL CIRC T Phase 3 weather&road conditions continued. Pull stands#17&#18, and repeat procedure to circulate hole clean.Then slow pumps to 3 BPM while reciprocate drill string. Perform Tabletop Drills and review guidelines. Crew Change 01/03/2011 Continue wait on Phase 3 weather and road conditions. Reciprocate drill string while pump at 3 BPM-200 PSI until 0700 HRS. Phase conditions lifted to Phase 2.Continue directional drill 13 1/2"surface hole form 2248'-2755'MD.ND=2378'. Section cut short from plan as per Geologist.Circulate&condition mud. BROOH from TD to 1300'at 30-40 ft/min with no issues.Trip back in.Wash&ream down last 4 stands. Circulate&condition mud.Total Bit HRS= 16.56.Total Jar HRS=41.26. Max gas observed-366 units. Page 5 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 07:00 7.00 2,248 2,248 SURFA( DRILL CIRC T Phase 3 weather&road conditions continued. Pull stand#19,and repeat procedure to circulate hole clean.Then slow pumps to 3 BPM while reciprocate drill string. Perform Tabletop Drills and review guidelines. 07:00 12:00 5.00 2,248 2,532 SURFA( DRILL DDRL P Directional Drill 13 1/2"Hole from 2248'-2532'MD.ND=2277'. Pumps at 650 GPM's-2000 PSI.60 RPM's.WOB=20-25 K.Torque on =6-8K. UP WT=140K.SO WT= 130K. ROT WT=134K.ADT=2.25 HRS.AST=1.27 HRS.ART=.98 HRS.Total Bit HRS=16.56.Total Jar HRS=41.26.Max gas observed =366 Units.Crew Change 12:00 18:00 6.00 2,532 2,755 SURFA( DRILL DDRL P Directional Drill 13 1/2"Hole from 2532'-2755'MD.ND=2378'. Pumps at 650 GPM's-2080 PSI.60 RPM's.WOB=25-30 K.Torque on =6-8K. UP WT=140K.SO WT= 130K. ROT WT= 135K.ADT=2.06 HRS.AST= 1.33 HRS.ART=.73 HRS.Total Bit HRS=18.62.Total Jar HRS=43.32.Max gas observed =55 Units.This section TD'd earlier than plan as per Geologist. 18:00 18:30 0.50 2,755 2,755 SURFA( DRILL CIRC P Circulate&condition mud with pumps at 650 GPM's-2100 PSI. Reciprocate&rotate drill string. Service swivel packing on Top Drive. 18:30 22:00 3.50 2,755 1,300 SURFA( DRILL REAM P BROOH at 30-30 FT/Min at full drilling rate from TD to 1300'slowing pumps to 450 GPM's coming into the permafrost.Observed max gas at 1003 Units. 22:00 22:30 0.50 1,300 1,300 SURFA( DRILL OWFF P Monitor well-static. Blow down Top Drive&inspect Top Drive Guard. 22:30 23:30 1.00 1,300 2,534 SURFA( DRILL TRIP P Trip back in hole form 1300'to 2534' with no issues.observed proper displacement&good hole conditions. 23:30 00:00 0.50 2,534 2,630 SURFA( DRILL REAM P Wash&ream dowm last 4 stands to 2630'. Attempt to wipe 7.5 Deg DL @ 2534'with no success. Obtain checkshot surveys. Observed max gas @ 1594 Units on bottoms up. Hole looked good.Crew Change 01/04/2011 Continue wash&ream down to TD after short trip.Circulate Nut Plug sweep&condition mud.Observed sweep back on calculated strokes. POOH on elevators. No Hole issues. Breakout&lay down BHA, lnpsect &grade bit to 1/2/CT/G/1/1/16"/ER/TD.Clean&clear rig floor. Rig up casing crew. Held PJSM. Make up 10 3/4"Shoe track assembly,check floats.Continue run casing to TD.Make up casing hanger and landing joint. Land on ring. UP WT-205K,SO WT 145K. Observed good hole conditions and proper displacement. Observed up to 1200 units of gas while run in hole.Circulate while run in hole at depths of 1200',2100'. Make up torque on casing aver a 8800 ft'lbs. 00:00 00:30 0.50 2,630 2,755 SURFA( DRILL REAM P Continue wash&ream down to TD @ 2755'MD. Page 6 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:45 1.25 2,755 2,755 SURFA( DRILL CIRC P Circulate&condition mud, pumping a 50 BBL, nut plug sweep with 10 PPB at 11.4 PPG. Pumps at 650 GPM's-2100 PSI. Reciprocate& rotate drill string.Observed no measurable increase in cuttings when sweep back,with sweep coming back on calculated strokes indicating a gauged hole. 01:45 02:00 0.25 2,755 2,755 SURFA( DRILL OWFF P Monitor well-Static. Prepare to POOH. 02:00 02:30 0.50 2,755 2,275 SURFA( DRILL TRIP P POOH first 5 stands with proper displacement,and good hole conditions. 02:30 03:00 0.50 2,275 2,275 SURFA( DRILL CIRC P Pump Dry job,blow down Top Drive. 03:00 05:30 2.50 2,275 545 SURFA( DRILL TRIP P POOH on elevators at 40-50 FT/MIN, observing good hole condition and proper displacement. Observed some swabbing closer to surface. Suspect BHA packed off with clay.Work string to allow to clean up and POOH.Monitor well at BHA-static. 05:30 07:30 2.00 545 100 SURFA( DRILL TRIP P Rack back HWDP. Continue POOH breakout&lay down BHA. 07:30 08:30 1.00 100 100 SURFA( DRILL TRIP P Plug in and download MWD assembly. 08:30 11:00 2.50 100 0 SURFA( DRILL PULD P Continue breakout&lay down BHA. Observed BHA&Bit packed off with clay. Flush motor with water. Inspect &grade bit to 1/2/CT/G/1/1/16"/ER/ TD. 11:00 11:30 0.50 0 0 SURFA( DRILL PULD P Lay down Tools.Send out stabilizers bit&breaker etc... V/ 11:30 12:00 0.50 0 0 SURFA( DRILL PULD P Clean&clear rig floor area.Crew Change 12:00 12:15 0.25 0 0 SURFA( CASING SFTY P Held PJSM with crew. Discuss safety&hazard recognitionissues. Discuss procedure to rig up and run casing. 12:15 14:30 2.25 0 0 SURFA( CASING RURD P Rig up casing running equipment. Remove short bales form Top Drive. Install long bales. Make up Franks fill up tool. Inspect and rig up casing stabbing board. 14:30 19:30 5.00 0 1,200 SURFA( CASING RNCS P Make up 10 3/4"shoe track assembly. Baker Loc shoe track. Check Floats. Make up torque average=8800 FT/LBS.Continue run casing observing set down at 450'.Wash through with 10-15 K set down.Continue run casing with no hole issues to 1200'. 19:30 20:30 1.00 1,200 1,200 SURFA( CASING CIRC P With Franks Fill up tool,circulate bottoms up staging to 3 BPM-160 PSI.Observed 1200 Units of gas. UP WT=135K, SO WT=118K. Reciprocate casing string. Page 7 of 57 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:30 00:00 3.50 1,200 2,745 SURF/NC CASING RNCS P Continue run casing to 2700'witno hole issues, breaking circulation at 2100'..Make up casing hanger and landing joint. RIH,while circulating at 3 BPM to land on ring. UP WT- 205K,SO WT=145K.Casing shoe at 2745'MD.Crew Change 01/05/2011 Breakdown Franks Fill Up tool. Rig up cement head&lines. Break circulation staging pumps to 6 BPM-180 PSI. Reciprocate casing string 20-25'increments Spot&rig up trucks,and cementers. Held PJSM.Circulate &condition mud staging pumps to 6 BPM-330 PSI. UP WT=205K, SO WT=145K.Turn over to //4 Schlumberger. Pump 10 BBLS of CW101 pressure test lines to 3000 PSI-good test.Mix and pump 40 bbls CW 101 Chem Wash, Pump 50 BBLs of 10.5 PPG Mud push with Red Dye.Turn over to 10.85 PPG Lead /• eY Cement,pump 339 bbls'Lead Cement, Switch To Tail Cement 85.4 bbl's pumped 12.0 Tail Cement. (� Dropped top plug and pumped 10 Bbls water.Switch to rig pumps and displace with Oil Base Mud. Bumped plug at 246 bbl's pumped for displacement.86 bbl's cement to surface CIP 07:10.Full returns and reciprocation throughout job. Reciprocated casing string 20'-30'increments with good movement during cementing operations. Rig down cement head and equipment. RD riser&diverter system. 00:00 01:00 1.00 2,745 2,745 SURFAt CASING RURD P Breakout&lay down Franks fill up tool.Make up Schlumberger cement head&lines. 01:00 04:30 3.50 2,745 2,745 SURFAt CEMEN"CIRC P Break circulation and stage pumps to 6 BPM-180 PSI,while reciprocate casing string in 20-25' increments. UP WT=205K,SO WT =145K.Spot all trucks and cement units. Load pits with OBM for displacement. 04:30 05:00 0.50 2,745 2,745 SURFAt CEMENT SFTY P Held PJSM with crew,Cementers, and all truck drivers.Assign Spill Champions,and discuss saftey& hazard recognition issues. Discuss cementing procedure. Continue reciprocate casing string, with pre-cement mudproperties of 9.4 PPG,YP-26 and Funnel Visc of 98. Batch Mix mud push,and prep for job. UP WT=205K,SO WT=145K. 05:00 06:30 1.50 2,745 2,745 SURFA(CEMENT CMNT P Turn over to Schlumberger. Pump 10 BBLS of CW101 pressure test lines to 3000 PSI-good test. Mix and pump 40 bbls CW 101 Chem Wash, Pump 50 BBLs of 10.5 PPG Mud push with Red Dye.Turn over to 10.85 PPG Lead Cement, pump 339 bbls'Lead Cement, Switch To Tail Cement 85.4 bbl's pumped 12.0 Tail Cement. Dropped top plug and pumped 10 Bbls water. Page 8 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:30 1.00 2,745 2,745 SURFA( CEM EN'CMNT P Switch to rig pumps and displace with Oil Base Mud. Bumped plug at 246 bbl's pumped for displacement. 86 bbl's cement to surface CIP 07:10. Full returns and reciprocation throughout job. Reciprocated casing string 20'-30' increments with good movement during cementing operations. 07:30 11:00 3.50 0 0 SURFA(CEMEN'RURD P Held PJSM. Rig down all cementing equipment&lines. Back out&lay down landing joint. Drain OBM from landing joint. 11:00 12:00 1.00 0 0 SURFA( CASING RURD P Clean up OBM on rig floor.Send out all casing running equipment.Crew Change 12:00 19:00 7.00 0 0 SURFA(WHDBO NUND P Continue lay down all casing running equipment.Clean drip pan from spud mud. Nipple down Riser and diverter system and knife valve. Nipple down speed head.Clean cement from annular&function annular bag. Nipple down 100'section of buoy line.Clean pits for bringing on OBM. 19:00 22:30 3.50 0 0 SURFA(WHDBO NUND P Nipple up casing&tubing spools as per FMC rep.Test metal to metal seal to 1000 PSI-15 minutes. Continue clean pits. Unload 10 3/4" caisng from pipe shed,and load 132 jnioints of 5"DP. 22:30 00:00 1.50 0 0 SURFA(WHDBO NUND P Continue NU tighten flanges with sweny wrench.Set 13 5/8" x 11" adapter. Prep riser for picking up. Continue clean pits and rockwasher. Remove diverter system,knife valve and speed head from cellar.Crew change 01/06/2011 Continue ND Diverter system. NU Casing&tubing spools.Test same to 1000 PSI-15 minutes. NU BOP stack&lines. Remove equipment from cellar. Load pipe shed with 5"DP. Install test joint and plug.Test BOP's to 3500/250 PSI.Test choke manifold,and all floor safety valves.Witness of test waived by AOGCC rep Jeff Jones. RD Test equipment. Install WB. RILDS. Install bales on Top Drive. 00:00 03:00 3.00 0 0 SURFA(WHDBO NUND P Continue NU BOP stack,choke& kill lines. Remove equipment from cellar. Load pipe shed.Cleaning pits. Install 13 5/8"x 11 adapter flange. 03:00 11:00 8.00 0 0 SURFA(WHDBO NUND P Set BOP stack on riser.Torque casing&tubing spools.Torque adapter flange. Install bell nipple& flowline. Make up choke&kill lines. Grease choke manifold. Prep to test. Continue load pipe shed and clean pits.Obtain RKB's. Record same. 11:00 11:30 0.50 0 0 SURFA(WHDBO BOPE P Install second annulus valve.Make up test joint&plug. RIH set same. 11:30 12:00 0.50 0 0 SURFA(WHDBO NUND P Open ram doors. Begin change rams to 5"solid body.Crew Change Page 9 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 0 0 SURFA(WHDBO NUND P Complete installation of 5"solid body rams in lower set. 14:00 15:30 1.50 0 0 SURFA(WHDBO BOPE P Rig up test equipment. Inspect test joint. Blow air through choke manifold. Function valves. Fill stack &lines with water. 15:30 21:00 5.50 0 0 SURFA(WHDBO BOPE P Test BOP stack.test Blinds,both sets of rams to 250/3000 PSI.Tets annular to 250/2500 PSI.Continue test choke manifold and all valves. Test floor safety valves. Record all tests on chart. Perform Koomey test. First 200 PSI increase in 50 secs, with full 3000 PSI in 200 secs. Observed 5 nitrogen bottles with 2425 avg pressure. 21:00 21:30 0.50 0 0 SURFA(WHDBO BOPE P Rig down all test equipment. Blow down lines. Line up choke manifold and stack to dril. 21:30 22:00 0.50 0 0 SURFA(WHDBO OTHR P Install wear bushing. RILDS. 22:00 00:00 2.00 0 0 SURFA( DRILL RURD P Install short bales on top drive. Adjust same for tilt. Install 5"DP elevators.Move 3 stands of HWDP from ODS to DS.Crew Change 01/07/2011 Pick up 5"DP from shed. Make up stands and rack back in derrick.Service rig. Stand back a total of 126 Stands. Slip&Cut drilling line. Held PJSM. Begin make up BHA. Make up 9 7/8"Hycalog DTX619M bit jetted for a TFA of 1.035 sq. in.Continue make up MWD assembly to the flex collar. Plug in to upload.Observed temperature of Nuke Collar too cold to read.Steam collar. 00:00 01:30 1.50 0 0 SURFA( DRILL PULD P Pick up 5"drill pipe from shed.Make up stands and rack back in derrick. 01:30 02:30 1.00 0 0 SURFA( RIGMNT SVRG P Service Top drive Draw works,and Iron roughneck. 02:30 03:30 1.00 0 0 SURFA( DRILL RGRP T Observed pipe machine down. Repair forward sprocket shaft on skate. 03:30 12:00 8.50 0 0 SURFA(DRILL PULD P Continue pick up 5"drill pipe from shed. Make up stands and rack back in derrick. Racked back a total of 63 stands.Crew Change 12:00 16:30 4.50 0 0 SURFA( DRILL PULD P Continue pick up 5"drill pipe from shed.Make up stands and rack back in derrick. Racked back a total of 28 stands.Total in derrick=126 Stands. 16:30 17:00 0.50 0 0 SURFA( DRILL PULD P Pull mouse hole form rotary table. Clean&clear rig floor. Send out all thread protectors. 17:00 17:30 0.50 0 0 SURFA( RIGMN1SFTY P Held PJSM with crew. Discuss safety&hazard recognition issues. Discuss procedure to slip&cut drilling line. 17:30 20:00 2.50 0 0 SURFA( RIGMNT SLPC P Hang Blocks.Slip&cut 60'of drilling line. Inspect brakes,deadman,and chains on draw works. Page 10 of 57 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:00 20:15 0.25 0 0 SURFA( DRILL SFTY P Held PJSM with crew,and Sperry Sun reps. Discuss safety&hazard recognition issues. Discuss procedure to make up BHA. 20:15 22:30 2.25 0 138 SURFA( DRILL PULD P Make up 9 7/8"Hycalog DTX619M PDC bit on SperryDrill lobe 7/8-6.0 stage motor.Orient to MWD. Continue make up MWD assembly making up Float collar, Integral blade stabilizer, PDDC collar, MWD assembly and nuke collar. Pick up one flex colar. 22:30 23:30 1.00 138 138 SURFA( DRILL PULD T Plug into upload MWD assembly. Observed Nuke collar at 40 deg temperature,too cold to read. use steam hose to warm tool. reattempt to upload with no success-too cold. 23:30 00:00 0.50 138 138 SURFA( DRILL PULD T Tools too cold to read.Make up top drive&circulate warm OBM mud through assembly to warm tools. 01/08/2011 Continue warm Nuke Collar. Plug in and Upload same.Continue make up BHA with Commander valve. Function test same,opening valve and closing.TIH picking up singles of 5"DP from shed to FC.CBU& Perform casing test to 3000 PSI-30 Min. Record on chart. Drill out shoe track plus 20'of new hole to 2775' MD.2384'TVD. Peform FIT test to 16.8 PPG EMW.Obtain SPR's. Directional drill 9 7/8"production hole to 4059'MD.ND=2697'.ADT=6.70 HRS.Total Bit HRS=6.70 HRS.Total Jar HRS=49.40. Max gas observed=2367 Units. ECD's at 9.78 PPG. 00:00 00:30 0.50 138 138 SURFA( DRILL PULD P Continue warm Nuke collar pumping wram OBM mud through assembly. Plug in and complete upload. 00:30 01:00 0.50 138 138 SURFA( DRILL DHEQ P Pulse test MWD at 650 GPMs- 1590 PSI. Good test. 01:00 01:15 0.25 138 138 SURFA( DRILL PULD P Held PJSM with Crew&MWD reps. Discuss safety&hazard recognition issues. Discuss installation of nukes in assembly. Install signs,clear floor area. 01:15 01:30 0.25 138 138 SURFA( DRILL PULD P Install Nuke sources in collar. 01:30 03:00 1.50 138 662 SURFA( DRILL PULD P Continue make up BHA, installing jars, HWDP and well commmander valve. 03:00 03:30 0.50 662 662 SURFA( DRILL DHEQ P Function test well commander valve, dropping ball with valve opening at 1850 PSI. Drop second ball to observe valve close with 1950 PSI. Good test. Blow down lines. 03:30 05:45 2.25 662 2,644 SURFA( DRILL TRIP P Continue TIH picking up 5"DP singles from shed to above FC at 2650'. 05:45 06:45 1.00 2,644 2,644 SURFA( DRILL CIRC P Circulate btms up to clear assembly &remove air from system. Prep to perform casing test. Pumps @ 600 GPM's-2120 PSI. 06:45 08:00 1.25 2,644 2,644 SURFA( DRILL PRTS P HELD PJSM. Rig up and test casing to 3000 PSI-30 Minutes.Good test. Record on chart. Page 11 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 09:45 1.75 2,644 2,755 SURFAt CEMEN-DRLG P Drill Shoe track&float equipment from 2656'-2755'MD. Pumps at 550 GPM's-1820 PSI. 09:45 10:00 0.25 2,755 2,775 SURFA( DRILL DRLG P Continue drill 20'of new hole from 2755'-2775'MD.TVD=2384'. Pumps at 600 GPM's-2020 PSI. 10:00 10:45 0.75 2,775 2,775 SURFA( DRILL CIRC P Circulate bottoms up with pumps at 600 GPM's-2040 PSI.Mud -8.9 PPG.Monitor well-static. 10:45 12:00 1.25 2,775 2,775 SURFA( DRILL LOT P Held PJSM-RU and perform FIT test to 16.8 PPG EMW. Qleed pressure and blow down lines.Rig down test equipment. Obtain SPR's Pump#1 30 SPM- 180 PSI,40 SPM-230 PSI Pump#2 30 SPM- 180 PSI,40 SPM-230 PSI Crew Change 12:00 18:00 6.00 2,775 3,465 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 2755'-3465'MD.ND=2550'. Pumps at 800 GPM's-3350 PSI. 120 RPM's.WOB=4-8 K.Torque on =5-6K. UP WT= 142K.SO WT= 118K. ROT WT=130K.ADT=3.59 HRS.AST= .57 HRS.ART=3.02 HRS.Total Bit HRS=3.75.Total Jar HRS=46.45. Max gas observed= 116 Units. ECD's-9.68 PPG 18:00 00:00 6.00 3,465 4,059 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 3465'-4059'MD.ND=2697'. Pumps at 800 GPM's-3380 PSI. 120 RPM's.WOB=8-10 K.Torque on=5-6K. UP WT=145K.SO WT =118K. ROT WT=132K.ADT= 2.95 HRS.AST=.24 HRS.ART= 2.71 HRS.Total Bit HRS=6.70. Total Jar HRS=49.40.Max gas observed=2367 Units. ECD's-9.78 PPG. Obtain SPR's @ 3868'MD Pump#1 30 SPM-220 PSI,40 SPM-290 PSI Pump#2 30 SPM-210 PSI,40 SPM-280 PSI Crew Change Page 12 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/09/2011 24 hr summary Continue Directional Drill 9 7/8"Production hole from 4059'-5006'MD.TVD-2924'.Observed down time for rod wash repair on mud pump.At 5006'MD, Open Well commander valve&CBU @ 920 GPM-2350 PSI while reciprocate drill string.Monitor well-static. POOH on elevators 4 stands,observing improper hole fill.At 4625'MD.Circulate at 550 GPM's-1400 PSI. Observed dramatic increase in flow out at 60%,shut down pumps after 500 stks pumped.Observed gas kick.Shut in annular,with flow to closed choke.Shut in CSG Pressure=560 PSI.Shut in DP Pressure= 100 PSI.Calculate pressures,and circulate through choke (Drillers Method)increasing nud wt from 9.0 PPG to 9.3 PPG.Circulate to kill well. Monitor well. Drop ball to pump down and close Well Commander valve with 2300 PSI.TIH 4 stands to bottom.Continue circulate well with 9.3 PPG,observing steady gas readings of 1700-2200 units. Increase mud wt to 9.5 PPG while circulating to observe gas units fall to below 200 units,and hold steady under 100 units. Monitor well 15 minutes.-static.CBU again to verify no influx with gas holding steady under 200 units. Monitor well-static. POOH on elevators observing good hole conditions and proper displacement.Screw in top drive at 3500'MD, back reaming through Campanian slowly,with no issues.Continue to BRROH to the shoe at 2745',observing overpulls up to 40K after each connection.When work through each stand after pumping,good hole conditions. Monitor well at the shoe-static. Displacement on TOH 5 BBLS over.SIMOPS:Cleaning up rig and location. 00:00 04:15 4.25 4,059 4,611 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 4059'-4611'MD.TVD=2828'. Pumps at 800 GPM's-3430 PSI. 120 RPM's.WOB=6-8 K.Torque on =5-6K. UP WT= 151K.SO WT= 122K. ROT WT= 133K.ADT=2.70 HRS.AST=.08 HRS.ART=2.62 HRS.Total Bit HRS=8.40.Total Jar HRS=52.10.Max gas observed= 1560 Units. ECD's-9.69 PPG. 04:15 06:45 2.50 4,611 4,611 PROD1 RIGMNT RGRP T Observed rod wash failed on#1 mud pump. Remove pump and repair same. Insrtall&test. Reciprocate& rotate drill string. 06:45 10:15 3.50 4,611 5,006 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 4611'-5006'MD.TVD=2924'. Pumps at 800 GPM's-3410 PSI. 120 RPM's.WOB=6-10 K.Torque on=5-6K. UP WT=153K.SO WT = 120K. ROT WT=134K.ADT= 1.93 HRS.AST=.0 HRS.ART= 1.93 HRS.Total Bit HRS=11.33. Total Jar HRS=54.03. Max gas observed=2150 Units. ECD's-9.75 PPG. (Short Trip depth) 10:15 10:45 0.50 5,006 5,006 PROD1 DRILL CIRC P PJSM.Monitor well-static. Drop ball to open well commander valve with 1950 PSI. Ball on seat in 247 stks. 10:45 12:00 1.25 5,006 5,006 PROD1 DRILL CIRC P Circulate&condition mud with pumps at 920 GPM's-2350 PSI. 100 RPM's. UP WT=154K, SO WT = 120K. ROT WT=133K. Pumped a total of 5530 stks. 1 1/2 Bottoms up. Blow down lines&top drive. Reciprocate Drill string.Crew Change Page 13 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 5,006 4,625 PROD1 DRILL TRIP IP Monitor well-static. POOH on elevators with first stand taking 1/2 BBL.Observed next 3 stands pulled with improper hole fill.trip tank had gained 1/2 BBL.Monitor well- Observed small trickle in the flow nipple.Well commander in open position. 12:30 17:00 4.50 4,625 4,625 PROD1 DRILL CIRC T At a depth of 4625'.We circulated at 550 GPMs-1400 PSI.Observed 33% Flow.At 500 strokes pumped, �Ll/ observed dramatic increase in flow out to 60%. Pumps off,shut in well closing annular with flow to a closed choke. Influx allowed OBM through rotary table into windwalls.Well stabilizred with SICP-560 PSI, SIDPP-100 PSI.Calculate well kill, and kill well with drillers method, Holding ICP.Complete well kill increasing mud wt from 9.0 PPG,to 9.3 PPG.After 4000 stks. Flow check well-dead. 17:00 17:30 0.50 4,625 4,625 PROD1 DRILL CIRC T Drop ball to close well commander valve with 2300 PSI. Ball seated in 247 Stks. 17:30 19:30 2.00 4,625 5,006 PROD1 DRILL CIRC T TIH 4 stands with no issues. Circulate&reciprocate drill string at 5 BPM-400 PSI with 17%flow out. Observed gas units maintaining from 1700-2200 units. Increase mud wt form 9.3 ppg-9.5 ppg,observing gas units fall to less than 200 units and remain steady at under 100 units. Complete circulation and one more bottoms up verifying good 9.5 PPG balancing well. 19:30 20:00 0.50 5,006 5,006 PROD1 DRILL OWFF T Monitor well-static. 20:00 20:30 0.50 5,006 5,006 PROD1 DRILL CIRC T Circulate one more bottoms up to verify no gas influx.Gas units remained under 100 units. Obtain SPR"S. Pump#1 -30 SPM-210 PSI.40 SPM-300 PSI. Pump#2-30 SPM-200 PSI.40 SPM-290 PSI. 20:30 21:00 0.50 5,006 5,006 PROD1 DRILL OWFF P Monitor well-static. Prepare for planned short trip. 21:00 22:30 1.50 5,006 3,494 PROD1 DRILL TRIP P POOH on elevators from 5006'- 3494'MD.Observed no issues and proper displacement. 5 BBLS over calculated. Page 14 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 3,494 3,114 PROD1 DRILL REAM P Screw into top drive and BROOH through Campanian sand slowly as planned with pumps at 6 BPM-1000 PSI with no issues.Observed when making connection to POOH on elevators,overpull of up to 40K. Suspect cuttings on top of assembly. During BROOH no issues,and work each stand without pumps again after back ream.Screw into top drive and continue BROOH at same rate.Crew Change 01/10/2011 Continue BROOH from 3114'to shoe at 2745'.Observed no issues and proper displacement.CBU at 600 GPM's-2100 PSI while reciprocate&rotate drill string with no visible increase in cuttings across shakers. Allow time to clean rig floor,top drive etc...Trip back in hole to wash last stand down with no issues. Observed proper displacement. Directional drill 9 7/8"hole form 5006'-6900'MD.TVD=3400'.Observed stroke counter issues w/MWD. Repair same.ADT=9.75 HRS.AST=.46 HRS.Total Bit HRS=21.08, Total Jar HRS=63.78. 00:00 00:45 0.75 3,114 2,745 PROD1 DRILL REAM P Contiue BROOH from 3114'-shoe at 2745'MD. Observed no issues and proper displacement. 00:45 01:15 0.50 2,745 2,800 PROD1 DRILL CIRC P Circulate bottoms up with 600 GPM's 2100 PSI.Observed no issues and gas readings maintaining under 200 units.Set bit depth below shoe depth,continue circulate at 2 BPM- monitor well-no losses. 01:15 03:30 2.25 2,800 2,800 PROD1 RIGMNT CIRC T Allow time as per Co.Man to wash& clean rig floor area,top drive, stabbing board rails,etc.pepare to trip back in hole.Continue monitor well-with no losses and static with 2 BPM-pumped. 03:30 05:30 2.00 2,800 5,006 PROD1 DRILL TRIP P Trip back in hole form 2800'-5006' MD. Observed no hole issues,clean hole, and proper displacemnt.Wash down last stand obtaining parameters. 05:30 12:00 6.50 5,006 5,724 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 5006'-5724'MD.TVD=3105'. Pumps at 800 GPM's-3840 PSI. 120 RPM's.WOB=6-8 K.Torque on =5-6K. UP WT= 160K.SO WT= 115K. ROT WT=134K.ADT=3.78 HRS.AST=.22 HRS.ART=3.56 HRS.Total Bit HRS=15.11.Total Jar HRS=57.81.Max gas observed =500 Units. ECD's-10.23 PPG. Crew change Page 15 of 57 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 12:00 18:00 6.00 5,724 6,427 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 5724'-6427'MD.ND=3274'. Pumps at 790 GPM's-3920 PSI. 120 RPM's.WOB=6-8 K.Torque on =5-6K. UP WT=175K.SO WT= 140K. ROT WT=140K.ADT=3.53 HRS.AST=.13 HRS.ART=3.40 HRS.Total Bit HRS=18.64.Total Jar HRS=61.34.Max gas observed =42 Units. ECD's-10.49 PPG. 18:00 22:30 4.50 6,427 6,900 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 6427'-6900'MD.ND=3400'. Pumps at 773 GPM's-3940 PSI. 120 RPM's.WOB=8-10 K.Torque on=7K. UP WT= 187K.SO WT= 110K. ROT WT=140K.ADT=2.44 HRS.AST=.11 HRS.ART=2.33 HRS.Total Bit HRS=21.08.Total Jar HRS=63.78.Max gas observed =42 Units. ECD's-10.53 PPG. 22:30 00:00 1.50 6,900 6,900 PROD1 RIGMNT RGRP T Observed failure of MWD stroke counter. Reciprocate&rotate drill string while repair stroke counter. Crew Change 01/11/2011 Continue directional drill 9 7/8"Hole from 6900'-8031'MD.Wiper trip&drill to 8503'MD. 00:00 06:00 6.00 6,900 7,562 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 6900'-7562'MD.ND=3560' Pumps at 755 GPM's-3950 PSI. 120 RPM's.WOB=8-10 K.Torque on=7K. UPWT=199K.SOWT= 112K. ROT WT=147K.ADT=2.44 HRS.AST=.11 HRS.ART=2.13 HRS.Total Bit HRS=24.54.Total Jar HRS=69.49. Max gas observed =42 Units. ECD's-10.49 PPG. 06:00 10:15 4.25 7,562 8,031 PROD1 DRILL DDRL P Directonal Drill 9 7/8"Hole from 7562' to 8031'MD.TVD=3670'.GPM=755 PSI=3950. RPM 120. TQN=8.5K TQF=7.5K WOB=8-12K PUW=210k SOW=110k ROT WT=149K. ECD,S=10.48 PPG.MAX GAS=16 units.ADT=2.25 HRS.ART=2.13 HRS.AST=.12 HRS. TRT=1.77 TST=25.02 HRS. BIT HRS=26.79 JAR HRS=69.49. 10:15 10:30 0.25 8,031 8,031 PROD1 DRILL OTHR P PJSM=Drop Ball to open well Commander.2 BPM PSI 290.W/C open @ 1950 PSI. Page 16 of 57 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 10:30 12:00 1.50 8,031 8,031 PROD1 DRILL (CIRC P Circ.Condition mud for wiper trip @ 8031'MD.GPM 915. PSI=3401. RPM=100.TQF=7.5K. PUW 200K. SOW=110K. RTW=149K. Pumped Total 9200 Strokes. Blow down top drive&Flow check well. (Static)Well Commander in open position. SPR-MP#1=30-290.40-390.MP #2=30-300 40-390.@ MD 8031. 3670'TVD. 12:00 15:00 3.00 8,031 4,810 PROD1 DRILL WPRT P POH from 8031'MD to 4810'MD. Up WT=152K. DN 118K.(Actual fill 33 bbls. Calculated Total 25.5 bbls.) 15:00 16:30 1.50 4,810 4,810 PROD1 DRILL CIRC P CBU @ 4801 MD.912 GPM 2610 PSI 38%Flow out 100 RPM 5K TQ Circulated 4100 Strokes. Shut down &drop ball to close well commander sub @ 25 SPM 150 PSI 10%flow out. Ball on seat @ 273 strokes.Pressure up to 1500 psi. Wait 30 secs. Pressure up to 2460 psi to shift tool closed.Check pressure w/tiool closed @ 25 spm 230 psi(OK) 16:30 17:00 0.50 4,810 4,810 PROD1 RIGMNT SVRG P Adjust brakes on drawworks. 17:00 19:30 2.50 4,810 8,031 PROD1 DRILL WPRT P TIH from 4801 MD to 8031 MD. Up wt 210K DN 110K. NOTE=Wash& Ream from 6156 MD to 6239'MD w/ 750 GPM 3740 PSI 100 rpm 6-7k TQ 32%flow out ECD,s 10.40 PPG rot wt 140K.5-6k tq pumps off.Circ 2200 strokes.Trip in Actual fill 35 bbls. 19:30 00:00 4.50 8,031 8,503 PROD1 DRILL DDRL P Drill from 8031'MD to 8503'MD 3785 TVD w/718 GPM 3970 PSI(On Bottom)Flow out 31% 120 RPM 9-10K TQ WOB 10K 3800 PSI Off Bottom PUW 215K SOW 105K ROT 147K 7-8K tq off bottomj ECD,S 10.54 PPG Max gas observed=45 units.ADT 2.37 ART 2.37 AST 0.0 Bit hrs 29.16.Jar hrs.71.86. SPR 8409'MD.3743'TVD.30 SPM#1 Pump 260 PSI 40 SPM#1 pump 360 psi.#2 Pump 30 spm 270 psi 40 spm 370 psi.Mud wt.9.5 ppg @ 23:00 hrs. 01/12/2011 Drilling 9 7/8"Directional Hole from 8505'MD to 10886'MD.4381'TVD. Page 17 of 57 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 12:00 12.00 8,503 9,832 PROD1 DRILL DDRL P Drilling 9 7/8"Directional Hole from 8505'MD to 9832'MD TVD 4118'. GPM 700. PSI 3950. RPM 120.TQN 10K TQF 9K.WOB 10-14K. PUW 225K. SOW 110K. ROT WT 154K. ECD,S 10.65 PPG.MAX GAS 21 units.ADT 3.30 HRS ART 2.82HRS. AST.48 HRS.TRT 2.25 HRS.TST 33.65 HRS. Bit HRS 35.90 HRS.Jar Hrs.78.60 HRS.SPR MP#1 30 SPM 310 PSI.40 SPM 430 PSI.MP #2 30 SPM 320 PSI 40 SPM 410 PSI @ MD 9548. 12:00 00:00 12.00 9,832 10,886 PROD1 DRILL DDRL P Drilling 9 7/8"directional Hole from 9832'MD to 10886'MD.4381'TVD. GPM 685.3990 PSI. Flow out 31%. RPM 120.TQ 9-10K WOB 6-8K. PUW 250K.SOW 100K ROT WT 160K. ECD,S 10.60 PPG MAX GAS 81 units.ADT 2.76 HRS.AST.21 HRS. ART 2.55 HRS. Bit HRS 42.78 Jar HRS.85.48 SPR @ 10595 MD 4309 ND.MP#1 30 SPM 380 PSI. 40 SPM 470 PSI. MP#2 30 SPM 370 PSI 40 SPM 460 PSI.. 01/13/2011 Drlg.9 7/8"Directional hole f/10886'to 11446'.Wiper Trip. 00:00 06:30 6.50 10,886 11,446 PROD1 DRILL DDRL P Drilling 9 7/8"Directional Hole from 10886'MD to 11446'MD.ND 4519'. GPM 680. PSI 3950. RPM 120.TQN 10K.TQF 8-10K.WOB 6-10K. PUW 270K. SOW 85K. ROT WT 160K. ECD,S 10.65 PPG. MAX GAS 24 UNITS.ADT 4.02 HRS.ART 4.02 HRS.AST 0.TRT 44.34 HRS.TST 2.46 HRS BIT HRS 46.80.JAR HRS. 89.50. 06:30 07:00 0.50 11,446 11,446 PROD1 DRILL CIRC P Circ.Condition mud @ 11446.0 MD For Wiper Trip. 07:00 08:00 1.00 11,446 11,446 PROD1 DRILL OTHR P PJSM=Drop ball to open well commander. 2 BPM 360 psi W/C open @ 2540 PSI. 08:00 09:00 1.00 11,446 11,446 PROD1 DRILL CIRC P Circ.condition mud w/well commander open @ 11446'. GPM 840 PSI 3950. RPM 100.TQF 8K. PUW 262K. SOW 100K. RTW 158K. Pumped total 12100 Strokes. Flo check well Static. 09:00 11:30 2.50 11,446 10,402 PROD1 DRILL REAM P PJSM=BROOH f/11446'MD to 10402'MD.GPM 830. PSI 3950. RPM 100.TQF 8K.Tight spot @ 10430'MD. • Page 18 of 57 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11:30 12:00 0.50 10,402 10,402 PROD1 DRILL CIRC P Circ.condition mud while work on#1 pump.GPM 840. PSI 3950. RPM 50. TQF 8K PUW 250K.SOW 120K. RTW 158K. SPR MP#1 30 SPM 390 PSI.40 SPM 500 PSI. MP#2 30-380 40 480 2 MD 11446'.W/C closed. SPR MP #1 30-340 40-400.MP#2 30-320 40-390.W/C open. 12:00 12:30 0.50 10,402 10,402 PROD1 DRILL CIRC P Circ.condition mud(change out liner gasket on MP#1)@ 10402'MD. GPM 840. PSI 3950. RPM 50 TQF 8K. PUW 250K. SOW 120K. RTW 158K. 12:30 21:30 9.00 10,402 7,939 PROD1 DRILL REAM P BROOH @ 20 FPM from 10402'MD to 10079'MD.670 GPM 3830 PSI. 31 %flow out. 100 RPM.9-10K TQ. PUW 240K. SOW 110K. NOTE: increase in drag-pump pressure& losses-packing off below well commander. Drop ball&circ.down w/25 SPM 250 psi. 14%flow out. Ball on seat @ 942 strokes. Bring pressure to 1500 psi&wait 30 secs. increase pressure @ 3 spm to 3000 psi.Tool shift closed. Continue BROOH f/10079 to 7939'MD.w/ 640 gpm 3500 psi ECD,S 10.95 29% flow out 100 rpm 9-10K tq up wt 240K down 110K. 21:30 00:00 2.50 7,939 7,939 PROD1 DRILL CIRC P Rotate&reciprocate while circ. bottoms up. 702 gpm 3730 psi 32% flow out 100 rpm 6-7K tq PUW 220K SOW 105K. Pumped 19800 total strokes. NOTE: pumped 40 bbl hi-vis sweep 9.5 PPG 190 vis. 50-60% increase in cuttings on sweep. Monitor well(Static)blow down top drive. 01/14/2011 Wiper trip&work tight hole. 00:00 00:30 0.50 7,939 8,660 PROD1 DRILL WPRT P RIH to 8,660'Took weight. 00:30 02:30 2.00 8,660 8,660 PROD1 DRILL REAM P Washed and reamed Tight spot @ 8,660'.Circulated and conditioned mud.675 GPM 3540 PSI 100 RPM 210KPUWt85KSOWt150K RTWt 7.5 KTq 02:30 03:30 1.00 8,660 10,360 PROD1 DRILL WPRT P RIH to 10,360'Took weight. 03:30 03:45 0.25 10,360 10,360 PROD1 DRILL CIRC P PJSM-Wash&Ream from 10330'to 10360'GPM 675 PSI 3540. RPM 100.TQF 7.5K ROT WT 150K. Observed full returns on down stroke. Observed packing off&over pull on up stroke f/10360'to 10330'. PACKED OFF) Page 19 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 09:45 6.00 10,360 10,260 PROD1 DRILL JAR T Attemp to free packed off temporarly detained drill string-attempt to establish circ. (no success)freed string by jarring down established rotation @ 10300'. rpm 80 tqf 10/20. unable to pump observed more packing off.continue working string from 10330 to 10260'w/rotary establish circ.@ 10260'. 09:45 11:30 1.75 10,260 10,260 PROD1 DRILL CIRC P Circ.condition hole @ 10260'.gpm 600 psi 3350. rpm 100.tqf 8k puw 225k.sow 112k. rtw 150k. pumped total 7500 strokes. 11:30 12:00 0.50 10,260 10,022 PROD1 DRILL REAM P BROOH from 10260'to 10022'.gpm 600 psi 3350 rpm 100 tqf 8k. 12:00 00:00 12.00 10,022 4,819 PROD1 DRILL REAM P PJSM=continue back ream from 10022'to 4819'MD.GPM 650 PSI 3200. RPM 100.TQ 10-15K. Flow out 32%. Up WT 220K.SOW 120K. Max Gas 415 units. No Swabbing. No overpull. Losses from 1200-2400 hrs.91 bbls. 01/15/2011 Attempting to POH. Hole packing off&losing fluid. 00:00 02:30 2.50 4,819 4,059 PROD1 DRILL REAM P Continue BROOH f/4819'to 4059'. GPM 700 PSI 3050 RPM 100 TQF 5K PUW 148K SOW 110K RTW 128K Observed slight packing off. 02:30 04:45 2.25 4,059 4,059 PROD1 DRILL CIRC P Circ.condition mud&hole @ 4049'. Pumped total 22900 strokes. Pump hi-vis sweep to clean hole ECD 10.04 ppg• 04:45 08:00 3.25 4,059 3,050 PROD1 DRILL REAM P Continue back ream f/4059'to 3050'. ✓ gpm 600.psi 2850. rpm 100 tqf 5k puw 145k.sow 110k. rtw 128k. Observed packing off&overpull @ 3050'. 08:00 12:00 4.00 3,050 3,050 PROD1 DRILL REAM P Attempt to establish circ. (No Success)Ream @ 80 rpm tq 6-15K from 3050'to 2642'.Attempt to break free of packoff(No Success)Still packed off. RIH from 2642'to 2755'. &attempt to break free of pack off. (No Success). 12:00 13:00 1.00 3,050 2,755 PROD1 DRILL TRIP P Continue attempt to establish circ. Rotate string @ 80 rpm.tq 8-20k from 2755'.Attempt to break free of packoff. No Success. POH from 2755 to 2735'.&attempt to break free. 13:00 14:30 1.50 2,755 2,755 PROD1 RIGMNT RGRP P PJSM=Change out&test swivel packing. 14:30 16:00 1.50 2,755 2,604 PROD1 DRILL REAM P Attempt to establish circ. Rotate @ 80 RPM tq 6-15K from 2755 to 2604'. Attempt to break free of packoff. 16:00 16:30 0.50 2,604 2,604 PROD1 DRILL OTHR P Drop 2.125"ball&shift well commander @ 3000 psi.9th ball dropped. Page 20 of 57 S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:30 1.00 2,604 2,910 PROD1 DRILL REAM P Ream down from 2604'to 2910'@ 30 RPM&500 gpm PSI 1100 tq 10K losses 143 bbls. 17:30 21:30 4.00 2,910 2,910 PROD1 DRILL OWFF P Releave pressure from charged up formation.52 bbl return. 21:30 22:15 0.75 2,910 2,745 PROD1 DRILL TRIP P Pump out of hole from 2910'to 2745'. to shoe flow rate 200 gpm 30 rpm. 22:15 22:45 0.50 2,745 2,745 PROD1 DRILL CIRC P Circ. bottoms up @ 5 bpm&stage up to 10 bpm icp-260 psi fcp 604 psi. 22:45 00:00 1.25 2,745 PROD1 DRILL OWFF P Flow check. hole giving back fluid. Let hole stabilize before pulli=ng out of hole. 01/16/2011 Finish POH.Change BHA. RIH 00:00 04:15 4.25 2,745 2,745 PROD1 DRILL OWFF P Monitor well for flow back from lost fluid in hole. Flowed back 10 bbls. 04:15 06:00 1.75 2,745 2,358 PROD1 DRILL TRIP P POH from 2745'to 2358'. Observe packing off&overpull. 06:00 07:00 1.00 2,358 2,358 PROD1 DRILL CIRC P Circ.&condition @ 2358'.GPM 890 PSI 1950 RPM 90 TQF 4K PUW 135K SOW 125K RTW 130K CBU pumped 3500 strokes. 07:00 08:30 1.50 2,358 1,887 PROD1 DRILL TRIP P POH w/pumps from 2358'to 1887'. GPM 420 PSI 480 PUW 134K SOW 122K. 08:30 09:00 0.50 1,887 1,887 PROD1 DRILL OWFF P Monitor well for flow. (Static) 09:00 11:15 2.25 1,887 483 PROD1 DRILL TRIP P POH w/pumps from 1887'to 483'. 11:15 12:00 0.75 483 483 PROD1 DRILL OWFF P Monitor well @ 483'.Static Total losses for tour 58 bbls. 12:00 12:15 0.25 483 483 PROD1 DRILL OWFF P Continue monitor well. 12:15 14:00 1.75 483 0 PROD1 DRILL TRIP P POH to BHA. 14:00 18:00 4.00 0 0 PROD1 DRILL PULD P PJSM=Pull source MWD. Plug in MWD Clean&lay down BHA from ✓ floor to Ground. BHA was Clean. 18:00 19:00 1.00 0 0 PROD1 DRILL OWFF P Monitor well. 19:00 21:30 2.50 0 0 PROD1 WHDBO BOPE P Pull wear bushing&set test plug. Rig up&test Annular preventer after using for well control 300-2500 psi. Rig down testing equipment. Pull test plug&set wear ring. 21:30 22:00 0.50 0 0 PROD1 RIGMNI SVRG P Service rig/top drive-blocks-crown-& drawworks. 22:00 00:00 2.00 0 PROD1 DRILL PULD P PJSM=Pickup&make up BHA#3. 01/17/2011 Make up BHA. RIH&wash&Ream. 00:00 00:45 0.75 80 80 PROD1 DRILL OWFF P PJSM=Upload MWD Tools. Monitor well on trip tank. 00:45 01:45 1.00 80 621 PROD1 DRILL TRIP P PJSM=RIH w/HWDP&Jars f/80'to 621'. 01:45 02:00 0.25 621 621 PROD1 DRILL DHEQ P PJSM=Pulse test MWD tools. 02:00 03:00 1.00 621 2,035 PROD1 DRILL TRIP P RIH from 621 to 2035'. Page 21 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:30 1.50 2,035 2,035 PROD1 RIGMNT SLPC P PJSM=Cut&Slip Drlg. Line 85'. Service top drive. Monitor well on trip tank. 04:30 05:00 0.50 2,035 2,694 PROD1 DRILL TRIP P RIH from 2035'to 2694'. 05:00 07:30 2.50 2,694 3,357 PROD1 DRILL REAM P Wash&ream from 2694'to 3357'. GPM 700 PSI 2580 RPM 120 TQF 5K. 07:30 08:30 1.00 3,357 3,357 PROD1 RIGMNT RGRP T Monitor well while work on mud pumps.Change out shear relieve valve. 08:30 09:30 1.00 3,357 3,545 PROD1 DRILL REAM P Wash&ream from 3357'to 3545'. GPM 700 PSI 2580 RPM 120 TQF 5K. 09:30 09:45 0.25 3,545 4,019 PROD1 DRILL TRIP P RIH from 3545'to 4019'. 09:45 11:00 1.25 4,019 4,303 PROD1 DRILL REAM P Wash&ream from 4019 to 4303'. 11:00 12:00 1.00 4,303 5,722 PROD1 DRILL TRIP P RIH from 4303 to 5722'. 12:00 14:30 2.50 5,722 9,699 PROD1 DRILL TRIP P RIH from 5722'to 9699'. 14:30 15:30 1.00 9,699 10,330 PROD1 DRILL REAM P Wash&ream from 9699'to 10330' @ 670 GPM 3800 PSI up wt 200K do 140K RPM 120 TQ 10K. 15:30 18:00 2.50 10,330 9,913 PROD1 DRILL REAM T Work string free from 10330'to 9913' Jarring up&down establish circ. & rotation. 18:00 00:00 6.00 9,913 10,147 PROD1 DRILL REAM P Ream down from 9913' to 10147'. GPM 210=650 PSI 2050 max gas 526 units. SPR#1 20 spm 190 30 spm 260.SPR#2 20 spm 200 30 spm 270 01/18/2011 Attempt to clean hole.Work tight pipe @ 9224'.MD 00:00 05:30 5.50 10,147 10,147 PROD1 DRILL REAM P Attempt to free drill string. Establish circ. @ 10147'. GPM 420 PSI 2040 RPM 80 TQ 7K.Attempt to bring pump rate up Packed off @ 575 gpm. 05:30 08:00 2.50 10,147 9,316 PROD1 DRILL TRIP P POH from 10147'to 9316'.Jarring 3 stands loose attempting to get above packoff,s. pulled to 400K jarring same. PUW 200K SOW 120K 120 RPM 08:00 12:00 4.00 9,316 9,316 PROD1 DRILL JAR T Attempt to establish circ. &rotation f/9316'to 9221'.observed more packing off&overpull.Attempt to free drill pipe(no Success) 12:00 15:30 3.50 9,316 9,224 PROD1 DRILL JAR T Continue Attempt to establish circ.& rotation f/9316'to 9221'.Jarring on drill string(No Success) 15:30 16:30 1.00 9,224 9,224 PROD1 RIGMNT SVRG T PJSM=Inspect derrick&top drive from jarring operation. 16:30 19:30 3.00 9,224 9,224 PROD1 DRILL JAR T Continue attempt to free drill string& establish circulation.Work from 9221'to 9226'. 19:30 20:30 1.00 9,224 9,224 PROD1 DRILL OTHR T Lay down single&change out short bails for long bails for back off operation. Page 22 of 57 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 20:30 00:00 3.50 9,224 9,224 PROD1 DRILL ELNE T PJSM=Rig up to run wireline freepoint&backoff shot thru top drive while waiting on haliburton to bring pump in sub. 01/19/2011 Make up Free point Attempt run.Would not go. Run Tractor w/480 grain string shot on wire line. 00:00 03:00 3.00 9,224 9,224 PROD1 DRILL ELNE T PJSM=Rig up to run Free point& Backoff shot in hole thru Top Drive. While waiting on Haliburton to get here w/Pump in sub. (loss time waiting on Haliburton 9 Hrs.) 03:00 06:30 3.50 9,224 9,224 PROD1 DRILL ELNE T PJSM=Haliburton Here w/tools. Make up Freepoint tools pick up 15' pup&prep to RIH w/freepoint. 06:30 08:30 2.00 9,224 9,224 PROD1 DRILL ELNE T PJSM=RIH w/freepoint to 3700'-would not go any further w/ wireline. POH to remove bowspring tool.Trouble shoot wireline tools. 08:30 12:00 3.50 9,224 9,224 PROD1 DRILL ELNE T PJSM=RIH w/freepoint on wireline to 3200'.Would not go any further. Consult w/Town. POH&lay down tools. 12:00 13:00 1.00 9,224 9,224 PROD1 DRILL ELNE T Conrtinue rigging down topdrive& monitor well by circ. over top of hole. 13:00 14:00 1.00 9,224 9,224 PROD1 DRILL JAR T Screw top drive into drill string&jar up @ 380K.(No Success) 14:00 16:00 2.00 9,224 9,224 PROD1 DRILL OTHR T Back out top drive&rig up wire line entry on top drive.Stand by for well tech tractor.Clean OBM from windwalls while waiting. 16:00 22:00 6.00 9,224 9,224 PROD1 DRILL ELNE T Well Tech on location w/tools.Well Tech&Haliburton rig up to run Tractor w/480 grain shot. 22:00 00:00 2.00 9,224 9,224 PROD1 DRILL ELNE T PJSM w/Haliburton&Well Tech on ✓/ correct handling of explosives& tools. Pickup tools&RIH to 200'. Make up top drive&continue run in w/wireline to 2960'.Would not go any further. Begin working tractor @ 2960'. 01/20/2011 Attempt to run backoff shot w/tractor. POH. rig down Howco&rig up SWS. 00:00 03:00 3.00 9,224 9,224 PROD1 DRILL ELNE T RIH w/Well Tech Tractor on wireline from 2960 to 8640'MD. 03:00 03:30 0.50 9,224 9,224 PROD1 DRILL ELNE T PJSM=Work 8 rounds left hand torqe into string as per baker fishing rep. 03:30 05:00 1.50 9,224 9,224 PROD1 DRILL OTHR T Attempt to RIH w/tractor on wireline. (No Success)Pump on tool w/.5 bpm-pump total 5.5 bbls. pressure build to 550 psi. Pack off leaking @ 550 psi.(No Tractor movement.) Did not want to go higher on pressure due to blowing packoff&creating spill. Page 23 of 57 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 05:00 11:00 6.00 9,224 9,224 PROD1 DRILL ELNE T PJSM=POH w/wireline&Well Tech Tractor to 7250'.Tool hung up. Attempt to free tool. Release torqe out og drill string.Work torqe in& out of drill string&tool released. Pull to 6558'&tool stuck again.Work drill string w/up&down&torqe. Released tool&POH. 11:00 12:00 1.00 9,224 9,224 PROD1 DRILL ELNE T PJSM=Lay down. halibuton wire line &well Tech tools. 12:00 13:30 1.50 9,224 9,224 PROD1 DRILL OTHR T Wireline out of hole&changing tools. Rig creww working on clean up. Derrick man inspecting derrick. Crew performing rig maintenance. 13:30 14:30 1.00 9,224 9,224 PROD1 DRILL OTHR T Rig down Haliburton wireline. 14:30 14:45 0.25 9,224 9,224 PROD1 DRILL JAR T Jar on drill string one time @ 380K. Jars went off freely. 14:45 22:30 7.75 9,224 9,224 PROD1 DRILL OTHR T Crews working on rig inspection from jarring operation&cleaning rig& maintenance where needed.While waiting on Schlumberger wireline unit &string shot. 22:30 00:00 1.50 9,224 9,224 PROD1 DRILL ELNE T PJSM=Pick up SWS tools hang sheaves in derrick&pull wire line to floor make up pump in sub&packoff string wireline thru sheave&top drive make up tools&well tech tractor. 01/21/2011 Make up tools RIH Backoff CBU POH(Estimated fish left in hole 111.08) 00:00 01:30 1.50 9,224 9,224 PROD1 DRILL ELNE T PJSM=Make up SWS Wireline tools &Well Tech Tractor. 01:30 02:30 1.00 9,224 9,224 PROD1 DRILL OTHR T PJSM=Pull backoff tools to rig floor &RIH to 250'.Work 8 rounds left hand torque into drill string. 02:30 09:30 7.00 9,224 9,224 PROD1 DRILL ELNE T PJSM=RIH w/SWS wireline,tractor &string shot loaded w/480 grain shot 12'long to 2900'.Tractor down from 2900'to 9132'w/10K left hand to set charge off @ 9113'. Shot successfull. POH w/wireline from 9113'to 240'. 09:30 11:00 1.50 9,224 9,224 PROD1 DRILL ELNE T PJSM=W/SWS prior to pulling tools &shot to rig floor. Rig down SWS. 11:00 12:00 1.00 9,224 9,224 PROD1 DRILL OTHR T Lay down 15'pup. Latch onto DP& work string from 9100'to 9073'up wt 210K 15K drag do wt 130K rot wt 150K. Slack off to 9100'&lay down long bails&pick up short bails. Make up top drive to string&break circulation @ 3 bpm 380 psi continue circ.bottoms up 2 times @ 300 gpm 580 psi rpm 120 tq 8-10K. 12:00 15:00 3.00 9,224 9,224 PROD1 DRILL CIRC T Circulating @ 3 bpm 380 psi take spr on pumps @ 20&30 spm work string from 9113'to 8924'. Page 24 of 57 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 15:00 20:30 5.50 9,224 9,224 PROD1 DRILL CIRC T Pump 50 bbls. hi vis sweep 10 ppg 200 vis increase pump to 600 gpm rpm 150 tq 8-10K upwt 160K 15K drag dnwt 130K rotwt 150K with sweep @ surface 70%increase in cuttings.CBU X 2 9.8 ppg 185 vis 800 gpm 2750 psi 150 rpm 8-10K tq. Shakers looking clean. 20:30 20:45 0.25 9,224 9,224 PROD1 DRILL OTHR T Flow Check. @ 9009'(Static)Blow down topdrive. 20:45 21:00 0.25 9,224 9,224 PROD1 DRILL TRIP T POH on elevators from 9009'to 8828'.&Monitor well(Static) 21:00 22:00 1.00 9,224 9,224 PROD1 DRILL TRIP T POH from 8828'to 7976'. MD. 22:00 23:00 1.00 9,224 9,224 PROD1 DRILL OTHR T Monitor well.(Static)Pump dry job. Blow down topdrive. 23:00 00:00 1.00 9,224 9,224 PROD1 DRILL TRIP T POH on elevators from 7976'to 6181'. 01/22/2011 POH lay down jars&2 flex collars.Test BOPE 00:00 03:00 3.00 9,224 9,224 PROD1 DRILL TRIP T Continue POH from 6181'to BHA @ 510'. 03:00 04:00 1.00 9,224 9,224 PROD1 DRILL PULD T Stand back 3 stands hwdp. Lay down jars&replace w/jt.of dp. Lay down 2 flex collars. (Fish left in hole 111.08'.) 04:00 05:00 1.00 9,224 9,224 PROD1 DRILL OTHR T Monitor well(Static)Clear&organize rig floor for BOPE test. 05:00 05:30 0.50 9,224 9,224 PROD1 WHDBO OTHR T Drain bop stack&pull wear bushing. 05:30 06:30 1.00 9,224 9,224 PROD1 WHDBO OTHR P Make up 5"test jt to lower test plug &set in csg.spool.Make up floor valve to Dart valve. Monitor well via open csg.spool valves during bope test. 06:30 12:00 5.50 9,224 9,224 PROD1 WHDBO BOPE P Fill bop stack&choke manifold w/ water(Witness of bope test was waived by Lou Grimaldi AOGCC @ 18:00 hrs. 1/21/2011.Test Annular 250 psi low 2500 psi high. Remainder of tests 250 psi low 3500 psi high.Top pipe rams,kill valve on mud line, kill line, kill hcr valve, manual kill valve Choke manifold& all valves, Dart valve,floor safety valve&choke hcr. 12:00 18:00 6.00 9,224 9,224 PROD1 WHDBO BOPE P Continue testing bope 250 psi low 3500 psi high test lower pipe rams. Perform Koomey draw down. System pressure=3000 psi.Test after close 1500 psi.200 psi attained=49 secs.. Full pressure attained=200 secs. Blind switch covers over all stations. Nitrogen 6 bottles w/average pressure 2400 psi. Koomey system=16 bottles w/average pressure=1100 psi.Test blind rams. Test lower IBOP.Test on upper IBOP failed. Page 25 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:30 0.50 9,224 9,224 PROD1 WHDBO SVRG P Service Rig. 18:30 22:30 4.00 9,224 9,224 PROD1 WHDBO RGRP P PJSM=Break out saver sub&lay down. Break out lower ibop&lay down.Change out upper ibop w/7 5/8"X 4 1/2"IF saver sub. 22:30 23:30 1.00 9,224 9,224 PROD1 WHDBO OTHR P Pick up GEO skid while rigging up to test upper ibop. 23:30 00:00 0.50 9,224 9,224 PROD1 WHDBO BOPE P Test upper ibop 300 psi low 3500 psi high.OK 01/23/2011 Finish IBOP Trpair. Pick up Fishing tools&RIH.Wash down&attempt to latch fish. 00:00 02:30 2.50 9,224 9,224 PROD1 WHDBO BOPE P Complete instalation of upper IBOP &test to 250-3500 OK. Rig down& blow down test equipment&prep floor to pick up fishing assembly. 02:30 05:00 2.50 9,224 9,224 PROD1 DRILL PULD T Pick up&make up Fishing assembly as per Baker Fishing rep. 05:00 05:30 0.50 9,224 9,224 PROD1 DRILL OTHR T Move HWDP in derrick from drillers side to off drillers side. 05:30 07:30 2.00 9,224 9,224 PROD1 DRILL TRIP T RIH to 2698'checking all 5" connections torque from back off operations. 07:30 09:30 2.00 9,224 9,224 PROD1 RIGMNT SLPC T PJSM=Cut&slip drlg. line.Adjust brakes.Check weiht indicator& calibrate. 09:30 11:00 1.50 9,224 9,224 PROD1 RIGMNISVRG P Service rig. Drawworks&iron roughneck. 11:00 12:00 1.00 9,224 9,224 PROD1 RIGMNT SVRG P Adjust IBOP actuator on top drive& function test OK. 12:00 13:00 1.00 9,224 9,224 PROD1 DRILL TRIP T RIH from 2698'to 4000'.Check torque on each connection. PUW 140K SOW 110K. 13:00 13:45 0.75 9,224 9,224 PROD1 DRILL CIRC T Circ. bottoms up @ 400 gpm 600 psi 26%flow out. 13:45 18:30 4.75 9,224 9,224 PROD1 DRILL TRIP T RIH from 4000'to 9038'. PUW 160K SOW 120K. 18:30 00:00 5.50 9,224 9,224 PROD1 DRILL FISH T Washing down from 9038'to 9083' started torquing up&packing off. Pick up to 9038'&CBU working pipe from 9070'to 9038'circulating @ 2 bpm&staging up to 12 bpm 1200 psi gpm 460 rpm 50 tq 5-8K. Increase to 18 bpm 750 gpm 2750 psi wash down to top of fish @ 9113' . Made several attemps to screw into fish w/no success. (Lost 186 bbls. fluid to formation&43 bbls. heavy fluid over shakers.) 01/24/2011 Attempt to latch fish. No Success. POH. Lay down tools. RIH w/Baker ECP. 00:00 02:00 2.00 9,224 9,224 PROD1 DRILL REAM T Wash&ream to top of fish @ 9113'. w/varied pump rates.3 bpm to 10 bpm 300 psi to 1600 psi rotary from 40-65 rpm.Attempt to latch fish w/ no success. Pipe sticking above jars. Page 26 of 57 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 02:00 02:30 0.50 9,224 9,224 PROD1 DRILL TRIP T Obseve well. Break out 15 5"pup jt. &POH to 8900'. 02:30 03:30 1.00 9,224 9,224 PROD1 DRILL TRIP T POH to 8090'. Pipe pulling free. 03:30 04:00 0.50 9,224 9,224 PROD1 DRILL OWFF T Observe well. Pump dry job&blow down topdrive. 04:00 04:45 0.75 9,224 9,224 PROD1 DRILL TRIP T POH from 8090'to 6640'. 04:45 05:15 0.50 9,224 9,224 PROD1 DRILL OTHR T Found hole in 5"drill pipe 5'below tool jt. 1"in size middle jt. in pipe tally stand#67. Change out&mark bad jt. 05:15 08:45 3.50 9,224 9,224 PROD1 DRILL TRIP T POH from 6640'to 340'. 08:45 09:00 0.25 9,224 9,224 PROD1 DRILL OWFF T Observe well @ BHA. 09:00 11:00 2.00 9,224 9,224 PROD1 DRILL PULD T Lay down Baker fishing assembly to pipe shed. Found pump out sub sheared. 11:00 12:00 1.00 9,224 9,224 PROD1 DRILL RURD T Clear floor of baker fishing tools&rig up to run 3.5"cementing string. 12:00 13:00 1.00 9,224 9,224 PROD1 DRILL RURD T Finish rigging up to run cementing assembly. 13:00 15:00 2.00 9,224 9,224 PROD1 DRILL PULD T Rig up&make up 3.5"handling equipment. Make up Baker Payzone External Casing Packer 7"26#L-80. X over on PH-6 3.5"Tbg. 12.95# L-80. 15:00 15:30 0.50 9,224 9,224 PROD1 RIGMN1SVRG T Service Rig. 15:30 18:30 3.00 9,224 9,224 PROD1 DRILL TRIP T RIH picking up 3.5"PH-6 tbg.to 1726'. 18:30 00:00 5.50 9,224 9,224 PROD1 DRILL TRIP T RIH w/Baker ECP from 1726'. On 5" Drill pipe to 7778'MD. Fill pipe every 15 stands. Monitor displacement on Pit#4. 01/25/2011 Continue trip in hole with Baker ECP to set @ 7966'. Rig up cement head. Pressure test lines to 3800 PSI. Set ECP in stages with mud pressuring to 3000 PSI. Rig up Cementers. Pump bottom&top plugs with 57 BBLS each of 17#cement.TOC calculated at 6967'MD. Displace with OBM,verify no cement to surface. POOH. Breakout and lay down 3 1/2"tbg. Breakout&inspect Baker running tools.Clean&clear rig floor. Held PJSM. Make up BHA#4. 00:00 00:30 0.50 7,778 7,966 PROD1 DRILL TRIP T 'Continue RIH w/Baker ECP on 5" Drill pipe to 7966'MD. Fill pipe every 15 stands.Observed proper displacement. 00:30 02:30 2.00 7,966 7,966 PROD1 DRILL CIRC T Fill drill string.Circulate at 3 BPM- 300 PSI. Prep to set ECP. Blow down Top Drive and rig up cement head, lines,and chart recorder. Held PJSM. 02:30 03:00 0.50 7,966 7,966 PROD1 DRILL PRTS T Pressure test lines to 3800 PSI. Record on chart. Page 27 of 57 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03:00 04:30 1.50 7,966 7,966 PROD1 DRILL PACK T Drop pump down plug. Pump down drill string with 4.5 BPM. Bump plug with 1150 Stks. Pressure to 1100 PSI-hold.Continue stage pressures and hold at 1300, 1500,and 1700 PSI.Observed packer inflation, continuing pressure to 2000 PSI,and then to 3000 PSI to observed disconnect. Pick up 10',and begin circulation. Packer set @ 7966'DPM 04:30 08:00 3.50 7,966 7,966 PROD1 DRILL CIRC T Circulate at 10 BPM-1700 PSI. Spot&rig up cementers. 08:00 08:30 0.50 7,966 7,966 PROD1 CEMEN"SFTY T Held PJSM with crew and Schlumberger cementers. Discuss safety&hazard recognition issues. Discuss procedure to pressure test and pump cement plugs. 08:30 09:30 1.00 7,966 7,966 PROD1 CEMEN"CMNT T With Schlumberger. Pressure test lines to 3000 PSI. Pump 20 BBLS of Mud Push,then 57 BBLS of 17# PPG cement,4 BBLS of Mud Push, and displace with 1095 STK of OBM. Bleed pressure. 09:30 10:00 0.50 7,966 7,566 PROD1 CEMEN"TRIP T Breakout Cement head, POOH with 5"DP to 7566'MD. 10:00 11:30 1.50 7,566 7,566 PROD1 CEMENT CIRC T Circulate on top of first plug at 10 BPM-1700 PSI,slowing pumps to overboard-20 BBLS contaminated cement-OBM mud to rockwasher. 11:30 12:00 0.50 7,566 7,566 PROD1 CEMENT PRTS T RU cement head. Pump 5 BBLS of mud push,and pressure test lines again to 3000 PSI. Crew Change. 12:00 12:15 0.25 7,566 7,566 PROD1 CEMENT CMNT T Continue pump 20 BBLS of mud push, 57 BBLS of 17 PPG cement,4 BBLS of mud push and displace with 1025 stks of OBM. 12:15 13:00 0.75 7,566 7,566 PROD1 CEMENT CIRC T Displace cement with OBM at 4.5 BPM-380 P.SI. Blow down Top Drive and lay down cement head. 13:00 13:45 0.75 7,566 6,830 PROD1 DRILL TRIP T POOH from 7566'-6830'MD. UP WT=150K. 13:45 15:00 1.25 6,830 6,830 PROD1 DRILL CIRC T Circulate bottoms up at 11.5 BPM- 1640 PSI.Observed no cement returns at surface. 15:00 16:00 1.00 6,830 5,560 PROD1 DRILL TRIP T POOH form 6830'-5560'MD. Observed proper displacement. 16:00 16:30 0.50 5,560 5,560 PROD1 DRILL OWFF T Pump 30 BBLS dry job. Monitor well. 16:30 18:00 1.50 5,560 1,726 PROD1 DRILL TRIP T Continue POOH from 5560'to 1726'. _ Observed proper displacement. 18:00 18:30 0.50 1,726 1,726 PROD1 DRILL RURD T Held PJSM. Rig up 3 1/2"handling equipment. 18:30 20:15 1.75 1,726 0 PROD1 DRILL TRIP T POOH lay down 3 1/2"stinger assembly. Breakout, inspect and lay down BOT running tool. 20:15 22:00 1.75 0 0 PROD1 DRILL PULD T Rig down handling equipment, crossovers and tools. Page 28 of 57 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 22:00 22:30 0.50 0 0 PROD1 DRILL PULD T Clean&clear rig floor area. Pull tools to rig floor. 22:30 23:00 0.50 0 0 PROD1 DRILL SFTY T Held PJSM with crew,and Sperry Sun reps. Discuss safety&hazard recognition issues. Discuss procedure to make up BHA and load nukes. 23:00 00:00 1.00 0 0 PROD1 DRILL PULD T Make up 9 7/8"Security FXG56X bit with TFA of 1.108 sq. in.on 7600 Geo-Pilot. Make up BHA to 102'. Crew Change 01/26/2011 Continue make up 9 7/8"drilling BHA#4.Observed trouble with reading MWD assembly as it was cold. Utilize steam&rig up to circulate through assembly with warm mud. Install nukes,perform Shallow pulse test,and pressure test Geo Skid unit.Trip in hole to tag up on bridges at 3493'MD.Contiue washing down through bridges,tagging hard cement at 6715'MD. Drill cement to 7144'MD.Observed survey indications that we came out on the low side of hole at 7144'Drill to 7269'. 00:00 04:30 4.50 0 110 PROD1 DRILL PULD T Continue make up drilling BHA#4. Plug in and upload assembly. Install nukes.Observed tool too cold to read.Attempt to steam tools and read with no success.Make up Top Drive,and float sub. Lower tools into well,and pump warm mud through assembly. Plug in a nd upload tools with success. Blow down Top Drive. 04:30 07:45 3.25 110 220 PROD1 DRILL DHEQ T Make up 2 flex drill collars. Space out to load nukes. Held PJSM.Test Geo Skid to 3500 PSI. Perform shallow pulse test. Blow down Top Drive and Geo Skid.Clear rig floor and Load nukes. Secure rig floor. 07:45 10:00 2.25 220 2,632 PROD1 DRILL TRIP T Continue make up remaiing BHA and trip in hole to 2632 instaloling Ghost reamer in between stands#12 and / #13. ✓ 10:00 11:30 1.50 2,632 2,632 PROD1 DRILL CIRC T Make up Top Drive and circulate to fill drill string.Send Doen link to Geo Pilot for test downlink. Blow down Top Drive&Geo Skid. 11:30 12:00 0.50 2,632 2,632 PROD1 DRILL WOC T Monitor well via trip tank while wait on cement.Crew Change 12:00 12:30 0.50 2,632 2,632 PROD1 DRILL WOC T Continue monitor well via trip tank while wait on cement. 12:30 13:00 0.50 2,632 2,632 PROD1 RIGMNT SVRG T Service rig&Top Drive.Calibrate block height. 13:00 13:30 0.50 2,632 3,493 PROD1 DRILL TRIP T Trip in hole form 2632'to tag up on a bridge at 3493'MD. 13:30 15:15 1.75 3,493 4,337 PROD1 DRILL REAM T Make up Top Drive and wash&ream from 3493'-4337'. Pumps at 600 GPM's-2180 PSI. RPM's 150.TQ= 4K. UP WT=150K,SO WT=120K. ROT WT=132K. Page 29 of 57 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 15:15 19:00 3.75 4,337 6,715 PROD1 DRILL CIRC T Circulate bottoms up at 4337'MD. Pumps at 525 GPM's-2050 PSI. Wash down to 4432'MD. Continue wash&ream from 4432'-6715'MD. Observed numerous stringers bridges)washing down, until tagged up on hard cement at 6715'MD. 19:00 22:15 3.25 6,715 7,269 PROD1 DRILL DDRL T Drill hard cement from 6715'-7269' MD.Observed weight on bit fall off and surveys indictaed we had come out on the low side of hole at 7144' MD. Pumps at 600 GPM's-2180 PSI with 150 RPM's.TQ=4K. UP WT=150K,SO WT=120K, ROT WT=130K.Observed gasket on shock hose on#2 mud pump failed and leaked. 22:15 00:00 1.75 7,269 7,366 PROD1 DRILL DDRL T Remove shock hose,and replace gasket.Continue with#1 mud pump at 470 GPM's-1720 PSI with ROP minimized at 80 ft/hr with deflection at 60 Left to obtain kick off. Drill to 7366'MD.Obtain surveys to verify kick off. Fluid losses for the day=0 BBLS.Crew Change 01/27/2011 Continue Directional Drill from 7269'-9198'.TVD-3948'.ADT 15.93 HRS.Total Bit HRS=15.93.Total Jar HRS= 15.93.Max Gas observed-86 Units. Fluid Loss-0 BBLS. 00:00 03:00 3.00 7,366 7,459 PROD1 DRILL DDRL T Control Directional Drill 9 7/8"Hole from 7366'-7459'MD.TVD=3562'. Pumps at 447 GPM's-1550 PSI. 150 RPM's.WOB=4-6 K.Torque on =7K. UP WT= 198K. SO WT= 110K. ROT WT= 150K.ADT=1.93 HRS.Total Bit HRS=2.75.Total Jar HRS=2.75. Max gas observed=14 Units. ECD's-10.66 PPG. Obtained SPR's. 03:00 06:00 3.00 7,459 7,646 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 7459'-7646'MD.TVD=3592'. Pumps at 720 GPM's-3700 PSI. 150 RPM's.WOB=4-6 K.Torque on =7K. UPWT=200K. SOWT= 109K. ROT WT= 151K.ADT=1.93 HRS.Total Bit HRS=4.69.Total Jar HRS=4.69. Max gas observed=40 Units. ECD's-10.71 PPG. 06:00 12:00 6.00 7,646 8,211 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 7646'-8211'MD.TVD=3722'. Pumps at 725 GPM's-3700 PSI. 150 RPM's.WOB=4-6 K.Torque on =7K. UP WT=206K. SO WT= 112K. ROT WT= 158K.ADT=4.28 HRS.Total Bit HRS=8.97.Total Jar HRS=8.97. Max gas observed=51 Units. ECD's-10.72 PPG.Crew Change Obtained SPR's Page 30 of 57 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 12:00 21:30 9.50 8,211 8,800 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 8211'-8800'MD.TVD=3854'. Pumps at 740 GPM's-3700 PSI. 150 RPM's.WOB=4-6 K.Torque on =7K. UP WT=210K. SO WT= 110K. ROT WT= 158K.ADT=4.38 HRS.Total Bit HRS=13.35.Total Jar HRS=13.35.Max gas observed =51 Units. ECD's-10.70 PPG. 21:30 22:30 1.00 8,800 8,800 PROD1 RIGMNT SVRG T Service rig.Change out swab&liner on mud pump#2. 22:30 00:00 1.50 8,800 9,198 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 8800'-9198'MD.TVD=3948'. Pumps at 760 GPM's-3850 PSI. 150 RPM's.WOB=4-6 K.Torque on =8K. UPWT=215K.SOWT= 112K. ROT WT= 160K.ADT=2.58 HRS.Total Bit HRS=15.93.Total Jar HRS= 15.93. Max gas observed =86 Units. ECD's-10.66 PPG. Crew Change Obtained SPR's. 01/28/2011 Continue Directional Drill from 9198'-9728'MD.4072'-ND.ADT=4.70 HRS.Total BIT HRS-20.63.Total Jar HRS-20.63. Pump Sweep while reciprocate&rotate drill string. Perform Wiper trip back to 6987'. Observed tight hole issues from 9160'-7930'. Pulled on elevators from 7930'-6987'.Circulated bottoms up. Run back in hole to tag up @ 9060'DPM. Oberved packing off issues when working through.Continue wash &ream down to 9160'DPM. Pumpe a 40 BBL-48 PPB Safeguard pill with to spot in formation.Continue work drill string until to clean up with free movement. Pumps at 675 GPM's 3700 PSI. 00:00 07:00 7.00 9,198 9,728 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 9198'-9728 MD.ND=4072'. Pumps at 735 GPM's-3900 PSI. 150 RPM's.WOB=4-5 K.Torque on =8K. UP WT=215K.SO WT= 120K. ROT WT=160K.ADT=4.70 HRS.Total Bit HRS=20.63.Total Jar HRS=20.63. Max gas observed v/ =65 Units. ECD's-10.64 PPG. Planed Wiper Trip Depth. 07:00 09:30 2.50 9,728 9,728 PROD1 DRILL CIRC T Pump 28 BBLS 9.8 PPG sweep, circulating 1 1/2 bottoms up. Pumps at 725 GPM's-3900 PSI. Obtain SPR's. Reciprocate&rotate drill string. 09:30 10:30 1.00 9,728 9,160 PROD1 DRILL WPRT T Blow down Top Drive. POOH on elevators observing good hole conditions and proper displacement form 9728'-9160'DPM.Work through tight spot with pumps, @ 9200'-9100'. Decision to BROOH. Page 31 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 9,160 8,874 PROD1 DRILL REAM T Back ream out of hole from 9160'- 8874'. Pumps at 725 GPM's-3800 PSI. 150 RPM's-7K TQ.Work through tight spots,observing some packing off. Pump sweeps as needed observing no noticeable increase or decrease in cuttings on shakers, no big pieces. Crew Change 12:00 17:30 5.50 8,874 7,930 PROD1 DRILL REAM T Continue BROOH from 8874'-7930'. Pumps at 725 GPM's-3700 PSI. 150 RPM's-7K TQ.Work through tight spots,observing some packing off. Pump sweeps as needed observing no noticeable increase or decrease in cuttings on shakers, no big pieces. No increase in torque, but hole sticky. Pulled until we could verify free movement with no rotation or pumps. 17:30 18:30 1.00 7,930 6,893 PROD1 DRILL WPRT T Continue wiper trip pulling out on elevators from 7930'-6893'.Above kick off point.Observed proper displacement. No overpulls. 18:30 19:30 1.00 6,893 6,893 PROD1 DRILL CIRC T CBU while reciprocate&rotate drill string. Pumps at 725 GPM's-3440 PSI. 150 RPM's.Observed no noticeable increas in cuttings on bottoms up. Blow down top drive& lines. 19:30 20:30 1.00 6,893 9,070 PROD1 DRILL WPRT T Run in hole on elevators from 6893'- 9070'.Observed tag up.Attempt to work through tight spot with no pumps. No success. UP WT 190K, SO WT= 120K. 20:30 00:00 3.50 9,070 9,160 PROD1 DRILL REAM T Make up top drive.Wash&ream in hole from 9070'-9160'.Stage pumps up to 650 GPM's-3200 PSI. Observed packing off initially, but no increase in torque.Continue work through tight spots,observing trend repeating itself at 9070' DPM,taking weight,packing off. Break out&lay down single.Canrig described litholgy as siltstone to claystone transition. Indications of instability. Pump a 40 BBL Safeguard 48 PPB pill to spot made up of Safeguard 20,40 and S200 hoping to heal formation.Continue work drill string to get full stand down plus single, and hole cleaning up allowing free movement. Observed pack off once again when making connection. Crew Change. Page 32 of 57 r-^ Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 01/29/2011 24 hr Summary Continue wash&ream back in hole for wiper trip. Observed hole with higher torques,and taking weight with no pump pressure increase. Pumps at 650 GPM's-3750 PSI. Indications of stability issues. Increase mud weight to 10.0 PPG for control.Continue wash in hole observing taking weight at times,no pressure increase, suspecting ghost reamer hanging up or pushing cuttings.Continuously monitor updated ABI surveys to verify no sidetracking.WOB up to 20K at times to get ghost reamer to break through and allow travel in hole.Once on bottom,circulate Hi Visc weighted sweep observing considerable increase in cuttings across shakers. Continue directional drill from 9728'-10840'MD.TVD=4340'.ADT=9.80 HRS Total Bit&Jar HRS=30.43. 00:00 05:00 5.00 9,160 9,728 PROD1 DRILL REAM T Continue wash&ream back in hole for wiper trip from 9160'to 9728'. Observed hole with higher torques, and taking weight with no pump pressure increase. Pumps at 650 GPM's-3750 PSI. Indications of stability issues. Bring mud weight to 10.0 PPG for control.Continue wsh in hole observing taking weight at times,no pressure increase, suspecting ghost reamer hanging up or pushing cuttings.Continuously monitor updated ABI surveys to verify no sidtracking.WOB up to 20K at times to get ghost reamer to break through and allow travel in hole. Observed less cuttings on shakers when obtained 10.0 PPG mud in wellbore.Continued to keep 650 GPM's-3750 PSI with 150 RPM's. Torque steady at 7-8 K. 05:00 08:30 3.50 9,728 9,728 PROD1 DRILL CIRC T Circulate pumping a 50 BBL weighted sweep to 12.0 PPG. Pumps @ 700 GPM's-3800 PSI. Reciprocate&rotate drill string. Observed considerable increas in cuttings when sweep came back and again 1000 stks later. 08:30 12:00 3.50 9,728 10,025 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 9728'-10025'MD.ND=4142'. Pumps at 703 GPM's-3900 PSI. 150 RPM's.WOB=10-12 K.Torque on=9K. UP WT=220K.SO WT= 108K. ROT WT=155K.ADT=2.28 HRS.Total Bit HRS=22.91.Total Jar HRS=22.91.Max gas observed =52 Units. ECD's-11.0 PPG. Mud Wt= 10.0 PPG Crew Change 12:00 18:00 6.00 10,025 10,487 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 10025'-10487'MD.ND=4255'. Pumps at 703 GPM's-3930 PSI. 160 RPM's.WOB=6-8 K.Torque on =9K. UP WT=230K.SO WT= 110K. ROT WT=160K.ADT=3.88 HRS.Total Bit HRS=26.79.Total Jar HRS=26.79.Max gas observed =56 Units. ECD's-11.02 PPG. Mud Wt= 10.0 PPG Page 33 of 57 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 18:00 00:00 6.00 10,487 10,840 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 10487'-10840'MD.TVD=4340'. Pumps at 703 GPM's-4000 PSI. 160 RPM's.WOB=6-8 K.Torque on = 10K. UPWT=230K. SOWT= 110K. ROT WT=160K.ADT=3.64 HRS.Total Bit HRS=30.43.Total Jar HRS=30.43. Max gas observed =80 Units. ECD's-10.89 PPG.Mud Wt=10.0 PPG Crew Change 01/30/2011 Continue Directional drilling 9 7/8"Production hole from 10840'-11247'MD.ND=4438'.ADT=3.68 HRS. Total Bit&Jar HRS=34.11.Changed out Liner gasket on Mud Pump#1. Pump a 30 BBLS weighted sweep and 3 bottoms up.Observed cuttings increase when sweep back. Pained wiper trip. POOH first 5 stands, until pulling tight. BROOH from 10774'-9920'.Observed packing off issues with pump t=rates at 600 GPM's- 3000 PSI. 160 RPM's and 8 K TQ. No increase in torque observed when packing off.Work through tight spots. String speed limited to 1 1/2-2 ft/minute.When attempting to POOH on elevators,pipe would pull free for a short time,then pulled tight again and work through spots. Continue to BROOH. 00:00 03:45 3.75 10,840 11,075 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 10840'-11075'MD.ND=4396'. Pumps at 701 GPM's-4040 PSI. 160 RPM's.WOB=3-5 K.Torque on =9K. UP WT=250K. SO WT= 92K. ROT WT= 166K. Max gas observed=62 Units. ECD's-10.89 PPG.Mud Wt=10.0 PPG 03:45 04:45 1.00 11,075 11,075 PROD1 DRILL RGRP T Change out Liner gasket on Mud Pump#1. reciprocate&rotate drill string at 450 GPM's-1900 PSI. 04:45 07:00 2.25 11,075 11,247 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 11075'-11247'MD.ND=4438'. Pumps at 701 GPM's-4080 PSI. 160 RPM's.WOB=3-5 K.Torque on =9K. UP WT=252K. SO WT= 92K. ROT WT= 166K.ADT=3.68 HRS.Total Bit HRS=34.11.Total Jar HRS=34.11.Max gas observed =60 Units. ECD's-10.97 PPG. Mud Wt= 10.0 PPG. Planned depth for wiper trip. 07:00 10:30 3.50 11,247 11,247 PROD1 DRILL CIRC T Pump a 30 BBL weighted sweep plus 3 bottoms up at 700 GPM's- 4050 PSI while reciprocate&rotate drill string.Observed increase in cuttings when sweep across shakers,and again on each bottoms up.Monitor well-static. 10:30 12:00 1.50 11,247 10,774 PROD1 DRILL WPRT T POOH first 5 stands from 11247'- 10774'.Observed good hole fill. Pulled tight at top of last stand.Crew Change Page 34 of 57 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 00:00 12.00 10,774 9,005 PROD1 DRILL WPRT T BROOH to 9920'.Attempted various parameters on BROOH,observing the sweet spot was 600 GPM's- 3000 PSI. 160 RPM's.Our trip speed was 1 '/2-2 ft/minute. If we tried pulling harder,pack off problems immediately.Work through each one. No noticeable increase in cuttings across shakers.Observed no Torque increases. Continue work string to bit depth of 9731', BROOH as above.,observed freer movement 9700'. Attempt to POOH on elevators. From 9731'-9250'3 stands.230K up wt. Fluid falling taking correct displacement. Once again,pulled tight, up to 30K over. BROOH at parameters as above from 9250'-9065'. Observed no Torque increases. Packing off,and we had hell gaining back full pump rates initially,but they came.We observed the hole would allow us to pull 4-5 ft/minute now,and eventually teased us into trying again on elevators. POOH on elevators form 9065'- 9005'.String Speed 16 ft/minute 230K up wt. Fluid falling taking correct displacement. But pulling tight again after 60'. . Crew Change 01/31/2011 Continue BROOH from 9920'.Attempt to pull on elevators with free movement for short time,and then.pulling tight.Continue BROOH to 4242'. Maintain 600 GPM's with 150 RPMs.Work through packoff isues,gaining free movement and good flow. Max gas observed-46 units. Fluid losses=87 BBLS. 00:00 12:00 12.00 9,920 6,246 PROD1 DRILL WPRT T Continue BROOH from 9005'-8970'. ✓/ Freer movement. POOH on elevators from 8970'- 8496'. Fluid falling taking correct displacement. Pulled tight again. Screw in and BROOH from 8496' staying with it to pump our cuttings out.Continue with 600 GPM's-2900 PSI, 160 RPM's pulling at 1 '/%-5 ft minute,working through each packoff. BROOH with increasing string speeds to 30 ft/minute-full pump rates.Tight spots at 7366- 7330'.And 6249'.Crew Change 12:00 00:00 12.00 6,246 3,633 PROD1 DRILL WPRT T BROOH from 6249'-3633'MD,with parameters as above.Sweet spot while BROOH seemed to stay at 600 GPM's,with 150 RPM's. Pulling speeds 1 1/2-5 ft/minute. We were able to POOH on elevators from 6324'-4298'MD. UP WT-150K, Page 35 of 57 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 02/01/2011 24 hr Summary Continue BROOH from 3633'to the shoe.Observed the hole allowed fater pulling speeds,and while circulating unloaded the hole with up to 4"in diameter cuttings, of rocks and cement. Pictures on S drive. CBU at the show.Monitor well-static. POOH to BHA. Lay down Ghost reamer. Reamer in gauge. POOH lay down BHA.Make up BHA#6,without nukes.TIH to shoe at 2745'.Observed proper displacement.Slip&cut drilling line&service rig. Fluid loss for the day 19 BBLS. 00:00 04:30 4.50 3,633 2,745 PROD1 DRILL WPRT T Continue BROOH form 3633' to the shoe at 2745'MD. Observed hole allowed faster pulling speeds form 3435',and unloaded on the shakers up to 4"in diameter cuttings of rocks and cement. Pictures on the S drive. 04:30 05:30 1.00 2,745 2,745 PROD1 DRILL WPRT T Circulate at the show pumping a 25 BBL Hi visc weighted sweep to clean up the casing. Increased pump rates to 760 GPM's-3105 PSI.Reciprocate&rotate drill string. 05:30 07:00 1.50 2,745 1,780 PROD1 DRILL TRIP T Monitor well-static. POOH to Ghost reamer. Inspect and lay down same. Reamer in gauge. Pictures posted on S drive. 07:00 08:30 1.50 1,780 200 PROD1 DRILL TRIP T Monitor well-static. POOH to BHA. Rack back HWDP, and jars. Pull to MWD assembly. 08:30 09:30 1.00 200 200 PROD1 DRILL PULD T Held PJSM with crew&Sperry reps. Discuss safety&hazard recognition issues. Discuss procedure to rig up and pull nukes. Unload nukes. Secure rig floor. 09:30 10:00 0.50 200 100 PROD1 DRILL PULD T Rack back flex drill collars. 10:00 11:00 1.00 100 100 PROD1 DRILL TRIP T Plug in and download MWD assembly. 11:00 12:00 1.00 100 0 PROD1 DRILL PULD T Continue pull assembly laying down Pulsar collar to DM collar.Crew Change 12:00 12:30 0.50 0 0 PROD1 DRILL PULD T Continue lay down BHA. Pull to bit, breakout&inspect same.Grade bit j to 0/1/ER/N/X/I/NO/HP.Observed damage to housing on Geo-Pilot. Egg Shaped. Pictures taken and posted on S drive. 12:30 13:30 1.00 0 0 PROD1 WHDBO BOPE T Drain BOP stack. Blow air through lines. Function test all rams,and the annular. Function test NCR's. 13:30 15:30 2.00 0 200 PROD1 DRILL PULD T Make up bit(4RR1)to 7600 GEO-Pilot.Conitnue make up BHA without nukes. Install integral blade stabilizer above MWD assembly. 15:30 17:00 1.50 200 200 PROD1 DRILL PULD T Plug in and upload MWD assembly. Grease up Blocks,draw works,and top drive while upload. 17:00 18:30 1.50 200 200 PROD1 DRILL PULD T Continue RIH with one stand of flex driill collars,and one stand of HWDP. Break in seals on Geo pilot, and perform shallow pulse test witgh 538 GPM's-1210 PSI.Good test. Page 36 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 20:00 1.50 200 2,745 PROD1 DRILL TRIP T Continue run in hole with remaining HWDP,and DP to shoe at 2745'. Observed proper displacement. 20:00 21:00 1.00 2,745 2,745 PROD1 DRILL TRIP T Fill drill string. Pulse test MWD assembly,and perform down link to Geo Pilot. Pu,ps at 500 GPM's- 1540 PSI.60 RPM's. Blow down Top Drive. 21:00 21:15 0.25 2,745 2,745 PROD1 DRILL SFTY T Held PJSM with crew. Discuss safety&hazard recognition issues. Discuss procedure to slip&cut drilling line. 21:15 23:00 1.75 2,745 2,745 PROD1 RIGMNT SLPC T Rig up and cut 120'of drilling line. Slip new line on. 23:00 00:00 1.00 2,745 2,745 PROD1 RIGMNT SVRG T Service rig.Add oil to top drive. Grease&inspect sheaves&crown section. Inspect saver sub.Grease upper&lower IBOP's. Change out dies in iron roughneck. Crew Change 02/02/2011 Calibrate block height with TOTCO.TIH from 2700'to tag up and work through tight spot @ 4070'and again at 6992'.Work through packoff&tight hole condtions @ 8570.Continue work down to 9058'DPM.Work String to obtain free movement&circulation. Decision to POOH,plug back. BROOH from 9058'-8658'POOH on elevators working a tight spot at 6581'-6487'. POOH,monitor well at shoe and at the BHA. POOH racking back HWDP,Jars and flex collars. 00:00 00:30 0.50 2,745 2,745 PROD1 DRILL PULD T Quadco/Totco hands calibrating block height.Clean&Clear rig floor. 00:30 10:30 10.00 2,745 9,058 PROD1 DRILL WPRT T TIH from 2745',observing good hole conditions and proper displacement. Wash through area at 4050'MD,and continue in on elevators.Tag up at 8750'DPM.Work throughj packoff issues to gain full circulation at 700 GPM's-3750 PSI. Circulate a bottoms up observing heavy siltstone returns on all 3 shaker beds until cleaned up. Continue wash in hole fighting packoff issues to 9058 MD. 10:30 12:00 1.50 9,058 8,658 PROD1 DRILL REAM T BROOH from 9058'-8658'DPM gaining full circulation.Crew Change 12:00 15:00 3.00 8,658 6,581 PROD1 DRILL TRIP T Continue POOH on elevators from 8658'-6581'DPM. Pulled tight. 15:00 15:30 0.50 6,581 6,487 PROD1 DRILL TRIP T Make up top drive and work through tight hole and pack off conditions. Observed no increase in cuttings on bottoms up plus 1000 stks. 15:30 20:00 4.50 6,487 2,730 PROD1 DRILL TRIP T POOH on elevators from 6487'-2730' insode surface casing shoe. Observed proper displacement. 20:00 20:15 0.25 2,730 2,730 PROD1 DRILL OWFF T Monitor well-static. 20:15 21:00 0.75 2,730 2,730 PROD1 DRILL TRIP T Mix&pump dry job. Blow down Top Drive&lines. 21:00 23:00 2.00 2,730 600 PROD1 DRILL TRIP T POOH on elevators form 2730'-600'. Observed proper displacement. 23:00 00:00 1.00 600 100 PROD1 DRILL TRIP T Rack back HWDP&Jars in derrick. Rack back Non Mag flex drill collars. Crew Change. Page 37 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/03/2011 24 hr Summary Continue lay down drilling BHA.Clean&clear rig floor. Pull tools to rig floor. Make up BOT ECP packer,and RIH picking up 49 jnts of 3 1/2"PH-6 DP.Crossover to DP run in hole to spot ECP at 3600'MD as planned. RU Schlumberger, lines,and trucks. Held PJSM. Pump 96 BBLS 17#cement for first plug from 3600'-3000'. POOH,wash off top 100'of cement as planned to observed about 4 BBLS back to surface. Mix and pump second plug,78.2 BBLS of 17#cement from 3100'-2500'. POOH above cement.CBU. POOH breakout&lay down tools. 00:00 01:00 1.00 100 0 PROD1 DRILL PULD T Continue POOH. Breakout&lay down BHA. Inspect&grade bit. 01:00 02:30 1.50 0 0 PROD1 DRILL PULD T Clean&clear rig floor.Send tools out. 02:30 04:00 1.50 0 0 PROD1 DRILL PULD T Rig up Doyon casing with power tongs.Check strap on 3 1/2"PH-6 DP. Held PJSM with crew&BOT rep. Discuss safety&hazard recognition issues. Discuss procedure to make up ECP and run in hole with 3 1/2"PH-6 DP. 04:00 07:30 3.50 0 1,528 PROD1 CEMEN"TRIP T Make up BOT ECP packer with crossovers to 3 1/2"PH-6 DP. Continue RIH picking up 49 jnts of 3 1/2"pipe. (1528.43'). 07:30 08:30 1.00 1,528 1,528 PROD1 CEMEN"TRIP T Crossover to 5"DP and continue RIH to spot&locate ECP @ 3600'DPM. Fill tbg. 08:30 10:00 1.50 1,528 3,600 PROD1 CEMEN"TRIP T Continue TIH with 5"DP. Position ECP at 3600'as planned. 10:00 11:00 1.00 3,600 3,600 PROD1 CEMEN-RURD T Make up cement head&lines. Fill drill pipe. ICP-4 BPM-475 PSI. FCP-4 BPM-350 PSI. 11:00 12:00 1.00 3,600 3,600 PROD1 CEMEN"PACK T Pressure test lines to 3000 PSI. Drop pump down plug. Latch dart in LWP.Continnue pressure up to shear at 700 PSI. Observe ECP inflation with calculated volume of.7 BBLS pumped.Observed disconnect with 2500 PSI. Pull up 10 ft.Crew Change 12:00 12:30 0.50 3,600 3,600 PROD1 CEMEN"PLUG T Circulate @ 3 BPM-155 PSI. Held PJSM with crew,cementers. Discuss safety&hazard recognition issues. Discuss procedure to pump 2 cement plugs. 12:30 14:30 2.00 3,600 3,600 PROD1 CEMEN"PLUG T Turn over to Schlumberger.Test lines to 3000 PSI. Pump 23 BBLS of 12.5#Mud Push&95 BBLS of 17# cement. Displace with rig pumps 34 BBLS to balance. SHut down. 14:30 16:30 2.00 3,600 3,100 PROD1 CEMEN"PLUG T Breakout&lay down cement head. POOH slowly from 3600'-3000'. Dry pipe.Wash back down to 3100'as planned. CBU observing 4 BBLS of cement back to surface. 16:30 17:30 1.00 3,100 3,100 PROD1 CEMEN"PLUG T Rig up and test lines to 3000 PSI. Pump 24 BBLS of 12.5#Mud Push &78.2 BBLS of 17#cement. Displace with rig pumps 25 BBLS to balance. Shut down. Page 38 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 19:00 1.50 3,100 2,000 PROD1 CEMEN"PLUG T POOH slowly from 3100'-2000'. Dry _ pipe. UP WT= 100K,SO WT 100K. 19:00 20:00 1.00 2,000 2,000 PROD1 CEMEN'CIRC T Circulate bottoms up x 2 observing no cement returns to surface.Pumps at 420 GPM's-1000 SPI. 20:00 20:30 0.50 2,000 1,541 PROD1 CEMENT TRIP T POOH, racking back 5 stands of DP. 20:30 21:00 0.50 1,541 1,541 PROD1 CEMEN'RURD T Rig up 3 1/2"tbg handling equipment. 21:00 00:00 3.00 1,541 0 PROD1 CEMEN"PULD T POOH laying down 3 1/2"PH-6 Tbg. (49 jnts). Breakout&lay down running tools and crossovers.Crew Change 02/04/2011 Clean&clear rig floor. Rig up and test BOP's.250/3500 PSI.Witness of test waived by AOGCC rep Chuck Sheve.Service rig. Make up 9 7/8"Drilling BHA with motor.TIH to tag cement stringers at 2300'MD. Continue wsh down tagging firm cement at 2450'MD. Drill cement to 2695'MD. Displace well with WBM LSND 9.5 PPG mud at 600 GPM's 2600 PSI. 00:00 03:00 3.00 0 0 PROD1 WHDBO PULD T Clean&clear rig floor area. Rig down tbg handling equipment.Clean OBM from tools. Breakout pups from cement head. Breakout XO's.Send tools out. 03:00 03:30 0.50 0 0 PROD1 WHDBO BOPE T Install joint, BOLDS and pull wear bushing. 03:30 03:45 0.25 0 0 PROD1 WHDBO SFTY T Held PJSM. Discuss safety&hazard recognition issues. Discuss procedure to rig up test BOP's. Install High Pressure signs. 03:45 04:30 0.75 0 0 PROD1 WHDBO BOPE T Make up test joint and test plug. RIH set same. 04:30 09:30 5.00 0 0 PROD1 WHDBO BOPE T RU&perform BOP test.Test all rams,and annular.Test choke manifold and all valves.Test floor safety valves.Al test 250/3500 PSI. Perform Koomey test. First 200 PSI in 37 secs. Full 3000 PSI in 195 secs. 5 Bottles of nitrogen with AVG pressure of 2400 PSI. Perform test on all gas alarms. Witness of test waived by AOGCC rep Chuck Sheve. 09:30 11:00 1.50 0 0 PROD1 WHDBO BOPE T Blow down all lines. Remove signs. Pull test plug. Install wear bushing. RILDS. 11:00 12:00 1.00 0 0 PROD1 RIGMNT SVRG T Servie rig dra works,Top Drive, Blocks,and Iron roughneck.Crew Change 12:00 12:30 0.50 0 0 PROD1 DRILL SFTY T Held PJSM with crew,and Sperry Sun reps. Discuss safety&hazard recognition issues. Discuss procure to make up BHA. 12:30 14:30 2.00 0 0 PROD1 DRILL PULD T Make up 9 7/8"Hycalog DTX619M-B10 Bit jetted for 1.035 sq. in.TFA, on a 7"Sperrylobe 7/8 6.0 stage motor.Continue make up MWD assembly,scribe motor to MWD. 14:30 15:30 1.00 0 0 PROD1 DRILL PULD T Plug in and upload MWD assembly. Page 39 of 57 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 15:30 16:00 0.50 0 0 PROD1 DRILL PULD T Continue make up stand of flex drill collars. 16:00 16:30 0.50 0 0 PROD1 DRILL PULD T Perform shallow pulse test with pumps at 500 GPM's-1350 PSI. Good test. 16:30 17:30 1.00 0 0 PROD1 DRILL PULD T Blow down Top Drive&lines. Held PJSM-Nukes. Install nuke sources as per MWD reps. 17:30 18:00 0.50 0 651 PROD1 DRILL PULD T Continue make up BHA with Flex drill collar,and HWDP&Jars from derrick.Total length of BHA= 651.24' 18:00 19:30 1.50 651 2,000 PROD1 DRILL TRIP T Trip in hole from 651'-2000'MD. 19:30 21:00 1.50 2,000 2,450 PROD1 DRILL WASH T Make up Top drive and wash down from 2000'-tag firm cement at 2450' MD. Observed cement stringers at 2300'. Pumps at 600 GPM's-2520 PSI with 50 RPM's. 21:00 22:45 1.75 2,450 2,695 PROD1 DRILL DDRL T Continue drill firm cement from 2450' -2695'MD with pumps at 600 GPM's -2600 PSI. 50 RPM's and 4-6KTQ. 22:45 00:00 1.25 2,695 2,695 PROD1 DRILL CIRC T Circulate bottoms up,and displace well with LSND mud.9.5 PPG. Pumps at 600 GPM's-2600 PSI. UP WT= 135K,SO WT=125K, ROT WT=130K. Crew change. 02/05/2011 /fp Continue displace well with 9.5 PPG LSND mud.Clean out troughs,and shakers area of OBM mud. Drill firm �G/(.� cement from 2695'-2745'MD(SHOE).Continue directional drill 9 7/8"hole kicking off et 2755' with drilling& survey indications coming out of bottom side of hole.Directional Drill form 2745'-4805'MD.TVD=2952'.ADT = 10.64 HRS.AST=1.61 HRS.Total Bit HRS= 12.25.Total Jar HRS=46.36 Max Gas observed=46 Units. Max ECD=10.78 PPG. 00:00 00:30 0.50 2,695 2,695 PROD1 DRILL CIRC T Continue displace well with 9.5 PPG LSND mud with pumps at 600 GPM's-600 PSI. 00:30 01:30 1.00 2,695 2,695 PROD1 DRILL CIRC T Clean out OBM from troughs,and lines. Clean out under shakers, mud pump lines. 01:30 02:15 0.75 2,695 2,745 PROD1 DRILL DDRL T Drill firm cement from 2695'-2745' CLS MD.(SHOE). 02:15 12:00 9.75 2,745 3,586 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from �^ 2745"-3586'MD.TVD=2629'. J Pumps at 750 GPM's-1750 PSI.75 RPM's.WOB=4-6 K.Torque on= 5K. UP WT= 141K.SO WT=120K. ROT WT=134K.ADT=3.20 HRS.AST=.77 HRS.ART=4.53 HRS Total Bit HRS=5.30.Total Jar HRS=39.41. Max gas observed= 116 Units. ECD's-10.25 PPG. Obtain Slow pump rates. Crew Change Page 40 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 3,586 4,239 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 3586'-4239'MD.TVD=2807'. Pumps at 780 GPM's-2350 PSI. 110 RPM's.WOB=2-4 K.Torque on =7K. UPWT= 147K. SOWT= 125K. ROT WT=135K.ADT=3.69 HRS.AST=.48 HRS.ART=3.21 HRS Total Bit HRS=8.99.Total Jar HRS=43.10. Max gas observed= 50 Units. ECD's-10.60 PPG. 18:00 00:00 6.00 4,239 4,805 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 4239'-4805'MD.TVD=2952'. Pumps at 800 GPM's-2610 PSI. 110 RPM's.WOB=2-4 K.Torque on =8K. UPWT= 155K.SOWT= 125K. ROT WT= 135K.ADT=3.26 HRS.AST=.36 HRS.ART=2.90 HRS Total Bit HRS=12.25.Total Jar HRS=46.36.Max gas observed= 46 Units. ECD's-10.78 PPG.Obtain Slow Pump Rates.Crew Change 02/06/2011 Continue directional drill 9 7/8"Production hole from 4805'-4995'for wiper trip depth. Pump weighted sweep observing 30%increase in cuttings when sweep came back. BROOH at drilling rates 30-40 ft/minute for wiper trip to shoe.CBU.Trip back in hole with good hole conditions.Wash down last stand,and continue drilling. Drill from 4995'-6320'MD TVD=3355'.ADT=9.46 HRS.AST=.61 HRS.Total Bit=21.71 HRS.Total Jar HRS=55.82.Max gas observed=116 units. ECD=10.78 PPG. 00:00 01:30 1.50 4,805 4,995 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 4805'-4995'MD.TVD=3002'. v7 Pumps at 800 GPM's-2580 PSI.90 RPM's.WOB=4-6K.Torque on= 7K. UP WT=155K.SO WT=132K. ROT WT=139K.ADT=1.13 HRS.AST=.22 HRS.ART=.91 HRS Total Bit HRS=13.38.Total Jar HRS=47.49. Max gas observed= 116 Units. ECD's-10.76 PPG. 01:30 02:15 0.75 4,995 4,995 PROD1 DRILL CIRC T Pump weighted sweep with pumps at 800 GPM's-2600 PSI.Observed approximately 30%increase in cuttings when sweep back across shakers. Reciprctae&rotate drill string with 110 RPM's. 02:15 06:30 4.25 4,995 2,745 PROD1 DRILL WPRT T BROOH at drilling rates form 4995'to shoe @ 2745'. String speed 30-40' ft/minute.Observed good hole and proper displacement. 06:30 07:45 1.25 2,745 2,745 PROD1 DRILL CIRC T Circulate bottoms up with increase in cuttings. Perform baseline ECD model. Blow down Top drive&lines. Monitor well-static. 07:45 09:15 1.50 2,745 4,995 PROD1 DRILL WPRT T Trip back in hole on elevators observing good hole conditions and proper displacement. make up top drive and wash down last stand at drilling rates to 4995'MD. Page 41 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 12:00 2.75 4,995 5,279 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 4995'-5279'MD.ND=3079'. Pumps at 800 GPM's-2610 PSI. 105 RPM's.WOB=4-7K.Torque on =8K. UP WT=157K.SO WT= 133K. ROT WT=140K.ADT=1.70 HRS.AST=.12 HRS.ART=1.58 HRS Total Bit HRS=15.08.Total Jar HRS=49.19. Max gas observed= 26 Units. ECD's-10.38 PPG. Obtained SPR's.Crew Change li 12:00 18:00 6.00 5,279 5,885 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 5279'-5885'MD.ND=3232'. Pumps at 795 GPM's-2950 PSI. 120 RPM's.WOB=4-6K.Torque on = 10K.UPWT= 170K.SOWT= 130K. ROT WT=145K.ADT=3.88 HRS.AST=.18 HRS.ART=3.70 HRS Total Bit HRS=18.96.Total Jar HRS=53.07. Max gas observed= 39 Units. ECD's-10.77 PPG. 18:00 00:00 6.00 5,885 6,320 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 5885'-6320'MD.ND=3355'. Pumps at 785 GPM's-2970 PSI. 120 RPM's.WOB=4-6K.Torque on = 11K. UP WT=175K.SO WT= 135K. ROT WT=145K.ADT=2.75 HRS.AST=.09 HRS.ART=2.66 HRS Total Bit HRS=21.71.Total Jar HRS=55.82. Max gas observed= 40 Units. ECD's-10.76 PPG. Obtained SPR's.Crew Change 02/07/2011 Continue directional drill from 6320'-6983'MD.ND=3535'. CBU pumping a weighted sweep. BROOH for wiper trip to 4800'at drilling rates observing good hole conditions. Hole unloading on bottoms up. Service rig. TIH with correct displacement.Wash down last stand and continnue directional drilling from 6983'-7644'MD. ND=3708'.ADT=8.96 HRS.AST=.55 HRS.Total Bit HRS=30.67.Total Jar HRS=64.78. MAx gas v/ observed=60 units. ECD= 10.77 PPG. 00:00 06:00 6.00 6,320 6,794 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 6320'-6794'MD.ND=3486'. Pumps at 800 GPM's-3190 PSI. 120 RPM's.WOB=4-6K.Torque on = 12K. UPWT=185K.SOWT= 147K. ROT WT= 131K.ADT=3.63 HRS.AST=.45 HRS.ART=3.18 HRS Total Bit HRS=25.34.Total Jar HRS=59.45.Max gas observed= 11 Units. ECD's-10.71 PPG. Page 42 of 57 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:00 08:15 2.25 6,794 6,983 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 6794'-6983'MD.TVD=3535'. Pumps at 800 GPM's-3210 PSI. 120 RPM's.WOB=4-6K.Torque on = 12K. UP WT= 186K.SO WT= 150K. ROT WT=130K.ADT=1.28 HRS.AST=.0 HRS.ART=1.28 HRS Total Bit HRS=26.62.Total Jar HRS=60.73. Max gas observed= 16 Units. ECD's-10.77 PPG. Obtained SPR's. 08:15 09:45 1.50 6,983 6,983 PROD1 DRILL CIRC T Circulate pumping a weighted sweep. Reciprocate&rotate drill string with drilling parameters.Observed 25% increase in cuttings when sweep across shakers. Monitor well-static. 09:45 12:00 2.25 6,983 5,752 PROD1 DRILL WPRT T BROOH at drilling rates for wiper trip to 5752'MD.Crew Change 12:00 13:30 1.50 5,752 4,800 PROD1 DRILL WPRT T Continue BROOH at drilling rates for wiper trip to 4800'MD. 13:30 14:30 1.00 4,800 4,800 PROD1 DRILL CIRC T Circulate pumping a weighted sweep. Reciprocate&rotate drill string with drilling parameters.Observed 25% increase in cuttings when sweep across shakers. Monitor well-static. 14:30 15:00 0.50 4,800 4,800 PROD1 RIGMNT SVRG T Service rig,Top Drive Draw works and blocks. 15:00 16:00 1.00 4,800 6,983 PROD1 DRILL TRIP T Trip back in hole observing good hole conditions and proper displacement. 16:00 18:00 2.00 6,983 7,173 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 6983'-7173'MD.TVD=3585'. Pumps at 767 GPM's-3520 PSI. 120 RPM's.WOB=6-8K.Torque on 13K. UPWT= 185K. SOWT= 145K. ROT WT=130K.ADT= 1.14 HRS.AST=.O HRS.ART=1.14 HRS Total Bit HRS=27.76.Total Jar HRS=61.87. Max gas observed= 40 Units. ECD's-10.70 PPG. Obtained SPR's. 18:00 00:00 6.00 7,173 7,644 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 7173'-7644'MD.TVD=3708'. Pumps at 795 GPM's-3610 PSI. 120 RPM's.WOB=6-8K.Torque on = 13K. UP WT=190K. SO WT= 150K. ROT WT= 125K.ADT=2.91 HRS.AST=.10 HRS.ART=2.81 HRS Total Bit HRS=30.67.Total Jar HRS=64.78.Max gas observed= 60 Units. ECD's-10.77 PPG. Obtained SPR's. Crew Change 02/08/2011 Continue directional drill from 7644'-9061'.TVD=4086'.ADT=10.21 HRS.AST=.48 HRS.Total Bit HRS= 40.88.Total Jar HRS=74.99. Max gas observed=46 units. ECD= 10.97 PPG. Circ. BU with noticible increase of cuttings across shakers. Backream OOH @ 25-30 FPM at drilling rates to 6984.. (Observed hole unloading on BU.) Page 43 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 7,644 8,209 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 7644'-8209 MD.TVD=3857'. Pumps at 800 GPM's-3710 PSI. 120 RPM's.WOB=6-8K.Torque on = 12K. UP WT=190K. SO WT= 135K. ROT WT=155K.ADT=3.85 HRS.AST= .15 HRS.ART=3.70 HRS Total Bit HRS=34.52.Total Jar HRS=68.63.Max gas observed= 46 Units. ECD's-10.92 PPG. Obtained SPR's. 06:00 12:00 6.00 8,209 8,612 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 8209'-8612 MD.TVD=3964'. Pumps at 790 GPM's-3790 PSI. 120 RPM's.WOB=8-10K.Torque on=13K. UP WT=190K.SO WT= 136K. ROT WT=158K.ADT=2.91 HRS.AST=.26 HRS.ART=2.65 HRS Total Bit HRS=37.43.Total Jar HRS=71.54.Max gas observed= 36 Units. ECD's-10.92 PPG. Obtained SPR's. 12:00 17:30 5.50 8,612 9,061 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole 8612'- 9061'MD,4086'TVD w/762 GPM/ 3740 PSI(ON BOTTOM)/ FLOWOUT 35%/120 RPM=13K TORQ(ON BOTTOM)/WOB=6-8 K/3600 PSI (OFF BOTTOM)/ P/UWT= 195K/SOWT=135K/ ROT WT=155K( PUMPS OFF)/ 12K TORQ(OFF BOTTOM)ECD'S =10.97 ppg/MAX GAS OBSERVED=46 UNITS/ADT= 3.45,ART=3.38,AST=0.07, BIT HRS=40.88,JAR HRS=74.99/ NOTE: PUMPED 40 BBL SWEEP 11.1 ppg ,53 vis ON STD#88 AND CIRULATED IT OUT OF HOLE WHILE DRILLED DOWN TO 9,061'MD STD#89( 1 1/2 TO 2 TIMES OF CUTTINGS INCREASED WITH SWEEP BACK TO SURFACE 17:30 18:30 1.00 9,061 9,061 PROD1 DRILL CIRC T CBU at 9061'MD. Pumps at 770 GPM-3 720 PSI 90 RPM Torque= 10K, ECD'S=10.85 ppg, MAX GAS =35 UNITS 18:30 21:30 3.00 9,061 7,500 PROD1 DRILL WPRT T Backream OOH from 9061'-7500'@ 750 gpm and 3500 psi. Torque on= 10K. UPWT=187K.SOWT= 125K.ECD's-10.83. Max Gas 70 units. Page 44 of 57 II— Time Logs I Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 22:30 1.00 7,500 7,400 PROD1 DRILL WPRT T Rotate and Recip while circ BU for ECD control. Observed at least 50% increase in cuttings at BU. Pumps @ 750 gpm and 3500 psi. 90 RPM, Torque on= 10K. UP WT=185K. SO WT=125K.ECD's-10.83. Max Gas 70 units. 22:30 00:00 1.50 7,400 6,984 PROD1 DRILL WPRT T Backream OOH from 7400'-6984'@ 750 gpm and 3400 psi. Torque on= 10K. UP WT=185K. SO WT= 130K.ECD's-10.90. Max Gas 70 units. 02/09/2011 Continue to backream out of hole from 6984'to shoe. Pumped from shoe to 1280'due to swabbing. Hole unloaded cuttings when circ at shoe. Pumped until hole cleaned up. Attempted to pull on elevators every 5 stands but continued to swab when attempted. 00:00 10:45 10.75 6,984 2,700 PROD1 DRILL WPRT T Backream OOH from 6984'-inside shoe @ 2700'pumping 750-800 gpm and 3080-2680 psi. Torque off =6K. UP WT= 140K. SO WT= 120K.ECD's-11.1,Observe some packing off at 3850'- 3710'and 3200 -3150. Circ and condition mud at shoe. Hole unloading cuttings. Pump until shakers clean up. 10:45 13:00 2.25 2,700 2,700 PROD1 RIGMNTSLPC T Slip and Cut Drlg Line 13:00 16:30 3.50 2,700 2,700 PROD1 RIGMNT SVRG T C/O saver sub, lubricate rig,tighten bolts on shot pin assembly. 16:30 20:00 3.50 2,700 2,550 PROD1 DRILL WPRT T Monitor well. POH on elevators f/ 2700-2550. UP WT=145k,SO WT=120k. Started swabbing well.. Break circ w/635 gpm @ 2190 psi. Saw gas increase to 300 units. Circulated nut plug/SAP sweep to breakup clay balling. Saw 60% increase in cuttings and gas dropped to 40 units after BU+. 20:00 00:00 4.00 2,550 1,280 PROD1 DRILL WPRT T Attempt to POH on elevators. Hole swabbing. Pump out of hole to 1280' w/3.5 BPM. 02/10/2011 Pulled out of hole and changed out MWD and bit. TIH to 9061'and drilled to 9252' 00:00 02:15 2.25 1,280 0 PROD1 DRILL TRIP T Continue pumping out of hole from 1280'-201'. Pumps at 3 BPM @ 190 psi. UPWT= 110KSOWT= .107 02:15 05:00 2.75 0 0 PROD1 DRILL PULD T LD BHA#6 MWD for battery change 05:00 05:45 0.75 0 0 PROD1 RIGMNT SVRG T Service Top Drive 05:45 07:15 1.50 0 40 PROD1 DRILL PULD T PU BHA#7 with new bit and MWD. Upload MWD tools 07:15 09:00 1.75 40 70 PROD1 DRILL PULD T Upload MWD tools. Bad read on nuke tool. LD pulser and nuke tool and PU new Page 45 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 11:00 2.00 70 70 PROD1 DRILL PULD T Continue PU BHA#7 with new bit and MWD. Upload new MWD tools and pulse test tools. Good test. Install source. 11:00 20:00 9.00 70 8,970 PROD1 DRILL WPRT T RIH w/HWDP Jars and 5"DP from 201'to 9061'. Fill pipe at 2800', 5345 and 7710'. Circulate gas out at 7710'with 577 gpm. Max gas=671 units. 20:00 00:00 4.00 9,061 9,252 PROD1 DRILL DDRL T Wash to bottom at 9061'. Directional Drill 9 7/8"Hole from 9061'- 9252'MD.TVD=4133'Pumps at 760 GPM's-3880 PSI. 120 RPM's.WOB =6-8K.Torque on=14K. UP WT= 198K.SO WT=130K. ROT WT= 145K.ADT=2.45 HRS.AST=.0 HRS.ART=2.45 HRS Total Bit HRS =2.45.Total Jar HRS=77.44.Max gas observed=10 Units. ECD's- 10.63 PPG. 02/11/2011 Continue directional drilling from 9252'-10,679'MD.TVD=4512. ADT=3.73 HRS.AST=.21 HRS.Total Bit HRS= 17.92.Total Jar HRS=92.91.Max gas observed=87 units. ECD=10.61 PPG. 00:00 06:00 6.00 9,252 9,604 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 9252'-9604'MD.ND=4223' Pumps at 760 GPM's-3980 PSI. 120 RPM's. Torque on=14K, Torque off= 13K.WOB=6-8K, UP WT=197K.SO WT=140K. ROT WT=155K.ADT=3.65 HRS.AST =.48 HRS.ART=3.17 HRS Total Bit HRS=6.10.Total Jar HRS= 81.09.Max gas observed=46 Units. ECD's-10.75 PPG. 06:00 12:00 6.00 9,604 9,918 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 9604'-9918'MD.ND=4305' Pumps at 760 GPM's-3980 PSI. 120 RPM's. Torque on= 14K, Torque off= 13K.WOB=4-8K, UP WT= 198K.SO WT=140K. ROT WT= 155K.ADT=3.80 HRS.AST =.32 HRS.ART=3.48 HRS Total Bit HRS=9.90.Total Jar HRS= 84.99.Max gas observed=36 Units. ECD's-10.61 PPG. 12:00 18:00 6.00 9,918 10,297 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 9918'-10297'MD.ND=4408' Pumps at 760 GPM's-3980 PSI. 120 RPM's. Torque on=15K, Torque off= 13K.WOB=6-12K, UP WT=200K.SO WT=140K. ROT WT=158K. ECD's-10.61 PPG. Page 46 of 57 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 10,297 10,679 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 10297'-10679'MD.TVD=4512'. Pumps at 750 GPM's-3500 PSI. 120 RPM's. Torque on=15K, Torque off= 13K.WOB=6-12K, UP WT=200K. SO WT=140K. ROT WT= 162K.ADT=3.73 HRS. AST=.21 HRS.ART=3.52 HRS Total Bit HRS=17.92 Total Jar HRS =92.91. Max gas observed=87 Units. ECD's-10.61 PPG. 02/12/2011 Directional drilled from 10,679' to 11,531'MD.TVD=4734. Max gas observed=58 units. ECD=10.6 PPG. Short tripped/BROOH to 8,868'. Circ 3 BU. Running back in hole at 9,919'to resume drilling. 00:00 06:00 6.00 10,679 11,102 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 10679'-11102'MD.TVD=4621'. Pumps at 800 GPM's-3850 PSI, 120 RPM's. Torque on=14K, Torque off= 12K.WOB=6-8K, UP WT=203K.SO WT=148K. ROT WI= 167K.ADT=4.43 HRS.AST =.21 HRS.ART=4.22 HRS Total Bit HRS=22.35 Total Jar HRS= 97.34. Max gas observed=58 Units. ECD's-10.61 PPG. 06:00 12:00 6.00 11,102 11,449 PROD1 DRILL DDRL T Directional Drill 9 7/8"Hole from 11102'-11449'MD.TVD=4711'. Pumps at 800 GPM's-3650 PSI, 120 RPM's. Torque on= 18K, Torque off=15K.WOB=6-8K, UP WT=205K.SO WT=145K. ROT WT=169K.ADT=3.83 HRS.AST =.61 HRS.ART=3.22 HRS Total Bit HRS=26.18 Total Jar HRS= 101.17.Max gas observed=36 Units. ECD's-10.68 PPG. 12:00 13:00 1.00 11,449 11,531 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 11449'-11531'MD.TVD=4734'. Pumps at 800 GPM's-3610 PSI, 120 RPM's. Torque on= 17K, Torque off= 13K.WOB=8-10K, UP WT=205K. SO WT=147K. ROT WT= 170K. ADT=3.83 HRS. AST=.0 HRS.ART=3.83 HRS Total Bit HRS=27.04Total Jar HRS = 102.03 Max gas observed=36 Units. ECD's-10.6 PPG. 13:00 14:15 1.25 11,531 11,531 PROD1 DRILL CIRC P Circulate and condition mud prior to short trip at 750 GPM-3440 PSI, Perform 15 min flow check prior to POH. 14:15 19:15 5.00 11,531 8,868 PROD1 DRILL REAM P BROOH f/11531'to 8868'MD. Pumps at 750 GPM-3500 PSI, 120 RPM,Torque=12-15k. Flow check at 10292 and 8868'. Page 47 of 57 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 19:15 20:00 0.75 8,868 8,868 PROD1 1 DRILL CIRC P Screens blinded off due to SakBlack product returning. Circ at 100 GPM and 420 PSI while cleaning and changing screens. Screened down to#80 to enable circulation. 20:00 22:30 2.50 8,868 8,868 PROD1 DRILL CIRC P Circulate 3 X BU at 750 GPM and 110 RPM. Flow check/Blow down .top drive prior to TIH. 22:30 00:00 1.50 8,868 9,919 PROD1 DRILL WPRT P Single in hole with additional 18 joints for TD requirement. Continue to RIH with stands to 9919'MD at report time. 02/13/2011 Directional drilled from 11,531' to 11,667'MD.ND=4771. Max gas observed=172 units. ECD=10.38 PPG. Bit quit drilling. After several attempts to resume drilling,decided to POOH. 00:00 01:30 1.50 9,919 11,531 PROD1 DRILL WPRT P Continue to RIH to bottom. Wash down last stand 01:30 03:30 2.00 11,531 11,667 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 11531'-11667'MD.ND=4771'. Pumps at 780 GPM's-3750 PSI, 120 RPM's. Torque on=20K, Torque off=16K.WOB=5-8K, UP WT=210K.SO WT=135K. ROT WT=167K. ADT=3.40 HRS.AST =.0 HRS.ART=3.40 HRS Total Bit HRS=30.47 Total Jar HRS=105.46 Max gas observed= 172 Units. ECD's-10.38 PPG. 03:30 10:30 7.00 11,667 11,667 PROD1 DRILL CIRC P ROP dropped to ZERO at 11,667' MD with no significant change in all other drilling parameters. Attempt various rotary and slide drilling suggestions with no success. Discuss with town and decided to POOH. Flow check prior to trip. 10:30 16:00 5.50 11,667 7,638 PROD1 DRILL REAM T PJSM. Backream from 11667'- 7638'MD. Pumps at 600 GPM's- 100 RPM's. Torque 10-15K. Up wt =210k, SO WT=140K 16:00 17:00 1.00 7,638 7,638 PROD1 DRILL CIRC T Circ BU at 600 increasing to 800 GPM. 17:00 18:00 1.00 7,638 6,995 PROD1 DRILL REAM T Cont.to backream from 7638-6995' MD. Pumps at 600 GPM's-100 RPM's. Torque 10-15K. 18:00 19:00 1.00 6,995 6,995 PROD1 DRILL CIRC T Circ BU at 600 increasing to 800 GPM due to some slight pack-offs. 19:00 20:00 1.00 6,995 6,300 PROD1 DRILL REAM T Cont.to backream from 6995'-6300' MD. Pumps at 600 GPM's-100 RPM's. Torque 10-15K. 20:00 22:00 2.00 6,300 2,903 PROD1 DRILL TRIP T Switch to elevators and POOH with acceptable overpull. Continue to casing shoe. 22:00 22:45 0.75 2,903 2,903 PROD1 DRILL CIRC T Pump 45 BBL sweep and 3 bottoms up with BHA just below shoe at 800 GPM,2700 PSI 110 RPM and Torque at 10k. 22:45 23:00 0.25 2,903 2,609 PROD1 !DRILL TRIP T Continue to POOH on elevators Page 48 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 23:30 0.50 2,609 2,609 PROD1 DRILL SFTY T BOP Drill and Rig Service 23:30 00:00 0.50 2,609 2,243 PROD1 DRILL TRIP T Continue to POOH on elevators 02/14/2011 POOH and change out bad motor. Also picked up back-up MWD. RIH and resumed drilling. 00:00 02:00 2.00 2,243 205 PROD1 DRILL TRIP T POOH on elevators to surface 02:00 04:30 2.50 205 112 PROD1 DRILL PULD T Stand back MWD. Break bit and evaluate mud motor. Excessive play in mud motor. Lay down motor 04:30 10:45 6.25 112 651 PROD1 DRILL PULD T PU BHA#9. PU back-up Pulser, nuke tools, EWR,flex collars, HWDP&jars 10:45 17:00 6.25 651 2,562 PROD1 DRILL TRIP T RIH with 5"DP from 651'to 2562' MD. Circulate waiting on weather 17:00 22:00 5.00 2,562 11,667 PROD1 DRILL TRIP T RIH with 5"DP from 2562'to 11667' MD. 22:00 23:15 1.25 11,667 11,712 PROD1 DRILL DDRL P Wash from 11630 to 11667. Directional Drill 9 7/8"Hole from 11667'-11712' MD.TVD=4782'. Pumps at 756 GPM's-3700 PSI, 100 RPM's. Torque on= 17K, Torque off= 16K.WOB=2K, UP WT=220K.SO WT=140K. ROT WT= 170K. ADT=.47 HRS.AST= .0 HRS.ART=.47 HRS Total Bit HRS=30.94 Total Jar HRS=105.93 Max gas observed= 172 Units. ECD's-10.26 PPG. NOTE: WOB at 2K vs. previous 6-8 k indicates current motor performing excellently. Also, rotary RPM limited to 100 RPM due to adjustable housing motor. 23:15 00:00 0.75 11,712 11,712 PROD1 RIGMNT RGRP T Shut down mud pump#2 for liner gasket repair. Work string at 100 RPM and 460 GPM while repairing 02/15/2011 Continued directional drilling from 11,712'-12874'MD.TVD=5091. Max gas observed=87 units. ECD= 10.61 PPG. 00:00 01:15 1.25 11,712 11,712 PROD1 RIGMNT RGRP T Cont.to circ while C/O #2 mud pump liner gasket 01:15 06:45 5.50 11,712 11,991 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 11712'-11991' MD.TVD=4864'. Pumps at 800 GPM's-3750 PSI, 100 RPM's. Torque on=20K, Torque off=17K.WOB=4/6K, UP WT=255K.SO WT=137K. ROT WT= 172K. ADT=3.31 HRS.AST =.35 HRS.ART=2.96 HRS Total Bit HRS=34.25 Total Jar HRS= 105.93 Max gas observed=172 Units. ECD's-10.26 PPG. 06:45 09:00 2.25 11,991 11,991 PROD1 RIGMNT RGRP T PJSM. C/O#1 mud pump liner gasket. Service Rig. Page 49 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:001 12:00 3.00 11,991 12,152 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 11991'-12152' MD.TVD=4905. Pumps at 800 GPM's-3750 PSI, 100 RPM's. Torque on=20K, Torque off= 19K.WOB=4/6K, UP WT=258K.SO WT=134K. ROT WT=172K. ADT=1.74 HRS.AST =0.0 HRS.ART= 1.74 HRS Total Bit HRS=35.88 Total Jar HRS= 110.98 Max gas observed=172 Units. ECD's-10.48 PPG. 12:00 00:00 12.00 12,152 12,874 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 12152'-12874' MD.ND=5091'. Pumps at 780 GPM's-3800 PSI, 100 RPM's. Torque on=21K, Torque off=19K.WOB=4/6K, UP WT=260K.SO WT=140K. ROT WT=165K. ADT=7.78 HRS.AST =0.68 HRS.ART=.68 HRS Total Bit HRS=43.77 Total Jar HRS= 119.09 Max gas observed=61 Units. ECD's-10.5 PPG. 02/16/2011 Continued directional drilling from 12,874'-14,134'MD.ND=5457'. Max gas observed=103 units. ECD= 10.62 PPG. 00:00 06:00 6.00 12,874 13,283 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 12874'-13283' MD.ND=5180'. Pumps at 800 GPM's-3800 PSI, 100 RPM's. Torque on=19K, Torque off=18K.WOB=4/6K, UP WT=240K.SO WT=139K. ROT WT=178K. ADT=4.60 HRS.AST = 1.75 HRS.ART=2.85 HRS Total Bit HRS=48.69 Total Jar HRS= 123.69 Max gas observed=46 Units. ECD's-10.61 PPG. 06:00 12:00 6.00 13,283 13,522 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 13283'-13522' MD.ND=5267'. Pumps at 800 GPM's-3900 PSI, 100 RPM's. Torque on=21K, Torque off= 18K.WOB=4/8K, UP WT=238K.SO WT=140K. ROT WT=180K. ADT=3.02 HRS.AST V = 1.52 HRS.ART=1.50 HRS Total Bit HRS=51.71 Total Jar HRS= 126.71 Max gas observed=100 Units. ECD's-10.72 PPG. 12:00 00:00 12.00 13,522 14,134 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 13522'-14134 MD.ND=5457'. Pumps at 780 GPM's-3900 PSI, 100 RPM's. Torque on=21K, Torque off= 18K.WOB=4/8K, UP WT=250K. SO WT=140K. ROT WT=180K. ADT=7.44 HRS.AST =5.41 HRS.ART= 1.50 HRS Total Bit HRS=51.71 Total Jar HRS= 126.71 Max gas observed=100 Units. ECD's-10.72 PPG. Page 50 of 57 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 02/17/2011 24 hr Summary Continued directional drilling from 14,134'MD-14,508'MD.TVD=5577'. Max gas observed=136 units. ECD= 10.48 PPG. Saw washout indication. POOH to 13,553'MD and found washout. Replaced joint, RIH and resume drilling to 14,520'MD. 00:00 06:00 6.00 14,134 14,316 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 14134'-14316 MD.TVD=5514'. Pumps at 760 GPM's-3650 PSI, 100 RPM's. Torque on=21K, Torque off=20K.WOB=4/10K, UP WT=252K. SO WT=137K. ROT WT=182K. ADT=3.16 HRS.AST =2.30 HRS.ART=.86 HRS Total Bit HRS=59.15 Total Jar HRS= 134.15 Max gas observed=103 Units. ECD's-10.52 PPG. 06:00 11:00 5.00 14,316 14,508 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 14316'-14508'MD.ND= '. Pumps at 775 GPM's-3890 PSI 5556, 100 RPM's. Torque on=23K, Torque off= 19K.WOB=6/10K, UP WT=260K.SO WT=140K. ROT WT=185K. ADT=2.92 HRS.AST =.8 HRS.ART=2.12 HRS Total Bit HRS=65.23 Total Jar HRS=140.23 Max gas observed=136 Units. ECD's-10.48 PPG. 11:00 17:00 6.00 14,508 14,508 PROD1 DRILL CIRC T Pressure dropped indicating washout. Checked surface equipment then dropped a packet of carbide marker. No indication received. 17:00 19:45 2.75 14,508 11,625 PROD1 DRILL TRIP T POOH on elevators from 14508'- 13553'MD and found washout. Replaced that single and continued POOH to 11625'to wipe hole. No swabbing or overpulls. 19:45 22:30 2.75 11,625 14,508 PROD1 DRILL TRIP T RIH on elevators from 11625-14508' MD. Precautionary wash and ream to bottom. 22:30 00:00 1.50 14,508 14,520 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 14508'-14520'MD.ND=5581'. Pumps at 605 GPM's-3900 PSI, 100 RPM's. Torque on=21K, Torque off=20K.WOB=4/6K, UP WT=260K. SO WT=132K. ROT WT= 182K. ADT=.47 HRS.AST= .0 HRS.ART= .47 HRS Total Bit HRS=65.70 Total Jar HRS= 140.70 Max gas observed= 156 Units. ECD's-10.47 PPG. 02/18/2011 Drilled to TD at 15,049'MD,5,779'MD. Circ.3 BU,Short trip and POOH to 5,848'MD Page 51 of 57 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 09:45 9.75 14,520 15,049 PROD1 DRILL DDRL P Directional Drill 9 7/8"Hole from 14520'-15049'MD.TVD=5779'. Pumps at 760 GPM's-3820 PSI, 100 RPM's. Torque on=21K, Torque off=18K.WOB=4/12K, UP WT=264K.SO WT=140K. ROT � WT=190K. ADT=7.76 HRS.AST =0 HRS.ART=7.76 HRS Total Bit HRS=73.46 Total Jar HRS=148.46 Max gas observed=26 Units. ECD's -10.53 PPG. Called TD. 09:45 13:00 3.25 15,049 15,049 PROD1 DRILL CIRC P Circulate 3 BU @ 760 GPM, 100 RPM,Torque off= 18-19k. Flow check/OK. 13:00 14:30 1.50 15,049 14,561 PROD1 DRILL TRIP P POOH on elevators from 15049'MD- 14944'MD. BROOH from 14944'MD to 14561'MD. @ 750 GPM,3800 PSI, 100 RPM,Torque=20K 14:30 15:00 0.50 14,561 15,049 PROD1 DRILL TRIP P RIH on elevators from 14561'-15049' MD 15:00 16:30 1.50 PROD1 DRILL CIRC P Circulate bottoms up @ 750 GPM, 100 RPM, 10rque-20K, UP WT= 265K.SO WT= 140K 16:30 21:30 5.00 15,049 9,899 PROD1 DRILL TRIP P POOH on elevators f/15049-13612' MD. UP WT=265K.SO WT= 140K. Pump 30 BBL slug and cont. to POOH to 10676'MD. Saw 30- 40K overpull. Backreamed from 10676-10486'MD @ 750 GPM, 3500 PSI, 100 RPM,Torque=18K. Wiped back down to 10676'MD. Cont to POOH on elevators to 9899' MD. UP WT=220K.SO WT= 135K. Saw tight spots @ 10700 to 10610, 10567-10486, 10296- 10201'MD. Wiped back through all spots without pumps and pulled thru clean. UP WT=220K.SO WT= 135K. 21:30 00:00 2.50 9,899 5,848 PROD1 DRILL TRIP P Pump 30 BBL slug and continue to POOH on elevators from 9899'- 5848'MD. UP WT= 170K.SO WT = 130K. 02/19/2011 POOH from 5,848'and test BOPE. Start running 7-5/8"casing to 236' 00:00 01:15 1.25 5,848 3,011 PROD1 DRILL TRIP P Continue to POOH from 5848'to 3011'MD. UP WT=140K.SO WT =132K. 01:15 02:30 1.25 3,011 3,011 PROD1 DRILL TRIP P Break circ at 210 GPM and work up to 750 GPM @2300 psi, 100 RPM. Recip to clean csg for storm packer 02:30 03:00 0.50 3,011 2,539 PROD1 DRILL TRIP P POH to 2539'MD Page 52 of 57 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:00 04:30 1.50 2,539 2,648 PROD1 WHDBO TRIP P Set packer at 104'MD with string hung off in surface casing and test to 300 PSI. This is in prep for the BOPE test which was due by midnight and is being peformed 6 hours after midnight with a variance from the AOGCC. 04:30 05:00 0.50 2,648 2,648 PROD1 WHDBO BOPE P Pump out stack,pull wear bushing, change lower pipe rams to 7-5/8"and PU 5"test joint and test plug. 05:00 13:00 8.00 2,648 2,648 PROD1 WHDBO BOPE P Perform BOP test. -Annular to 250/2500 PSI,all other tests to 250/3500 PSI. Test all rams, and annular.Test choke manifold and all valves.Test floor safety valves. Perform Koomey test.Accum drawdown test-3000 PSI start then bled to 1500 PSI. First 200 PSI increase in 55 secs,full 3000 PSI in 203 secs. 16 Bottle accum precharge=1000 PSI,5 Bottles of nitrogen back-up with AVG pressure of 2350 PSI. PU 7-5/8"test joint and test with annular and pipe rams. Rig down all testing equipment and pull test plug. Test witnessed by John Crisp. 13:00 16:00 3.00 2,648 651 PROD1 WHDBO BOPE P RIH and pull Baker storm packer. Continue to POOH to BHA at 651.15' 16:00 20:00 4.00 651 0 PROD1 DRILL PULD P POOH w/BHA,stand back Hvy wt, LD jars, pull R/A sources,download MWD and LD BHA. 20:00 23:00 3.00 0 0 COMPZ CASING RNCS P Clear and clean floor. PJSM, RU to run 7-5/8"surface casing 23:00 00:00 1.00 0 236 COMPZ CASING RNCS P Run 7-5/8",29.7#. L-80. BTCM csg production casing from surface to 236.54'. Check floats, OK. 02/20/2011 Run 7-5/8"casing to 236'-12,500'MD. Circulate BU every 2500'MD. 00:00 12:00 12.00 236 5,833 COMPZ CASING RNCS P Run 7-5/8",29.7#, L-80, BTCM csg from 236'to 5833'MD. Circ BU at shoe at 4 BPM @ 350 PSI. Fill pipe every jt and completely fill every 10 jts. Obtain PU/SO every 4th joint. UPWT=185K.SOWT=130K 12:00 18:00 6.00 5,833 10,000 COMPZ CASING RNCS P PJSM. Cont.to RIH with 7-5/8", 29.7#, L-80, BTCM csg from 5833'to 10000'MD. Circ BU at 5000'at 4 BPM @ 350 PSI. Fill pipe every jt and completely fill every 10 jts. Obtain PU/SO every 4th joint. UP WT=200K SO WT=128K Page 53 of 57 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 10,000 12,500 COMPZ CASING RNCS P PJSM. Cont.to RIH with 7-5/8", 29.7#, L-80, BTCM csg from 10000 to 12500'MD. Circ BU at 12500'at 5 BPM @ 620 PSI. Fill pipe every jt and completely fill every 10 jts. Obtain PU/SO every 4th joint. UP WT=300KSOWT=140K 02/21/2011 Mix and pump 35 bbl CW-100 and 40 bbl MudPush II at 11.5 ppg, 152 bbl Tail cement at 15.8 ppg(735 sx). Bumped plug at planned strokes plus 18. Check floats-OK. 00:00 02:30 2.50 12,500 12,500 COMPZ CASING RNCS P Continue to circ BU at 12500'at 5 BPM @ 530 PSI. UP WT=280K SOWT=135K 02:30 06:30 4.00 12,500 15,027 COMPZ CASING RNCS P Cont.to RIH with 7-5/8",29.7#, L-80, BTCM csg from 12500 to 15027'MD. 06:30 08:00 1.50 15,027 15,027 COMPZ CASING RNCS P LD Franks tool and PU landing jt. Set hanger in csg spool and verify set w/FMC. RU cement head on landing joint. 08:00 14:45 6.75 15,027 15,027 COMPZ CASING CIRC P Circulate and condition hole at 5 BPM while reciprocating. UP WT= 325K SO WT=140K. Circulate 3 BU. 14:45 20:00 5.25 15,027 15,027 COMPZ CEMENT CMNT P PJSM. Mix and pump 5 bbl CW 100. Pressure test lines to 3000 osi. Mix and pump 35 bbl CW-100 and 40 (V` bbl MudPush II at 11.5 ppg. Drop bottom plug. Mix and pump 152 bbl Tail cement at 15.8 ppg(735 sx). Drop top plug and pump 10 bbl seawater followed by 6731 strokes of seawater with rig pump. Bumped plug and increase pres to 500 psi over pump pres.and hold 15 minutes Check floats-OK. Bled back 2.5 bbl. 20:00 00:00 4.00 15,027 15,027 COMPZ CEMEN'RURD P Rig down Schlumberger. Clean and blow down BOP stack. MU running tool for installing pack-off. 02/22/2011 Install 7 5/8"packoff.Test same to 5000 PSI. Slip&cut drilling line. Service rig.Lay down 5"drillpipe form derrick. SIMOPS: RU Little Red on OA. Pump 120 BBLS of seawater to flush annulus. Freeze protect with 110 BBLS of diesel @ 2 BPM. ICP-500 PSI. FCP= 1000 PSI.Shut in Pressure=650 PSI. RU&Test annular and 3 1/2"x 5"rams to 250/3500 PSI. RU to run 3 1/2"completion string. Pull chemical injection spool to floor. 00:00 02:00 2.00 15,027 15,027 COMPZ WHDBO NUND P Install 7 5/8"packoff. Pull flange on OA valve to verify set down depth as per FMC rep. Pull packoff. Flush stack&clean packoff.Set again. Verify set down. Energize packoff and test same to 5000 PSI-10 minutes.Good test. Install flange back on OA valve. 02:00 04:00 2.00 0 0 COMPZ RIGMNT SLPC P Held PJSM-Slip&Cut drilling line. 04:00 05:30 1.50 0 0 COMPZ RIGMNT SVRG P Service rig,top drive&draw works. Adjust brakes. Page 54 of 57 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 05:30 12:00 6.50 0 0 COMPZ DRILL PULD P Held PJSM-Discuss safety& hazard recognition issues. Discuss procedure to lay down 5"DP. Install mousehole. Breakout&lay down drill pipe form derrick.Crew Change SIMOPS: Load&strap 3 1/2"tubing in shed. 12:00 21:00 9.00 0 0 COMPZ DRILL PULD P Continue breakout&lay down 5"DP from derrick. SIMOPS: RU Little Red Services to OA. Flush OA with 120 BBLS of seawater,followed with 110 BBLS of freeze protect diesel at 2 BPM. ICP =500 PSI. FCP=1000 PSI. Shut in pressure=650 PSI. 21:00 23:00 2.00 0 0 COMPZ WHDBO BOPE P Pull WB. RU&install test plug.Test annular&3 1/2"x 5"rams to 250/ 3500 PSI. Record on chart. Rig down test equipment. 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD P Rig up to run 3 1/2"completion as per detail. Pull chemical injection spool to floor. Rig up tubing running equipment. Check all equipment and tools for run. Pull clamps to rig floor. Crew Change 02/23/2011 Continue RU to run 3 1/2" Production string. Held PJSM. Make up BOT Solid seat shear out sub,continue with assembly to the chemical injection mandrel. Install chemical injection line.Test same.Continue run production tubing.At joint#142,observed pressure on Chmical injection line dropped to 0 PSI.Trouble shoot &test line.Call for&RU HES Slickline. Pressure down tbg to 500 PSI.Verify valve OK. Pull valve. Install Dummy valve.Test Chem line observing pressure drop each time to 0 PSI.Verify dummy seated and tested. to 500 PSI.Cut Chemical line,and secure same to tbg as per Schlumberger rep. Continue RIH with 3 1/2" production string. Phase 2 weather conditions. 00:00 01:00 1.00 0 0 COMPZ RPCOM RURD P Continue RU to run 3 1/2"production tubing. 01:00 01:30 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM. Discuss safety&hazard recognition issues. Discuss procedure to run 3 1/2"production string as per detail. 01:30 11:00 9.50 0 4,620 COMPZ RPCOM RCST P Make up BOT Solid seat shear out sub,continue with assembly, installing Circulation mandrel, D nipple without RHC plug and Baker FHL packer with PBR and locater assembly with pups to the chemical injection mandrel.Make up chemical injection line.test same.Continue RIH with 3 1/2"prodution tbg, installing clamps on each jnt. Make up torque-2800 Ft/lbs. 11:00 14:00 3.00 4,620 4,433 COMPZ RPCOM RCST T While on joint#142,observed pressure drop to 0 PSI on Chemical Injection line.Trouble shoot same& attempt to hold pressure at 1000 PSI,2000 PSI with pressure dropping to 0 PSI quickly. POOH from 4620'-4433'inspecting line. Call for Slickline unit. Page 55 of 57 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 14:00 15:00 1.00 4,433 4,433 COMPZ RPCOM SLKL T Wait in Slickline unit while continue clean pits, service rig. 15:00 23:30 8.50 4,433 4,433 COMPZ RPCOM SLKL T Spot HES Slickline unit. Held PJSM.RU sheaves and line. Pump down tubing to 500 PSI to check valve.Good test. Repeat attempts to hold pressure on C.L.with no success.WLIH to retrieve valve. WLIH to set dummy valve.Test same via tbg to 500 PSI.Good test verifying dummy valve seated. Repeat test on C.L.-no success. Rig down Slickline unit&sheaves.Cut chemical injection line,plug the ends. Secure line to tbg with 1/2 clamps. 23:30 00:00 0.50 4,433 0 COMPZ RPCOM RCST P Continue run 3 1/2"production string as per detail.Crew Change 02/24/2011 Continue run 3 1/2"Production string as per detail from 4630'-14120'MD.Set packer @ 14028'and shear out.Space out. Install hanger.Spot Corrossion inhibitor(7BBLS). Land hanger&test tbg and annulus. Bleed pressure to shear DCK valve and obtain IA x tbg communication. Install TWC. Pressure down annulus to test same to 1000 PSI. Pull landing joint. ND BOP stack and riser.Continue cleaning pits in rockwasher. 00:00 12:30 12.50 COMPZ RPCOM RCST P Continue run 3 1/2"Production string as per detail from 4630'-14000'MD. Installed a total of 133 Cannon Clamps.4-1/2 clamps at mid joint. UP WT=155K,SO WT=107K. 12:30 13:30 1.00 COMPZ RPCOM RCST P Pressure down tbq to 2500 PSI to set packer @ 14028'as planned. Increase pressure to 3500 PSI,to shear solid shear seat sub. Bleed pressure to 1000 PSI,shear off ball seat. Pick up to shear PBR. Bleed pressures. Pull up above PBR. 13:30 14:30 1.00 COMPZ RPCOM CIRC P Pump to spot corrossion inhibitor as planned. 7 BBLS.Chase with 120 BBLS of sewater. 3 BPM. 14:30 16:30 2.00 COMPZ RPCOM RCST P Pull 2 jnts,and install space out pup. Install tbg hanger and landing joint. Land hanger. RILDS. UP WT= 155K, SO WT=107K. 16:30 18:00 1.50 COMPZ DRILL PRTS P Rig up lines and hoses.pump down tbg to pressure test to 3500 PSI-30 minutes.Good test. Bleed pressure to 2000 PSI. Hold. Pressure down annulus to 3000 PSI for 30 minute test. Bleed pressure to observe valve shear at 2481'. Bleed all pressures. All test recorded on chart. 18:00 19:00 1.00 COMPZ DRILL PULD P Back out&lay down landing joint. Install TWC as per FMC rep. Pressure down anulus to test TWC to 1000 PSI. Good test. 19:00 20:15 1.25 COMPZ DRILL RURD P Rig down Control line spooler. RD all tbg running equipment. Blow down all lines. Page 56 of 57 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:15 20:30 0.25 COMPZ WHDBO SFTY P Held PJSM with crew. Discuss safety&hazard recognition issues. Discuss procedure to ND BOP stack,and NU tree. 20:30 00:00 3.50 COMPZ WHDBO NUND P Nipple down BOP stack and riser. ND Choke&Kill lines.Continue clean pits in rockwasher.Crew Change 02/25/2011 Continue ND BOP's. NU adapter flange and Tree. RU Little red,and pump 102 BBLS of freeze protect diesel. Allow to U-tube until dead. . Blow down lines. Rig on standby-Phase 3 weather conditions. 00:00 06:00 6.00 COMPZ WHDBO NUND P Continue NU adapter flange&tree. test same to 250/5000 PSI. Record on chart. 06:00 08:00 2.00 COMPZ WHDBO FRZP P Rig up Little Red Services. Make up tree valves&lines for freeze protect job. 08:00 08:30 0.50 COMPZ DRILL SFTY P Held PJSM with crew&Litte Red reps. Discuss safety&hazard recognition issues. Discuss pumping freeze protect diesel in well. 08:30 11:30 3.00 COMPZ DRILL FRZP P With Little Red,pump 102 BBLS of freeze protect diesel at 1 BPM as planned. ICP-200 PSI.OA=200 PSI. 11:30 12:00 0.50 COMPZ DRILL FRZP P Allow well to U-Tube. Phase 3 1weather condiitons.Crew Change. 12:00 00:00 12.00 COMPZ DRILL OTHR T Continue allow well to U-Tube until dead.. Phase 3 weather condiitons. Perform light duty work around rig. Crew Change. TBG Pressure=0 PSI Annulus Pressure=0 PSI Outer Annulkus=450 PSI. 02/26/2011 Continue wait on phase 3 weather. Install BPV. Rig down lines on tree. Secure well head. Prep rig for skidding rig floor&move.Skid rig floor. Pull rock washer away from rig.Spot on location. Prep system for move. Rig released at 0400 HRS. 00:00 04:00 4.00 COMPZ DRILL OTHR T Continue wait on Phase 3 weather. Install BPV as per FMC rep. Rig down lines and secure well head. TBG Pressure=0 PSI Annulus Pressure=0 PSI Outer Annulkus= 450 PSI. Rig Released @ 0400 HRS. Page 57 of 57 2L-320 Well Work Summary DATE SUMMARY 3/15/11 DRIFT TBG 2.60" &TAGGED @ 1 . .,,0' SLM, SAMPLE OBTAINED. REPLACE_ ..)OV W/DV @ 2481' RKB. MIT-T 3500 PSI, PASSED, LRS MIT-IA 3500 PSI, PASSED. IN PROGRESS. 3/16/11 DRIFT TBG W/ 15'X 2.63" DMY GUN &TAGGED @ 14180' SLM, THICK DRILLING MUD. EST. 230' SHORT OF PERF TARGET. COMPLETE 3/19/11 WASHED DOWN FROM SLICK LINE TAG AT 14180 MD TILL A HARD TAG AT 14989 CTMD. WELL FREEZE PROTECTED. TURN WELL OVER TO DSO, JOB COMPLETE. 3/20/11 DRIFTED TBG W/ 15.5'X 2.63" DMY GUN TO 14600' SLM. COMPLETE 3/21/11 PERFORATED 14390'-14405'WITH 2.5" PROSPECTOR RDX CHARGES, 6 SPF, 60 DEG PHASING. INCREASED SURFACE PRESSURE TO 2700 PSI PRIOR TO PERFORATING CASING. IN PROGRESS. 3/22/11 ATTEMPTED 2ND RUN FOR INITIAL BERMUDA PERFS. TOOLSTRING FELL ERRATICALLY BEYOND 3000', VERY LOW TENSIONS REQUIRED TO FALL. WIRELINE STACKED OUT ABOVE GREASE TUBES AT 14300' DUE TO A RAISED ARMOR. RAISED ARMOR DUE TO TENSION PROFILE AND WELL GEOMETRY. DISCUSSED WITH CWG, WILL REATTEMPT TOMORROW WITH DIFFERENT WIRELINE. 3/23/11 ATTEMPTED TO PERFORATE 14420'-14435' BUT TOOLSTRING STOPPED FALLING BEFORE REACHING TARGET DEPTH. WILL REATTEMPT TOMORROW WITH PUMP-DOWN ASSIST. BOTTOM NOSE MISSING FROM BHA. SEE DIGITAL PICTURE IN ATTACHMENTS. 3/24/11 PERFORATED 1442('-14435'WITH 2.5" PROSPFCTOR RDX CHARGFS, 6 SPF, 60 DEG ✓ PHASING. RIGGED DOWN TURNED WELL OVER TO DSO. 3/27/11 TAGGED @ 14880' SLM WITH 2.73" CENT&2.5" BAILER. MEASURED BHP @ 14413' RKB. WHILE PULLING UP HOLE FOR 2ND SURVEY STOP, TOOLS HUNG UP @ 13810' SLM. UNABLE TO WORK FREE. DROPPED CUTTER BAR. RECOVERED ALL WIRE. IN PROGRESS. 3/31/11 TROUBLESHOOT OBSTRUCTION @ 13786' SLM WHILE TRYING TO FISH TOOLSTRING. IN PROGRESS. STATE OF ALASKA s + ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: AbandonRe air w ell �"` p Rug Perforations r Stimulate Other r Alter Casing r Pull Tubing 1—Perforate New Pool Waiver r Time Extension fl Change Approved Program IV rat. Shutdow n r Perforate Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r - 210-166-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20627-00—00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 380052,380051,386053 - 2L-320 9. Field/Pool(s): Kuparuk River Field/Tarn'Oil Pool 10. Present Well Condition Summary: Total Depth measured 15049 feet Plugs(measured) None true vertical 5780 feet Junk(measured) None Effective Depth measured 15027 feet Packer(measured) 14029 true vertical 5772 feet (true vertucal) 5427 Casing Length Size MD TVD Burst Collapse CONDUCTOR 58 16 100 100 SURFACE 2704 10.75" 2746 2374' PRODUCTION 14988 9.625" 15027 5772' RECEIVED OJN 0 7 ;IL Perforation depth: Measured depth: 14390'-14405', 14420'-14435' True Vertical Depth: 5535'-5540',5545'-5550' gaga Cril & G8g CQ9t16.Commission Ancner ge Tubing(size,grade,MD,and ND) 3.5, L-80, 14120 MD,5453 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PKR 3 1/2"X 7 5/8"@ 14029 MD and 5427 TVD NIPPLE-Camco"DS"Nipple with 2.875"Profile @ 492 MD and 492 TVD 11.Stimulation or cement squeeze summary: Intervals treated(measured): 14390'-14435' Treatment descriptions including volumes used and final pressure: 242271#of 16/20 carbolate 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation not applicable Subsequent to operation 268 947 308 -- 349 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development-ri Service Il Stratigraphic 15.Well Status after work: 4 Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG i' 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 an.265-6471 Printed Name John Peirce Title Wells Engineer Signature Phone:265-6471 1/ 4 ---------- Date /� A .( ham' ii MOMS JUN 07 ZOtY �[�' f( Form 10-404 Revised 10/2010 /i Y rm Submit Original Only 2L-320 Well Work Summary DATE SUMMARY 3/15/11 DRIFT TBG 2.60"&TAGGED @ 14.00' SLM, SAMPLE OBTAINED. REPLACE, ,iOV W/DV @ 2481' RKB. MIT-T 3500 PSI, PASSED, LRS MIT-IA 3500 PSI, PASSED. IN PROGRESS. 3/16/11 DRIFT TBG W/ 15'X 2.63" DMY GUN &TAGGED @ 14180' SLM, THICK DRILLING MUD. EST. 230' SHORT OF PERF TARGET. COMPLETE 3/19/11 WASHED DOWN FROM SLICK LINE TAG AT 14180 MD TILL A HARD TAG AT 14989 CTMD. WELL FREEZE PROTECTED. TURN WELL OVER TO DSO, JOB COMPLETE. 3/20/11 DRIFTED TBG W/ 15.5'X 2.63" DMY GUN TO 14600'SLM. COMPLETE 3/21/11 PERFORATED 14390'-14405'WITH 2.5" PROSPECTOR RDX CHARGES, 6 SPF, 60 DEG PHASING. INCREASED SURFACE PRESSURE TO 2700 PSI PRIOR TO PERFORATING CASING. IN PROGRESS. 3/22/11 ATTEMPTED 2ND RUN FOR INITIAL BERMUDA PERFS. TOOLSTRING FELL ERRATICALLY BEYOND 3000', VERY LOW TENSIONS REQUIRED TO FALL. WIRELINE STACKED OUT ABOVE GREASE TUBES AT 14300' DUE TO A RAISED ARMOR. RAISED ARMOR DUE TO TENSION PROFILE AND WELL GEOMETRY. DISCUSSED WITH CWG, WILL REATTEMPT TOMORROW WITH DIFFERENT WIRELINE. 3/23/11 ATTEMPTED TO PERFORATE 14420'-14435' BUT TOOLSTRING STOPPED FALLING BEFORE REACHING TARGET DEPTH. WILL REATTEMPT TOMORROW WITH PUMP-DOWN ASSIST. BOTTOM NOSE MISSING FROM BHA. SEE DIGITAL PICTURE IN ATTACHMENTS. 3/24/11 PERFORATED 14420'-14435'WITH 2.5" PROSPECTOR RDX CHARGES, 6 SPF, 60 DEG PHASING. RIGGED DOWN TURNED WELL OVER TO DSO. 3/27/11 TAGGED @ 14880' SLM WITH 2.73"CENT&2.5" BAILER. MEASURED BHP @ 14413' RKB: 2023 PSI. WHILE PULLING UP HOLE FOR GRADIENT STOP, TOOLS HUNG UP @ 13810' SLM. UNABLE TO WORK FREE WITH PUMP ASSIST. DROPPED CUTTER BAR. RECOVERED ALL WIRE. IN PROGRESS. 3/31/11 TROUBLESHOOT OBSTRUCTION @ 13786' SLM WHILE TRYING TO FISH TOOLSTRING. IN PROGRESS. 4/1/11 FISHED PERF GUN BULL NOSE LOST ON 3/23/11. PULLED CUTTER BAR &TOOLSTRING. COMPLETE. 5/15/11 TARN FRAC: PUMPED A TOTAL OF 242,271 LBS OF 16/20 CARBOLITE, PLACING 210,305 LBS BEHIND PIPE. COMPLETED FRAC WITH 9 PPA ON FORMATION. FRAC PUMPED TO 85% DESIGN. JOB SCREENED OUT, PUMPED 6 BBL OF LINEAR AND 8 BBL OF DIESEL PRIOR TO PRESSURING OUT AT 4200 PSI. 5/19/11 RIH, CLEAN OUT FILL TO 14,240 CTMD, RETURN 5/20, IN PROGRESS 5/20/11 RIH, CLEAN OUT FILL FROM 14, 240 TO 14,340, LUBRICATOR SEAL LEAK, POOH MAKE REPAIRS, SHUT DOWN FOR NIGHT, IN PROGRESS 5/21/11 RIH, CLEAN OUT FILL TO 14,560' CTMD, WIPER TRIP OUT OF HOLE, READY FOR SLICKLINE, IN PROGRESS 5/23/11 TAGGED @ 14286' SLM. JOB SCOPE CHANGED. JOB SUSPENDED. 5/24/11 SET 2.75" D CAT SV @ 14077' RKB. IN PROGRESS. 5/25/11 PULLED DV @ 13750' RKB. READY FOR CIRC OUT. 5/26/11 SET OV @ 13750' RKB. PULLED 2.75" D CAT SV @ 14077' RKB. READY FOR FLOWBACK. 6/2/11 GAUGE TBG WITH 2.84 G. RING TO CMU @ 13,957' RKB, TAG FILL @ 14,204' SLM, EST. 195' OF FILL. JOB COMPLETE r I. 4KUP 2L-320 r, Col'ocoPfiilfps - ,r Well Attributes Max Angle&MD TD �'' 4949 Wellbore APVUWI IF IdN a Well Status Inc'(1 MD(ftKB) Act Bfm(RKB) te a' ' p"- 4 501032062700 TARN PARTICIPATING AREA PROD I 15,049.0 Comment H2S(ppm) Data Annotation E d Date KB-Grd(ft) R g Release Date ...Well Con%HORIZONTAL 2L 320 5/10/ q, ,V1,gp( --,ry,�SSSV:NIPPLE Last WO J 2/26/2011 - ShcemalC ACWal Annotation (Depth WEB) (End Date Annotation Last Mod End Date Last Tag:SLM l 14,880.0 3/27/2011 Rev Reason:FRAC L Imosbor 5/16/2011 HAviceR.36 ` P Casing Strings : Casing Description String 0... String ID...Top MKS) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd CONDUCTOR 16 14969 41.9 100.0 100.0 164.00 1.03 WELDED ,.. r, Cuing Description String 0... String ID...Top(6108) Set Depth(f_.Set Depth(TVD)...Siring Wt...String.-String Top Thrd SURFACE 103/4 9.794 41.9 2,745.6 2,375.5 45.50 L-80 BTC --- ---- " Coving Description String 0... String ID...Top(ftl(B) Sat Depth(f...Sat Depth(TVD)...String Wt...String...String Top Thrd I PRODUCTION 7 5/8 6.875 38.7 15,027.0 5,771.6 29.70 L-80 BTCM Tubing Strings i Tubing Description String 0... (string ID...Top(ftKB) SDepth(f...S 1 Depth(ND)..String Wt.. String_.String Top Thrd CONDUCTOR, Y: TUBING 31/2 i 2.992 I 36.5 ISM 14,120.4 I 5,453.1 9.30 L-80 EUE 8RD 42-100 Completion Details Top Depth NIPPLE,492 ) - (WD) Top Incl Komi_ Top(ftKB) (KKB) (1) lino Deenription Comment __- ID(in) 36.5 36.5 -0.02 HANGER FMC Hanger w/pupjt Hanger=.75',Pup=2.65 3.500 492.2 492.1 2.30 NIPPLE Camco'DS"Nipple w'Oh 2.875"Profile 2.875 13,957.7 5,405.5 72.59 SLEEVE-C Baker CMU sliding sleeve w/2.813 DS profile(CLOSED) 2.812 GAS LIFT ' 2481 ( +. ) 14,005.2 5,419.7 72.82 PER PER and Locator 22.8832 2.990 14,028.5 5,426.6 72.93 PACKER Baker FHL Pkr 3 1/2"x 7 5/8" 3.000 14,077.0 5,440.7 73.18 NIPPLE Camco"D"Nipple With 2.75"Profile 2.750 14,119.5 5,452.9' 73.60 SOS Solid Seat Shear out Sub 2.970 Perforations&Slots -._- Shot Top(TVD) Btm(TVD) Dens Top(RKB) Wm(ftKB) (R103) (01KB) Zone_ __. Date (91)-, Type Comment 14,390.0 14,405.0 5,534.8 5,540.0 3)22/2011 6.0 IPERF 2.5"PROSPECTOR RDX . [ SURFACE,_ • CHARGES,6 SPF,60 DEG 42-2,716 PHASING. 14,420.0 14,435.0 5,545.2 5,550.0 3/24/2011 6.0 IPERF 2.5"PROSPECTOR RDX CHARGES,6 SPF,60 DEG GAS LIFT, PHASING. 3,072 Stimulations&Treatments `F iti. ;;~ Bottom �� Min Top Max Bbn Top Depth Depth I Depth Depth (TVD) (TVD) (RKB) MKS) (6KB) MB) Type Date Comment 14,390.0 14,435.0 5,534.8 5,550.0 FRAC 5/15/2011 TARN FRAC-pumped 242,271#of 16/20 Carbolite, 210,305#behind pipe;9 ppa on formation;85%of design. GAS LIFT. 7.975 I GAS LIFT, 11,877 1111 GAS LIFT. I . 13 750 CHEMICAL, i 1- 13.840 SLEEVE-C, - 13,958 ,. POR,14,005 __ ..._ PACKER, 14,029 - It tr NIPPLE.14.077 Mandrel Details lit:.. Top Depth Top Port GAS LIFT,___ (TVD) Incl OD Valve Latch Size TRO Run 14,094 Stn Top(ftKB) (RKB) (1 Make , Model (in) Sery TYPe TYW (in) (pafl Run Data Can...ill 1 2,481.2 2,250.7 56.26 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/15/2011 SOS,14,120-- -- 2 3,072.0 2,490.2 72.19 CAMCOIKBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/28/2011 3 7,975.0 3,793.5 73.94 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/28/2011 (PERF 4 11,877.2 4,830.9 73.92 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/282011 "wry 14,390-14,405 FRAC,14,390 5 13,750.4 5,341.7 71.76 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/28/2011 (PERF 6 13,840.4 5,369.7 71.70 CAMCO KBMG 1 CHEM DMY BK 0.000 0.0 1/28/2011 14,120.14,435 7 14,094.4 5,445.7 73.31 CAMCO MMG RG-2 1 1/2 GAS LIFT CV RKP 0.000 0.0 12812011 PRODUCTION, 3915,027 TD(21320), 15,049 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 30, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2L-320 Run Date: 3/21/2011 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-320 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20627-00 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 &!O _,4 apSSC, .'mom `'t j J_ a ^: Date: Signed: rr 33,.z ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT01808 TO: Christine Shartzen ConocoPhillips Alaska, Inc. State of Alaska-AOGCC P.O. Box 100360 333 W.7"'Ave.,Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: KRU 2L-320, PB1, PB2 AOGCC permit: 210-166-0 DATE: 3/14/2011 Transmitted: Kuparuk River Unit, North Slope,Alaska ,2L--320, (2L-320PB1, 2L-320PB2) Hardcopy and CDROM Final Well report, Mud logging report, CANRIG;well 2L-320(501032062700; PB1 501032062770; PB2 501032062771)All three wellbores included in this report 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) d Gas ratio (TVD) LWD Combo (MD) LWD Combo (ND) Drilling dynamics (MD) Drilling dynamics (ND) CDROM contains; daily reports, DML data, final well report, LAS files, mud log PDF files, remarks and tiff files Sign,scan and return in .pdf format if applicable to Sandra.D.Lemke0Conocophillips com CC: 2L-320 transmittal folder, production well files, eSearch RECEIVED Receipt: Date: MAR 17 2011 GIS-Technical Data Manageng 'ono�cf3 Navaska 1 Ph: 9072656947 flowage WELL LOG TRANSMITTAL To: State of Alaska March 3, 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-320+PB1+PB2 AK-MW-0007742776 2L-320+PB1+PB2 50-103-20627-00: -70: -71 2"x 5" MD TRIPLE COMBO Logs: 1 Color Log for each wellbore 2"x 5"TVD TRIPLE COMBO Logs: 1 Color Log for each wellbore Digital Log Images&LDWG-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 —/&' c:90 Bry. , , 11. tiONQ.COM MAR 2011 0 _5 Date: Signed: OilCons.Canmissial Mc/lenge EXPLANATION FOR THE REQUEST FOR VARIANCE BEYOND THE 2 WEEK TIMEFRAME Fr° 2L-320 2 (0- /4 Due to operational and weather delays as the well was being drilled to total depth at 15,000'+, the delay past the required deadline was anticipated on Thursday, February 17 and a waiver to go past the midnight deadline was requested. During the previous chance to perform the BOP test on the morning of February 14, there was still time to drill the hole to TD and perform the BOP test. The two items that were the cause for the +1-4 hour delay on the test were: Downhole equipment failure Motor and MWD failed Washout in drillpipe Weather A Phase three blow delayed the operation Below is the timeline for the past five days. Mon, 14-Feb POH for downhole failure. Currently at 11,667. Anticipated had 3500' or 3 days max to drill and would be testing BOP by late Wed, Feb 16 or early Thurs, Feb 17 with tubing and casing rams Tue, 15-Feb Drilling at 11, 970'. Motor and MWD had failed and both had to be replaced (Lost 6 hours). RIH and had to stop at the shoe due to Phase 3 weather(Lost 4 Hours). Wed, 16-Feb Good footage day, drilled to 14134' Thu, 17-Feb Had a washout-(Lost 12 hours) Realized BOP test would most likely not start until after midnight on Friday, February 18, the day the test was required. Sent request to AOGCC asking for permission to start BOP test after midnight or 2-4 hours later than the 2 week requirement. Fri, 18-Feb Drilled to TD. POOH for BOP test Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, February 18, 2011 3:03 PM To: 'David Nugent' Cc: DOA AOGCC Prudhoe Bay Subject: RE: 2L-320 (PTD 210-166) David, The Commission acknowledges your possible late start on the required BOP test. The Commission is very strict on the 2 week time limit for BOP testing. In the course of two weeks the operator(CPAI) is expected to plan accordingly to schedule a BOP test as opportunities arise. I don't know the details of the drilling operation so this borehole/well may have given few chances to fit in an earlier BOP test. In this case you will have to do the best possible and get to a safe point(drill bit to casing shoe )and begin the BOP test at that point ( as your plan below states) . Please put an explanation for the late test on the BOPE test form also. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: David Nugent [mailto:drengrmgt@yahoo.com] Sent: Friday, February 18, 2011 2:40 PM To: Schwartz, Guy L (DOA) Cc: david.nugent@contractor.conocophillips.com Subject: 2L-320 PB2 Guy, I wanted to give you an update on our 2L-320 well. We drilled to 15,049' this morning - TD for this well. We just completed our short trip and are currently heading back to bottom to circulate 1 - 2 bottoms up. We anticipate beginning to POOH around 4pm today. We will then POOH to the surface casing shoe. Once our bit is inside the surface casing, we will hang off the drill string on a storm packer and begin our BOP test. We anticipate having the bit at the surface casing shoe sometime between midnight and 6am Saturday (depending on how much, if any,backreaming is necessary). The inspector on the slope (John Crisp)has been notified of our upcoming BOP test. The BOP test was supposed to begin by midnight tonight. We thought we would make this deadline up to yesterday afternoon/evening, however we lost about 8 hours then looking for a washout in our drill string. We will begin our BOP test at the earliest opportunity as soon as our drill string is out of the open hole and hung off inside the surface casing. We ask a variance on the requirement to test before midnight tonight. 2/18/2011 Page 2 of 2 Thank you for your consideration. You can contact me at 622-8577 if necessary. I am home today so please respond to my yahoo email address. David A.Nugent 2/18/2011 Page 1 of 2 Schwartz, Guy L (DOA) From: Nugent, David (Swift Technical Services LLC) [David.Nugent@contractor.conocophillips.com] Sent: Wednesday, February 09, 2011 2:07 PM To: Schwartz, Guy L(DOA) Subject: RE: 2L-320 PB2 Section (ADP Permit 210166 ) Attachments: BHA300 Schematic LIH.pdf Guy, I checked the directional plan and we are not changing it by more than 500' I attached the lost BHA I got from Sperry. There was no radioactive source in the lost BHA. Note that everything above and including the first flex collar was recovered, the second TmiddTe)flex collar and everything below was left in the hole. So basically the right side of the schematic was left in the hole. Let me know if you need anything else. David A. Nugent From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, February 07, 2011 1:40 PM To: Nugent, David (Swift Technical Services LLC) Subject: RE: 2L-320 PB2 Section (ADP Permit 210166 ) David, Before I forget can you send me a schematic of the BHA that was lost in the first PB section. I had forgotten to get that and was assuming it was not a radioactive source BHA. We are tracking lost BHA's in our data system.... I assume you are not changing the directional plan by more than 500' (wp-8 from PTD plan) from the original plan as a revision would be needed. (the first two drilling attempts appear to be easily with 500' ) Thanks for the update... and good luck. 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: Monday, February 07, 2011 12:58 PM To: Schwartz, Guy L (DOA) Subject: 2L-320 ADP Permit 210166 Guy, 2/9/2011 Page 2 of 2 I am taking over the drilling of the 2L-320 well from Mike Greener. He has been reassigned to look at the"big picture"for wells in the future. We ran into some problems on the drilling of the sidetrack of this well, and I wanted to let you know where we stand now and our forward plans. Due to hole conditions, we were unable to drill the sidetrack hole below 11,247' MD/4,438'TVD. So we decided to plug back the hole to the shoe and sidetrack again. This is what we have done with the sidetrack so far: 1. Ran an ECP packer and set it at 3,600' MD. 2. Pick up 3-1/2"cement stinger and set a cement plug from 3,600' MD to 3,000' MD with 96 bbls of 17ppg cement. 3. Wash off top 100'of cement. 4. Set a cement plug from 3,100' MD to 2,500' MD with 78 bbls of 17ppg cement. 5. Pick up out of cement and circulate BU. 6. POOH and lay down tools. 7. Test BOP's to 250/3,500 psi. 8. Pick up bit, motor, and LWD tools and TIH. 9. Tag firm cement at 2,450' MD. Drill firm cement to 2,695' MD. 10. Displace well from OBM to 9.5 ppg WBM. 11. Continue to drill firm cement and kick off well at 2,755' MD (surface shoe at 2,745' MD). 12. Directionally drilled to 6,320' MD as of midnight this morning. We made a short trip at 4,995' MD. Our plans are to continue directionally drilling this well to TD using WBM and frequent short trips. I attached the new directional plan we are using for this sidetrack. Our target is the same, however we will be hitting the target at a higher inclination and holding the higher inclination through the target to TD. Let me know if you need any additional information or if you have any questions. David A. Nugent Swift Technical Services ConocoPhillips Alaska ATO 1502 Anchorage, AK 907-263-4228 'iai')n> 1 , (1b Zloira HALLIBURTON I Sperry Drilling Length Length (ft) (ft) BHA Schematic Conoco Phillips Alaska, Inc. 2L-320 BHA#: Jar 31.90 Flex Collar 1 30.73 Run #: 300 Drillstring: Drillstring f`' r-,1, BHA Configuration ,1 /(----- 1h OD (in) Length (ft) Description L.e- 8.55 8.55 0.90 PDC Hycalog DTX619M i(t pf`e_ 6.95 24.28 7"SperryDrill Lobe 7/8-6.0 stg Wµ 6.75 2.25 Float Sub 6.75 5.54 Integral Blade-Spiral P Flex Collar 31.03 --1 f 6.75 9.20 Non-Mag 6 3/4"PCDC Collar 6.75 28.17 Non-Mag 6 3/4" 3 Jts 5"X 3" EWR/DGR/PWD/HCIM Collar HWDP#49.3- 89.38 6.83 10.01 Non-Mag 6 3/4"TM/Pulser NC50(IF) Collar 6.52 31.03 Flex Collar 6.63 30.73 Flex Collar 6.57 30.37 Flex Collar 6 3/4" 5.00 89.38 3 Jts 5"X 3"HWDP#49.3- TM/Pulser 10.01 NC50(IF) Collar 6.50 31.90 Jar 5.00 327.67 11 Jts 5"X 3"HWDP#49.3- NC50(IF) y'9 6 3/4" 11 EWR/DGR/P 2817 Flex Collar 30.37 WD/HCIM -) Collar II 6 3/4"PCDC 9.20 Collar Integral Blade-Spiral 5.54 Float Sub 2.25 7"SperryDrill Lobe 7/8-6.0 24.28 stg PDC Hycalog q --, 0.90 DTX619M - r{ Y) Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, February 07, 2011 1:40 PM To: 'Nugent, David (Swift Technical Services LLC)' Subject: RE: 2L-320 PB2 Section (ADP Permit 210166 ) David, Before I forget can you send me a schematic of the BHA that was lost in the first PB section. I had forgotten to get that and was assuming it was not a radioactive source BHA. We are tracking lost BHA's in our data system.... I assume you are not changing the directional plan by more than 500' (wp-8 from PTD plan)from the original plan as a revision would be needed. (the first two drilling attempts appear to be easily with 500' ) Thanks for the update... and good luck. 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: Monday, February 07, 2011 12:58 PM To: Schwartz, Guy L (DOA) Subject: 2L-320 ADP Permit 210166 Guy, I am taking over the drilling of the 2L-320 well from Mike Greener. He has been reassigned to look at the"big picture"for wells in the future. We ran into some problems on the drilling of the sidetrack of this well, and wanted to let you know where we stand now and our forward plans. Due to hole conditions, we were unable to drill the sidetrack hole below 11,247' MD/4,438'TVD. So we decided to plug back the hole to the shoe and sidetrack again. This is what we have done with the sidetrack so far: 1. Ran an ECP packer and set it at 3,600' MD. 2. Pick up 3-1/2" cement stinger and set a cement plug from 3,600' MD to 3,000' MD with 96 bbls of 17ppg cement. 3. Wash off top 100' of cement. 4. Set a cement plug from 3,100' MD to 2,500' MD with 78 bbls of 17ppg cement. 5. Pick up out of cement and circulate BU. 6. POOH and lay down tools. 7. Test BOP's to 250/3,500 psi. 2/7/2011 Page 2 of 2 8. Pick up bit, motor, and LWD tools and TIH. 9. Tag firm cement at 2,450' MD. Drill firm cement to 2,695' MD. 10. Displace well from OBM to 9.5 ppg WBM. 11. Continue to drill firm cement and kick off well at 2,755' MD (surface shoe at 2,745' MD). 12. Directionally drilled to 6,320' MD as of midnight this morning. We made a short trip at 4,995' MD. 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'' - ', a p yHzIv N - ` f W A 01 p o ` L. w lCA 0 � ... 0 D �b pp W LA 3 O a 9 0m pvm (i m Jw�,, .yy m D�y� Zp 0...co o Gc O 00 0.1 I,A ,nNm.... 0 2i G^ A N ‘.0O A 3N co 01 N oo�wT po m o_ e m :tea �� 0 Page 1 of 2 Schwartz, Guy L (DOA) From: Greener, Mike R. [Mike.R.Greener@conocophillips.com] Sent: Monday, January 24, 2011 1:29 PM To: Schwartz, Guy L (DOA) Subject: FW: Plan forward 2L-320 as of 1/24/2011 Attachments: Greener Mike (Mike.R.Greener@conocophillips.com).vcf p r D "L( - /6,c, This is the plan forward for 2L-320 as we are unable to get the fish and have planned to sidetrack around it. Once we get a KO the revised directional will be forwarded to you. Mike Greener The following plan forward was developed for the 2L-320 as of 1/24/11. 1. Finish POOH and lay down fishing equipment. 2. PU cementing packer, 3-1/2" stinger and RIH. 3. Set packer at 8,000'. (Note: If you have trouble RIH with packer, you can set it as shallow as 5,000') 4. Inflate packer with mud to set and circulate hole clean. 5. Place 1,000' of cement in two balanced plugs. Mike Martin will provide cement details and balanced plug information. 6. After setting the first balanced plug, wash down to within 300' of the packer and then place the second balanced plug. 7. POOH and lay down all cementing equipment. PU RSS and full package of LWD/MWD tools and RIH to surface shoe. 8. Cement requires 24 hours of set time before we attempt to do our sidetrack. 2/7/2011 Page 2 of 2 I 9. Sidetrack point will be where we can get a stable footing on the cement. The sidetrack is an azimuth sidetrack. We must avoid placing a belly in the wellbore so the casing will not hang up. If there are any corrections, suggestions, or ideas with this plan forward, please reply to this email. 2/7/2011 Page 1 of 1 Schwartz, Guy L (DOA) PTD 2-16) — /6,6, From: Schwartz, Guy L (DOA) Sent: Thursday, January 20, 2011 2:02 PM To: 'Greener, Mike R.' Cc: DOA AOGCC Prudhoe Bay Subject: RE: 2L-320 1/20/2011 BOP Test Exception Mike, You are granted an extension from the upcoming BOP test until you are able to POOH with the current drill string. Good luck with the string shot and backoff. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Greener, Mike R. [mailto:Mike.R.Greener@conocophillips.com] Sent: Thursday, January 20, 2011 1:53 PM To: Schwartz, Guy L (DOA) Cc: Chambers, Mark A; Galiunas, Elizabeth C; Doyon 15 Company Man Subject: 2L-320 1/20/2011 BOP Test Exception Doyon 15 is drilling 2L-320 in the Tarn field. During the process of making a planned wiper trip from the depth of 11,445' MD / 4,519' TVD the drillstring became stuck at 9,240' MD. We are currently (1/20/2011 @ 14:00 hrs) trying to get a string shot down the drillpipe so we can do a backoff and POOH. Our deadline for a BOP test is midnight on 1/20/2011. It is very unlikely that we can meet this deadline and we are requesting an exception on the BOP test until we are able to separate the string and POOH. Mike Greener Page 1 of 1 Regg, James B (DOA) From: Greener, Mike R. [Mike.R.Greener@conocophillips.com] Pth LI0_ Sent: Tuesday, January 11, 2011 1:01 PM Kg“ ZL- / To: Schwartz, Guy L (DOA); Shultz, Steve (Orbis Engineering, Inc.) Cc: Regg, James B (DOA); Kanady, Randall B; Alvord, Chip; Galiunas, Elizabeth C Subject: RE: Kick on 2L-320 Attachments: Greener Mike (Mike.R.Greener@conocophillips.com).vcf; State report of BOP use.doc Attached is the reviewed and revised report of the kick on 2L-320. If there is anymore information needed, please let me know. Mike Greener From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, January 11, 2011 10:50 AM To: Greener, Mike R.; Shultz, Steve (Orbis Engineering, Inc.) Cc: Regg, James B (DOA); Kanady, Randall B Subject: FW: Kick on 2L-320 Steve/Mike: We got this initial report from the rig concerning the kick on 2L-320. Could you make sure we get a more detailed report as per AOGCC Guidance document 10-003 ... Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Doyon 15 Company Man [mailto:D15CM@conocophillips.com] Sent: Monday, January 10, 2011 5:28 AM To: DOA AOGCC Prudhoe Bay Cc: Chambers, Mark A Subject: Kick on 2L-320 Larry Hill /Scott Heim Doyon 15 Drilling Supervisor Office: 907-659-1755 Rig: 907-659-1756 Fax: 907-659-7364 1/11/2011 2L-320 Kick 1/9/11 Date, Time of BOPE Use: 1/9/2011 at 12:30 hrs Well/Location/PTD Number: 2L-320/Tarn /2101660 Rig Name: Doyon 15 Operator Contact: ConocoPhillips, Anchorage, Alaska Operations summary: Hole was drilled to a depth of 5,006'. At this depth a wiper trip was scheduled. Per the program, we opened the well commander tool and circulated 1.5 bottoms up with a rate of 220 spm. We then flow checked the well (the well was dead) and prepared to pull out of the hole on the trip tank. We got a strap on the trip tank and pulled out of the hole 4 stands. (NOTE: After pulling the 4 stands the pit watcher had gained 1/2 a bbl, which meant that there was 3.5 bbl influx in the well.) At that point, the driller informed the Company Representative that the hole was not taking fluid. The decision was made to flow check the well. The well was flowing a tiny trickle (barely enough to be seen). At 12:30 pm the top drive was made up and circulation was started. The flow increased dramatically and we turned off the pump and the Tool Pusher moved to shut in the well. The Tool Pusher shut in the well with the (Hydril) bag. Then we opened to the closed choke valve and monitored pressures. The casing pressure stabilized at 560 psi and the drill pipe pressure stabilized at 100 psi. The decision was made to pump the well by the driller's method. We started pumping at 1:25 pm and circulated the well holding ICP. At 4000 strokes the well was checked and was dead. Continued to circulate 9.3 PPG mud and RIH. Circulated and raised MW to 9.5 PPG. Resumed operations. BOPE Used: Annular Reason for BOPE Use: Prevent flow on drilling mud from well Actions Taken: Annular closed for shut in. Last BOPE test was 1/6/2011 at 15:30 hrs fid eeft,r4- 5�� ? ,k 1(i�li1 SQL 2L-320 Kick 1/9/11 zlo-te(0 Hole was drilled to a depth of 5,006'. At this depth a wiper trip was scheduled. Per the program, we opened the well commander tool and circulated 1.5 bottoms up with a rate of 220 spm. We then flow checked the well (the well was dead) and prepared to pull out of the hole on the trip tank. We got a strap on the trip tank and pulled out of the hole 4 stands. (NOTE: After pulling the 4 stands the pit watcher had gained 1/2 a bbl, which meant that there was 3.5 bbl influx in the well.) At that point, the driller informed the Company Representative that the hole was not taking fluid. The decision was made to flow check the well. The well was flowing a tiny trickle (barely enough to be seen). At 12:30 pm the top drive was made up and circulation was started. The flow increased dramatically and we turned off the pump and the Tool Pusher moved to shut in the well. The Tool Pusher shut in the well with the (Hydril) bag. Then we opened to the closed choke valve and monitored pressures. The casing pressure stabilized at 560 psi and the drill pipe pressure stabilized at 100 psi. The decision was made to pump the well by the driller's method. We started pumping at 1:25 pm and circulated the well holding ICP. At 4000 strokes the well was checked and was dead. Continued to circulate 9.3 PPG mud and RIH. Circulated and raised MW to 9.5 PPG. Resumed operations. ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION Division of Spill Prevention and Response Prevention and Emergency Response Program SITUATION REPORT INCIDENT NAME: Doyon Rig Oil Based Mud Spill SITREP#: 1 SPILL NUMBER: 11399900901 LEDGER CODE:Requested TIME/DATE OF SPILL:The incident occurred at 12:30 PM on January 9,2011. The ConocoPhillips Alaska, Inc. (CPAI)reported the incident to ADEC at 2:02 PM on the same day. TIME/DATE OF SITUATION REPORT:3:00 PM on January 10,2011 TIME/DATE OF THE NEXT REPORT: 3:00 PM on January 11,2011 TYPE/AMOUNT OF PRODUCT SPILLED:Doyon Drilling,Inc.staff estimated that approximately 45 barrels (1,890 gallons)of mineral oil based mud were released from a Doyon drill rig to snow-covered gravel pad,snow covered tundra,onto the wind walls,and within the secondary containment of the rig. Doyon Drilling,Inc. staff estimated the volume based on the amount of make-up mud required to refill the bore hole. LOCATION:Kuparuk 2L Well 320 CAUSE OF SPILL:The cause of the release is under investigation. POTENTIAL RESPONSIBLE PARTY(PRP):ConocoPhillips Alaska,Inc./Doyon Drilling,Inc. RESPONSE ACTION:The rig operator notified CPAI after a"gas kick"released drilling fluids from the well. The Alaska Clean Seas responders and trained volunteers from the Kuparuk Operations Center identified the spill area on the pad and tundra and began mobilizing other resources for cleanup and response work. The mineral oil based drilling mud spread over a 66-by 200-foot area of tundra and a 200-by 300-foot area of gravel pad along with the rig wind walls and cellar. Spill response technicians used hand shovels and brooms to remove the mud from the snow-covered tundra surface and stockpiled the removed material for transport and disposal. The drilling mud recovered from the rig's secondary containment area will be recycled or transported offsite for disposal. An ADEC responder has been dispatch to Kuparuk to assess the situation,monitor cleanup activities,and review work plans. No injuries were reported from the incident. SOURCE CONTROL:The well was shut in. Mud was returned to the well bore,stabilizing the subsurface conditions. RESOURCES AFFECTED: Snow-covered tundra and gravel pad. FUTURE PLANS AND RECOMMENDATIONS:The spill response crew will continue to conduct cleanup activities.CPAI will prepare a work plan for ADEC's review. WEATHER:East wind at approximately 5 knots,visibility 10 miles,ambient temperature 25°F. UNIFIED COMMAND AND PERSONNEL: Incident Commander: Kristy McCollough(ConocoPhillips) F.O.S.C.: S.O.S.C.: Tom DeRuyter(ADEC) Doyon Rig Oil Based Mud Spill 1/10/2011 Page 2 of 2 Sitrep 1 Field S.O.S.C.: John Ebel(ADEC) FOR ADDITIONAL INFORMATION CONTACT: Tom DeRuyter,ADEC at(907)451-2145 Photographs and other spill information are available for viewing at: http://www.state.ak.us/dec/spar/perp/index.htm AGENCY/STAKEHOLDER NOTIFICATION LIST This sitrep has been distributed to the following agencies and stakeholders. This situation report was also distributed to the various agency staff listed on the standard distribution list. The receiving agencies listed in the standard distribution list includes:Governor's office,Senator Begich's office,ADF&G,ADNR,SECC,EPA,DOI, NMFS,and USFWS. AGENCY/STAKEHOLDER NAME SENT VIA ADDITIONAL INFO TELEPHONE FAX ADNR Melissa Head Email 451-2719 451-2751 Gary Schultz 451-2732 ADF&G(Habitat) Al Ott/Jack Winters Fax 459-7285 or 459-7279 459-7303 AOGCC Fax 276-7542 EPA Matt Carr/Robert Whittier Fax 271-5083/271-3247 271-6340 Attorney General Office Cam Leonard/ Fax 451-2811/451-2914 451-2985/ Steve Mulder 278-7022 Governor's Office Pamell/Treadwell Email 451-2920 451-2858 (Fairbanks) Lt.Governor's Office Mead Treadwell Email 465-3520 465-5400 (Juneau) Senator Murkowski's Chief of Staff Fax North Slope only (202)224-6665 (202)224-5301 Washington DC Office Senator Murkowski's Office Fax North Slope only 456-0233 451-7146 in Fairbanks Legislator(Senate T) Donnie Olson(D) Fax Nome 465-3707 465-4821 Legislator(House 40) Reggie Joule(D) Fax Kotzebue 465-4833 or 465-4586 (800)782-4833 Legislator(Senate F) John Coghill Fax Valdez 488-1546/465-3719 488-4271/ 465-3258 Legislator(House 12) Eric Feige Fax Valdez 269-0129/465-4859 269-0128/465- 3799 North Slope Borough Edward Sagaan Itta Fax Mayor 852-0200 852-0337 I North Slope Borough Dan Forster Fax Planning Director 852-0440 852-5991 roi �g S SEAN PARNELL,GOVERNOR Li b -t. LE 0 F n [Ln ,ni\. ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,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-320 ConocoPhillips Alaska, Inc. Permit No: 210-166 Surface Location: 202' FNL, 792' FEL, SEC. 22, T1ON, R7E, UM Bottomhole Location: 242' FNL, 303' FEL, SEC. 25, 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. do4 � -op ,r� . Norma ommissioner DATED this Z2ay 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) STATE OF ALASKA ; ALASKA OIL AND GAS CONSERVATION COMMISSION NON/AECEIA/E7 2010 PERMIT TO DRILL 20 AAC 25.005 8x14 iA ild Gat COM.C'Qii 'k3S101s la.Type of Work: lb.Proposed Well Class: Development-Oil ❑✓ , Service-Winj ❑ Single Zone ❑✓ ' 1c. proposed for: Drill E. Re-drill❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5, Bond: U Blanket u Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180. 2L-320 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 14845' . TVD: 5870' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:202'FNL,792'FEL,Sec.22,T1ON,R7E,UM ADL 380052,380051,380053 ' Tarn Oil Pool . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 130'FSL,444'FEL,Sec.24,T1ON, R7E,UM 4600,4599,4601 12/16/2010 Total Depth: 9.Acres in Property: 14.Distance to 242'FNL,303'FEL,Sec.25,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- 460859 • y- 5927644` Zone- 4 GL Elevation above MSL: - 115 feet to Same Pool: 2L-301 ,913'©11237' 16.Deviated wells: Kickoff depth: 400 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 77° deg Downhole:2402 psig , Surface: 1798 psig • 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (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 3150' Surf. Surf 3150' 2469' 540 sx ASLite,370 sx DeepCRETE 9.875" 7.625" 29.7# L-80 BTCM 14845' Surf. Surf 14845' 5870' 710 sx GasBLOK 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 ND(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 E Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-4297 Printed Name G. C. Alvord Title Alaska Drilling Manager Signature :/ / ^1- Phon 265-6120 Date i t( 1(o i L Q i, , (,~(_�� Commission Use Only Permit to Drill API Number: 1 Permit ApprovI See cover letter Number 2_/o / (43113 50/03 -7 7 7 •-a Date: 1, .\\\ for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m- ane,ga hydrates,or gas contained in shales: 4 ., ft3.3560 r s� Qv P �s r Samples req'd: Yes ❑ ,o 1 Mud log req'd: Yes ❑ No W Other: Z. aJ s • Ade"',,,(,,,, T t H2S easures: Yes (4 No a 'ctional svy req'd: Yes [( No ❑ %, n APPROVED BY THE COMMISSION DATE: //• j?j,,v ,COMMISSIONER Form 10-401 (Revised 7/2009) Thi p(/fl valid f a ni n{tNla :pprov I(2i • •C 25.005(8)► L 111 Submit in Duplicate 100360ConocoPhalli Post Office Box Anchorage,Alaska 99510-0360 Chip Alvord Phone(907)265-6120 Email: Chip.Alvord@conocophillips.com November 1 1,2010 RECEIVE* Alaska Oil and Gas Conservation Commission �),� 1 ` 2010�� 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 MaSial &Gas Cons.Coag 5sion RE: Application for Permit to Drill 2L-320 Anchorage Dear Commissioners, ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore production well 2L-320. The well will be drilled and completed using Doyon Rig#15. The planned spud date for 2L-320 is Dec. 16,2010. 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, A- t (%iL_ ti((,(LatP Chip Alvord Drilling Manager ation for Permit to Drill,Well 2L-320 Saved: 11-Nov-10 Permit It — Tarn Well 2L-320 4e. Application for Permit to Drill Document a ell maximize well Value Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 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 32c 2L-342•APD Page 1 of 7 gg AL Printed: 11-Nov-10 l ation for Permit to Drill,Well 2L-320 Saved: 11-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 be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. 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 identiffing 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 202' FNL, 792' FEL, Sec 22, TION,R7E,UM . NAD 1927 RKB Elevation 155.4'AMSL Northings: 5,927,644 Eastings: 460,859 Pad Elevation 115.4'AMSL . Location at Top of Productive Interval 130' FSL,444' FEL, Sec 24,TION,R7E,UM (Bermuda) Nad 1927 Measured Depth, RKB: 14,289' Northings: 5,922,648 Eastings: 471,747 Total Vertical Depth, RKB: 5,481' Total Vertical Depth, SS: 5,326' Location at Total Depth 242'FNL, 303' FEL, Sec 25,T1ON,R7E,UM Nad 1927 Measured Depth,RKB: 14,845' Northings: 5,922,275 Eastings: 471,887 Total Vertical Depth,RKB: 5,870' Total Vertical Depth, SS: 5,715' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) Ifa 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. 3Za 2L- 12APD Page 2 of 7 Printed: 11-Nov-10 f ation for Permit to Drill,Well 2L-320 Saved: 11-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(BOPE)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-320's offset wells are: Well Type SBHP MW Distance Direction Shut in Time 2L-301 Producer 1,228 psi 4.6 ppg 2,020' E/NE 148 hrs 2L-309 Producer 1,418 psi 5.1 ppg 1,910' S/SW 920 hrs 2L-317A Injector 3,822 psi 13.8 ppg 1,500' W 432 hrs Given the above range of pressures,2L-320 is expected to have a BHP range of 2,000—2,400 psi at the reservoir depth of 5,483'TVD. This gives a mud weight range of 7.0 ppg—8.4 ppg for 2L-320. • Equivalent Mud Weight @ TD=2,400/(5,483*.052)=8.4 ppg=0.438 psi/ft The maximum potential surface pressure(MPSP)while drilling 2L-320 is calculated using the higher end of the predicted reservoir pressure 2,400 psi,a 0.11 psi/ft gas gradient,and a Bermuda sand top TVD of 5,483' (estimated top of reservoir in 2L-320). MPSP =(5,483 ft TVD)*(0.438-0.11 psi/ft) = 1,798 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(1); 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. a -3r,1-) -2I-31-2 APD Page 3 of 7 RI S I N ALPrinted. 11-Nov-10 E ` 1� A ition for Permit to Drill,Well 2L-320 Saved: 11-Nov-10 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed; Casing and 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 3,150' Surf 3,150'/2,469' 540 sx ASLite Lead 10.7 ppg, 370 sx Tail Slurry 12.0 ppg Cement Top planned @ 12,220'MD/ 7-5/8 9-7/8 29.7 L-80 BTCM 14,845' Surf 14,845'/5,870' 4,719'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 for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 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.fuid system,as required by 20 AAC 25.033; Drilling will be done using mud systems having the following properties: Surface WBM 120'—3,150 ' 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 3,150'—14,845' Density(ppg) 8.5—9.0 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- O APD Page 4 of 7 U R I G I N A ( Printed:11-Nov-10 Al lion for Permit to Drill,Well 2L-320 Saved: 11-Nov-10 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.0330; 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(c)(11) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom founded structure,jack-up rig,orf oating 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 for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding)have been met; Evidence of bonding for 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-320 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(3,150'MD/2,469'TVD) according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with oil base mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Notify '— state of BOP test. Record results. 7. Shut in BOP's and pressure test casing to 300,0 nsi per AOGCC regulations. Record results. 8. Drill out cement and 20'minimum to 50' maximum of new hole.Perform LOT. • 9. Directionally drill 9-7/8"hole to 14,845'MD/5,870'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 14,845'MD/5,870'TVD and cement. 3Lo 2L-3t2•APD Page 5 of 7 'ORIGINAL Printed: 11-Nov-10 ation for Permit to Drill,Well 2L-320 Saved: 11-Nov-10 11. Run 3-1/2"completion tubing with packer and set at+/- 14,250' MD/5,449'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 1(.. «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: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 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 3 Z. 2L-3+2--APD Page 6 of 7 0 R I6I Printed: 11-Nov-10 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-320 (Delilah) 2L-320 :f Plan: 2L-320 (wp05) Standard Proposal Report 02 November, 2010 HALLIBURTON Sperry Drilling Services ORtGINAL H I I I 0 � co 11 I I I —CO �.L, g II I I =OMMO N C o c II I I I - O t. ti Cl) II I I - 0 II I I I O -� ` a 03 00 o 11 1 I I C. - 0 < Ee� U -11 "a N EM II n i I I sd - o La �� J E O O O f- CO Z-E- II I I I QQ Q4� N - N 0 Q c0 U) M 00 M S M h S00103 . 11 . . 6o W LLILUUUPp COU n yam, 11 Z I I I d� - J - c o _ M I I 0 I I 1 00 I /1\ N - O O , 0 mvNv on00N. 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Design: 2L-320(wp05) Project Kuparuk River Unit,North Slope Alaska,United States 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 Site Kuparuk 2L Pad Site Position: Northing: 5,927,695.13 ft Latitude: 70°12'48.272 N From: Map Easting: 461,077.91 ft Longitude: 150°18'50.048 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.30° Well Plan:2L-320(Delilah) Well Position +N/-S 0.00 ft Northing: 5,927,644.48 ft Latitude: 70°12'47.763 N +E/-W 0.00 ft Easting: 460,858.81 ft Longitude: 150°18'56.402 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.80 ft Wellbore 2L-320 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 3/23/2010 21.46 80.70 57,627 Design 2L-320(wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) C) 40.00 0.00 0.00 115.66 11/2/2010 10:08:54AMPage 2 y p COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-320(Delilah) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-320(Delilah) Survey Calculation Method: Minimum Curvature Wellbore: 2L-320 Design: 2L-320(wp05) 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) (1100ft) (1100ft) (°/100ft) (0) 40.00 0.00 0.0040.00 -114.80 0.00 0.00 0.00 0.00 0.00 0.00 390.00 0.00 0.00 390.00 235.20 0.00 0.00 0.00 0.00 0.00 0.00 540.00 3.00 125.00 539.93 385.13 -2.25 3.22 2.00 2.00 0.00 125.00 740.00 9.00 125.00 738.74 583.94 -14.24 20.33 3.00 3.00 0.00 0.00 1,040.00 9.00 125.00 1,035.05 880.25 -41.16 58.78 0.00 0.00 0.00 0.00 1,363.56 17.09 125.00 1,350.00 1,195.20 -83.01 118.55 2.50 2.50 0.00 0.00 1,463.56 17.09 125.00 1,445.58 1,290.78 -99.86 142.62 0.00 0.00 0.00 0.00 2,929.58 75.63 119.14 2,414.22 2,259.42 -614.96 1,016.95 4.00 3.99 -0.40 -6.65 3,529.58 75.63 113.14 2,563.13 2,408.33 -870.92 1,538.49 0.97 0.00 -1.00 -90.00 5,429.58 75.63 113.14 3,034.68 2,879.88 -1,594.25 3,230.96 0.00 0.00 0.00 0.00 5,729.58 75.64 111.59 3,109.12 2,954.32 -1,704.84 3,499.70 0.50 0.00 -0.52 -90.00 11,879.58 75.64 111.59 4,634.92 4,480.12 -3,897.30 9,039.33 0.00 0.00 0.00 0.00 11,949.62 77.48 109.94 4,651.20 4,496.40 -3,921.44 9,103.02 3.50 2.64 -2.37 -41.31 13,120.97 77.48 109.94 4,905.09 4,750.29 -4,311.32 10,178.01 0.00 0.00 0.00 0.00 14,289.02 45.66 159.11 5,480.80 5,326.00 -4,940.75 10,915.36 4.50 -2.72 4.21 137.03 14,595.22 45.66 159.11 5,694.80 5,540.00 -5,145.37 10,993.44 0.00 0.00 0.00 0.00 14,845.22 45.66 159.11 5,869.52 5,714.72 -5,312.43 11,057.19 0.00 0.00 0.00 0.00 11/2/2010 10:08:54AM Page 3 COMPASS 2003.16 Build 69 nP1fI 1 1 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-320(Delilah) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Staked:2L-320 @ 154.80f1(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-320(Delilah) Survey Calculation Method: Minimum Curvature Wellbore: 2L-320 Design: 2L-320(wp05) Planned Survey Measured Vertical Map Map � Depth Inclination Azimuth Depth TVDss +N/-S +EI-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 5,927,644.48 460,858.81 0.00 0.00 Surface Location:202'FNL,792'FEL-Sec22,T10N-R07E 100.00 0.00 0.00 100.00 -54.80 0.00 0.00 5,927,644.48 460,858.81 0.00 0.00 200.00 0.00 0.00 200.00 45.20 0.00 0.00 5,927,644.48 460,858.81 0.00 0.00 300.00 0.00 0.00 300.00 145.20 0.00 0.00 5,927,644.48 460,858.81 0.00 0.00 390.00 0.00 0.00 390.00 235.20 0.00 0.00 5,927,644.48 460,858.81 0.00 0.00 400.00 0.20 125.00 400.00 245.20 -0.01 0.01 5,927,644.47 460,858.83 2.00 0.02 500.00 2.20 125.00 499.97 345.17 -1.21 1.73 5,927,643.26 460,860.54 2.00 2.08 540.00 3.00 125.00 539.93 385.13 -2.25 3.22 5,927,642.21 460,862.02 2.00 3.87 600.00 4.80 125.00 599.79 444.99 -4.59 6.56 5,927,639.85 460,865.35 3.00 7.90 700.00 7.80 125.00 699.17 544.38 -10.89 15.55 5,927,633.51 460,874.30 3.00 18.73 740.00 9.00 125.00 738.74 583.94 -14.24 20.33 5,927,630.13 460,879.07 3.00 24.49 800.00 9.00 125.00 798.01 643.21 -19.62 28.02 5,927,624.71 460,886.73 0.00 33.76 900.00 9.00 125.00 896.78 741.98 -28.59 40.84 5,927,615.67 460,899.50 0.00 49.19 1,000.00 9.00 125.00 995.54 840.74 -37.57 53.65 5,927,606.64 460,912.26 0.00 64.63 1,040.00 9.00 125.00 1,035.05 880.25 -41.16 58.78 5,927,603.02 460,917.37 0.00 70.80 1,100.00 10.50 125.00 1,094.18 939.38 -46.98 67.10 5,927,597.15 460,925.66 2.50 80.83 1,200.00 13.00 125.00 1,192.08 1,037.28 -58.66 83.78 5,927,585.39 460,942.28 2.50 100.92 1,300.00 15.50 125.00 1,289.00 1,134.20 -72.78 103.94 5,927,571.16 460,962.37 2.50 125.21 1,363.56 17.09 125.00 1,350.00 1,195.20 -83.01 118.55 5,927,560.86 460,976.92 2.50 142.80 1,394.74 17.09 125.00 1,379.80 1,225.00 -88.26 126.05 5,927,555.57 460,984.40 0.00 151.84 Permafrost 1,400.00 17.09 125.00 1,384.83 1,230.03 -89.15 127.32 5,927,554.67 460,985.66 0.00 153.37 1,463.56 17.09 125.00 1,445.58 1,290.78 -99.86 142.62 5,927,543.88 461,000.90 0.00 171.80 1,500.00 18.54 124.47 1,480.28 1,325.48 -106.21 151.78 5,927,537.49 461,010.03 4.00 182.81 1,600.00 22.52 123.35 1,573.91 1,419.11 -125.75 180.90 5,927,517.81 461,039.04 4.00 217.51 1,700.00 26.50 122.56 1,664.88 1,510.08 -148.29 215.71 5,927,495.08 461,073.73 4.00 258.65 1,800.00 30.49 121.96 1,752.74 1,597.94 -173.74 256.06 5,927,469.43 461,113.95 4.00 306.05 1,900.00 34.49 121.48 1,837.07 1,682.27 -201.96 301.75 5,927,440.97 461,159.49 4.00 359.45 2,000.00 38.48 121.10 1,917.46 1,762.66 -232.83 352.56 5,927,409.85 461,210.13 4.00 418.61 2,100.00 42.47 120.77 1,993.51 1,838.71 -266.19 408.23 5,927,376.20 461,265.62 4.00 483.24 2,200.00 46.47 120.49 2,064.86 1,910.06 -301.87 468.50 5,927,340.21 461,325.70 4.00 553.02 2,300.00 50.47 120.25 2,131.15 1,976.35 -339.71 533.08 5,927,302.04 461,390.07 4.00 627.61 2,400.00 54.46 120.03 2,192.06 2,037.26 -379.52 601.64 5,927,261.88 461,458.42 4.00 706.65 2,500.00 58.46 119.84 2,247.30 2,092.50 -421.10 673.86 5,927,219.93 461,530.41 4.00 789.75 2,600.00 62.46 119.66 2,296.60 2,141.80 -464.26 749.37 5,927,176.38 461,605.70 4.00 876.51 2,700.00 66.45 119.49 2,339.71 2,184.91 -508.78 827.83 5,927,131.46 461,683.91 4.00 966.51 2,800.00 70.45 119.33 2,376.43 2,221.63 -554.45 908.83 5,927,085.38 461,764.67 4.00 1,059.30 2,900.00 74.45 119.18 2,406.58 2,251.78 -601.04 992.00 5,927,038.37 461,847.59 4.00 1,154.44 2,929.58 75.63 119.14 2,414.22 2,259.42 -614.96 1,016.95 5,927,024.31 461,872.47 4.00 1,182.96 3,000.00 75.63 118.44 2,431.70 2,276.90 -647.81 1,076.74 5,926,991.15 461,932.07 0.97 1,251.08 3,100.00 75.63 117.44 2,456.52 2,301.72 -693.20 1,162.32 5,926,945.33 462,017.41 0.97 1,347.87 3,150.00 75.63 116.94 2,468.92 2,314.13 -715.33 1,205.40 5,926,922.98 462,060.38 0.97 1,396.29 10 3/4"Casing @ 3150'MD,2469'TVD:917'FNL,412'FWL-Sec23,T10N,R07E-10 3/4" 11/2/2010 10:08:54AM0 ta INAI COMPASS 2003.16 Build 69 Halliburton -Sperry HALL I B U R TO N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-320(Delilah) Company: ConocoPhillips(Alaska)Inc.-Kup2 ND Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-320(Delilah) Survey Calculation Method: Minimum Curvature Wellbore: 2L-320 Design: 2L-320(wp05) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) C) (°) (ft) ft (ft) (ft) (ft) (ft) 2,325.00 3,193.82 75.63 116.50 2,479.80 2,325.00 -734.41 1,243.32 5,926,903.70 462,098.19 0.97 1,438.73 C-80 3,200.00 75.63 116.44 2,481.33 2,326.53 -737.08 1,248.68 5,926,901.01 462,103.53 0.97 1,444.72 3,300.00 75.63 115.44 2,506.15 2,351.35 -779.45 1,335.79 5,926,858.19 462,190.42 0.97 1,541.59 3,400.00 75.63 114.44 2,530.97 2,376.17 -820.29 1,423.63 5,926,816.90 462,278.04 0.97 1,638.45 3,443.64 75.63 114.00 2,541.80 2,387.00 -837.63 1,462.18 5,926,799.36 462,316.49 0.97 1,680.70 Campanian Sands 3,500.00 75.63 113.44 2,555.79 2,400.99 -859.59 1,512.17 5,926,777.14 462,366.36 0.97 1,735.27 3,529.58 75.63 113.14 2,563.13 2,408.33 -870.92 1,538.49 5,926,765.68 462,392.62 0.97 1,763.90 3,600.00 75.63 113.14 2,580.61 2,425.81 -897.73 1,601.22 5,926,738.55 462,455.20 0.00 1,832.05 3,700.00 75.63 113.14 2,605.42 2,450.63 -935.80 1,690.30 5,926,700.02 462,544.07 0.00 1,928.83 3,800.00 75.63 113.14 2,630.24 2,475.44 -973.87 1,779.37 5,926,661.49 462,632.94 0.00 2,025.61 3,900.00 75.63 113.14 2,655.06 2,500.26 -1,011.94 1,868.45 5,926,622.96 462,721.81 0.00 2,122.39 4,000.00 75.63 113.14 2,679.88 2,525.08 -1,050.01 1,957.53 5,926,584.44 462,810.68 0.00 2,219.16 4,100.00 75.63 113.14 2,704.70 2,549.90 -1,088.08 2,046.60 5,926,545.91 462,899.55 0.00 2,315.94 4,200.00 75.63 113.14 2,729.52 2,574.72 -1,126.15 2,135.68 5,926,507.38 462,988.42 0.00 2,412.72 4,300.00 75.63 113.14 2,754.33 2,599.53 -1,164.22 2,224.76 5,926,468.85 463,077.29 0.00 2,509.50 4,400.00 75.63 113.14 2,779.15 2,624.35 -1,202.29 2,313.84 5,926,430.33 463,166.16 0.00 2,606.27 4,500.00 75.63 113.14 2,803.97 2,649.17 -1,240.36 2,402.91 5,926,391.80 463,255.03 0.00 2,703.05 4,600.00 75.63 113.14 2,828.79 2,673.99 -1,278.43 2,491.99 5,926,353.27 463,343.90 0.00 2,799.83 4,700.00 75.63 113.14 2,853.61 2,698.81 -1,316.50 2,581.07 5,926,314.74 463,432.77 0.00 2,896.61 4,800.00 75.63 113.14 2,878.43 2,723.63 -1,354.57 2,670.14 5,926,276.22 463,521.64 0.00 2,993.39 4,900.00 75.63 113.14 2,903.24 2,748.44 -1,392.64 2,759.22 5,926,237.69 463,610.51 0.00 3,090.16 5,000.00 75.63 113.14 2,928.06 2,773.26 -1,430.71 2,848.30 5,926,199.16 463,699.38 0.00 3,186.94 5,100.00 75.63 113.14 2,952.88 2,798.08 -1,468.78 2,937.38 5,926,160.63 463,788.25 0.00 3,283.72 5,200.00 75.63 113.14 2,977.70 2,822.90 -1,506.85 3,026.45 5,926,122.11 463,877.12 0.00 3,380.50 5,300.00 75.63 113.14 3,002.52 2,847.72 -1,544.92 3,115.53 5,926,083.58 463,965.99 0.00 3,477.27 5,400.00 75.63 113.14 3,027.34 2,872.54 -1,582.99 3,204.61 5,926,045.05 464,054.86 0.00 3,574.05 5,429.58 75.63 113.14 3,034.68 2,879.88 -1,594.25 3,230.96 5,926,033.66 464,081.14 0.00 3,602.68 5,500.00 75.63 112.78 3,052.15 2,897.35 -1,620.86 3,293.77 5,926,006.72 464,143.81 0.50 3,670.82 5,600.00 75.63 112.26 3,076.97 2,922.17 -1,657.96 3,383.25 5,925,969.16 464,233.10 0.50 3,767.54 5,700.00 75.63 111.75 3,101.78 2,946.98 -1,694.25 3,473.07 5,925,932.41 464,322.71 0.50 3,864.22 5,729.58 75.64 111.59 3,109.12 2,954.32 -1,704.84 3,499.70 5,925,921.69 464,349.29 0.50 3,892.80 5,800.00 75.64 111.59 3,126.59 2,971.79 -1,729.94 3,563.13 5,925,896.26 464,412.58 0.00 3,960.85 5,900.00 75.64 111.59 3,151.40 2,996.60 -1,765.59 3,653.21 5,925,860.15 464,502.46 0.00 4,057.48 6,000.00 75.64 111.59 3,176.21 3,021.41 -1,801.24 3,743.28 5,925,824.03 464,592.34 0.00 4,154.11 6,100.00 75.64 111.59 3,201.02 3,046.22 -1,836.89 3,833.36 5,925,787.92 464,682.22 0.00 4,250.74 6,200.00 75.64 111.59 3,225.83 3,071.03 -1,872.54 3,923.43 5,925,751.81 464,772.10 0.00 4,347.37 6,300.00 75.64 111.59 3,250.64 3,095.84 -1,908.19 4,013.51 5,925,715.70 464,861.98 0.00 4,444.00 6,400.00 75.64 111.59 3,275.45 3,120.65 -1,943.84 4,103.58 5,925,679.58 464,951.86 0.00 4,540.63 6,500.00 75.64 111.59 3,300.26 3,145.46 -1,979.49 4,193.66 5,925,643.47 465,041.74 0.00 4,637.26 6,600.00 75.64 111.59 3,325.07 3,170.27 -2,015.14 4,283.73 5,925,607.36 465,131.62 0.00 4,733.88 6,700.00 75.64 111.59 3,349.88 3,195.08 -2,050.79 4,373.81 5,925,571.24 465,221.50 0.00 4,830.51 6,800.00 75.64 111.59 3,374.69 3,219.89 -2,086.44 4,463.89 5,925,535.13 465,311.38 0.00 4,927.14 6,900.00 75.64 111.59 3,399.50 3,244.70 -2,122.09 4,553.96 5,925,499.02 465,401.27 0.00 5,023.77 11/2/2010 10:08:54AM Page 5 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-320(Delilah) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-320(Delilah) Survey Calculation Method: Minimum Curvature Wellbore: 2L-320 Design: 2L-320(wp05) I Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,269.51 7,000.00 75.64 111.59 3,424.31 3,269.51 -2,157.74 4,644.04 5,925,462.91 465,491.15 0.00 5,120.40 7,100.00 75.64 111.59 3,449.12 3,294.32 -2,193.39 4,734.11 5,925,426.79 465,581.03 0.00 5,217.03 7,200.00 75.64 111.59 3,473.93 3,319.13 -2,229.04 4,824.19 5,925,390.68 465,670.91 0.00 5,313.66 7,300.00 75.64 111.59 3,498.74 3,343.94 -2,264.69 4,914.26 5,925,354.57 465,760.79 0.00 5,410.29 7,400.00 75.64 111.59 3,523.55 3,368.75 -2,300.34 5,004.34 5,925,318.46 465,850.67 0.00 5,506.92 7,500.00 75.64 111.59 3,548.36 3,393.56 -2,335.99 5,094.41 5,925,282.34 465,940.55 0.00 5,603.55 7,600.00 75.64 111.59 3,573.17 3,418.37 -2,371.64 5,184.49 5,925,246.23 466,030.43 0.00 5,700.18 7,700.00 75.64 111.59 3,597.98 3,443.18 -2,407.29 5,274.56 5,925,210.12 466,120.31 0.00 5,796.81 7,800.00 75.64 111.59 3,622.79 3,467.99 -2,442.94 5,364.64 5,925,174.00 466,210.19 0.00 5,893.44 7,900.00 75.64 111.59 3,647.60 3,492.80 -2,478.59 5,454.71 5,925,137.89 466,300.07 0.00 5,990.06 8,000.00 75.64 111.59 3,672.41 3,517.61 -2,514.24 5,544.79 5,925,101.78 466,389.95 0.00 6,086.69 8,100.00 75.64 111.59 3,697.22 3,542.42 -2,549.88 5,634.86 5,925,065.67 466,479.83 0.00 6,183.32 8,200.00 75.64 111.59 3,722.03 3,567.23 -2,585.53 5,724.94 5,925,029.55 466,569.71 0.00 6,279.95 8,300.00 75.64 111.59 3,746.84 3,592.04 -2,621.18 5,815.02 5,924,993.44 466,659.59 0.00 6,376.58 8,400.00 75.64 111.59 3,771.65 3,616.85 -2,656.83 5,905.09 5,924,957.33 466,749.47 0.00 6,473.21 8,500.00 75.64 111.59 3,796.46 3,641.66 -2,692.48 5,995.17 5,924,921.22 466,839.35 0.00 6,569.84 8,600.00 75.64 111.59 3,821.27 3,666.47 -2,728.13 6,085.24 5,924,885.10 466,929.23 0.00 6,666.47 8,700.00 75.64 111.59 3,846.08 3,691.28 -2,763.78 6,175.32 5,924,848.99 467,019.11 0.00 6,763.10 8,800.00 75.64 111.59 3,870.89 3,716.09 -2,799.43 6,265.39 5,924,812.88 467,108.99 0.00 6,859.73 8,900.00 75.64 111.59 3,895.70 3,740.90 -2,835.08 6,355.47 5,924,776.76 467,198.88 0.00 6,956.36 8,977.00 75.64 111.59 3,914.80 3,760.00 -2,862.53 6,424.82 5,924,748.96 467,268.08 0.00 7,030.76 C-50 9,000.00 75.64 111.59 3,920.51 3,765.71 -2,870.73 6,445.54 5,924,740.65 467,288.76 0.00 7,052.99 9,100.00 75.64 111.59 3,945.32 3,790.52 -2,906.38 6,535.62 5,924,704.54 467,378.64 0.00 7,149.62 9,200.00 75.64 111.59 3,970.13 3,815.33 -2,942.03 6,625.69 5,924,668.43 467,468.52 0.00 7,246.25 9,300.00 75.64 111.59 3,994.94 3,840.14 -2,977.68 6,715.77 5,924,632.31 467,558.40 0.00 7,342.87 9,400.00 75.64 111.59 4,019.75 3,864.95 -3,013.33 6,805.84 5,924,596.20 467,648.28 0.00 7,439.50 9,500.00 75.64 111.59 4,044.56 3,889.76 -3,048.98 6,895.92 5,924,560.09 467,738.16 0.00 7,536.13 9,600.00 75.64 111.59 4,069.37 3,914.57 -3,084.63 6,986.00 5,924,523.98 467,828.04 0.00 7,632.76 9,700.00 75.64 111.59 4,094.17 3,939.38 -3,120.28 7,076.07 5,924,487.86 467,917.92 0.00 7,729.39 9,800.00 75.64 111.59 4,118.98 3,964.19 -3,155.93 7,166.15 5,924,451.75 468,007.80 0.00 7,826.02 9,900.00 75.64 111.59 4,143.79 3,988.99 -3,191.58 7,256.22 5,924,415.64 468,097.68 0.00 7,922.65 10,000.00 75.64 111.59 4,168.60 4,013.80 -3,227.23 7,346.30 5,924,379.52 468,187.56 0.00 8,019.28 10,100.00 75.64 111.59 4,193.41 4,038.61 -3,262.88 7,436.37 5,924,343.41 468,277.44 0.00 8,115.91 10,200.00 75.64 111.59 4,218.22 4,063.42 -3,298.53 7,526.45 5,924,307.30 468,367.32 0.00 8,212.54 10,300.00 75.64 111.59 4,243.03 4,088.23 -3,334.18 7,616.52 5,924,271.19 468,457.20 0.00 8,309.17 10,400.00 75.64 111.59 4,267.84 4,113.04 -3,369.83 7,706.60 5,924,235.07 468,547.08 0.00 8,405.80 10,500.00 75.64 111.59 4,292.65 4,137.85 -3,405.48 7,796.67 5,924,198.96 468,636.96 0.00 8,502.43 , 10,600.00 75.64 111.59 4,317.46 4,162.66 -3,441.13 7,886.75 5,924,162.85 468,726.84 0.00 8,599.06 10,629.57 75.64 111.59 4,324.80 4,170.00 -3,451.67 7,913.39 5,924,152.17 468,753.42 0.00 8,627.63 C-40 10,700.00 75.64 111.59 4,342.27 4,187.47 -3,476.78 7,976.82 5,924,126.74 468,816.72 0.00 8,695.68 10,800.00 75.64 111.59 4,367.08 4,212.28 -3,512.43 8,066.90 5,924,090.62 468,906.60 0.00 8,792.31 8,888.94 10,900.00 75.64 111.59 4,391.89 4,237.09 -3,548.08 8,156.97 5,924,054.51 468,996.49 0.00 11,000.00 75.64 111.59 4,416.70 4,261.90 -3,583.73 8,247.05 5,924,018.40 469,086.37 0.00 8,985.57 11/2/2010 10:08:54AM ` Page 6 i N A COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-320(Delilah) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-320(Delilah) Survey Calculation Method: Minimum Curvature Wellbore: 2L-320 Design: 2L-320(wp05) 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) 4,286.71 11,100.00 75.64 111.59 4,441.51 4,286.71 -3,619.38 8,337.13 5,923,982.28 469,176.25 0.00 9,082.20 11,200.00 75.64 111.59 4,466.32 4,311.52 -3,655.03 8,427.20 5,923,946.17 469,266.13 0.00 9,178.83 11,300.00 75.64 111.59 4,491.13 4,336.33 -3,690.68 8,517.28 5,923,910.06 469,356.01 0.00 9,275.46 11,355.09 75.64 111.59 4,504.80 4,350.00 -3,710.32 8,566.90 5,923,890.16 469,405.52 0.00 9,328.70 Top Pool @ 11355'MD,4505'TVD:1363'FSL,2490'FWL-Sec24,T1 ON,R07E-C-37 11,400.00 75.64 111.59 4,515.94 4,361.14 -3,726.33 8,607.35 5,923,873.95 469,445.89 0.00 9,372.09 11,500.00 75.64 111.59 4,540.75 4,385.95 -3,761.98 8,697.43 5,923,837.83 469,535.77 0.00 9,468.72 11,600.00 75.64 111.59 4,565.56 4,410.76 -3,797.63 8,787.50 5,923,801.72 469,625.65 0.00 9,565.35 11,700.00 75.64 111.59 4,590.37 4,435.57 -3,833.28 8,877.58 5,923,765.61 469,715.53 0.00 9,661.98 11,800.00 75.64 111.59 4,615.18 4,460.38 -3,868.93 8,967.65 5,923,729.50 469,805.41 0.00 9,758.61 1 11,879.58 75.64 111.59 4,634.92 4,480.12 -3,897.30 9,039.33 5,923,700.76 469,876.94 0.00 9,835.50 11,900.00 76.17 111.11 4,639.90 4,485.10 -3,904.51 9,057.78 5,923,693.45 469,895.34 3.50 9,855.25 11,949.62 77.48 109.94 4,651.20 4,496.40 -3,921.44 9,103.02 5,923,676.29 469,940.49 3.50 9,903.37 12,000.00 77.48 109.94 4,662.12 4,507.33 -3,938.21 9,149.26 5,923,659.28 469,986.64 0.00 9,952.31 12,100.00 77.48 109.94 4,683.80 4,529.00 -3,971.50 9,241.04 5,923,625.52 470,078.23 0.00 10,049.44 12,200.00 77.48 109.94 4,705.47 4,550.68 -4,004.78 9,332.81 5,923,591.76 470,169.82 0.00 10,146.58 12,300.00 77.48 109.94 4,727.15 4,572.35 -4,038.07 9,424.58 5,923,558.01 470,261.41 0.00 10,243.71 12,400.00 77.48 109.94 4,748.82 4,594.03 -4,071.35 9,516.36 5,923,524.25 470,353.00 0.00 10,340.85 12,500.00 77.48 109.94 4,770.50 4,615.70 -4,104.64 9,608.13 5,923,490.49 470,444.59 0.00 10,437.98 12,600.00 77.48 109.94 4,792.17 4,637.38 -4,137.92 9,699.90 5,923,456.74 470,536.18 0.00 10,535.12 12,700.00 77.48 109.94 4,813.85 4,659.05 -4,171.21 9,791.67 5,923,422.98 470,627.77 0.00 10,632.26 12,800.00 77.48 109.94 4,835.52 4,680.73 -4,204.49 9,883.45 5,923,389.22 470,719.36 0.00 10,729.39 12,900.00 77.48 109.94 4,857.20 4,702.40 -4,237.78 9,975.22 5,923,355.47 470,810.95 0.00 10,826.53 13,000.00 77.48 109.94 4,878.87 4,724.08 -4,271.06 10,066.99 5,923,321.71 470,902.54 0.00 10,923.66 13,100.00 77.48 109.94 4,900.55 4,745.75 -4,304.35 10,158.77 5,923,287.95 470,994.13 0.00 11,020.80 13,120.97 77.48 109.94 4,905.09 4,750.29 -4,311.32 10,178.01 5,923,280.87 471,013.34 0.00 11,041.16 13,200.00 74.89 112.45 4,923.97 4,769.17 -4,339.05 10,249.56 5,923,252.78 471,084.73 4.50 11,117.66 13,300.00 71.66 115.71 4,952.75 4,797.95 -4,378.09 10,336.98 5,923,213.29 471,171.94 4.50 11,213.37 13,400.00 68.48 119.10 4,986.84 4,832.04 -4,421.33 10,420.42 5,923,169.63 471,255.16 4.50 11,307.31 13,500.00 65.37 122.64 5,026.04 4,871.24 -4,468.49 10,499.38 5,923,122.06 471,333.86 4.50 11,398.90 13,600.00 62.35 126.36 5,070.10 4,915.30 -4,519.29 10,573.36 5,923,070.88 471,407.57 4.50 11,487.58 13,700.00 59.44 130.28 5,118.75 4,963.95 -4,573.41 10,641.91 5,923,016.41 471,475.83 4.50 11,572.81 13,800.00 56.65 134.45 5,171.69 5,016.89 -4,630.52 10,704.60 5,922,958.98 471,538.22 4.50 11,654.05 13,900.00 54.01 138.88 5,228.59 5,073.79 -4,690.28 10,761.06 5,922,898.94 471,594.35 4.50 11,730.81 14,000.00 51.54 143.60 5,289.10 5,134.30 -4,752.30 10,810.92 5,922,836.67 471,643.89 4.50 11,802.61 14,100.00 49.27 148.65 5,352.85 5,198.05 -4,816.21 10,853.89 5,922,772.55 471,686.52 4.50 11,869.02 14,200.00 47.24 154.04 5,419.45 5,264.65 -4,881.61 10,889.69 5,922,706.97 471,721.98 4.50 11,929.62 14,283.29 45.76 158.78 5,476.80 5,322.00 -4,936.93 10,913.89 5,922,651.52 471,745.89 4.50 11,975.38 S-8 14,289.02 45.66 159.11 5,480.80 5,326.00 -4,940.75 10,915.36 5,922,647.69 471,747.34 4.50 11,978.37 S8 Target @ 14289'MD,5481'TVD:130'FSL,444'FEL-Sec24,T1ON,R07E-2L-Delilah T1(wp03) 14,300.00 45.66 159.11 5,488.48 5,333.68 -4,948.09 10,918.16 5,922,640.34 471,750.11 0.00 11,984.07 14,400.00 45.66 159.11 5,558.36 5,403.56 -5,014.92 10,943.66 5,922,573.39 471,775.26 0.00 12,035.99 14,500.00 45.66 159.11 5,628.25 5,473.45 -5,081.74 10,969.16 5,922,506.44 471,800.41 0.00 12,087.92 11/2/2010 10:08:54AM Page�7� COMPASS 2003.16 Build 69 Halliburton -Sperry 11ALL I B U RTO N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-320(Delilah) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-320(Delilah) Survey Calculation Method: Minimum Curvature Wellbore: 2L-320 Design: 2L-320(wp05) 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) 5,532.00 14,583.77 45.66 159.11 5,686.80 5,532.00 -5,137.72 10,990.52 5,922,450.36 471,821.47 0.00 12,131.41 C-35 14,595.22 45.66 159.11 5,694.80 5,540.00 -5,145.37 10,993.44 5,922,442.70 471,824.35 0.00 12,137.35 2L-Delilah T2(wp03) 14,600.00 45.66 159.11 5,698.14 5,543.34 -5,148.56 10,994.66 5,922,439.49 471,825.56 0.00 12,139.84 14,700.00 45.66 159.11 5,768.03 5,613.23 -5,215.39 11,020.16 5,922,372.55 471,850.71 0.00 12,191.76 14,800.00 45.66 159.11 5,837.92 5,683.12 -5,282.21 11,045.66 5,922,305.60 471,875.86 0.00 12,243.68 14,845.21 45.66 159.11 5,869.52 5,714.72 -5,312.42 11,057.19 5,922,275.33 471,887.23 0.00 12,267.16 TD @ 10845'MD,5870'TVD:242'FNL,303'FEL-Sec25,T10N,R07E 14,845.22 45.66 159.11 5,869.52 5,714.72 - -5,312.43 .11,057.19 5,922,275.32 471,887.23 0.00 12,267.16 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) 2L-Delilah T2(wp03) 0.00 0.00 5,694.80 -5,145.37 10,993.43 5,922,442.69 471,824.34 -plan hits target center -Point 2L-Delilah T1 (wp03) 0.00 0.00 5,480.80 -4,940.75 10,915.36 5,922,647.69 471,747.34 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (') 14,845.22 5,869.52 7" 7 8-1/2 3,150.00 2,468.92 10 3/4" 10-3/4 12-1/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 1,394.74 1,379.80 Permafrost 0.00 14,583.77 5,686.80 C-35 0.00 3,443.64 2,541.80 Campanian Sands 0.00 8,977.00 3,914.80 C-50 0.00 11,355.09 4,504.80 C-37 0.00 14,283.29 5,476.80 S-8 0.00 3,193.82 2,479.80 C-80 0.00 10,629.57 4,324.80 C-40 0.00 11/2/2010 10:08:54AM Page 8 ) 1,4, IA COMPASS 2003.16 Build 69 Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-320(Delilah) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Staked:2L-320 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-320(Delilah) Survey Calculation Method: Minimum Curvature Wellbore: 2L-320 Design: 2L-320(wp05) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 40.00 40.00 0.00 0.00 Surface Location:202'FNL,792'FEL-Sec22,T1ON-R07E 3,150.00 2,468.92 -715.33 1,205.40 10 3/4"Casing @ 3150'MD,2469'TVD:917'FNL,412'FWL-Sec23,T10N,R07E 11,355.09 4,504.80 -3,710.32 8,566.90 Top Pool @ 11355'MD,4505'TVD:1363'FSL,2490'FWL-Sec24,T1 ON,R07E 14,289.02 5,480.80 -4,940.76 10,915.36 S8 Target @ 14289'MD,5481'TVD:130'FSL,444'FEL-Sec24,T1ON,R07E 14,845.21 5,869.52 -5,312.42 11,057.19 TD @ 10845'MD,5870'TVD:242'FNL,303'FEL-Sec25,T1ON,R07E 11/2/2010 10:08:54AMPage 9 COMPASS 2003.16 Build 69 OR ! 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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-320 Hazards.doc ORIGINAL Prepared by Mike Greener Page 1 of 1 ConocoPhills s _, 'Drilling 2L-320 Producer -- &wells 3-1/2" Completion String ConocoPhillips I I 1 3 '/z" Camco'DS'Nipple w/2.875"No-Go Profile,EUE 8RD 16" 164.82# mod,at—500'MD SCH1001mat ;iG @+/- 110'MD 1 3 'A"9.3#L-80 EUE 8RD mod tubing ili Arcticset Lite @ 10.7 ppg to surface Ei I i '---- Top of 12 ppg Tail Slurry @ 2,000'MD iiggi GLM# Type Setting Depth(TVD-RKB) Valve Type 1 KB 1 ' Dummy 10-3/4"45.5#L-80 BTC @ 2 KB Not Done Yet Dummy +/-3,100'MD/2,470'TVD 3 KB Completion Eng. Needs SOV to review TOC 15.8 ppg @+/- 12 MD 3-'h" KBMG-LTS Chemical Injection Madrel(Placed below bottom GLM)with 3/8"encapsulated control line to surface 7-5/8"29.7# L-80 BTCM to 14,100'MD 3-'/i" Baker'CMU'Sliding Sleeve(closed)with Camco 2.813" 5,347'TVD 'DS'profile,EUE 8RD mod,located 1 joint above PBR 7-5/8"29.7# _ 1, P-110 BTCM 14,100'MD to TD ;. ��i 3-'/z"x " , placed<2007-5/8'MD Baker aboveFHL the perforatedPackerwith intePBRrvalEUE 8RD mod, — 14,250'MD/5,449'TVD 3-1/2"Camco'D'Nipple w/2.75"No-Go Profile and RHC plug, EUE8RD mod,located 1 full joint below packer ‘1). v ;I:::::• 3 h,Wireline Entry Guide,EUE 8RD mod,located 50' MD above top of Bermuda — 14,350'MD/5,518'TVD Planned Perforations— 14,440'to 14,460'MD 14,856'MD/5,872'TVD =___i-: ; == ' 0 2L-320 (Delilah) Schlumberger CemCADE Preliminary Job Design 10-3/4" Surface Casino V2 - OBM Preliminary Job Design based on limited 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-2,000' 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@slb.com 0.6381 ft3/ft x (80')x 1.00 (no excess) = 51 ft3 0.3637 ft3/ft x(1520-80')x 4.00 (300% excess)= 2095 ft3 t < TOC at Surface 0.3637 ft3/ft x (2000- 1520)x 1.50 (50% excess) = 262 ft3 I 51 ft3 + 2095 ft3+262 ft3 = 2408 ft3 r: 2408 ft3/4.51 ft3/sk= 534 sks Round up to 540 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 (3000-2000)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 2.1°F/100 ft. from surface) 1,520 MD(1,499'TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW 100 5.0 50.0 10.0 10.0 MUDPUSH II 5.0 50.0 10.0 20.0 < Top of Tail at Drop bottom plug 0.0 0.0 5.0 25.0 2,000'MD ASL 6.0 428.9 71.5 96.5 DeepCRETE 6.0 104.9 17.5 114.0 Drop top plug 0.0 0.0 5.0 119.0 CW8 5.0 10.0 2.0 121.0 Switch to rig 0.0 0.0 3.0 124.0 MOBM 8.0 264.8 33.1 157.1 Slow&bump plug 3.0 6.0 2.0 159.1 < 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 3,000 MD (2,446'TVD) Spacer Properties: 10.5 ppg MudPUSH* II, Pv 20-25, Ty 30-35 Centralizers: As per CPAi program. * Mark of Schlumberger ORIGIN L E 2L-320 (Delilah) Schlumberger CemCADE Preliminary Job Design 7-5/8" Longstring (WP-03) V4 - OBM Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Location: Alpine Client: CPAI Revision Date: 10/12/2010 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 g Phone: (907)263-4207 -12,356' MD. Mobile:(907)748-6900 email: martinl3©slb.com Tail Slurry Minimum pump time: -240 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(14720- 12220')x 1.50 (50% excess)= 806 ft3 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 3,000'MD BHST = 146°F, Estimated BHCT = 113°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Cumulative Stage Time Stage Volume Time (bpm) (bbl) (min) (min) CW101 5.0 40.0 8.0 8.0 MUDPUSH II 5.0 40.0 8.0 16.0 Drop bottom plug 0.0 0.0 5.0 21.0 GasBLOK Slurry 6.0 147.1 24.5 45.5 Drop top plug 0.0 0.0 5.0 50.5 Seawater 5.0 10.0 2.0 52.5 Switch to rig 0.0 0.0 3.0 55.5 Seawater 8.0 662.4 82.8 138.3 < Top of Cement at Slow&bump plug 3.0 6.0 2.0 140.3 12,356'MD MUD REMOVAL Expected Properties: ppg, Pv<25, Ty<20. < 7-5/8",29.7#casing in 9-7/8"OH Spacer Properties: 11.5 ppg MudPUSH" II, Pv=20-25, Tv= 35-40 Centralizers: As per COP program TD at 14,856'MD (5,776'TVD) Mark of Schlumberger ORIGINAL OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME b27"( PTD# 2-IC) /�6-, Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: � ''( k/11- 47-POOL: j r"c <i 'r �C� 1".1 (4'/ I Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter (2r)/ CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well _ SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Cr) afD ') 'O D T8 1-11 C m ' o r ' o m 0 0 � o u' � ' o a xI- c° I- 3 0 ua o 3. m 7 0 Nir, Ni a Ni N (D C) O_ O O O O W W W W W W W CO W W N.) N.) Ni N.) Ni N.) N.) N.) N.) N (O 00 1 Cr) 01 A Co N o n CO Co -1 O) 01 A Co N - O CO Co -I 0) 01 A co N -, O (O Co O) C)) A Co N - O V m Co nCI) cn0 -0 K � g0W W0 � D � > oonocon vD * n -n -0OO = co * * * crvz , n 0o 0 CD N. w o C 0 0 0 0 -Op o: CD n) m cn) _1 _1 _1 0, 0 o m a) CD o 0 m Cl o o o L n o 70 n r FIT m 3. -o , 0) cn 'c m m m C0 o .0 .0 7 v n -o m 0 3 3 3 3 < o C ° 3 ° c c (0 g < < 0 c o - o 0 0 0 0 0 o O n co N 0 �. _ -o cn = a m a v = - 0 0 0 c y v 3 m m ° ° m o m w c m 7 Z "� 7 0 () 3 0. C (D N �. a) a 0 0 n O O 7 < co 0 c 7 7 CO o 00 3 n 0 a ' _ v 0 n a y m 0 -. CD 7 7 m 0 a v (D (D (D 0 3 0 0 On 3 07 m' < m o o _7 a Q Q Q D a n a 0 v m CD n a o a 3 m o CD m N o a 0 c0 3 0 7 o CD o v < 3 ° a 7 p� N °) m m V) ° n n N �, C) 7' O (p O N (� p, N N 0) •p co ? 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Z N x N O O co "0 0 N N n N (D N y co c--,...c. o N 3 0 (0 CD - s 5,› r 3 co 3 co m . 7 A 0 o 7 7 p o (OD w a g o m cD 01o �cy� `� o It 7N Mb;� -N -n O O 0 7 U) CD o 7 ZO O O co 3 m 3 o 5. 7 ° _ nl 7 N N Iv CD N ZZz -< Z z -< -< -< -< -< -< -< -< z -< -< -< z -< z -< ZZz -< -< -< -< -< -< -< -< -< -< -< Zz D D D C 0 D o CD CD C C C C C D o 0 0 0 o D CD D D D o 0 0 C C 0 CD 0 C CD 0 o D D (n N N N (n N CI) (n (n (n (n 0 q) cn y (d N N N N N N N N N N N. 0 -D (D• x N > 0 O. CD 0 OZ in m C C Z < N C w Co (<p x0 3 0 D 7/ N 0 CD o N o '' p 0• 3 a o .o D 0 r 7 II m _ C 7 ° C C o O Z Ni 3 �G -p' (D N N v r v v o ° 0 0 o o 3 3 0- 0 co ° 0- N a o w X C D -. n Co 7 CD .- 0- n < 3 C CD 'cn -0 c (n �. -O -. A m 0 Co 3 0 CD 0 m = 0 0 - c X m co co a co o ("I T H D o D a m v - 3 0 0 4 xi 0 xi c0i C N y I I 'O a 5- A z O C CD n o 7 CO A CD N C V V O W 01 (n O 0 a 01 p r 00 - O O6 0 NiNi 3 _ 0 0 0 co.OA N C 0, Co cr�I O ° N' N N 01 O -I -I o w c N. .) 0 D m 3 Co0 o -o v0) co 0 Cn v Z A = 0 -o (O 'O Ni -O Ni 3 N O 0 Cl r N m co C • N *. o C< N 7 O N . d _ - Q !n Q CD c (D a (D = n n 7 ° 7 co O (D (D = A 0 n 7 C C. 0 D 0 - D 0 m ? n co r00 Co (n (. O Co c0 O 0 3 co O (.071 7 a -o N 0 0 (0 3 0 = < 3 C -1 o C n 0 (D n > 0 o 7 .-- c) OJ CO 0 0 (71 (A) D O 0 C = C1 OCT O 0 N' (I, o (0 u) w ��ell --aistory File APPEND' IX Infoinmation of detailed nature that is not particularly geiiiiane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simpirfy 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 $ Tue Mar 01 10:04:33 2011 Reel Header Service name LISTPE Date 11/03/01 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 11/03/01 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-320 API NUMBER: 501032062700 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 01-MAR-11 JOB DATA MWD RUN 1 MWD RUN 6 MWD RUN 7 JOB NUMBER: AKMW0007742776 AKMW0007742776 AKMW0007742776 LOGGING ENGINEER: BENJAMIN SCH BENJAMIN SCH BRIAN STEPHE OPERATOR WITNESS: RAY SPRINGER LARRY HILL LARRY HILL MWD RUN 8 JOB NUMBER: AKMW0007742776 LOGGING ENGINEER: JOE GRANADOS OPERATOR WITNESS: LARRY HILL SURFACE LOCATION SECTION: 22 TOWNSHIP: 1ON RANGE: 7E FNL: 202 FSL: FEL: 792 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 155.85 GROUND LEVEL: 114 . 90 WELL CASING RECORD OPEN HOLE CASING DRILLERS cIYo ( 06-3-&e5 BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 16.000 110.0 2ND STRING 9.875 10.750 2745.0 3RD STRING PRODUCTION STRING 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. THIS SIDETRACK KICKED OFF OF A CEMENT PLUG AT THE 10.75" CASING SHOE (2745'MD/2374 'TVD) IN 2L-320 PB1. 4. MWD RUNS 1, 6-8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTIL- IZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESIS- TIVITY PHASE-4 (EWR4) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . MWD RUNS 6-8 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL NEUTRON (CTN) , AND PRESSURE-WHILE-DRILLING (PWD) . MWD ALD DATA WERE REPLACED WITH ROTATED MAD ALD DATA OVER THE FOLLOWING SLIDE INTERVALS (SENSOR DEPTHS,MD) : 14, 102.5'-14, 177' ; 14, 197.5'- 14,238.5' ; 14,293.5'-14, 324 ' ; 14, 387'-14, 405' . NO SEPARATE MAD PRESENTATION IS INCLUDED. THE RO9P MALFUNCTIONED INTERMITTENTLY DURING MWD RUN 7, THEREFORE THE RO9P CURVE IS NOT PRESENTED OVER THE MWD RUN 7 INTERVAL (9014.5'MD/4073'TVD - 11621'MD/4758'TVD, SENSOR DEPTHS) . 5. LWD DATA ARE CONSIDERED PRIMARY DEPTH CONTROL PER E-MAIL FROM LISA WRIGHT (CPAI) TO BRYAN BURINDA (SD) DATED 12 JANUARY 2011. HOWEVER, MAD DATA WERE CORRECTED (SHIFTED) TO MWD DATA. 6. MWD RUNS 1, 6-8 REPRESENT WELL 2L-320 WITH API#: 50-103-20627-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15, 049'MD/5779'TVD. ROPA = AVERAGE RATE OF PENETRATION WHILE DRILLING DGRC = DGR COMBINED GAMMA RAY RO9P = 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 PARAMETERS USED IN POROSITY LOG PROCESSING: 411 HOLE SIZE: FIXED HOLE SIZE - 9.875" BIT MUD WEIGHT: 9.5 - 9.65 PPG MUD SALINITY: 700 - 1200 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 11/03/01 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 235.0 14990.0 FET 245.0 15000.0 RPS 245.0 15000.0 RPM 245.0 15000.0 RPD 245.0 15000.0 RPX 245.0 15000.0 ROP 303.5 15049.0 DRHO 2735.0 14968.5 CALN 2735.0 14968.5 NPHI 2735.0 14955.0 PEF 2735.0 14968.5 NCNT 2735.0 14955.0 FCNT 2735.0 14955.0 RHOB 2735.0 14968.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 235.0 2745.0 MWD 6 2745.0 9061.0 MWD 7 9061.0 11667.0 MWD 8 11667.0 15049.0 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 15049 7642 29629 235 15049 RHOB MWD G/CC 1.529 2.713 2.32324 24468 2735 14968.5 DRHO MWD G/CC -2.895 0.394 0.0489106 24468 2735 14968.5 CALN MWD IN 8.25 14.46 9.99278 22272 2735 14968.5 PEF MWD B/E 1.84 16.3 2.74344 24468 2735 14968.5 GR MWD API 16.16 222.29 116.371 29511 235 14990 FET MWD HR 0.19 777.24 1.51635 29434 245 15000 RPX MWD OHMM 1.09 2000 22.4579 24220 245 15000 RPS MWD OHMM 1.21 2000 30.7937 29434 245 15000 RPM MWD OHMM 1.36 2000 32.8445 29434 245 15000 RPD MWD OHMM 1.56 2000 19.4306 29434 245 15000 ROP MWD FPH 0.14 650.53 134.806 29492 303.5 15049 FCNT MWD CP30 360.46 1818.49 618.312 24441 2735 14955 NCNT MWD CP30 81224.9 147333 100162 24441 2735 14955 NPHI MWD PU 9.34 77.35 30.8797 24441 2735 14955 First Reading For Entire File 235 Last Reading For Entire File 15049 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/01 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 411 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/01 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 235.0 2687.0 EWXT 245.0 2696.0 R27P 245.0 2696.0 R15P 245.0 2696.0 R09P 245.0 2696.0 R39P 245.0 2696.0 ROPA 303.5 2745.0 LOG HEADER DATA DATE LOGGED: 03-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 2745.0 TOP LOG INTERVAL (FT) : 303.0 BOTTOM LOG INTERVAL (FT) : 2745.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 66.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 252384 EWR4 ELECTROMAG. RESIS. 4 77613 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) : 9.20 MUD VISCOSITY (S) : 198.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 100 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.800 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.200 88.5 MUD FILTRATE AT MT: 2.500 68.0 MUD CAKE AT MT: 3.000 68.0 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 MWDO10 API 4 1 68 4 2 FET MWD010 HR 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 235 2745 1490 5021 235 2745 GR MWDO10 API 16.16 133.03 73.4557 4905 235 2687 FET MWDO10 HR 0.19 25.34 1.78646 4903 245 2696 RPX MWDO10 OHMM 1. 69 2000 94.8507 4903 245 2696 RPS MWDO10 OHMM 1.51 2000 162.239 4903 245 2696 RPM MWDO10 OHMM 1.59 2000 170.767 4903 245 2696 RPD MWDO10 OHMM 1.76 2000 85.3882 4903 245 2696 ROP MWD010 FPH 15.21 398.44 164.752 4884 303.5 2745 First Reading For Entire File 235 Last Reading For Entire File 2745 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/01 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 11/03/01 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 ac Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 2687.5 9004.0 R27P 2735.0 9014.0 R15P 2735.0 9014.0 ACDL 2735.0 8980.5 R09P 2735.0 9014.0 TNFA 2735.0 8967.0 EWXT 2735.0 9014.0 R39P 2735.0 9014.0 TNPS 2735.0 8967.0 TNNA 2735.0 8967.0 AHSI 2735.0 8980.5 APEL 2735.0 8980.5 ADCL 2735.0 8980.5 ROPA 2745.5 9061.0 LOG HEADER DATA DATE LOGGED: 08-FEB-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 9261.0 TOP LOG INTERVAL (FT) : 2745.0 BOTTOM LOG INTERVAL (FT) : 9261.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 67.5 MAXIMUM ANGLE: 76.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 269077 EWR4 ELECTROMAG. RESIS. 4 127479 CTN COMP THERMAL NEUTRON 231173 ALD Azimuthal Litho-Dens 188935 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.880 DRILLER'S CASING DEPTH (FT) : 2745.0 I # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.50 MUD VISCOSITY (S) : 46.0 MUD PH: 9.4 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3) : 5.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1. 600 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .790 144 .9 MUD FILTRATE AT MT: 1.400 68.0 MUD CAKE AT MT: 1.250 68.0 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 MWD060 G/CC 4 1 68 4 2 DRHO MWD060 G/CC 4 1 68 8 3 CALN MWD060 IN 4 1 68 12 4 PEF MWD060 B/E 4 1 68 16 5 GR MWD060 API 4 1 68 20 6 FET MWD060 HR 4 1 68 24 7 RPX MWD060 OHMM 4 1 68 28 8 RPS MWD060 OHMM 4 1 68 32 9 RPM MWD060 OHMM 4 1 68 36 10 RPD MWD060 OHMM 4 1 68 40 11 ROP MWD060 FPH 4 1 68 44 12 FCNT MWD060 CP30 4 1 68 48 13 NCNT MWD060 CP30 4 1 68 52 14 NPHI MWD060 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2687.5 9061 5874.25 12748 2687.5 9061 RHOB MWD060 G/CC 1.561 2.694 2.25234 12492 2735 8980.5 DRHO MWD060 G/CC -2.895 0.312 0.0469074 12492 2735 8980.5 CALN MWD060 IN 8.25 14. 1 9.86614 11932 2735 8980.5 PEF MWD060 B/E 1.87 16.3 2.6069 12492 2735 8980.5 GR MWD060 API 36. 92 195.74 115.15 12634 2687.5 9004 FET MWD060 HR 0.22 777.24 1.05926 12559 2735 9014 RPX MWD060 OHMM 1.51 28.39 4 .02873 12559 2735 9014 RPS MWD060 OHMM 2.09 1847.12 4 .5681 12559 2735 9014 RPM MWD060 OHMM 2.23 2000 5.53753 12559 2735 9014 RPD MWD060 OHMM 2.3 2000 7.26046 12559 2735 9014 ROP MWD060 FPH 6.06 650.53 163.758 12632 2745.5 9061 FCNT MWD060 CP30 360.46 1772.58 562. 672 12465 2735 8967 NCNT MWD060 CP30 81224. 9 128967 96742 12465 2735 8967 NPHI MWD060 PU 9.34 77.35 32.9287 12465 2735 8967 First Reading For Entire File 2687.5 Last Reading For Entire File 9061 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/01 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/01 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TNPS 8967.5 11572.0 TNFA 8967.5 11572.0 TNNA 8967.5 11572.0 AHSI 8981.0 11585.5 APEL 8981.0 11585.5 ADCL 8981.0 11585.5 ACDL 8981.0 11585.5 DGRC 9004.5 11611.0 R39P 9014.5 11621.0 EWXT 9014.5 11621.0 R15P 9014.5 11621.0 R27P 9014 .5 11621.0 ROPA 9061.5 11667.0 LOG HEADER DATA DATE LOGGED: 13-FEB-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 11667.0 TOP LOG INTERVAL (FT) : 9261.0 BOTTOM LOG INTERVAL (FT) : 11667.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 73.7 MAXIMUM ANGLE: 75.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718520 EWR4 ELECTROMAG. RESIS. 4 11241795 CTN COMP THERMAL NEUTRON 231173 ALD Azimuthal Litho-Dens 188935 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.880 DRILLER'S CASING DEPTH (FT) : 2745.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9. 60 MUD VISCOSITY (S) : 55.0 MUD PH: 9.7 MUD CHLORIDES (PPM) : 700 FLUID LOSS (C3) : 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.800 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .850 144 . 9 MUD FILTRATE AT MT: 1.400 65.0 MUD CAKE AT MT: 1.900 65.0 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 MWD070 G/CC 4 1 68 4 2 DRHO MWD070 G/CC 4 1 68 8 3 CALN MWD070 IN 4 1 68 12 4 PEF MWD070 B/E 4 1 68 16 5 GR MWD070 API 4 1 68 20 6 FET MWD070 HR 4 1 68 24 7 RPS MWD070 OHMM 4 1 68 28 8 RPM MWD070 OHMM 4 1 68 32 9 RPD MWD070 OHMM 4 1 68 36 10 ROP MWD070 FPH 4 1 68 40 11 FCNT MWD070 CP30 4 1 68 44 12 NCNT MWD070 CP30 4 1 68 48 13 NPHI MWD070 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8967.5 11667 10317.3 5400 8967.5 11667 RHOB MWD070 G/CC 1.529 2.708 2.37409 5210 8981 11585.5 DRHO MWD070 G/CC -0.032 0.394 0.0535407 5210 8981 11585.5 CALN MWD070 IN 8. 96 12.02 10.1504 4944 8981 11585.5 PEF MWD070 B/E 1.86 7.26 2.84105 5210 8981 11585.5 GR MWD070 API 82.49 222.29 141.354 5214 9004.5 11611 FET MWD070 HR 0.42 51.57 1. 95789 5214 9014.5 11621 RPS MWD070 OHMM 2.25 12.71 4 .32292 5214 9014.5 11621 RPM MWD070 OHMM 2.49 23.57 4. 94086 5214 9014.5 11621 RPD MWD070 OHMM 2. 61 21.76 5.12454 5214 9014.5 11621 ROP MWD070 FPH 0.14 447.61 94. 6936 5212 9061.5 11667 FCNT MWD070 CP30 410.19 1448.07 591.576 5210 8967.5 11572 NCNT MWD070 CP30 83983.5 126043 98611.8 5210 8967.5 11572 NPHI MWD070 PU 12.42 64.29 31.8211 5210 8967.5 11572 First Reading For Entire File 8967.5 Last Reading For Entire File 11667 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/01 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/01 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TNPS 11572.5 14955.0 TNFA 11572.5 14955.0 TNNA 11572.5 14955.0 APEL 11586.0 14968.5 AHSI 11586.0 14968.5 ADCL 11586.0 14968.5 ACDL 11586.0 14968.5 DGRC 11611.5 14990.0 R27P 11621.5 15000.0 R39P 11621.5 15000.0 R15P 11621.5 15000.0 EWXT 11621.5 15000.0 RO9P 11621.5 15000.0 ROPA 11667.5 15049.0 LOG HEADER DATA DATE LOGGED: 18-FEB-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 15049.0 TOP LOG INTERVAL (FT) : 11667.0 BOTTOM LOG INTERVAL (FT) : 15049.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 67.9 MAXIMUM ANGLE: 75.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 269077 EWR4 ELECTROMAG. RESIS. 4 127479 CTN COMP THERMAL NEUTRON 11256612 ALD Azimuthal Litho-Dens 144855 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.880 DRILLER'S CASING DEPTH (FT) : 2745.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.60 MUD VISCOSITY (S) : 42.0 MUD PH: 9.5 MUD CHLORIDES (PPM) : 700 FLUID LOSS (C3) : 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.400 70.0 MUD AT MAX CIRCULATING TERMPERATURE: . 660 155.5 MUD FILTRATE AT MT: 1.100 68.0 MUD CAKE AT MT: .820 69.0 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 MWD080 G/CC 4 1 68 4 2 DRHO MWD080 G/CC 4 1 68 8 3 CALN MWD080 IN 4 1 68 12 4 PEF MWD080 B/E 4 1 68 16 5 GR MWD080 API 4 1 68 20 6 FET MWD080 HR 4 1 68 24 7 RPX MWD080 OHMM 4 1 68 28 8 RPS MWD080 OHMM 4 1 68 32 9 RPM MWD080 OHMM 4 1 68 36 10 RPD MWD080 OHMM 4 1 68 40 11 ROP MWD080 FPH 4 1 68 44 12 FCNT MWD080 CP30 4 1 68 48 13 NCNT MWD080 CP30 4 1 68 52 14 NPHI MWD080 PU 4 1 68 56 15 • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11572.5 15049 13310.8 6954 11572.5 15049 RHOB MWD080 G/CC 1.723 2.713 2.41497 6766 11586 14968.5 DRHO MWD080 G/CC -0.024 0.329 0.0490439 6766 11586 14968.5 CALN MWD080 IN 8.19 14.46 10.0982 5132 11586 14968.5 PEF MWD080 B/E 1.84 5.38 2. 92038 6766 11586 14968.5 GR MWD080 API 75.55 206.82 130.525 6758 11611.5 14990 FET MWD080 HR 0.42 44.93 1.82919 6758 11621.5 15000 RPX MWD080 OHMM 1.09 11.92 4.18474 6758 11621.5 15000 RPS MWD080 OHMM 1.21 12.56 4.58927 6758 11621.5 15000 RPM MWD080 OHMM 1.36 16.81 5.05597 6758 11621.5 15000 RPD MWD080 OHMM 1.56 15.42 5.23197 6758 11621.5 15000 ROP MWD080 FPH 7.18 601.87 90.0247 6764 11667.5 15049 FCNT MWD080 CP30 454 .11 1818.49 741.405 6766 11572.5 14955 NCNT MWD080 CP30 88223.8 147333 107657 6766 11572.5 14955 NPHI MWD080 PU 10.65 43.04 26.3801 6766 11572.5 14955 First Reading For Entire File 11572.5 Last Reading For Entire File 15049 11 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/01 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 Physical EOF Tape Trailer Service name LISTPE Date 11/03/01 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 11/03/01 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Feb 28 15:21:22 2011 Reel Header Service name LISTPE Date 11/02/28 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/02/28 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-320 PB1 API NUMBER: 501032062770 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 28-FEB-11 JOB DATA MWD RUN 1 MWD RUN 2 JOB NUMBER: AKMW0007742776 AKMW0007742776 LOGGING ENGINEER: BENJAMIN SCH BENJAMIN SCH OPERATOR WITNESS: RAY SPRINGER LARRY HILL SURFACE LOCATION SECTION: 22 TOWNSHIP: lON RANGE: 7E FNL: 202 FSL: FEL: 792 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 155.85 GROUND LEVEL: 114.90 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 2745.0 3RD STRING PRODUCTION STRING 210 —1(o& `moo 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) . THE BHA BECAME STUCK, AND WAS ABANDONED, DURING MWD RUN 3. NO PROGRESS WAS MADE, NO NEW DATA WERE ACQUIRED. 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-320 PB1 WITH API#: 50-103-20627-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11, 446'MD/4520'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 MATRIX 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 PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: FIXED HOLE SIZE - 9.875" BIT MUD WEIGHT: 8. 9 - 9. 6 PPG MUD SALINITY: 37, 000 - 54, 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 11/02/28 i 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 235.0 11387.5 RPS 245.0 11397.5 FET 245.0 11397.5 RPD 245.0 11397.5 RPX 245.0 11397.5 RPM 245.0 11397.5 ROP 303.5 11446.0 NPHI 2735.0 11352.5 DRHO 2735.0 11366.5 NCNT 2735.0 11352.5 CALN 2735.0 11366.5 FCNT 2735.0 11352.5 PEF 2735.0 11366.5 RHOB 2735.0 11366.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 235.0 2755.0 MWD 2 2755.0 11446.0 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 FONT 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 11446 5840.5 22423 235 11446 RHOB MWD G/CC 0.31 2.818 2.26372 17264 2735 11366.5 DRHO MWD G/CC -2.874 0.32 0.0696976 17264 2735 11366.5 CALN MWD IN 8.25 15.69 9.85303 16706 2735 11366.5 PEF MWD B/E 1.61 14.3 3.72292 17264 2735 11366.5 GR MWD API 16.16 223.16 112.866 22306 235 11387.5 FET MWD HR 0.18 114. 64 1.10854 22229 245 11397.5 RPX MWD OHMM 1.51 2000 24.8829 22229 245 11397.5 RPS MWD OHMM 1.51 2000 40.2158 22229 245 11397.5 RPM MWD OHMM 1.37 2000 42.8701 22229 245 11397.5 RPD MWD OHMM 1.64 2000 24.6918 22229 245 11397.5 ROP MWD FPH 15.21 398.44 191.492 22286 303.5 11446 FONT MWD CP30 320.35 1128.55 515.65 17236 2735 11352.5 NCNT MWD CP30 72862.1 108657 87992.3 17236 2735 11352.5 NPHI MWD PU 14.27 68.96 33.2963 17236 2735 11352.5 First Reading For Entire File 235 Last Reading For Entire File 11446 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 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 235.0 2687.0 R15P 245.0 2696.0 R39P 245.0 2696.0 R27P 245.0 2696.0 RO9P 245.0 2696.0 EWXT 245.0 2696.0 • ROPA 303.5 2755.0 LOG HEADER DATA DATE LOGGED: 03-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 2755.0 TOP LOG INTERVAL (FT) : 303.0 BOTTOM LOG INTERVAL (FT) : 2755.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 66.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 252384 EWR4 ELECTROMAG. RESIS. 4 77613 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) : 9.20 MUD VISCOSITY (S) : 198.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 100 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.800 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.200 88.5 MUD FILTRATE AT MT: 2.500 68.0 MUD CAKE AT MT: 3.000 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 FET MWD010 HR 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 235 2755 1495 5041 235 2755 GR MWD010 API 16. 16 133.03 73.4557 4905 235 2687 FET MWD010 HR 0.19 25.34 1.78646 4903 245 2696 RPX MWD010 OHMM 1. 69 2000 94.8507 4903 245 2696 RPS MWD010 OHMM 1.51 2000 162.239 4903 245 2696 RPM MWD010 OHMM 1.59 2000 170.767 4903 245 2696 RPD MWD010 OHMM 1.76 2000 85.3882 4903 245 2696 ROP MWD010 FPH 15.21 398.44 164.473 4904 303.5 2755 First Reading For Entire File 235 Last Reading For Entire File 2755 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 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 2687.5 11387.5 APEL 2735.0 11366.5 TNPS 2735.0 11352.5 R15P 2735.0 11397.5 EWXT 2735.0 11397.5 R27P 2735.0 11397.5 R39P 2735.0 11397.5 R09P 2735.0 11397.5 AHSI 2735.0 11366.5 TNFA 2735.0 11352.5 ADCL 2735.0 11366.5 TNNA 2735.0 11352.5 ACDL 2735.0 11366.5 ROPA 2755.5 11446.0 LOG HEADER DATA DATE LOGGED: 13-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 11446.0 TOP LOG INTERVAL (FT) : 2755.0 BOTTOM LOG INTERVAL (FT) : 11446.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 66.7 MAXIMUM ANGLE: 77.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 275518 EWR4 ELECTROMAG. RESIS. 4 230203 CTN COMP THERMAL NEUTRON 185457 ALD Azimuthal Litho-Dens 126973 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.875 DRILLER'S CASING DEPTH (FT) : 2745.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) : 9.50 MUD VISCOSITY (S) : 71.0 MUD PH: .0 MUD CHLORIDES (PPM) : 35000 FLUID LOSS (C3) : 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 254 .4 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 FONT 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 2687.5 11446 7066.75 17518 2687.5 11446 RHOB MWD020 G/CC 0.31 2.818 2.26372 17264 2735 11366.5 DRHO MWD020 G/CC -2.874 0.32 0.0696976 17264 2735 11366.5 CALN MWD020 IN 8.25 15. 69 9.85303 16706 2735 11366.5 PEF MWD020 B/E 1. 61 14 .3 3.72292 17264 2735 11366.5 GR MWD020 API 43. 99 223.16 123.975 17401 2687.5 11387.5 FET MWD020 HR 0.18 114 . 64 0.916696 17326 2735 11397.5 RPX MWD020 OHMM 1.51 2000 5.08312 17326 2735 11397.5 RPS MWD020 OHMM 1.58 2000 5. 68512 17326 2735 11397.5 RPM MWD020 OHMM 1.37 2000 6.67723 17326 2735 11397.5 RPD MWD020 OHMM 1. 64 2000 7.51562 17326 2735 11397.5 ROP MWD020 FPH 49.28 379.38 199.115 17382 2755.5 11446 FONT MWD020 CP30 320.35 1128.55 515. 65 17236 2735 11352.5 NCNT MWD020 CP30 72862.1 108657 87992.3 17236 2735 11352.5 NPHI MWD020 PU 14 .27 68.96 33.2963 17236 2735 11352.5 First Reading For Entire File 2687.5 Last Reading For Entire File 11446 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 11/02/28 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/02/28 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Feb 28 15:51:03 2011 Reel Header Service name LISTPE Date 11/02/28 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/02/28 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-320 PB2 API NUMBER: 501032062771 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 28-FEB-11 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 4 JOB NUMBER: AKMW0007742776 AKMW0007742776 AKMW0007742776 LOGGING ENGINEER: BENJAMIN SCH BENJAMIN SCH JOE GRANADOS OPERATOR WITNESS: RAY SPRINGER LARRY HILL RAY SPRINGER SURFACE LOCATION SECTION: 22 TOWNSHIP: 1ON RANGE: 7E FNL: 202 FSL: FEL: 792 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 155.85 GROUND LEVEL: 114.90 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 2745.0 3RD STRING PRODUCTION STRING alo I 2 2 �b �� 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. THIS OPEN-HOLE SIDETRACK EXITED 2L-320 PBl AT 7144'MD/3461'TVD, WITHIN THE MWD RUN 2 INTERVAL. 4 . MWD RUNS 1,2, 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTIL- IZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESIS- TIVITY PHASE-4 (EWR4) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . MWD RUNS 2, 4 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL NEUTRON (CTN) , AND PRESSURE-WHILE-DRILLING (PWD) . MWD RUN 4 ALSO INCLUDED GEOPILOT ROTARY STEERABLE BHA (GP) . NO PROGRESS WAS MADE ON MWD RUN 5. 5. LWD DATA ARE CONSIDERED PRIMARY DEPTH CONTROL PER E-MAIL FROM LISA WRIGHT (CPAI) TO BRYAN BURINDA (SD) DATED 12 JANUARY 2011. 6. MWD RUNS 1,2, 4 REPRESENT WELL 2L-320 PB2 WITH API#: 50-103-20627-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11,247'MD/4438'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 MATRIX 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 PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: FIXED HOLE SIZE - 9.875" BIT MUD WEIGHT: 8. 9 - 10.1 PPG MUD SALINITY: 37, 000 - 54, 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 11/02/28 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 235.0 11196.0 RPS 245.0 11210.0 FET 245.0 11210.0 RPX 245.0 11210.0 RPD 245.0 11210.0 RPM 245.0 11210.0 ROP 303.5 11247.0 DRHO 2735.0 11173.5 NPHI 2735.0 11160.5 CALN 2735.0 11173.5 PEF 2735.0 11173.5 NCNT 2735.0 11160.5 RHOB 2735.0 11173.5 FCNT 2735.0 11160.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 235.0 2755.0 MWD 2 2755.0 7144.0 MWD 4 7144.5 11247.0 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 11247 5741 22025 235 11247 RHOB MWD G/CC 0.31 2.751 2.26008 16878 2735 11173.5 DRHO MWD G/CC -2.874 0.303 0.0630229 16878 2735 11173.5 CALN MWD IN 8.25 19.05 9.74359 16469 2735 11173.5 PEF MWD B/E 1.61 14.3 3.79717 16878 2735 11173.5 GR MWD API 16.16 217.03 109. 647 21923 235 11196 FET MWD HR 0.16 379.16 1. 19962 21854 245 11210 RPX MWD OHMM 1.51 2000 25.2266 21854 245 11210 RPS MWD OHMM 1.51 2000 40.8879 21854 245 11210 RPM MWD OHMM 1.59 2000 45.7336 21854 245 11210 RPD MWD OHMM 1.76 2000 26.2908 21854 245 11210 ROP MWD FPH 15.21 441.34 170.177 21888 303.5 11247 FONT MWD CP30 320.35 1746.1 506.501 16852 2735 11160.5 NCNT MWD CP30 71102.7 112626 86357 16852 2735 11160.5 NPHI MWD PU 8.5 69.57 33.42 16852 2735 11160.5 First Reading For Entire File 235 Last Reading For Entire File 11247 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 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 235.0 2687.0 R39P 245.0 2696.0 EWXT 245.0 2696.0 R15P 245.0 2696.0 R09P 245.0 2696.0 R27P 245.0 2696.0 ROPA 303.5 2755.0 $ LOG HEADER DATA DATE LOGGED: 03-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 2755.0 TOP LOG INTERVAL (FT) : 303.0 BOTTOM LOG INTERVAL (FT) : 2755.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 66.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 252384 EWR4 ELECTROMAG. RESIS. 4 77613 $ 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) : 9.20 MUD VISCOSITY (S) : 198.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 100 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.800 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.200 88.5 MUD FILTRATE AT MT: 2.500 68.0 MUD CAKE AT MT: 3.000 68.0 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 MWDO10 API 4 1 68 4 2 FET MWDO10 HR 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWDO10 OHMM 4 1 68 20 6 RPD MWDO10 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 2755 1495 5041 235 2755 GR MWD010 API 16.16 133.03 73.4557 4905 235 2687 FET MWDO10 HR 0.19 25.34 1.78646 4903 245 2696 RPX MWDO10 OHMM 1. 69 2000 94 .8507 4903 245 2696 RPS MWDO10 OHMM 1.51 2000 162.239 4903 245 2696 RPM MWDO10 OHMM 1.59 2000 170.767 4903 245 2696 RPD MWDO10 OHMM 1.76 2000 85.3882 4903 245 2696 ROP MWDO10 FPH 15.21 398.44 164 .473 4904 303.5 2755 First Reading For Entire File 235 Last Reading For Entire File 2755 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 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 2687.5 7144 .0 EWXT 2735.0 7144 .0 R09P 2735.0 7144 .0 R15P 2735.0 7144 .0 R39P 2735.0 7144 .0 R27P 2735.0 7144.0 TNFA 2735.0 7144.0 APEL 2735.0 7144.0 TNNA 2735.0 7144.0 AHSI 2735.0 7144.0 ADCL 2735.0 7144.0 TNPS 2735.0 7144.0 ACDL 2735.0 7144.0 ROPA 2755.5 7144.0 LOG HEADER DATA DATE LOGGED: 13-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 7144 .0 TOP LOG INTERVAL (FT) : 2755.0 BOTTOM LOG INTERVAL (FT) : 7144.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 66.7 MAXIMUM ANGLE: 77.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 275518 EWR4 ELECTROMAG. RESIS. 4 230203 CTN COMP THERMAL NEUTRON 185457 ALD Azimuthal Litho-Dens 126973 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.875 DRILLER'S CASING DEPTH (FT) : 2745.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) : 9.50 MUD VISCOSITY (S) : 71.0 MUD PH: .0 MUD CHLORIDES (PPM) : 35000 FLUID LOSS (C3) : 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 254 .4 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 2687.5 7144 4915.75 8914 2687.5 7144 RHOB MWD020 G/CC 0.31 2.587 2.2012 8819 2735 7144 DRHO MWD020 G/CC -2.874 0.303 0.0670432 8819 2735 7144 CALN MWD020 IN 8.25 15. 69 9.86561 8410 2735 7144 PEF MWD020 B/E 1. 61 14.3 3.57222 8819 2735 7144 GR MWD020 API 43. 99 155.27 111.009 8914 2687.5 7144 FET MWD020 HR 0.2 114 . 64 1.22992 8819 2735 7144 RPX MWD020 OHMM 1.51 2000 6.04596 8819 2735 7144 RPS MWD020 OHMM 2.53 2000 7.04844 8819 2735 7144 RPM MWD020 OHMM 2.59 2000 8. 60701 8819 2735 7144 RPD MWD020 OHMM 2.65 2000 10.1407 8819 2735 7144 ROP MWD020 FPH 57.22 307. 96 207.132 8778 2755.5 7144 FCNT MWD020 CP30 320.35 1030. 99 492.265 8819 2735 7144 NCNT MWD020 CP30 72862.1 106751 86494.8 8819 2735 7144 NPHI MWD020 PU 15.91 68. 96 34.5523 8819 2735 7144 First Reading For Entire File 2687.5 Last Reading For Entire File 7144 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TNPS 7144 .5 11160.5 ROPA 7144.5 11247.0 EWXT 7144.5 11210.0 R39P 7144 .5 11210.0 RO9P 7144 .5 11210.0 TNFA 7144.5 11160.5 APEL 7144.5 11173.5 AHSI 7144.5 11173.5 DGRC 7144.5 11196.0 TNNA 7144.5 11160.5 ADCL 7144.5 11173.5 R15P 7144.5 11210.0 ACDL 7144.5 11173.5 R27P 7144.5 11210.0 $ LOG HEADER DATA DATE LOGGED: 30-JAN-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 11247.0 TOP LOG INTERVAL (FT) : 7144 .0 BOTTOM LOG INTERVAL (FT) : 11247.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 73.2 MAXIMUM ANGLE: 77.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 11321777 EWR4 ELECTROMAG. RESIS. 4 231951 CTN COMP THERMAL NEUTRON 185457 ALD Azimuthal Litho-Dens 125035 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.875 DRILLER'S CASING DEPTH (FT) : 2745.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) : 10.00 MUD VISCOSITY (S) : 86.0 MUD PH: .0 MUD CHLORIDES (PPM) : 43000 FLUID LOSS (C3) : 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 169.7 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 MWD040 G/CC 4 1 68 4 2 DRHO MWD040 G/CC 4 1 68 8 3 CALN MWD040 IN 4 1 68 12 4 PEF MWD040 B/E 4 1 68 16 5 GR MWD040 API 4 1 68 20 6 FET MWD040 HR 4 1 68 24 7 RPX MWD040 OHMM 4 1 68 28 8 RPS MWD040 OHMM 4 1 68 32 9 RPM MWD040 OHMM 4 1 68 36 10 RPD MWD040 OHMM 4 1 68 40 11 ROP MWD040 FPH 4 1 68 44 12 FCNT MWD040 CP30 4 1 68 48 13 NCNT MWD040 CP30 4 1 68 52 14 NPHI MWD040 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7144 .5 11247 9195.75 8206 7144.5 11247 RHOB MWD040 G/CC 1.809 2.751 2.32452 8059 7144.5 11173.5 DRHO MWD040 G/CC -0.031 0.21 0.0586235 8059 7144.5 11173.5 CALN MWD040 IN 8.76 19.05 9. 61626 8059 7144.5 11173.5 PEF MWD040 B/E 2.25 11.19 4.04334 8059 7144.5 11173.5 GR MWD040 API 52. 62 217.03 130.054 8104 7144 .5 11196 FET MWD040 HR 0.16 379.16 0.812927 8132 7144 .5 11210 RPX MWD040 OHMM 1. 93 28.01 4 .04952 8132 7144 .5 11210 RPS MWD040 OHMM 2.02 144.06 4 .42049 8132 7144 .5 11210 RPM MWD040 OHMM 1.73 2000 10. 6107 8132 7144 .5 11210 RPD MWD040 OHMM 1.83 2000 8.17386 8132 7144 .5 11210 ROP MWD040 FPH 21. 93 441.34 134 .054 8206 7144 .5 11247 FCNT MWD040 CP30 323.03 1746. 1 522.13 8033 7144.5 11160.5 NCNT MWD040 CP30 71102.7 112626 86205.7 8033 7144 .5 11160.5 NPHI MWD040 PU 8.5 69.57 32.1769 8033 7144 .5 11160.5 First Reading For Entire File 7144.5 Last Reading For Entire File 11247 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/02/28 Maximum Physical Record65535 File Type LO r Next File Name STSLIB.005 Physical EOF Tape Trailer Service name LISTPE Date 11/02/28 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/02/28 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File NI= . . ConocoPhil l l s Alaska, Inc, • FINAL WELL REPORT MUDLOGGING DATA TARN 2L-320 TARN 2L-320 PB1 TARN 2L-320 PB2 Provided by: CANRIG DRILLING TECHNOLOGY I.I U. Approved by: Lisa M. Wright Compiled by: Steven Pike Jeffrey McBeth Joshua Dubowski Dan Grunwald Dan Sherwood Distribution: March 8, 2011 Date: February 18, 2011 ConocoPhillips Alaska.Inc. 2L-320 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 8 3.1 LITHOSTRATIGRAPHY 8 3.2 MUDLOG SUMMARY 9 3.3 CONNECTION GASES 15 3.4 TRIP(WIPER)GASES 15 3.5 GAS PEAKS 16 3.6 SAMPLING PROGRAM/SAMPLE DISPATCH 17 4 PRESSURE/FORMATION STRENGTH DATA 18 4.1 PORE PRESSURE GRADIENT EVALUATION 18 4.2 QUANTITATIVE METHODS 19 5 DRILLING DATA 20 5.1 SURVEY DATA 20 5.2 BIT RECORD 29 5.3 MUD RECORD 30 6 DAILY REPORTS 34 Enclosures 2"/100' Formation Log (MD/TVD) 2"/100' Drilling Dynamics Log (MD/TVD) 2"/100' Gas Ratio Log (MD/TVD) 2"/100' LWD/Lithology Log (MD/TVD) Final Data CD CANRIG ConocoPhillips Alaska.Inc. 2L-320 1 MUDLOGGING EQUIPMENT & CREW 11 Equipment Summary Parameter Equipment Type/Position Total Comments Downtime QGM agitator and gas trap Ditch gas Flame ionization total gas 0 and chromatography. Totco calibrating Hook Load/Weight on bit Totco WITS Feed 2%hours hookload (during drilling) Derived from Pump Stroke Mud Flow In 0 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 Pump stroke counters Totco WITS Feed* 0 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 until second sidetrack RPM Totco WITS Feed* 0 Torque Totco WITS Feed* 0 *Totco internal communications down sporadically for short periods of time Crew Unit Type Arctic Unit Number : ML057 Years Days Sample Years Days Mudloggers •1 *2 Catchers *1 *2 Technician Days Jeffrey McBeth 2 29 Doug Acker 1 7 Howard Lamp 1 Joshua Dubowski 2 14 Eric Jones 1 8 Allen Williams 2 Dan Sherwood 2 33 Steve Franzen 1 25 Dan Grunwald 2 16 Greg Hammond 1 27 Steven Pike 9 21 Zach Mester 1 24 Josh Michaud 1 11 Jim Foradas 4 14 *1 Years experience as Mudlogger '2 Days at wellsite between spud and total depth of well 2 CANRIG ConocoPhiHips A'aska.Inc. 2L-320 2 WELL DETAILS 2.1 Well Summary Well: 2L-320 API Index#: 50-103-20627-00-00 2L320-PB1 50-103-20627-00-70 2L-320 PB2 50-103-20627-00-71 Field: Kuparuk River Unit Surface Co-Ordinates: 202' FNL, 792' FEL, Sec 22, Tarn Oil Pool T10N, R7E, Umiat Meridian Borough: North Slope Primary Target Depth: 14,173' MD/5468'TVD State: Alaska Total Depth: 15,049' MD/5779'TVD Rig Name/Type: Doyon 15, Arctic Triple Suspension Date: N/A Primary Target: Bermuda Formation License: N/A Spud Date: December 31, 2010 Ground Elevation: 115.4'AMSL Completion Date: February 21, 2011 RT Elevation: 155.4'AMSL Completion Status: Completed Producer Secondary Target: None Depth: Classification: Oil TD Date: February 18, 2011 TD Formation: Seabee Fm. /equivalent Days Testing: N/A Days Drilling: 30 days 2.2 Hole Data Maximum Depth Mud Shoe Depth Hole — TD Dev. Casing/ MD TVDSS LOT Weight Section MD TVDSS Formation ()Inc) Liner (ppg) (ft) (ft) (ppg) (ft) (ft) Schrader 13W 2755' -2223' Bluff Fm./ 9.4 68° 10%" 2745' -2220' 16.8 equivalent 9'/8° 15049' -5766' Seabee Fm./ 9.8 68° 7%" 15035' -5620' (NA) equivalent 3 CANRIG ConocoPhillips Alaska.Inc. 2L-320 2.3 Daily Activity Summary 12/31/2010 Function test diverter. Test surface lines. Clean out conductor and dilled ahead to 306'. Circulated hole clean. Pulled out of hole. Picked up remaining BHA and ran in hole. Drilling ahead to 451'at midnight, gyro every stand. 01/01/2011 Drilling ahead, gyro every stand up to 1670' 01/02/2011 Drilled to 2246' and shut down at roughly 6am. Waiting on weather — phase 3 conditions. Circulating at 3 to 6 barrels per minute. Reciprocating pipe. Rotating at 30 rpm. Stand back one stand. 01/03/2011 Shut down due to weather until 7am. Drilling ahead to 2755'to TD surface hole.Circulate bottoms up. Back ream out of the hole to—1500'. Run in hole. Pumps off for—1 hour 10 min while running in hole and saw 1594u gas. Wash & ream to bottom. Work dog leg. 01/04/2011 Circulate bottoms up. Pumped 50 barrels 11.4 ppg nut plug sweep around. Circulate hole clean. Pump dry job. Pull out of hole. Lay down BHA. Rig up and run 10 3/" casing. On bottom with casing at midnight. Preparing to make up cement head and circulate. 01/05/2011 Run in hole,casing to 2745'.Rig up cement head.Circulate and condition mud. Pump cement job beginning with 40bbls of chemical wash, followed by 50bbls of mud push, followed by 335bb1 of 11.0 ppg cement, followed by 82 bbls of 12.0 ppg cement,followed by 245 bbls of 9.0 ppg oil based mud to bump the plug. CIP at 5:15am. Rig down cementers. Nipple down diverter. Nipple up BOP's 01/06/2011 Nipple up and test BOP's. Loading drill pipe to the pipe shed. Pickup drill pipe. 01/07/2011 Pick up drill pipe. Service and grease top drive,draw works, pipe skate. Continue to pick up drill pipe. Slip and cut drilling line. Pick up BHA and RIH 01/08/2011 Continue to RIH picking up singles. Circulate and condition mud at 2644'. Perform casing test to 3000 psi. Drill out float, cement, shoe, and 20' of new formation. Perform FIT test to 12 ppg EMW. Drilling ahead to 4082' at midnight. 01/09/2011 Drilling to 4611',circulating while repairing rod wash pump.Drilling to 5006'. Drop ball to open well commander. CBU for 5300 stks. Flow check well—well static. Begin short trip. POOH 4 stands. Take kick. Shut in well. Circulate out gas. Weight up to 9.3 ppg. Open well. Drop ball to close well commander. RIH. CBU. Weight up to 9.5ppg. Monitor well—Static. Short trip to shoe. 01/10/2011 Continue to POOH.CBU at the shoe.Circulate at 2 bpm while cleaning up rig. Monitor well—well static. RIH. Wash and ream from 4911'to 5006'. Drilling ahead to 6952 at midnight. 01/11/2011 Drilling to 8031'. Drop ball and open well commander. Circulate 9200 stks. Minor increase in cuttings at shakers. POOH to 4801'. Circulate 4800 stks. RIH to 8031'. Drilling ahead to 8503'at midnight. 01/12/2011 Drilled F/8,503'T/10,886'. 01/13/2011 Drilled F/10,886'to 11,445'. Back reamed out of Hole to 7,939'and circulated sweep. 01/14/2011 RIH from 7939' to 8660'. Circulate and condition mud. RIH from 8660' to tight spot at 10360'. Work pipe from 10,330'to 10,360', observed overpull on up stroke and packing off. Jar drill string loose, but observed packing off again at 10,330'. Work pipe from 10,330'to 10,260'and establish circulation at 10,260'. Circulate bottoms-up and backream out of hole to 4819' as of midnight. 4 CANRIG ConocoPhillips Alaska.Inc. 2L-320 01/15/2011 POOH to 3,050'P/O and encounter stuck D/P and P/O ream to 2,910'flow check well and observe flow back. Currently monitoring well. 01/16/2011 Monitored well @ 2,745' POOH to 1,887' and monitor well. POOH download MWD LID BHA. Monitor well and test BOP. P/U BHA#300 and begin RIH. 01/17/2011 RIH and S/C D/L Continue to RIH to 9,669'and begin reaming to btm.Cont to ream encountering stuck pipe and P/O @ 10,220'—10',free jarring as necessary.Continue to reciprocate tight spot at the time of report. 01/18/2011 Work drill string free and POOH to 9,316'experience overpull and P/O cannot establish circulation, rotation or block movement. 01/19/2011 RIH with wireline assy to 3,200' POOH to surface and screw into T/D jar and R/U wireline and continue to RIH at time of report. 01/20/2011 RIH with wireline to 8,700' and have wireline tractor unable to continue any further. POOH to 7,250'and unable to POOH any further due to tractor malfunction. Wait for Schlumberger to arrive and R/U retrieval equipment. 01/21/2011 R/U Schlumberger wireline and RIH to 9,113'and activate charge severing D/P. Circ sweep and flow check well. Begin POOH. 01/22/2011 Finish POOH. Test BOP's replacing IBOP. 01/23/2011 Complete BOP testing and M/U fishing assy. RIH to 2,968' and S/C drill line. RIH to 9,113' encountering tight hole and P/O. Continue to work tight spot at the time of report. 01/24/2011 Attempts at fishing fail. POOH UD fishing assy.R/U 3.5"tubing running equipment and begin RIH. R/U cementing equipment. Currently RIH at the time of report 01/25/2011 RIH with tubing to 7,966' and set open hole packer. R/U cement head and lines and pressure test. Pump 56 bbls and W/D R/U and pump 56 bbls. Cir B/U and POOH. L/D BHA and R/D cement equipment. P/U BHA for next drilling run. 01/26/2011 P/U new BHA and drilling assy., begin RIH to 2,632'and wait for cement to cure. RIH to 3493' and stack out. Begin washing and reaming down to 7,144' and K/O. Continue to drill ahead at the time of report. 01/27/2011 Drill from 7,334'to 9202' 01/28/2011 Drill from 9202'TO 9729'and begin backreaming out of hole to 6,987'.Circ 1.5x btms Up and begin RIH to approx 9040'stack out and begin reaming and washing down. 234 units of reaming gas recorded at approx 9070'. Continue to wash and ream to btm at the time of report. 01/29/2011 Continue to wash and ream to btm, 9,728' and then drill ahead to current depth of 10,849'. 01/30/2011 Continue to drill to 11,246' and pump sweep and circulate. Begin POOH backreaming 9,000'. 01/31/2011 Continue to backream out of hole to 3050'. 02/01/2011 Continue to backream out of hole to 2,735'flow check well and POOH elevators. UD 5 CANRIG ConocoPhillips Alaska,Inc. 2L-320 BHA. P/U new BHA and RIH and S/C DL. Currently S/C 02/02/2011 RIH to 8750'and encounter tight hole. Begin reaming and washing to 9058'. Back ream out of hole to 8760'. POOH on elevators to surface and monitor well. 02/03/2011 UD drilling assy, P/U packer and cmnt string. RIH to 3620' and set packer. R/U cmnt head and pressure test lines. Conduct 2 stage cmnt job. CBU and POOH UD 3.5"tubing. 02/04/2011 Test BOP's, P/U new BHA, RIH to 2,000' and begin washing down to 2,445'.Drilling out cmnt to 2695' at the time of report 02/05/2011 Drill from 2745'to 4807' . 02/06/2011 Drill from 4807'to 4997'and back ream to 2724'.RIH to 4900'and wash and ream down to bottom. Continue to drill ahead to current depth of 6324'. 02/07/2011 Drill from 6324'to 6983'and back ream out of hole to 4800'. Circulate two times btms up and RIH and drill ahead to current depth of 7684'. 02/08/2011 Drill from 7700'to 9064'and circ btms up. Begin back reaming out of hole to 6635'. 02/09/2011 Continue to back ream out of hole to 4,333'circulate at 4,333'. Continue to back ream out of hole to 2,700'and pump sweep. S/C drill line. Remove saber sub, POOH to 2,550', 15k overpull obs.(swabbing), circulate out gas with max gas recorded at 281 u.Flow check well,obs static. Pump 40 bbl sweep,continue to POOH. 02/10/2011 Continue to POOH, UD BHA and P/U new BHA. RIH to 7,710' stage pumps to break Circulation observe max gas @ 671 u. Circulate until gas levels decrease. RIH to bottom and continue to drill ahead to a current depth of 9290'. 02/11/2011 Drill from 9290'to current depth of 10,700'. 02/12/2011 Drill from 10,700'to 11,532'. Back ream out of the hole to 8,868' cir 3xbtms up and Flow check well (static). RIH to 10,200' at the time of report. 02/13/2011 Continue RIH in hole to bottom and drill to 11,666' ROP dropped substantially. Begin back reaming out of hole to surface. 02/14/2011 Continue to POOH and L/D BHA. P/U new BHA and RIH to 2818'. Wait on weather then continue in hole to bottom and drill to 11,714. Repairing#2 mud pump at the time of report. 02/15/2011 Drilled to 11,991'. Serviced rig, greased and inspected TD, Draw works, and iron roughneck. Continued drilling. 02/16/2011 Drilling ahead. 02/17/2011 Drilled from 14,134' to 14,508'. Flow check (static), circulate bottoms up @ 40 SPM. Drop in pressure. POOH from 14,508' to 13,553' lay down washed out single, replaced single. Cont to POOH to 11,625' MD, flow check(static) RIH on elevators from 11,625' MD to 14,508'. Drilling ahead. 02/18/2011 Drilling from 14,52' to TD @ 15049'. Circulate 3x bottoms up. Flow check (static). POOH from 15,049'to 14,944', pump out of hole to 14,561'. RIH to 15,049'.Circulate b/u. POOH from 15,049'to 10,676'. Back reamed through 10,676' to 10,486'. Wipe back down to 10,486'. POOH, pulled tight @ 10,700', wipe back through tight spots. Pumped dry job and cont to POOH from 9,899'to 5,848'. 02/19/2011 P/U and set packer @ 103.77'. Pump out stack.Change lower rams from 5'to 7-5/8".Test BOPE. 6 CANRIG ConocoPhillips Alaska.Inc. 2L-320 Rig down testing equip. POOH from 2,511'to BHA @ 651'. P/U and UD BHA. Clear and clean rig floor area. Pick up and rig up to run 7-5/8"casing. Run 7-5/8"casing. 02/20/2011 Run 7-5/8"casing fom 236'MD to 5,833'.Circulate B/U at shoe @ 5bpm. Fill pipe every joint and completely fill every 10 joints.Obtain P/U and S/O weights every 4th joint in open hole.Cont RIH T/10,000 MD circulate B/U @ 4 bpm. Cont to RIH to 12,500' MD and circulate B/U, and rig down logging unit. 7 CANRIG ConocoPhillips 2L-320 3 GEOLOGICAL DATA 3.1 Lithostratioraphy All tops provided by ConocoPhillips Operations Geologist. MD TVD TVDSS MD TVD TVDSS Top/Marker prognosis prog prog actual actual actual 10 3/4" Casing Shoe 3,150' 2,469' -2,314' 2,745' 2,376' -2,220 9 7/8" Intermediate Borehole (prognosed depths per wp08): 080 (K10) 3,047' 2,480' -2,325' 3,047' 2,483' -2,327' Camp Sand (Top) 3,264' 2,540' -2,385' 3,264' 2,545' -2,389' C50 8,309' 3,885' -3,730' 8,333' 3,889' -3,733' C40 9,782' 4,275' -4,120' 9,827' 4,282' -4,126' C37 10,651' 4,505' -4,350' 10,428' 4,443' -4,287' S8-Top Reservoir 14,236' 5,475' -5,320' 14,173' 5,468' -5,312' T1.5- Base Reservoir 14,548' 5,575' -5,420' 14,588' 5,607' -5,451' C35 14,824' 5,690' -5,535' 14,867' 5,712' -5,556' TD 15,085' 5,811' -5,656' 15,049' 9 7/8" PB2 Intermediate Borehole (prognosed depths per wp06): C80 (K10) 3,193' 2,480' -2,325' 3,130' 2,482' -2,326' Camp Sand (Top) 3,444' 2,543' -2,387' 3,408' 2,545' -2,389' C50 9,061' 3,916' -3,760' 9,065' 3,916' -3,760' C40 10,730' 4,312' -4,156' 10,713' 4,310' -4,154' TD 2L-320 PB2 -- -- -- 11,247' 4,438' -4,282' 9 7/8" PB1 Intermediate Borehole (prognosed depths per wp05): C80 (K10) 3,193' 2,480' -2,325' 3,130' 2,482' -2,326' Camp Sand (Top) 3,444' 2,542' -2,387' 3,408' 2,545' -2,389' C50 8,977' 3,915' -3,760' 9,036' 3,918' -3,762' C40 10,630' 4,325' -4,170' 10,600' 4,310' -4,154' TD 2L-320 PB1 -- -- -- 11,446' 4,519' -4,363' 8 CANRIG ConocoPhillips Alaska.Inc. 2L-320 3.2 Mudloq Summary Surface to top of C-80 (0' MD to 3047' MD, 0 TVD to-2327 TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 1064 60 529.4 559 0 19.6 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. The sand conglomerate in this section is composed of very light gray to pale green with clear quartz grains sometimes with moderate orange pink hue; medium to upper fine to lower coarse grained; moderate to low sphericity; subangular to subrounded; sample matrix composed of unconsolidated quartz grains; pebbles become abundant again; average pebble size approximately 3x4 millimeters; pebbles are well rounded to rounded to subrounded;common amounts of glauconite present;trace amounts of pyrite and brown laminated carbonaceous material; good estimated porosity and permeability. Sand in this formation consists of light medium gray to translucent white and smoky gray quartz;lower medium to upper fine to occasionally upper medium and lower fine grained; moderate to poor sorting; sub angular to angular to occasionally sub rounded; poor to moderate sphericity; unconsolidated; impact abrasions are present but uncommon. The claystones in this section are comprised of dark medium gray to very dark medium gray with blackish hues; poor to moderate induration; noticeably harder than in the previous sample; brittle to crumbly to occasionally tough; irregular to occasionally blocky to rarely planar; tabular to platy cuttings habit; dull to occasionally earthy luster; smooth to clayey texture; pulverized clay is moderately hydrophilic; moderate to good cohesiveness; poor to moderate adhesiveness; pasty to lumpy consistency; no visible fluorescence. Gas levels were generally low, with the exception of a section with peaks over 185 units to 559 units from approximately 2484' MD to 2784' MD, usually associated with methane hydrates just above the base of the permafrost. Peaks Depth (MD) TG Cl C2 C3 IC4 nC4 iC5 nC5 2702' 559u 167974 21 25 18 8 40 26 2738' 525u 149398 3 23 15 10 30 10 C-80 to top of Camp Sand (3048'to 3264' MD, -2328 TVDSS to-2389 TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 266 35 175.4 180 3 21.8 The Camp sand formation is comprised of sandstone, sand, siltstone, claystone, and carbonaceous shales. The siltstones in this formation are made up of medium dark gray with some light gray; very mushy; soft throughout; irregular fracture; amorphous cuttings habit; earthy to very dull luster; very gritty to slightly silty texture; very thin laminae interbedded with thin lenses of sand; no sample fluorescence was observed. 9 CANRIG ConocoPhillips Alaska.Inc. 2L-320 Clays and claystones in this section are comprised of light gray to medium gray with some grayish brown; gray; pasty to punky; malleable tenacity irregular fracture; amorphous cuttings with some platy habit; silty to gritty texture;thin laminae structure; contains thin lenses of sand and fine carbonaceous material; less than 5% sample fluorescence; no solvent cut; no other petroleum indicators were observed. The sands in this formation are composed of translucent to clear with some white to light gray and bluish green hues;predominantly quartz grain sand with some dark colored lithic fragments;lower very fine to upper fine grain sand; very well sorted throughout; very well rounded to subrounded; moderate sphericity; poor apparent sample porosity;very thin lenses of sand interbedded with thin beds of siltstone and moderately thick beds of claystone; very little to no sample fluorescence; no solvent cut. Sandstones in this section are made up of white to black with medium light gray to medium dark gray; predominantly quartz sand matrix; individual grains appear to be primarily clear to Smokey gray colored quartz; grain size varies from upper fine to lower medium; sand grains are predominantly fair to moderately sorted and subangular to angular; grain supported with some rare matrix support; matrix displays dominant silty gritty texture;large sandstone fragments appear to show some grading grain size from medium grained to trace very fine grained to almost silt; cohesive siltstone with distinctive shale laminar bedding appear as inclusions in sandstone; rare massive fragments of hydrophilic claystone; no sample fluorescence was observed; no other petroleum indicators were observed. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 3179' 180 35538 78 29 - - - - Camp Sand to top of C50(3265'to 8333' MD, -2389 TVDSS to-3733 TVDSS Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 206 9 118.1 85 2 29.1 The C-50 formation is comprised of sandstones,sand,siltstones,claystones,carbonaceous shale,and shale The sandstones in this unit are comprised of white to light gray pale brown and dark yellowish brown with some clear to translucent; predominantly quartz grain sand matrix; upper very fine to lower medium grain sand; subangular to subrounded with some slightly angular to rounded; moderate to high sphericity; sand grains are slightly cemented with a siliceous cement matrix;some grains appeared to be polished and frosted; some loose unconsolidated sand grains in sample; abundant dark colored lithic fragments; no sample fluorescence was observed. Siltstones in this formation are composed of brownish gray to dark grayish brown with light medium gray and reddish brown and grayish blue green hues; slightly stiff to clumpy;very brittle; irregular fracture throughout; amorphous cuttings habit;earthy to slightly dull luster with some slightly vitreous in places;very silty texture to somewhat slightly gritty; very thick siltstone beds interbedded with thicker lenses of sandstone and thin claystone beds; no visible fluorescence; no solvent cut. Claystones in this formation are made up of brownish gray to grayish brown to pale yellowish brown; slightly firm to moderately firm; crumbly to slightly crunchy; subblocky blocky to subplaty with occasional planar cuttings fracture;earthy;moderately to very silty;grades to siltstone and sandstone;clay content very slightly organic;very slight reddish brown to black carbon silts and fines partially lineated;trace of pyrite;trace mica; no visible fluorescence; no solvent cut. 10 CANRIG ConocoPPhillips Alaska,Inc. 2L-320 The shales in this section are made up of medium gray to grayish brown and brownish gray; slightly firm to somewhat stiff; slightly dense to somewhat crumbly; planar to slightly splintery fracture; platy to amorphous cuttings habit;mostly waxy to slightly greasy luster;very smooth to slightly silty texture;very thin beds of shale interbedded with very thin beds of carbonaceous shale thin beds of sandstone lenses and thicker beds of siltstone; no visible sample fluorescence was observed; no solvent cut. Gas is generally low and associated with the base of the C-50 and the top of the C-40 formation. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 IC5 nC5 7826 85 15888 583 188 30 12 15 - C50 to top of C40(8334'to 9827' MD, -3734 TVDSS to-4126 TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 157 22 98.9 87 14 56.7 This interval is comprised of sandstones, sand, siltstone, claystone, shale and carbonaceous shale. The sandstones in this section are comprised of predominantly translucent to clear with some white light gray very light gray,gray black and grayish black hues; predominantly quartz grain sand matrix; upper very fine to lower medium grain sand;subangular to subrounded with some slightly angular to rounded;moderate to high sphericity; abundant dark colored lithic fragments; sand grains appeared to be polished and frosted; moderately thin sand lenses interbedded with thick beds of siltstone and thin beds of shale and carbonaceous shale; fair to poor sample porosity; no visible sample fluorescence was observed; no solvent cut. Siltstones in this formation are made up of pale brown to dark yellowish brown brownish gray to grayish brown and some black; very pasty to mushy; mostly crumbly to slightly crunchy throughout; irregular fracture; amorphous cuttings habit; very dull to slightly earthy luster; very silty to slightly clayey texture; very thin laminae interbedded with very thin lenses of sand and thin beds of claystone and shale; no visible sample fluorescence was observed; no solvent cut. An example of the carbonaceous shales in this formation are black reddish black dusky red blackish red brownish black and duskybrown; mostlystiff to slightly firm; verybrittle to slightly sectile; very planar to 9 Y 9 Y splintery fracture; flaky to platy cuttings habit; mostly vitreous to somewhat resinous luster; very smooth texture; very thin laminae interbedded with thick beds of siltstone and sandstone with thin beds of shale; no visible sample fluorescence; no solvent cut. Gas is generally low in this formation section. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 9827' 87 16142 592 191 30 13 16 - C40 to C37(9828'to 10428' MD,-4127 TVDSS to-4287 TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 495 13 96.9 75 2 40.4 11 CANRIG ConocoPPhillips Alaska.Inc. 2L-320 This interval is generally comprised of sandstone, sand, siltstone, claystone, shale, and carbonaceous shale. The sandstones in this section are comprised of dark gray to light gray with some white to translucent to clear with some very dark gray to grayish black hues; predominantly quartz grain sand matrix; upper fine to upper medium grain sand; subangular to subrounded with some slightly rounded to angular; moderate to high sphericity;abundant dark colored lithic fragments;moderately thin beds of sand interbedded with thick beds of siltstone; no visible sample fluorescence was observed. An example of the sands in the C-37 are composed of dark gray to light gray with some white smoky to translucent and clear with some very dark gray to grayish black hues;predominantly quartz grain sand matrix; upper fine to upper medium grain sand;subrounded to subangular with some mostly angular to very rounded; moderate to high sphericity; abundant dark colored lithic fragments; moderately thicker beds of sand and sandstones interbedded with thinner beds of siltstones;abundant pyrite crystals throughout sample;no sample fluorescence was observed. Siltstones in the C-37 unit are generally made up of grayish black to dark gray with some brownish gray medium gray to grayish brown; very mushy to pasty; mostly crunchy to slightly crumbly throughout; irregular fracture; amorphous cuttings habit; very dull to slightly earthy luster;very silty to slightly clayey texture; very thin laminae interbedded with very thin lenses of sand and thin beds of claystone and shale;no visible sample fluorescence was observed; no solvent cut. The claystones in this formation are comprised of dusky brown to dusky yellowish brown amorphous claystone;lumpy to clumpy consistency;pulverulent tenacity;nodular massive cuttings habit;dull earthy luster; very clayey and silty; lithics; pyrite and tuff are also present; no petroleum indicators. Carbonaceous shales in this unit are made up of black to blackish red with some very dusky red and dusky yellowish brown hues; slightly firm to moderately soft; subblocky with visible fissility and occasional planar fracture;clayey to earthy to silty texture;traces of carbon silts fines and flakes;partially interbedded with trace micro pyrite micas; no visible sample fluorescence. Total gas was generally low in this section of the formation. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 10192' 75 13833 520 188 39 18 21 - C37 to S8-Top Reservoir(10429'to 14173' MD,-4288 TVDSS to-5312 TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 274 9 73 138 8 48 This interval is comprised of sandstones, sands, and siltstones. The sandstones of this formation are comprised of clear to translucent with some light gray and white with pale blue and pale blue predominantly quartz grain sand; lower very fine to lower fine with some upper fine grain sand;moderately well sorted throughout;very angular to subangular with some slightly rounded to subrounded in places; moderate sphericity; very little loose unconsolidated sand; predominantly siliceous cemented sandstone with some slightly calcareous in places; pale to bright golden yellow to yellow green sample fluorescence; very slow milky white solvent cut. The siltstones in this section are composed of medium gray to medium light gray with some grayish brown and brownish gray in places;moderately soft to slightly stiff;blocky to platy with some slight fissility;predominantly very earthy to very dull; mostly very silty with some slightly gritty; thinner siltstone beds interbedded with 12 CANRIG ConocoPhillips Alaska,Inc. 2L-320 thicker beds of siliceous cemented quartz sandstone mostly friable; bright yellow sample fluorescence approximately 20%-40%;delayed milky white solvent cut; poor to fair porosity. Gas was generally low in this section. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 11301 67 12001 485 229 69 36 39 - S8-Top Reservoir to T1.5-Base Reservoir(14173'to 14588' MD, -5312'TVDSS to-5451' TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 274 15 74.1 138 19 43.3 The reservoir zone is predominantly comprised of sandstones, and sands, with some sandy siltstones. The sandstones in the reservoir section are comprised of very light gray to bluish white to white with abundant transparent grains;upper very fine to lower fine with occasional upper fine grains;mostly friable to firmly friable consolidated sandstone fragments with some loose disaggregated quartz grains; moderate to low sphericity; angular to subangular;poor to moderate sorting;siliceous cement with trace amount of calcareous cementing; grain supported; trace amount of pyrite; no petroleum odor;faint yellowish green. Sands in this section are made up of light gray to white with translucent; upper very fine to upper fine grain with occasional medium sized grains and lower coarse sized sandstone fragments;well sorted;subangular to subrounded; moderate to low sphericity; sands are loose disaggregated and consolidated; sandstone is moderately hard to hard with calcareous cementing;trace amounts of pyrite and dark carbonaceous material in sample; no petroleum odor; no visible fluorescence; no cut fluorescence; no visible cut; no visible residual. The siltstone in this formation is composed of dark brownish gray to dark olive gray;amorphous cuttings habit; irregular fracture;earthy to dull luster;silty to gritty to slightly clayey texture;crumbly to crunchy to rarely brittle; sandstone claystone are common but not abundant;disseminated pyrite and dark lithics are rare;pale bright golden yellow to yellow green fluorescence; slow milky white solvent cut;free oil in sample. Peaks Depth (MD) TG Cl C2 C3 Ic4 nC4 iC5 nC5 14358 109 20631 2546 1561 520 201 117 40 14450 138 26003 3866 2783 961 515 189 105 T1.5-Base Reservoir to Top of C35(14589'to 14867' MD, -5452' TVDSS to-5556'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 126 41 84.3 47 11 20.2 This section consists of siltstones, shales, claystones with a lesser amount of sandstones, and sand. The average siltstones in this section are comprised of medium gray to light gray with brownish gray and brownish hues;crumbly to crunchy to occasionally brittle;irregular fracture;amorphous cuttings habit;very dull to slightly earthy luster;very silty to slightly clayey texture;shale is black to grayish black crumbly to somewhat 13 CANRIG Conocoi hiiiips Alaska.Inc 2L-320 flexible; planar fracture; platy to flaky cuttings habit claystone and sandstone common; dark lithics rare; no visible sample cut; no odor; no fluorescence. Gas is generally low in this section. Peaks Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 (MD) 14595' 47 7461 662 620 365 221 121 52 C35 to TD(14868'to 15049' MD, -5557 TVDSS to-5780 TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 86 29 72.3 79 20 69 This interval consists of carbonaceous siltstone,with some shale,carbonaceous shale,with lesser amounts of sandstones, and sand. Siltstones in this section are comprised of medium gray to olive gray to occasionally light gray with brownish hues; crumbly to crunchy to occasionally brittle; irregular fracture; amorphous cuttings habit; very dull to slightly earthy luster;very silty to slightly clayey texture; shale is black to grayish black crumbly to somewhat flexible;planar fracture;platy to flaky cuttings habit claystone and sandstone common;dark lithics;no sample fluorescence; no odor. The shales are made up of medium gray to grayish brown; planar fracture;platy to flakey cuttings habit;brittle to crumbly to somewhat flexible; very earthy to occasionally dull luster; clayey to silty texture; sandstone siltstone and claystone present as well; disseminated pyrite throughout the sample; no visible sample fluorescence was observed; no free oil was observed in the sample. Gas is generally low. Peaks Depth (MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 14986' 79 15440 1505 956 342 214 186 57 14 CANRIG ConocoPPhillips Alaska.Inc. 2L-320 3.3 Connection Gases 1 unit=0.05%Methane Equivalent Depth Gas over BGG (feet) (units) 1484' 401 2543' 123 2599' 195 2702' 353 3491' 2093 3585' 2300 3678' 2320 3775' 1352 3868' 1554 3954' 580 4044' 1972 4320' 1000 4407' 1143 4526' 1270 4610' 2056 4685' 1709 4911' 455 5004' 1222 3.4 Trip(Wiper)Gases 1 unit=0.05% Methane Equivalent Depth Trip to Gas (feet) (feet) (units) 3081' 1390' 212 3200' SHOE 1115 5038' SHOE 52 (WG) 3200' SHOE 11 9352' 7600' 1214 (WG) 4999' SHOE 45 6990' 4818' 52 9064' Surface 671 11532' 8868' 175 11666' Surface 53 15049' Surface 15 CANRIG ConocoPhillips Alaska.Inc. 2L-320 3.5 Gas Peaks Depth TG Cl C2 C3 IC4 nC4 iC5 nC5 (MD/TVD) (units) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) 1002/995.85 847.9 197160 14.4 2.5 13.7 - - - 1304/1288.58 920.3 227248 3.7 11.9 14.1 - - - 1358.75/1377 2267.2 560685.01 26.91 2.4 3.0 - - - 16 CANRIG ConocoPhillips Alaska,Inc. 2L-320 3.6 Sampling Program/Sample Dispatch Reference samples throughout the entire hole were collected in plastic vials and stored in tray folders. Samples for the first sidetrack are stored in the sample trays in the order in which they were drilled, immediately following the samples from total depth of the plugback (11445'). Likewise, samples for the second sidetrack are stored in the sample trays in the order in which they were drilled, immediately following the samples from total depth of the first sidetrack(11247'). Wet sample collection was cancelled just after 5000' of drilling. Set Type/Purpose Frequency Interval Dispatched to Washed, screened, 50' 110'—2750' CPAI,ABV 100 and dried reference 50' 2750'—11450' Bayview Warehouse samples in sample50' *7300'—11247' 619 E.Ship Creek Ave. A envelopes and50' **2750'-14200' Anchorage,AK 99501 plastic vials ** Attn:D.Przywojski/M. 10' 14200'—14650' McCracken Set owner: CPAI 50' **14650'—15050' (907)263-4859 Washed, screened, 50' 110'—2750' CPAI,ABV 100 and dried reference 50' 2750'—11450' Bayview Warehouse samples in sample50' *7300'—11247' 619 E.Ship Creek Ave. B envelopes and50' **2750'-14200' Anchorage,AK 99501 plastic vials ** Attn:D.Przywojski/M. 10' 14200'—14650' McCracken Set owner:AOGCC 50' **14650'—15050' (907)263-4859 Unwashed and screened wet 50' 11'—5100' CPAI,ABV 100 Bayview Warehouse samples in plastic 619 E.Ship Creek Ave. C Whirl-Pak®bags 10' Cancelled Anchorage,AK 99501 Attn:D.Przywojski/M. Set owner: CPAI 50' Cancelled McCracken (907)263-4859 *Samples from Sidetrack#1 begin at 7300'and continue to 11247' **Samples from Sidetrack#2 begin at 2750' and continue to 15050' DRY SAMPLE BOX INTERVALS: 110'-2750', **2750'—5050', **5050'—7700', **7700'—10450', **10450'—13050', **13050'—14500', **14500'— 15050' WET SAMPLE VIAL INTERVALS: 2750'—5050', 5050'—7550', 7550'—10050', 10050'—11450', *7300—9800, *9800'—11250' WET SAMPLE Whirl-Pak®bags INTERVALS: 150'-2750', 2750'—4600, 4600'—5000' 17 CANRIG co ' s 0 2 2 2 2 2 0 0 U c = I 0 I mU0 UU0 Ub = = U = = = 0- mUt0 i 00 5 C7 C7 U C7 (7 m m m m CO 13 Z Z Z a fy f CC W d > > > > 0 0 0 Z Z H W W W W W L �. -a x0 cfl co oo co O N- r- co N. a) H 2 a o a) ai ai ai ai ai ai ai I CL cn ❑ g co co I. .- N co a- V) H N N M l 1 4 4 a U) ,s 0. II i G FO- ❑ co `n cocCOcoM co o eN- ) 3 M R to co.. N V' c0 3 J Z N N M T LO to LO co C " a f6 8, 0 -c M - 0o M DO I� co ❑ ..... c�0 co N N I� W co a) c) cvLo_ co o II M M cd- a) O NF Ni' t� r .- ,- ,- V) Q a) C 0 N A c \ \ \ c o 9 O oo LaM O O O O o 'a O N 0 M N M p (n I- CNI W CO V w \ F— } V) 1- H H a = I- o Cl) J t) Cl) U co N co Z m m CO as c Z = is O {{_ \ o o \ o o Cl) > �+ p) O O O o0 '- I- a 0 0 II l'"' W ca O — 00 (0 ti O co N- N N 0 Q = _ t o 5 V) u) ❑ Z co N Cl) ,„I- V) d ` r+ >' CL 'p a J J J J V) Z J J 06 ` U V) Cl) U CO m V) U u_ C N c L o W 3 -ao L >. Mdas aa) N ca v) a` o a) v CO i R Y E LS � M p M 0 _VV) d Ce a° c u. U Uo U 0 U o crow 0 ~ W I- m I- o_ ao U? 0 I- Z I- C C 2 °0 2 E J a ¥ £ _ ƒ / 5e 7 / .- .- � 2 a '5 -2 0 G Lu R > 2 = 7 � E0c » 22 6. V C k n � omo © 3 � § ^ a / [ \ / o = o % �w = a 2 2 %/ d 6_ > .E 7 G > LU > - \ 6 f $ us / \ / ) Ct ® _ coo = £ 6 ± � a u) a : 5- 2 § f 6 a) 2E % % § oa / 227 E - Etc 2 ■ ._ Co - _ •- 5 c f q - : } V0 _ 5 / � 0 — e 7 7 f C g \ _c § � CU � / / \ \J4.4 / a 11 E % c .0 ca as o - ou) k E E. .uJ f 7 \ 7 q + f as X - ® o 0_co D 2 0 \\ k $ -0 / 0 // 2 \ 3 E � 2 § � ■ ems 2 ° ole § S = � w 2 § k . c2 £ mc 'd)• 99 K $ k 0.f m o o a) k -• k k o ± g ■ -...1.(13- 7 = 0 CU E E ,_ i - E 0 \� k ■ UI fl u » 2 � \ 4- 0 � . \ Gk ■ e2 0 / tic t ems § If 82 � '...7, kk \ SE k § � .1E' �: 2 § 3 \ al » § k k > / k \ e @ ® co k e E E 2 / .§ k J § / k k ConocoPhillips Alaska,Inc. 2L-320 5 DRILLING DATA 5.1 Survey Data, Measured Inclination Azimuth True N(+)/S(-) E(+)/W(-) Vertical Dogleg Depth ° ° Vertical Section Rate (ft) ( ) ( ) Depth (ft) (ft) (ft) (ft) (°/100ft) 40.95 0.00 0.00 40.95 0.00 0.00 0.00 0.00 100.00 0.33 84.28 99.99 0.01 0.16 0.14 0.55 165.00 1.15 107.76 164.99 -0.16 0.97 0.95 1.31 254.00 1.32 121.22 253.97 -0.96 2.70 2.85 0.37 351.00 1.62 121.02 350.94 -2.25 4.83 5.33 0.30 440.00 2.18 111.76 439.89 -3.52 7.48 8.27 0.71 535.00 2.59 108.96 534.80 -4.89 11.19 12.20 0.44 627.00 3.22 118.88 626.69 -6.81 15.42 16.85 0.87 724.00 4.73 124.16 723.45 -10.38 21.11 23.52 1.60 819.00 8.46 127.81 817.81 -16.86 29.88 34.23 3.94 915.00 14.69 132.07 911.81 -29.36 44.51 52.83 6.54 960.00 15.36 131.75 955.27 -37.15 53.19 64.03 1.50 1007.00 14.59 132.53 1000.67 -45.30 62.19 75.68 1.69 1102.00 13.97 129.16 1092.74 -60.63 79.90 98.28 1.09 1197.00 13.71 129.77 1184.98 -75.07 97.45 120.35 0.31 1292.00 14.90 126.21 1277.04 -89.49 115.96 143.27 1.55 1388.00 17.10 121.82 1369.31 -104.22 137.91 169.44 2.61 1483.00 18.33 123.05 1459.81 -119.74 162.30 198.15 1.35 1526.44 18.21 120.12 1501.06 -126.87 173.90 211.69 2.13 1625.40 21.61 121.51 1594.09 -144.16 202.82 245.24 3.46 1724.63 26.65 120.77 1684.62 -165.10 237.54 285.61 5.08 1821.04 32.12 120.40 1768.60 -189.15 278.26 332.73 5.67 1865.48 33.22 121.66 1806.01 -201.52 298.81 356.61 2.91 1915.34 34.45 122.10 1847.42 -216.19 322.38 384.20 2.51 2009.93 37.07 124.24 1924.17 -246.45 368.62 438.99 3.06 2104.95 39.99 122.44 1998.50 -278.95 418.08 497.64 3.29 2198.85 43.73 120.23 2068.43 -311.49 471.61 559.98 4.28 2292.79 49.05 118.82 2133.20 -344.96 530.79 627.82 5.76 2336.84 49.65 118.67 2161.90 -361.03 560.09 661.19 1.38 2387.60 50.51 119.09 2194.47 -379.84 594.17 700.06 1.80 2432.85 52.56 118.18 2222.62 -396.81 625.27 735.44 4.79 2483.66 56.45 118.10 2252.11 -416.32 661.74 776.76 7.65 2530.68 58.11 117.70 2277.53 -434.83 696.70 816.29 3.60 2575.11 59.23 117.16 2300.63 -452.31 730.39 854.22 2.72 2665.45 64.61 115.86 2343.14 -487.85 801.69 933.89 6.08 20 CANRIG ConocoPhillips Alaska.Inc. 2L-320 Measured Inclination Azimuth True N(+)/S(-) E(+)/W(-) Vertical Dogleg Depth ° ° Vertical Section Rate (ft) ( ) ( ) Depth (ft) (ft) (ft) (ft) (°/100ft) 2706.47 66.33 114.91 2360.17 -503.85 835.41 971.20 4.69 2790.11 68.87 116.88 2392.04 -537.62 904.96 1048.52 3.73 2886.54 72.87 117.07 2423.64 -578.94 986.13 1139.58 4.15 2980.63 76.90 117.14 2448.16 -620.32 1066.98 1230.37 4.28 3075.46 76.97 117.09 2469.60 -662.42 1149.20 1322.71 0.08 3170.09 76.74 117.50 2491.12 -704.68 1231.09 1414.83 0.48 3265.06 76.63 117.46 2512.99 -747.32 1313.08 1507.20 0.12 3359.55 77.11 116.41 2534.46 -789.01 1395.11 1599.19 1.19 3452.77 76.56 116.61 2555.69 -829.52 1476.34 1689.95 0.62 3547.24 76.27 116.88 2577.88 -870.85 1558.34 1781.76 0.41 3642.29 76.49 114.99 2600.27 -911.24 1641.41 1874.13 1.94 3737.88 76.39 115.26 2622.68 -950.70 1725.55 1967.05 0.29 3832.19 76.63 113.53 2644.68 -988.57 1809.06 2058.74 1.80 3926.35 76.66 114.22 2666.43 -1025.65 1892.84 2150.31 0.71 4020.84 76.55 114.51 2688.32 -1063.58 1976.57 2242.20 0.32 4116.18 76.59 112.61 2710.46 -1100.64 2061.57 2334.87 1.93 4210.92 76.38 112.58 2732.61 -1136.03 2146.61 2426.85 0.22 4305.97 76.36 112.88 2755.00 -1171.72 2231.81 2519.10 0.30 4401.06 76.18 112.82 2777.57 -1207.59 2316.94 2611.37 0.19 4492.57 76.08 113.02 2799.51 -1242.19 2398.76 2700.11 0.23 4584.88 76.00 113.22 2821.78 -1277.37 2481.15 2789.60 0.22 4682.94 75.90 113.30 2845.59 -1314.93 2568.55 2884.64 0.12 4778.33 75.86 113.49 2868.86 -1351.67 2653.45 2977.08 0.19 4868.88 75.84 113.53 2890.99 -1386.69 2733.97 3064.82 0.04 4968.35 75.80 113.13 2915.36 -1424.88 2822.52 3161.18 0.39 5061.70 75.69 113.38 2938.35 -1460.61 2905.64 3251.58 0.28 5155.29 75.69 113.27 2961.48 -1496.51 2988.92 3342.19 0.11 5248.63 75.62 113.62 2984.60 -1532.49 3071.88 3432.55 0.37 5346.43 75.42 112.05 3009.06 -1569.24 3159.15 3527.12 1.56 5440.48 75.43 112.44 3032.73 -1603.70 3243.40 3617.99 0.40 5536.87 75.36 112.53 3057.03 -1639.37 3329.58 3711.12 0.11 5628.95 75.31 113.17 3080.34 -1673.96 3411.67 3800.09 0.67 5726.48 75.55 111.56 3104.88 -1709.88 3498.96 3894.32 1.61 5818.80 75.63 111.58 3127.85 -1742.75 3582.12 3983.51 0.08 5913.82 75.58 111.35 3151.48 -1776.43 3667.77 4075.30 0.24 6008.39 75.54 111.49 3175.06 -1809.87 3753.03 4166.63 0.14 6103.26 75.31 111.76 3198.93 -1843.71 3838.38 4258.22 0.36 6198.22 75.10 112.01 3223.18 -1877.93 3923.58 4349.84 0.33 6293.47 75.25 110.80 3247.56 -1911.54 4009.30 4441.66 1.23 21 CANRIG ConocoPhillips Alaska.Inc. 2L-320 Measured True Vertical Dogleg Inclination Azimuth N(+)/S(-) E(+)/W(-) Depth ° ° Vertical Section Rate (ft) ( ) ( ) Depth (ft) (ft) (ft) (ft) (°/100ft) 6388.43 75.12 111.48 3271.84 -1944.65 4094.93 4533.18 0.70 6483.51 75.09 111.50 3296.28 -1978.31 4180.43 4624.82 0.03 6578.07 75.75 111.27 3320.08 -2011.68 4265.64 4716.08 0.73 6672.52 75.66 111.91 3343.40 -2045.35 4350.74 4807.37 0.66 6766.95 75.57 111.60 3366.86 -2079.26 4435.70 4898.63 0.33 6860.96 75.44 111.85 3390.39 -2112.95 4520.25 4989.43 0.29 6951.67 75.49 111.83 3413.16 -2145.61 4601.75 5077.04 0.05 7050.17 75.44 112.28 3437.88 -2181.41 4690.12 5172.20 0.44 Ti 7144.69 75.56 111.28 3461.55 -2215.37 4775.10 5263.50 1.03 Pb 7241.87 76.45 111.14 3485.05 -2249.48 4863.01 5357.51 0.92 Pb 7332.25 76.44 111.13 3506.23 -2281.16 4944.96 5445.10 0.01 Pb 7429.12 76.43 111.67 3528.95 -2315.52 5032.64 5539.01 0.54 Pb 7524.14 76.32 111.61 3551.33 -2349.58 5118.47 5631.12 0.13 Pb 7616.26 76.46 111.95 3573.01 -2382.80 5201.61 5720.45 0.38 Pb 7707.87 76.48 111.73 3594.44 -2415.93 5284.29 5809.32 0.23 Pb 7803.76 76.37 110.82 3616.95 -2449.75 5371.15 5902.26 0.92 Pb 7899.20 76.30 111.08 3639.50 -2482.91 5457.75 5994.68 0.27 Pb 7988.14 76.25 110.99 3660.60 -2513.92 5538.40 6080.80 0.11 Pb 8087.05 76.16 111.75 3684.19 -2548.92 5627.85 6176.59 0.75 Pb 8180.93 76.08 111.82 3706.71 -2582.75 5712.48 6267.52 0.11 Pb 8276.68 75.93 111.53 3729.86 -2617.06 5798.82 6360.20 0.33 Pb 8371.14 75.82 111.57 3752.91 -2650.71 5884.02 6451.57 0.12 Pb 8462.99 75.75 111.52 3775.47 -2683.41 5966.84 6540.38 0.09 Pb 8554.24 75.68 111.46 3797.98 -2715.80 6049.12 6628.58 0.09 Pb 8653.05 75.68 111.28 3822.42 -2750.69 6138.27 6724.05 0.17 Pb 8747.68 75.50 111.49 3845.97 -2784.11 6223.62 6815.44 0.28 Pb 8841.78 75.48 111.98 3869.55 -2817.84 6308.24 6906.33 0.50 Pb 8938.54 75.59 111.86 3893.72 -2852.82 6395.16 6999.82 0.16 Pb 9033.60 75.49 112.27 3917.46 -2887.40 6480.46 7091.69 0.43 Pb 9129.01 75.31 112.59 3941.51 -2922.63 6565.81 7183.87 0.37 Pb 9225.37 75.13 113.07 3966.09 -2958.78 6651.68 7276.93 0.51 Pb 9319.51 74.92 112.77 3990.42 -2994.20 6735.44 7367.77 0.38 Pb 9415.52 75.24 111.45 4015.14 -3029.11 6821.39 7460.36 1.36 Pb 9510.28 75.22 111.65 4039.29 -3062.77 6906.62 7551.75 0.20 Pb 9604.17 75.20 112.18 4063.26 -3096.65 6990.83 7642.34 0.54 Pb 9699.37 75.95 110.42 4086.98 -3130.14 7076.73 7734.27 1.95 Pb 9794.51 75.89 110.76 4110.12 -3162.59 7163.12 7826.19 0.35 Pb 9889.41 76.16 110.56 4133.04 -3195.08 7249.29 7917.93 0.35 TI sidetrack#1 tie-in Pb plugback 22 CANRIG ConocoPhillips Alaska.Inc 2L-320 Measured Inclination Azimuth True N(+)/S(-) E(+)/W(-) Vertical Dogleg Depth ° ° Vertical Section Rate (ft) ( ) ( ) Depth (ft) (ft) (ft) (ft) (°/100ft) Pb 9984.03 75.70 111.14 4156.05 -3227.75 7335.06 8009.38 0.76 Pb10079.22 75.57 111.37 4179.66 -3261.18 7421.00 8101.33 0.27 Pb10174.34 75.49 111.32 4203.43 -3294.70 7506.78 8193.17 0.09 Pb10269.34 75.48 111.45 4227.24 -3328.24 7592.42 8284.88 0.13 Pb10364.57 75.54 111.79 4251.07 -3362.21 7678.13 8376.85 0.35 Pb10458.17 75.42 111.93 4274.54 -3395.94 7762.23 8467.26 0.19 Pb10553.92 75.45 112.30 4298.61 -3430.83 7848.08 8559.76 0.37 Pb10649.23 75.44 112.56 4322.57 -3466.03 7933.36 8651.86 0.26 Pb10743.87 75.46 112.46 4346.34 -3501.10 8017.98 8743.33 0.10 Pb10839.20 75.78 111.16 4370.02 -3535.41 8103.71 8835.46 1.36 Pb10933.42 75.74 111.31 4393.20 -3568.49 8188.84 8926.51 0.16 Pb11028.70 75.75 111.09 4416.66 -3601.88 8274.93 9018.58 0.22 Pb11122.29 75.79 111.12 4439.66 -3634.55 8359.57 9109.01 0.05 Pb11218.46 75.74 111.02 4463.31 -3668.06 8446.55 9201.93 0.11 Pb11309.40 75.70 111.73 4485.74 -3700.18 8528.62 9289.81 0.75 Pb11408.96 75.59 111.29 4510.43 -3735.54 8618.35 9386.01 0.44 Pb11446.00* 75.59 111.29 4519.64 -3748.57 8651.78 9421.78 n.a. T1 7144.69 75.56 111.28 3461.55 -2215.37 4775.10 5263.50 1.03 stl 7246.00 73.24 110.69 3488.79 -2250.32 4866.20 5360.75 1.03 st1 7336.47 73.99 109.12 3514.31 -2279.86 4947.81 5447.11 2.36 sti 7• 430.72 74.75 108.16 3539.71 -2308.87 5033.81 5537.19 1.86 stl 7525.07 76.09 106.43 3563.46 -2336.01 5120.99 5627.52 1.27 stl 7613.74 76.6 104.61 3584.39 -2359.07 5204.01 5712.34 2.27 stl 7709.52 76.86 104.68 3606.38 -2382.64 5294.20 5803.84 2.08 stl 7• 804.47 76.8 105.47 3628.01 -2406.68 5383.48 5894.72 0.28 st1 7900.00 76.86 105.82 3649.78 -2431.76 5473.05 5986.32 0.81 sti 7993.24 76.93 106.24 3670.92 -2456.84 5560.33 6075.85 0.36 stl 8089.13 76.48 107.00 3692.97 -2483.53 5649.75 6168.01 0.45 stl 8183.88 76.55 108.52 3715.07 -2511.64 5737.49 6259.27 0.90 sti 8277.10 77.1 109.29 3736.32 -2541.04 5823.36 6349.41 1.56 stl 8367.43 77.18 109.36 3756.42 -2570.19 5906.46 6436.93 1.00 st1 8462.75 76.67 109.34 3777.98 -2600.95 5994.07 6529.22 0.12 stl 8554.32 76.6 109.66 3799.15 -2630.69 6078.05 6617.79 0.54 stl 8651.92 77.05 109.88 3821.40 -2662.83 6167.48 6712.32 0.35 st1 8• 747.01 77.05 109.69 3842.71 -2694.20 6254.68 6804.51 0.51 stl 8840.76 76.73 109.81 3863.97 -2725.06 6340.61 6895.33 0.19 stl 8936.91 76.54 109.74 3886.20 -2756.71 6428.64 6988.38 0.36 Tt sidetrack#1 tie-in Pb plugback stl sidetrack#1 *projected 23 CANRIG Conoco..- Phillips Alaska.Inc. 2L-320 Measured Inclination Azimuth True N(+)/S(-) E(+)/W(-) Vertical Dogleg Depth ° ° Vertical Section Rate (ft) ( ) ( ) Depth(ft) (ft) (ft) (ft) (°/100ft) st1 9024.94 76.61 110.10 3906.63 -2785.88 6509.14 7073.58 0.21 st1 9124.47 76.15 110.04 3930.07 -2819.07 6600.00 7169.85 0.41 st1 9222.00 75.85 110.45 3953.67 -2851.82 6688.79 7264.06 0.47 st1 9319.84 76.22 110.37 3977.28 -2884.93 6777.77 7358.61 0.51 st1 9414.67 76.61 110.83 3999.55 -2917.36 6864.06 7450.42 0.39 st1 9510.44 76.67 110.46 4021.68 -2950.22 6951.25 7543.25 0.63 st1 9605.72 76.98 110.59 4043.40 -2982.74 7038.13 7635.65 0.38 st1 9701.01 76.49 110.47 4065.26 -3015.27 7124.99 7728.02 0.35 sti 9795.52 76.47 110.75 4087.36 -3047.62 7211.00 7819.56 0.53 st1 9890.32 76.22 110.36 4109.74 -3079.96 7297.25 7911.31 0.29 st1 9985.25 75.96 109.88 4132.56 -3111.66 7383.78 8003.03 0.48 st110081.33 75.85 110.26 4155.96 -3143.64 7471.31 8095.77 0.40 st110175.24 75.72 110.31 4179.02 -3175.20 7556.69 8186.40 0.15 st110270.15 75.59 110.12 4202.53 -3206.97 7642.98 8277.94 0.24 51110365.25 75.46 109.85 4226.31 -3238.44 7729.52 8369.57 0.31 st110460.48 76.16 110.24 4249.65 -3270.09 7816.25 8461.45 0.84 st110555.26 76.28 109.69 4272.23 -3301.52 7902.77 8553.05 0.58 st110650.04 76.16 109.42 4294.80 -3332.33 7989.51 8644.58 0.30 st110745.12 75.97 109.41 4317.70 -3363.00 8076.54 8736.31 0.20 st110839.85 76.15 109.66 4340.52 -3393.74 8163.19 8827.73 0.32 st110934.56 76.29 109.34 4363.08 -3424.45 8249.90 8919.18 0.36 st1 11029.46 76.23 109.33 4385.62 -3454.97 8336.88 9010.80 0.06 511 11124.65 75.97 110.28 4408.49 -3486.28 8423.82 9102.72 1.01 st111219.48 76.11 111.06 4431.37 -3518.76 8509.92 9194.40 0.81 T22746.00 67.33 115.85 2375.66 -519.44 868.27 1007.57 3.74 512 2782.07 67.65 116.26 2389.41 -534.09 898.23 1040.92 1.10 512 2876.40 69.24 116.63 2424.07 -573.16 976.78 1128.64 1.72 512 2966.96 69.46 116.76 2456.01 -611.23 1052.49 1213.37 0.28 512 3066.90 71.66 117.82 2489.27 -654.44 1136.23 1307.57 2.42 st2 3160.02 73.45 117.68 2517.18 -695.80 1214.85 1396.34 1.93 512 3255.54 74.82 116.51 2543.29 -737.64 1296.64 1488.19 1.86 st2 3347.46 74.62 116.92 2567.52 -777.51 1375.85 1576.84 0.48 512 3439.93 75.01 116.93 2591.74 -817.92 1455.41 1666.06 0.41 512 3538.95 74.64 116.23 2617.66 -861.42 1540.50 1761.60 0.47 512 3633.61 74.18 117.35 2643.10 -903.23 1621.53 1852.74 0.50 st2 3729.70 74.55 117.31 2669.00 -945.71 1703.74 1945.24 0.39 st1 sidetrack#1 T2 sidetrack#2 tie-in st2 sidetrack#2 *projected Measured Inclination Azimuth True N(+)/S(-) E(+)/W(-) Vertical Dogleg 24 CANRIG ConocoPhillips Alaska.Inc. 2L-320 Depth (°) (°) Vertical (ft) (ft) Section Rate (ft) Depth (ft) (ft) (°/100ft) 512 3818.10 73.71 116.82 2693.17 -984.40 1779.46 2030.24 1.09 512 3916.63 73.86 116.73 2720.68 -1027.02 1863.92 2121.83 0.18 st2 4011.86 74.21 115.97 2746.88 -1067.66 1945.97 2216.38 0.85 st2 4106.94 74.48 114.50 2772.54 -1106.69 2028.78 2307.93 1.52 5t2 4201.28 74.28 113.63 2797.94 -1143.73 2111.74 2398.75 0.91 5t2 4296.05 74.35 112.47 2823.56 -1179.46 2195.69 2489.89 1.18 5t2 4390.96 74.69 112.62 2848.89 -1214.53 2280.17 2581.23 0.39 512 4484.34 75.05 110.77 2873.27 -1247.85 2363.92 2671.15 1.95 5t2 4578.89 75.37 109.47 2897.40 -1279.29 2449.76 2762.14 1.37 512 4672.50 75.68 109.58 2920.80 -1309.58 2535.19 2852.26 0.35 512 4764.26 76.03 109.57 2943.23 -1339.40 2619.02 2940.73 0.38 st2 4863.26 74.69 110.51 2968.25 -1372.22 2709.01 3036.05 1.64 _ 5124957.36 74.98 110.38 2992.86 -1403.94 2794.11 3126.50 0.34 512 5052.31 74.17 110.47 3018.12 -1435.88 2879.88 3217.65 0.86 5t2 5144..57 74.42 110.50 3043.09 -1466.97 2963.08 3306.10 0.27 st2 5240.30 74.57 110.89 3068.68 -1499.56 3049.38 3398.00 0.42 st2 5336.14 74.07 111.46 3094.59 -1532.89 3135.42 3489.99 0.77 st2 5431.05 74.07 112.07 3120.43 -1566.76 3220.23 3581.10 0.68 5t2 5525.73 74.61 112.09 3145.78 -1601.05 3304.76 3672.15 0.30 st2 5619.93 74.75 111.82 3170.67 -1635.02 3389.03 3762.81 0.31 512 571 5.00 74.69 112.02 3195.72 -1669.25 3474.11 3854.33 0.21 512 5808.23 74.94 112.19 3220.14 -1703.11 3557.47 3944.13 0.32 512 5902.59 74.75 110.94 3244.81 -1736.59 3642.17 4034.97 1.29 512 5997.20 74.25 110.23 3270.09 -1768.64 3727.52 4125.78 0.90 5t2 6092.99 74.68 109.87 3295.75 -1800.28 3814.21 4217.63 0.58 st2 6187.97 74.72 11.34 3320.81 -1831.77 3900.24 4308.81 0.48 512 6282.41 74.82 109.87 3345.62 -1863.10 3985.81 4854.95 0.81 512 6376.37 75.00 109.61 3370.08 -1983.74 4071.20 4489.74 0.33 512 6476.88 73.93 109.70 3394.59 -1923.39 4154.23 4577.43 1.17 512 6564.36 74.17 109.76 3421.10 -1954.71 4241.55 4669.69 0.26 st2 6658.47 73.66 111.53 3474.75 -1986.59 4326.17 4759.77 1.89 512 6757.84 74.12 110.84 3474.75 -2021.09 4415.18 4854.95 0.81 Ste 6850.16 74.29 110.96 3499.88 -2052.78 4498.17 4943.47 0.22 5t2 6945.81 74.55 110.96 3525.57 -2085.73 4584.21 5035.30 0.27 5127040.72 74.79 111.25 3550.67 -2118.69 4669.60 5126.54 0.39 st2 7134.53 74.98 111.51 3575.13 -2151.71 4753.94 5216.85 0.34 512 7229.30 75.19 111.26 3599.52 -2185.10 4839.21 5309.18 0.34 . st2 sidetrack#2 *projected 25 CANRIG ConocoPhillips Alaska.Inc. 2L-320 Measured Inclination Azimuth True N(+)/S(-) E(+)/W(-) Vertical Dogleg Depth ° ° Section Vertical Rate (ft) ( ) ( ) Depth(ft) (ft) (ft) (ft) (°/100ft) st2 7325.00 75.24 111.37 3623.94 -2218.10 4839.21 5308.18 0.34 st2 7418.73 75.47 111.62 3647.64 -2251.96 5009.79 5490.89 0.39 st2 7511.74 74.62 111.12 3671.64 -2284.71 5093.47 5580.49 1.05 st2 7606.16 74.69 111.50 3696.63 -2317.80 5178.30 5671.29 0.40 St2 7699.13 74.81 111.65 3721.08 -2350.78 5261.71 5760.75 0.20 st2 7794.08 74.93 111.19 3745.86 -2384.26 5347.03 5852.16 0.48 st2 7887.70 74.96 111.68 3770.18 -2417.29 5431.19 5942.32 0.51 st2 7984.06 73.97 111.45 3795.99 -2451.42 5517.53 6034.92 1.05 st2 8074.74 74.24 111.79 3820.82 -2483.55 5598.60 6121.92 0.47 st2 8172.77 74.63 112.15 3847.13 -2518.88 5686.18 6216.16 0.53 st2 8266.89 75.07 112.19 3871.73 -2553.16 5770.31 6306.84 0.47 st2 8361.26 74.49 111.15 3896.50 -2586.79 5854.94 6397.68 1.23 st2 8452.52 74.49 111.53 3920.91 -2618.79 5936.84 6485.36 0.40 st2 8548.32 74.16 110.19 3946.79 -2651.63 6023.03 6577.27 1.39 st2 8644.57 74.21 110.67 3973.02 -2683.96 6109.81 6669.49 0.48 st2 8738.61 74.16 110.72 3998.65 -2715.93 6194.45 6759.64 0.07 st2 8833.33 74.18 109.91 4024.49 -2747.57 6279.91 6850.37 0.82 st2 8927.94 74.36 110.08 4050.14 -2778.71 6365.49 6940.99 0.26 st2 9022.43 74.51 110.43 4075.49 -2810.22 6450.89 7031.61 0.39 st2 9119.44 75.68 111.12 4100.45 -2843.48 6538.53 7125.01 1.39 st2 9214.82 75.72 110.89 4124.00 -2876.60 6624.82 7217.13 0.24 st2 9309.63 74.51 110.24 4148.36 -2908.79 6710.60 7308.40 1.44 st2 9404.70 75.76 110.26 4172.75 -2940.60 6796.81 7399.87 1.31 st2 9500.74 75.84 109.63 4196.31 -2972.35 6884.33 7492.51 0.64 st2 9595.74 74.33 109.52 4220.76 -3003.11 6970.82 7583.79 1.59 st2 9691.49 74.44 110.28 4246.53 -3034.50 7057.53 7675.54 0.77 st2 9784.56 74.95 111.53 4271.10 -3066.53 7141.39 7765.00 1.41 st2 9873.82 75.34 111.70 4293.98 -3098.31 7221.60 7851.06 0.47 st2 9972.47 74.65 111.49 4319.52 -3133.38 7310.20 7946.11 0.73 st210068.50 73.69 111.90 4345.72 -3167.53 7396.04 8038.27 1.08 st210164.51 73.97 112.00 4372.46 -3202.00 7481.57 8130.29 0.31 st210259.29 74.37 111.88 4398.31 -3236.07 7566.15 8221.29 0.44 st210352.17 74.60 111.86 4423.16 -3269.41 7649.20 8310.59 0.25 st210445.83 74.96 111.49 4447.74 -3303.01 7733.10 8400.76 0.39 st210541.32 73.99 110.33 4473.30 -3336.07 7818.95 8492.46 1.79 st210636.42 74.18 109.98 4499.38 -3367.58 7904.81 8583.50 0.41 st210735.31 74.81 110.25 4525.82 -3400.35 7994.29 8678.34 0.69 st2 sidetrack#2 *projected 26 CAINRIG Conoc Phillips Alaska.Inc. 2L-320 Measured Inclination Azimuth True N(+)/S(-) E(+)/W(-) Vertical Dogleg Depth ° ° Vertical Section Rate (ft) ( ) ( ) Depth (ft) (ft) (ft) (ft) (°/100ft) st210829.65 75.56 110.41 4549.94 -3432.04 8079.81 8769.15 0.81 st210923.36 74.31 110.19 4574.30 -3463.43 8164.68 8859.24 1.35 stz 11019.31 74.82 110.02 4599.83 -3495.23 8251.53 8951.30 0.56 st211114.05 75.26 109.92 4624.29 -3526.49 8337.55 9042.38 0.48 st211205.83 74.69 110.93 4648.08 -3557.42 8420.62 9130.65 1.23 st211304.75 75.25 111.10 4673.73 -3591.68 8509.80 9225.87 0.59 st211392.60 74.88 111.06 4696.38 -3622.21 8589.01 9310.48 0.42 st2 11491.91 74.12 111.72 4722.92 -3657.11 8678.11 9405.91 1.00 st211588.96 74.30 111.62 4749.32 -3691.59 8764.90 9499.07 0.21 st211677.13 74.00 111.36 4773.40 -3722.67 8843.82 9583.66 0.44 st211775.28 73.45 111.02 4800.91 -3756.72 8931.67 9677.59 0.65 st211870.25 72.90 111.03 4828.40 -3789.34 9016.52 9768.20 0.58 st211965.39 74.21 112.55 4855.33 -3823.21 9101.24 9859.24 2.06 st212059.64 74.52 112.06 4880.74 -3857.66 9185.21 9949.84 0.60 st212153.99 74.84 112.40 4905.66 -3892.08 9269.44 10040.68 0.49 st212249.75 75.38 112.22 4930.27 -3927.21 9355.06 10133.06 0.59 st212341.93 74.44 111.56 4954.27 -3960.40 9437.64 10221.87 1.23 st212437.35 74.34 111.35 4979.94 -3994.01 9523.18 10313.52 0.24 st212531.36 74.64 110.96 5005.08 -4026.70 9607.66 10403.83 0.51 st212624.83 74.96 111.24 5029.59 -4059.18 9691.81 10493.74 0.45 st212723.63 75.57 111.34 5054.72 -4093.87 9780.84 10589.02 0.63 st212817.22 75.93 111.02 5077.76 -4126.64 9865.42 10679.45 0.51 st212914.72 73.78 110.32 5103.23 -4159.86 9953.47 10773.20 2.31 st213008.88 74..2 110.12 5129.18 -4191.15 10038.40 10863.30 0.51 stz 13103.27 74.73 110.24 5154.45 -4222.52 10123.77 10953.83 0.55 st2 13197.41 74.80 112.07 5179.19 -4255.30 10208.47 11044.38 1.88 st213289.56 74.26 115.48 5203.77 -4291.09 10289.74 11133.13 3.61 st2 13388.01 74.09 118.43 5230.63 -4334.02 10374.15 11227.81 2.89 st213480.94 72.93 122.54 5257.02 -4379.21 10450.93 11316.58 4.42 st213578.39 71.34 127.84 5286.93 -4432.62 10526.70 11408.01 5.43 st213622.88 71.45 129.78 5301.12 -4459.04 10559.56 11449.07 4.14 st2 13669.61 71.10 132.51 5316.13 -4488.16 10592.88 11491.72 5.58 st213721.10 71.73 134.05 5332.54 -4521.62 10628.41 11538.23 3.09 st213764.25 71.78 136.82 5346.05 -4550.81 10657.16 11576.79 6.10 st213813.63 71.90 138.97 5361.44 -4585.62 10688.62 11620.22 4.14 st213862.49 71.93 142.29 5376.61 -4621.52 10718.08 11662.31 6.46 st213910.32 72.42 143.63 5391.26 -4657.87 10745.51 11702.77 2.86 st2 sidetrack#2 *projected 27 CANRIG ConocoPhillips Alaska.Inc. 2L-320 Measured Inclination Azimuth True N(+)/S(-) E(+)/W(-) Vertical Dogleg Depth ° ° Vertical Section Rate (ft) Depth (ft) (ft) (ft) (ft) (°/100ft) st213951.10 72.46 145.69 5403.56 -4689.58 10767.99 11736.78 4.82 512 14005.19 72.82 146.84 5419.70 -4732.51 10796.66 11781.21 2.14 stz 14046.$9 73.02 147.34 5431.95 -4765.98 10818.32 11815.22 1.24 512 14099.51 73.55 148.36 5447.17 -4808.62 10845.12 11857.85 1.96 51214144.63 73.70 150.62 5459.97 -4845.90 10867.09 11893.79 4.87 512 1 41 95.02 73.90 153.13 5474.03 -4888.57 10889.90 11932.83 4.80 51214241.15 72.94 156.33 5487.19 -4928.54 10908.77 11967.15 6.97 s1214284.13 72.24 157.85 5500.06 -1966.31 10924.73 11997.89 3.75 51214334.85 70.79 158.13 5516.14 -5010.91 10942.76 12033.46 2.91 51214428.77 69.09 157.76 5548.35 -5092.67 10975.89 12098.72 1.85 51214523.72 68.02 157.32 5583.06 -5174.35 11009.65 12164.52 1.21 _ 51214620.51 67.94 157.79 5619.35 -5257.28 11043.91 12231.31 0.46 st214712.61 67.95 157.80 5653.94 -5336.31 11076.17 12294.61 0.01 st214808.14 67.91 158.06 5689.83 -5418.35 11109.43 12360.12 0.26 St214904.19 67.94 157.78 5725.93 -5500.83 11142.89 12426.00 0.27 St214999.37 68.29 158.21 5761.41 -5582.72 11175.98 12491.28 0.56 51215049.00 68.29 158.21 5779.77 -5625.53 11193.10 12525.25 0.00 512 sidetrack#2 *projected 28 CANRIG « R 0 0 0 0 0 0 R I k k 2 I k 2 2 q / ƒ I n i 0 3 & 6 / a_ z - 9 2 \ § « x 033 \ 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CO(I) 0) M CO N M CA CD sr CO M %t CO CO CO 0) O N U1 u7 ti M N M 0p.— 3aDODODCs D000DODaDaDOD j 0Tr0TrTrvCOvvvvvvvTrTr a OD OD of o CD CO CO CO O it upa) upu) COCD0000N- N- (OC N. N. nr- a 66noirnDiDi66666o0 oioirnoioirnoirnoioioioiaiairnoi w V) CO m � aocooDODoo t TrinT- ipQDQD .- pCO isCOr CD) CA 0 C) C) C) ' C) NU) - UMMMMM Cs Cs 0030000OOI� N Tr - h r- 0 ,- � NNrv � vv CYC MCOM � 000 N- N- 0 � � � Cn Cn 0 a) u7 M O O Tr Tr Tr Tr T' Tr (a N N M M ( ? 't V V Tr tC) t\ 2 O C Tr Tt co co L S - - - - - - - O M CD CD M sr r CA CO Z O r- N- r N- N- .r U) u) CC) O - N U) CO CD 0) O v CA Q) +'' CO CO CO CO CO TY CO O r- Tr Tr T' Tr Tr N 0. T' u7 N O CO Co N O to CD CO CO C D to O :ii �' V CO Cf) N u7 NNN N N y N- v N N O O s- 0 .- s- s- N M Tr up u, N 0 Tr Tr Tr Tr Tr 0 O r O N 0 Cl V CD r 0) O CD * * * * * * * * * * * * _I T rQ O O O O O O O O O O O O O O CL r 0 0 0 O 0 0 0 0 0 0 0 0 0 O O O O N N N N N N N N N N N N N N N N N IN N N N N I- CCI N N N F- Ca N CV N N N 0 N C S U). NMNrCC) CSD CO CDOc- V- tcorsCOCDOr' NMTCC) COr- OCAO 'O N N N N N N N N N M M `- N M tO t0 CO d) 7 N N N 7 N (NJ N N N '�' N 2 'AlNNNNNINNNNN M M 0 y C N CD C (6 N � co ` U co 5 2 E > '5 o >T • W U u H ❑ CU U W o rn m 2 E o tt^^ Y M � oU � J 8. 0U 'c II Cl _ a N ▪ 2 O u U V u II Ov) < w o �. c5oo NYU) N N U II II LL LL ti p II 750 COLLLL lt U Att ›N u) •- oo 0 y N N w o • a, , a > 2LLa L II II II II > (1) > a a :E > a >- 6 DAILY REPORTS 34 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Ray Springer Scott Heim Date: 12/31/2010 Time: 00:00 Current Depth (MD): 451' Current Drilling Ahead Current Depth (TVD): 451' Operations: 24 hr Footage (MD): 341' Drilling Parameters ROP: Current: 80.6 Max: 237 Torque: Current: N/A Max: N/A WOB: Current N/A Max: N/A RPM: Current: 33 Max: 40 PP: Current: 1145 Max: 1320 Lag: Strokes: 607 Time: 4.7 min Surf-Surf: Strokes: 8821 Time: 67.9 min ECD: Current: - Max: - Mud Properties @ 451' MW: 8.9 FV: 268 PV: 34 YP: 47 FL: 11.2 Gels: , 20/37/ Sol: 2% pH: 9.3 Cr: 200 Ca++: 40 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: _ 2u Max: 25u Depth (MD/TVD): 309'/309' Avg BG : 1u Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 N/A 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%Sand, 30% Conglomerate Sand Last 24 hrs: N/A Function test diverter.Test surface lines. Clean out conductor and dilled ahead to 306'. Operational Summary: Circulated hole clean. POOH. Picked up remaining BHA and RIH. Drilling ahead to 451'@ midnight,gyro every stand. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,130.00 CANRIG IJRII.I.Irvf Trn iruirr f.rii. ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Ray Springer Scott Heim Date: 01/01/2011 Time: 00:00 Current Depth (MD): 1800' Current Drilling Ahead Current Depth (TVD): 1751' Operations: 24 hr Footage (MD): 1349' Drilling Parameters ROP: Current: 134 Max: 328 Torque: Current: N/A Max: N/A WOB: Current 24.4 Max: 30.9 RPM: Current: 40 Max: 43 PP: Current: 1507 Max: 1771 Lag: Strokes: 2755 Time: 23 min Surf-Surf: Strokes: 10653 Time: 88.8 min ECD: Current: - Max: - Mud Properties @ 1671' MW: 9.1 FV: 245 PV: 47 YP: 51 FL: 8.8 Gels: 38/65/ Sol: 4% pH: 9.2 CC: 100 Ca++: 40 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 451u Max: 454u Depth (MD/TVD): 1800'/1751' Avg BG : 167u Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 N/A Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases 401 1484'/1460' 99905.16 - - - 2.3667 - 2.4611 Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 • nC5 1376'/1358' 2252 557158.19 26.484 2.696 3.432 0.000 3.432 0.000 Lithologies: Current: 50%Sand, 50% Claystone Last 24 hrs: Sand, Claystone, Conglomerate, Sandstone. Operational Summary: Drilling ahead,gyro every stand up to 1670' Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG Conoc Phillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Ray Springer Scott Heim Date: 01/02/2011 Time: 00:00 Current Depth (MD): 2242' Current Wait on weather Current Depth (TVD): 2102' Operations: 24 hr Footage (MD): 442' Drilling Parameters ROP: Current: 0 Max: 276 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 42 RPM: Current: 0 Max: 42 PP: Current: 230 Max: 2203 Lag: Strokes: 3328 Time: 24.1 Surf-Surf: Strokes: 10072 Time: 73 min ECD: Current: - Max: - Mud Properties @ 1671' MW: 9.3 FV: 205 PV: 40 YP: 39 FL: 7.2 Gels: 25/49/ Sol: 5% pH: 9.0 Cr: 100 Ca++: 40 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 20u Max: 772u Depth (MD/TVD): 1863'/1808' Avg BG : 20u Gas Events Trip Gas Depth (MD/TVD) _ Cl C2 C3 iC4 nC4 iC5 nC5 N/A 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 1863'/1808' 772 201386.515 - 1.046 1.273 3.274 - - Lithologies: Current: 90%Sand, 10% Claystone Last 24 hrs: Sand, Claystone, Conglomerate, Sandstone. Drilled to 2246'and shut down at roughly 6am. Waiting on weather—phase 3 Operational Summary: conditions. Circulating at 3 to 6 bpm. Reciprocating pipe. Rotating at 30 rpm. Stand back one stand. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,130.00 CANRIG Daua ieo T,,.nw,ian..,.Lrn. ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Ray Springer Scott Heim Date: 01/03/2011 Time: 00:00 Current Depth (MD): 2755' Current Work dog leg Current Depth (TVD): 2378' Operations: 24 hr Footage (MD): 513' Drilling Parameters ROP: Current: 0 Max: 209 Torque: Current: N/A Max: N/A WOB: Current 0 _ Max: 45 RPM: Current: 0 Max: 42 PP: Current: 1496 Max: _ 2264 Lag: Strokes: 4104 Time: 26 Surf-Surf: Strokes: 11043 Time: 69'9 min ECD: Current: - Max: - Mud Properties @ 2755' MW: 9.4 FV: 188 PV: 43 YP: 52 FL: 6 Gels: 22/45/ Sol: 5% pH: 9.0 Cr: 100 Ca++: 40 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 340u Max: 553u Depth (MD/TVD): 2702'/2359' Avg BG : 250u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) 1594 2753'/2378' 503177.6 - - 15.9094 - 21.4168 1.4248 Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) 123 2543'/2284' 43968.796 166.858 15.580 9.743 11.070 20.813 14.033 195 _ 2599/2312' 97578.657 34.637 15.008 5.619 21.983 27.602 27.900 353 2702/2359' 167974.684 20.767 24.916 22.614 3.588 26.202 31.580 Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 80% Claystone, 10%Sand, 10% Conglomeratic Sand Last 24 hrs: Sand, Claystone, Conglomerate, Sandstone. Shut down due to weather until 7am. Drilling ahead to 2755'to TD surface hole. CBU. Operational Summary: Back ream out of the hole to -1500'. RIH. Pumps off for-1 hour 10 min while running in hole and saw 1594u gas.Wash & ream to bottom.Work dog leg. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Ray Springer Scott Heim Date: 01/04/2011 Time: 00:00 Current Depth (MD): 2755' Current RIH Casing Current Depth (TVD): 2378' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 0 RPM: Current: 0 Max: 39 PP: Current: 34 Max: 1451 Lag: Strokes: 4104 Time: 26 Surf-Surf: Strokes: 11043 Time: 69'9 min ECD: Current: - Max: - , Mud Properties @ 2755' MW: 9.4 FV: 152 PV: 44 _ YP: 37 FL: 6 Gels: l 18/38/ Sol: 4% pH: 8.9 Cr: 100 Ca++: 40 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 118u Max: 1884u Depth (MD/TVD): 1120'/1095' Avg BG : 145u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) 1884 1120'/1095' 376789.223 - - - - 6.6181 15.119 Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG _ Cl C2 C3 iC4 nC4 iC5 nC5 257072300' 1206 286264.109 - - - - - 17.540 Lithologies: Current: 80%Claystone, 10%Sand, 10%Conglomeratic Sand Last 24 hrs: Sand, Claystone, Conglomerate, Sandstone. CBU. Pumped 50 bl 11.4 ppg nut plug sweep around. Circulate hole clean. Pump dry Operational Summary: job. POOH. Lay down BHA. Rig up and run 10 3/4"casing. On bottom with casing at midnight. Preparing to make up cement head and circulate. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG 1)arr.r.r HTu-r ii nry I.rri. ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Ray Springer Scott Heim Date: 01/05/2011 Time: 00:00 Current Depth (MD): 2755' Current Nipple up BOP's Current Depth (TVD): 2378' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 1205 Lag: Strokes: 4104 Time: 26 Surf-Surf: Strokes: 11043 Time: 69'9 min ECD: Current: - Max: - Mud Properties @ 2755' MW: 9.0 FV: 50 PV: 13 YP: 11 FL: 0 Gels: 13/18/19 Sol: - pH: - Cr: - Ca++: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: 1048u Depth (MD/TVD): 2755'/2378' Avg BG : Ou Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 80%Claystone, 10%Sand, 10%Conglomeratic Sand Last 24 hrs: Sand, Claystone, Conglomerate, Sandstone. RIH casing to 2745'. Rig up cement head. Circulate and condition mud. Pump cement job beginning with 40bbls of chemical wash,followed by 50bbls of mud push,followed Operational Summary: by 335bb1 of 11.0 ppg cement,followed by 82 bbls of 12.0 ppg cement,followed by 245 bbls of 9.0 ppg OBM to bump the plug. CIP at 5:15am. Rig down cementers. Nipple down diverter. Nipple up BOP's 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: 01/06/2011 Time: 00:00 Current Depth (MD): 2755' Current Picking up drill pipe Current Depth (TVD): 2378' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 4104 Time: 26 Surf-Surf: Strokes: 11043 Time: 69"9 min ECD: Current: - Max: - Mud Properties @ 2755' MW: 8.9 FV: 59 PV: 18 YP: 15 FL: 6.4 Gels: 24/32/34 Sol: 5.28% pH: - Cr: 55000 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): 0'/0' Avg BG : Ou Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 80%Claystone, 10% Sand, 10%Conglomeratic Sand Last 24 hrs: Sand, Claystone, Conglomerate, Sandstone. Operational Summary: Niple up and test BOP's. Loading drill pipe to the pipe shed. Pickup drill pipe. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,130.00 CANRIG Ilnii.i.irvr-Tr.irvrri.rrz:r-I.rir. ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Scott Heim Date: 01/07/2011 Time: 00:00 Current Depth (MD): 2755' Current Picking up BHA Current Depth (TVD): 2378' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 4104 Time: 26 Surf-Surf: Strokes: 11043 Time: 6min9'9 ECD: Current: - Max: - Mud Properties @ 2755' MW: 8.9 FV: 59 PV: 18 YP: 15 FL: 6.3 Gels: 23/26/29 Sol: 5.32% pH: - Cr: 54000 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): 070' Avg BG : Ou Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 80% Claystone, 10%Sand, 10%Conglomeratic Sand Last 24 hrs: Sand, Claystone, Conglomerate, Sandstone. Operational Summary: Pick up drill pipe. Service and grease top drive, draw works, pipe skate. Continue to pick up drill pipe. Slip and cut drilling line. Pick up BHA and RIH. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,130.00 CANRIG Dui�wr Tuvanu,c,Lrn. ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Scott Heim Date: 01/08/2011 Time: 00:00 Current Depth (MD): 4082' Current Drilling Ahead Current Depth (TVD): 2702' Operations: 24 hr Footage (MD): 1704' Drilling Parameters ROP: Current: 216 Max: 349 Torque: Current: N/A Max: N/A WOB: Current N/A Max: N/A RPM: Current: 93 Max: 94 PP: Current: 3383 Max: 3493 Lag: Strokes: 2848 Time: 14.5min Surf-Surf: Strokes: 8140 Time: 41.5min ECD: Current: - Max: - Mud Properties @ 3776' MW: 8.9 FV: 68 PV: 19 YP: 16 FL: 6.0 Gels: 23/27/30 Sol: 5.32% pH: - Cr: 55000 Ca++: - MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 1529u Max: 1972u Depth (MDR-VD): 4082'/2702' Avg BG : 100u Gas Events Trip Gas Depth Cl C2 C3 IC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) 2093 3491'/2565' 638674.8 1555 80.0466 6.1487 6.1487 21.5856 2300 3585'/2590' 671197.8 971.25 39.729 8.933 8.933 11.639 2320 367872611' 411331.9 897.5 13.243 5.1971 1.1601 3.6025 1352 3775'/2630' 342461.4 396.1 21.31 4.1374 3.744 3.144 1554 3868'/2655' 386149.2 452.8 27.31 5.1564 4.896 4.121 580 3954'/2670' 62726.07 14.6409 24.8268 15.842 13.6259 1972 4044'/2695' 620277.6 2815 25.8974 7.0724 6.2814 4.8568 Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 3400'/2545' 340 56606.098 666.612 20.675 10.508 19.912 Lithologies: Current: 70% Siltstone, 20%Claystone, 10% Sand Last 24 hrs: Siltstone, Claystone. Sand, Sandstone. Continue to RIH picking up singles. Circulate and condition mud at 2644'. Perform Operational Summary: casing test to 3000 psi. Drill out float,cement, shoe,and 20'of new formation. Perform FIT test to 12 ppg EMW. Drilling ahead to 4082'at 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: 01/09/2011 Time: 00:00 Current Depth (MD): 5006' Current Short trip to shoe Current Depth (TVD): 2924' Operations: 24 hr Footage (MD): 924' Drilling Parameters ROP: Current: 0 Max: 331 Torque: Current: N/A Max: N/A WOB: Current N/A Max: N/A RPM: Current: 0 Max: 94 PP: Current: 129 Max: 3490 Lag: Strokes: 3493 Time: 18.4min Surf-Surf: Strokes: 8379 Time: 44.1 min ECD: Current: - Max: - Mud Properties @ 5006' MW: 9.5 FV: 70 PV: 19 YP: 18 FL: 6.2 Gels: 22/32/35 Sol: 6.79% pH: - Cr: 39000 Ca++: - MW Change: Depth: 5006 From: 8.9 To: 9.5 Reason: Took kick Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 41u Max: 2372u Depth (MD/TVD): 5006'/2924' Avg BG : 50u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth C1 C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) 1000 4320 247828.3 840 18.5402 1143 4407 263099.1 825 10.153 4.9292 5.5686 8.0272 1270 4526 395603.2 1192.5 16.333 2.8397 3.4402 2056 4610 1709 4685 549500.3 1847.5 34.7261 5.465 2.0784 1.6864 455 4911 329584.5 1304.415 94.848 75.471 22.54 1222 5004 317816.2 702.5 11.2566 4.1185 25.1255 Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 3400'/2545' 340 56606.098 666.612 20.675 10.508 19.912 Lithologies: Current: 80% Siltstone, 10%Claystone, 10% Sand Last 24 hrs: Siltstone, Claystone. Sand, Sandstone. Drilling to 4611', circulating while repairing rod wash pump. Drilling to 5006'. Drop ball to open well commander. CBU for 5300 stks. Flow check well—well static. Begin short Operational Summary: trip. POOH 4 stands. Take kick. Shut in well. Circulate out gas. Weight up to 9.3 ppg. Open well. Drop ball to close well commander. RIH. CBU.Weight up to 9.5ppg. Monitor well—Static. Short trip to shoe. 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: 01/10/2011 Time: 00:00 Current Depth (MD): 6952' Current Drilling ahead. Current Depth (TVD): 3413' Operations: 24 hr Footage (MD): 1946' Drilling Parameters ROP: Current: 191 Max: 342 Torque: Current: N/A Max: N/A WOB: Current 5.1 Max: 46.9 RPM: Current: 92 Max: 93 PP: Current: 3729 Max: 4089 Lag: Strokes: 4857 Time: 25.8min Surf-Surf: Strokes: 10040 Time: 53.4min ECD: Current: - Max: - Mud Properties @ 6899' MW: 9.5 FV: 56 PV: 21 YP: 14 FL: 4.9 Gels: 27/32/33 Sol: 9.99% pH: - Cr: 39000 Ca++: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 20.9u Max: 45u Depth (MD/TVD): 6599'/x' Avg BG : 26u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 90% Siltstone, 10%Sand Last 24 hrs: Siltstone, Claystone. Sand, Sandstone. Continue to POOH. CBU at the shoe. Circulate at 2 bpm while cleaning up rig. Monitor Operational Summary: well—well static. RIH.Wash and ream from 4911'to 5006'. Drilling ahead to 6952 at midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Scott Heim Date: 01/11/2011 Time: 00:00 Current Depth (MD): 8503' Current Drilling ahead. Current Depth (TVD): 3784' Operations: 24 hr Footage (MD): 1551' Drilling Parameters ROP: Current: 176 Max: 240 Torque: Current: N/A Max: N/A WOB: Current 19.2 Max: 26.6 RPM: Current: 92 Max: 96 PP: Current: 3810 Max: 4009 Lag: Strokes: 5936 Time: 34.5min Surf-Surf: Strokes: 12411 Time: 72.2min ECD: Current: - Max: - Mud Properties @ 8315' MW: 9.6 FV: 64 PV: 23 YP: 13 FL: 5.0 Gels: 21/31/32 Sol: 10.44% pH: - Cr: 40000 Ca++: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 18.2u Max: 40u Depth (MD/TVD): 8321'/x' Avg BG : 26u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) 23u 8031'/ - - - - - - Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 60%Siltstone, 30%Sand, 10%Claystone Last 24 hrs: Siltstone, Claystone. Sand. Drilling to 8031'. Drop ball and open well commander. Circulate 9200 stks. Minor Operational Summary: increase in cuttings at shakers. POOH to 4801'. Circulate 4800 stks. RIH to 8031'. Drilling ahead to 8503'at midnight. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips 1 Alaska,Inc. Tarn 2L-312 Daily Report Report for: Larry Hill Guy Heim Date: 01/12/2011 Time: 00:00 Current Depth (MD): 10886' Current Drilling ahead. Current Depth (TVD): 4375' Operations: 24 hr Footage (MD): 2383' Drilling Parameters ROP: Current: 135 Max: 271 Torque: Current: N/A Max: N/A WOB: Current 5.8 Max: 44.5 _ RPM: Current: 95 _ Max: 95 PP: Current: 3991 Max: 4077 _ Lag: Strokes: 5936 Time: 34.5min Surf-Surf: Strokes: 12411 Time: 72.2min ECD: Current: - Max: - Mud Properties @ 8315' MW: 9.5 FV: 71 PV: 29 YP: 16 FL: 4.4 Gels: 20/31/32 Sol: 12% pH: - Cr: 36000 Ca++: - MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: , 32u Max: 82u Depth (MD/TVD): 10568'/x' Avg BG : 34u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 80% Siltstone, 10%Claystone Last 24 hrs: Siltstone, Claystone. Sand. Operational Summary: Drilled F/8,503'T/10,886'. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/13/2011 Time: 00:00 Current Depth (MD): 11445' Current Tripping in hole. Current Depth (TVD): 4541' Operations: pp g 24 hr Footage(MD): 559' Drilling Parameters ROP: Current: 0 Max: 169 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 52 RPM: Current: 0 Max: 95 PP: Current: _ 0 Max: 3750 Lag: Strokes: 0 Time: 0 Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 8315' MW: 9.5 FV: 71 PV: 34 YP: 17 FL: 4.8 Gels: 21/34/35 Sol: 12% pH: - Cr: 35000 Ca`+: - MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: 44u Depth (MD/TVD): 10962'/x' Avg BG : 30u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) _ TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100% Siltstone, Last 24 hrs: Siltstone, Claystone. Operational Summary: Drilled F/10,886'to 11,445' Back Reamed out of Hole to 7,939' and circulated sweep. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/14/2011 Time: 00:00 Current Depth (MD): 11445' Current POOH. Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: N/A Max: N/A WOB: Current _ 0 Max: N/A RPM: Current: 0 Max: 76 PP: Current: 0 Max: 3500 Lag: Strokes: 0 Time: N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 8315' MW: _ 9.5 FV: 73 PV: 27 YP: 16 FL: 5.0 Gels: 22/33/34 Sol: 12% pH: - Cr: 46000 Ca++: - MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: 125u Depth (MD/TVD): 10962'/x' Avg BG : 3u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100% Siltstone, Last 24 hrs: Siltstone, Claystone. Operational Summary: Begin RIH and encountered stuck DP @ 10,360'and P/O.Jarred free begin POOH. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG IIIIJJNI'T;'iivniin: I.rii. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/15/2011 Time: 00:00 Current Depth (MD): 11445' Current Monitoring Flow Back Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: N/A Max: N/A WOB: Current 0 Max: N/A RPM: Current: 0 Max: 76 PP: Current: 0 Max: 3500 Lag: Strokes: 0 Time: N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 8315' MW: 9.5 FV: 71 PV: 29 YP: 17 FL: 5.0 Gels: 21/29/32 Sol: 14% pH: - Cr: 47000 Ca++: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: 143bbls Gas Data Ditch Gas: Current: Ou Max: 125u Depth (MD/TVD): 10962'/x' Avg BG : 3u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Siltstone, Last 24 hrs: Siltstone, Claystone. Operational Summary: POOH to 3,050' P/O and encounter stuck D/P and P/O ream to 2,910'flow check well and observe flow back. Currently monitoring well. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG I)PII.I.INI'TrA'll\(IISr.Y I.rit ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/16/2011 Time: 00:00 Current Depth (MD): 11445' Current RIH Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: N/A Max: N/A WOB: Current 0 Max: N/A RPM: Current: 0 Max: 76 PP: Current: 0 Max: N/A Lag: Strokes: 0 Time: N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 8315' MW: 9.5 FV: 68 PV: 22 YP: 16 FL: 5.1 Gels: 21/18/30 Sol: 12% pH: - Cr: 36500 Ca++: MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: 11bbls Gas Data Ditch h Gas: Current: 3u Max: 6u Depth (MD/TVD): 10962'/x' 1 1u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) _ TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Siltstone, Last 24 hrs: Siltstone, Claystone. Operational Summary: Monitored well @ 2,745' POOH to 1,887'and monitor well. POOH download MWD UD BHA. Monitor well and test BOP. P/U BHA#300 and begin RIH. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips , • Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/17/2011 Time: 00:00 Current Depth (MD): 11445' Current RIH Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: N/A Max: N/A WOB: Current 0 Max: N/A RPM: Current: 75 Max: 96 PP: Current: 2077 Max: 3828 Lag: Strokes: 0 Time: N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Pro erties @ 8315' MW: 9.5 FV: 75 PV: 23 YP: 17 FL: 5.2 Gels: 21/27/36 Sol: 14% pH: - Cr: 43000 Ca+': - MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: 11 bbls Gas Data Ditch Gas: Current: 44u Max: 374u Depth (MD/TVD): 10962'/x' Average: 42u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Siltstone, Last 24 hrs: Siltstone, Claystone. RIH and S/C D/L Continue to RIH to 9,669'and begin reaming to btm. Cont to ream Operational Summary: encountering stuck pipe and P/O @ 10,220—10,'free jarring as necessary. Continue to reciprocate tight spot at the time of report. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/18/2011 Time: 00:00 Current Depth (MD): 11445' Current Standing By Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: N/A Max: N/A WOB: Current _ 0 Max: N/A RPM: Current: 0 Max: 91 PP: Current: 0 Max: 3672 Lag: Strokes: 0 Time: N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 8315' MW: 9.7 FV: 72 PV: 25 YP: 18 FL: 5.2 Gels: 16/37/ Sol: 11% pH: - Cr: 37500 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: N/A Max: 127u Depth (MD/TVD): 10962'/x' Average: 2u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) _ Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Siltstone, Last 24 hrs: Siltstone, Claystone. Operational Summary: Work drill string free and POOH to 9,316'experience overpull and P/O cannot establish circulation,rotation or block movement. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/19/2011 Time: 00:00 Current Depth (MD): 11445' Current Running Wireline Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: N/A Max: N/A WOB: Current 0 Max: N/A RPM: Current: 0 Max: 0 PP: Current: 0 Max: N/A Lag: Strokes: 0 Time: N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 11445' MW: 9.8 FV: 76 PV: 25 YP: 18 FL: 4.8 Gels: 15/43/45 Sof: 12% pH: - CF: 37500 Ca++: - MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: N/A Max: 0 Depth (MD/TVD): 10962'/x' Average: 0 Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Siltstone, Last 24 hrs: Siltstone, Claystone. Operational Summary: RIH with wireline assy to 3,200' POOH to surface and screw into T/D jar and R/U wireline and continue to RIH at time of report. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG )IIII.I.IN(Triiinu.::r l.ri. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/20/2011 Time: 00:00 Current Depth (MD): 11445' Current Running Wireline Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: N/A Max: N/A WOB: Current 0 Max: N/A RPM: Current: 0 Max: 0 PP: Current: 0 Max: N/A Lag: Strokes: 0 Time: N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 11445' MW: 9.8 FV: 73 PV: 24 YP: _ 16 FL: 4.9 Gels: 16/35/31 Sol: 12% pH: - Cr: 36000 Ca++: - MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: N/A Max: 0 Depth (MD/TVD): 10962'/x' Average: 0 Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100% Siltstone, Last 24 hrs: Siltstone, Claystone. RIH with wireline to 8,700'and have wireline tractor unable to continue any further. Operational Summary: POOH to 7,250'and unable to POOH any further due to tractor malfunction. Wait for Schlumberger to arrive and R/U retrieval equipment. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/21/2011 Time: 00:00 Current Depth (MD): 11445' Current POOH Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: N/A Max: N/A —PP: Current 0 Max: _ N/A RPM: Current: 0 Max: 0 PP: Current: 0 Max: 2843 Lag: Strokes: 0 Time: N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 11445' MW: 9.8 FV: 69 PV: 30 YP: 15 FL: 4.7 Gels: 19/44/46 Sol: 12% pH: - Cr: 34500 Ca++: MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: N/A Max: 198 Depth (MD/TVD): 10962'/x' Average: 30U/w circ Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks _ Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Siltstone, Last 24 hrs: Siltstone, Claystone. Operational Summary: R/U Schlumberger wireline and RIH to 9,113'and activate charge severing D/P .Circ sweep and flow check well. Begin POOH Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG 1)ci i.i.inr Tri-iiin:s I.riU ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/22/2011 Time: 00:00 Current Depth (MD): 11445' Current Testing BOP's Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: _ N/A Max: N/A WOB: Current 0 Max: N/A RPM: Current: _ 0 Max: 0 PP: Current: 0 Max: N/A Lag: Strokes: 0 Time: _ N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 11445' MW: 9.8 FV: 73 PV: 27 YP: 15 FL: 4.6 Gels: 17/40/43 Sol: 12% pH: - Cr: 35000 Ca": - MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: N/A Max: 198 Depth (MD/TVD): 10962'/x' Average: NA Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Siltstone, Last 24 hrs: Siltstone, Claystone. Operational Summary: Finish POOH.Test BOP's replacing IBOP Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/23/2011 Time: 00:00 Current Depth (MD): 11445' Current Fishing Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: N/A Max: N/A WOB: Current 0 Max: N/A RPM: Current: 48 Max: 96 PP: Current: 216 Max: 2982 Lag: Strokes: 0 Time: N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 11445' MW: _ 9.9 FV: 83 PV: 29 YP: 15 FL: 4.9 Gels: 14/48/49 Sol: 12% pH: - Cr: 34500 Ca++: MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 1u Max: 100u Depth (MD/TVD): 10962'/x' Average: 5u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Siltstone, Last 24 hrs: Siltstone, Claystone. Complete BOP testing and M/U fishing assy. RIH to 2,968' and S/C drill line. RIH to Operational Summary: 9,113' encountering tight hole and P/O. Continue to work tight spot at the time of report. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG i)aii.i.irv<Traii>i.rt.v I.rn. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/24/2011 Time: 00:00 Current Depth (MD): 11445' Current RIH w tubing on DP Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: N/A Max: N/A WOB: Current 0 Max: N/A RPM: Current: 0 Max: 48 PP: Current: 0 Max: 1478 Lag: Strokes: 0 Time: N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 11445' MW: 9.8 FV: 82 PV: 26 YP: 14 FL: 5.0 Gels: 19/45/46 Sol: 12% pH: - Cr: 35000 Ca++: MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 1u Max: N/A Depth (MDR-VD): 10962'/x' Average: 1u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Siltstone, Last 24 hrs: Siltstone, Claystone. Operational Summary: Attempts at fishing fail. POOH L/D fishing assy. R/U 3.5"tubing running equipment and begin RIH. R/U cementing equipment. Currently RIH at the time of report Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG Dnn.i.wo Tv..uoinr,.Lm. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/25/2011 Time: 00:00 Current Depth (MD): 11445' Current Assemble BHA Current Depth (TVD): 4541' Operations: 24 hr Footage (MD): 0" Drilling Parameters ROP: Current: 0 Max: N/A Torque: Current: N/A Max: N/A WOB: Current 0 Max: N/A RPM: Current: 0 Max: 48 PP: Current: 0 Max: 4019 Lag: Strokes: 0 Time: N/A Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 11445' MW: 9.9 FV: 83 PV: 28 YP: 18 FL: 5.8 Gels: 15/46/48 Sol: 12% pH: - CF: 35000 Ca++: MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 0 Max: N/A Depth (MD/TVD): 10962'/x' Average: 5u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Siltstone, Last 24 hrs: Siltstone, Claystone. RIH with tubing to 7,966'and set open hole packer. R/U cement head and lines and Operational Summary: pressure test. Pump 56 bbls and W/D R/U and pump 56 bbls. Cir B/U and POOH. UD BHA and R/D cement equipment. P/U BHA for next drilling run. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG Dxu.i m<'Tccnani.nnv Lrn. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/26/2011 Time: 00:00 Current Depth (MD): 7335' Current Drilling Ahead Current Depth (TVD): xxxx' Operations: 24 hr Footage (MD): 121' Drilling Parameters ROP: Current: 43 Max: N/A Torque: Current: N/A Max: N/A WOB: Current 3.2K Max: N/A RPM: Current: 150 Max: 150 PP: Current: 1713 Max: 4019 Lag: _ Strokes: 5125 Time: 46 Surf-Surf: Strokes: 6353 Time: 56 ECD: Current: - Max: - Mud Properties @ 11445' MW: 9.9 FV: 83 PV: 28 YP: _ 18 FL: 5.8 Gels: 15/46/48 Sol: 12% pH: - Cr: 35000 Ca++: MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 9u Max: 18u Depth (MD/TVD): 7268' Average: 2u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 70% Cement 30%Siltstone, Last 24 hrs: P/U new BHA and drilling assy., begin RIH to 2,632'and wait for cement to cure. RIH Operational Summary: to 3493'and stack out. Begin washing and reaming down to 7,144'and K/O. Continue to drill ahead at the time of report. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG fiau.i.iw.Tra rvnie,m'Lrn. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/27/2011 Time: 00:00 Current Depth (MD): 9202' Current Drilling Ahead Current Depth (TVD): 3947' Operations: 24 hr Footage (MD): 1868' Drilling Parameters ROP: Current: 142 Max: 185 Torque: Current: N/A Max: N/A WOB: Current 4.2K Max: 35K RPM: Current: 150 Max: 150 PP: Current: 3531 Max: 3955 Lag: Strokes: 6435 Time: 36.5 Surf-Surf: Strokes: 6353 Time: 56 ECD: Current: - Max: - Mud Properties @ 11445' MW: 9.9 FV: 71 PV: 22 YP: 14 FL: 5.6 Gels: 16/24/28 Sol: 10.24% pH: - Cr: 39000 Ca++: MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 50u Max: 87u Depth (MD/TVD): 8872'/3891' Average: 2u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 65% Siltstone 30%Claystone 5% Sand, Last 24 hrs: Siltstone, Claystone and Sand Operational Summary: Drill from 7,334'to 9202' Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/28/2011 Time: 00:00 Current Depth (MD): 9729' Current REAMING TO BTM Current Depth (TVD): 4071' Operations: 24 hr Footage (MD): 1868' Drilling Parameters ROP: Current: N/A Max: 188 Torque: Current: N/A Max: N/A WOB: Current N/A Max: 26.5K RPM: Current: 150 Max: _ 150 PP: Current: 151 Max: 3955 Lag: Strokes: 6804 Time: N/A Surf-Surf: Strokes: 8454 Time: _ N/A ECD: Current: - Max: - Mud Properties @ 11445' MW: _ 9.8 FV: _ 89 PV: 27 YP: 21 FL: 5.2 Gels: 23/34/34 Sol: 9.69% pH: - Cr: 40500 Ca++: MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data LDitch Gas: Current: Ou Max: 234u Depth (MD/TVD): Ream Gas Average: 26u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth C1 C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 50%Siltstone 50% Claystone, Last 24 hrs: Siltstone, Claystone and Sand Drill from 9202'TO 9729'and begin backreaming out of hole to 6,987'.Circ 1.5x btms Up and begin RIH to approx 9040'stack out and begin reaming and washing down. Operational Summary: 234 units of reaming gas recorded at approx 9070'. Continue to wash and ream to btm at the time of report. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG Dui.Jnr T:cnvni.n.r Lrn. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/29/2011 Time: 00:00 Current Depth (MD): 10849' Current Drilling Ahead Current Depth (TVD): 4346.6' Operations: 24 hr Footage (MD): 1120' Drilling Parameters ROP: Current: 183 Max: 213 Torque: Current: N/A Max: N/A WOB: Current 3.2K Max: 22K RPM: Current: 150 Max: 150 PP: Current: 3905 Max: 3931 Lag: Strokes: 17589 Time: 45.17 Surf-Surf: Strokes: 9437 Time: 56.17 ECD: Current: - Max: - Mud Properties @ 10849' MW: 10.0 FV: 86 PV: 27 YP: 23 FL: 4.2 Gels: 15/32/36 Sol: 10.32% pH: - Cr: 43000 Ca++: MW Change: Depth: 9.8 From: 10.0 To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data REAM GAS/ Ditch Gas: Current: 55u Max: 80u Depth MD/TVD : CONNECTION p ( ) GAS 10,677'/4,311' Average: 26u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth C1 C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) 10,677/4,311' - - - - - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 75%Siltstone 20% Claystone, 5%Sandstone Last 24 hrs: Siltstone, Claystone and Sandstone, Tuff,Tuffaceous Claystone Operational Summary: Continue to wash and ream to btm, 9,728' and then drill ahead to current depth of 10,849'. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG IJaii.iiri'I.Tr, ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/30/2011 Time: 00:00 Current Depth (MD): 11,246 Current Backreaming Current Depth (TVD): 4438' Operations: 24 hr Footage (MD): 397' Drilling Parameters ROP: Current: N/A Max: 183 Torque: Current: N/A Max: N/A WOB: Current N/A Max: 9.6K RPM: Current: 0 Max: 0 PP: Current: 0 Max: 3950 Lag: Strokes: 7867 Time: N/A Surf-Surf: Strokes: 9786 Time: N/A ECD: Current: - Max: - Mud Properties @ 10849' MW: 10.1 FV: 84 PV: 24 YP: 18 FL: 4.0 Gels: 18/33/39 Sol: 12.2% pH: - Cr: 47000 Ca++: MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 63u Depth (MD/TVD): REAM GAS Average: 26u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) 10,677/4,311' - - - - - - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 75% Siltstone 20%Claystone, 5%Sandstone Last 24 hrs: Siltstone, Claystone and Sandstone, Tuff, Tuffaceous Claystone Operational Summary: Continue to drill to 11,246'and pump sweep and circulate. Begin POOH backreaming 9,000' . Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 01/31/2011 Time: 00:00 Current Depth (MD): 11,246 Current Backreaming/POOH Current Depth (TVD): 4438' 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: 161 Max: 165 PP: Current: 2124 Max: 3218 Lag: Strokes: 7867 Time: N/A Surf-Surf: Strokes: 9786 Time: N/A ECD: Current: - Max: - Mud Properties @ 10849' MW: 10.1 FV: 86 PV: 28 YP: 22 FL: 4.0 Gels: 23/42/45 Sol: 12.5% pH: - CF: 46500 Ca++: MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 7u Max: 46u Depth (MD/TVD): REAM GAS Average: 16u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 IC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 75% Siltstone 20%Claystone, 5%Sandstone Last 24 hrs: Siltstone, Claystone and Sandstone, Tuff, Tuffaceous Claystone Operational Summary: Continue to backream out of hole to 3050'. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 02/01/2011 Time: 00:00 Current Depth (MD): 11,246 Current Slip and Cut Drill Line Current Depth (TVD): 4438' 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: 150 PP: Current: N/A Max: _ 3425 Lag: Strokes: N/A Time: N/A Surf-Surf: Strokes: N/A Time: N/A ECD: Current: - Max: - Mud Properties @ 11,246' MW: 10.1 FV: 83 PV: 27 YP: 17 FL: 4.0 Gels: 17/40/47 Sol: 12% pH: - Cr: 47000 Ca`+: - MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 126u Depth (MD/TVD): REAM GAS Average: 8u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 75%Siltstone 20% Claystone, 5%Sandstone Last 24 hrs: Siltstone, Claystone and Sandstone, Tuff, Tuffaceous Claystone Continue to backream out of hole to 2,735'flow check well and POOH elevators. UD Operational Summary: BHA. P/U new BHA and RIH and S/C DL. Currently S/C Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 02/02/2011 Time: 00:00 Current Depth (MD): 11,246 Current Monitor Well Current Depth (TVD): 4438' 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: 166 PP: Current: N/A Max: 3718 Lag: Strokes: N/A Time: N/A Surf-Surf: Strokes: N/A Time: N/A ECD: Current: - Max: - Mud Properties @ 11,246' MW: 10.1 FV: 84 PV: 27 YP: 21 FL: 4.0 Gels: 18/39/45 Sol: 12% pH: - Cr: 47500 Ca++: MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 275u Depth (MD/TVD): REAM GAS Average: 12u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 75%Siltstone 20% Claystone, 5%Sandstone Last 24 hrs: Siltstone, Claystone and Sandstone, Tuff,Tuffaceous Claystone RIH to 8750' and encounter tight hole. Begin reaming and washing to 9058'. Back ream Operational Summary: out of hole to 8760'. POOH on elevators to surface and monitor well. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG Dau.i.ivo Trtn rvni.unr Lni. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 02/03/2011 Time: 00:00 Current Depth (MD): 11,246 Current UD 3.5"Tubing Current Depth (TVD): 4438' 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: 166 PP: Current: N/A Max: 2788 Lag: _ Strokes: N/A Time: N/A Surf-Surf: Strokes: N/A Time: N/A ECD: Current: - Max: - Mud Properties @ 11,246' MW: 10.1 FV: 86 PV: 28 YP: 21 FL: 4.0 Gels: 19/41/49 Sol: 12% pH: - CF: 47000 Ca`+: MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 7u Depth (MD/TVD): N/A Average: Ou Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 IC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 75%Siltstone 20% Claystone, 5%Sandstone Last 24 hrs: Siltstone, Claystone and Sandstone, Tuff, Tuffaceous Claystone UD drilling assy, P/U packer and cmnt string. RIH to 3620' and set packer. R/U cmnt Operational Summary: head and pressure test lines. Conduct 2 stage cmnt job. CBU and POOH UD 3.5" tubing. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 02/04/2011 Time: 00:00 Current Depth (MD): 2745 Current Drilling Cement Current Depth (TVD): 2375 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: 166 PP: Current: N/A Max: N/A Lag: Strokes: N/A Time: N/A Surf-Surf: Strokes: N/A Time: N/A ECD: Current: - Max: - Mud Pro•erties @ 2745' MW: 9.5 FV: 51 PV: 5 YP: 15 FL: 6.2 Gels: 13/15/17 Sol: 4.6% pH: - CF: Ca': - - MW Change: Depth: 2745 From: 10.1 To: 9.5 Reason: WBM Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: Ou Depth (MD/TVD): N/A Average: Ou Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: N/A Last 24 hrs: Operational Summary: Test BOP's, P/U new BHA, RIH to 2,000'and begin washing down to 2,445'.Drilling out cmnt to 2695'at the time of report. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 02/05/2011 Time: 00:00 Current Depth (MD): 4807 Current Drilling Ahead Current Depth (TVD): 2959' Operations: 24 hr Footage (MD): 2062' Drilling Parameters ROP: Current: 0 Max: 252 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 24.5K RPM: Current: 0 Max: 166 PP: Current: 2454 Max: 2795 Lag: Strokes: 3363 Time: 34 Surf-Surf: Strokes: 4145 Time: 42 ECD: Current: - Max: - Mud Properties @ 4807' MW: 9.6 FV: 48 PV: 13 YP: 18 FL: 4.6 Gels: 13/22/24 Sol: 5.6% pH: 9.6 Cr: 1000 Ca++ 180 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 46u Max: 166u Depth (MD/TVD): 3288/2551.46 Average: 28u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: CLAYSTONE, DISSAGGREGATED SAND, SANDSTONE,SILTSTONE Last 24 hrs: CLAYSTONE, DISSAGGREGATED SAND, SANDSTONE,SILTSTONE Operational Summary: Drill from 2745'to 4807' . Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 02/06/2011 Time: 00:00 Current Depth (MD): 6324 Current Drilling Ahead Current Depth (TVD): 3556 Operations: 24 hr Footage (MD): 1517 Drilling Parameters ROP: Current: 0 Max: 265 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 24.7K RPM: Current: 0 Max: 125 PP: Current: 0 Max: 3021 Lag: 5475 Time: 29 Strokes: 4426 Time: 23.54 Surf-Surf: Strokes: ECD: Current: - Max: - Mud Properties @ 6324' MW: 9.5 FV: 51 PV: 15 YP: 21 FL: 3.8 Gels: 10/20/27 Sol: 7% pH: 9.0 Cr: 800 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 10u Max: 71u Depth (MD/TVD): 4824/2978 Average: 28u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 105 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Sandstone, siltstone, claystone, disaggregated sand Last 24 hrs: Sandstone, siltstone, claystone, disaggregated sand Operational Summary: Drill from 4807'to 4997'and back ream to 2724'.RIH to 4900'and wash and ream down to bottom. Continue to drill ahead to current depth of 6324'. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG Dau.i.mr Tel rvornrs Lni. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Guy Heim Date: 02/07/2011 Time: 00:00 Current Depth (MD): 7684 Current Drilling Ahead Current Depth (TVD): 3734 Operations: 24 hr Footage (MD): 1360 Drilling Parameters ROP: Current: 157 Max: 265 Torque: Current: N/A Max: N/A WOB: Current 29.6 Max: 28.9K RPM: Current: 122 Max: 125 PP: Current: 3563 Max: 3696 Lag: Strokes: 5548 Time: 30 Surf-Surf: Strokes: 6880 Time: 7.4 ECD: Current: - Max: - Mud Properties @ 7684' MW: 9.5 FV: 46 PV: 13 _ YP: 20 FL: 3.6 Gels: 7/13/22 Sol: 7.5% pH: 9.4 Cr: 800 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 51u Max: 60u Depth (MD/TVD): 7108/3602 Average: 38u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Sandstone, siltstone, claystone, disaggregated sand Last 24 hrs: Sandstone, siltstone, claystone, disaggregated sand Operational Summary: Drill from 6324'to 6983'and back ream out of hole to 4800'. Circulate two times btms up and and RIH and drill ahead to current depth of 7684'. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG Dan.i.ieo Tn'irvni.unv Lru. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Scott Heim Date: 02/08/2011 Time: 00:00 Current Depth (MD): 9064 Current Back Ream Out of Hole Current Depth (TVD): 4086 Operations: 24 hr Footage (MD): 1380 Drilling Parameters ROP: Current: ; N/A Max: 206 Torque: Current: N/A Max: N/A WOB: Current _ N/A Max: 38K RPM: Current: 86 Max: 126 PP: Current: 3246 Max: 3696 Lag: Strokes: 6345@9064 Time: N/A Surf-Surf: Strokes: 7877@9064 Time: N/A ECD: Current: - Max: - Mud Properties @ 9064' MW: 9.6 FV: _ 47 PV: 16 YP: 21 FL: 3.3 Gels: ) 10/16/23 Sol: 8.4% pH: 9.6 Cr: 800 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 38u Max: 73u Depth (MD/TVD): 8600/3990 Average: 34.4u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Sandstone, siltstone, claystone, disaggregated sand Last 24 hrs: Sandstone, siltstone, claystone, disaggregated sand Operational Summary: Drill from 7700'to 9064'and circ btms up. Begin back reaming out of hole to 6635' Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG I)xii.i.i HiTr-ivuir. I.nt ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Scott Heim Date: 02/09/2011 Time: 00:00 Current Depth (MD): 9064 Current POOH Current Depth (TVD): 4086 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: 0 Max: 117 PP: Current: 0 Max: 3302 Lag: Strokes: 6345@9064 Time: N/A Surf-Surf: Strokes: 7877@9064 Time: N/A ECD: Current: - Max: - Mud Properties @ 9064' MW: 9.6 FV: 49 PV: 19 YP: 17 FL: 3.2 Gels: 7/13/18 Sol: 8.9% pH: 10.2 CF: 700 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 17u Max: 281u Depth (MD/TVD): Trip Gas Average: 34u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 1C4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Sandstone, siltstone, claystone, disaggregated sand Last 24 hrs: Sandstone, siltstone, claystone, disaggregated sand Continue to back ream out of hole to 4,333' circulate at 4,333'. Continue to back ream Operational Summary: out of hole to 2,700'and pump sweep. S/C drill line. Remove saber sub, POOH to 2,550', 15k overpull obs.(swabbing),circulate out gas with max gas recorded at 281u. Flow check well, obs static. Pump 40 bbl sweep, continue to POOH. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG 1)au.i.ieo T-cuani.u:a Lrn. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Scott Heim Date: 02/10/2011 Time: 00:00 Current Depth (MD): 9290 Current POOH Current Depth (TVD): 4148 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 91 Max: 205 Torque: Current: N/A Max: N/A WOB: Current 12.4 Max: 37 RPM: Current: 121 Max: 122 PP: Current: 3820 Max: 3976 Lag: Strokes: 6419 Time: 36 Surf-Surf: Strokes: 7994 Time: 44.41 ECD: Current: - Max: - Mud Properties @ 9290' MW: _ 9.6 FV: 60 PV: 19 YP: 20 FL: 3.1 Gels: 8/15/18 Sol: 8% pH: 9.7 Cr: 700 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 4u Max: 671u Depth (MD/TVD): Trip Gas/POG Average: 6u While drilling Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Claystone, siltstone, disaggregated sand Last 24 hrs: N/A Continue to POOH, UD BHA and P/U new BHA. RIH to 7,710' stage pumps to break Operational Summary: Circulation observe max gas @ 671 u. Circulate until gas levels decrease. RIH to bottom and continue to drill ahead to a current depth of 9290'. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Pat Archey Date: 02/11/2011 Time: 00:00 Current Depth (MD): 10700 Current Drilling Ahead Current Depth (TVD): 4517 Operations: 24 hr Footage (MD): 1410 Drilling Parameters ROP: Current: 88 Max: 209 Torque: Current: N/A Max: N/A WOB: Current 2.2 Max: 44 RPM: Current: 121 Max: _ 125 PP: Current: 3573 Max: 3995 _ Lag: _ Strokes: 7405 Time: 41 Surf-Surf: Strokes: 9228 Time: 51.5 ECD: Current: - Max: - Mud Properties @ 10700' MW: 9.6 FV: 44 PV: 12 YP: . 18 FL: 3.1 pH: 9.6 Cr: 800 Ca Gels: 8/15/23 Sol: 9% � ++ 40 - MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 53u Max: 86u Depth (MD/TVD): 9829/4282 Average: 41u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Siltstone, claystone„ disaggregated sand, Last 24 hrs: Siltstone, claystone, sandstone, disaggregated sand, carbonaceous shale Operational Summary: Drill from 9290'to current depth of 10,700'. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG Daiuieo Trrirvnpum'Ln,. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Pat Archey Date: 02/11/2011 Time: 00:00 Current Depth (MD): 11532 Current RIH Current Depth (TVD): 4735 Operations: 24 hr Footage (MD): 835 Drilling Parameters ROP: Current: N/A Max: 264 Torque: Current: N/A Max: N/A WOB_: Current N/A Max: 69 RPM: Current: N/A Max: 125 PP: Current: N/A _ Max: 3875 Lag: Strokes: 7990 Time: N/A Surf-Surf: Strokes: 9961 Time: N/A ECD: Current: - Max: - Mud Properties @ 10700' MW: 9.7 FV: 42 PV: 13 YP: 17 FL: 3.4 Gels: 7/13/19 Sol: 9% pH: 9.5 CF: 700 Ca' 10.4 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 68u Depth (MD/TVD): 11301/4689 Average: 33u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 105 nC5 (MD/TVD) Connection Depth C1 C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Unconsolidated sand Last 24 hrs: Siltstone, claystone, sandstone, unconsolidated sand, carbonaceous shale Operational Summary: Drill from 10,700'to 11,532'. Back ream out of the hole to 8,868'cir 3xbtms up and Flow check well (static). RIH to 10,200' at the time of report. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG 1)nn.i.ivr T:cuvni.ucr Lrn. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Pat Archey Date: 02/13/2011 Time: 00:00 Current Depth (MD): 11666 Current POOH Current Depth (TVD): 4771 Operations: 24 hr Footage (MD): 134 Drilling Parameters ROP: Current: N/A Max: 115 Torque: Current: N/A Max: N/A WOB: Current N/A Max: 68 RPM: Current: N/A Max: 125 PP: Current: N/A Max: 3868 Lag: Strokes: _ 8082 Time: N/A Surf-Surf: Strokes: 10075 Time: N/A ECD: Current: - Max: - Mud Properties @ 11666' MW: 9.7 FV: 45 PV: 13 YP: 19 FL: 3.6 Gels: 8/13/16 Sol: 9% pH: 9.4 Cr: 800 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 175u Depth (MD/TVD): Trip Gas/BU gas Average: 47u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Unconsolidated sand, siltstone, calcareous siltstone, shale Last 24 hrs: Siltstone, claystone, sandstone, unconsolidated sand, shale Operational Summary: Continue RIH in hole to bottom and drill to 11,666' ROP dropped substantially. Begin back reaming out of hole to surface. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Larry Hill Pat Archey Date: 02/14/2011 Time: 00:00 Current Depth (MD): 11714 Current Repairing Mud Pump Current Depth (TVD): 4784 Operations: 24 hr Footage (MD): 38 Drilling Parameters ROP: Current: N/A Max: 102 Torque: Current: N/A Max: N/A WOB: Current N/A Max: 68 RPM: Current: N/A Max: 102 PP: Current: 1532 Max: 3650 Lag: Strokes: 8107 Time: 45 Surf-Surf: Strokes: 10109 Time: 56 ECD: Current: - Max: - Mud Properties @ 11714' MW: 9.6 FV: 45 PV: 11 YP: 19 FL: 3.4 Gels: , 9/15/17 Sol: 8% pH: 9.4 Cr: 700 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 30u Max: 314u Depth (MD/TVD): Trip Gas/BU gas Average: 35u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth C1 C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Unconsolidated sand, siltstone, calcareous siltstone, shale Last 24 hrs: Unconsolidated sand, shale, calcareous siltstone, shale Continue to POOH and UD BHA. P/U new BHA and RIH to 2818'.Wait on weather Operational Summary: then continue in hole to bottom and drill to 11,714. Repairing#2 mud pump at the time of report. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Ray Springer Pat Archey Date: 02/15/2011 Time: 00:00 Current Depth (MD): 12874 Current Drilling ahead Current Depth (TVD): 5091 Operations: 24 hr Footage (MD): 1429 Drilling Parameters ROP: Current: 90 Max: 119 Torque: Current: N/A Max: N/A WOB: Current 56 _ Max: 60 RPM: Current: N/A Max: 102 PP: Current: 1532 Max: 3650 Lag: Strokes: 8875 Time: 47.7 Surf-Surf: Strokes: 16636 Time: 89.4 ECD: Current: - Max: - Mud Properties @ 12693' MW: 9.8 FV: 44 PV: 11 YP: 23 FL: 3.5 Gels: l 8/14/20 Sol: 9% pH: 9.4 Cr: 800 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 11u Max: 100u Depth (MD/TVD): Trip Gas/BU gas Average: 45u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 60%Sand, 40% Sandstone Last 24 hrs: Sand, Sandstone, Siltstone, Shale Operational Summary: Drilled to 11,991'. Serviced rig,greased and inspected TD, Draw works,and iron roughneck. Continued drilling. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Ray Springer Pat Archey Date: 02/16/2011 Time: 00:00 Current Depth (MD): 14134 Current Drilling ahead Current Depth (TVD): 5457 Operations: 24 hr Footage (MD): 1260 Drilling Parameters ROP: Current: 57 Max: 146 Torque: Current: N/A Max: N/A WOB: Current 76 Max: 106 RPM: Current: N/A Max: 102 PP: Current: _ 3551 Max: 3968 Lag: Strokes: 9744 Time: 52.4 Surf-Surf: Strokes: 18718 Time: 100.6 ECD: Current: - Max: - Mud Properties @ 12693' MW: 9.7 FV: 47 PV: 10 YP: 21 FL: 3.2 Gels: 7/10/12 Sol: 10% pH: 9.4 CF: 700 Ca' 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 30u Max: 116u Depth (MD/TVD): Trip Gas/BU gas Average: 34u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth C1 C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 50% Sand, 50%Siltstone Last 24 hrs: Sand, Sandstone, Siltstone, Shale, Claystone Operational Summary: Drilled to 11,991'. Serviced rig,greased and inspected TD, Draw works, and iron roughneck. Continued drilling. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG I)nu.i ivr Tmuvni.ucr Lrn. ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Ray Springer Pat Archey Date: 02/17/2011 Time: 00:00 Current Depth (MD): 14520 Current Drilling ahead Current Depth (TVD): 5594 Operations: 24 hr Footage (MD): 386 Drilling Parameters ROP: Current: 61 Max: 129 Torque: Current: N/A Max: N/A WOB: Current 8 Max: 82 RPM: Current: N/A Max: 102 PP: Current: 3711 Max: 3924 Lag: Strokes: 10022 Time: 57 Surf-Surf: Strokes: 17621 Time: 166.2 ECD: Current: - Max: - Mud Properties @ 12693' MW: 9.7 FV: 43 PV: 12 YP: 26 FL: 3.1 Gels: 8/10/12 Sol: 10% pH: 9.5 Cr: 700 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 20u Max: 129u Depth (MD/TVD): Trip Gas/BU gas Average: 40u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 10% Sand, 70%Sandstone, 20%Siltstone Last 24 hrs: Sand, Sandstone, Siltstone Drilld from 14,134'to 14,508'. Flow check(static), circulate bottoms up @ 40 SPM. Operational Summary: Drop in pressure. POOH from 14,508'to 13,553' lay down washed out single, replaced single. Cont to POOH to 11,625' MD,flow check(static) RIH on elevators from 11,625' MD to 14,508'. Drilling ahead. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG I)cu.i ier Tccnvoina Lrix Conoco hillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Ray Springer Pat Archey Date: 02/18/2011 Time: 00:00 Current Depth (MD): 15049 Current Drilling ahead Current Depth (ND): 5779 Operations: 24 hr Footage (MD): 529 Drilling Parameters ROP: Current: 0 Max: 95 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 75 RPM: Current: N/A Max: 102 PP: Current: 0 Max: 4029 Lag: Strokes: 3366 Time: 18.4 Surf-Surf: Strokes: 9474 Time: 51.8 ECD: Current: - Max: - Mud Properties @ 15049' MW: 9.7 FV: 42 PV: 12 YP: 19 FL: 3.4 Gels: 8/10/11 Sol: 10% pH: 9.5 CF: 700 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 78u Depth (MD/TVD): Trip Gas/BU gas Average: 27u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth C1 C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 40%Siltstone, 20%Sand, 20%Shale. 10%Carbonaceous Shale, 10% Sandstone, Last 24 hrs: Sand, Sandstone, Siltstone, Shale, Carbonaceous Shale Drilling from 14,52'to TD @ 15049'.Circulate 3x bottoms up. Flow check(static). POOH from 15,049'to 14,944',pump out of hole to 14,561'. RIH to 15,049'. Circulate Operational Summary: b/u. POOH from 15,049'to 10,676'. Back reamed through 10,676'to 10,486'.Wipe back down to 10,486'. POOH, pulled tight @ 10,700',wipe back through tight spots. Pumped dry job and cont to POOH from 9,899'to 5,848'. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Ray Springer Pat Archey Date: 02/19/2011 Time: 00:00 Current Depth (MD): 15049 Current RIH Casing Current Depth (TVD): 5779 Operations: 24 hr Footage(MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 0 RPM: Current: N/A Max: 102 PP: Current: 147 Max: 147 Lag: Strokes: 10022 Time: 57 Surf-Surf: Strokes: 17621 Time: 166.2 ECD: Current: - Max: - Mud Properties @ 15049' MW: 9.7 FV: 43 _ PV: 11 YP: 23 FL: 3.6 Gels: 7/9/10 Sol: 10% pH: 9.4 Cr: 700 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: Ou Depth (MD/TVD): Trip Gas/BU gas Average: Ou Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 10% Sand, 70% Sandstone, 20% Siltstone Last 24 hrs: Sand, Sandstone, Siltstone P/U and set packer @ 103.77'. Pump out stack. Change lower rams from 5'to 7-5/8". Operational Summary: Test BOPE. Rig down testing equip. POOH from 2,511'to BHA @ 651'. P/U and LID BHA. Clear and clean rig floor area. Pick up and rig up to run 7-5/8"casing. Run 7-5/8" casing. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-320 Daily Report Report for: Ray Springer Pat Archey Date: 02/20/2011 Time: 00:00 Current Depth (MD): 15049 Current RIH Casing Current Depth (TVD): 5779 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 0 RPM: Current: N/A Max: 102 PP: Current: 0 Max: 0 Lag: Strokes: 10022 _ Time: 57 Surf-Surf: Strokes: 17621 Time: 166.2 ECD: Current: - Max: - Mud Properties @ 15049' MW: 9.8 FV: 47 PV: 13 YP: 19 FL: 3.5 Gels: 8/9/11 Sol: 10% pH: 9.2 Cr: 700 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: Ou Depth (MD/TVD): Trip Gas/BU gas Average: Ou Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth C1 C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 10% Sand, 70% Sandstone, 20%Siltstone Last 24 hrs: Sand, Sandstone, Siltstone Run 7-5/8"casing fom 236' MD to 5,833'.Circulate B/U at shoe @ 5bpm. Fill pipe Operational Summary: every joint and completely fill every 10 joints.Obtain P/U and S/O weights every 4`" joint in open hole. Cont RIH T/10,000 MD circulate B/U @ 4 bpm. Cont to RIH to 12,500' MD and circulate B/U. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,430.00 CANRIG Dnn.i.irvr Tcci nvv.on-Lrn. m 0 3 0 r 0 c0