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207-165
Originated: Delivered to:26-Aug-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2Z-20 50-029-21876-00 910220628 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 12 2Z-20 50-029-21876-00 910219502 Kuparuk River Packer Setting Record Field- Final 12-Aug-25 0 13 3K-102 50-029-23378-00 910262525 Kuparuk River Leak Detect Log Field- Final 19-Aug-25 0 14 3M-13 50-029-21720-00 910219405 Kuparuk RiverLeak Detect LogField- Final 8-Aug-25 0 15 3M-13 50-029-21720-00 910219403 Kuparuk River Multi Finger Caliper Field & Processed 1-Aug-25 0 16 3M-13 50-029-21720-00 910219405 Kuparuk River Plug Setting Record Field- Final 8-Aug-25 0 17 3Q-07 50-029-21682-00 910180539 Kuparuk River Multi Finger Caliper Field & Processed 13-Jul-25 0 18910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:188-124207-165187-040186-194T40834T40834T40835T40836T40836T40836T408378/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:54:51 -08'00'3K-10250-029-23378-00 910262525Kuparuk RiverLeakDetect LogField- Final19-Aug-2501T40835188 124207-165187 040 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-08-24_24025_KRU_3K-102_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 24025 KRU 3K-102 50-029-23378-00 Caliper Survey w/ Log Data 24-Aug-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 207-165 T40802 8/27/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.27 08:01:54 -08'00' • • trn~~e ~'roj~ct Wait Mistcary Fits ~ov~r f~~g~ XHVZE This page identifies those items that were nat scanned during the initial production scanning phase: They are available in the original fiile, may be scanned during a special rescan activity ar are viewable by direct inspection of the file. - ~ ~ Well History File Identifier Organizing (done) ,~ =,d~ iiumiiiuiiuoi o Re.~a~~reaea iiiuiui~iuum RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. I ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ /s/ Pro "ect Proofin II I II II II I I III I I III J g BY: Maria Date: ~ o /s/ Scanning Preparation _~ x 30 = ~ ~ + ~ =TOTAL PAGES ~~ (Count does not include cover sheet) BY: Maria Date: ,~ ~~ ~~ /s/ Production Scanning Stage 1 Page Count from Scanned File: ~<~ (Count does include cove sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: j ~' © /s/ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'I II I II II I I III ReScanne~al III I1IIIIIII~ II III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III II'I III 10!6/2005 Well History File Cover Page.doc • 111. COilOCO P111111PS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 - -74 tictiMES) MAR 2 (7) March 9, 2012 rAM 4 X. Commissioner Dan Seamount CUM, G'XiTiiid-Dh Alaska Oil & Gas Commission d" 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 aO7- (66 Commissioner Dan Seamount 3 - ( 3- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were 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 spreadsheet 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 fall of 2011. The corrosion inhibitor/sealant was pumped on various days in January and February 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. Since; , // MT veland ConocoPhillips Well Integrity Projects Supervisor • • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 3 -09 -2012 3A,3G,3H,3K PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PM* cement pumped cement date inhibitor sealant date ft bbls ft gal 3A -17A 50029226910100 2101130 31" NA 13" NA 5.95 2/14/2012 3G-20 50103201410000 1901230 SF NA 24" NA 3.83 2/14/2012 31-1-17 50103200810000 1870990 19" NA 19" NA 3H-21 50103200940000 1880080 8" NA 15" NA 4.25 2/14/2012 3H-23A 50103202040100 1961860 6" NA 12" NA 6.38 2/14/2012 3K-102 50029233780000 2071650 SF NA 16" NA 6.8 2114/2012 ~~ _ ? n MICROFILMED 6/30/2010 DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Fites\OLK9\Microfilm_Marker.doc ~ ~ Conoc P ' ' o hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder ~ ~ ~ ~ ' Alaska Oil & Gas Commission ~ ~' 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 3 ~'~ '-' ~ ~ ~ ~ a ~: .,r~,r ..t.~. i ~ t 'ii+~ a Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treahnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~` 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~~~ MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 an_ ~u ~v o~n o..a Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-106 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . Na 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9l2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 • ~ ~ ~~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Welt Job # ,r .='~:~~~1~~;3.! i`~~~'~~ ~>' ~~~~ ~ _.m ~~~ ~~~~; MAY ~ ~ ~~~049 : al~~~~ ~61 ~ ~as Cc~s~. ~~~~ai~~~~~ a~~lG'~1(~t~~~ Log Description NO. 5228 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 05/12/09 3A-18 AYS4-00069 PERF/SBHP SURVEY - 6 -' OM26/09 1 1 3C-08 B146-00033 GLS ~( " 04/21/09 1 1 2M-25 B14B-00034 GR/TEMP LOG !9 f- 04/22/09 1 1 1 R-19A AYS400065 SBHP SURVEY -r C' `~ 3~ ` 04/23/09 1 1 3G-13 AYS400067 SBHP SURVEY - ( 04/24/09 1 1 3G-05 AYS400066 SBHP SURVEY 04/24/09 1 1 3F-07 614B-00038 SBHP SURVEY - ~ 04/24/09 1 1 3F-OS B14B-00037 SBHP SURVEY - 04/2M09 1 1 3M-25A 614B-00040 SBHP SURVEY OM25/09 1 1 3K-08 614B-00039 SBHP SURVEY ~/ OM25/09 1 1 2N-318A AWJI-00026 MEM BHP SURVEY -d OM27/09 1 1 2Z-07 B14B-00045 SBHP SURVEY . L 04/29/09 1 1 2Z-O1A B14B-00044 SBHP SURVEY ~-_ ~ Q 04/29/09 1 1 3K-102 ANHY-00080 GLS _~ 04/30/09 1 1 2W-06 B04C-00036 PRODUCTION PROFILE 05/02/09 1 1 2W-12 604C-00037 PRODUCTION PROFiLE O~~ 05/03/09 1 1 3C-02 B04C-00045 POWERCUTTER W/SBHP SURVEY 05/09/09 1 1 1 J-120 B04C-00043 GLS ~-- ~ D O 05/08/09 1 1 31-11 B04C-00044 SMALL TBG PUNCH W/SBHP 05/08/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ~~~ • FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Kuparuk River Unit 3K-102 DATE: 3/12/2009 ~~~~~~~ TRANSMITTAL CONF/DENT/AL DATA 3 TO: Christine Mahnken State of Alaska AOGCC 333 W. 7"' Ave, Suite 100 Anchorage, Alaska 99501-3539 Kuparuk River Unit, North Slope, Alaska 3K-102 (500292337800) Report and CDROM _ Final Well Report, Mud Logging Data, 3K-102; Epoch, report date: 02/07/2008; table of contents, pment and crew, well data, geological data, pressure/strength data, drilling data, daily reports, formation 'ormation Log MD and TVD 3600-14084' aas Ratio Log MD (only) 3600-14084' ,~,~ ~ ~'~!.1 ~~~ ~; ~~~. WD COMBO log MD and TVD 3600-14084' )rilling Dynamics Log MD and TVD 3600-14084' CDROM contains: 3K-102 and well report, morning reports, LAS data, PDF and tiff format color log image files; DML files and lithology remarks. CC: Anna Belanger, C AI Geologist i Receipt: --~"'~~-- Date: ~~~;: ~ -- .. L~®'~ =1 ~ui's.~x~~#;~~ci l~r~eii'?~3~L;°,'?<~~~a` ~ -'J~v~F~~:':.~~i,~,~.~ ~ ;~~~`;~L'13~8"~~~ >~f~,ss~~t ~ ~~?,` .~~~~'~, ~~'~,~3~4~~' .~ndra.®.LemkeC~Cr~nocophil/i s;com DATA SUBMITTAL COMPLIANCE REPORT 1 /7/2009 Permit to Drill 2071650 Well Name/No. KUPARUK RIV U WSAK 3K-102 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23378-00-00 MD 14084 TVD 3653 Completion Date 2/13/2008 Completion Status 1-OIL Curren t Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Direction al Survey Yes DATA INFORMAT ION Types Electric or Other Logs Run: GR /RES /NEUTRON /DENSITY / MUDLOTS & GR /RES / MUD L (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number Name. Scale Media No Start Stop CH Received Comments og Pressure 5 Col 1 4435 7488 Case 1/28/2008 Mod Dynamic Tester Pres ~, ', and Sample Log 14-Jan- 2008 rED D Asc Directional Survey 40 14084 Open 3/28/2008 / r~fCpt Directional Survey 40 14084 Open 3/28/2008 LIS Verification 3114 14084 Open 4/21/2008 LIS Veri, GR, NPHI, NCNT, PEF, PRX, PRS, FET, RPD, RPM, FCNT, RHOS, DRHO, ROP C Lis 16138 ~uction/Resistivity 3114 14084 Open 4/21/2008 LIS Veri, GR, NPHI, ', NCNT, PEF, PRX, PRS, !, FET, RPD, RPM, FONT, RHOB,DRHO,ROP ~g Production 5 Blu 0 6915 ~~.. ~t t 5/5/2008 MPPL, Spin, Pres, Temp, GR, CCL 26-Apr-2008 C Pds 16194 "Production 0 6915 Open 5/5/2008 MPPL, Spin, Pres, Temp, GR, CCL 26-Apr-2008 C Pds 16204 Production 100 6795 Open 5/5/2008 MPPL, Pres, Temp, ', Gradio, Spin, Deft 8-Apr- ~ ~~ 2008 ~ /'Log Production 5 Blu 100 6795 ~fi 5/5/2008 MPPL, Pres, Temp, I, Gradio, Spin, Deft 8-Apr- C 16229 Vree Notes 0 0 Open 5/7/2008 2008 TVD and MD of TC in CGM, PDF, and EMF veiw. wog Induction/Resistivity 25 Col 121 14084 Open 5/7/2008 MD ROP, DGR, EWR, ALD, CTN //Cog Induction/Resistivity 25 Col 121 3652 Open 5/7/2008 TVD DGR, EWR, ALD, _ __ _. _ _ _ _ - _ _ - - __ _- CTN I~ II DATA SUBMITTAL COMPLIANCE REPORT 1 /7/2009 Permit to Drill 2071650 Well Name/No. KUPARUK RIV U WSAK 3K-102 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23378-00-00 MD 14084 TVD 3653 Completion Date 2/13/2008 Completion Status 1-OIL Current Status 1-OIL UIC N og Production 5 Blu 6689 6908 Case 5/23/2008 Mem PPL, GR, CCL, Temp, Pres, Spin 9-May- 2008 /ED C Pds 16343 production 6689 6908 Case 5/23/2008 Mem PPL, GR, CCL, Temp, Pres, Spin 9-May- ', 2008 Well CoreslSamples Information: Name ADDITIONAL INFORMATION Well Cored? ~/ N $ t.a.f Cart e ++17 Chips Received? .a'-f-IQ~' Analysis Y / N Received? Comments: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops ~ N -- - - --_ -- -- - - -- Compliance Reviewed By: _ _.__ Date: _, Q - _ _ _ t H2S concerns on 3K-102 Davies, Stephen F (DOAj From: Hartwig, Dennis D (Dennis.D.Hartwig@conocophillips.com] Sent: Tuesday, July 29, 2008 3:37 PM To: Davies, Stephen F (DOA) Subject: RE: H2S concerns on 3K-102 Steve, Page 1 of 2 Zo7 ~/4 ~ 1 received more information today from the actual production operator, on duty March 21, regarding the presence of H2S while flowing back 3K-102. On the 21St of March, 3K-102 was being gas lifted with 1.3MMCF of lift gas. The lift gas itself contains between 160-180 ppm of H2S and would definitely taint the H2S readings in the test separator. This is probably a more viable explanation than my earlier response. I also learned today that the Mudloggers did not detect H2S because they were not running any H2S sensors. However, rig H2S sensors were operational during drilling operations and there were no reports of H2S encountered. Regards...Dennis From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, July 28, 2008 12:35 PM To: Hartwig, Dennis D Cc: Maunder, Thomas E (DOA) Subject: RE: H2S concerns on 3K-102 Thanks Dennis. Steve Davies AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Seat: Monday, July 28, 2008 11:53 AM To: Davies, Stephen F (DOA) Subject: H2S concerns on 3K-102 Steve, I have investigated the 3K-102 H2S occurrence (90 units) on 3/21/08. It is likely that the H2S occurrence was a carry over from Kuparuk wells in the test separator. • Both the 3K-35 (160ppm H2S) and the 3K-16 (150 ppm H2S) were run through the test separator prior to running the 3K-102. The practice has been to purge the test separator between tests however, variables such as partially open valves on the Kuparuk wells may have allowed some contamination with the 3K-102 results. While drilling the 3K-102 mud loggers were utilized and logging did not indicate the presence of H2S. 8/4/2008 H2S concerns on 3K-102 Page 2 of 2 • 3K West Sak area has not been water flood and without the presence of produced water H2S is not anticipated while drilling of either the 3K-103 or the 3K-108. I will continue to dig, but thus far I would have to go with Kuparuk contamination in the test separator as the likely culprit. Regards... Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 8/4/2008 rage i oi i , ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E {DOA) Sent: Sunday, May 25, 2008 11:20 AM To: 'Hartwig, Dennis D' Cc: Allsup-Drake, Sharon K Subject._R~E: 3K-102 (207-165 nd 3K-102L1 (207-166) Dennis and Sharon, A new 407 is not necessary. I will make the hand corrections. Tom From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.tom] Sent: Thursday, May 15, 2008 4:27 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: 3K-102 (207-165) and 3K-102L1 (207-166) Tom, Thank-you for the clarification and correction. The correct packer depth of 6,761' will be corrected in our records. Would you like a resubmitted/corrected copy of the 407 ? Regards, Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office : 907-265-6862 Cell : 90?-980-1433 Fax :907-265-1535 -'t: `+~?`~~:.i_ ` , ._ :'~~.~:. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, May 09, 2008 1:09 PM To: Harlwig, Dennis D Cc: Allsup-Drake, Sharon K; Regg, James B(DOA) Subject: 3K-102 (207-165) and 3K-102L1 (207-166) Dennis and Sharon, I am reviewing the 407s for these wells. Regarding the packer information given in block 24, the packer being referred to at that point should be the packer where the tubing is landed. I know it can get confusing with multilaterals. The packer depth for both repo~ts should be 6761'. What we are looking for is the packer that establishes the "bottom" of the inner annulus. This is especially a needed piece of information for injection wells. CaA or message with any questions. 7om Maunder, PE AOGCC ' 5/25/2008 ~~~~~~~ NO. 4707 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N ~ /fl Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 05/15/08 iF-12 11996623 PRODUCTION PROFILE / ~ 05/01/08 1 1 3J-11 11996624 PRODUCTION PROFILE C/L~ 05!02/08 1 1 3K-102 11963094 MEM PROD PROFILE ap'~ - ~ 05/09/08 1 1 1J-152 11996632 GLS ( C 05/09/08 1 1 1 E-166 11994665 GLS - 05/11 /08 1 1 1E-168 11994665 GLS _ 05/10/08 1 1 iH-01 11996626 PRODUCTION PROFILE W/FSI ~ (o / - 05/10/08 1 1 2X-15 11996634 PRODUCTION PROFILE W/FSI - ~ 05/12/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, May 09, 2008 1:09 PM To: 'Hartwig, Dennis D' Cc: 'Allsup-Drake, Sharon K'; Regg, James B (DOA) Subject: 3K-102 (207-165) and 3K-1021.1 (207-166) Dennis and Sharon, I am reviewing the 407s for these wells. Regarding the packer information given in block 24, the packer being referred to at that point should be the packer where the tubing is landed. I know it can get confusing with multilaterals. The packer depth for both reports should be 6761'. What we are looking for is the packer that establishes the "bottom" of the inner annulus. This is especially a needed piece of information for injection wells. Call or message with any questions. Tom Maunder, PE AOGCC 5/9/2008 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3K-102+L1+L1PB1 AK-MW-547949 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3K-102+L1+L1PB1 2" x 5" MD TC Logs: 1 Color Log 50-029-23378-00,60,70 2" x 5" TVD TC Logs: 1 Color Log 50-029-23378-00,60 Digital Log Images 1 CD Rom 50-029-23378-00,60,70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 690,0 Arc~i~,Blv~:- ; n, ~~~h~ra A~a~ka 99518 ~~ Date' `, 7 `~" ~) Si ed: (% April 22, 2008 ~~~~~ ~~ ~a 3 ~ ~o~-~~ 5' ¢~~~~ ~~~a r M1A' , ~ ~ 4,:„y"F ~~ ~- {~ ~ ~. Schlumberger -DCS ~~ 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Date NO. 4678 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 04/30/08 3K-102 NA PRODUCTION PROFILE _ 04/08/08 1 1 1 E-04 11996622 LDL ~~ -t p _ ~( 04/16/08 1 1 2U-13 11996617 PRODUCTION PROFILE - ~ ` 04/10/08 1 1 2W-17 11996618 SFRT - 04/12/08 1 1 2L-330 11970662 PERF/SBHP _ ~ 04/19/08 1 1 3F-18 11970666 LDL - ~ 04/23/08 1 1 iD-130 11964595 LDL C ~- 04/23/08 1 1 1 Y-07 11964596 INJECTION PROFILE - ~ / '3 04/24/08 1 1 2T-217A 11970667 INJECTION PROFILE -.p t!to (`j 04/24/08 1 1 1 F-05 11964597 INJECTION PROFILE / ~^-~ 04/25/08 1 1 3K-102 12021157 MEM PROD PROFILE ( 04/26/08 1 1 1 L-09 11970669 PRODUCTION PROFILE ~-/ 04!26/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~w ( {~ ~yp~ y~ tr~1~I1~G1-G~ ~ ,~,1 i~~ i~ ~1 ~ ~~~ii1 .. Schlumberger -DCS 2525 Gambell Street, Suite 400 ~~ - Anchorage, AK 99503-2838 ATTN: Beth Field: Kuparuk Well Job # Log Description Date NO. 4678 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD 04/30/08 3K-102 NA PRODUCTION PROFILE 04/08/08 1 1 1 E-04 11996622 LDL ~ 't D _ !{ 04/16/08 1 1 2U-13 11996617 PRODUCTION PROFILE - a~f ` 04/10/08 1 1 2W-17 11996618 SFRT ^ 04/12/08 1 1 2L-330 11970662 PERF/SBHP U - 1 04/19/08 1 1 3F-18 11970666 LDL - G 04/23/08 1 1 1D-130 11964595 LDL _C ~._ 04/23/08 1 1 1Y-07 11964596 INJECTION PROFILE -~~ ~ ~ 04/24/08 1 1 2T-217A 11970667 INJECTION PROFILE - ...0 ~(o ~ 04/24/08 1 1 1 F-05 11964597 INJECTION PROFILE / (nj _ 04/25/08 1 1 3K-102 12021157 MEM PROD PROFILE _ ( 04/26/08 1 1 f L-09 11970669 PRODUCTION PROFILE C( 04/26/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. l WELL LOG TRANSMITTAL To: State of Alaska April 16, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 3K-102 AK-MW-547949 1 LDWG formatted CD Rom with verification listing. API#: SO-029-23378-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~ ~~-~ ' l ~ ~ e~ ~ ~ ~'> _ - Date: Signed: ~b~ /~S~ ~~ (0l3~ FW: 3K-102L1PB1 PTD #207-166 -Request to gas lift via own sleeve: Page 1 of 3 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, April 17, 2008 3:37 PM To: Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF3 Prod Engrs Subject: RE: 3K-102 PTD #207-165 -Request to gas lift via open sleeve. Tom, During the flow back to tanks, there was a max rate of about 2200 bopd. When we turned it to the plant the initial rate was 2000 bopd and over the next 15 days declined to 1800 bopd. Please let me know if you need any more information. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 From: Maunder, Thomas E (DOA) [mailto:bom.maunder@alaska.gov] Sent: Tuesday, April 15, 2008 3:47 PM To: NSK Problem Well Supv Subject: RE: 3K-102 PTD #207-165 -Request to gas lift via open sleeve. Brent, For the record, how did the testing perform? A summary would be appreciated. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent; Tuesday, April 15, 2008 3:46 PM To: Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF3 Prod Engrs; NSK West Sak Prod Engr Subject: RE: 3K-102 PTD #207-165 -Request to gas lift via open sleeve. Tom, The test has been completed and the well was shut in on 04/08/08. Any further production will be done with the sliding sleeve closed and gas lifted via the GLM's. Please let me know if you have any questions. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. 4118/2008 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 ~~~~~~~~ ~ ~ ~ ~~ Phone: 907-265-6830 March 26, 2008 Commissioner R~~+~IVE® State of Alaska MAR 2 8 2008 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Alaska Oil & Gas Cons. Commission Anchorage, Alaska 99501 Anchorage Subject: Well Completion Reports for 3K-102 and 3K-102L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the West Sak multi-lateral 3K-102 and 3K-102L1. If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~ V ~~ ~a~ 2 ~ 2aos WELL COMPLETION OR RECOMPLETION REP,~lQ~Q~ c~r'--~,,;Qe~ 1a. Well Status: Oil ^/ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1 : WeII Class: . ~ lopment / "-exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., oraband.: February 13, 2008 ~ 12. Permit to Drill Number: 207-165 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: January 6, 2008 13. API Number: 50-029-23378-00 4a. Location of Well (Governmental Section): Surface: 910' FSL, 315' FWL, Sec. 35, T13N, R09E, UM 7. Date TD Reached: January 28, 2008 • 14. Well Name and Number: 3K-102 Top of Productive Horizon: 1564' FNL, 1914' FEL, Sec. 35, T13N, R09E, UM 8. KB (ft above MSL): 40' RKB Ground (ft MSL): 74.3' AMSL • ,~,~. 15. Field/Pool(s): Kuparuk River Field Total Depth: 2132' FNL, 543' FEL, Sec. 36, T13N, R09E, UM 9. Plug Back Depth (MD + TVD): 14071' MD / 3652' TVD West Sak Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529306 y- 6007904 ~ Zone- 4 10. Total Depth (MD + TVD): 14084' MD / 3653' TVD 16. Property Designation: ADL 25519 TPI: x- 532341 y- 6010722 Zone- 4 Total Depth: x- 538995 - 6010186 Zone- 4 11. SSSV Depth (MD + TvD): Camco nipple @ 516' MD/515' TVD 17. Land Use Permit: 2555 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): Est. 1629 TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res/Neutron/Density/Mud lots in intermediate and GR/Res/mud log in laterals 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE NTING CO AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEME RE RD PULLED 20" 94# H-40 40' 121' 40' 121' 40" pre-installed 13.375" 68# L-80 40' 3143' 40' 2190' 16" 653 sx ASLite; 248 sx DeepCRETE 9.625" 40# L-80 40' 7596' 40' 3546' 12.25" 530 sx DeepCRETE 5.5" 15.5# L-80 6850' 14073' 3459' 3653' 8.5" slotted liner 23. Open to production or injection? Yes ^/ No If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 6768' 7648'-8880' MD 3548'-3561' TVD 32 spf 8882'-12343' MD 3561'-3577' TVD 32 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12511'-13477' MD 3580'-3610' TVD 32 Spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 13778'-14032' MD 3640'-3653' TVD 32 spf n/a 26. PRODUCTION TEST Date First Production March 21, 2008 Method of Operation (Flowing, gas lift, etc.) gas lift oil -shares production with 3K-102L1 Date of Test 3/24/2008 Hours Tested 12 hours Production for Test Period --> OIL-BBL 1034 GAS-MCF 1115 WATER-BBL 0 CHOKE SIZE 112 Bean GAS-OIL RATIO 1133 Flow Tubing press. 262 psi Casing Pressure gp8 Calculated 24-Hour Rate -> OIL-BBL 2004 GAS-MCF 2270 WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes ~ No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. f.... ail '~tt~i 5i^~ I;~~- 4 { Lli~ 1 SEE ATTACHMENT U~~I~tEC! ~ - - Form 10-407 Revised 2/2007 • CONTINUED ON REVERSE SIDE ~~~c, ~ 1. of ~ ~~~~ G 28. GEOLOGIC MARKERS (List all formations and ma encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes / No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1843' 1629' needed, and submit detailed test information per 20 AAC 25.071. T3 1736' 1559' K15 2112' 1786' Ugnu C 4376' 2666' Ugnu B 5516' 3042' Ugnu A 5816' 3137' K13 6333' 3307' West Sak D 6796' 3449' West Sak C 7042' 3491' West Sak B 7380' 3535' , N/A Formation at total depth: West Sak B 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, core summary, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt:_:,,......D~nnis artwig @ 265-6862 f Printed Name, ~~~ ~Rand~ Thomas Title: Drilling Team Leader ~-""°^' 3 r2 ib Signature \ t ~ Phone ~~-~.~ yd Date -6 r INSTRUCTIONS Sharon Allsup-Drake 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 welt 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 2/2007 KRU 3K-102 ConocoPhltp~t Alaska, lnc. 3K-1 X02 - -- - - - _ API. 500[9`1"337800 Well T e: PROD An ie a~ TS: de 5i Heat Trace SSSV T e: NIPPLE Ori Com letion: An le TD: 90 de 14084 (t-3006, Annular Fluid: Last W/O: Rev Reason: NEW WELL OD:1.000) Reference L 41' RKB Ref L Date: Last U date: 2/19/2008 Last Ta TD: 14084 ftKB TUBING Last Tag Date: Max Hnle Angle - - 92 deg ~ 12315 (ob7ss, ,, ~ Casin Strin -ALL STRINGS OD:4.500, a ` Descri ion Size To _ Bottom TVD Wt Grade Thread ID:3.95B) CONDUCTOR 20.000 0 120 120 94.00 H-40 WELDED SURFACE 13.375 0 3143 2190 68.00 L-80 BTC INTERMEDIATE 9.625 0 7595 3547 40.00 L-80 BTCM D-SAND WINDOW 9.625 6795 6796 3448 0.00 B-SAND SLOTTED LINER 5.500 6850 14073 3653 15.50 L-80 BTC/HYD _ 521 - °' _- - Tubin Strin -TUBING -- _ _ _ - - TVD Wt _Grade Thread Size __ Top Bottom -"-~ , - ~ _ 4500 ~) 5,G6 3441 12E0 Lf0 _ __.. BTM__. .... - - Perforations .Summary _ - --- _-- --- _- - __-- Interval TVD Zone Status Ft SPF Date T Comment 7648 - 8880 3548 - 3561 WS B 1232 32 1/31/2008 Slots Alternating solid/slotted pipe, 2.5" x .125 wide in 4 circumferential rows/ft 3" centers 8882 - 12343 3561 - 3577 WS B 3461 32 1/31/2008 Slots Alternating solid/slotted pipe, 2.5" x .125 wide in 4 - circumferential rows/ft 3" PACKER - centers (6761F>762, - 12511 - 13477 3580 - 3610 WS B 966 32 1/31/2008 Slots Altemating solid/slotted pipe, OD:9.210) = = = 2.5" x .125 wide in 4 circumferential rows/ft 3" centers PUP 13788 -14032 3640 - 3653 WS B 244 32 1/31/2008 Slots Alternating solid/slotted pipe, (6762786, 2.5" x .125 wide in 4 OD:4.500) circumferential rows/ft 3" cenfer_s Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2316 1881 CAMCO KBMG DMY 1.0 BK-5 0.000 0 2111/2008 2 4559 2732 GAMCO KBMG DMV 1A BK-5 0000 0 2/11/21M8 HANGER etC.~ - GOMPIETION' Oth@I lU 5 B UIp. , , --- - - ---- - (67s1Fi7s2, De h TVD T e Descri ion ID OD:7.620) 1 1 Heat Trace HEAT TRACE FROM SURFACE TO 3008' 0.000 36 36 HANGER VETCOGRAYTUBINGHANGER 3.500 516 515 NIP CAMCO DB-6 NIPPLE w/NO-GO PROFILE 3.875 6645 3409 GAUGE BAKER GUARDIAN GAUGE CARRIER 3.958 6689 3421 SLEEVE-O BAKER CMD SLIDING SLEEVE w/CAMCO 3.812" DB PROFILE OPEN 3.810 6735 3434 SEAL BAKER LOCATOR SEAL ASSEMBLY 3.990 6741 3436 PBR BAKER POLISHED BORE RECEPTACLE 190-47 3.880 6761 3441 PACKER D-SAND LEM BAKER TOROUEMASTER PACKER (LENGTH f/N0-GO TO TOP OF 4.750 ® ~~ "' PACKER 6762 3441 PACKER D-SAND LEM BAKER TOROUEMASTER PACKER (NO-GO PROFILE INSIDE 4.750 TOROUEMASTER 6762 3441 ANCHOR XO BAKER ANCHOR SEAL ASSEMBLY CROSSOVERS 3.860 6762 3441 PUP D-SAND LEM PUP 3.958 6764 3441 ANCHOR BAKER'ML' ANCHOR SEAL ASSEMBLY 3.860 LINER 6871 14072 I X653 i SHOE i B-SAND LINER SILVER BULLET SHOE i 4 .9.50 i - - -__ - General Notes __ - -- - _- , Date i Note I 2/10/2008 NOTE: MULTI-LATERAL WELL 3K-102 IB-SANDI. 3K-10211 (D-SAND) West Sak 3K-102 SWC.xIs ~ Sidewall Cores 3K-102 Geochem SWC Preliminary Actual Actual Formation MD MD SSTVD i Inches Recovery 1 West Sak B 7557 7557 -3472.12 2" 2 West Sak B 7534 7534 -3471.42 1-1 /2" 3 .West- Sak B 7508 7508- -3470.44 1-1 /2" 4 West Sak B 7488 7488 -3469.51 2" 5 West Salo B 7480 7480 -3469.08- 2" 6 West Sak B 7458. 7458. -3467.73 1-3/4" 7 West Sak B 7435. 7435 -3466.07 2" 8 West- Sak B 7406 ` 7406 -3463.59 2" 9 West Sake DI 7029. 7029 -3414.87 1-3/4" 10 West Salo DI 7025 7025 -3414.26 2" 11 West Sak Dl 7002 7002 -3410.72 1-1/Z" 12" West Sak DI 6980 6980 -3407.25 1-7/8" 13 West Sak DI 6977 6977 -3406.77 2" 14 West Salo DI 6963 6963 -3404.51 1-5/8" 15 West Sak Du 6876 6876 -3389.90 1-7/8" 16 West Sak Du 6862 6862 -3387.50 1-5/8" 17 West Salo Du 6855 - 6855 -3386.29 1-7/8" 18 West Sak Du 6850- 6850 -3385.43 1-5/8" 19 West- Sak Du 6839 - 6839. ~ -3383.52 2" 20 West-Sak Du 6818 6818 -3379.68 2" 21 N Sand 6302- 6302- -3223.29 2" 22 N Sand 6298 6298 -3221.98 No Sam le 23 N Sande 6294 6294 -3220.66 2" 24 N Sand 6285- 6285 -3217.70 1-3/4" 25 U nu A 5926 5926°- -3099.36 2" 26 U nu A 5916 5916 -3096.06 1-3/4" 27 U nu A 5905= 5905 -3092.42 2" 28° U nu A 5895. 5895:- -3089.11 1-1/2" 29 U nu A 5882 5882 -3084.82 1-7/8" 30 U nu B 5769- 5769 -3048.40 1-7/8" 31 U nu B 5765 5765 -3047.13- 1-5/8" 32 U nu B 5740 5740 -3039.25 1-1/2" 33 U nu B 5720 5720 -3032.97 2" 34 U nu B 5680 5680 -3020.45 1-3/4" 35 U nu B 5655 5655 -3012.57 1-7/8" 36 U nu B 5637 5637 -3006.87 1-5/8" 37 U nu B 5619 5619 -3001.13. 1-1/2" 38 Una B- 5605 5605- -2996.65 1-3/8" 39 U nu B 5580 5580 -2988.63 2" 40 U nu B 5568= 5568 -2984.78 1-7/8" 41 U nu B 5555 5555 -2980.62 1-1/2" 42 U nu C 5476 5476 -2955.32 1-1/2" 43 U nu C 5470. 5470 -2953.38 2" 44 U nu C 5448 5448 -2946.22 1-3/4" 45 U nu C 5428 5428 -2939.67 1-3/4" Oi( Quality SWC Formation Count West Sak B 8 West Sak D Lower 6 West Sak D Upper 6 N Sand 3 Ugnu A 5 Ugnu B 12 Ugnu C 4 Total 44 (Misfired) ~ ~ Slotfed and Blank Liner Detail weu: 3K-1oz COf1000 P II+I~ I , $ p 3K-102 B Lateral 5-1/2"Slotted Liner w/ FreeCaps & Blanks Date: 1/31/2008 '~ Alaska, Inc. Rig: Doyon 15 Depth Jt Number Nut~of Well Equipment Description and Comments Page 1 Length Tops 5" DP to SurFace =_> 6839.36 Baker Liner settin tool Does not sta in hole 10.74 68s~ s6 Baker 7" X 9-5/8" MLZXP Liner Hngr Pkr-Length above collet profile OD 8.29" / 6.1,0" „ 12.68 6850.10 Baker 7" X 9-5/8" MLZXP Liner Hanger Packer- below collet O.D. 8.43"/ LD. 6.10" 8.43 " '` 6862.78 Baker "Flex-Lock" Hanger Section O.D. 8.31" / LD. 6.10" 5.27 6871.21 Crossover Bushin 7" H d 563 X 5-1/2" H d 563 O.D. 7..65" / I.D. 4.86" 1.45 6876.48 Baker "Seal Bore Extension" O.D. 6.28" / I.D. 4.75" 19.67 6877.93 Crossover Pup 5-1/2" H d 563 X 5-1/2" H d 521 O.D. 6.08" / I. D. 4.94" 4.11 6897.60 Pup Jt 5-112" H d 521 X 5-1/2" H d 521 O.D. 5.73" / I. D. 4.99" 3.65 6901.71 Jts 151 to 168 18 Jts $-1/2", 15.5 f,.L-80; H dril 521 `flank Casin - 742.71 6905.36 Jts 121 to 150 30 Jts 5-112"' 15.5 f, L-80, H di•il 521 Slotted Casin 1232.19 7648.07 XO Sub 5-1 /2" H d 521 X 5-1 /2", BTC 1.65 8880.26 Jts 71 to 120 50 Jts 5-1/2" :15.5 f L-80 $TCM Slotted cs with for ue: rin s 2112.85 8881.91 Jts 39 to 70 32 Jts 5-1/2", 15.5 f, L-80, BTCM Slotted CS 1348.54 10994.76 Jts 35 to 38 4 Jts 5-112" 15.5. f L-80 BTCM Blank cs 167.72 12343.30 Jts 12 to 34 23 Jts 5-1/2" 15.5 f L-80, BTCM Slotted CS 966.07 12511.02 XO Sub 5-1/2" BTCM box X 4-112" BTC in _.: - 1.3s 13477.09 4-1/2 11.6 f, BTC, L-80, Blank cs W/Tam FreeCa s 35' u f/ in 41.62 13478.47 XO Sub 4-.112" BTC box X 5-1/2" BTC in ~ .~ ~, , 1.40 13520.09 Jts 7 to 11 5 Jts 5-1/2" 15.5 f L-80 BTCM ~ Blank cs 213.64 13521.49 XO S u b 5-1 /2" BTCM box X 4-1 /2", BTC i n _.. 1.39 13735.13 4-1/2" 11.6 f, BTC, L-80, Blank cs w/Tam FreeCa s 12' u f/ in 40.39 13736.52 XO Sub 4-1/2" BTC box X 5-1/2" BTC in .. 1.37 13776.91 Jts 1 to 6 6 Jts 5-1/2", 15.5 f; L-80, BTCM Slotted Casin 253.52 13778.28 5-112" 15.5 f L-80 BTCM Blank CS 40.06 14031.80 5-1/2" Silver Bullet Shoe OD 6.32" 1.69 14071.86 TD 14084' MD 3652' TVD, 90.15 De 14073.55 MLZXP acker oriented 30 de left of hi hside. 14073.55 To of MLZXP 6850.10', 3459' TVD, 80.05 De hole an le 14073.55 Run centalizers one erjointf/jts 1-150 floating. Run the 59 Spiro liders (1-59) 14073.55 Spiroglider (5.5" x 8-1/4", P/N 9099407) Ran from 14031' to 11457' 14073.55 HydroForms (5.5" X 8" , R/N 80589) jts 60-150 Ran from 11457 to 7648'. 14073.55 TAM Free Caps (4-1/2" x 8.375", P/N 11383376) 14073.55 No centralizers on shoe joint and the 4-1 /2"joints w/ TAM FreeCaps. 14073.55 (2) 4-1/2" x 8.375" Tam Free Caps: Set Depth's are 13485.09'& 13764.91' 14073.55 Remarks: Torque: 5-1/2" BTCM ~ 4000 ft-Ibs Avg 10 jts to diamonds, 5-1/2 BTC w/torque rings 4500 ft-Ibs., 7" Hyd 563 to 70 00 ft lbs. Total Footage of each: 5-1/2"= 1974.90' Hyd 521, 2112.85' BTCM w/ Torq Rings, 2989.55' BTCM, 4-1/2" = 82.01' BTC Up Wt 245k Torque Rings In ; Jts 71 Thru jts 121 Dn Wt 125K Block Wt 72K 5.5" rabbitted w/ 4.825" plastic, 4.5" rabbitted w/ 3.833" plastic Mud in the hole 9.3 ppg MOBM Drilling Supervisors: Fred Herbert / Granville Rizek Halliburton Company Survey Report Compam: ConacoPhillips Alaska Inc. Date: 2/19/2008 Time 16:25'10 Page: Field: Kuparuk River Unit Co -ordiuate(NE) Reference VJeIL 3K-102, Tr ue North . Site Kuparuk 3K Pad Ve rtical (TVD) Re ference: 3K-102 (33.8+~0) 73.3 «cll: 3K-102 scc 6on (VS),Refereneet Wsil (O.OON,O.OOF 76.37Azi) weupath: 3K-102 Survey Cakalation Method: Minimum Curvature Db: vracie Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 ~ Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum; Mean Sea Level Geomagnetic Model: bggm2007 Well: 3K-102 Slot Name: 50-029-23378-00 Well Position: +N/-S -524.80 ft Northing: 6007903.98 ft . Latitude: 70 25 57.619 N +E/-W -2.99 ft Easting : 529305.25 ft . Longitude: 149 45 40.017 W Positron Uncertainty: 0.00 ft Wellpath: 3K-102 Drilled From: Well Ref. Point 50-029-23378-00 Tie-on Depth: 40.00 ft Current Datum: 3K-102 (33.8+40) Height 73.80 ft , Above System Datum: Mean Sea Level MagoeticData: 1/5/2008 Declination: 22.96 deg Field Strength: 57630 nT Mag Dip Angl e: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.00 0.00 0.00 76.97 Survey Program for Definitive Wellpath Date: 2/19/2008 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 107.00 456.00 3K-102 Gyro (107.00-456.00) CB-GYRO-SS Camera based gyro single shot 502.52 14053.97 3K-102 MWD+SAG+IIFR+CA+MS (502 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey _. _ MD Incl ~zim TVT) tiysTVD A7/S ElW ~lap~ NIapE Tool ft deg deg ft ft ft ft ft ft ~ ~ 40.00 0.00 0.00 40.00 -33.80 0.00 0.00 6007903.98 529305.25 TIE LINE 107.00 0.12 187.79 107.00 33.20 -0.07 -0.01 6007903.91 529305.24 CB-GYRO-SS 173.00 0.32 332.86 173.00 99.20 0.03 -0.10 6007904.01 529305.15 CB-GYRO-SS 264.00 1.71 326.92 263.98 190.18 1.39 -0.96 6007905.37 529304.28 CB-GYRO-SS 311.00 2.93 328.00 310.94 237.14 3.00 -1.98 6007906.97 529303.26 CB-GYRO-SS 360.00 3.60 325.07 359.86 286.06 5.32 -3.52 6007909.29 529301.71 CB-GYRO-SS 393.00 4.19 320.51 392.79 318.99 7.10 -4.88 6007911.06 529300.34 CB-GYRO-SS 456.00 5.02 315.48 455.58 381.78 10.84 -8.28 6007914.79 529296.93 CB-GYRO-SS 502.52 6.10 309.53 501.88 428.08 13.87 -11,61 6007917.80 529293.58 MWD+IFR-AK-CAZ-SC 597.51 9.81 301.38 595.95 522.15 21.29 -22.42 6007925.18 529282.75 MWD+IFR-AK-CAZ-SC 692.36 14.58 298.64 688.63 614.83 31.23 -39.81 6007935.05 529265.33 MWD+IFR-AK-CAZ-SC 788.03 17.23 300.42 780.63 706.83 44.18 -62.60 6007947.91 529242.49 MWD+IFR-AK-CAZ-SC 882.92 20.60 303.29 870.39 796.59 60.46 -88.68 6007964.09 529216.34 MWD+IFR-AK-CAZ-SC 977.62 24.32 309.27 957.90 884.10 81.96 -117.71 6007985.47 529187.23 MWD+IFR-AK-CAZ-SC 1073.47 25.15 315.91 1044.97 971.17 109.09 -147.17 6008012.48 529157.67 MWD+IFR-AK-CAZ-SC 1168.61 28.47 320.62 1129.88 1056.08 141.15 -175.64 6008044.42 529129.08 MWD+IFR-AK-CAZ-SC 1264.34 33.51 324.93 1211.93 1138.13 180.44 -205.32 6008083.60 529099.24 MWD+IFR-AK-CAZ-SC 1359.93 37.65 327.01 1289.66 1215.86 226.55 -236.39 6008129.58 529067.99 MWD+IFR-AK-CAZ-SC 1453.35 41.64 327.71 1361.58 1287.78 276.74 -268.52 6008179.63 529035.67 MWD+IFR-AK-CAZ-SC 1549.39 44.49 328.80 1431.74 1357.94 332.51 -303.01 6008235.26 529000.97 MWD+IFR-AK-CAZ-SC 1644.78 48.56 329.73 1497.36 1423.56 392.00 -338.36 6008294.61 528965.39 MWD+IFR-AK-CAZ-SC ~ 1740.75 52.01 332.50 1558.68 1484.88 456.64 -373.97 6008359.10 528929.53 MWD+IFR-AK-CAZ-SC 1835.09 52.93 335.11 1616.15 1542.35 523.77 -406.98 6008426.09 528896.26 MWD+IFR-AK-CAZ-SC 1930.96 53.51 337.49 1673.56 1599.76 594.07 -437.83 6008496.27 528865.13 MWD+IFR-AK-CAZ-SC 2025.37 53.35 341.57 1729.83 1656.03 665.08 -464.34 6008567.16 528838.34 MWD+IFR-AK-CAZ-SC 2120.17 56.23 343.72 1784.48 1710.68 739.00 -487.42 6008640.99 528814.98 MWD+IFR-AK-CAZ-SC 2215.71 60.69 346.00 1834.45 1760.65 817.58 -508.64 6008719.48 528793.45 MWD+IFR-AK-CAZ-SC 2310.64 64.18 347.58 1878.38 1804.58 899.50 -527.85 6008801.31 528773.92 MWD+IFR-AK-CAZ-SC 2406.76 65.75 347.86 1919.05 1845.25 984.59 -546.37 6008886.32 528755.07 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report C'umpany: ConoooPhillips Alaska Inc- Date: 2/19J200B Timc 1625:10 1'agc: 3 HicJd: Kuparuk River Unit Co-ordinate~(t~E)Rcicrenee: Well: 3K-102, True North Site Kuparuk 3K Pad ~'crtical(IVD)keference: 3K-102(33.8+40}-.73.8 ~~ell: 3K-102 Section (VS) Reference: Well (O.OON,O.OOE;76.97Azi) Wellpnlh: 3K-102 tiurvey Calculation .~lethud: " Minimum Curvature Db: Oracle Su ivc~ ~'FD Licl lzim I"~D S~~T~'D V/S Fa~~' 11aptY MapT. ~houl ~ ft dey deg ft ft ft ft ft 'ft 2501.28 66.76 351.50 1957.12 1883.32 1069.69 -561.86 6008971.35 528739.25 MWD+IFR-AK-CAZ-SC 2596.49 68.92 354.77 1993.04 1919.24 1157.22 -572.37 6009058.83 528728.39 MWD+IFR-AK-CAZ-SC 2691.71 70.32 356.64 2026.20 1952.40 1246.22 -579.05 6009147.80 528721.37 MWD+IFR-AK-CAZ-SC 2787.46 70.50 1.44 2058.32 1984.52 1336.39 -580.56 6009237.94 528719.50 MWD+IFR-AK-CAZ-SC 2880.62 69.59 6.14 2090.13 2016.33 1423.73 -574.78 6009325.30 528724.93 MWD+IFR-AK-CAZ-SC 2976.89 67.70 10.24 2125.20 2051.40 1512.45 -562.04 6009414.06 528737.33 MWD+IFR-AK-CAZ-SC 3071.87 67.06 15.09 2161.75 2087.95 1597.96 -542.83 6009499.64 528756.20 MWD+IFR-AK-CAZ-SC 3109.84 67.16 17.28 2176.52 2102.72 1631.55 -533.08 6009533.26 528765.82 MWD+lFR-AK-CAZ-SC 3181.98 66.27 18.07 2205.04 2131.24 1694.69 -512.96 6009596.47 528785.69 MWD+IFR-AK-CAZ-SC 3223.71 65.97 20.36 2221.93 2148.13 1730.72 -500.41 6009632,55 528798.10 MWD+IFR-AK-CAZ-SC 3319.60 67.21 23.90 2260.04 2186.24 1812.21 -467.25 6009714,16 528830.93 MWD+IFR-AK-CAZ-SC 3414.26 67.01 28.08 2296.87 2223:07 1890.57 -429.05 6009792.66 528868.82 MWD+IFR-AK-CAZ-SC 3509.64 66.99 31.93 2334.15 22&0.35 196&.58 -385.16 6009868.84 528912.41 MWD+IFR-AK-CAZ-SC 3603.77 67.71 35.99 2370.41 2296.61 2038.61 -336.64 6009941,05 528960.64 MWD+IFR-AK-CAZ-SC 3699.36 67.30 40.31 2407.00 2333.20 2108.05 -282.10 6010010.69 529014.90 MWD+IFR-AK-CAZ-SC 3795.09 67.98 44.22 2443.43 2369.63 2173.54 -222.57 6010076.42 529074.17 MWD+IFR-AK-CAZ-SC 3891.20 67.80 47.69 2479.61 2405.81 2235.44 -158.58 6010138.55 529137.91 MWD+IFR-AK-CAZ-SC 3986.01 67.14 49.23 2515.94 2442.14 2293.51 -93.04 6010196.88 529203.22 MWD+IFR-AK-CAZ-SC 4081.49 66.77 52.05 2553.33 2479.53 2349.22 -25.11 6010252.85 529270.91 MWD+IFR-AK-CAZ-SC 4175.56 67.16 56.38 2590.15 2516.35 2399.83 45.09 6010303.73 529340.91 MWD+IFR-AK-CAZ-SC 4270.61 67.61 60.75 2626.72 2552.92 2445.57 119.94 6010349.76 529415.57 MWD+IFR-AK-CAZ-SC 4365.65 68.59 65.69 2662.18 2588.38 2485.27 198.63 6010389.76 529494.10 MWD+IFR-AK-CAZ-SC 4462.06 68.66 71.07 2697.34 2623.54 2518.33 282.06 6010423.15 529577.38 MWD+IFR-AK-CAZ-SC 4556.93 69.47 76.38 2731.26 2657.46 2543.14 367.08 6010448.29 529662.30 MWD+IFR-AK-CAZ-SC 4652.49 69.97 80.09 2764.40 2690.60 2561.41 454.81 6010466.90 529749.95 MWD+IFR-AK-CAZ-SC 4747.29 71.22 84.12 2795.90 2722.10 2573.68 543.36 6010479.52 529838.44 MWD+IFR-AK-CAZ-SC 4842.39 71.50 84.47 2826.30 2752.50 2582.63 633.02 6010488.83 529928.06 MWD+IFR-AK-CAZ-SC 4937.20 71.21 83.81 2856.61 2782.81 2591.81 722.39 6010498.35 530017.38 MWD+IFR-AK-CAZ-SC 5032.21 71.10 83.54 2887.30 2813.50 2601.71 811.76 6010508.60 530106.70 MWD+IFR-AK-CAZ-SC 5127.57 71.35 82.94 2917.99 2844.19 2612.34 901.41 6010519.58 530196.31 MWD+IFR-AK-CAZ-SC 5223.21 72.34 82.19 2947.79 2873.99 2624.10 991.53 6010531.70 530286.36 MWD+IFR-AK-CAZ-SC 5319.30 71.14 82.07 2977.90 2904.10 2636.59 1081.92 6010544.54 530376.69 MWD+IFR-AK-CAZ-SC 5413.30 70.70 82.72 3008.63 2934.83 2648.35 1169.97 6010556.65 530464.69 MWD+IFR-AK-CAZ-SC 5508.50 71.38 83.04 3039.56 2965.76 2659.51 1259.31 6010568.15 530553.98 MWD+IFR-AK-CAZ-SC 5603.67 71.28 83.19 3070.02 2996.22 2670.32 1348.82 6010579.31 530643.44 MWD+IFR-AK-CAZ-SC 5698.43 71.81 82.55 3100.02 3026.22 2681.48 1438.01 6010590.82 530732.58 MWD+IFR-AK-CAZ-SC 5793.63 71.47 81.46 3130.01 3056.21 2694.04 1527.49 6010603.74 530821.99 MWD+IFR-AK-CAZ-SC ' 5888.18 70.70 81.52 3160.66 3086.86 2707.28 1615.95 6010617.32 530910.39 MWD+IFR-AK-CAZ-SC 5983.93 70.63 81.11 3192.36 3118.56 2720.92 1705.26 6010631.31 530999.64 MWD+IFR-AK-CAZ-SC 6078.56 71.11 81.24 3223.37 3149.57 2734.64 1793.60 6010645.37 531087.92 MWD+IFR-AK-CAZ-SC 6173.94 70.52 81.45 3254.71 3180.91 2748.19 1882.66 6010659.28 531176.91 MWD+IFR-AK-CAZ-SC 6269.74 70.75 81.47 3286.48 3212.68 2761.62 1972.04 6010673.05 531266.23 MWD+IFR-AK-CAZ-SC 6364.36 71.01 82.04 3317.47 3243.67 2774.44 2060.51 6010686.21 531354.65 MWD+IFR-AK-CAZ-SC 6459.26 70.56 82.04 3348.71 3274.91 2786.85 2149.26 6010698.97 531443.34 MWD+IFR-AK-CAZ-SC 6554.55 71.45 84.24 3379.72 3305.92 2797.60 2238.71 6010710.08 531532.73 MWD+IFR-AK-CAZ-SC 6649.10 71.33 87.44 3409.91 3336.11 2804.10 2328.07 6010716.93 531622.06 MWD+IFR-AK-CAZ-SC 6745.33 75.46 88.89 3437.40 3363.60 2807.04 2420.22 6010720.23 531714.18 MWD+IFR-AK-CAZ-SC 6839.79 80.01 89.76 3457.46 3383.66 2808.12 2512.49 6010721.67 531806.44 MWD+IFR-AK-CAZ-SC 6935.37 80.36 90.76 3473.76 3399.96 2807.70 2606.67 6010721.61 531900.61 MWD+IFR-AK-CAZ-SC 7031.11 81.33 91.48 3488.99 3415.19 2805.85 2701.17 6010720.14 531995.11 MWD+IFR-AK-CAZ-SC 7126.32 81.15 89.60 3503.49 3429.69 2804.96 2795.26 6010719.62 532089.19 MWD+IFR-AK-CAZ-SC 7221.45 82.47 89.88 3517.04 3443.24 2805.39 2889.42 6010720.42 532183.34 MWD+IFR-AK-CAZ-SC ~. Halliburton Company Survey Report Company: GonocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: KaUaruk 3K Pad Weil: 3K-102 Wellpath: 3K-102 Survey ~~ID Incl lLim I'! D S}s "h!'U ft dey deg ft ft 7316.87 83.76 89.52 3528.48 3454.68 7411.66 84.83 88.94 3537.90 3464.10 7506.93 87.59 89.96 3544.20 3470.40 7566.46 88.64 89.95 3546.16 3472.36 7652.20 88.38 88.90 3548.39 3474.59 7748.99 88.70 89.62 3550.85 3477.05 7843.54 89.80 91.16 3552.09 3478.29 7937.24 89.75 91.81 3552.46 3478.66 8034.42 89.75 90.66 3552.88 3479.08 8129.62 90.37 89.75 3552.78 3478.98 8224.35 89.87 89.03 3552.58 3478.78 8319.22 89.75 88.74 3552.90 3479.10 8413.98 88.94 86.74 3553.98 3480.18 8506.48 89.19 86.04 3555.49 3481.69 8605.58 88.64 86.06 3557.37 3483.57 8699.87 89.13 86.21 3559.20 3485.40 8795.95 89.75 87.37 3560.14 3486.34 8890.09 89.62 88.29 3560.66 3486.86 8984.44 89.01 88.70 3561.79 3487.99 9079.46 90.35 92.45 3562.32 3488.52 9174.99 90.61 92.83 3561.52 3487.72 9269.84 89.99 95.53 3561.02 3487.22 9365.42 88.82 93.90 3562.01 3488.21 9460.07 89.56 93.18 3563.35 3489.55 9555.93 89.50 93.69 3564.14 3490.34 9651.11 91.50 92.97 3563.31 3489.51 9746.60 90.49 93.61 3561.65 3487.85 9841.56 90.43 92.29 3560.89 3487.09 9937.26 90.92 90.37 3559.76 3485.96 10032.90 90.80 89.51 3558.32 3484.52 10131.95 89.25 89.33 3558.28 3484.48 10223.13 89.26 88.87 3559.47 3485.67 10317.90 89.44 88.92 3560.54 3486.74 10413.43 90.00 90.91 3561.01 3487.21 10508.67 90.55 93.29 3560.55 3486.75 10604.17 91.11 97.87 3559.17 3485.37 10699.32 88.01 97.15 3559.90 3486.10 10796.42 86.91 98.62 3564.20 3490.40 10889.32 88.13 101.12 3568.22 3494.42 10982.52 89.84 104.35 3569.87 3496.07 11077.29 88.70 101.97 3571.08 3497.28 11172.88 88.27 102.85 3573.61 3499.81 11267.83 87.90 102.36 3576.78 3502.98 11363.49 88.39 102.21 3579.88 3506.08 11458.41 90.15 103.29 3581.09 3507.29 11555.25 90.68 102.50 3580.39 3506.59 11648.60 90.61 99.94 3579.33 3505.53 11744.20 90.30 98.87 3578.58 3504.78 11839.36 87.83 99.55 3580.13 3506.33 11934.72 88.82 97.29 3582.92 3509.12 12029.76 91.23 98.02 3582.87 3509.07 12125.42 90.98 96.52 3581.03 3507.23 12220.21 91.23 95.66 3579.20 3505.40 IMtr. /1912008 Yimc 1625:10 P:i~;c: 3 Caordinate(NE)Refcrcncc: Well: 3K-102. True North Vertical ("CVD) Reference: 3K-102 (33.8+40) 73.8 Section(VS)Reference: Well (0-OON.O.OOE,76.97Azi) Survc~ Calculation Method: Minimum Curvature llh: Oracle ~/S E,~lY MapAT ft ft ft 2805. 88 _ . - 2984.14 - --- 6010721. 29 2807. 15 3078.45 6010722. 92 2808. 06 3173.50 6010724. 21 2808. 11 3233.00 6010724. 49 2808. 97 3318.70 6010725. 69 2810. 22 3415.45 6010727. 31 2809. 57 3509.99 6010727. 04 2807. 15 3603.66 6010724. 98 2805. 05 3700.81 6010723. 27 2804. 71 3796.01 6010723. 30 2805. 72 3890.73 6010724. 68 2807. 57 3985.58 6010726. 90 2811. 30 4080.26 6010731. 01 2817. 13 4172.56 6010737. 20 2823. 95 4271.41 6010744. 41 2830. 31 4365.47 6010751. 13 2835. 68 4461.39 6010756. 89 2839. 25 4555.46 6010760. 82 2841. 73 4649.77 6010763. 67 2840. 77 4744.76 6010763. 09 2836. 37 4840.19 6010759. 06 2829. 46 4934.78 6010752. 52 2821. 60 5030.02 6010745. 04 2815. 76 5124.48 6010739. 57 2810. 02 5220.16 6010734. 20 2804. 49 5315.17 6010729. 05 2799. 01 5410.49 6010723. 95 2794. 12 5505.32 6010719. 43 2791. 90 5600.98 6010717. 59 2792. 00 5696.61 6010718. 06 2793. 01 5795.65 6010719. 45 2794. 44 5886.81 6010721. 24 2796. 26 5981.56 6010723. 44 2796. 41 6077.08 6010723. 96 2792. 92 6172.25 6010720. 84 2783. 63 6267.26 6010711. 94 2771. 20 6361.58 6010699. 87 2757. 89 6457.67 6010686 .95 2741. 99 6549.10 6010671. 40 2721. 45 6639.97 6010651. 22 2699. 87 6732.24 6010630 .01 2679. 34 6825.56 6010609 .84 2658. 63 6918.17 6010589. 50 2638. 29 7011.59 6010569. 53 2617. 34 7104.16 6010548 .95 2595. 73 7198.55 6010527 .71 2577. 57 7290.10 6010509 .91 2561. 95 7384.42 6010494 .66 2546. 72 7478.33 6010479 .80 2532. 76 7572.61 6010466 .22 2520. 10 7666.80 6010453 .93 2508. 00 7761.67 6010442 .20 2497. 95 7855.91 6010432 .52 MapF: ~I'oul ft 532278.05 MWD+IFR-AK-CAZ-SC 532372.35 MWD+IFR-AK-CAZ-SC 532467.38 MWD+IFR-AK-CAZ-SC 532526.87 MWD+IFR-AK-CAZ-SC 532612.57 MWD+IFR-AK-CAZ-SC 532709.30 MWD+IFR-AK-CAZ-SC 532803.83 MWD+IFR-AK-CAZ-SC 532897.49 MWD+IFR-AK-CAZ-SC 532994.65 MWD+IFR-AK-CAZ-SC 533089.84 MWD+IFR-AK-CAZ-SC 533184.55 MWD+IFR-AK-CAZ-SC 533279.38 MWD+IFR-AK-CAZ-SC 533374.03 MWD+IFR-AK-CAZ-SC 533466.30 MWD+IFR-AK-CAZ-SC 533565.11 MWD+IFR-AK-CAZ-SC 533659.13 MWD+IFR-AK-CAZ-SC 533755.02 MWD+IFR-AK-CAZ-SC 533849.07 MWD+IFR-AK-CAZ-SC 533943.36 MWD+IFR-AK-CAZ-SC 534038.35 MWD+IFR-AK-CAZ-SC 534133.78 MWD+IFR-AK-CAZ-SC 534228.38 MWD+IFR-AK-CAZ-SC 534323.65 MWD+IFR-AK-CAZ-SC 534418.12 MWD+IFR-AK-CAZ-SC 534513.82 MWD+IFR-AK-CAZ-SC 534608.84 MWD+IFR-AK-CAZ-SC 534704.17 MWD+IFR-AK-CAZ-SC 534799.01 MWD+IFR-AK-CAZ-SC 534894.67 MWD+IFR-AK-CAZ-SC 534990.29 MWD+IFR-AK-CAZ-SC 535089.31 MWD+IFR-AK-CAZ-SC 535180.46 MWD+IFR-AK-CAZ-SC 535275.19 MWD+IFR-AK-CAZ-SC 535370.70 MWD+IFR-AK-CAZ-SC 535465.87 MWD+IFR-AK-CAZ-SC 535560.91 MWD+IFR-AK-CAZ-SC 535655.27 MWD+IFR-AK-CAZ-SC 535751.39 MWD+IFR-AK-CAZ-SC 535842.88 MWD+IFR-AK-CAZ-SC 535933.82 MWD+IFR-AK-CAZ-SC 536026.16 MWD+IFR-AK-CAZ-SC 536119.56 MWD+IFR-AK-CAZ-SC 536212.24 MWD+IFR-AK-CAZ-SC 536305.73 MWD+IFR-AK-CAZ-SC 536398.37 MWD+IFR-AK-CAZ-SC 536492.84 MWD+IFR-AK-CAZ-SC 536584.45 MWD+IFR-AK-CAZ-SC 536678.81 MWD+IFR-AK-CAZ-SC 536772.78 MWD+IFR-AK-CA2-SC 536867.11 MWD+IFR-AK-CAZ-SC 536961.33 MWD+IFR-AK-CAZ-SC 537056.24 MWD+IFR-AK-CAZ-SC 537150.50 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Cen,pany: Cr~nccoPhillipsAlaska Inc. Ih~te: 2/1 912 0 0 8 lime: 1625:10 Page: J Field: Kuparuk River Unit ('u-ordinnte(NE) Reference Well: 3K-102. True North Site: Kuparuk 3K Pad L~erticaG('['VD) Reference 3K-102(33:b+40) 73.8 Well: 3K-102 Section (VS) Reference: Well (O.OON,O OOE76.97Azi) Wellpath; 3K-102 Survey CakulationMelhod: Minimum Curvature Db: Oracle Su~~'ey ]btl) fncl Ai.im T~ U Svs'I'1'D A%S E/W MapN bfapE I"ool ft deg deg ft ft ft ft ft ft 12315.24 91.54 97.29 3576.90 3503.10 2487.23 7950.30 6010422.18 537244.93 MWD+IFR-AK-CAZ-SC 12410.29 89.75 95.99 3575.83 3502.03 2476.25 8044.70 6010411.56 537339.36 MWD+IFR-AK-CAZ-SC 12506.41 86.16 95.44 3579.26 3505.46 2466.68 8140.26 6010402.37 537434.96 MWD+IFR-AK-CAZ-SC 12601.62 87.27 96.75 3584.72 3510.92 2456.59 8234.78 6010392.65 537529.50 MWD+IFR-AK-CAZ-SC 12696.55 88.32 101.18 3588.37 3514.57 2441.81 8328.45 6010378.24 537623.22 MWD+IFR-AK-CAZ-SC 12791.35 89.19 103.82 3590.43 3516.63 2421.30 8420.97 6010358.10 537715.81 MWD+IFR-AK-CAZ-SC 12885.91 89.50 101.90 3591.52 3517.72 2400.25 8513.15 6010337.42 537808.06 MWD+IFR-AK-CAZ-SC 12981.56 89.35 98.32 3592.48 3518.68 2383.47 8607.30 6010321.00 537902.27 MWD+IFR-AK-CAZ-SC 13078.44 89.82 98.50 3593.18 3519.38 2369.30 8703.13 6010307.21 537998.15 MWD+IFR-AK-CAZ-SC 13171.89 90.67 96.59 3592.78 3518.98 2357.03 8795.77 6010295.31 538090.82 MWD+IFR-AK-CAZ-SC 13267.23 87.89 95.60 3593.98 3520.18 2346.91 8890.55 6010285.56 538185.63 MWD+IFR-AK-CAZ-SC 13362.25 85.98 95.31 3599.06 3525.26 2337.89 8985.00 6010276.91 538280.11 MWD+IFR-AK-CAZ-SC 13457.97 83.81 95.43 3607.57 3533.77 2328.96 9079.92 6010268.36 538375.05 MWD+IFR-AK-CAZ-SC 13552.50 83.56 96.32 3617.97 3544.17 2319.35 9173.38 6010259.12 538468.54 MWD+IFR-AK-CAZ-SC 13648.58 84.37 98.68 3628.07 3554.27 2306.88 9268.10 6010247.02 538563.30 MWD+IFR-AK-CAZ-SC 13744.16 84.68 96.38 3637.19 3563.39 2294.41 9362.42 6010234.92 538657.66 MWD+IFR-AK-CAZ-SC 13839.23 86.92 98.58 3644.16 3570.36 2282.07 9456.41 6010222.95 538751.69 MWD+IFR-AK-CAZ-SC 13933.24 86.72 98.86 3649.37 3575.57 2267.83 9549.19 6010209.08 538844.52 MWD+IFR-AK-CAZ-SC 14027.95 89.25 97.84 3652.70 3578.90 2254.09 9642.83 6010195.71 538938.20 MWD+IFR-AK-CAZ-SC 14053.97 90.15 100.11 3652.84 3579.04 2250.03 9668.53 6010191.75 538963.91 MWD+IFR-AK-CAZ-SC 14084.00 90.15 100.11 3652.76 ~ 3578.96 2244.76 9698.10 6010186.60. 538993.49 • PROJECTED t0 TD ~~ ConoCOPhitlips Time Log Summary WelNlew 6Yeb ReAOrtfng Well Name: 3K-102 Job Type: DRILLING ORIGINAL Ti L cJs -- - - Date From To Dur S,~De th E_ Depth Phase Code Subcode T CQM 12/31/2007 00:00 06:00 6.00 MIRU MOVE DMOB P Raise work platform for BOPE & Clean cellar Box, Prep cellar for move, Continue cleaning pollution pan, Removing 5" D.P. f/ pipe shed, Continue cleaning pits, Rig down Choke lines between Pit & Sub complexes, Rig down Choke line, Mud bucket drain line, Bleed off line & Cement line in no mans land under floor to prep to skid rig floor, Move break shack next to truck shop, Remove beaver slide, Blow down mud & centrifical pumps, Lower strong backs in pipe shed & pin same, Blow down water & steam lines, Disconnect same, Rig down hole fill, cellar pump & vac. lines inner connect. 06:00 07:45 1.75 MIRU MOVE DMOB P Skid rig floor back, Finish cleaning its. 07:45 08:30 0.75 MIRU MOVE DMOB P Pick up support feet for Sub base & secure cellar for ri move. 08:30 09:45 1.25 MIRU MOVE DMOB P Move cuttings boxes from Rockwasher. 09:45 10:45 1.00 MIRU MOVE DMOB P Move Rockwasher to front of Pad entrance. 10:45 12:00 1.25 MIRU MOVE DMOB P Warm up moving system on Pits & ick u herculite from Rockwasher. 12:00 15:00 3.00 MIRU MOVE DMOB P Move Pits Module & stage away from Sub Module. 15:00 17:00 2.00 MIRU MOVE DMOB P Move Sub Module out from Well 1J-174 & Turn around. 17:00 18:00 1.00 MIRU MOVE DMOB P Move & Stage Pit Module at entrance of Pad. 18:00 22:00 4.00 MIRU MOVE DMOB P Move & Stage Sub Module at entrance of Pad. 22:00 00:00 2.00 MIRU MOVE DMOB P Depart 1J-Pad with both the Sub & Pit Modules movin to 3K-Pad. 01/01/2008 00:00 06:00 6.00 MIRU MOVE MOB P Continue moving both the Sub & Pit Modules from 1J pad, moving to 3K-Pad. Modules are at the Spine road at 0600 hrs 1-1-2008. 06:00 12:00 6.00 MIRU MOVE MOB P Continue moving both the Sub & Pit Modules from the 1J/Spine access road, moving to 3K-Pad. Modules are on the Spine road in front of KCC @ 1200 hrs 1-1-2008. Page "l oaf 42 1 J Time Logs _ _ _ _ i Date From To Dur S De th E De th Phase CodeSubcode T COM 01/01/2008 12:00 __ 20:00 8.00 MIRU MOVE OTHR NP Waiting for Shared services flights into/out of Kuparuk. Doyon was asked to wait until after 7 pm (Field wide crew change)1-1-2008 before continuing to move. While waiting: Repair hinge pin retaining cap on the driller's side jacks on the sub module. Clean rig. Aquire 2500 gallons of fuel while in front of KCC. 20:00 00:00 4.00 MIRU MOVE MOB P Continue moving both the Sub & Pit Modules from the KCC/Spine road, moving to 3K-Pad. Modules are on the S ine road /1A 2359 hrs 1-1-2008. 01/02/2008 00:00 02:00 2.00 MIRU MOVE MOB P Continue moving both the Sub & Pit Modules from the 1A/Spine road, moving to 3K-Pad. Hinge assembly of sub module rear broke. Back up the it module to the 1A/S ine access. 02:00 08:00 6.00 MIRU MOVE RGRP T Welder working to fix the hinge assembly (steering) (cellar end) of sub module. 08:00 10:30 2.50 MIRU MOVE MOB P Continue moving both the Sub & Pit Modules from the 1A/Spine road to the 1R/1G access road. Hinge assembly of sub module (front left) broke. 10:30 15:00 4.50 MIRU MOVE RGRP T Welder working to fix the hinge assembly (steering) (front left) of sub module. 15:00 19:00 4.00 MIRU MOVE OTHR NP Doyon was asked to wait until after 7 pm (Field wide crew change) 1-2-2008 before continuin to move. 19:00 20:30 1.50 MIRU MOVE MOB P Continue moving both the Sub & Pit Modules from the 1AlSpine road to the KCS Y/Oliktock access road. 20:30 23:15 2.75 MIRU MOVE MOB P Continue moving both the Sub & Pit Modules from the KCS Y/Oliktock access road to 1Q pad/Oliktock Road wide s ot. 23:15 00:00 0.75 MIRU MOVE RGRP T Hinge assembly of sub module (rear right) broke. Welder working to fix the hinge assembly (steering) (rear right) of sub module. NOTE: Repairs completed @ 02:30 hrs 1/3/2008. Rolling up hoses and allowing weld to cool off. Will wait until) 06:00 hrs(CPF 3 and STP will have their crew changes completed) to begin moving a ain. 01/03/2008 00:00 02:30 2.50 MIRU MOVE RGRP T Hinge assembly of sub module (rear right) broke. Welder working to fix the hinge assembly (steering) (rear right) of sub module. 02:30 06:00 3.50 MIRU MOVE OTHR NP Doyon was asked to wait until after 6 am (CPF 3 &STP crew change) 1-3-2008 before continuin to move. \. ~i Time Logs _ Date From To Dur S D_ epth E. De th Phase Code Subcode T COM 01/05/2008 20:00 20:45 0.75 MIRU WELCT BOPE P Tag fill inside of the conductor @ 103'. Pickup and then perform Function Test of the diverter system. Witness of test waived by AOGCC inspector John Crisp. Annular closed on 5"drill pipe in 30 seconds. The knife valve opened in 27 seconds. Koomey test: 3000 psi initial, 1800 psi after functioning annular and knife valve. 200 psi increase in 50 seconds, full charge in 2 minutes 45 seconds. 5 bottles of nitrogen f/ backup w/ average of 2425 si. 20:45 21:30 0.75 0 63 SURFA DRILL PULD P PU/MU BHA #1: Pickup Sperry Sun motor and MU the Hughes 16" MX-1 bit. Pickup/Makeup the Sperry Sun Evador EM NM drill collar and welded blade stabilizer. Run in the hole 21:30 00:00 2.50 63 63 SURFA DRILL OTHR T Installing Sperry Sun probe in the Evador Non Mag Drill collar. The stabilizer fins on the probe would not go into the collar. Reason was that the OD of fins was 3.5" and the plastic spacers in a connection had 3.25" ID. Break connection, remove shims, trim the ID, so that the stabilizer fins of the probe would go past the connection shims. 01/06/2008 00:00 00:45 0.75 0 0 SURFA DRILL PULD P Continue installing Sperry Sun probe in the Evador Non Mag Drill collar. Pickup and makeup the index sub, antenna sub, float sub and UBHO sub. Orient Sperry MWD with the motor and orient the UBHO sub. 00:45 01:00 0.25 0 0 SURFA DRILL OTHR P Rig up Sperry Sun gyro. 01:00 01:30 0.50 0 0 SURFA DRILL PULD P PU one flex non mag drill collar, then make a top drive connection on the first stand of 5" HWDP. 01:30 02:00 0.50 0 0 SURFA DRILL OTHR P Fill conductor with water. Check for leaks-OK. Pressure test mud lines to 3000 si-OK. 02:00 02:15 0.25 0 0 SURFA DRILL OTHR P Clean out the conductor. Pumping 450 m, rotatin 40 r m. 02:15 04:15 2.00 0 195 SURFA DRILL DRLG P Spud well 3K-102. Drilling 16" surface hole. 04:15 05:00 0.75 195 195 SURFA DRILL TRIP P Stand back a stand of 5" HWDP with the jars. PU 2 flex drill collars. Make a to drive connection. 05:00 06:00 1.00 195 259 SURFA DRILL DRLG P Drill 16" surface hole. 06:00 10:45 4.75 259 542 SURFA DRILL DDRL P Kick off and directional drill 16" surface hole. G ro each stand. 10:45 12:00 1.25 542 0 SURFA DRILL TRIP NP Pull out of the hole due to super suckers unable to service rig (Rig in the road around the Kuparuk River brid a .Clean cla off of the BHA. f~aga 5 z~f ~2 Time Logs _ i Date From To _ Dur S De th E. Depth Phase Code Subcode T C_OM 01/08/2008 17:00 17:45 ~ 0.75 130 216 SURFA CASIN RNCS P P/U Jt's 4 & 5; Fill Pipe & Circ 17:45 18:00 0.25 216 216 SURFA RIGMN OTHR NP Attempt to Switch to high Line Power; Rig Went Off-Line; Retried X 2 w/ Same Results; Rig Back on own En fines 18:00 00:00 6.00 216 2,560 SURFA CASINC RNCS P Continue RIH f/ 216 - 2560' MD; Fill Pipe Every 5 Jts and Gather T & D Data Every 10; CBU @ 1067' MD @ 5 BPM & Circ'ed 145 Bbls @ 2100' MD @ 6 BPM; Saw No Obstructions While Runnin in Hole 01/09/2008 00:00 01:00 1.00 2,560 3,090 SURFA CASINC RNCS P Continue RIH f/ 2560' to 3090'. Fill Pipe Every 5 Jts and Gather T & D Data Every 10. Circulate 5 bpm w/ 250 psi a total of 50 bbls while running jt # 73 in the hole. Saw no obstructions while runnin in the hole. 01:00 02:00 1.00 3,090 3,090 SURFA RIGMN RGRP T Attempt to remove Frank's fillup tool, but a problem with the top drive would not allow the top drive to perfrom. Continue to circulate and c-cndition mud, reciprocate pipe 35' while Rig electrician travels from Kuparuk base camp to the rig. Circulated another 212 bbls. Pumping 5 bpm w/ 250 psi. PU wt 255k, SO wt 155k. 02:00 02:45 0.75 3,090 3,143 SURFA CASINC RNCS P Make up Vetco/Gray hanger using the shorter handling joint, slack off and set slips on the pup of the hanger. Then remove the short landing joint, makeup the long landing joint. Pickup and remove the slips. Run in the hole and land on the hanger @ 0245 hrs 1-9/2008. Shoe depth 3143.24'. PU wt 250k, SO wt 155k. 02:45 03:00 0.25 3,143 3,143 SURFA CASINC CIRC P Circulate with Frank's fillup tool. Circulated a total of 65 bbls. Initial circulating rate 5 bpm w/ 240 psi, then pumping 6 bpm w/ 300 psi. Rig up tongs to break the Frank's fillup tool. A total of 552 bbls of mud was circulated while runnin casin . 03:00 03:45 0.75 3,143 3,143 SURFA CASIN RURD P Break off the Frank's fillup tool. Lay down same. Blow down the to drive. 03:45 04:00 0.25 3,143 3,143 SURFA CEME~ RURD P Rig up Dowell cement adapter and cement head. Connect 2" cementing hose. Secure lines and cement head. ~'~g~ i of 42 Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T COM 01/09/2008 04:00 05:15 1.25 3,143 3,143 SURFA CEME CIRC P Circulate and condition mud prior to the cement job. Circulate a total of 517 bbls with the cement head. Start off with 4.8 bpm w/ 150 psi, then 6 bpm w/ 200 psi, after pumping 100 bbls increase rate to 7 bpm w/ 270 psi. Final mud properties: 9.3 ppg MW, 51 vis, PV 21 YP 12, gels 3/4. Reciprocate pipe 35'. PU wt 255k, SO wt 160 to 170k.. Pre job safety meeting for the cement job was conducted while circulatn ,with all arties. 05:15 05:30 0.25 3,143 3,143 SURFA CEME SFEO P Dowell pump 10 bbls of CW 100, shut down. Pressure test lines to 3000 si. 05:30 07:45 2.25 3,143 3,143 SURFA CEME OTHR P Dowell continue to pump a total of 50 bbls CW100 (8.3 ppg), pumping 4-5 bpm w! 78 psi, follow with 46.2 bbls of MudPush with red dye (10.5 ppg), drop bottom plug, mix and pump 531.4 bbls of lead (ASlite) (10.7 ppg), follow with 108.8 bbls of tail (DeepCrete) (12 ppg), then drop the top plug. _Reciprocated pipe 35' strokes until CW 100 was at the shoe. After Lead cement was to the shoe continued to reci rocate 10' strokes. Quit reciprocating @ 0725 hrs (after um in 30 bbls of tail cement) (90.8 bbls of lead cement around the shoe . 07:45 09:00 1.25 3,143 3,143 SURFA CEME DISP P Dowell displace (clean up lines behind the plug) pumping 6.4 bpm w/ 156 psi with 20 bbls of water, then the rig pumps continue the displacement pumping 9.3 ppb mud. Rig pumping 9.3 ppg mud treated w/ 12 sx SAP and 12 sx bi Garb @ 7 bpm with initial 320 psi final 580 psi. Slowed the rate down to 3 bpm w/ 440 psi -20 bbls prior to bumping the plug. Plug bumped on calculated strokes with 500 psi over final pressure. Cement in place @ 0900 hrs 1-9-2008. A total of 141.4 bbls of good 10.7 cement was circulated to surface. 09:00 09:15 0.25 3,143 3,143 SURFA CEME OTHR P Hold 940 psi for 5 min. Bleed off pressure, check floats- holding. Blow down the cement line. 09:15 10:00 0.75 3,143 3,143 SURFA CEME RURD P Rig down cement equipment. Clean floor. 10:00 11:00 1.00 3,143 3,143 SURFA CASIN( RURD P Break and lay down the landing joint (LH Stub Acme thread}. Lay down casing tools. Lay down cementing tools. PU Sperry Sun GeoPilot Flex collar and ut in the i e shed. Page 8 of A2 C~ Time Logs -- _ Date From To Dur S Depth E. De th Phase Code Subcode T COM __ __ 01/09/2008 11:00 14:30 3.50 3,143 3,143 SURFA WELL NUND P Nipple down diverter system: Flow line, riser, diverter "T', Vetco/Gray quick connect. Remove equipment from the cellar. 14:30 16:15 1.75 3,143 3,143 SURFA WELCT NUND P Bring into the cellar the Vetco/Gray multibowl. Orient wellhead. Test sealsub and Graylock seal (Casing to wellhead seal) to 5000 psi for 10 min. Rig up the choke lines on top of the pit module. 16:15 20:45 4.50 3,143 3,143 SURFA WELCT NUND P Install riser to wellhead, NU BOP stack, double valve annulus, connect choke line to the BOP stack. Make up kill line, choke fine, flowline and drilling nipple. Install plates around the bell nipple. Install master bushings. Attatch drain hoses to the drip pan. Rig down long bales, install the mousehole. 20:45 23:00 2.25 3,143 3,143 SURFA WELCT OTHR P Rig up to test the BOPE. Pick up a 5" test joint and lower test plug. Line up the choke manifold, rig up testing equipment with a chart recorder. Fill stack and choke manifold with water. Function test BOP's before starting test. 23:00 00:00 1.00 3,143 3,143 SURFA WELC BOPE P Test BOPE. Witness of test waived by AOGCC inspector Bob Noble. Testing 250 psi low and 3000 psi high. Hold each test f/ 5 min. 01/10/2008 00:00 02:15 2.25 SURFA WELCT BOPE P Continue testing BOPE. Witness of test waived by AOGCC inspector Bob Noble. Testing 250 psi low and 3000 psi high. Hold each test f/ 5 min, chart test. 02:15 06:00 3.75 SURFA WELC BOPE T Continue testing BOPE. Witness of test waived by AOGCC inspector Bob Noble. Testing 250 psi low and 3000 psi high. Hold each test f/ 5 min, chart test. Note: During test: Annular tested w/ 5" test joint. Manual and HCR valve on choke line failed--greased and worked -- retested-OK. Upper pipe rams (3-1 /2" x 6" variables) tested with 5", failed on 5.5". Choke pressure guage not working. Electrician tried to calibrate it. Still working on it. Will use the chart recorder guage by the choke panel for casing pressure guage. Koomy was tested: initial 3075 psi, 1550 psi after closing, 200 psi buildup in 52 seconds, full charge in 3 min 18 seconds, 5 bottle avers a 2400 si. Pa~g~ 9 of 42 C Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM ~ 01/10/2008 06:00 08:30 2.50 SURFA WELCT BOPE T Continue testing BOPE. Witness of test waived by AOGCC inspector Bob Noble. Testing 250 psi low and 3000 psi high. Hold each test f/ 5 min, chart test. Lower pipe rams were tested w/ the 9-5/8" test joint. "O" ring seal on the face of the 4-1/2" IF connection on the 9-5/8" test joint failed. Replaced "O" ring --retested- OK.. Rig down the 9-5/8" test joint. Lay down same. Drain stack, blow down choke manifold. Gas detectors were tested. 08:30 10:00 1.50 110 SURFA RIGMN RGRP T Change the upper pipe rams from 3-1 /2" x 6" variables to 4-1/2" x7" variables. 10:00 11:00 1.00 110 SURFA WELCT BOPE T PU the 5" test joint and make up the lower test plug. Run in and set the test plug. Test the 4-1 /2" x 7" variable rams to 250 psi low and 3000 psi high. Hold each test 5 minutes. Test against the HCR choke and HCR kill line valves. Lay down the 5" test joint, pickup the 5.5" test joint. Test the 4-1 /2" x 7" variables with the 5.5" test joint, same low and high and valves tested. 11:00 11:30 0.50 SURFA WELCT OTHR P Rig down and lay down 5.5" testjoint and lower test plug. Make up the running tool and set the wear bushing. Lay down the running tool. Blow down choke and kill lines. Close the lower annulus valve. 11:30 12:15 0.75 SURFA DRILL PULD P Bring tools to the floor for BHA #2. 12:15 14:00 1.75 0 110 SURFA DRILL PULD P PU BHA #2. Make up the bit, geopilot, geo flex collar, smart stab, 8" Gamma/Res/PWD/HCIM, Nuetron Densit , ulsar and nm float sub. 14:00 15:15 1.25 110 110 SURFA DRILL OTHR P Upload MWD. Gamma calibration was not ood. 15:15 16:30 1.25 110 34 SURFA DRILL PULD T Lay down pulsar, Nuetron Density, Gamma/Res/PWD/HCIM 16:30 17:15 0.75 34 110 SURFA DRILL PULD T Pickup/Makeup Gamma/Res/PWD/HCIM, Nuetron Densit , ulsar and nm float sub. 17:15 18:45 1.50 110 110 SURFA DRILL OTHR T Upload MWD. Gamma calibration ok. Load sources. 18:45 19:30 0.75 110 393 SURFA DRILL TRIP P Continue to MU BHA #2. 19:30 22:00 2.50 393 2,970 SURFA DRILL PULD P Pickup/makeup run in the hole 81 joints of 5" drill pipe from the pipe shed. 22:00 23:30 1.50 2,970 3,054 SURFA DRILL CIRC P Make a top drive connection, then tag up @ 3054'. Pumping 810 gpm w/ 1850 psi. Rotate 30 rpm w/ 10k ft Ibs of torque. PU wt 150k, SO wt 105k, rotatin wei ht 125k. I~~e 1ti ot~Z \~ Time Logs __ Date From To Dur S De th E. De th Phase Code Subcode T COM 01/10/2008 23:30 00:00 0.50 3,054 2,970 SURFA DRILL OTHR P _ Stand back a stand. Rig up to test 13-3/8" casin . 01/11/2008 00:00 01:00 1.00 2,970 2,970 SURFA CASIN DHEO P Test 13 3/8" Surtace Casing to 3,000 PSI; Chart Pressure Sensor Failed Durin Test & Chart was Invalidated 01:00 01:30 0.50 2,970 2,970 SURFA RIGMN' RGRP T Replace Charting Tool Sensator 01:30 02:30 1.00 2,970 2,970 SURFA CASIN DHEO P uccessfully Tested 13 3/8" Casing to , 3,000 PSI & Held Pressure for 30 _ Minutes Pum ed 5.7 Bbls for Test w/ 5.7 Bbl Bleed Back 02:30 02:45 0.25 2,970 2,970 SURFA CASIN( RURD P Rig Down Casing Testing Equipment 02:45 03:00 0.25 2,970 2,970 SURFA RIGMN SFTY P PJSM for Cut & Slip Drill Line 03:00 04:00 1.00 2,970 2,970 SURFA RIGMN SVRG P Cut /Slip 1 3/8" Drill Line (102'), Change Saver Sub, Service Drawworks, Top Drive, Blocks, & Crown 04:00 04:15 0.25 2,970 2,970 SURFA RIGMN SFTY P PJSM Change Saver Sub 04:15 05:45 1.50 2,970 2,970 SURFA RIGMN RGRP P Change Saver Sub 05:45 06:00 0.25 2,970 2,970 SURFA RIGMN SFTY P PJSM Service Crown, Blocks, ~ Top Drive 06:00 07:00 1.00 2,970 2,970 SURFA RIGMN SVRG P Service Topr Drive, Crown, & Blocks 07:00 08:30 1.50 2,970 3,150 SURFA CEME COCF P Pick Up stand Previously Stood Back & Drill Cement, Cement Plugs, Float Collar, Shoe f/ 3054' (Collar) - 3150' MD 08:30 09:00 0.50 3,150 3,170 SURFA DRILL DRLG P Drill 20' New Hole f/ 3150' - 3170' MD; Flow 780 GPM @ 1680 PSI; 70 RPM, P/U 160, S!O 108, Rot 130; Torque 9 - 13 09:00 10:00 1.00 3,170 3,170 SURFA DRILL CIRC P Cir & Condition Mud; Displace Wellbore f/ S ud Mud to LSND 10:00 10:45 0.75 3,170 3,140 SURFA DRILL RURD P POOH into Casing @ 3140' MD; Blow Down To Drive & Ri U for LOT 10:45 11:15 0.50 3,140 3,140 SURFA DRILL LOT P Perform LOT w/ 8.8 PPG LSND per Well Plan; Pumped 3.1 Bbls for Test Leak Off Occurred 776 PSI - EMW 15.6 PPG' Fra r PSI 11:15 11:45 0.50 3,140 3,140 INTRM1 DRILL RURD P Rig Down LOT Equipment & Blow Down Kill Line 11:45 12:00 0.25 3,140 3,170 INTRM1 DRILL TRIP P RIH f/ 3140' - 3170' MD, Get Survey, Down Link, Set Drilling Parameters, & Calibrate Draw Works De th Encoder 12:00 18:00 6.00 3,170 4,190 INTRM1 DRILL DDRL P Ddrl f/ 3170' - 4190' MD; 1020 GPM @ 1860 PSI; WOB 20, P/U 185, S/O 115, Rot 138; ECD = 9.29 18:00 00:00 6.00 4,190 4,897 INTRM1 DRILL DDRL P Ddrl f/ 4190' - 4897' MD; 1040 GPM @ 2190 PSI; WOB 10, P!U 220, S/O 115, Rot 145; ECD = 9.52; Max EPOCH Gas = 40 Units 4~aae i 1 of 42 • Time Logs _ Date From To Dur_ S De th E. Depth Phase Code Subcode T COM _ 01/12/2008 00:00 06:00 6.00 4,897 5,786 INTRMI DRILL DDRL P Ddrlg f/ 4897' - 5786' MD; 1040 GPM @ 2550 PSI; P/U 240, S/O 105, Rot 145; ECD = 9.96; Max EPOCH Gas 530 units 06:00 12:00 6.00 5,786 6,488 INTRM1 DRILL DDRL P Directional drill 12-1 /4" intermediate hole. 12:00 17:00 5.00 6,488 6,885 INTRM1 DRILL DDRL P Directional drill 12-1/4" intermediate hole. 17:00 17:30 0.50 6,885 6,885 INTRM1 DRILL CIRC P Observed flow increase f/ 37% to 40%.. Pulled off bottom. Shut down pumps to observe well. Gas cut mud w/ EPOCH reading 650 units of gas. Turn on the degasser, monitor gains/losses while circulating bottom's up. Circulating 6883'/ 3464' TVD. Max gas observed 1457 units from drilled depth of 6880'. Too of the West Rak "D" at a rox 6796' MD/ 3449' TVD. 17:30 18:00 0.50 6,885 6,887 INTRMI DRILL DDRL P Directional drill 12-1/4" intermediate hole. 18:00 00:00 6.00 6,887 7,552 INTRM1 DRILL DDRL P Ddrl f/ 6887'-7552' MD; ECD = 10.02; Avg EPOCH Gas = 200 - 250 Units w/ Three Spikes to _ 1100 Units Between 6895' - 7095' MD 01/13/2008 00:00 00:15 0.25 7,552 7,600 INTRM1 DRILL DDRL P Ddrl f/ 7552' - 7600' MD' (TD); 960 GPM @ 2850 PSI; ECD = 10.05; Max EPOCH Gas 2240 Units 00:15 01:00 0.75 7,600 7,600 INTRMI DRILL CIRC P CBU; Pumping 1030 GPM with 3160 PSI; ECD = 10.04; Max EPOCH Gas 2240 Units & Dropped to 450 Units After B/U 01:00 01:30 0.50 7,600 7,600 INTRM1 DRILL OTHR P Obtain MWD Survey; Take SPR, Blow Down Top Drive; EPOCH Gas Increased to 750 Units After Circulation Started 01:30 02:00 0.50 7,600 7,600 INTRM1 DRILL OWFF P Observe Well For Flow (Static). Drop a 2.46" OD rabbit with 110' of slickline for a tail. 02:00 02:45 0.75 7,600 7,535 INTRM1 DRILL CIRC P Pull Up & Circulate High Weight /High Vis Sweep (10.4 PPG, 230 Vis); Pumping 975 GPM with 2950 PSI; Pumped 56 bbls. Sweep Resulted in Slight Cuttings Increase; ECD = 10.01; Max EPOCH Gas 1310 Units 02:45 03:30 0.75 7,535 7,060 INTRM1 DRILL REAM P BROOH f/ 7535' - 7060' MD. Pulling speed 30 -35 feet per minute; RPM 120, Torque 20K; Pumping 1006 gpm w/ 3200 psi. Aquire T & D Data Every 5 Stds 03:30 04:30 1.00 7,060 6,770 INTRM1 DRILL REAM P BROOH f/ 7060' - 6770' MD; Pumping 1006 gpm w/ 3000 psi. Slowed Rate for Hole Cleaning. Pulling speed 15' per minute. Rotate 120 rpm w/ 20k ft Ibs of for ue. F`~ge 1 ~ rzf 42~ • • Time Logs Date From To Dur S. De th E. D_e th Phase Code Subcode T COM 01/13/2008 04:30 05:30 1.00 6,770 6,770 INTRM1 DRILL CIRC P CBU; Pumping 1015 GPM with 3000 PSI; RPM 120, Torque 20k ft Ibs; ECD Range 10.25 - 9.89 final; Max EPOCH Gas 447 Units. Pulling speed 2' er minute. 05:30 05:45 0.25 6,770 7,535 INTRM1 DRILL TRIP P TIH on Elevators f/ 6770' - 7535' MD to Observe Well for Flow 05:45 06:15 0.50 7,535 7,535 INTRM1 DRILL OWFF P Observe Well for Flow; (Static) 06:15 07:15 1.00 7,535 7,535 INTRMI DRILL CIRC P CBU After Shutdown and Monitor Well For Stability. EPOCH maximum gas of 238 units. 07:15 07:30 0.25 7,535 7,535 INTRM1 DRILL OTHR P Clean /Clear Rig Floor & Monitor Well Static 07:30 12:00 4.50 7,535 5,140 INTRMI DRILL REAM P BROOH f/ 7535' to 5140'. Rotating 120 rpm w/ 20k to 13k ft Ibs of torque.. Pumping 1010 gpm with 3200 to 2650 psi. PU wt 290k to 220k. SO wt 118 to 115k. Rotating wt 155k to 145k. Max gas recorded by EPOCH was 266 units. 12:00 15:15 3.25 5,140 3,140 INTRMI DRILL REAM P BROOH f/ 5140' to 3140'. Rotating 120 rpm w! 13k to 6k ft Ibs of torque.. Pumping 1050 gpm with 2650 to 2600 psi. PU wt 220k to 168k. SO wt 115 to 113k. Rotating wt 145k to 130k. Maximum gas recorded by EPOCH was 42 units. 15:15 17:00 1.75 3,140 3,140 INTRM1 DRILL CIRC P Pump a 60 bbl weighted hi vis sweep (11.1 ppg/ 230 vis). Circulate bottm's up (X6). Pumping 1050 gpm w/ 2600 psi initial and 2300 psi final. Rotate 120 rpm w/ 10k ft Ibs of torque. Initial ECD was 9.68 ppg, final 9.54 ppg. No Epoch gas. PU wt 165k, SO wt 108k, Rotating weight 130k. Course gravel returns in the swee . 17:00 17:15 0.25 3,140 3,140 INTRM1 DRILL OWFF P Monitor well. Static. 17:15 17:45 0.50 3,140 3,140 INTRM1 DRILL CIRC P Pump a 20 bbl dry job (11.1 ppg). Blow down the top drive. Install stri er rubbers. 17:45 18:00 0.25 3,140 2,684 INTRM1 DRILL TRIP P Pull out of the hole. Monitor well on the tri tank. 18:00 19:15 1.25 2,684 300 INTRM1 DRILL TRIP P POOH f/ 2684' - 300' MD; Hole Took 27 Bbls vs. Calculated 16 Bbls = 11 Bbls Over Dis lacement 19:15 20:00 0.75 300 202 INTRM1 DRILL OTHR P Pulled Heavi Weight DP Stand w/Jars & Unraveled Rabbit Tail; Break Jars to Retrieve Wire, No Rabbit, & Stand Back 20:00 20:15 0.25 202 202 INTRMI DRILL SFTY P PJSM for Removing Nuclear Sources 20:15 21:00 0.75 202 70 INTRM1 DRILL TRIP P Stand Back Drill Collars and Remove Sources; Rabbit Located /Retrieved on To of Pulser P~sJe 13 cat G2 ~ i Time Logs: Date From To Dur S De th E. De th Phase Code Subcode T COM __ 01/13/2008 21:00 22:00 1.00 70 70 INTRM1 DRILL DHEQ P Download MWD Tools 22:00 00:00 2.00 70 0 INTRM1 DRILL PULD P UD MWD Tools, Geo Pilot and Break Out /Grade Bit 01/14/2008 00:00 00:15 0.25 0 0 INTRM1 DRILL OTHR P Continue to clean rig floor after laying down BHA #2. 00:15 00:30 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting on picking up and making up 5" HWDP from the i e shed. 00:30 02:15 1.75 0 0 INTRM1 DRILL PULD P Pickup/make up 39 jts (13 stands) of 5" HWDP. Drift to 2.45". Stand back in the derrick. 02:15 02:45 0.50 0 0 INTRM1 EVALF OTHR P Bring Schlumberger tools to the rig floor. 02:45 03:15 0.50 0 0 INTRM1 EVALF SFTY P Pre job safety meeting with Schlumber er wireline. 03:15 04:15 1.00 0 0 INTRM1 EVALF PULD P Pickup tool string via beaver slide, lower into the pipe shed. Arrange tools in order to icku . 04:15 06:00 1.75 0 165 INTRM1 EVALFI PULD P Assemble Schlumberger tool string in the hole. Total length 165.3'. Calibrate and test tools- OK.Bring side entry sub to the floor. Note: While blind rams were closed -for 4,5 hrs a total of 12 bbls of fluid was required to fill hole when the rams were o ened. 06:00 06:15 0.25 165 165 INTRM1 EVALFI SFTY P Pre job safety meeting with day crew. 06:15 07:15 1.00 165 165 INTRM1 EVALF OTHR P Hang the upper sheave at the collar finger with the wireline strung up through the sheave. Make up the 3-1 /2" IF pin x 4-1/2" IF box crossover to the tool string and makeup stand #1. 07:15 12:00 4:75 165 4,540 INTRM1 EVALFI TRIP P Trip in the hole with Schlumberger logging tools on the 5"drill pipe. Fill pipe @ 1500', at the casing shoe, then break circulation every 5 stands while running in the open hole. At depth of 4540' : PU wt 175k, SO wt 108k. 12:00 15:00 3.00 4,540 6,130 INTRM1 EVALFI TRIP P Continue to trip in the hole with Schlumberger logging tools on the 5" drill pipe. Break circulation every 5 stands while runnin in the o en hole. 15:00 15:45 0.75 6,130 6,130 INTRM1 EVALFI OTHR P Install Schlumberger side entry sub. Ri u Schlumber er lower sheave. 15:45 17:15 1.50 6,130 6,130 INTRMI EVALF CIRC P Pump down the locomotive. Pumping 30 spm (3.5 bpm) (150 gpm) with 160 psi. Increase rate to 70 spm (8.26 bpm) (347 gpm) w/ 410 psi. Latch in the locomotive. 17:15 18:00 0.75 6,130 6,160 INTRM1 EVALFI OTHR P Blow down the top drive. Clamp off the wireline to the side entry sub. Calibrate tension on line and toolstring. Finish running in the hole stand # 63. 6~~ge 1~4 of 42 Time Logs _ _ _ Date From To Dur S Depth E th Phase Code Subcode T CoM 01!14/2008 18:00 00:00 6.00 6,160 7,551 INTRM1 EVALFI DLOG P Run in the hole (15'/ min) taking pressures. PU wt 245k, SO wt 110k. Stopping to take pressure samples. For the whole trip: Calculated 65.6 bbls, actual 36 bbls for a loss of 29.6 bbls. SWS packer depth 6330' --bottom of logging tool 6358.5'-- probe depth 6295'. SWS packer depth 6883' -bottom of logging tool 6911.5'--probe depth 6848'. SWS packer depth 6897' --bottom of logging tool 6925.5'--- probe depth 6862'. SWS packer depth 7012' --bottom of logging tool 7040.5'--- probe depth 6977'. SWS packer depth 7060' --bottom of logging tool 7088.5'-- probe depth 7025'. SWS packer depth 7470' -bottom of logging tool 7498.5'---probe depth 7435'. SWS packer depth 7523' -bottom of logging tool 7551.5'--- probe depth 7488'. 01/15/2008 00:00 00:15 0.25 7,551 7,516 INTRM1 EVALFI DLOG P POOH @ 15 fpm, circulating over top of hole, weights - 110k SO, 245k PU. Sto in to take sam les as directed. 00:15 02:00 1.75 7,516 7,516 INTRM1 EVALFI DLOG P Take samples using MDT tool 02:00 04:00 2.00 7,516 7,551 INTRMI EVALF DLOG P TIH @ 15 fpm, circulating over top of hole. Stopping to take samples as directed. Lost 3 BBLS of mud to hole. 04:00 07:15 3.25 7,551 6,130 INTRM1 EVALFI TRIP T POOH @ 15 fpm, weights - 112k SO, 245k PU, monitor well via tri tank 07:15 08:45 1.50 6,130 6,130 INTRM1 EVALFI PULD T Rig down wireline clamp, pull wireline and la down side ent sub. 08:45 10:15 1.50 6,130 4,323 INTRM1 EVALF TRIP T Continue POOH 10:15 12:15 2.00 4,323 4,323 INTRM1 EVALFI PULD T Pick up and rig up side entry sub. Pump down wireline tool at 4 bpm, 150 psi. Land tool and install wireline clam .Test tool. 12:15 18:00 5.75 4,323 5,980 INTRMI EVALFI DLOG P RIH, stop for pressure tests at: 4470' - 1210 psi, 5010' - 1265 psi, 5589 - no test, 5655' - 1399 psi, 5672' -hole washed out no test, 5951' - 1399 si 18:00 21:00 3.00 5,980 4,425 INTRM1 EVALFI TRIP T POOH on elevators @ 20 fpm. 170k PU wei ht. Monitor well on tri tank. 21:00 22:00 1.00 4,425 4,425 INTRMI EVALF PULD T Rig down wireline clamp, pull wireline and lay down side entry sub. Blow down to drive. P~a~ 16 of ~2 l I • Time Logs _ Dam From To _ Dur S. De th E. De tit Phase Code Subcode T COM ___ i 01/15/2008 22:00 22:30 0.50 4,425 4,425 INTRM1 EVALF OTHR T Blow down top drive, install stripping rubbers, monitor well -static 22:30 00:00 1.50 4,425 1,115 INTRM1 EVALFI TRIP T POOH on elevators @ 60 fpm. 80k PU wei ht. Monitor well via tri tank. 01/16/2008 00:00 00:30 0.50 1,115 400 INTRM1 EVALFI TRIP T POOH on elevators @ 60 fpm. Monitoring well via trip tank. PU Wt 80k 00:30 00:45 0.25 400 400 INTRMI EVALFI TRIP T Pull stripping rubbers and monitor well - static 00:45 01:00 0.25 400 165 INTRM1 EVALF TRIP T POOH on elevators @ 60 fpm. Monitoring well via trip tank. PU Wt 75k 01:00 03:30 2.50 165 0 INTRM1 EVALFI PULD T PJSM -laying down logging tools. Lay down logging tools. Trip out of hole from 5980' -calculated hole fill 53.6 bbls, actual 77.5 bbls, lost 24 bbls. 03:30 05:00 1.50 0 0 INTRM1 RIGMN SVRG T Clear rig floor, service drawworks, crown and topdrive. Repair/replace to in tools 05:00 06:00 1.00 0 0 INTRM1 EVALF PULD T PJSM- picking up logging tools. Pick u and make u to in tools 06:00 07:00 1.00 0 165 INTRM1 EVALFI PULD T Test logging tools - ok 07:00 14:30 7.50 165 6,130 INTRM1 EVALF TRIP T TIH with logging tools. Break circulation at 1700', 3100' and every 5 stands while in open hole. Pumping at 4 bpm to insure tools are clear of debris. Hole taking proper dis tacement Burin tri . 14:30 16:45 2.25 6,130 6,130 INTRM1 EVALFI PULD T Pick up and make upside entry sub. Pump down wireline @ 7 bpm, 330 si. 16:45 18:00 1.25 6,130 6,643 INTRM1 EVALF TRIP T Continue TIH with logging tools @ 13-16 fpm. Maintaining wireline tension less than 3000# and tool com ression less than 500#. 18:00 20:15 2.25 6,643 7,516 INTRM1 EVALF TRIP T Continue TIH with logging tools to 1st sample depth.. Circulating over top of hole, monitoring well via trip tank. PU wt. 230k, SO wt.115k. Calculated displacement for trip 62 bbls, actual 62 bbls, 0 bbl ain.loss 20:15 22:00 1.75 7,516 7,516 INTRM1 EVALF DLOG T Sample formation -failed, packer will not maintain seal a ainst formation._ Lost 2 bbls 22:00 22:15 0.25 7,516 7,507 INTRM1 EVALF TRIP T POOH @ 14-15 fpm to 2nd sample depth. Circulating over top of hole, monitoring well via trip tank. PU wt. 230k, SO wt.115k. 22:15 23:00 0.75 7,507 7,507 INTRM1 EVALFI DLOG T Sample formation -failed, packer will intain seal a ainst formation. 23:00 23:15 0.25 7,507 7,550 INTRM1 EVALFI TRIP T TIH @ 14-15 fpm to 3rd sample depth. Circulating over top of hole, monitoring well via trip tank. PU wt. 230k, SO wt.115k. ~~ F~aOe 96 cif 42 • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 01/16/2008 23:15 23:45 0.50 7,550 7,550 INTRM1 EVALF DLOG T .Sam le formation -failed, acker will not maintain seal a ainst formation. 23:45 00:00 0.25 7,550 7,214 INTRM1 EVALFI T POOH@ 14-15 fpm for 4th sample. tar et de th for 4th sam le 7005' 01/17/2008 00:00 00:30 0.50 7,214 7,005 INTRM1 EVALFI TRIP T POOH @ 14-15 fpm to 4th sample depth. Circulating over top of hole, monitoring well via trip tank. PU wt. 230k, SO wt.115k. 00:30 02:00 1.50 7,005 7,005 INTRM1 EVALFI DLOG T Sample formation -failed, packer will not maintain seal against formation. Lost .5 bbl while testin . 02:00 02:15 0.25 7,005 6,881 INTRM1 EVALF TRIP T POOH @ 14-15 fpm for 5th sample attempt. Circulating over top of hole, monitoring well via trip tank. PU wt. 230k, SO wt.115k. 02:15 02:45 0.50 6,881 6,881 INTRM1 EVALFI DLOG T Sample formation -failed, packer will not maintain seal against formation. Lost .5 bbl while testin . 02:45 03:00 0.25 6,881 6,925 INTRM1 EVALFI TRIP T TIH @ 14-15 fpm for 6th sample attempt. Circulating over top of hole, monitoring well via trip tank. PU wt. 230k, SO wt.115k. 03:00 05:00 2.00 6,925 6,927 INTRM1 EVALFI DLOG T Last attempt to sample formation - failed. Moved 2' in hole and tried a - failed. Lost 1 bbl while t 05:00 06:30 1.50 6,927 6,730 INTRM1 EVALFI TRIP T POOH to side entry sub. Circulating over top of hole, monitoring well via trip tank. PU wt. 235k, SO wt.115k. 06:30 07:45 1.25 6,730 6,730 INTRM1 EVALFI PULD T Remove line clamp, unlatch tool, pull wireline and la down sub. 07:45 09:00 1.25 6,730 7,496 INTRM1 EVALF TRIP T TIH to deepest logging depth to circulate bottoms u . 09:00 12:00 3.00 7,496 7,496 INTRM1 EVALFI CIRC T Circulate at 6 bpm for 10250 strokes. Observed max gas fo 120 units at bottoms u . 12:00 12:15 0.25 7,496 7,496 INTRM1 EVALFI OTHR T Monitor well -static 12:15 13:00 0.75 7,496 7,024 INTRM1 EVALFI TRIP T POOH on elevators. Stop to pump dry 'ob and blow down to drive. 13:00 16:30 3.50 7,024 165 INTRM1 EVALFI TRIP T Continue POOH. Hole took 23.9 bbls over calculated displacement during tri . 16:30 19:00 2.50 165 0 1NTRM1 EVALFI PULD T PJSM -laying down logging tools. Lay down to in strip . 19:00 19:30 0.50 0 0 INTRM1 EVALFI OTHR T Clear and clean rig floor 19:30 20:15 0.75 0 30 INTRM1 EVALFI PULD P PJSM - ickin u side wall corin_ tool As safety measure all radios,cell phones, camp to rig wireless and top drive were turned off while handling coring assembly. Notified security and pad operator before operations began. Picked up and ener ized corin tools. 20:15 21:00 0.75 30 316 INTRM1 EVALF TRIP P TIH 3 stands with coring assembly. Notified security and pad operator that corin tools were safe) in hole. ~.r.w_-_._ Ea~~? 17 ~~ ~2 Time Logs Date From To Dur 5. De th E. Depth Phase Code Subcode T COM 01/19/2008 00:30 01:30 1.00 30 0 INTRM1 CORINCORIN PULD P Lay down side wall coring assembly. Total of 45 side wall cores in tool, 44 fired, 1 misfire, none lost in hole 01:30 02:00 0.50 0 0 INTRM1 CORING OTHR P Clear and clean rig floor. 02:00 04:00 2.00 0 299 INTRM1 EVALF TRIP P PJSM -Picking up hole opener. Pick u and make u hole o ener BHA 04:00 06:00 2.00 299 2,210 INTRM1 EVALFI TRIP P TIH on elevators with hole opener BHA. Monitor displacement via trip tank. Fill pipe @ 1733', 10 bpm, 310 si 428 m. Circulated 1000 strokes 06:00 06:30 0.50 2,210 3,143 INTRM1 EVALFI TRIP P TIH on elevators at 100-120 fpm, obtain PU & SO eve 10 stands 06:30 07:30 1.00 3,143 3,143 INTRM1 EVALFI CIRC P Circulate bottoms up at shoe. Stage pumps to 900 gpm, 2400 psi, rotating 120 rpm, torque 8-10k. Blow down top drive after bottoms u . 07:30 08:00 0.50 3,143 4,305 INTRMI EVALFI TRIP P TIH recording PU & SO weights 08:00 08:30 0.50 4,305 4,305 INTRM1 EVALFI CIRC P Break circulation, pumping 400 gpm, 410 psi, rotating 120 rpm, torque 12k. Pum ed 75 bbls. 08:30 09:00 0.50 4,305 5,350 INTRM1 EVALFI TRIP P TIH recording PU & SO weights 09:00 09:45 0.75 5,350 5,350 INTRM1 EVALFI CIRC P Circulate bottoms up. Stage pumps to 900 gpm, 1870 psi, rotating 120 rpm, torque 14k. Circulated 750 bbls. Blow down to drive after bottoms u . 09:45 10:30 0.75 5,350 6,490 INTRM1 EVALFI TRIP P TIH recording PU & SO weights 10:30 11:00 0.50 6,490 6,490 INTRM1 EVALF CIRC P Break circulation, pumping 900 gpm, 2240 psi, rotating 120 rpm, torque 17k. 11:00 11:30 0.50 6,490 7,600 INTRM1 EVALFI TRIP P TIH to TD recording PU & SO weights. Hole took proper displacement during TIH. 11:30 12:00 0.50 7,600 7,600 INTRMI EVALFI CIRC P Circulate bottoms up. Staged pumps to 900 gpm., 2400 psi, rotating 120 rpm, torque 17k. Pumped 60 bbl sweep, no significant increase in cuttin s returned. Max as 131 units. 12:00 14:15 2.25 7,600 7,600 INTRM1 EVALFf CIRC P Circulate 3 additional bottoms up. Pumping at 900 gpm., 2400 psi, rotating 120 rpm, torque 17k. Pumped 60 bbl sweep, no significant increase in cuttings returned. Max gas 131 units. 14:15 14:30 0.25 7,600 7,600 INTRM1 EVALFI TRIP P Tag bottom at 7600' MD with pumps off. Monitor well -static 14:30 15:00 0.50 7,600 7,160 INTRM1 EVALF TRIP P POOH on elevators. Hole taking ro er dis lacement. Pum d 'ob 15:00 18:45 3.75 7,160 299 INTRM1 EVALFI TRIP P POOH on elevators. Monitor hole fill via tri tank. 18:45 19:15 0.50 299 299 INTRM1 EVALF TRIP P Monitor well -static. PJSM - La in down hole o ener BHA ~~€~e 19 of 42 • Time Logs _ ~ Date _ From To Dur S. De th_ E. Depth Phase Code Suhcode T COM I 01/19/2008 19:15 21:00 1.75 299 0 INTRM1 EVALF PULD P Lay down BHA. Flex collars, stabilizer, float and bit sub. 21:00 22:15 1.25 0 0 INTRM1 EVALFI RURD P Pull wear ring 22:15 23:00 0.75 0 0 INTRM1 EVALFI RURD P Clean and clear rig floor. 23:00 00:00 1.00 0 0 INTRM1 CASIN RURD P Rig up 9-5l8" casing tools, tongs, elevators, s iders and work latform 01/20/2008 00:00 01:15 1.25 0 0 INTRMI CASIN( RURD P Continue rigging up 9-5/8" casing handlin tools 01:15 01:45 0.50 0 0 INTRM1 CASIN SFTY P PJSM -Running 9-5/8" casing 01:45 02:45 1.00 0 166 INTRM1 CASIN( RNCS P TIH with 9-5/8" casin 02:45 03:15 0.50 166 166 INTRM1 CASIN RNCS P Pump 4 bbls and check float e ui ment 03:15 06:00 2.75 166 1,581 INTRM1 CASIN RNCS P Continue running 9-5/8" casing 06:00 06:30 0.50 1,581 1,581 INTRM1 CASIN CIRC P Break circulation half way to surface casing shoe, pumping at 6 bpm, 230 si 06:30 09:30 3.00 1,581 3,143 INTRM1 CASIN RNCS P Continue running 9-5/8" casing. Record PU & SO Burin run. 09:30 10:15 0.75 3,143 3,143 INTRM1 CASIN CIRC P Circulate bottoms up at surface casing shoe. Stage pumps to 6 bpm, 260 psi. No looses observed. 10:15 13:00 2.75 3,143 5,326 INTRM1 CASIN RNCS P Continue running 9-5/8" casing. Record PU & SO during run. Fill pipe eve 5 'oints. 13:00 13:30 0.50 5,326 5,326 INTRM1 CASIN CIRC P Break circulation in open hole half way to TD. Stage pumps to 6 bpm, 280 psi. Circulate total of 120 bbls. No losses. 13:30 16:45 3.25 5,326 7,595 INTRM1 CASINC RNCS P Continue running 9-5/8" casing. Record PU & SO during run. Fill pipe every 5 joints. Picked up joint #198 and tagged bottom on depth. Lay down joint #198. Lost 8 bbls over calcul 16:45 18:00 1.25 7,595 7,595 INTRM1 CEME CIRC P Circulate and condition mud for cement job. Stage pumps to 6 bpm, 330 si, reci rocatin i e 10 - 20'. 18:00 18:45 0.75 7,595 7,595 INTRM1 CEME~ RURD P Rig down fill up tool and rig up cement head. Blow down to drive. 18:45 21:45 3.00 7,595 7,595 INTRM1 CEME~ CIRC T Waiting on mix water. Water from first truck was 104 degrees, too hot for cement job. While waiting, circulate thru cement head at 6 bpm, 190 psi. PU wt 355k, SO wt 130k, reciprocating pipe 10 - 20'. Move trucks from in front of pipe shed and load drill i e. 21:45 22:15 0.50 7,595 7,595 INTRM1 CEME~ SFTY P PJSM -cementing 9-5/8" casing. ~~e 2fl cif 42 Time Logs Date From To Dur 5. De th E. De th Phase Code Subcode T COM 01/20/2008 22:15 00:00 1.75 7,595 7,595 INTRM1 CEME~ OTHR P _ Turn rig over to Dowell cementers. Pump 5 bbls of water, pressure test lines to 3000 psi, pump 50.1 bbls cw100, 50.6 bbls Mud Push, drop bottom plug, pump 209.9 bbls of 12.5 ppg Deepcrete cement, drop top plug and be in dis lacement at 23:55. 01/21/2008 00:00 00:15 0.25 7,595 7,595 INTRM1 CEME~ DISP P Continue with Intermediate cement job. Drop bottom plug and push out with 5 bbls of water. 00:15 01:45 1.50 7,595 7,595 INTRM1 CEME DISP P Take over displacement using rig pumps. Displace with 8.4 ppg OBM, pumping 7 bpm, 140 psi. Reciprocating pipe 5 - 10' until 124 bbls of cement out the casing shoe. Slow pumps to 3 bpm at 5500 strokes, -15 bbl from bumping. Bump plug at 5656 strokes and pressure 680 psi. Increase pressure to 1300 psi, hold 5 minutes and bleed off. Check floats -floats holding. Estimated neutral wt 250k. 01:45 02:30 0.75 7,595 7,595 INTRM1 CEME~ RURD P Blow down lines and rig down cement head. 02:30 05:00 2.50 0 0 INTRM1 CASIN NUND P Nipple down stack to set 9-5/8" slips. Pick up to 325k on weight indicator and set slips. Cut off casing. Sim ops - la la in down 9-5/8" casin tools. 05:00 05:30 0.50 0 0 INTRM1 CASIN( OTHR P Lay down landing joint and cut joint. Len th of cut'oint 7.63' 05:30 06:30 1.00 0 0 INTRM1 CASIN( NUND P Nipple up stack, test seal ring and pack off to 2500 psi. Held for 10 minutes and charted. Tested good. Sim ops -rig down and lay down long bails 06:30 07:45 1.25 0 0 INTRM1 CASIN NUND P Continue to nipple up stack, rig up and perform infectivity test on 13-3/8" x 9-5/8" annulus. Formation broke at 600 psi or 14.6 ppge. Continued pump at 3 bpm, 650 psi to flush annulus. Total volume um ed 210 bbls. 07:45 12:30 4.75 0 0 INTRM1 DRILL PULD P Pick up 35 stands of 5"drill pipe from shed (20 slick, 15 with wearsox). Pull mouse hole from rota table. 12:30 15:00 2.50 0 0 INTRM1 WELCT BOPE P R_ig up BOPE test equipment. Fill stack and lines with water. Sim ops - freeze protect 13-3/8" x 9-5/8" annulus. €~ar~e ii eat ~2 Time Lois I Date From To Dur 5 De th E._D~th Phase Code Subcode T COM _ _ 01/21/2008 15:00 20:30 5.50 0 0 INTRM1 WELCT BOPE P Test ROPE, witnessed by AOGCC - Chuck Scheve, draw down test, koomey pressure 3000 psi, function rams and HCR, bleeding pressure to 1450 psi. presure built to 1650 psi in 30 seconds and 3000 psi in 3 minutes 38 seconds. Test manifold to 250 psi low & 3000 psi high. Hold for 5 minutes. Manual choke failed high ressure test. 20:30 21:00 0.50 0 0 INTRMI WELC ROPE T Rig down test equipment, pull test plug, drain stack and lay down test 'oint. 21:00 21:15 0.25 0 0 INTRM1 RIGMN SFTY P PJSM -slip and cut drilling tine. 21:15 22:45 1.50 0 0 INTRM1 RIGMN SVRG T Hang blocks and rig up to slip and cut drilling line, cut 115'. Inspect brakes and drawworks. Sim ops -repair manual choke valve. 22:45 23:30 0.75 0 0 INTRM1 WELCT BOPE T Pick up test joint and test plug, fill stack with water. Test manual choke, 250 psi low, 3000 psi high, hold for 5 minutes - assed tests 23:30 00:00 0.50 0 tNTRM1 WELCT BOPE P Rig down test equipment, install wear bushing, run in lock down screws and la down test 'oint. Blow down lines. 01/22/2008 00:00 00:15 0.25 0 0 INTRM1 RIGMN SFTY P PJSM -Changing saver sub 00:15 02:00 1.75 0 0 INTRM1 RIGMN SVRG P Change 4-1 /2" saver sub 02:00 02:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM -Picking up BHA 02:15 04:00 1.75 0 73 INTRM1 DRILL PULD P Pick up BHA #4, 8-1/2" geopilot. Upload MWD and pick up remainder of BHA 04:00 06:00 2.00 73 789 INTRM1 DRILL TRIP P Pick up remaining BHA and TIH on elevators. Shallow pulse test pumping 600 gpm, 1300 psi. Continue TIH until crew Chan e. PU 110k, SO 110k. 06:00 11:45 5.75 789 7,496 INTRM1 DRILL TRIP P TIH on elevators. Monitoring well via trip tank. Filled pipe at 2257', 600 gpm, 1810 psi, rotating 30 rpm, torque 3-4k, checked MWD and geopilot. Filled pipe at5114', 216 gpm, 390 psi, rotating 30 rpm, torque 7-8k, Rotating wt140k and again at 7017', 600 gpm, 2610 psi, rotating 30 rpm, torque 9k, rotating wt 140k PU wt 205k, SO wt 135k. 11:45 12:00 0.25 7,496 7,504 INTRM1 DRILL TRIP P Tag float equipment, pumping 3 bpm, 300 si 12:00 12:15 0.25 7,504 7,397 INTRM1 DRILL TRIP P POOH on elevators, monitoring well via tri tank. PU wt 205k, SO wt 135k ~~e 2~ f ~~ Time Logs ___ _ _ Date From To Dur S. Depth _E_Depth_Phase Code Subcode T COM _ 01/23/2008 02:45 03:15 0.50 7,874 7,493 PROD1 DRILL TRIP T POOH on elevators to shoe due to Phase 3 weather conditions, monitor fill via tri tank. 03:15 04:15 1.00 7,493 7,493 PROD1 DRILL CIRC T Circulate @ 7493'. Rotate and recip while circ (9000 stks total). 2720 psi, 620 m, 50 r m, 14-15k ft/Ibs for ue. 04:15 06:00 1.75 7,493 7,493 PROD1 DRILL WOW T Monitor well via trip tank wait on phase 3 weather conditions, Secure ri . 06:00 12:00 6.00 7,493 7,493 PROD1 DRILL WOW T Install TIW valve and monitor well Burin hase 3 weather conditions 12:00 16:00 4.00 7,493 7,493 PROD1 DRILL WOW T Remove TIW valve and circulate @ 400 gpm w/ 1290 psi. Up wt 210k, Dn wt 110k. Well stable no losses or ains. 16:00 18:00 2.00 7,493 7,493 PROD1 DRILL WOW T Circulate @ reduced rate, 96 gpm, 210 psi, Up wt 210k, Dn 110k. Well static no losses or ains. 18:00 00:00 6.00 7,493 7,493 PROD1 DRILL WOW T Circulate @ reduced rate, 96 gpm, 210 psi, Up wt 210k, Dn 110k. Well static no losses or ains. 01/24/2008 00:00 06:00 6.00 7,493 7,493 PROD1 DRILL WOW T Circ @ 7493, reduced rate 96 gpm, 210 si due to Phase III weather 06:00 09:00 3.00 7,493 7,493 PROD1 DRILL WOW T Circ @ 7493, reduced rate 96 gpm, 210 psi. Pit volume static. Inspect and repair secondary containment around cellar, remove snow from berms around entire ri . 09:00 10:15 1.25 7,493 7,493 PROD1 DRILL WOW T Circ, increase rate to 600 gpm, 2860 si for 5100 total stks. 10:15 10:45 0.50 7,493 7,874 PROD1 DRILL TRIP T TIH on elevators to 7778'. Precautionary wash and ream to bottom @ 7874'. no fill. Monitor dis lacement w/ tri tank. 10:45 12:00 1.25 7,874 8,024 PROD1 DRILL DRLG P Drilling B lateral 12:00 18:00 6.00 8,024 8,635 PROD1 DRILL DRLG P Drilling B lateral 18:00 00:00 6.00 8,635 9,015 PROD1 DRILL DRLG P Drilling B lateral 01/25/2008 00:00 06:00 6.00 9,015 9,396 PROD1 DRILL DDRL P Drilling B Lateral 06:00 12:00 6.00 9,396 10,158 PROD1 DRILL DDRL P Drilling B Lateral 12:00 18:00 6.00 10,158 10,919 PROD1 DRILL DDRL P Drilling B Lateragl 18:00 00:00 6.00 10,919 11,542 PROD1 DRILL DDRL P Drilling B Lateral 01/26/2008 00:00 06:00 6.00 11,542 12,060 PROD1 DRILL DDRL P Drilling B Lateral 06:00 12:00 6.00 12,060 12,608 PROD1 DRILL DDRL P Drilling B Lateral 12:00 18:00 6.00 12,608 12,982 PROD1 DRILL DDRL P Drilling B Lateral 18:00 19:00 1.00 12,982 13,000 PROD1 DRILL DDRL P Drilling B Lateral ~~c~e 2A t~f ~2 Time .Logs Date Fro m To Dur S. Depth E. Depth Ph se Code Subcode T COM _ 01/26/2008 _ _ 19:00 19:30 0.50 13,000 13,000 PROD1 DRILL OWFF P _ Garner Slow Pump Rates on both pumps, Monitor well for flow, Static, No flow observed 19:30 21:00 1.50 13,000 12,917 PROD1 DRILL REAM P Pump 40 bbl sweep (11.2 wt, 247 vis) Back ream out of hole slowly @ 2 fpm until sweep is back to surface30% increase in cuttings also w/ splintered shale come back. Total of 9731 stks 21:00 00:00 3.00 12,917 11,298 PROD1 DRILL REAM P Back ream out of hole (30 fpm), Monitor displacement, ECD's .120 r m, 665 m w/ 3950 si. 01/27/2008 00:00 06:00 6.00 11,298 8,160 PROD1 DRILL REAM P Back ream out of hole (30 fpm), Monitor displacement, ECD's .120 r m, 700 m w/ 3520 si. 06:00 07:00 1.00 8,160 7,586 PROD1 DRILL REAM P Back ream out of hole (30 fpm), Monitor displacement, ECD's .120 rpm, 700 gpm w/ 3520 psi. Hole fill 23 bbls over calculated 07:00 07:15 0.25 7,586 7,586 PROD1 DRILL OWFF P Pull air slips & stripping rubbers. Monitor well for flow, well static 07:15 09:15 2.00 7,586 7,586 PROD1 DRILL CIRC P Circulate to clean up casing, rotate and recip pipe. 3-1/2 bottoms up, shakers clean 09:15 09:45 0.50 7,586 7,586 PROD1 DRILL OWFF P Monitor well, blown down Top Drive. Well static no losses or flow. 09:45 10:30 0.75 7,586 7,586 PROD1 DRILL FIT P Perform FIT to 13.1 ppg EMW. Casing shoe depth 75 4' MD, 3546' TVD, TD 13000' MD 3593' TVD. Mud Wt 9.3 ppg, Pressure 700 psi. Bled back 3 bbls. Record test on chart 10:30 11:00 0.50 7,586 7,586 PROD1 DRILL FIT P Rig Down test quipment, blow down Kill Line. 11:00 11:15 0.25 7,586 7,586 PROD1 DRILL CIRC P Circulate, pump up PWD Data 11:15 12:30 1.25 7,586 7,586 PROD1 RIGMN SVRG P Service Top Drive Blocks and Crown. Adjust draworks brakes, replce light in derrick, install safety cable. Monitor well via tri tank 12:30 15:00 2.50 7,586 12,917 PROD1 DRILL TRIP P TIH on elevators, fill pipe every 25 stds. Monitor displacement w/trip tank. 1/2 over calculated. 15:00 16:30 1.50 12,917 13,000 PROD1 DRILL REAM P Wash and ream to bottom last stand. No fill 16:30 18:00 1.50 13,000 13,175 PROD1 DRILL DDRL P Drilling B Lateral 18:00 00:00 6.00 13,175 13,518 PROD1 DRILL DDRL P Drilling B Lateral. 01/28/2008 00:00 06:00 6.00 13,518 13,920 PROD1 DRILL DDRL P Drilling B Lateral, Note crossed fault @ 13685' MD 3632' ND 45' DTEthrow. No increase in gas or evidence of radient increase. 06:00 07:30 1.50 13,920 14,08 PROD1 DRILL DDRL P Drilling B Lateral to TD 07:30 07:45 0.25 14,084 14,084 PROD1 DRILL OWFF P Monitor well, Obtain SPR f~a€~e 2~ gat ~2 ~~ j Time Logs __ _ Date From To Dur S. De th E. De th Phase Code Subcode T COM 01/28/2008 07:45 09:30 1.75 14,084 13,964 PROD1 DRILL CIRC P _ Circulate, pump 40 bbl sweep. Rotate and recip pipe while circulating sweep out of bit. 09:30 12:30 3.00 13,964 12,318 PROD1 DRILL REAM P Backream out of hole @ 2 fpm until sweep reaches surface. increase rate to 30 f m 12:30 18:00 5.50 12,318 12,440 PROD1 DRILL REAM T .Lost returns Cal 12318' while ht increase in torque and overpull. Lost 100% returns momentarily.. Slack off, lower pump rate. RIH 1 stand to 12434' ,Monitor well. Regain partial circulation, Stage up pumps 200 gpm to 500 gpm, Continue BROOH slowly. Begin losing returns lower rate. Increase flow rate slowly to 475 gpm w/minimal losses. continue Backreaming @ reduced rate still dealing with partial losses and packing off occassionally . Work thru spot that was packing off. Well ap ear r thin .Monitor well , flows back for 10/15 minutes at declining rate until static. Total mud lost to formation this tri 54 bbls. 18:00 22:30 4.50 12,440 11,301 PROD1 DRILL REAM T Backream out of the hole. increasing gpm to 640 gpm 3800 psi, minimal losses. 22:30 23:30 1.00 11,301 11,301 PROD1 WELC OWFF T Monitorwell-static. 23:30 00:00 0.50 11,301 12,111 PROD1 DRILL TRIP T Trip in the hole on elevators. 01/29/2008 00:00 01:30 1.50 12,111 13,650 PROD1 DRILL TRIP T Trip in the hole on elevators. 01:30 02:15 0.75 13,650 14,084 PROD1 DRILL REAM T Ream in hole due to no down weight. 02:15 04:15 2.00 14,084 13,872 PROD1 DRILL REAM T Backream out of the hole. Pumping 450 gpm w/ 2450 psi. Rotating 120 rpm w/ 16k ft Ibs of torque. Pulling speed 2 feet per min. Record PU and SO wt's eve 5 stands. 04:15 04:30 0.25 13,872 13,717 PROD1 DRILL REAM T Continue to backream out of the hole. Pumping 450 gpm w/ 2450 psi. Rotating 120 rpm w/ 16k ft Ibs of torque. Pulling speed 15 feet per min. Hole packed off @ 13717'. Decrease flow rate to 350 m w/ 1750 si. 04:30 05:30 1.00 13,717 13,586 PROD1 DRILL REAM T Continue to backream out of the hole. Pumping 350 gpm w/ 1750 psi. Rotating 120 rpm w/ 16k ft Ibs of for ue. Pullin seed 5 feet er min. 05:30 06:00 0.50 13,586 13,396 PROD1 DRILL REAM T Continue to backream out of the hole. Pumping 350 gpm w! 1750 psi, slowly increasing rate to 470 gpm w/ 2650 psi. Rotating 120 rpm w/ 16k ft Ibs of for ue. Pullin seed 15 feet er min. Page 2~ of X32 Time Logs Date _ From To _ Dur S. De th E. Depth Phase Code Subcode T COM ___ 01/29/2008 06:00 08:15 2.25 13,396 12,318 PROD1 DRILL REAM T Continue to backream out of the hole. Pumping 450 gpm w/ 2070 psi. Rotating 120 rpm w/ 16-13k ft Ibs of for ue. Pullin seed 15 feet er min. 08:15 12:00 3.75 12,318 10,255 PROD1 DRILL REAM P Continue to backream out of the hole. Pumping 450 gpm w/ 2070 psi. Rotating 120 rpm w/ 13k ft Ibs of torque. Pulling speed 15 feet per min. Record PU and SO wt's every 5 stands. 12:00 16:30 4.50 10,255 7,636 PROD1 DRILL REAM P Continue to backream out of the hole. Pumping 450 gpm w/ 2070 to 1710 psi. Rotating 120 rpm w/ 13k to 10k ft Ibs of torque. Pulling speed 30 feet per min. Record PU and SO wt's every 5 stands. 16:30 17:00 0.50 7,636 7,491 PROD1 DRILL TRIP P Pump out of the hole. Pumping 450 gpm w11920 psi. Total loss of fluid on the trip to here is 21 bbls. (9-5/8" casin shoe 7594' . 17:00 19:00 2.00 7,491 7,396 PROD1 DRILL CIRC P Rotate and reciprocate from 7491' to 7396', circulate to clean up the casing. Pumping 550 gpm w/ 2040 psi. Rotate 120 r m w/ 10 to 11 k ft Ibs of for ue. 19:00 20:00 1.00 7,396 7,396 PROD1 RIGMN SVRG P Service rig. 20:00 21:00 1.00 7,396 6,446 PROD1 DRILL TRIP P Trip out of the hole 5 stands, drop 2.35" rabbit w/ 120' of tail, then pull 5 more stands. 21:00 21:30 0.50 6,446 6,446 PROD1 DRILL CIRC P Pump a 17 bbl dry job, chase with 10 bbls. Blow down the to drive. 21:30 00:00 2.50 6,446 1,307 PROD1 DRILL TRIP P Trip out of the hole. 01/30/2008 00:00 00:30 0.50 1,307 355 PROD1 DRILL TRIP P Trip out of the hole. Retrieve the rabbit. 00:30 02:00 1.50 355 60 PROD1 DRILL PULD P Lay down BHA. 02:00 04:00 2.00 60 60 PROD1 DRILL OTHR P Download Sperry Sun MWD 04:00 05:00 1.00 60 0 PROD1 DRILL PULD P Continue to lay down BHA. 05:00 05:30 0.50 0 0 COMPZ CASIN( RURD P Rig up to run the "B" lateral 5-1/2" slot/blank liner. 05:30 05:45 0.25 0 0 COMPZ CASINC SFTY P Pre job safety meeting on running the "B" lateral 5-1/2" slot/blank liner. 05:45 13:00 7.25 0 7,173 COMPZ CASINC RNCS P Run the 5-1/2" 15.5 qp~f "~B" lateral slot/blank liner. Record PU and SO wt's per Rig engineer. Monitor dis lacement on the tri tank. 13:00 13:15 0.25 7,173 7,200 COMPZ CASINC RNCS P Make up the Baker Seal Bore extension 13:15 14:00 0.75 7,200 7,200 COMPZ CASIN RURD P Rig up Baker tongs for small tools. 14:00 15:15 1.25 7,200 7,200 COMPZ CASINC OTHR P Make up liner running toots and MLZXP and flex lock hanger to Sperry Sun slim MWD. Page 2~ of ~2 Time Logs i Date From To Dur S Depth E Depth Phase Code Subcode T COM __ __ 01/30/2008 15:15 15:30 0.25 7,200 7,230 COMPZ CASIN( OTHR P Orient Sperry Sun MWD with Baker MLZXP acker. RIH with same. 15:30 16:00 0.50 7,230 7,230 COMPZ CASIN( RURD P Rig down Baker small tongs and tools. 16:00 16:15 0.25 7,230 7,230 COMPZ CASIN( OTHR P Move a stand of drill collars and a stand of 5" HWDP from the off driller's side to the driller's side of derrick. 16:15 16:30 0.25 7,230 7,323 COMPZ CASIN RUNL P Make up a stand of 5" drill pipe to the running tool, then run in the hole. Shallow pulse test MWD w/ 100 gpm w/ 560 si. 16:30 21:00 4.50 7,323 12,947 COMPZ CASIN( RUNL P Continue to run liner in the hole on 5" drill string. Record PU and SO weight's and rotating torque per Rig Engineer. Monitor displacement on the tri tank. 21:00 22:30 1.50 12,947 14,084 COMPZ CASIN RUNL P Continue to run liner. Rabbit 5" HWDP with a 2.45" rabbit, and strap same. Ta bottom. 22:30 00:00 1.50 14,084 14,084 COMPZ CASIN( OTHR P Pumping 100 gpm w/ 850 psi. Obtain tool face of 90 right, turn string 180 deg and work torque down and up to 38 deg left of high side at midnight. PU wt 245k, SO wt 125k. 01/31/2008 00:00 00:30 0.50 14,084 14,084 COMPZ CASINC OTHR P Pumping 100 gpm w/ 850 psi. Tool face showing 38 deg left of high side @ setting depth. Apply a small amount of right hand turn and work until a 30 left is observed at setting de th. PU wt 245k, SO wt 125k. 00:30 00:45 0.25 14,084 14,050 COMPZ DRILL OTHR P Pickup and break, then set back a stand of 5" HWDP. Pickup a single of 5"drill pipe. Pipe was rabbitted with a 2.45" rabbit. 00:45 01:45 1.00 14,050 14,080 COMPZ CASINC OTHR P Working pipe from 14080' to 13985' while pumping 100 gpm w/ 850 psi. Obtain 30 de left of hi h side. 01:45 02:30 0.75 14,080 14,074 COMPZ CASIN CIRC P Break the single, drop a 1-3/4 ball to set hanger and packer. Circulate ball to seat pumping 100 gpm w/ 850 psi. Ball on seat after pumping 96.5 bbls. Note worked pipe two more times while pumping ball to seat. MWD showin 301eft of hi h side. 02:30 03:00 0.50 14,074 14,074 COMPZ CASIN OTHR P Pressure string to 2100 psi to set liner _... hap er. Slack off and set 45k on liner hanger to verify set. Continue to pressure to 3500 psi to activate pusher tool to set the MLZXP liner top packer. Continue to pressure to 4000 psi to release liner and neutralize the usher tool. Pace ~8 0~ ~2 Time Logs I Date From To Dur S De th E.. D~th Phase Code Subcode T COM 01/31/2008 03:00 03:45 0.75 14,074 14,074 COMPZ CASIN( DHEO P Test annulus to 2500 psi f/ 5 min, ok. Chart test. Pumped through the kill line, using the annular. Bleed off pressure. PU 9' and locate top of packer with the dog sub. Set 45k down on the top of liner with the dog sub. Verified top of liner depth using calculations from to with do sub. 03:45 04:00 0.25 6,908 6,889 COMPZ CASINC RUNL P Pickup and lay down the single of 5" drill pipe. Pickup wt 205k, SO wt 150k. 04:00 04:15 0.25 6,889 6,859 COMPZ CASINC CIRC P Pickup a single, then Break circulation. Monitor well- static. 04:15 04:30 0.25 6,859 6,859 COMPZ CASIN CIRC P Pump a 10 bbl dry job. Chase with 10 bbls of mud. 04:30 04:45 0.25 6,724 6,799 COMPZ CASINC OTHR P Stand back this stand. Blow down the to drive and kill line. 04:45 07:30 2.75 6,799 72 COMPZ CASINC RUNL P Pull out of the hole with liner running tools. Monitor well usin the tri tank. 07:30 08:00 0.50 72 72 COMPZ CASINC RURD P Rig up Baker tongs for Sperry Sun slim MWD. 08:00 09:00 1.00 72 0 COMPZ CASIN OTHR P Break and fay down Sperry Sun Slim MWD. Break and lay down Baker liner running tools. Shut the blind rams. 09:00 09:30 0.50 0 0 COMPZ CASINC OTHR P Lay down Baker tongs for Sperry Sun slim MWD. 09:30 10:00 0.50 0 0 PROD2 STK OTHR P Rig up to pickup Baker whipstock. 10:00 10:15 0.25 0 0 PROD2 STK OTHR P Pre job safety meeting on picking up the whi stock. 10:15 10:30 0.25 0 0 PROD2 STK PULD P Pickup stand of 5" HWDP with the 'ars, break and la down the same. 10:30 13:30 3.00 0 174 PROD2 STK PULD P Make up Baker whipstock assembly. 13:30 14:00 0.50 174 174 PROD2 STK OTHR P Upload Sperry Sun MWD. 14:00 14:15 0.25 174 334 PROD2 STK PULD P Continue to make up the whipstock assembl BHA # 5 . 14:15 17:15 3.00 334 5,913 PROD2 STK TRIP P Trip in the hole w/ whipstock and milling assembly on 5" drill string. Fill pipe and shallow pulse test @ 1282'. Pumping 550 gpm w/ 1350 psi. Fill pipe @ 3662' pumping 515 gpm w/ 1600 si. 17:15 17:45 0.50 5,913 5,955 PROD2 STK OTHR P Madd pass interval 5913' to 5955' bottom of string). Gamma depth of 5776' to 5816' (Within 1' of matching up to depth of Ugnu-A). Pumping 575 gpm w/ 2360 psi. Log @ 3 foot per minute max runnin seed. 17:45 18:30 0.75 5,955 6,724 PROD2 STK TRIP P Continue to trip in w/ BHA #5 (Whipstock assembly), on 5" drill string. Pickup/make up a single after stand #68. E~age 29 csf 42 3~ Time Logs ~ -- -- ! Date From To Dur S_Depth E. De th Phase Code Subcode T COM ___ 01/31/2008 18:30 19:30 1.00 6,724 6,724 PROD2 STK OTHR P Orient whipstock from 68 deg right of high side to 15 deg left. Pumping 575 gpm w/ 2800 psi. PU wt 190k, SO wt 145k. Working stand from 6724' to 6629' 95' . 19:30 20:30 1.00 6,724 6,863 PROD2 STK TRIP P Make up another stand (#69). Pumping 575 gpm w/ 2800 psi, slack off to 6860', working whipstock to 20 deg left of highside. Shut down pumps, slack of 5k with collet @ 6862.58' (.20' high). Begin pumping again to squire survey, showing 17 deg left of highside to 14 deg left of hi h side. PU wt 190k, SO wt 145k. 20:30 20:45 0.25 6,863 6,795 PROD2 STK OTHR P Slack off 45k to shear bolt. Obtain new parameters: PU wt 185k, SO wt ~~ ~ 14147k, rotating 70 rpm: rotating weight 162k w/ 10k ft Ibs of torque. Pumping 367 gpm w/ 1280 psi. i Note: Top of window will be 6795.32', bottom of window 6812.3', upper mill @ bottom of window @ 6831.02'. Total milled minimum 35.7'= 16.98' slide + 18.72' starter mill (8.5" OD to 8-5/8" u er mill. 20:45 00:00 3.25 6,795 6,809 PROD2 STK WPST P Mill window. Pumping 502 gpm w/ 2110 psi. Rotate 100 rpm w/ 11 k ft Ibs of torque. wt on bit 4k. Note: Pumped a 35 bbl sweep (10.3 ppg/ 230 vis) while milling window @ 6805'. 02/01/2008 00:00 00:15 0.25 6,809 6,812 PROD2 STK WPST P Mill window. Pumping 502 gpm w/ 2110 psi. Rotate 100 rpm w/ 11 k ft Ibs of torque. wt on bit 4k. Note: Pumped a 35 bb! sweep (10.3 ppg/ 230 vis) while milling window @ 6805'. 00:15 01:45 1.50 6,812 6,833 PROD2 STK WPST P Continue milling window to bottom of window @ 6812.30' (3452' TVD) Bottom mill depth 6831.02'). Then 2 upper mill Z' below bottom of window. Increase pump rate to 550 gpm w/ 2450 psi. Rotate 60 rpm w/ 11-12k ft Ibs of torque. Note: Pumped a 52 bbl sweep (10.3 ppg/ 2540 vis) while milling window @ 6833'. 01:45 02:30 0.75 6,833 6,833 PROD2 STK WPST P Ream window f/ 6833' to 6775'. Pumping 550 gpm w/ 2450 psi. Rotate 60 rpm w/ 11-12k ft Ibs of torque. Note: Pumped a 50 bbl weighted Hi vis swee + 2 BU. 02:30 03:00 0.50 6,833 6,833 PROD2 STK CIRC P Circulate hole clean. Pump a BU. 03:00 03:15 0.25 6,833 6,833 PROD2 STK OTHR P With pumps off: Slackoff thru window and PU. Noticed 20k ove ull. >F3~g~ ~;3 of ~2 Time Logs _ _ _ Date From To Dur S. De th E. De th Phase Cade Subcode T COM 02/01/2008 14:45 17:00 2.25 1,306 6,734 PROD2 _ DRILL TRIP P _ Continue to trip in the hole with BHA #6. Fill pipe every 25 stands. Monitor well on the trip tank. Fill @ 6162' um in 600 m w/ 2760 si. 17:00 17:45 0.75 6,734 6,734 PROD2 DRILL CIRC P Circulate while working pipe from 6734' to 6638'. Pumping 600 gpm w/ 2830 psi. Rotate 40 rpm w/ 9k ft Ibs of torque. PU wt 185k, SO wt 125k. Circulate 500 bbls total. 17:45 19:00 1.25 6,734 6,734 PROD2 DRILL LOT P Rig up to perform a LOT. Pump through the kill line to fill, use top pipe rams (Variable 4-1/2" x 7") 9.3 ppg mud in the hole. TD was drilled to 6835' (3456' TVD), applied pressure of 900 psi = 14.3 ppQ EMW. Rig down testing equipment. Blow down the kill line. 19:00 19:15 0.25 6,734 6,835 PROD2 DRILL TRIP P Trip in the hole to drill the "D" lateral. Did not notice anything going through the window. Note: Top of window 6795.32' (3448.9' TVD), bottom of window 6812.3' (3452.4' TVD). Oriented to 30 de left of hi hside. 19:15 00:00 4.75 6,835 7,114 PROD2 DRILL DDRL P Obtain parameters. Directional drill 8-1 /2" "D" lateral with a motor with 1.5 de bend. 02/02/2008 00:00 00:30 0.50 7,114 6,915 PROD2 DRILL TRIP P Pull out of the hole with BHA #6 on elevators. 00:30 01:00 0.50 6,915 6,830 PROD2 DRILL REAM P Observed excess drag @ 6915' (25k over pull). Make up the top drive and ream w/ 50 rpm 11-14k ft Ibs of torque. Pumping 550 gpm w/ 2450 psi. Rot wt 145k, PU wt 205k, SO wt 125k. 01:00 01:15 0.25 6,830 6,726 PROD2 DRILL TRIP P Continue to pull out of the hole with BHA #6 on elevators. 01:15 01:30 0.25 6,726 6,726 PROD2 DRILL OWFF P Monitor well- static. Pump a 30 bbl dry job, chase with 10 bbl. Blow down the to drive. 01:30 03:45 2.25 6,726 452 PROD2 DRILL TRIP P Continue to pull out of the hole with BHA #6 on elevators. 03:45 04:45 1.00 452 80 PROD2 DRILL PULD P Work BHA#6. 04:45 05:45 1.00 80 80 PROD2 DRILL OTHR P Download Sperry Sun MWD. 05:45 06:15 0.50 80 0 PROD2 DRILL PULD P Lay down motor and bit. 06:15 06:30 0.25 0 0 PROD2 WELCT OTHR P Drain BOP stack. Pull the wear bushin . 06:30 08:00 1.50 0 0 PROD2 WELCT OTHR P Rig up to test BOPE. Witness of test waived by AOGCC inspector Chuck Sheave. Make up testing tools. Fill stack with water. Pay ~2 raf 42 r~ ~~ ~~ Time Logs _ _ _ _ Date From To Dur S. De th E. De th Phase Code Subcode T COM 02/02/2008 08:00 12:00 4.00 0 0 PROD2 WELCT BOPE P Test all componets to 250 psi low and 3000 psi high. Tested the annular with 4-1 /2" & 5" test jts. Tested upper pipe rams with 4-1/2" test joint. Hold each test for 5 min. Chart test. Perform Koomey test. Test and calibrate gas alarms. 12:00 13:30 1.50 0 0 PROD2 WELCT OTHR NP Rig Down BOPE Test Equipment and Set Wear Bushin 13:30 14:00 0.50 0 0 PROD2 DRILL RURD NP Rig Up to P/U BHA#7, Closed Blind Rams 14:00 14:45 0.75 0 0 PROD2 DRILL OTHR NP Clean & Clear Rig Floor 14:45 15:00 0.25 0 0 PROD2 DRILL SFTY P PJSM on P/U BHA #7 w/ Sperry Sun Re 15:00 17:30 2.50 0 75 PROD2 DRILL PULD NP P/U BHA #7 f/ 0 - 75' MD per Sperry Sun Re 17:30 18:00 0.50 75 0 PROD2 WELC OTHR NP Stand Back BHA #7, Drain Stack and Pull Wear Bushing; R/U to Test U er Variable Rams w/ 5" Test Jt. 18:00 18:30 0.50 0 0 PROD2 WELCT BOPE NP Test 4 1/2" X 7" Variable Upper Pipe Rams w/ 5" test Jt. to 250 PSI Low and 3,000 PSI High; Hold for 5 minutes; Test Good 18:30 19:15 0.75 0 0 PROD2 WELCT OTHR NP Rig Down Test Equipment and Install Wear Bushin 19:15 19:30 0.25 0 75 PROD2 DRILL PULD NP P/U BHA #7 19:30 20:00 0.50 75 75 PROD2 DRILL DHEQ P Upload Software to MWD Tools 20:00 20:30 0.50 75 356 PROD2 DRILL PULD P Continue P/U BHA#7 20:30 20:45 0.25 356 356 PROD2 DRILL DHEQ P Shallow Test BHA 20:45 21:00 0.25 356 372 PROD2 DRILL PULD P Complete P/U of BHA #7 21:00 22:15 1.25 372 2,749 PROD2 DRILL TRIP P RIH on Elevators f/ 372' - 2749' MD; Monitor Dis lacement Via Tri Tank 22:15 22:45 0.50 2,749 2,749 PROD2 DRILL DHEQ P Fill Pipe & Test MWD Tools 22:45 00:00 1.25 2,749 5,132 PROD2 DRILL TRIP P Cont RIH on Elevators f/ 2749 - 5132' MD 02/03/2008 00:00 02:00 2.00 5,132 6,918 PROD2 DRILL TRIP P RIH on Elevators f/ 5132' - 6918' MD; Hole Deviation "Check Shots" @ 6824', 6857', 6887', & 6918' MD Good 02:00 03:30 1.50 6,918 7,114 PROD2 DRILL REAM P Noted Increase in Drag @ 6918' MD; Reamed Down f/ 6918' - 7114' MD; 30 RPM, 550 GPM @ 2450 PSI, Torque 12 K, P/U 185, S/O 122, Rot 142; Took Hole Deviation "Check Shots" @ 6986,', 7014', 7071', & 7109' MD, All Shots Good 03:30 06:00 2.50 7,114 7,270 PROD2 DRILL DDRL P Ddrl "D" lateral f! 7114' - 7270' MD; 600 GPM @ 2770 PSI, P!U 195, S/O 122, Rot 145; ECD = 10.82 PPG; Max EPOCH Gas 264 Units F'ag~ 33 of d2 • ~J Time Lo s Date ___ From To Dur S De th E_ D~th Phase Code Subcode T COM __ 02/03/2008 06:00 12:00 6.00 7,270 8,079 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 7270' - 8079' MD; 700 GPM @ 3420 PSI; P/U 200, S/O 115, Rot 150; ECD = 11.15 PPG; Max EPOCH Gas 1111 Units 12:00 18:00 6.00 8,079 8,374 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 8079' - 8374' MD; 700 GPM @ 3530 PSI; P/U 200, S/O 118, Rot 150; ECD = 11.02 PPG; Max EPOCH Gas 954 Units 18:00 00:00 6.00 8,374 8,965 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 8347' - 8965' MD; 660 GPM @ 3290 PSI; P/U 205, S/O 120, Rot 150; ECD = 11.47; Max EPOCH Gas 1150 Units 02/04/2008 00:00 06:00 6.00 8,965 9,668 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 8965' - 9668' MD; 650 GPM @ 3360 PSI; P/U 215, S/O 112, Rot 148; ECD = 11.72; Max Gas 1343 Units 06:00 12:00 6.00 9,668 10,453 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 9668' - 10453' MD; 630 GPM @ 3220 PSI; P/U 215, S/O 105, Rot 155; ECD = 11.65; Max Gas 1673 Units 12:00 18:00 6.00 10,453 11,124 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 10453' - 11124' MD; 640 GPM @ 3390 PSI; P/U 215, S/O 105, Rot 148; ECD = 11.91; Max Gas 1834 Units 18:00 00:00 6.00 11,124 11,715 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 11124' - 11715' MD; 650 GPM @ 3340 PSI; P/U 215, S/O 105, Rot 150; ECD = 11.91; Max Gas 1179 Units 02/05/2008 00:00 04:45 4.75 11,715 12,200 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 11715' - 12200' MD; 650 GPM @ 3340 PSI; P/U 215, S/O 105, Rot 150; ECD = 11.91; Max Gas 1179 Units 04:45 06:45 2.00 12,200 12,457 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 12200' - 12457' MD; 650 GPM @ 3340 PSI; P/U 215, S/O 105, Rot 150; ECD = 11.91; Max Gas 1179 Units 06:45 07:30 0.75 12,457 12,175 PROD2 DRILL TRIP NP POOH f/ 12457' - 12175' MD for Side Track. 07:30 07:45 0.25 12,175 12,200 PROD2 DRILL DDRL NP Trou h for Sidetrack f/ 12175' - 12200' MD; De artin Down and Ri ht 07:45 12:00 4.25 12,200 12,457 PROD2 DRILL DDRL NP Cont'd Ddrlg "D" Lateral f/ 12200' - 12457' MD; 615 GPM @ 3390 PSI; P/U 215, S/O 105, Rot 150; ECD = 12.14; Max as 738 Units 12:00 18:00 6.00 12,457 13,167 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 12457' - 13167' MD; 630 GPM @ 3710 PSI; P/U 220, S/O 98, Rot 150; ECD = 12.3; Max Gas 1501 Units 18:00 20:15 2.25 13,167 13,502 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 13167' - 13502' MD; 615 GPM @ 3670 PSI; P/U 225, S/O 95, Rot 150; ECD = 12.42; Max Gas 1839 Units 20:15 22:00 1.75 13,502 13,502 PROD2 DRILL CIRC P Rot & Recip While Pumping 43 Bbis of 11.1 PPG 249 Vis Sweep to Clean Hole; Take SPR's Pa~~ 34 ~sf 42 • i Time Logs _~ _ Date From To Dur S De th E. De th Phase Code Subcode T CO M 02/05/2008 22:00 00:00 2.00 13,502 13,694 PROD2 DRILL DDRL P _ Ddrl "D" Lateral f! 13502' - 13694' MD; 615 GPM @ 3800 PSI; P/U 225, S/O 95, Rot 150; ECD = 12.53; Max Gas 979 Units 02/06/2008 00:00 06:00 6.00 13,694 14,081 PROD2 DRILL DDRL P "Lateral f/ 13694' - 14081' MD , TD ;_„585 GPm @ 3490 PSI; P/U 250, S/O 85, Rot 150; ECD = 12.62 06:00 08:00 2.00 14,081 14,081 PROD2 DRILL CIRC P Rot &Recip While Pumping 50 Bbl 11.3 PPG 400 Vis Sweep; 595 GPm 3720 PSI 08:00 12:00 4.00 14,081 11,602 PROD2 DRILL REAM P BROOH f/ 14081' - 11602' MD; 640 GPM 3800 PSI; P/U 220, S/O 98 12:00 18:00 6.00 11,602 8,654 PROD2 DRILL REAM P BROOH f/ 11602' - 8654' MD; 650 GPM 3250 PSI; P/U 190, S/O 115 18:00 22:00 4.00 8,654 7,033 PROD2 DRILL REAM P BROOH f/ 8654' - 7003' MD; 600 GPM 2490 PSI 22:00 22:15 0.25 7,033 6,748 PROD2 DRILL TRIP P Pump Out-of-Hole f/ 7033' - 6748' MD; 600 GPM 2440 PSI 22:15 00:00 1.75 6,748 6,748 PROD2 DRILL CIRC P Rot &Recip While Circ 1- B/U, then Pump 50 Bbl 11.3 PPG 330 Vis Sweep at Shoe, and 3 - B/U After Swee 02/07/2008 00:00 00:15 0.25 6,748 6,748 PROD2 DRILL OWFF P Observe Well For Flow (Static) 00:15 00:30 0.25 6,748 6,748 PROD2 RIGMN SVRG P Inspect & Adjust Draw Works Brakes 00:30 04:00 3.50 6,748 13,980 PROD2 DRILL TRIP P RIH on Elevators f/ 6748' - 13980' MD; Filled Pi a e/ 25 Stds 04:00 04:15 0.25 13,980 14,075 PROD2 DRILL OTHR P Rotate & Wash in Hole f/ 13980' - 14075' MD; 195 GPM @ 850 PSI; P/U 220, S/O 100, Rot 150; 12 Bbl Loss for Whole Tri 04:15 06:00 1.75 14,075 14,081 PROD2 DRILL CIRC P CBU While Working Pipe f/ 14081' - 13983' MD; Staged Pumps Down f/ 600 GPM @ 3370 PSI to 375 GPM @ 1800 PSI Due to Hole Taking Fluid (30 bbl Loss 06:00 07:45 1.75 14,081 14,081 PROD2 DRILL CIRC P Pump 50 Bbl (9.3 PPG, 400 Vis) Sweep While Working Pipe f/ 14081' - 13983' MD; 450 GPM 2370 PSI 07:45 09:00 1.25 14,081 14,081 PROD2 DRILL CIRC P Displace Wellbore Fluid to 9.3 PPG SFOBM; 650 GPM 3800 PSI 09:00 09:45 0.75 14,081 14,081 PROD2 DRILL OWFF P Observe Well for Flow (Static) 09:45 15:30 5.75 14,081 6,179 PROD2 DRILL TRIP P POOH on Elevators f/ 14081' - 6179' MD; Dropped 2.36" Rabbit w/ 186' Tail @ 13409' MD; P/U 270 - 245, S/O 80 - 105 f/ 14081' - 11507' MD 15:30 15:45 0.25 6,179 6,179 PROD2 DRILL OWFF P Observe Well for Flow (Static) 15:45 18:00 2.25 6,179 657 PROD2 DRILL TRIP P POOH f/ 6179' - 657' MD; Rerieved Rabbit 18:00 18:30 0.50 657 371 PROD2 DRILL TRIP P POOH f/ 657' - 371' MD 18:30 19:30 1.00 371 75 PROD2 DRILL PULD P UD BHA #7 f/ 371' - 75' MD, Break Out Bit; Well Static 1 Pa~ae 3~ taf ~2 l l Time Logs _ _ Date_ From To Dur 5 Depth E. De th Phase Code Subcode T COM 02/07/2008 19:30 20:45 1.25 75 75 PROD2 _ DRILL DHEQ P Download MWD Tools; Well Static 20:45 22:00 1.25 75 0 PROD2 DRILL PULD P UD BHA #7 f/ 75' - 0' per Sperry Rep 22:00 22:15 0.25 0 0 PROD2 DRILL OTHR P Close Blind Rams ; Celan & Clear Rig Floor 22:15 23:45 1.50 0 149 COMPZ FISH PULD P M/U Whi stock Rerieval BHA er Baker Oil Tools Re 23:45 00:00 0.25 149 245 COMPZ FISH TRIP P RIH on Elevators f/ 149' - 245 ; Circ @ 3 Bpm @ 1040 Psi Prior to Opening CCV 02/08/2008 00:00 00:15 0.25 245 245 COMPZ FISH CIRC P Drop 2 1/8" Ball to Open CCV, CCV Opened @ 2010 PSI; PSI Dropped to 50 PSI 3 BPM After Actuation 00:15 03:15 3.00 245 6,683 COMPZ FISH TRIP P RIH w/ CCV Open f/ 245' - 6683' MD; P/U 210, S/O 150, Rot 170, Tor ue 9K 03:15 04:00 0.75 6,683 6,775 COMPZ FISH CIRC P Circulate Through Open CCV Staging Pumps Up f/ 450 GPM @ 1210 PSI - 900 GPM @ 3450 PSI; P/U 210, S/O 150, Rot 175, Tor ue 12K 04:00 05:00 1.00 6,775 6,775 COMPZ RPCO CIRC P Condition Mud to 3 % 776 Lube; 600 GPM @ 2010 PSI; P/U 210, S/O 150, Rot 175, Tor ue 10K 05:00 05:30 0.50 6,775 6,775 COMPZ FISH CIRC P Dropped 2 1/8" Ball to Close CCV; Ball on Seat early @ 486 Strokes; CCV Closed @ 2320 PSI; Pressure Increased f/ 180 PSI @ 30 Strokes to 480 PSI 30 Strokes 05:30 06:00 0.50 6,775 6,808 COMPZ FISH FISH P RIH f/ 6775' - 6808" MD; Washed Slot & Attempt to Engage Whipstock; En a ed Whi stock and Pulled U to pan _ ~hserved Unloader Shear Whi stock Free; P/U 210, S/O 150 06:00 07:00 1.00 6,808 6,683 COMPZ FISH CIRC P POOH f/ 6808' - 6683' MD; CBU 450 GPM 2520 PSI 07:00 07:30 0.50 6,683 6,683 COMPZ FISH OTHR P Observe Well For Flow (Static) 07:30 10:45 3.25 6,683 215 COMPZ FISH TRIP P POOH f/ 6683' - 215' MD 10:45 12:00 1.25 215 0 COMPZ FISH PULD P Lay down Fishing Tools 12:00 14:30 2.50 0 0 COMPZ FISH PULD P Break Out /Lay Down Whipstock BHA 14:30 15:00 0.50 0 0 COMPZ RPCOti OTHR P Clean & Clear Rig Floor 15:00 15:15 0.25 0 0 COMPZ RPCO SFTY P PJSM for Seal Bore Diverter Run 15:15 16:15 1.00 0 0 COMPZ RPCO DHEQ P Upload MWD Tools Pie 36 rrf ~2 • Time Logs Date From To Dur 5 De th E. De th Phase Code Subcode T COM 02/08/2008 16:15 18:30 2.25 0 0 COMPZ RPCO PULD P P/U Seal Bore DiverterAssy and MWD Tools; SBD Oriented 13.7 Degrees Right of Production Anchor at Surface Due to Evidence of Mill Walking to Right on Whipstock; Oriented MWD to SBD Lug; "' Note: MLZXP Set at 30 Degreees Left of High Side, w/ BOT Correction MWD Should Show 17 Degrees Left When Latched *' 18:30 18:45 0.25 0 0 COMPZ RPCOh DHEO P Flow Test Baker Seal Bore Diverter Nozzle and Shallow Test MWD Tools: Gain MWD Detection - 270 GPM @ 580 PSI; Actuate (Release) SBD Collet 420 GPM 1340 PSI 18:45 23:00 4.25 0 6,743 COMPZ RPCOh TRIP P RIH w/ Baker Seal Bore Diverter f/ 0.0 - 6888' MD 23:00 00:00 1.00 6,743 6,888 COMPZ RPCOI~ OTHR P Worked Last Stand While Orienting SBD to 22 left of high side; Latched In to MLZXP Packer at 6888' MD; SBD Ramp Aligned @ 19 Deg Left When Latched; Verified Latch by Pulling to 260K; Slack off to 110k, Released Inner String while pumping 475 GPM w/ 2660 PSI; P/U 190, S/O 150 02/09/2008 00:00 00:15 0.25 6,888 6,839 COMPZ RPCO CIRC P After release of the Seal Bore Diverter, pull out of the hole from the top of the Seal Bore Diverter @ 6787.91' to 6739 while pumping 475 GPM w/ 2660 PSI; P/U 190, S/O 150. Continue to circulate to et a bottom's u . 00:15 00:30 0.25 6,839 6,839 COMPZ RPCO OWFF P Monitor well (static). Install stripper rubber. 00:30 03:45 3.25 6,839 127 COMPZ RPCOh TRIP P Pull out of the ho-e w/ Seal Bore running tools. Record PU and SO wt's eve 10 stands. 03:45 04:15 0.50 127 104 COMPZ RPCOh PULD P Lay down BHA. 04:15 04:45 0.50 104 90 COMPZ RPCOh OTHR P Download Sperry Sun MWD. 04:45 05:30 0.75 90 0 COMPZ RPCOti PULD P Continue to lay down running tools for the Seal Bore Diverter 05:30 05:45 0.25 0 0 COMPZ RPCO PULD P Pickup from the pipe shed the Centurian circulating valve. Break the ball catcher and remvoe (2) 2 1/8" balls. Screw back together hand tight and la back down. 05:45 07:15 1.50 0 0 COMPZ RPC06 RURD P Ri u to run the 4-1/2" "D" lateral slot blank 11.6 f L-80 BTC liner. 07:15 07:30 0.25 0 0 COMPZ RPCO SFTY P PJSM on running the liner. 07:30 12:30 5.00 0 7,116 COMPZ RPCOh TRIP P Run 4 1/2" Slotted/Blank Liner f/ 0' - 7116' MD; Obtain Torque and Drag Data Eve 5 Stds 12:30 13:45 1.25 7,116 7,168 COMPZ RPCOb PULD P M/U Ram HangerAssy per BOT Rep ~ P~e~e ~7 of 42 i ~ Time Logs _ Date From _To Dur S De th E. Depth Phase Code Subcode T COM___ 02/09/2008 13:45 14:30 0.75 7,168 7,167 COMPZ RPCO OTHR P Clean & Clear Rig Floor 14:30 19:15 4.75 7,167 13,890 COMPZ RPCO TRIP P RIH on DP f/ 7167' - 13980' MD; No Obstructions or Tight Spots Noted Through Diverter or Sidetrack; Obtained T & D Data Every 5 Stds; With no pump: PU wt @ 13390' was 220K, SO wt 110k. With pumps on 5 bpm w/ 680 psi: PU wt 220k, SO wt 135k, Rot wt 160k w/ 11 k ft Ibs of for ue 19:15 19:30 0.25 13,890 13,977 COMPZ RPCO TRIP P With no pump: PU wt @ 13890' MD P/U 220, S/O 115; With pumps on 5 bpm w/ 680 psi: PU wt 220k, SO wt 135k, Rot wt 160k w/ 11 k ft Ibs of torque; Slack off 30'/min while rotating was150k w/ 10k ft Ibs of torque. Pickup 30'/min while rotating was 180k w/ 10k ft/Ibs of torque; RIH Stand #71 t/ 13977' MD 19:30 19:45 0.25 13,977 14,030 COMPZ RPCO TRIP P Wash In Hole f/ 13977' - 13998' MD per BOT Rep; 207 GPm @ 680 PSI; Shut Down Pumps and RIH to 14030' MD; P/U 200, S/O 130, Set Down 45 K (82K on Wt. indicator) and Latched Into Diverter; Pulled Out of Diverter w/ 60 K (260 K Wt. Indicator) Overpull; Set Down 45 K (82K on Wt. Indicator) and Latched Back In; Picked Up to 230 K to Test Latch (Good); Set Back Down to 82 K on Indicator 19:45 20:45 1.00 14,030 6,623 COMPZ RPCO CIRC P Drop 29/32" Ball and Pump Down First 800 Strokes 5 BPM w/ 700 PSI, then 2 BPM w/ 260 PSI; ball on Seat @ 1100 Strokes; Pressure Up to 3000 PSI to Release Inner String & Bled Off; POOH t/ 6523' MD ** Wellview Depth Changed 6623' MD Due to Liner Left in Hole ** 20:45 21:00 0.25 6,623 6,623 COMPZ RPCO CIRC P Pressure Up to 4000 PSI to Push Ball Through Seat; Regained Circulation; Circ'ed 8 BPM w/ 850 PSI for 2,000 Strokes to Com lete B/U 21:00 21:15 0.25 6,623 6,623 COMPZ RPCOh SFTY P PJSM for Cut/Slip Drill Line & Lube To Drive 21:15 22:15 1.00 6,623 6,623 COMPZ RIGMN SVRG P Cut 178' of 1-3/8" Drill Line. 22:15 22:45 0.50 6,623 6,623 COMPZ RIGMN SVRG T Trouble shoot electric motor on drilling lines ool reel. 22:45 00:00 1.25 6,623 6,623 COMPZ RIGMN SVRG P Grease and inspect top drive, blocks, and crown while monitor well on the tri tank. 02/10/2008 00:00 00:30 0.50 6,623 6,623 COMPZ RIGMN SVRG P Slip 178' of 1-3/8" drilling line onto the drawworks. Finish w/ installation of drillin line. 00:30 02:00 1.50 6,623 6,623 COMPZ RIGMN SVRG P Change Gear oil & Filters on Draw Works; Ins ect Blocks & Crown ~'ag~ ~$ ~t ~2 i J Time LOgg __ Date From To Dur S De th E. De th Phase Code Sub code T COM 02/10/2008 02:00 02:30 0.50 6,623 6,623 COMPZ RPCOh _ CIRC P CBU 340 GPM @ 870 PSI 02:30 03:00 0.50 6,623 6,623 COMPZ RPCO OWFF P OWFF (Static) 03:00 05:15 2.25 6,623 0 COMPZ RPCOh TRIP P POOH f/ 6623' - 0' MD per BOT Rep; UD Baker RAM Han er Runnin Tools 05:15 06:00 0.75 0 0 COMPZ RPCOh OTHR P Clean & Clear Rig Floor 06:00 06:45 0.75 0 0 COMPZ RPCOh RURD P Rig Up to Run LEM and Torque Master Packer per Sperry Sun & BOT re s: Close Blind Rams 06:45 07:00 0.25 0 0 COMPZ RPCO SFTY P PJSM for P/U LEM, Packer, and MWD Tools 07:00 08:15 1.25 0 0 COMPZ RPCOb PULD P P/U Type II (instead of Type I as planned)LEM, Torque Master Packer, and MWD 08:15 08:30 0.25 0 0 COMPZ RPCOh DHEQ P Pulse Test MWD 80 GPm @ 400 PSI; Blow Down To Drive 08:30 13:00 4.50 0 6,778 COMPZ RPCOh TRIP P RIH w/ Type II LEM on DP f/ 0' - 6778' MD 13:00 13:45 0.75 6,778 6,810 COMPZ RPCO DHEQ P Orient Type II LEM Lug to RAM Hanger; 90 GPM @ 830 PSI; P/U 198, S/O 150 Note: LEM lug self oriented from 6 deg Right of highside to 85 deg Right of hi hside b MWD readin s. 13:45 15:30 1.75 6,810 6,810 COMPZ RPCO PACK P Drop 29/32" Ball to Set Packer; Ball on Seat @ 1350 Strokes; 92 GPM @ 990 PSI; Pressured Up to 2500 PSI to Set Packer; Held Pressure for 5 Minutes (Good); Top of Packer 6760.96' M D 15:30 16:00 0.50 6,810 6,810 COMPZ RPCO PACK P Pressure U Annulus Through Kill Line t/ 2500 PSI and Hold f/ 5 Minutes 16:00 16:15 0.25 6,810 6,810 COMPZ RPCOti PACK P Pump down string, Pressured Up to 4380 PSI to Release Packer Setting Tool and blow ball seat. 16:15 17:30 1.25 6,810 6,810 COMPZ RPCO CIRC P CBU: 340 GPM @ 900 PSI; Pump 26 Bbl "Dry Job" and chase w/ 10 Bbl Mud; Dro "Mud Do " 17:30 22:30 5.00 6,810 0 COMPZ RPCOh TRIP P POOH f/ 6810' - 0' MD; Lay Down 5" DP 22:30 00:00 1.50 0 0 COMPZ RPCOh PULD P Break Out & UD BOT Packer Setting Tools & Slim Hole MWD Tools 02/11/2008 00:00 00:30 0.50 0 0 COMPZ RPCO PULD P Continue to UD MWD and BOT Packer Settin Tools 00:30 01:00 0.50 0 0 COMPZ RPCOh OTHR P Clean Clear Rig Floor of LEM Running Tools 01:00 02:15 1.25 0 0 COMPZ RPCOh RURD P Close Blind Rams, Drain Stack & Pull Wear Bushing; Pull Mousehole Remove Drain, Install Bull Plug & Install In Rotary Table; Prep t/ UD 5" DP f/ Derrick 02:15 02:30 0.25 0 0 COMPZ RPCOf~ SFTY P PJSM for UD 5" DP f/ Derrick P~g~ 3J saf ~2 l J Time Logs _ _ Da e From_To _ Dur S. Depth E. Depth Phase Code Subcode T COM _ _ 02/11/2008 02:30 06:00 3.50 0 0 COMPZ RPCOh PULD P UD 5" DP f/ Derrick 06:00 09:45 3.75 0 0 COMPZ RPCOti PULD P Continue t/ UD 5 " DP f/ Derrick 09:45 14:00 4.25 0 0 COMPZ RPCO RURD P Clean & Clear Rig Floor; R/U Centerlift &GBR for 4 1/2" Tubing Run w! Heat Trace & Gau a Cable 14:00 14:15 0.25 0 0 COMPZ RPCOh SFTY P PJSM w/GBR, Centerlift, BOT, & Rig Crew for Runnin 4 1/2" Tubin Strin 14:15 18:00 3.75 0 1,205 COMPZ RPCO RCST P Run 4 1/2" Completion String f/ 0' - 1205' MD er Detail 18:00 22:00 4.00 1,205 3,457 COMPZ RPCO RCST P Continue Running 4 1/2" Tubing f/ 1205' - 3757' MD 22:00 00:00 2.00 3,757 3,757 COMPZ RPCOh RURD P P/U Dual Channel Cross Clamps; R/U Heat Trace Sheave in Derrick 02/12/2008 00:00 01:00 1.00 3,757 3,757 COMPZ RPCOh RURD P P/U Dual Channel Cross Clamps; R/U Heat Trace Sheave in Derrick 01:00 01:15 0.25 3,757 3,757 COMPZ RPCO SFTY P Pre job safety meeting on running with both the heat trace and TEC wire. 01:15 01:45 0.50 3,757 3,757 COMPZ RPCOh DHEQ P Test heat trace (Megger wire) OK. 01:45 03:00 1.25 3,757 3,944 COMPZ RPCOh RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Joint # 125 in the hole. Monitor well on the trip tank. 03:00 03:15 0.25 3,944 3,944 COMPZ RPCOti DHEQ P Test heat trace (Megger wire) OK. Testin TEC wire for the ua e. OK. 03:15 05:00 1.75 3,944 4,314 COMPZ RPCO RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Joint # 137 in the hole. Monitor well on the trip tank. 05:00 05:30 0.50 4,314 4,314 COMPZ RPCOh DHEQ P Test heat trace (Megger wire) OK. Testin TEC wire for the ua e. OK. 05:30 06:00 0.50 4,314 4,438 COMPZ RPCO RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Joint # 141 in the hole. Monitor well on the trip tank. 06:00 12:00 6.00 4,438 5,197 COMPZ RPCOti RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Monitor well on the tri tank. 12:00 18:00 6:00 5,197 6,344 COMPZ RPCOh RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Monitor well on the tri tank. 18:00 21:15 3.25 6,344 6,739 COMPZ RPCOh RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Monitor well on the tri tank. 21:15 00:00 2.75 6,739 6,739 COMPZ RPCOh RCST T Attempting to latch TorqueMaster anchor assembl .Not latching. Call town and discuss options. Attempt to rotate tubing 90* & 180' with elevators. Can't hold torque. Continue attem is to latch anchor 02/13/2008 00:00 01:15 1.25 6,768 6,768 COMPZ RPCOh RCST T TorqueMaster anchor not latching. Circulate bottoms ups while discussing options with town. Pumping 338 gpm, 480 psi, max gas 41 units. Page ~tP caf 42 C~ Time Los _ Date_ From S De th E. De th Phase Code Subcode T COM To Dur _ 02/13/2008 _ 01:15 01:45 _ 0.50 6,768 6,768 COMPZ RPCOh RCST _ T Continue working pipe attempting to latch anchor. Pumps on, rotate 90*, 180* holding torque with topdrive. Stop pumps, rotate 270"` attempt to latch. 1st try saw bobble on weight indicator. 2nd try latched with 28' of joint 216 in the hole. 01:45 02:00 0.25 6,768 6,768 COMPZ RPCO RURD T Rig down crossovers and blow down to drive. 02:00 02:15 0.25 6,768 6,768 COMPZ RPCO RCST P Pull with elevators to 55k over up wt of 130k to shear from seal assembl 02:15 03:30 1.25 6,768 6,679 COMPZ RPCOh RCST P POOH and lay down 3 joints of tubing. Retest heat trace and control line, both ood. 03:30 04:45 1.25 6,679 6,768 COMPZ RPCOh HOSO P PU space out pups, hanger and landin ~oint and run in hole. 04:45 05:30 0.75 6,768 6,768 COMPZ RPCO PULD P Rig down sheves from derrick. 05:30 08:15 2.75 6,768 6,768 COMPZ RPCOh RCST P Splice heat trace and control cable. Sim ops clear rig door, clean drip pan and clean it #5. 08:15 10:15 2.00 6,768 6,768 COMPZ RPCO RCST P Land tubing in hanger, run in lock down screws, pull landing joint, blow down lines, clear ri floor. 10:15 14:30 4.25 0 0 COMPZ RPCOh RURD P Lay down mouse hole, nipple down ROPE. 14:30 15:00 0.50 0 0 COMPZ RPCOti NUND P Nipple up tubing adapter and tree. 15:00 15:30 0.50 0 0 COMPZ RPCO RCST P Test heat trace and control cable, test ood. 15:30 17:00 1.50 0 0 COMPZ RPCOh NUND P Pressure test sea-s and tree to 5000 si, test ood 17:00 18:00 1.00 0 0 COMPZ RPCOCV RURD P PJSM -freeze protect. Rig up to freeze protect 9-5/8" x 4-1/2" annulus and 4-1/2" tubing. Pressure test lines and ull 2 wa check valve. 18:00 19:00 1.00 0 0 COMPZ RPCOb FRZP P Freeze protect 9-5/8" x 4-1/2" annulus and 4-1/2" tubing. Pump 160 bbls at 3 b m, 675 si. 19:00 20:30 1.50 0 0 COMPZ RPCO FRZP P Put 9-5/8" x 4-1/2" annulus and 4-1/2" tubing in communication and u-tube freeze protect diesel. Sim ops -blow down lines & clear cellar for ri move. 20:30 22:00 1.50 0 0 COMPZ RPCOb RURD P Shut in well, rig up lubricator, install back pressure valve and gauges. Tubing pressure 350 psi, 9-5/8" x 4-1 /2" annulus pressure 350 psi, 13-3/8" x 9-5/8"annulus pressure 150 si 22:00 00:00 2.00 0 0 COMPZ RPCOti OTHR P Clean cellar box, blow down steam and water lines. Disconnect lines between modules. Move cuttings boxes and re rockwasher for move. 02/14/2008 00:00 01:15 1.25 0 0 COMPZ RPCOb OTHR P PJSM -removing beaver slide. Lay down beaver slide Gage ~1 0~ ~2 • Time Logs _ _ Date From To Dur S De th E_~th P~e_ Code Subcode T COM__ 02/14/2008 01:15 03:00 1.75 0 0 COMPZ RPCOh OTHR P PJSM -skidding rig floor. Skid rig floor and function test moving system. Release ri at 03:00 6~~ge 42 ~rf d2 • 27-Mar-08 AOGCG Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3K-102 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 10,084.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 n ~ ~ _ , Date~,~ ~~ ~?~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ao~- ~~s- FW: 3K-102L1PB1 PTD #20 ~6 -Request to gas lift via open sleeve Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.comj Sent: Monday, February 25, 2008 8:53 AM To: Maunder, Thomas E (DOA) Subject: RE: 3K-102 PTD #207-165 -Request to gas lift via open sleeve. Tom, Page 1 of ~!~, ~~ Your presumption is correct the sleeve will be closed for further production past the 30 day clean up period. The rig recently moved off the well and operations is in the process of attaching the surface piping. I assume the 407 is in the mail but I'll double check with drilling regarding it's status. Point noted on the nomenclature with regard to the laterals, thanks. Thanks again Perry Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent. onday, February 25, 2008 8:35 AM To: NSK II Integrity Proj Subject: RE: -102 PTD #207-165 -Request to gas lift via open sleeve. Perry, I looked at the well fife an a permit was for agas-lifted producer. I don't see ai regarding lifting from the slee for the 30 or so days proposed. I presume the after that is to lift via GLMs as us ? Is the rig just finishing the well? We not have a 407 in the file. One other item, the correct well referenc ~ 3K-102 not 3K-102L1 or 2L1 PB1. It can be confusing. All production is "credit " to the motherbore Laterals are sort of long perforations. Call or message if you have any questions. Tom Maunder, PE AOGCC From: N5K Well Integrity Proj [mailto:Ni @conomphillips.com] Sent: Monday, February 25, 2008 4: M To: Maunder, Thomas E (DOA) Subject: FW: 3K-102l1P81 #207-166 -Request to gas lift via open sleeve. Tom, CPAI wptfid like permission to temporarily gas lift 3K-102L1PB1 via an open CMD, sliding sleeve at 6688' MD: ,~Gr wish is to lift as deeply as possible in order to maximize clean up of the residual oil based drilling mud. We would like to produce the well with the sleeve open for no more than 30 days. 2/25/2008 FW: 3K-102L1PB1 PTD #207 6 -Request to gas lift via own sleev~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 25, 2008 8:35 AM To: 'NSK Well Integrity Proj' Subject: RE: 3K-102 PTD #207-165 -Request to gas lift via open sleeve. Perry, I looked at the well file and the permit was #or a gas-lifted producer. I don't see an issue regarding lifting from the sleeve for the 30 or so days proposed. I presume the intent after that is to lift via GLMs as usual? Is the rig just finishing the well? We do not have a 407 in the file. One other item, the correct well reference is 3K-102 not 3K-102L1 or -102L1 PB1. It can be confusing. All production is "credited" to the motherbore. Laterals are sort of long perforations. Call or message if you have any questions. Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [maiito:N1878@conocophillips.com] Sen#: Monday, February 25, 2008 4:40 AM To: Maunder, Thomas E (DOA) Subject: FW: 3K-102L1PBi PTD #207-166 -Request to gas lift via open sleeve. Tom, Page 1 o((f~~ 2(,L ~L~ CPAI would like permission to temporarily gas lift 3K-102L1 PB1 via an open CMD, sliding sleeve at 6688' MD. Our wish is to lift as deeply as possible in order to maximize clean up of the residual oil based drilling mud. We would like to produce the well with the sleeve open for no more than 30 days. The enclosed schematic is in a slightly different format then previous ones you may be accustomed to. Please let me know if you have any questions. Sincerely Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 2/25/2008 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ,TM <° c ~_ ~t~ , 3; ~,~ ~„ ,,a,,r, ,, ~~~t~~ Log Description NO.4564 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 01 /25!08 2B-13 11996584 PRODUCTION PROFILE gj~ - J p 01110108 1 1E-112 11994598 INJECTION PROFILE V~, - ~{ 01111/08 1 iJ-164L1 12005203 MEM INJECTION.PROFILE ~QS- ~ ~ ~~ 01122/08 1 2M-20 11996596 PRODUCTION PROFILE - p~( 01122108 1 1C-170 11970605 U51T 12/02107 1 2G-06 11994596 PSP MULTI-FINGER CALIPER - 01/10/08 1 3K-102 11994599 MDT '~ - 01/14/08 1 1J-127 11994603 INJECTION PROFILE ()=C..- ~O(o~-p~('~- 01121108 1 2T-21 11839639 RST 1 ~ 08/02107 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Cb ~ ~ ,.~ ~ SARAH PAL/N, GOVERNOR ~SJ~ OIL ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'1'IOI1T Cp1~II-TI55IO1~T ANCHORAGE, ALASKA 99501-3539 Randy Thomas PHONE (907) 279-1433 Drilling Team Leader FAx (907) 27s-7542 Conoco Phillips Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 3K-102 Conoco Phillips Alaska, Inc. Permit No: 207-165 Surface Location: 910' FSL, 315 FWL, SEC. 35, T13N, R09E, UM Bottomhole Location: 3154' FSL, 4736' FWL, SEC. 36, T13N, R09E, UM Dear Mr. Thomas: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 6~-3607 (pager). b~G~~~ ~--~ ~iairman DATED this ~ day of rr~,c>~h 2007 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • • Co~ocoPh ~ I l ~ s h Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com December 3, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 3K-102, 3K-102 Li Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a horizontal well in the West Sak "B" and "D" sands. The main bore of the well will be designated 3K-102, and the lateral bore of the well will be designated 3K-102L1. - Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 3K-102 is January 1, 2008. If you have any questions or require any further information, please contact Dennis Hartwig at 265-6862. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader ~j~:~.~ ~ ~ 2ao7 --"t93;i~c~ ,~ "; > I;~n~. ~OrT13i11SSi01~ ~~:~,chara~e • u STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ISSION PERMIT TO DRILL h~ b1a~- 20 AAC 25.005 w , ~°~ ~~ ~`~~~~ r ,: ~/ar . !x' - ~ ; ~r~~1lisSi0t1 I-~d~ t,,• s 1a. Type of Work: Drill Q ~ Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil ^ ~ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. ' 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 3K-102 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14077 ' TVD: 3628' 12. Field/PO01(S): KuparukRiver Field 4a. Location of Well (Governmental Section): Surface: 910' FSL, 315' FWL, Sec. 35, T13N, R09E, UM 7. Property Designation: ADL 25519 West Sak Oil Pool ~ Top of Productive Horizon: 3719' FSL, 3598' FWL, Sec. 35, T13N, R09E, UM 8. Land Use Permit: ALK 2555 13. Approximate Spud Date: 1/1/2008 Total Depth: 3154' FSL, 4736' FWL, Sec. 36, T13N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 544' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529306 ' y- 6007904 ~ Zone- 4 10. KB Elevation ~, /~ ~ ~,t L 7"1- /~ ~Z'~ ~" (Height above GL): 40' RKB feet 15. Distance to Nearest ~ Well within Pool: 3K-20 , 363' 8865' @ 16. Deviated wells: Kickoff depth: 300 ' ft. Maximum Hole Angle: g0° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1596 psig ~'' Surface: 1197 psig 18. Casing Program S if ti Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 40" 20" 94# K-55 Welded 80' 40' 40' 120' 120' 260 cf ArcticCrete 16" 13-3/8" 68# L-80 BTC 3100' 40' 40' 3100' ~ 2187' ~ 670 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 7800' 40' 40' 7800' ; 3576' ~ 660 sx DeepCRETE 8.5" 5.5" 15.5# L-80 Hydril 521 7002' 7075' 3497' 14077', 3628' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be com pleted for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dennis Hartwig @ 265-6862 Printed Name Randy Thomas Title Drilling Team Leader Signature ~ ~ Vii--L~-~ Phone Z~.S_.~ z? 3"C• Date ~ 2 (j~d ^f Sh r n II -Dr k Commission Use Only Permit to Drill Number: ~~~- ~~p ~ API Numbe7r: 2 /yam 50- ~ Z.9~' ~~3 ~~ ~ Permit Approval / xx Date: ~~ ' l / ~ V ~" See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me ane, gas hydrates, or gas contained in shales:. ;-~ ` Samples req'd: Yes ^ No Mud log req'd: Yes ^ No [t~ Other:.y~~~` ~JO~ ~5~ H2S measures: Yes ^ No ire I svy req'd: Yes [~'J No ^ ~~!/~~~ APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 Submit in Duplicate /~/~i'o~ ~ t 2 .G ,a,~' A~ion for Permit to Drill, Well 3K-102 Revision No.O Saved: 28-Nov-07 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) .............................................:.................................................. 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ..................................................................................................:............ 8 1. Well Name Requirements of 20 AAC 25.005 (~ 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(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 3K-102. 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 identifying the properly 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. (8) 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 910' FSL 315' FWL Section 35 T13N R09E ASP Zone 4 NAD 27 Coordinates RKB Elevation 74.3' AMSL Northings 6,007,904' Eastings: 529,306' Pad Elevation 34.3' AMSL Location at Top of Productive Interval 3,719' FSL, 3,598' FWL, Section 35, T13N, R09E West Sak "B" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 7,615' Northings: 6,010,726' Eastings: 532,573' Total Vertical De th, RKB: 3 562' Total Vertical De th, SS: 3,488' Location at Total De th 3 154' FSL, 4,736' FWL Section 36, T13N, R09E ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 14,077' Northings: 6,010,192' Eastings: 538,994' Total Vertical De th, RKB: 3,628' Total Vertical De th, SS: 3 554' j+'"ti ~' t V ~ ~! ~. { 3K-102 PERMIT IT.doc Page 2 of 8 Printed: 28-Nov-07 A~ation for Permit to Drill, Well 3K-102 Revision No.0 Saved: 28-Nov-07 Permit It -West Sak Well#3K-102 •~~~~ .., +k Application for Permit to Drill Document ~-~ ax~ell Mpxintiiz~ tM~ll +fa144 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) ....................................................................................................... 3 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 ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 „'~:IGINAL 3K--102 PERMIT /T.doc Page 1 of 8 Printed: 28-Nov-07 and (D) other information required by 20 AAC 25.050(6); A~tion for Permit to Drill, Well 3K-102 Revision No.O Saved: 28-Nov-07 Requirements of 20 AAC 25.050(6) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 3K-102 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 (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 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 (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 3K-102. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 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 maybe encountered, criteria used to determine it; and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 3K area are 0.44 psi/ft, or 8.4 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak ~~B" sand formation is 1,197 psi, calculated thusly: MPSP = (3,628 ft TVD)(0.44 - 0.11 psi/ft) = 1,197 psi (8) 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: 3K-102 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dril! 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(f); 3K-102 will be completed with a 9-5/8" intermediate casing landed in the West Sak B sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the °Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 3K-102 PERMIT /T.doc Page 3 of 8 Printed: 28-Nov-07 ^IGWAL A~ation for Permit to Drill, Well 3K-102 Revision No.O Saved: 28-Nov-07 5. 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 Fle with the commission and identified in the application: (6) a complete prop~~sed 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 See also Attachment 3: Cement Summary Hole Top Btm CsglTbg Size Weight Length MD/TVD MD/TVD OD in in /b/ft Grade Connection ft ft ft Cement Pro ram 20 x 34 40 94 K55 Welded 80 40 J 40 120 / 120 Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8 16 68 L-80 BTC 3,100 0 / 0 3,100 /2,187 670 sx ASLite Lead, 220 sx DeepCRETE Tail Cement Top planned @ 9-5/8 12-1/4 40 L-80 BTCM 7,800 0 / 0 7,800 / 3,576 4,100'MD / 2,561TVD Cemented w/ 660 sx, 12.5 ppg DeepCRETE. 5-1/2 81/2" B Sand 15.5 L-80 Hydril 521 7,002 7,075 / 3,497 14,077 / 3,628 Slotted- no cement Slotted Lateral (3K-102) X BTC 4-1/2 81/2" D Sand 11.6 L-80 Hydril 521 7,094 6,975/ 3,458 14,069 / 3,564 Slotted- no cement slotted Lateral (3K-102 X BTC L1 6. 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); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 3K-102. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 3K-102 PERMIT /T.doc Page 4 of 8 Printed: 28-Nov-07 ~~~~~~ A~tion for Permit to Drill, Well 3K-102 Revision No.0 Saved: 28-Nov-07 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) S ud to Base of Permafrost Base of Permafrost to 13-3/8" Casin Point Initial Value Final Value Initial Value Final Value Density (PPg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 seconds) Yie-d Point 50 70 30 50 cP) Plastic Viscostiy 30 55 15 20 (Ib/100 sf) PH 9.0 9.5 9.0 9.5 .4P/ Filtrate NC 0 8 8 0 8 0 (cc / 30 min . . . Intermediate Hole Mud Program (LSND) Y3-3/S" Cs Shoe to 9-5/8" Cs Point Value Density (PP91 8.8 - 9.2 Funnel Viscosity 45 - 60 seconds) Plastic Viscostiy 12 - 18 (Ib/100 s Yield Point 18-24 (cP) API Filtrate 4 - 6 cc / 30 min Chlorides (mg/I) <500 pH 9.0 - 10.0 MBT < 18.0 Lateral Mud Program (MI VersaPro Mineral Oil ~ Base) B & D sand laterals Value Densi ( 8.4 - 8.5 Plastic Viscostiy 15 - 25 Ib/100 sf Yield Point 15 - 20 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200 si & 150° Oil /Water Ratio 80 / 20 Electrical 650 - 900 Stabilit Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 8. 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 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 3K-102 PERMIT IT.doc Page 5 of 8 ^ ~ ~ A i Printed: 28-Nov-07 A~ation for Permit to Drill, Well 3K-102 Revision No.0 Saved: 28-Nov-07 9. 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: (i 0) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061 (a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. 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: (ii) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed condition-<; as required by 20 AAC 25.061 (b); Not applicable: Application is not for an offshore well. 11. 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. 12. 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 also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 120' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Install 21-1/4"Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3,100' MD / 2,187' ND as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 12-1/4" bit and 8"drilling assembly, with MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 9-5/8" casing point at 7,800' MD / 3,576' ND, the prognosis top of the B sand. Pull out of hole backreaming to the surface casing shoe. 9. Run in hole with Schlumberger drillpipe conveyed MDT tools and obtain fluid samples through West B, D and Ugnu Sands. 10. Run in hole with Schlumberger drillpipe conveyed sidewall cores and obtain samples in West Sak B, D and Ugnu sand package. 11. Perform hole cleaning run prior to running casing. ORIGINAL 3K-102 PERMIT IT.doc Page 6 of 8 Printed: 28-Nov-07 A~tion for Permit to Drill, Well 3K-102 Revision No.O Saved: 28-Nov-07 12. Run 9-5/8", 40# L80, BTC Mod casing to surface. (top of cement to be 4,100' MD / 2,561' TVD which corrresponds to 500' above the Ugnu C formation.) ,~_ C~w~c.+~~-Cus\t~ SSE CMCsty` 13. Install wellhead x 9-5/8" packoff and test to 5000 psi. ~C~ ~~ j 14. Flush 13-3/8" x 9-5/8"annulus with water, followed by diesel. ~'" ~ `~ 15. PU 8-1/2" PDC Bit and 6-3/4"drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 16. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling OBM mud. Perform formation integrity test to leak off, recording results. ~r~y`~ 7 Directionally drill 8-1/2" hole to TD at +/- 14,077' MD / 3,628' TVD as per directional plan. > ~' . ~-~` 18. POOH, back reaming out of lateral to 9-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. Pump out of Hole. 19. PU and run 5-1/2" slotted liner. 20. Land liner, set liner hanger @ +/- 7,075'MD / 3,497TVD. POOH. ~®~ ~ ~ ~ Note: Remaining operations are covered under the 3K-102L! Application for Permit to Drill, and are provided here for information only. 21. Run and set Baker Gent WindowMaster whipstock system, at window point of +/- 6,975' MD / 3,458' TVD, the top of the D sand. 22. Mill 8-1/2" window. POOH. 23. Pick up 8-1/2"drilling assembly with LWD, MWD, PWD and rotary steerable tool. RIH. 24. Drill to TD of B sand lateral at +/- 14,069 MD / 3,564' TVD, as per directional plan. 2S. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. Pump out of hole. 26. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 27. RIH and set Baker Seal Bore diverter 28. PU and run 4-1/2"slotted liner with Baker Oil Tools RAM Hangar system. 29. Land Baker RAM hanger in Baker seal bore diverter. Release hanger running tool. POOH 30. Make up junction isolation / re-entry (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly (Torquemaster packer) and release from assembly. Pull out of hole laying down drillpipe as required. 31. PU Gas Lift completion as required and RIH to depth. Land tubing. Set BPV 32. Nipple down BOPE, nipple up tree and test. Pull BPV. 33. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 34. Set BPV and move rig off. 35. Rig up wire line unit. Pull BPV. 36. Set gas lift valves in mandrels. 37. Place well on production. 3K-102 PERMIT /T.doc Page 7 of 8 Printed: 28-Nov-07 A~ation for Permit#o Drill, Well 3K-102 Revision No.O Saved: 28-Nov-07 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 3K Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 3K Pad, 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 (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14. Attachments __ _ Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 CemCADE Summary Attachment 4 Well Schematic OR16!NAL 3K-102 PERMIT /T.doc Page 8 of 8 Printed: 28-Nov-07 3K-102~rilling Hazards ~mmarv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 16" Open Hole / 13-3/$" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Low Maintain planned mud parameters, Increase Gravels mud wei t, use wei hted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumpin out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Increase Gravels mud wei ht, use wei hted swee s. Gas Hydrates Low Control drill; reduced pump-rates, reduced ,% drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei ht Abnormal Reservoir Moderate BOP training and drills, increased mud weight. Pressure ~' Lost circulation Moderate Reduced pump rates, mud rheolo y, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumpin out 8-1/2" Open Hole / 5-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Moderate ~ Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud wei ht Lost Circulation Moderate Reduced pump rates, mud rheolo y, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumpin out, backreamin 3K-102 Drilling Hazards Summary.doc prepared by Dennis Hartwig 11/30/2007 1:15:00 PM , Plan: 3K-102 (wp06) Sperry Drilling Services Proposal Report -Geographic 09 November, 2007 ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 3K Pad Plan 3K-102 3K-102 Local Coordinate Origin: Centered on Well Plan 3K-102 Viewing Datum: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) ' TVDs to System: N North Reference: True Unit System: API - US Survey Feet ~3per~y ©riiling Services OR161NAL Project: Kuparuk River Unit Site: Kuparuk 3K Pad ~ ~ ~ ~ Well: Plan 3K-102 _ Wellbore: 3K-102 Plan: 3K-102 (wp06) (~$ WEf.L DETAILS: Plan 3K-102 NAU 1927 (NAUCUN CONUS) Alaska ZoneAlaska Zone 04 !!) Ground Level: 34.30 +N/-S +FJ-W Northing Fasting Latittude Longitude Slot 0.00 0.00 6007903.69 529305.84 70°25'S7.616N 149°45'40W ANNOTATIONS ND MD Annotation 40.00 40.00 SHL: 909.84 FSL, 314.99 FWL -SEC 35 -T73N - R09E 3273.62 6250.00 Begin Pump Tangent 80° INC ~ 6250' MD. 3273.82' TVD 3338.20 6450.00 End PumpTangent (dj 6450' MD, 3380.2' ND 3562.43 7615.50 9-5/8" (~ 3718.82 FSL, 3597.58 FWL -SEC 35 -T73N - R09E 3628.0014076.70 BHL ~ 14076.8' MD, 3628.0' TVD, 3153.78 FSL, 4736.10 FWL -SEC 36 -T73N - R09E 1077 538 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Targel 1 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 z zso.ao 0.09 o.ao zso.oa 0.ao a.oa o.o0 0.00 o.oa 3 380.00 3.00 310.00 379.95 2.02 -2.41 2.50 310.00 -2.41 4 703.47 12.70 310.00 700.00 30.39 -36.22 3.00 0.00 -36,22 5 1392.55 40.00 320.00 1311.68 253.08 -240.57 4.00 13.96 -240.57 6 2480.23 68.00 350.00 1954.17 1044.49 -563.89 3.3fi 51.08 -563.89 7 3980.23 68.00 50.00 2516.08 2292.48 -109.65 3.71 90.00 -109.65 8 4753.17 71.22 82.87 2791.99 2575.14 543.84 4.00 90.06 543.84 9 8507.47 71.22 62.87 3356.70 2781.39 2191.91 0.00 0.00 2191.91 10 8775.37 80.00 89.22 3423.27 2798.98 2450 41 4.00 35.88 2450.41 11 6975.37 80.00 89.22 3458.00 2801.66 2647.35 0.00 0.00 2647.35 12 7005.37 80.00 89.22 3463.21 2802.08 2676.89 0.00 0.00 2676.89 13 7435.37 80.00 89.22 3537.88 2807.83 3100.32 0.00 0.00 3100.32 14 7535.50 83.00 89.38 3552.68 2809.04 3199.34 3.00 3.00 3199.34 15 7585.50 83.00 89.38 3558.77 2809.58 3248.96 0.00 0.00 3248.96 16 7615.50 83.00 89.38 3562.43 2809.90 3278.74 0.00 0.00 3278.74 17 7815.06 88.98 69.63 3576.37 2811.61 3477.71 3.00 2.45 3477.71 18 8803.19 88.98 89.63 3593.94 2817.92 4465.66 0.00 0.00 4465.88 19 8832.24 89.60 90.25 3594.30 2817.95 4494.71 3.00 44.97 4494.71 3K-102 T2 20 8832.90 89.60 90.27 3594.30 2817.95 4495.37 3.00 90.00 4495.37 2110115 40 89.60 90.27 3603.30 2811.91 5777.82 0.00 0.00 5777.82 3K-102 T3 2210415.71 89.52 99.28 3605.62 2786.94 6076.77 3.00 90.53 6076.77 2311332.23 89.52 99.28 3613.30 2639.17 8981.27 0.00 0.00 6981.27 3K-102 T4 2471375.95 89.00 98.07 3613.86 2632.57 7024.48 3.00 -113.29 7024.48 2912032.03 89.00 98.07 3625.30 2540.44 7673.96 0.00 0.00 7673.98 3K-102 TS 2812074.89 90.29 98.14 3625.57 2534.39 7716.39 3.00 2.84 7716.39 2T 3332.55 90.29 98.14 3819.30 2358.38 8981.37 0.00 0.00 8981.37 3K-102 T8 2813365.14 89.31 98.18 3619.42 2351.73 8993.63 3.00 177.43 6993.63 2914076.84 89.31 98.18 3628.00 2250.45 9698.04 0.00 0.00 9698.04 3K-102 T7 COr1000~1~~~~p5 H/dLLIBURT©N aP.'.y o.xts.,o wrwb.. FORMATION TOP DETAILS No. NDPath NDSS MDPath Formation 1 1559.30 1485 1736.04 T3 2 1629.30 1555 1843.41 Permafrost 3 1786.30 1712 2111.89 K15 4 2379.30 2305 3615.10 T3+800 5 2658.30 2584 4364.32 Ugnu C 6 2998.30 2924 5394.09 Ugnu B 7 3094.30 3020 5692.32 Ugnu A 8 3298.30 3224 6326.05 K13 9 3464.30 3390 7011.65 W Sak D 10 3516.30 3442 7311.10 W Sak C 11 3559.30 3485 7589.84 W Sak B CASING DETAILS No MD TVD TVDss Name Size 1 3100 2187 2113 13 3/8" 13-. 2 7615.51 3%2.43 3488.13 9 5/8" 9-5/8 3 14076.70 3628.00 3553.7 51/2" 5-1/2 SHL: 909.64 FSL, 314.99 FWL -SEC 35 - T13N - R09E - -0 ---- -------- 0° :..p 538 500 c 1077 o p00 9-518" ~ 3718.82 FSL, 3597.58 FWL -SEC 35 - T13N - R09E C~ T3 Permafrost ,' BHL ~ 14076.8' MD, 3628.0' ND, 3153.79 FSL, 4736.10 FWL -SEC 36 - T13N - R09E .e.. `-' , 7SO ~ ~`.L 1615 -~- - - - - - - - - - - - - - - - - - - - - - - o- - - - - - - - - - - - - - - - - T T - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ _ - - - - - - - i-- Q ~ ~'= - - - - - - K15 - - - - - - Sp ~0 ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - U - - - - - - - - - - - - - - - - ~ ` ' ~_ 2154 T3+800 0 ` ~ ` ~ ~ -o--p$- 13 318" - -o - -,-- -- `~ 3 2692 -UgnuC ------ ------ - ~ o ` b ,~ s \ ~ O - - - - - - - - - - - - _' - - - - - - - - - - ---- -'~------'---------------o---o---a---o-- o ---------ate- o --------- - - - - - o o ' 0 0 ° o 3231 --UgnuA ------ ---------- o 0 --0---`O---a--`p--~----------"o-~ ~--------- -------- ~--~o---~°-,~-a---ur--a°0---~- - - - K13 ________ __________-__ = - - - - - _ = == ___ __________ ______%- __ ____-- ____ ___ __ ___ _____ __ ________ 3769 ~ W Sak D _ _ 9 518"^„ o ~ ~ 3K-102 (wp06) ° ~ ~ 5 1/2" W Sak B W Sak C 4308 Begin Pump Tangent 80° INC ~ 6250' MD, 3273.82' ND 3K-102 T2 3K-102 T3 ', 3K-102 T4 3K-102 TS 3K-102 T6 3K-102 T7 4846 End PumpTangent ~ 6450' MD, 3380.2' ND i ~I -2154 -1615 -1C77 -536 -0 538 1077 1615 2154 2692 3231 3769 4308 4846 5385 5923 6462 7000 7538 8077 8615 9154 9692 10231 10769 Vertical Section at 90.00° (1400 ft/in) Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-102 Wellbore: 3K-102 Plan: 3K-102 (wp06) w' ConocoPhillps 8p~rry OrilBny 8ervlcar CASING DETAILS No MD 1'VD NDss Name 1 3615.10 2379.30 2305 13 3/8" 2 7615.51 3562.43 3488.13 9 5/8" 3 14076.70 3628.00 3553.7 51/2" 5029 4571 9-5/8" ~n 3718.82 FSL, 3597.58 FWL -SEC 35 - T13N - R09E~ 4l 14 End PunlpTangent @6450' M1m, 3380.2' tt 3657 ` t Begin Pump Tangent 80° BJC @ 6250' IvQ), 3273.82' r 3200 ~ ' ~ `~ __` c 2286 ~' 1829 13 3/s' s 0 1371 Z` 2000 914 \~50 O ~ 457 -914 ISHL 909.64 FSL, 314.99 FWL-SEC 35-T13N- -1371 -1829 SECTION DETAILS REFERENCE INFORMATION Sec MD Inc Azl ND +NJ-S +E/-W DLeg TFace VSec Teiget Cc-ordinate (N/E) Reference: Well Plan 3K-102, True Norlh 1 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 Vertical (ND) Reference: 74.3' RKB (34.3+40) ~ 74.300 (Doyonl5) 2 260.00 0.00 0.00 260.00 0.00 0.00 0.00 0.00 0.00 Measured Depth Reterence: 74.3' RKB (34.3+40) (~ 74.308 (Doyonl5) 3 380.00 3.00 310.00 379.85 2.02 -2.41 2.50 310.00 -2.41 Calculation Method: Minimum Curvature 4 703.47 12.70 310.00 700.00 30.39 -38.22 3.00 0.00 -36.22 55 40.00 320.00 1317.88 253.06 -240.57 5 1392 4.00 13.96 -240.57 . 6 2480.23 68.00 350.00 1954.17 1044.49 -563.89 3.36 51,08 -563.89 WELL DETAILS. Plan 3K-102 08 2202.48 -109.85 00 2516 7 3980 23 68 00 50 3.71 90,00 -109.65 . . . . 8 4753.17 71.22 82.87 2791.99 2575.14 543.84 4.00 90.06 543,84 Ground Level: 34.30 9 6507.47 71.22 82.87 3358.70 2781.39 2191.91 0.00 0.00 2187.91 +N/-$ +El-W Northing Easting La[ittude Longitude Slot 10 6775.37 80.00 89.22 3423.27 2798.98 2450.41 4.00 35.68 2450.41 69 52930.5 84 70°25'S7.616N 149°45'40W 00 0 00 6007903 0 11 6975.37 80.00 89.22 3458.00 2601.66 2847.35 0.00 0.00 2847.35 . . . . 12 7005.37 80.00 89.22 3463.21 2802.06 2876.89 0.00 0.00 2676.89 13 7435.37 80.00 89.22 3537.88 2807.83 3100.32 0.00 0.00 3100.32 14 7535.50 83.00 80.38 3552.68 2800.04 3199.34 3.00 3.00 3189.34 15 7585.50 83.00 89.38 3558.77 2609.58 3248.98 0.00 0.00 3248.98 ANNOTATIONS 7s 7615.50 83.00 89.38 3582.43 2909.90 3278.74 0.00 0.00 3276.74 17 7815.06 88.98 89.63 3578.37 2811.61 3477.71 3.00 2.45 3477.71 18 8803.19 88.98 89.83 3593.94 2817.92 4485.88 0.00 0.00 4485.88 ND MD AnnOtallOn t9 x942.24 9s.so 90.25 3594.30 2817.95 4494.71 3.00 44.97 4494.71 3K-102 T2 40.00 40.00 SHL: 909.64 FSL, 314.99 FWL -SEC 35 - T13N - 809E zo 9832.90 89.60 90.27 3594.30 2817.95 4495.37 3.o0 90 00 44x5.37 3273.82 6250.00 Begin Pump Tangent 80° INC @ 6250' MD, 3273.82' ND znoit5.ao 99.60 9o.z7 3603.30 2911.91 5777.92 0.00 o.go 5777.ez 3K-102 T3 3380 2' ND 00 End Pum Tan ent 6450' MD 3336 20 6450 @ 2210415.71 89.52 99.28 3605.82 2786.94 8078.77 3.00 90.53 8076.77 . , . . p 9 " 2311332.23 ss.52 98.28 3613.30 2638.17 8981.27 0.00 g.oa 6981,27 3K-toz Ta @ 3718.82 FSL, 3597.58 FWL -SEC 35 - T13N - 809E 3562.43 7615.50 9-5/8 zm 7375.x5 as.og 98.07 3613.as 2x32.57 7oz4.ae 3.00 - 713.29 7024.48 S 3628.0014076.70 BHL @ 14076.8' MD, 3628.0' ND, 3153.79 FSL, 4736.10 FWL -SEC 36 - T13N - RO Size 2512032.03 89.00 98.07 3625.30 2540.44 7873.98 89 90.29 98.14 3825.57 2534.39 7718.39 2812074 0.00 3.00 0.00 7673.96 3K-102 T 2.84 7718.39 13-3/8 . 2713332.55 90.29 98.14 3619.30 2356.36 8961.37 0.00 0.00 8961.37 3K-102 T6 9-5/8 2813365.14 89.31 98.18 3619.42 2351.73 8993.83 3.00 177.43 8993.63 5_1/2 2914078.84 89.31 98.18 3828.00 2250.45 9898.04 0.00 0.00 9698.04 3K-102 T7 3K-1027'2 3K-IU2'1'3 3K-102'1'4 ~L @ 14076.8' MD, 3628.0' 7VD, 3153.79 FSL, 4736.10 FWL -SEC 36 - TI3N - R09F~ 51/2" 3 I N r ~ M 3K-102 TS 3K-102 T6 3K-IU27~7 \~11 ~ -3200 -2743 -2286 -1829 -1371 -914 -457 0 457 914 1371 1829 2286 2743 3200 3657 4114 4571 5029 5486 5943 6400 6857 7314 7771 8229 8686 9143 9600 10057 10514 10971 11429 11886 West(-)/East(+) (1600 ft/in) Halliburton Company Compass Proposal Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: '` Well Plan 3K-102 Company: ConocoPhillips Alaska Inc. TVD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: Kuparuk River Unit MD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: Kuparuk 3K Pad North Reference: .True Well: Plan 3K-102 Survey Calculation Method: Minimum Curvature Wellbore: 3K-102 Design: 3K-102 (wp06) Project Kuparuk P.iver Unit, North Slope Alaska, U nited States Map System: Geo Datum: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) System Datum: Mean Sea Level Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Flan 3K-102 Well Position +N/-S 0.00 ft Northing: 6,007,903.69 ft Latitude: 70° 25' 57.616" N +E/-W 0.00 ft Easting: 529,305.84 ft ~ Longitude: 149° 45' 40.000" W Position Uncertai nty 0.00 ft Wellhead Elevation: ft Ground Level: 34.30ft Wellbore 3K-102 Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2007 10/10/2007 23.09 80.88 57,623 Design 3K-102 wp06j Audit Notes: Version: 33 Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From (TVD) +N!-S +E!-W Direction (ft) (ft) lft) (°) 40.00 0.00 0.00 90.00 11/9/2007 11:03:20AM Page 2 of 7 COMPASS 2003.11 Build 48 ~ k `rt i' t 5""'". Halliburton Company Compass Proposal Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 3K-102 Company: ConocoPhillips Alaska Inc. ND Reference: ~ 4.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: Kuparuk River Unit MD Reference: 4.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: Kuparuk 3K Pad North Reference: True WeII: Plan 3K-102 Survey Calculation Method: Minimum Curvature Wellbore: 3K-102 Design: 3K-102 (wp06) Plan Summary Measured bogleg Build Turn Depth Inclination Azimuth TVD TVDSS +N/-5 +E/_yy Rate Rate Rate TFO (ft) l~) (°) (ft) (ft) (ft) (ft) (°1100ft) (°/100ft) (°I100ft) (°) 40.00 0.00 0.00 40.00 -34.30 0.00 0.00 0.00 0.00 0.00 0.00 260.00 0.00 0.00 260.00 185.70 0.00 0.00 0.00 0.00 0.00 0.00 380.00 3.00 310.00 379.95 305.65 2.02 -2.41 2.50 2.50 0.00 310.00 703.47 12.70 310.00 700.00 625.70 30.39 -36.22 3.00 3.00 0.00 0.00 1,392.55 40.00 320.00 1,311.88 1,237.58 253.06 -240.57 4.00 3.96 1.45 13.96 2,480.23 68.00 350.00 1,954.17 1,879.87 1,044.49 -563.89 3.36 2.57 2.76 51.08 3,980.23 68.00 50.00 2,516.08 2,441.78 2,292.48 -109.65 3.71 0.00 4.00 90.00 4,753.17 71.22 82.87 2,791.99 2,717.69 2,575.14 543.84 4.00 0.42 4.25 90.06 6,507.47 71.22 82.87 3,356.70 3,282.40 2,781.39 2,191.91 0,00 0.00 0.00 0.00 6,775.37 80.00 89.22 3,423.27 3,348.97 2,798.98 2,450.41 4.00 3.28 2.37 35.88 6,975.37 80.00 89.22 3,458.00 3,383.70 2,801.66 2,647.35 0.00 0.00 0.00 0.00 7,005.37 80.00 89.22 3,463.21 3,388.91 2,802.06 2,676.89 0.00 0.00 0.00 0.00 7,435.37 80.00 89.22 3,537.88 3,463.58 2,807.83 3,100.32 0.00 0.00 0.00 0.00 7,535.50 83.00 89.38 3,552.68 3,478.38 2,809.04 3,199.34 3.00 3.00 0.16 3.00 7,585.50 83.00 89.38 3,558.77 3,484.47 2,809.58 3,248.96 0.00 0.00 0.00 0.00 7,615.50 83.00 89.38 3,562.43 3,488.13 2,809.90 3,278.74 0.00 0.00 0.00 0.00 7,815.06 88.98 89.63 3,576.37 3,502.07 2,811.61 3,477.71 3.00 3.00 0.13 2.45 8,803.19 88.98 89.63 3,593.94 3,519.64 2,817.92 4,465.66 0.00 0.00 0.00 0.00 8,832.24 89.60 90.25 3,594,30 3,520.00 2,817.95 4,494.71 3.00 2.12 2.12 44.97 8,832.90 89.60 90.27 3,594.30 3,520.00 2,817.95 4,495.37 3.00 0.00 3.00 90.00 10,115.40 89.60 90.27 3,603.30 3,529.00 2,811.91 5,777.82 0.00 0.00 0.00 0.00 10,415.71 89.52 99.28 3,605.62 3,531.32 2,786.94 6,076.77 3.00 -0.03 3.00 90.53 11,332.23 89.52 99.28 3,613.30 3,539.00 2,639.17 6,981.27 0.00 0.00 0.00 0.00 11,375.95 89.00 98.07 3,613.86 3,539.56 2,632.57 7,024.48 3.00 -1.19 -2.76 -113.29 12,032.03 89.00 98.07 3,625.30 3,551.00 2,540.44 7,673.96 0.00 0.00 0.00 0.00 12,074.89 90.29 98.14 3,625.57 3,551.27 2,534.39 7,716.39 3.00 3.00 0.15 2.84 13,332.55 90.29 98.14 3,619.30 3,545.00 2,356.36 8,961.37 0.00 0.00 0.00 0.00 13,365.14 89.31 98.18 3,619.42 3,545.12 2,351.73 8,993.63 3.00 -3.00 0.13 177.43 14,076.84 89.31 98.18 3,628.00 3,553.70 2,250.45 9,698.04 0.00 0.00 0.00 0.00 11/9/2007 11:03:20AM Page 3 of 7 COMPASS 2003.11 Build 48 ~~~1.~~9~t1 ~~ Halliburton Company Compass Proposal Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: ;Well Plan 3K-102 Company: ConocoPhillips Alaska Inc. TVD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project Kuparuk River Unit MD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyonl5) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-102 Survey Calculation Method: Minimum Curvature Wellbore: 3K-102 Design: 3K-102(wp06) Planned Survey 3K-102 (wp06) Map Map MD Incl Azimuth TVD (ft) TVDSS +N/S +EI-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ftl (ft) (ft) (ft) (ft) {°1100ft) [ft) 40.00 0.00 0.00 40.00 -34.30 0.00 0.00 6,007,903.69 529,305.84 0.00 0.00 ~ SHL: 909.64 F SL, 314 .99 FWL -S EC 35 - T13N - R09E 100.00 0.00 0.00 100.00 25.70 0.00 0.00 6,007,903.69 529,305.84 0.00 0.00 200.00 0.00 0.00 200.00 125.70 0.00 0.00 6,007,903.69 529,305.84 0.00 0.00 260.00 0.00 0.00 260.00 185.70 0.00 0.00 6,007,903.69 529,305.84 0.00 0.00 ~ 300.00 1.00 310.00 300.00 225.70 0.22 -0.27 6,007,903.91 529,305.57 2.50 -0.27 380.00 3.00 310.00 379.95 305.65 2.02 -2.41 6,007,905.70 529,303.43 2.50 -2.41 400.09 3.60 310.00 400.00 325.70 2.76 -3.29 6,007,906.44 529,302.54 2.99 -3.29 500.50 6.61 310.00 500.00 425.70 8.51 -10.14 6,007,912.16 529,295.67 3.00 -10.14 601.53 9.65 310.00 600.00 525.70 17.69 -21.08 6,007,921.30 529,284.69 3.00 -21.08 703.47 12.70 310.00 700.00 625.70 30.39 -36.22 6,007,933.93 529,269.51 3.00 -36.22 806.89 16.75 313.46 800.00 725.70 47.96 -55.75 6,007,951.42 529,249.91 4.00 -55.75 912.56 20.92 315.64 900.00 825.70 71.93 -80.00 6,007,975.30 529,225.56 4.00 -80.00 1,021.28 25.23 317.16 1,000.00 925.70 102.80 -109.34 6,008,006.05 529,196.11 4.00 -109.34 1,134.01 29.70 318.29 1,100.00 1025.70 141.29 -144.28 6,008,044.39 529,161.02 4.00 -144.28 1,252.03 34.40 319.18 1,200.00 1125.70 188.37 -185.55 6,008,091.31 529,119.57 4.00 -185.55 1,377.11 39.38 319.92 1,300.00 1225.70 245.51 -234.23 6,008,148.25 529,070.67 4.00 -234.23 1,392.55 40.00 320.00 1,311.88 1237.58 253.06 -240.57 6,008,155.77 529,064.30 4.00 -240.57 1,509.80 42.57 324.54 1,400.00 1325.70 314.25 -287.82 6,008,216.77 529,016.81 3.36 -287.82 1,649.26 45.83 329.37 1,500.00 1425.70 395.76 -340.71 6,008,298.07 528,963.61 3.36 -340.71 1,736.04 47.96 332.11 1,559.30 1485.00 451.03 -371.64 6,008,353.21 528,932.46 3.36 -371.64 T3 1,797.74 49.51 333.95 1,600.00 1525.70 492.36 -392.67 6,008,394.45 528,911.28 3.36 -392.67 1,843.41 50.67 335.25 1,629.30 1555.00 524.00 -407.69 6,008,426.03 528,896.13 3.36 -407.69 Permafrost 1,958.68 53.67 338.36 1,700.00 1625.70 607.68 X43.49 6,008,509.56 528,860.01 3.36 -443.49 2,111.89 57.77 342.14 1,786.30 1712.00 726.80 -486.15 6,008,628.50 528,816.89 3.36 -486.15 K15 2,137.83 58.47 342.74 1,800.00 1725.70 747.80 -492.80 6,008,649.47 528,810.16 3.36 -492.80 2,346.42 64.23 347.31 1,900.00 1825.70 924.55 -539.87 6,008,826.03 528,762.40 3.36 -539.87 2,480.23 68.00 350.00 1,954.17 1879.87 1,044.49 -563.89 6,008,945.85 528,737.91 3.36 -563.89 2,602.57 68.01 354.89 2,000.00 1925.70 1,156.89 -578.79 6,009,058.19 528,722.56 3.71 -578.79 2,869.51 68.01 5.57 2,100.00 2025.70 1,404.04 -577.79 6,009,305.31 528,722.59 3.71 -577.79 3,136.46. 68.00 16.25 2,200.00 2125.70 1,646.73 -531.01 6,009,548.16 528,768.41 3.71 -531.01 3,403.41 68.01 26.93 2,300.00 2225.70 1,876.54 -440.08 6,009,778.30 528,858.44 3.71 -440.08 3,615.10 68.01 35.39 2,379.30 2305.00 2,044.34 -338.61 6,009,946.49 528,959.24 3.71 -338.61 T3+800 - 3,670.35 68.01 37.60 2,400.00 2325.70 2,085.52 -308.14 6,009,987.78 528,989.54 3.71 -308.14 3,937.30 68.00 48.28 2,500.00 2425.70 2,266.44 -139.76 6,010,169.34 529,157.19 3.71 -139.76 3,980.23 68.00 50.00 2,516.08 2441.78 2,292.48 -109.65 6,010,195.50 529,187.19 3.71 -109.65 4,205.12 68.27 59.69 2,600.00 2525.70 2,412.46 60.74 6,010,316.13 529,357.10 4.00 60.74 4,364.32 68.81 66.51 2,658.30 2584.00 2,479.44 192.78 6,010,383.62 529,488.86 4.00 192.78 Ugnu C 4,481.10 69.37 71.47 2,700.00 2625.70 2,518.52 294.58 6,010,423.10 529,590.50 4.00 294.58 4,753.17 71.22 82.87 2,791.99 2717.69 2,575.14 543.84 6,010,480.69 529,839.51 4.00 543.84 11/9/2007 11:03:20AM Page 4 of 7 COMPASS 2003.11 Build 48 ~~+1' ~ M 4 ,? ti t Halliburton Company Compass Proposal Report -Geographic Database: -DM 2003.11 Single User Db Local Co-ordinate Reference: V':rell Plan 3K-102 Company: ConocoPhillips Alaska Inc. TVD Reference: 4.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: Kuparuk River Unit MD Reference: ~ 4.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-102 Survey Calculation Method: P.4inimum Curvature Wellbore: 3K-102 Design: 3K-102 (vrp06) Planned Survey 3K-102 (wp06) Map MD Incl Azimuth TVD (ft) TVDSS +N/-S +E/-W Northing (ft) (°) 1°1 (ft) (ft) (ft) Ift) 4,778.06 71.22 82.87 2,800.00 2725.70 2,578.07 567.22 6,010,483.71 5,088.71 71.22 82.87 2,900.00 2825.70 2,614.59 859.07 6,010,521.37 5,394.09 71.22 82.87 2,998.30 2924.00 2,650.49 1,145.95 6,010,558.40 Ugnu B 5,399.37 71.22 82.87 3,000.00 2925.70 2,651.11 1,150.91 6,010,559.04 5,692.32 71.22 82.87 3,094.30 3020.00 2,685.55 1,426.12 6,010,594.56 Ugnu A 5,710.02 71.22 82.87 3,100.00 3025.70 2,687.63 1,442.76 6,010,596.70 6,020.68 71.22 82.87 3,200.00 3125.70 2,724.16 1,734.60 6,010,634.37 6,250.00 71.22 82.87 3,273.82 3199.52 2,751.12 1,950.03 6,010,662.17 Begin Pump Tangent 80° INC @ 6250' MD, 3273.82' TVD 6,326.05 71.22 82.87 3,298.30 3224.00 2,760.06 2,021.48 6,010,671.39 K13 6,331.33 71.22 82.87 3,300.00 3225.70 2,760.68 2,026.44 6,010,672.03 6,450.00 71.22 82.87 3,338.20 3263.90 2,774.63 2,137.92 6,010,686.42 End PumpTangent ~ 6450' MD, 3380.2' TVD 6,507.47 71.22 82.87 3,356.70 3282.40 2,781.39 2,191.91 6,010,693.39 6,662.18 76.27 86.60 3,400.00 3325.70 2,794.96 2,339.74 6,010,707.54 6,775.37 80.00 89.22 3,423.27 3348.97 2,798.98 2,450.41 6,010,712.00 6,975.37 80.00 89.22 3,458.00 3383.70 2,801.66 2,647.35 6,010,715.45 7,005.37 80.00 89.22 3,463.21 3388.91 2,802.06 2,676.89 6,010,715.97 7,011.65 80.00 89.22 3,464.30 3390.00 2,802.15 2,683.08 6,010,716.08 W Sak D -Top of D-sand 7,217.24 80.00 89.22 3,500.00 3425.70 2,804.90 2,885.52 6,010,719.63 7,311.10 80.00 89.22 3,516.30 3442.00 2,806.16 2,977.96 6,010,721.25 W Sak C 7,435.37 80.00 89.22 3,537.88 3463.58 2,807.83 3,100.32 6,010,723.40 7,535.50 83.00 89.38 3,552.68 3478.38 2,809.04 3,199.34 6,010,725.00 7,585.50 83.00 89.38 3,558.77 3484.47 2,809.58 3,248.96 6,010,725:73 7,589.84 83.00 89.38 3,559.30 3485.00 2,809.62 3,253.27 6,010,725.79 W Sak B 7,615.50 83.00 89.38 3,562.43 3488.13 2,809.90 3,278.74 6,010,726.17 5-518" ~ 3718.82 FSL, 3597.58 FWL -SEC 35 - T13N - R09E - 9 518" 7,719.68 86.12 89.51 3,572.30 3498.00 2,810.90 3,382.43 6,010,727.58 3K-1 Q2 T1 7,815.06 88.98 89.63 3,576.37 3502.07 2,811.61 3,477.71 6,010,728.67 8,803.19 88.98 89.63 3,593.94 3519.64 2,817.92 4,465.66 6,010,738.86 8,832.24 89.60 90.25 3,594.30 3520.00 2,817.95 4,494.71 6,010,739.00 3K-102 T2 8,832.90 89.60 90.27 3,594.30 3520.00 2,817.95 4,495.37 6,010,739.00 9,644.91 89.60 90.27 3,600.00 3525.70 2,814.13 5,307.35 6,010,738.37 Map Fasting pLSEV Vert Section lft) ('/100ft) (ft) 529,862.88 0.00 567.22 530,154.55 0.00 859.07 530,441.26 0.00 1,145.95 530,446.21 0.00 1,150.91 530,721.26 0.00 1,426.12 530,737.88 0.00 1,442.76 531,029.55 0.00 1,734.60 531,244.86 0.00 1,950.03 531,316.26 0.00 2,021.48 531,321.22 0.00 2,026.44 531,432.64 0.00 2,137.92 531,486.59 0.00 2,191.91 531,634.35 4.00 2,339.74 531,744.99 4.00 2,450.41 531,941.90 0.00 2,647.35 531,971.44 0.00 2,676.89 531,977.62 0.00 2,683.08 532,180.04 0.00 2,885.52 532,272.45 0.00 2,977.96 532,394.80 0.00 3,100.32 532,493.80 3.00 3,199.34 532,543.42 0.00 3,248.96 532,547.73 0.00 3,253.27 532,573.19 0.00 3,278.74 532,676.86 3.00 3,382.43 532,772.13 3.00 3,477.71 533,759.95 0.00 4,465.66 533,789.00 3.00 4,494.71 533,789.66 3.00 4,495.37 534,601.57 0.00 5,307.35 11/92007 11:03:20AM Page 5 of 7 COMPASS 2003.11 Build 48 ~ ~~ ~~~ Halliburton Company Compass Proposal Report -Geographic Database: EDM 2003.11 Single User Db ~ Local Co-ordinate Reference: Well Plan 3K-102 Company: ConocoPhillips Alaska Inc. TVD Refere nce: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: Kuparuk River Unit MD Reference: 74,3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-102 Survey Calculation Method: PAinimum Curvature Wellbore: 3K-102 Design: 3K-102 (vrp06) Planned Survey 3K-102 (wp06) Map Map MD Ift) Incl Azimuth TVD (ft) (°) (°) TVDSS (ft) +N/-S 1ft) +E!-W (ft) Northing 1ft) Easting DLSEV (ft) (°/100ft) Vert Section (ft) 10,115.40 89.60 90.27 3,603.30 3529.00 2,811.91 5,777.82 6,010,738.00 535,072.00 0.00 5,777.82 3K-102 T3 10,415.71 89.52 99.28 3,605.62 3531.32 2,786.94 6,076.77 6,010,714.21 535,371.02 3.00 6,076.77 11,332.23 89.52 99.28 3,613.30 3539.00 2,639.17 6,981.27 6,010,570.00 536,276.00 0.00 6,981.27 3K-102 T4 11,375.95 89.00 98.07 3,613.86 3539.56 2,632.57 7,024.48 6,010,563.58 536,319.23 3.00 7,024.48 12,032.03 89.00 98.07 3,625.30 3551.00 2,540.44 7,673.96 6,010,474.00 536,969.00 0.00 7,673.96 3K-102 T5 12,074.89 90.29 98.14 3,625.57 3551.27 2,534.39 7,716.39 6,010,468.12 537,011.45 3.00 7,716.39 13,332.55 90.29 98.14 3,619.30 3545.00 2,356.36 8,961.37 6,010,295.00 538,257.00 0.00 8,961.37 3K-102 T6 13,365.14 89.31 98.18 3,619.42 3545.12 2,351.73 8,993.63 6,010,290.50 538,289.27 3.00 8,993.63 14,076.84 89.31 98.18 3,628.00 3553.70 2,250.45 9,698.04 6,010,192.00 538,994.00 0.00 9,698.04 BHL @ 14076.8' MD, 3628.0' TVD, 3153.79 FSL, 4736.10 FWL -SEC 36 - T13N - R09E - 5 112" - 3K-102 T7 Geologic Targets ~K-102 TVD TVDSS Target Name +N/-S +E/-W Northing Easting (ft) (ft) -Sh ape ft ft (ft) (ft) 3,603.30. 3K-102 T3 2,811.91 5,777.82 6,010,738.00 535,072.00 - Point 3,613.30 3K-102 T4 2,639.17 6,981.27 6,010,570.00 536,276.00 - Point 3,625.30 3K-102 T5 2,540.44 7,673.96 6,010,474.00 536,969.00 - Point 3,594.30 3K-102 T2 2,817.95 4,494.71 6,010,739.00 533,789.00 - Point 3,628.00 3K-102 T7 2,250.45 9,698.04 6,010,192.00 538,994.00 - Point 3,619.30 3K-102 T6 2,356.36 8,961.37 6,010,295.00 538,257.00 - Point 3,464.30 Top of D-sand 2,801.06 2,684.45 6,010,715.00 531,979.00 - Point 3,572.30 3K-102 T1 2,801.66 3,295.52 6,010,718.00 532,590.00 - Point 11/9/2007 11:03:20AM Page 6 of 7 COMPASS 2003.11 Build 48 `~ ~ ~`~ ~~ ~ ~ ~ ~~ Halliburton Company Compass Proposal Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: \^:'ell Plan 3K-102 Company: ConocoPhillips Alaska Inc . ND Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyonl5) Project: Kuparuk River Unit MD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-102 Survey Calculation Method: P,4inimum Curvature Wellbore: 3K-102 Design: 3K-102 (wp06) Prognosed C asing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) lft) (") (") 3,100.0 2,187.30 13-318 17-112 7,615.51 3,562.43 9-518 12-1 /4 14,076.80 3,628.00 5-112 8-1l2 Prognosed F ormation Intersection Points Measure Depth (ft) d Inclination Azimuth (°) (°) ND (ft) NDSS +N/-E (ft) +EI-W (ft) (ft1 Name 1,736.04 47.96 332.11 1,559.30 451.03 -371.64 T3 1,843.41 50.67 335.25 1,629.30 524.00 -407.69 Permafrost 2,111.89 57.77 342.14 1,786.30 726.80 -486.15 K15 3,615.10 68.01 35.39 2,379.30 2,044.34 -338.61 T3+800 4,364.32 68.81 66.51 2,658.30 2,479.44 192.78 Ugnu C 5,394.09 71.22 82.87 2,998.30 2,650.49 1,145.95 Ugnu B 5,692.32 71.22 82.87 3,094.30 2,685.55 1,426.12 Ugnu A 6,326.05 71.22 82.87 3,298.30 2,760.06 2,021.48 K13 7,011.65 80.00 89.22 3,464.30 2,802.15 2,683.08 W Sak D 7,31 L 10 80.00 89.22 3,516.30 2,806.16 2,977.96 W Sak C 7,589.84 83.00 89.38 3,559.30 2,809.62 3,253.27 W Sak B Plan Annotat ions ~ Measured Vertical Local Coordinates Depth Depth +N/-5 +E/-W Comment (ftl (ft) lft) (ft) 40.00 40.00 0.00 0.00 SHL: 909.64 FSL, 314.99 FWL -SEC 35 - T13N - R09E 6,250.00 3,273.82 2,751.12 1,950.03 Begin Pump Tangent 80° INC @ 6250' MD, 3273.82' TVD 6,450.00 3,338.20 2,774.63 2,137.92 End PumpTangent @ 6450' MD, 3380.2' TVD 7,615.50 3,562.43 2,809.90 3,278.73 9-5/8" @ 3718.82 FSL, 3597.58 FWL -SEC 35 - T13N - R09E 14,076.84 3,628.00 2,250.45 9,698.03 BHL @ 14076.8' MD, 3628.0' ND, 3153.79 FSL, 4736.10 FWL -SEC 36 - T1 11/9/2007 11:03:20AM Page 7 of T COMPASS 2003.11 Build 48 ~~~~~ <.. Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 11/7/2007 - Time: 09:00:04 -- -~ Page: 2 Field: Kuparuk River Unit Reference Site: Kuparuk 3K Pad Co-ordinate(1E) Refer ence: Well: Pla n 3K-102, True North Reference Nell: Plan 3K-102 Vertical (TVD) Reference: 74.3' RKB (34.3+40) 74.3 ~ Reference N'ellpath: 3K-102 I Db: Oracle Summary <______________________ Offset ~~'ellpath -------- -------------> Reference Offset Ctr-Ctr No-Go .Allowable _ Site Nell H'ellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 3K Pad Plan 3K-D8 3K-D8 V1 Plan: 3K-D8 w 3173.52 2650.00 165.61 49.85 115.76 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E12 3K-E12 L1 VO Plan: 3K- 892.72 775.00 561.86 18.33 543.53 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E12 3K-E12 V1 Plan: 3K-E12 892.72 775.00 561.86 18.80 543.05 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E14 3K-E14 L1 V2 Plan: 3K- 324.54 325.00 25.10 6.59 18.51 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E14 3K-E14 V4 Plan: 3K-E14 324.54 325.00 25.10 7.07 18.04 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E15 3K-E15 L1 V1 Plan: 3K- 323.67 325.00 75.26 6.65 68.61 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E15 3K-E15 V2 Plan: 3K-E15 323.67 325.00 75.26 6.96 68.30 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E16 3K-E16 L1 VO Plan: 3K- 324.09 325.00 50.18 6.69 43.49 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E16 3K-E16 V1 Plan: 3K-E16 324.09 325.00 50.18 7.00 43.18 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E6 3K-E6 V1 Plan: 3K-E6 ( 1820.74 1650.00 170.13 30.77 139.36 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E7 3K-E7 V1 Plan: 3K-E7 ( 1568.04 1500.00 127.10 28.38 98.72 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E8 3K-E8 V1 Plan: 3K-E8 w 2836.70 2425.00 136.52 48.70 87.82 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E9 3K-E9 V1 Plan: 3K-E9 ( 524.88 525.00 14.63 9.78 4.85 Pass: Major Risk ;~ t •_ _~ t ! ., ~ 6 t aa:. 3 rte. e, v N a U Y ya o~ CG F U~ E Q M M y~ > i 6i ~ ~ y o0 ~ 3 3 ~ eo ~ .... 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'."y~` O M i;. ~+ L CL L. ~, - G ,;~ ~ 1 O Ct~ r = \ v ,^ ,:"~, ~~"t . !~- g ~ sR ~e~gd 4 a^o z ~ ASR; O U~o~E U ~°r oini ~~~rs° --~~ wom` ?~Zg- 5~yr3 ~' ~ _~ " ~ ~11~ I/ y _- ~ ,~'c O O 0 N O O _~ N O~ W x W M O f•1y ~ x 1 r ... .~. M ~~ oo ~ N N N II I 0 0 0 0 0 O 0 0 0 0 0 O 0 0 0 0 t~ o0 0~ o .-...1-..-..-. ~ N ~1 N ~ p a v U 0 c m 00 N0 I I Q / / L ! E v c _ T N m 5 H ~ Z5 ~ G~ vi = V ~ < 4 ~v'b ~ `a a 3'v a „ ., a ^~~-° y S~ ~=-LLs ..~ °$ o ~ E~~~E u c~r~,. ~' ~~v,$ U Hain nnui i~ rnrnuu :nuunniri .u ii w1 l ~ ! V l 1 ~! h L Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 11/7/2007 Time: 09:00:04 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 3K Pad Co-ordinate(NE) Refer ence: Well: Pla n 3K-102, Tr ue North Reference «'ell: Plan 3K-102 Vertical (T VD) Refere nce: 74.3' RK B (34.3+40) 74.3 Reference Wellpath: 3K-102 Db: Oraole GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD I nterval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 40.00 to 14076.84 ft Scan Method: Trav Cylinder North Maximum Radius: 1 603.68 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/10/2007 Validated: N o Version: 4 Planned From To Survey Toolcode Tool Name ft ft 40.00 1000.00 Planned: 3K-102 (wp06) V33 CB-GYRO-SS Camera based gyro single shot 1000.00 14076.84 Planned: 3K-102 (wp06) V33 MWD+IFR-AK-CAZ-SC MWD+ IFR AK CAZ SCC Casing Points ~1D 1'~'D Diameter Hole Size Name - - ft ft in in - - - 3614.71 2379.30 13.375 17.500 13 3/8" --- - 7615.51 3562.62 9.625 12.250 9 5/8" 14076.84 3628.19 5.500 8.500 51/2" Summary <--------------------- O ffset Wellpath ------ ---------------> Reference Offset Ctr-Ctr So-Go Allowable Site ~'1'ell ~'1'ellpath MD vID Distance Area Deviation Warning ft ft ft ft ft Kuparuk 3K Pad 3K-01 3K-01 V1 3583.59 3025.00 285.96 77.94 208.02 Pass: Major Risk Kuparuk 3K Pad 3K-02 3K-02 V1 2608.99 2325.00 96.77 59.89 36.88 Pass: Major Risk Kuparuk 3K Pad 3K-04 3K-04 V1 2167.19 2025.00 159.63 51.99 107.64 Pass: Major Risk Kuparuk 3K Pad 3K-05 3K-05 V1 1346.36 1275.00 290.96 25.27 265.70 Pass: Major Risk Kuparuk 3K Pad 3K-06 3K-06 V1 1316.71 1250.00 288.00 22.31 265.69 Pass: Major Risk Kuparuk 3K Pad 3K-07 3K-07 V1 1279.99 1225.00 269.01 23.76 245.25 Pass: Major Risk Kuparuk 3K Pad 3K-08 3K-08 V1 1276.72 1225.00 250.11 23.71 226.40 Pass: Major Risk Kuparuk 3K Pad 3K-09 3K-09 V4 1222.41 1175.00 231.24 22.56 208.68 Pass: Major Risk Kuparuk 3K Pad 3K-09 3K-09A V1 1244.70 1200.00 232.64 24.59 208.05 Pass: Major Risk Kuparuk 3K Pad 3K-10 3K-10 V1 1101.33 1075.00 170.92 20.38 150.53 Pass: Major Risk Kuparuk 3K Pad 3K-11 3K-11 V1 1075.60 1050.00 165.02 19.02 146.00 Pass: Major Risk Kuparuk 3K Pad 3K-12 3K-12 V1 1017.87 1000.00 149.49 18.17 131.31 Pass: Major Risk Kuparuk 3K Pad 3K-13 3K-13 V1 964.29 950.00 124.68 18.82 105.86 Pass: Major Risk Kuparuk 3K Pad 3K-14 3K-14 V1 938.01 925.00 106.04 19.81 86.23 Pass: Major Risk Kuparuk 3K Pad 3K-15 3K-15 V1 874.74 875.00 70.77 16.72 54.04 Pass: Major Risk Kuparuk 3K Pad 3K-16 3K-16 V1 776.82 775.00 64.92 14.41 50.51 Pass: Major Risk Kuparuk 3K Pad 3K-17 3K-17 V1 774.46 775.00 27.72 15.30 12.42 Pass: Major Risk Kuparuk 3K Pad 3K-18 3K-18 V1 549.73 550.00 33.06 10.58 22.48 Pass: Major Risk Kuparuk 3K Pad 3K-19 3K-19 V6 6566.89 5175.00 223.18 92.99 130.19 Pass; Major Risk Kuparuk 3K Pad 3K-20 3K-20 V14 9094.54 6800.00 297.58 174.90 122.69 Pass: Major Risk Kuparuk 3K Pad 3K-22 3K-22 V3 677.92 625.00 453.79 12.43 441.35 Pass: Major Risk Kuparuk 3K Pad 3K-22 3K-22A V1 677.92 625.00 453.79 12.43 441.35 Pass: Major Risk Kuparuk 3K Pad 3K-23 3K-23 V2 1133.80 1050.00 387.70 21.22 366.48 Pass: Major Risk Kuparuk 3K Pad 3K-24 3K-24 V12 6099.10 4625.00 175.50 129.33 46.17 Pass: Major Risk Kuparuk 3K Pad 3K-25 3K-25 V1 1646.50 1525.00 184.89 33.05 151.84 Pass: Major Risk Kuparuk 3K Pad 3K-26 3K-26 V1 1107.29 1050.00 292.41 20.89 271.52 Pass: Major Risk Kuparuk 3K Pad 3K-27 3K-27 V2 834.86 800.00 317.07 16.00 301.06 Pass: Major Risk Kuparuk 3K Pad 3K-30 3K-30 V1 717.93 700.00 226.24 13.69 212.55 Pass: Major Risk Kuparuk 3K Pad 3K-31 3K-31 V4 995.07 975.00 148.97 18.96 130.01 Pass: Major Risk Kuparuk 3K Pad 3K-32 3K-32 V1 840.27 825.00 158.08 15.84 142.24 Pass: Major Risk Kuparuk 3K Pad 3K-34 3K-34 V2 625.23 625.00 121.84 12.24 109.59 Pass: Major Risk Kuparuk 3K Pad 3K-35 3K-35 V2 723.05 725.00 94.00 13.40 80.59 Pass: Major Risk Kuparuk 3K Pad Plan 3K-102 3K-102 L1 V3 Plan: 3K- 6975.00 6975.00 0.00 122.52 -122.52 FAIL: Major Risk Kuparuk 3K Pad Plan 3K-D10 3K-D10 Pilot Hole V1 P 4904.94 3700.00 263.97 78.27 185.70 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D10 3K-D10 V1 Plan: 3K-D10 4943.70 3775.00 149.94 84.14 65.81 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D11 3K-D11 V2 Plan: 3K-D11 5905.13 4525.00 347.15 86.29 260.85 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D12 Plan 3K-D12 V1 Plan: 3 7381.29 5450.00 318.65 110.38 208.26 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D13 3K-D13 V2 Plan: 3K-D13 449.12 425.00 675.63 9.09 666.55 Pass: Mpjor Risk Kuparuk 3K Pad Plan 3K-D14 3K-D14 V1 Plan: 3K-D14 589.35 550.00 650.47 11.85 638.63 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D15 3K-D15 V1 Plan: 3K-D15 388.72 375.00 628.52 7.75 620.77 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D16 3K-D16 V1 Plan: 3K-D16 635.20 600.00 603.85 12.46 591.40 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D17 3K-D17 V1 Plan: 3K-D17 12950.48 10125.00 468.40 236.40 232.01 Pass: Major Risk . ft ~~~ ~ t =~ . ~... Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 11 /27/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,850' MD (1,633' TVD) < Top of Tail at 2,300' MD < 13 3/8", 72.0# casing in 16" OH TD at 3,100' MD (2,187 ND) Mark of Schlumberger CemCADE Preliminary Job Design 13 3/8" Surface reliminary Job Design based on limited input data. For estimate purposes only. Schlumberger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,300' MD. Lead Slurry Minimum pump time: 290 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1850' - 80') x 3.50 (250% excess) = 2605.6 ft3 0.4206 ft3/ft x (2300' - 1850') x 1.35 (35% excess) = 255.5 ft3 81.5 ft3 + 2605.6 ft3+ 255.5 ft3 = 2942.6 ft3 2942.6 ft3 / 4.45 ft3/sk = ~ 661.3 sks Round up to 670 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 220 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x (3100' - 2300') x 1.35 (35% excess) = 454.2 ft3 0.8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 454.2 ft3 + 66.5 ft3 = 520.7 ft3 520.7 ft3/ 2.47 ft3/sk = / 210.8 sks Round up to 220 sks BHST = 42`F, Estimated BHCT = 70`i=. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbll (min) (min) CW 100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 6 50 8.3 33.3 Lead Slurry 7 531 75.9 109.2 Tail Slurry 6 97 16.2 125.4 Drop Top Plug 8.0 133.4 Water 5 20 4.0 137.4 Switch to Rig Pumps 5.0 142.4 Displacement 7 407 58.1 200.5 Slow Rate 3 20 6.7 207.2 MUD REMOVAL Recommended Mud Properties: 8.8 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 17-21, TY = 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. OR161NAL Schlumberger CemCAD E* well cementing recommendation for Surface Operator : CPAi Well 3K-102 Country :USA Field Kuparuk State :Alaska Prepared for : CPAi Location Proposal No. : V1 (wp06) Service Point Date Prepared : 11-19-2007 Business Phone FAX No. Prepared by Maureen Torrie Phone 1-907-265-6336 E-Mail Atltlress mtorrie@slb.com 5~~ O~ a Cy C ~9 ~~aTE Prudhoe Bay (907659-2434 f907i659-2538 Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger Client CPAi Well 3K-102 String Surface District Prudhoe Bay Country USA Loadcase Surface Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :3100.0 ft BHST : 42 degF Bit Size : 16 in ft o, .'.'. Permafrost Well Lithology Previous String MD OD Weight ID ft in Ib/ft in 80.0 20 94.0 19.124 Landing Collar MD :3020.0 ft Casing/liner Shoe MD :3100.0 ft Formation Press. SG~la~derg~r Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread ft in ft Ib/ft in si si 3100.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Page 2 3k-102,V2.cfw;11-27-2007; Loadcase Surface~Veip6rsiojnJn~wjcs-cem452_01 1 Y 7 1 (x 1000) psi ~ ~ Client CPAi Well 3K-102 String Surface District Prudhoe Bay Country USA Loadcase Surface Mean OH Diameter :16.000 in Mean Annular Excess :136.1 Mean OH Equivalent Diameter :18.998 in Total OH Volume :1058.9 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. ft in % in 1500.0 16.000 250.0 21.184 3100.0 16.000 35.0 16.822 Max. Deviation Angle : 68 deg Max. DLS :4.007 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 40.0 40.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 260.0 260.0 0.0 0.0 0.000 300.0 300.0 1.0 310.0 2.500 380.0 379.9 3.0 310.0 2.500 400.0 399.9 3.6 310.0 3.000 500.0 499.5 6.6 310.0 3.000 600.0 598.5 9.6 310.0 3.000 703.5 700.0 12.7 310.0 2.996 800.0 793.4 16.5 313.3 4.007 900.0 888.2 20.4 315.4 3.998 1000.0 980.7 24.4 316.9 3.999 1100.0 1070.3 28.4 318.0 3.999 1200.0 1156.5 32.3 318.8 4.002 1300.0 1239.1 36.3 319.5 3.998 1392.6 1311.9 40.0 320.0 4.002 1400.0 1317.6 40.2 320.3 3.371 1500.0 1392.7 42.3 324.2 3.362 1600.0 1465.3 44.7 327.7 3.367 1700.0 1534.9 47.1 331.0 3.358 1800.0 1601.4 49.6 334.0 3.359 1900.0 1664.5 52.1 336.8 3.364 2000.0 1724.1 54.8 339.4 3.363 2100.0 1779.9 57.4 341.9 3.367 2200.0 1831.6 60.2 344.2 3.357 2300.0 1879.3 62.9 346.3 3.363 2400.0 1922.6 65.7 348.4 3.365 2480.2 1954.1 68.0 350.0 3.361 2500.0 1961.5 68.0 350.8 3.707 2600.0 1998.9 68.0 354.8 3.709 2700.0 2036.4 68.0 358.8 3.709 2800.0 2073.9 68.0 2.8 3.709 2900.0 2111.3 68.0 6.8 3.709 3000.0 2148.8 68.0 10.8 3.709 3100.0 2186.3 68.0 14.8 3.708 ~~I r~r 3k-102,V2.cfw;11-27-2007; LoadCaseSurface;Versionwcs-cem452_07 Page 3 G`~ M ~ i i / Client CPAi Well 3K-102 String Surface District Prudhoe Bay Country USA Loadcase Surface Formation Data MD Frac. Pore Name Lithology ft Ib/ al Ib/ al 1850.0 12.00 8.00 Permafrost Sandstone 3100.0 12.00 8.00 Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1850.0 1633.4 29 0.3 3100.0 2186-3 42 0.8 ft o- 0 0 o' N O O O ~• 1 degF Temperature ~~hlumd~rg~r Page 4 3k-102,V2.cfw;11-27-2007; LoadCaseSurface;Versionwcs-cem452_07 -; ~ ~1 SAL • Client CPAi S~I~~~~r~~r Well 3K-102 String Surface District Prudhoe Bay Country USA Loadcase Surface Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :3080.0 ft Casing Shoe :3100.0 ft NB of Cent. Used :43 NB of Floating Cent. :43 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint % ft 2020.0 16 1/3 1502213-13 3/8-8-POSITIVE W044 0.0 1975.6 3100.0 27 1/1 1502213-13 3/8-8-POSITIVE W044 56.4 3100.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ibf Ibf 1502213-13 3/8-8- W044 13 3/8 15.626 15.626 Yes Houma N.A. N.A. N.A. POSITIVE (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications % deg (x 1000) ft ft 0 25 50 75 100 0 40 80 0 0.5 1.0 1.5 2.0 0 Between Cent. '.. '. -Deviation ~ hbri. Depart. + +At Cent. ', ', ' ... '.. ', ', ', ~ ' ', '. '. N O _ t- 1- i I ~ . I ~ } o 00 o ~ c~ ~ ' O O ~ u7 N 1 ~ I - - r ..__. ......_-.._- __ _.... ...... .. O ~ 1 . _- .~.. . i ~ ' u7 ~- i-~ ii ~ _ j ~ 1. _:! 1 ~ !, ,, =1 ~ .I ~ ' ' . O ~ o V ~: I '' ~ ', N N Pipe Standoff Deviation Hori. Departure 3k-1D2, V2.cfw; 11-27-2007; Loadcase Surface ; Version wcs-cem452_07 O~~GINAL Page 5 Client CPAi S ~I r~r Well 3K-102 ~ String Surface District Prudhoe Bay Country USA Loadcase Surface Section 3: fluid description Fluid No: 1 Rheo. Model :BINGHAM At temp. : 80 degF MUD Mud Type : WBM Water Type :Fresh VOLUME FRACTION Solids : 6.0 Oil : 0.0 Water :94.0 Mud DESIGN Density P~ Tv Gel Strength Job volume MUDPUSH II DESIGN Fluid No: 2 Density : 10.50 Ib/gal Rheo. Model :BINGHAM P~ :25.000 cP At temp. : 80 degF Ty :15.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :50.0 bbl CW100 DESIGN Fluid No: 3 Density : 8.40 Ib/gal Rheo. Model :NEWTONIAN At temp. : (degF) Viscosity :3.000 cP Gel Strength : (Ibf/100ft2) Job volume :50.0 bbl Surface Lead DESIGN Fluid No: 4 Density : 10.70 Ib/gal Rheo. Model : HERSCHEL_B. k : 5.53E-4 Ibf.s^n/ft2 At temp. : 65 degF n :0.978 Ty :33.101bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type :Fresh water SLURRY Mix Fluid :21.765 gal/sk Yield :4.56 ft3/sk Porosity :63.8 Density :8.321b/gal 9.50 Ib/gal 15.000 cP :30.00 Ibf/100ft2 (Ibf/100ft2) :432.2 bbl Job volume :467.7 bbl Quantity :575.82 sk Solid Fraction :36.2 Base Fluid :21.167 gal/sk 3k-102, V2.ciw; 11-27-2007 ; Loadcase Surface ; Version wcs-cem452_07 "~~~~1 Page 6 Client CPAi Well 3K-102 ~I~r~r String Surface District Prudhoe Bay Country USA Loadcase Surface 12 ppg DeepCRETE DESIGN Fluid No: 5 Density : 12.00 Ib/gal Rheo. Model : HERSCHEL_B. k : 7.84E-3 Ibf.s^n/ft2 At temp. : 64 degF n :0.781 Ty :13.121bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid :10.671 gal/sk Job volume :92.9 bbl Dry Density : 199.77 Ib/ft3 Yield :2.59 ft3/sk Quantity :201.39 sk Sack Weight : 94 Ib Porosity :55.1 % Solid Fraction :44.9 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Base Fluid :10.621 gal/sk 3k-102,V2.cTw;11-27-2007; LoadcaseSurface;Versionwcs-cem452_07 ,. ~~ a ~ ., s ~ ~~ Page 7 Client CPAi ~~~I ~~~~ Well 3K-102 String Surface District Prudhoe Bay Country USA Loadcase Surface Section 4: fluid sequence Job Objectives• Bring cement to surtace. Original fluid Mud 9.50 Ib/gal P~ :15.000 cP Tv :30.00 Ibf/100ft2 Displacement Volume 452.2 bbl Total Volume 1112.8 bbl TOC 0.0 ft Name Volume bbl Ann. Len ft Top ft Fluid Sequence Density Ib/ al Rheology CW100 50.0 0.0 8.40 viscosity:3.000 cP MUDPUSH II 50.0 0.0 10.50 P~:25.000 cP Tv:15.00 Ibf/100ft2 Surface Lead 467.7 2300.0 0.0 10.70 k:5.53E-4 Ibf.s^n/ft2 n:0.978 Tv:33.10 Ibf/100ft2 12 ppg DeepCRETE 92.9 800.0 2300.0 12.00 k:7.84E-3 Ibf.s^n/ft2 n:0.781 Tv:13.12 Ibf/100ft2 Water 20.0 2886.4 8.32 viscosity:3.000 cP Mud 432.2 0.0 9.50 P~:15.000 cP Tv:30.00 Ibf/100ft2 Static Securi Checks Frac 5 psi at 80.0 ft Pore 11 psi at 80.0 ft Collapse 2038 psi at 3020.0 ft Burst 5020 psi at 0.0 ft Cs .Pump out 53 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Comments Temp. de F CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 CW100 5.0 40.0 8.0 50.0 80 MUDPUSH II 6.0 50.0 8.3 50.0 80 Pause 0.0 0.0 5.0 0.0 80 Surface Lead 7.0 467.7 66.8 467.7 80 12 ppg 6.0 92.9 15.5 92.9 80 DeepCRETE Pause 0.0 0.0 5.0 0.0 80 Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Mud 7.0 422.2 60.3 422.2 80 Mud 3.0 10.0 3.3 432.2 80 Total 03:13 hr:mn 1112.8 bbl Dynamic Security Checks Frac 4 psi at 80.0 ft Pore 2 psi at 80.0 ft Collapse 2038 psi at 3020.0 ft Burst 4763 psi at 0.0 ft Temperature Results API BHCT 61 degF I Simulated Max HCT 69 degF Simulated BHCT 69 degF Max HCT Depth 3100.0 ft CT at TOC 57 degF Max HCT Time 03:13:16 hr:mnsc Page 8 3k-102,V2.ciw;11-27-2007; LoadCaseSurface;Versionwcs-cem452_07 '1.., ~ •~ C s ~t ~ ~ V Y Client CPAi Sc hlu ~6 ~r ~r Well 3K-102 g String Surface District Prudhoe Bay Country USA Loadcase Surface ft 0 0 0 0 N f6 ~ o N O N ~ a` c Q Ib/gal 7.5 10.0 12.5 - Hydrostatic 0 M ~ Calc. FUmp Aess. twin. Hydrostatic - Calc. VVHP ' Max. Gynarric ',. twin. Dynanic ~ -~ o '. - Frac .N N Pore a 0_ 2 0 ~ 0 0.3 0.6 0.9 1.2 Pumped Volume (bbl) (x 1000) 0 D rn -~ Aonul~ Velocdy ~ ue m = sl uu n Frac Pore ~ Hydrostatic '.. Dynanic ~....- I I n nd no n~ nd n~ nR n7 (1R (19 1.0 1-1 1.2 Pumped Volume (bbl) (x 1000) Page 9 3k-1D2,V2cfw;11-27-2001; LoadCaseSurface;Versionwcs-cem452_01 ~:~~lGINAL i i CemCADE Preliminary Job Design 9.625" Intermediate Casin Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 11!27/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. < 13 3/8", 72.0# casing at 3,100' MD < Top of Tail at 4,100' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 7,800' MD (3,576' TVD) Schlumberger Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C formation - (Ugnu C at 4600' MD, TOC at 4100' MD, 3700' MD annular length). Tail Slurry Minimum thickening time: min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 3700' x 1.25 (25% excess) = 1448.6 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1448.6 ft3 + 34.1 ft3 = 1482.7 ft3 1482.7 ft3/ 2.25 ft3/sk = 659.0 sks Round up to 660 sks BHST = 73`F, Estimated BHCT = 60`F. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbp (min) (min) CW 100 5 50 10.0 10.0 Drop Bottom Plug 10.0 20.0 MudPUSH II 5 50 10.0 30.0 Tail Slurry 5 264 52.8 82.8 Drop Top Plug 10.0 92.8 Water 5 20 4.0 96.8 Switch to Rig Pum s 5.0 101.8 Displacement 7 530 75.7 177.5 Slow Rate 3 35 11.7 189.2 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH* II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 1 perjoint across zones of interest for proper cement placement. Schlumberger CemCAD E*well cementing recommendation for Intermediate Operator : CPAi Well 3K-102 Country :USA Field Kuparuk State :Alaska Prepared for : CPAi Location Proposal No. : V2 (wp06) Service Point Prudhoe Bay Date Prepared : 11-27-2007 Business Phone (907-659-2434 FAX No. (907) 659-2538 Prepared by :Maureen Torrie Phone 1-907-265-6336 E-Mail Atltlress mtorrieC~slb.com ~`~ ~ C'y C ~G ql U RT E Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model; the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Mark of Schlumberger JRIGINAL Client CPAi Well 3K-102 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate~a) Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :7800.0 ft BHST : 73 degF ft 0 0 D ... Permafrost Ugnu C •:.• Ugnu B ••• K13 •• WSakC • ••• W Sak B o~ Well Lithology Previous String MD OD Weight ID ft in Ib/ft in 3100.0 13 3/8 68.0 12.415 Landing Collar MD :7720.0 ft Casing/liner Shoe MD :7800.0 ft Formation Press. ~chlumderger Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread ft in ft Ib/ft in si si 7800.0 9 5/8 40.0 40.0 8.835 L-80 3090 5320 BTCS Page 2 3k-102,V2.ciw;t1-27-2007; LoadCaselntermediatelal;Versionwcs-cem452_07 ORIGINAIr. (x 1000) psi 0, 2 Client CPAi Well 3K-102 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediatelal Mean OH Diameter :12.250 in Mean Annular Excess :25.0 Mean OH Equivalent Diameter :12.823 in Total OH Volume :670.8 bbl (including excess) Max. Deviation Angle : 83 deg Max. DLS :4.007 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 40.0 40.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 260.0 260.0 0.0 0.0 0.000 300.0 300.0 1.0 310.0 2.500 380.0 379.9 3.0 310.0 2.500 400.0 399.9 3.6 310.0 3.000 500.0 499.5 6.6 310.0 3.000 600.0 598.5 9.6 310.0 3.000 703.5 700.0 12.7 310.0 2.996 800.0 793.4 16.5 313.3 4.007 900.0 888.2 20.4 315.4 3.998 1000.0 980.7 24.4 316.9 3.999 1100.0 1070.3 28.4 318.0 3.999 1200.0 1156.5 32.3 318.8 4.002 1300.0 1239.1 36.3 319.5 3.998 1392.6 1311.9 40.0 320.0 4.002 1400.0 1317.6 40.2 320.3 3.371 1500.0 1392.7 42.3 324.2 3.362 1600.0 1465.3 44.7 327.7 3.367 1700.0 1534.9 47.1 331.0 3.358 1800.0 1601.4 49.6 334.0 3.359 1900.0 1664.5 52.1 336.8 3.364 2000.0 1724.1 54.8 339.4 3.363 2100.0 1779.9 57.4 341.9 3.367 2200.0 1831.6 60.2 344.2 3.357 2300.0 1879.3 62.9 346.3 3.363 2400.0 1922.6 65.7 348.4 3.365 2480.2 1954.1 68.0 350.0 3.361 2500.0 1961.5 68.0 350.8 3.707 2600.0 1998.9 68.0 354.8 3.709 2700.0 2036.4 68.0 358.8 3.709 2800.0 2073.9 68.0 2.8 3.709 2900.0 2111.3 68.0 6.8 3.709 3000.0 2148.8 68.0 10.8 3.709 3100.0 2186.2 68.0 14.8 3.709 3136.5 2199.9 68.0 16.3 3.712 3200.0 2223.7 68.0 18.8 3.707 3300.0 2261.2 68.0 22.8 3.709 3400.0 2298.6 68.0 26.8 3.709 3500.0 2336.1 68.0 30.8 3.709 3600.0 2373.6 68.0 34.8 3.709 3700.0 2411.0 68.0 38.8 3.709 3800.0 2448.5 68.0 42.8 3.709 3900.0 2485.9 68.0 46.8 3.709 3980.2 2516.0 68.0 50.0 3.709 ~~1r~~r Page 3 3k-102,V2.cTw;11-27-2007; LoadCaselntermediatela);Versionwcs-cem452_07 21GINAL • Client CPAi Well 3K-102 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate (a) MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 4000.0 2523.4 68.0 50.8 3.990 4100.0 2560.8 68.1 55.2 3.998 4200.0 2598.0 68.3 59.5 4.005 4300.0 2634.8 68.6 63.8 4.000 4400.0 2671.0 69.0 68.0 4.001 4500.0 2706.5 69.5 72.3 3.997 4600.0 2741.0 70.1 76.5 3.997 4700.0 2774.5 70.8 80.7 4.002 4753.2 2791.8 71.2 82.9 4.007 4800.0 2806.9 71.2 82.9 0.000 4900.0 2839.1 71.2 82.9 0.000 5000.0 2871.2 71.2 82.9 0.000 5100.0 2903.4 71.2 82.9 0.000 5200.0 2935.6 71.2 82.9 0.000 5300.0 2967.8 71.2 82.9 0.000 5400.0 3000.0 71.2 82.9 0.000 5500.0 3032.2 71.2 82.9 0.000 5600.0 3064.4 71.2 82.9 0.000 5700.0 3096.6 71.2 82.9 0.000 5800.0 3128.8 71.2 82.9 0.000 5900.0 3161.0 71.2 82.9 0,000 6000.0 3193.2 71.2 82.9 0.000 6100.0 3225.4 71.2 82.9 0.000 6200.0 3257.6 71.2 82.9 0.000 6300.0 3289.8 71.2 82.9 0.000 6400.0 3322.0 71.2 82.9 0.000 6507.5 3356.6 71.2 82.9 0.000 6600.0 3384.0 74.2 85.1 3.998 6700.0 3408.4 77.5 87.5 3.999 6775.4 3423.1 80.0 89.2 4.003 6800.0 3427.4 80.0 89.2 0.000 6900.0 3444.8 80.0 89.2 0.000 6919.5 3448.2 80.0 89.2 0.000 6975.4 3457.9 80.0 89.2 0.000 7005.4 3463.1 80.0 89.2 0.000 7100.0 3479.5 80.0 89.2 0.000 7200.0 3496.9 80.0 89.2 0.000 7300.0 3514.2 80.0 89.2 0.000 7345.7 3522.2 80.0 89.2 0.000 7400.0 3531.6 80.0 89.2 0.000 7435.4 3537.7 80.0 89.2 0.000 7500.0 3547.9 81.9 89.3 3.007 7535.5 3552.5 83.0 89.4 2.988 7585.5 3558.6 83.0 89.4 0.000 7600.0 3560.4 83.0 89.4 0.000 7615.5 3562.3 83.0 89.4 0.000 7800.0 3584.8 83.0 89.4 0.000 3k-102,V2.cTw;11-27-2007; LoadCaselntermediatelal;Versionwcs-cem452_07 SCI r~r Page 4 0„IGINAL Client CPAi Well 3K-102 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediatelal MD ft Frac. Ib/ al Formation Data Pore Name Ib/ al Lithology 1850.0 12.00 8.00 Permafrost Sandstone 3601.0 12.00 8.00 Sandstone 4600.0 12.00 8.00 Ugnu C Sandstone 5380.0 12.00 8.00 Ugnu B Sandstone 5700.0 12.00 8.00 Ugnu A Sandstone 6320.0 12.00 8.00 K 13 Sandstone 7300.0 12.00 8.00 W Sak C Sandstone 7800.0 12.00 8.00 W Sak B Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 2 5 0.0 1850.0 1633.4 30 0.3 3601.0 2373.9 46 0.9 7615.5 3561.0 72 1.3 7800.0 3584.8 73 1.3 ft o- degF b c ac c ~ ~ 0 0 0 rn 0 0 0 a, Temperature c o ~ 0 0 b x c* a C~ C~ Cr C S~hl~mb~rg~r Hori. Departure 3k-102. V2ciw;il-Z7-2007; Loadcaselntermediatela);Versionwrs-cem452_07 Page 5 ORIGINAL (x 1000) ft i '~ Client CPAi Well 3K-102 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediatelal Section 2: ce ntralizer placement Top of centralization :0.0 ft Bottom Cent. MD :7630.0 ft Casing Shoe :7800.0 ft NB of Cent. Used :96 NB of Floating Cent. :96 S~hlum6er~~r Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint % ft 4280.0 0 0/0 0.0 4295.8 7160.0 72 1/1 HYDROFORM 9625 72.9 7040.0 7640.0 24 2/1 HYDROFORM 9625 81.6 7560.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ibf Ib HYDROFORM 9625 9 5/8 12.250 12.250 Yes Volant N.A. N.A. N.A. (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft O ~ 25 50 75 100 0 - Between Cent. F +At Cent. deg 50 1 (x 1000) ft 0 0 0 0 0 0 0 m ~ I Deviation Page 6 3k-102, UZciw ; 11-272007; Loadcase Intermediate lal : Version wcs-cem452_07 ~~~~LNAL T ~- r ~~~1~~ ,_ I i ~ ~ -~ T i............ i i,' ~ i -;----~ ~~ II ! , Client CPAi Well 3K-102 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate la- Section 3: fluid description Fluid No: 1 Rheo. Model : GINGHAM At temp. : 80 degF MUD Mud Type : WBM Water Type :Fresh VOLUME FRACTION Solids : 6.0 Oil : 0.0 Water :94.0 Mud DESIGN S~! r~r Density :9.501b/gal P~ :15.000 cP Ty :30.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :565.4 bbl MUDPUSH II DESIGN Fluid No: 2 Density : 11.00 Ib/gal Rheo. Model : HERSCHEL_B. k : 3.47E-2 Ibf.s^n/ft2 At temp. : 80 degF n :0.394 Ty :15.501bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :50.0 bbl CW100 DESIGN Fluid No: 3 Density : 8.40 Ib/gal Rheo. Model :NEWTONIAN At temp. : (degF) Viscosity :3.000 cP Gel Strength : (Ibf/100ft2) Job volume :50.0 bbl 12.5 DeepCRETE DESIGN Fluid No: 6 Density :12.50 Ib/gal Rheo. Model : HERSCHEL_B. k : 2.12E-3 Ibf.s^n/ft2 At temp. : 60 degF n :0.994 Ty :20.561bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid :7.818 gal/sk Job volume :264.1 bbl Dry Density : 199.77 Ib/ft3 Yield :2.26 ft3/sk Quantity :655.32 sk Sack Weight : 94 Ib Porosity :46.2 % Solid Fraction :53.8 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Base Fluid :7.738 gal/sk Page 7 a);Versionwcs-cem452_07 3k-102,UZ.ciw;t1-27- 2 007; LoadCaselntermediatel R ` ' t ~ RF x" 1 ~ . • Client CPAi Well 3K-102 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate la) ~clr~~r Section 4: fluid sequence Job Objectives: Isolate Ugnu C (at 4600' MD/ 2658'TVD) by covering with 500' of cement. Original fluid Mud 9.50 Ib/gal P~ :15.000 cP Tv :30.00 Ibf/100ft2 Displacement Volume 585.4 bbl Total Volume 949.4 bbl TOC 4100.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al CW 100 50.0 789.7 2593.2 8.40 viscosity:3.000 cP MUDPUSH II 50.0 717.1 3382.9 11.00 k:3.47E-2 Ibf.s^n/ft2 n:0.394 Tr:15.50 Ibf/100ft2 12.5 DeepCRETE 264.1 3700.0 4100.0 12.50 k:2.12E-3 Ibf.s^n/ft2 n:0.994 Tv:20.56 Ibf/100ft2 Water 20.0 7456.2 8.32 viscosity:3.000 cP Mud 565.4 0.0 9.50 P~:15.000 cP Tv:30.00 Ibf/100ft2 Static Security Checks Frac 295 psi at 3100.0 ft Pore 160 psi at 3100.0 ft Collapse 2781 psi at 7720.0 ft Burst 5303 psi at 3382.9 ft Cs .Pum out 56 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Comments Temp. de F CW100 5.0 25.0 5.0 25.0 80 Pause 0.0 0.0 10.0 0.0 80 CW100 5.0 25.0 5.0 50.0 80 MUDPUSH II 5.0 50.0 10.0 50.0 80 Pause 0.0 0.0 5.0 0.0 80 12.5 5.0 264.1 52.8 264.1 80 DeepCRETE Pause 0.0 0.0 5.0 0.0 80 Water 5.0 20.0 4.0 20.0 80 Mud 6.0 530.4 88.4 530.4 80 Mud 3.0 35.0 11.7 565.4 80 Total 03:16 949.4 bbl hr:mn D namic Security Checks Frac 13 psi at 7800.0 ft Pore 160 psi at 3100.0 ft Collapse 2751 psi at 0.0 ft Burst 4784 si at 0.0 ft Temperature Results API BHCT 76 degF I Simulated Max HCT 73 degF Simulated BHCT 57 degF Max HCT Depth 7800.0 ft CT at TOC 59 degF Max HCT Time 00:00:00 hr:mn:sc Page 8 3k-102,VZc1w;11-27-2007; LoadCaselntermediatelai;Versionwcs-cem452_07 Client CPAi Well 3K-102 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate la- Ib/gal ft 7.5 10.0 12.5 o ~ ~ ~. -- Hydrostatic °o ~ -- 1vin. Hydrostatic --~ Max. Cynarric ,- 1vin. Cynartrc o -- o - Frac 'y V -- Pore a a __ > N O O M ~ 0 0 0 O O O Cn - 0 0 0 ~o N n N 4) a` =1uid Sequence I ~ i IT Dynamic Well Security • Schlu~b~rgur Pumped Volume (bbl) 0 o~ c ~~ _T U O ~ M Q O Pumped Volume (bbl) Pumped Volume (bbl) m m ~o No N ~ d Q- C C Pumped Volume (bbl) Page 9 3k-102,V2.cfw;11-27.2007; Load~aselntermediatelal,Versionwcs-cem452_07 ~~IGINQL Client CPAi Well 3K-102 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate 1a1 Section 6: WELLCLEAN I I Simulator ~,a ~,o ft 0 50 100 0 100 0 o - Mud Contarrinalan - Uncontamnated Slurry 0 0 0 M O O_ O CD O O O ~- Fluid Sequence Cement Coverage Fluids Concentrations 0 t000 2000 ^. 3000 a o ~ 4000 r 5000 ~ 6000 7000 Z ~ PAud `~ MUDPUSH II ,_.~ '~,daker CW100 D 12.5 DeepCRETE S~hl~lh~rg~r Uncontaminated Slurry Deviation Risk Mud on the Wall 0 0 t000 7000 2000 2000 ^• 1000 = - 3000 C n 4000 -._, 4000 a ~ 5000 - _ h C~ 5000 ~ 5000- ~ ~ 6000 7000 - • -- 7000 ,~ 3 ~ o 0 High Low 0 Medium Q Nane Page 10 3k-702,V2cfw;11-27-2007: Loadcaselntermediatela);Versionwrs-cem452_07 deg 50 100 ~Vy/ i~V~ V ~ Wellhead /Tubing /Tree: 13-3/8" x 4112", 5,000 psi Insulated Conductor: 20" 94# K-55x34" 0.312 WT +l- 80' COIC1000`Phi I li ps 2007 West Sak Producer with Rotating self-Aligning Multilateral (RAMTM) System 3875"OB Nipple ~500'MD Dual lateral Completion Lateral Ent ry Module ILEM1 Hea[Trace Cable to 3,000'MD 3K-102 HB DLP With Divert ers and Isolation 1~ Lateral Acc ess "FB" Diverter Lateral lsolationllniet GLM, Camco, 4112" x 1" KBMG, Assembw (Inat alNa N LeMt ~~€ WP Oli rlnaNlNn LEM GLM, Camco, 4112" x 1" KBMG, e-5/8"ML TOrqueMasNr - 13-318" Casing Shoe, Packer - 68#, L-80, BTC Gauge Carner w/ TEC line to surtace ~ 3600' MD, 2373' ND ~ - Positive latchirq Collet CMD Sliding Sleeve, w/ 3.81" DB Nipple, +l- 1 Jt above seals NdKatea cgrr«t LgvtNn sow Nlsn,p oat Tubin95tring o,ientirq ProliN t"°t°"°"~'H"" ; r~Ml" PosaWe Locating Co1Nt Latenlorvertm LaNral IsoNUOn 4112" 12.6#, L-80, IBTM 3.958" s TorqueMaster Packer „y ~ amp upper seals ID, 3.833"Doff Seal Bore tar Lateral Isolation Diverter ° Snip lN6nap OUt 4Y.° lateral Entry Module t.se ID positive Locating (LEM) with 3.68" Seal Bore colNt PBR Seal Assembly wl 0.Sand Casing Exit LaNOi Access w~rgow TorqueMaster 3458'ND, 'D' Sand Lateral 6975'MD Inovaes vowv. Lr..a n~«aa vN naa.muav grve,.n Lalenl Nomion Lower fiesta , Production Anchor 4.75" Seal OD 83 deg inc tsaaN keae RAM sw a«e av«an / 4-112" tt.Ba, BTL, L20 Slotted Llrter Nofa: GS spear used for running and pullin g diverters 7" X 9-518" RAM Hanger 5.960" Lateral Drift ID 3.688" Mainbore Drift ID ~UlDnlent $DeCItICat10 7" X 9.518" RAM Junction f1S Mainbore Drih: 3.68" Lateral Drift: 5.80" RAM Hangerl5eal Bore Diverter OD: 8.375" Overall Length of RAM Junction: 38.3 ft Seal Bore Divener Running Tool: FJD RAM Hanger Running Tool: HRD-E 4-112" Lateral Entry Module LEM OD: 6.99" Mainbore Drift wlo Diverter: 3.68" Mainbore Drift wl Isolation Diverter: 2.50" Lateral Drift wl "FB" Diverter: 3.68" OD of Diverters: 3.68" 4-Y::" x 9-518" RAM Seal Bore Diverter (SBD) with 3.68" Seal Bore L112" 126a IBTM Tubing' 7" X 9-518" MLZXP Liner Hanger Packer Set at +/- 7025' 4712" Guide Shce, 6.00" OD 4112" Casing Shoe, 11.6#, L-80 BTCM 3.582" DB Nipple ~ 14069' MD, 3564' ND / ML Protltwtlon Anchor A s P l a n n e d Seal Aexmbly 'B' Sand Lateral 4.75" Seal OD 3.875"ID 5712" tS.SN, BTC, L-00 Slotted liner ~ S11T" Eccentric Guide Shce Sealbore Recepkck 4.75" ID i,,;,;. IEI/ ~ -„},,~:.~ 5.112" Casing Shoe, 15.5#, L-80 BTCM 9-518" Casing Shce, 40.0#, L-80 BTC @ 14076' MD, 3628' ND ~ 7800' MD, 3576' ND 89 deg inc V t•® HKU6XE5 Baker Oil Tools 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 a Maunder, Thomas E (DOA) Page 1 of 2 From: Eggemeyer, Jerome C. [Jerome.C.Eggemeyer@conocophillips.comj Sent: Monday, December 10, 2007 1052 AM To: Maunder, Thomas E (DQA); Thomas, Randy ~ Cc: Regg, James t3 (DOA) Subject: RE: Testing Casings by Bumping the Plug Tom, good point on item 12, I think this should say: 12. Run 9-5/8", 40# L80, BTC Mod casing to surface and cement as per Schlumberger procedure. (top of cement to be 4,100' MD / 2,561' TVD which corresponds to 500' above the Ugnu C formation.) Testing the casing after bumping the plug can provide a time savings and it is the only way to get a casing test prior to the cement setting. By getting the test before the cement sets there is less risk of causing amicro-annulus due to ballooning of the casing/cement and then leaving a micro annulus between the casing and cement when the casing contracts back after the test. Amicro-annulus can be a larger problem with high pressure gas (which we do not have) but we have maintained this option to give the latitude to optimize the operations. You raised the question about potential for untested connections, this is one reason we address re-testing if cement if found very high in the well (maybe the plug did not pump but something else plugged the circulation path). If the plug has bumped then all connections above the plug are being tested, if the plug is found a couple joints above the float collar (in spit of bumping the plug) then it is likely that the float leaked back a few bbls. If the plug bumps and the casing is tested then the only connections that are not tested are those in the shoe track. By testing during drill-out, after drilling the float collar, we would be testing the connection below the float collar but otherwise the same connections are being tested. I agree with your point about the casing test curve and implication that an ideal pressure volume curve can not be created when bumping and tested, although if bumping on time and at a stow rate they would be able to extract a curve from the job log (although not idea{). The casing test curve gives and indication that you are not pumping around the shoe or that you are testing against a closed valve at the surface. Both of these situations can be recognized by comparison to prior jobs. Thus far I have not considered these to be detrimental to getting a successful LOT. Let me know if this does not answer your questions. Thanks, Jerome From: Maunder, Thomas E (DOA) [maitto:tom.maunder@alaska.gov] Sent: Friday, December 07, 2007 12:04 PM To: Thomas, Randy L; Eggemeyer, Jerome C. Cc: Jim Regg Subject: Testing Casings try Bumping the Plug Randy and Jerome, f am reviewing the apptication for 3K-'102 and have a couple of comments/questions. It appears that the step to cement the 9-5/8" casing was not included in section 12 (Proposed Drilling Program). See step 12. 12/I0/2001 • Page 2 of 2 In step 4 and presumabty in the instructions for cementing the 9-5/8" casing, there is an instruction th test the casing after bumping to plug. Insteps 6 and 15, it is stated to retest the casing if cement is tagged rrmre than 100' above the float collar. If either casing is considered pressure tested after bumping the plug, 1. Are ALL connections that could be exposed to well pressure effec~vety tested? 2. Haw is the base fine pressure information developed for use in conjunction with the LOT? 3. If cement is encountered less than 100` above the fbat collar, it would appear no possible damage is presurr~d to the 3 or 4 connections that could be subject to dritbut forces. Call or message with any questions. I look forward to your reply. Tom Maunder, RE AOGCC 12/10/2007 i ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~/~ _ ~d Z- PTD# ~~ ~' ~~ / Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) 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 25.045(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (SO- =, 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 Atl 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. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for dame of well) until after f Comfy Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. 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O C _ ~ N ~ ~ ~ ~ N ~ ° • (~+ ~ O p c0 O m ii ^ r ` ~ ~ J Q~ a w Q~ U Q ~ ~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infom~ation, 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. r • r 3k-102.tapx Sperry-sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 10 10:24:28 2008 Reel Header Service name .............LISTPE Date . ...................08/04/10 Ori9in ...................5T5 Reel Name. .... ........UNKNOWN .continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date. ..................08/04/10 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................5T5 LIS writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River unit, west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000547949 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services scientific Technical services 3K-102 500292337800 ConocoPhillips Alaska, Inc Sperry Sun 10-APR-08 MWD RUN 3 Mw-000547949 B. HENNINGSE M. THORNTON 35 13N 9E 910 314 .00 73.80 33.80 Page 1 ~D~ f65' ~l~13'~ • OPEN HOLE BIT SIZE (IN) 1ST STRING 12.250 2ND STRING 8.500 3RD STRING PRODUCTION STRING REMARKS: 3k-102.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 3143.0 9.625 7595.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTRONMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase 4), GEOPILOT ROTARY-STEERABLE BHA (GP), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AT-BIT GAMMA (ABG), AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUN 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTRONMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase 4), GEOPILOT ROTARY-STEERABLE BHA (GP), AT-BIT GAMMA (ABG), AND PRESSURE WHILE DRILLING (PWD). 6. GAMMA RAY DATA FROM AT-BIT GAMMA (ABG) MERGED ONTO BOTTOM OF DUAL GAMMA RAY (DGR) AT THE END OF MWD RUN 3. 7. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM. JEFFREY HARRISON (CPAI) TO BRYAN BURINDA DATED 03-APR-2008. 8. MWD RUNS 1-3 REPRESENT WELL 3K-102 WITH API#: 50-029-23378-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14084'MD/3652'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED." SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT Page 2 . • ~' 3k-102.tapx BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 12 1/4~~ FIXED AVG OFFSET: 0.3~~ FIXED MUD WEIGHT: 8.8 - 9.2 PPG MUD SALINITY: 650 - 1000 PPM CHLORIDES FORMATION WATER SALINITY: 12000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 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 3114.5 14079.5 NPHI 3133.0 7508.5 NCNT 3133.0 7508.0 PEF 3133.0 7526.0 RPX 3133.0 14038.5 RPS 3133.0 14038.5 FET 3133.0 14038.5 RPD 3133.0 14038.5 RPM 3133.0 14038.5 FONT 3133.0 7508.0 RHOB 3144.0 7526.0 DRHO 3144.0 7526.0 ROP 3150.0 14084.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH Page 3 U MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 REMARKS: MERGED MAIN PASS. 3k-102.tapx MERGE TOP MERGE BASE 3114.5 7600.0 7556.5 14084.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logyin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD Pu 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3114.5 14084 8599.25 21940 3114.5 14084 FCNT MWD CP30 489.79 3205.72 901.74 8751 3133 7508 NCNT MwD cP30 123681 193237 147131 8751 3133 7508 RHOB MWD G/CC 1.422 2.739 2.12924 8765 3144 7526 DRHO MWD G/CC -0.052 0.371 0.0272073 8765 3144 7526 RPD MWD OHMM 0.81 2000 34.874 21812 3133 14038.5 RPM MWD OHMM 1.68 2000 33.5003 21812 3133 14038.5 RPS MWD OHMM 0.06 2000 29.6206 21812 3133 14038.5 RPX MWD OHMM 0.19 2000 25.6956 21812 3133 14038.5 FET MWD HR 0.12 239.57 1.97711 21812 3133 14038.5 GR MWD API 20.55 132.74 70.3683 21931 3114.5 14079.5 PEF MwD B/E 0.92 15.64 2.15057 8787 3133 7526 ROP MWD FPH 0.55 1461.32 242.362 21869 3150 14084 NPHI MWD Pu 9.97 102.82 41.1577 8752 3133 7508.5 First Reading For Entire File..........3114.5 Last Reading For Entire File...........14084 File Trailer Service name .............STSLIB.001 Page 4 3k-102.tapx service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Ty[~e ................L0 Next Flle Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3114.5 7564.0 PEF 3133.0 7526.0 FET 3133.0 7556.0 RPX 3133.0 7556.0 PEF 3133.0 7508.5 RPS 3133.0 7556.0 RPM 3133.0 7556.0 FCNT 3133.0 7508.0 RPD 3133.0 7556.0 NCNT 3133.0 7508.0 RHOB 3144.0 7526.0 DRHO 3144.0 7526.0 RoP 3150.0 7600.0 LOG HEADER DATA DATE LOGGED: 13-JAN-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.0 MAXIMUM ANGLE: 88.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 77613 Page 5 3k-102.tapx CTN COMP THERMAL NEUTRON ALD Azimuthal Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .......... 0 Data specification Block Type..... 0 Logging Direction ................. DOwn Optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum Specification Block sub-type ...0 158417 239330 12.250 3143.0 Fresh water Gel 9.00 45.0 9.8 800 6.9 2.000 74.0 1.329 114.8 2.200 74.0 2.100 70.0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FONT MwD020 CP30 4 1 68 4 2 NcNT MwD020 cP30 4 1 68 8 3 RHOB MWD020 G/CC 4 1 68 12 4 DRHO MWD020 G/CC 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MwD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 B/E 4 1 68 44 12 ROP MwD020 FPH 4 1 68 48 13 NPHI MwD020 Pu 4 1 68 52 14 First Last Page 6 • • 3k-102.tapx Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3114.5 7600 5357.25 8972 3114.5 7600 FCNT MWD020 CP30 489.79 3205.72 901.74 8751 3133 7508 NCNT MWD020 CP30 123681 193237 147131 8751 3133 7508 RHOB MWD020 G/CC 1.422 2.739 2.12924 8765 3144 7526 DRHO MWD020 G/CC -0.052 0.371 0.0272073 8765 3144 7526 RPD MWD020 OHMM 0.81 2000 22.5701 8847 3133 7556 RPM MWD020 OHMM 3.8 2000 21.8657 8847 3133 7556 RPS MWD020 OHMM 0.06 147.36 16.365 8847 3133 7556 RPX MWD020 OHMM 4.07 61.22 12.0036 8847 3133 7556 FET MWD020 HR 0.12 157.53 1.06724 8847 3133 7556 GR MWD020 API 20.55 132.74 70.0588 8900 3114.5 7564 PEF MWD020 B/E 0.92 15.64 2.15057 8787 3133 7526 ROP MWD020 FPH 0.75 504.35 240.255 8901 3150 7600 NPHI MWD020 PU 9.97 102.82 41.1577 8752 3133 7508.5 First Reading For Entire File..........3114.5 Last Reading For Entire File...........7600 File Trailer Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type ................L0 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.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 7556.5 14038.5 FET 7556.5 14038.5 RPx 7556.5 14038.5 RPD 7556.5 14038.5 RPM 7556.5 14038.5 GR 7564.5 14079.5 ROP 7600.5 14084.0 LOG HEADER DATA Page 7 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 S 3k-102.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... .......... 0 Data specification Block Type..... 0 Logging Direction ................. DOwn Optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth units. .. .. ..... Datum specification Block sub-type ...0 28-JAN-08 Insite 74.11 Memory 88.4 91.5 TOOL NUMBER 120557 145654 8.500 7595.0 Mineral oil Bas 9.30 85.0 27000 136.000 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 Page 8 R 8 102 .tapx RPS MWD030 OHMM 4 1 12 4 RPX MwD030 OHMM 4 1 68 16 5 FET MwD030 HR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 ROP MwD030 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 7556.5 14084 10820.3 13056 7556.5 14084 RPD MWD030 OHMM 1.2 2000 43.2698 12965 7556.5 14038.5 RPM MWD030 OHMM 1.68 2000 41.4394 12965 7556.5 14038.5 RPS MWD030 OHMM 0.32 2000 38.6659 12965 7556.5 14038.5 RPX MWD030 OHMM 0.19 2000 35.0388 12965 7556.5 14038.5 FET MWD030 HR 0.14 239.57 2.60198 12924 7556.5 14038.5 GR MWD030 API 32.23 129.4 70.5796 13031 7564.5 14079.5 ROP MWD030 FPH 0.55 1461.32 243.808 12968 7600.5 14084 First Reading For Entire File..........7556.5 Last Reading For Entire File...........14084 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/10 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................08/04/10 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Library. Scientific Technical Services Library. scientific Technical services Page 9 a ~- Physical EoF 3k-10~.tapx End Of LIS File Page 10
