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208-082
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~ - ~ ~~ Well History File Identifier Two-sided II I II II II (' II I II III ^ Rescan Needed II I II'I II () I I II (III Organ-z-ng (done) RE CAN DIG TAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. 1 ^ 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: ~ O /s/ Pro -ect Proofing II I II II II I I I II I I I II J BY: Maria Date: ro f O lsl Scanning Preparation _~ x 30 =1~ + 1 =TOTAL PAGES Count does not include cover sheet) BY: .Maria Date: ~/~Q~~n lsl Production Scanning Stage 7 BY: Stage 1 BY: Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO Maria Date: ~, / ~ f ~ lsl If NO in stage 1, page(s) discrepancies were found: YES NO Maria __ Date: /S u ~ n n u ~ u n i ~ ~n Scanning is complete at this point unless rescanning is required. ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III (IIIII III IIII III 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/10/2010 Permit to Drill 2080820 Well Name/No. COLVILLE RIV QANN CD2-464 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20574-00-00 MD 10776 TVD 4088 Completion Date 6/17/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMAT~N Mud Log No Samples No Directional Survey Yes DATAINFORMATpN Types Electric or Other Logs Run: GR/RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Da Digital Dataset Log Log Run Interval OH T e Med/Frmt Number Name Scale Media No Start Stop CH Received Comments pt LIS Verification 2532 10727 Open 7/16/2008 LIS Veri, GR, RPX, RP~, FET, RPS, RPD, ROP, NPHI, NCNT, RHOB, ,/ DRHO, Pef, FCNT D C Lis 16618r Induction/Resistivity 2532 10727 Open 7/16/2008 LIS Veri, GR, RPX, RPM, FET, RPS, RPD, ROP, i NPHI, NCNT, RHOB, ~~ DRHO, Pef, FCNT D C Pds 16619 y(nduction/Resistivity 114 10776 Open 7/16/2008 CGM, PDS, and EMF graphics in TVD and MD EWR Logs Induction/Resistivity 25 Col 114 10776 Open 7/16/2008 MD ROP, DGR, ALD, CTN, EWR log Induction/Resistivity 25 Col 114 4087 Open 7/16/2008 TVD DGR, ALD, CTN, EWR ~D Asc Directional Survey 0 10776 Open 7/2/2008 Rpt ~ D~ir ctional Survey 0 10776 Open 7/2/2008 D C Las 17593`~Temperature 2204 4811 Case 2/20/2009 Temp Survey, GR, CCL, Pres og Temperature 2 Col 100 4808 Case 2/20/2009 Temp Survey, MPL, Pres, GR, CCL, Temp 3-Feb- 2009 DATA SUBMITTAL COMPLIANCE REPORT 2/10/2010 Permit to Drill 2080820 Well Name/No. COLVILLE RIV QANN CD2-464 Operator CONOCOPHILLIPS ALASKA INC MD 10776 TVD 4088 Completion Date 6/17/2008 Completion Status 1-OIL Current Status 1-OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMI~TION Well Cored? Y // N~ Chips Received? ~FiQ' Analysis ,111N- Received? Comments: API No. 50-103-20574-00-00 UIC N ~N Daily History Received? Formation Tops ~/ N Compliance Reviewed By: _ __ Date: _L `-'3Z2.~~ , ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-082 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD2-464 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20574-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final ~ 308-234 7/3/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days- Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 374* 374 totals (bbls): 2008 / 3rd 12574 100 0 12674 13 7/6/2008 8/23/2008 CD2-463, CD2-467, CD2-470 Zoos / ath 0 0 1" 1 zoos / 1st 0 0 0 0 2009 / 2nd 0 0 0 0 2009 / 3rd 0 0 0 0 rotas Ending Report is due on the 20th volume 12574 100 375* 13049 13 of the month following the final month of the quarter. Ex: (bbls): Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): "Leak-Off test, in~ectivit test and freeze rotect volumes onl and correct to the best of my knowledge. I hereby certify that the foregoing is true /^ Signature: .l~1. ~~ Date: ~9~'!'~~ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-082 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD2-464 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20574-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^Q or Final ^ 308-234 7/3/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 374* 374 totals (bbls): 2008 / 3rd 12574 100 0 12674 13 7/6/2008 8/23/2008 CD2-463, CD2-467, CD2-470 Zoos / ath 0 0 1 * 1 Zoos / 1st 0 0 0 0 009 / 2nd 0 0 0 0 Total Ending Report is due on the 20th volume 12574 100 375" 13049 13 of the month following the final month of the quarter Ex: (bbis~: . Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *Leak-Off test, in'ectivit test and freeze rotect volumes onl I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~7 /Z~ ~ ~ ~ Date: Signature: 3~,i , . Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-082 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD2-464 2. Address: 4b. Well Status: Oil ^~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20574-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 308-234 7/3/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 374* 374 totals (bbls): 2008 / 3rd 12574 100 0 12674 13 7/6/2008 8/23/2008 CD2-463, CD2-467, CD2-470 2008 / 4th 0 0 1 * 1 2009 / 1st 0 0 0 0 2009 / 2nd Total Ending Report is due on the 20th volume 12574 100 375* 13049 13 of the month following the final month of the quarter. Ex: (bbls): Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *Leak-Off test, in~ectivi test and freeze protect volumes onl rect to the best of my knowledge. cor ue and I hereby certify that the foregoing is tr / ~ Q Signature: __ ~ ~ V'~'~ Date: ~~~ ~~ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate .: ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 200' Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • a~~f BAR ~ .~ Qo 9 lsk~ Oil bas Cogs. ~, .:: ,,,~. s~ Anchorage ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). 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 treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 16th & 17th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, '~ ~`., Perry Klein' ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off ..r- Report of Sundry Operations (10-404) Alpine Field Date 3!19/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD2-72 207-057 SF NA 6" NA 0.85 3/17/2009 CD2-73 208-196 4'5" NA 4'5" NA 21.25 3/17/2009 CD2-75 208-064 SF NA 8" NA 1.70 3/17/2009 CD2-463 207-107 4' NA 4' NA 14.87 3/17/2009 CD2-464 208-082 6" NA 6" NA 1.70 3/17/2009 CD2-465 208-145 19" NA 19" NA 4.25 3/17/2009 CD2-466 208-095 8.5" NA 8'S" NA 1.70 3/16/2009 CD2-467 208-114 SF NA 6" NA 0.85 3/16/2009 CD2-468 208-180 SF NA 5" NA 1.70 3/17/2009 CD2-469 208-122 SF NA 7" NA 0.85 3/17/2009 CD2-470 208-129 SF NA 8" NA 1.70 3/17/2009 1/VG~~ 'Y~..f Ti~r'~4N~~1 /I/T `~~4L -- ---- - - ProActive Diagnostic Services, Inc. To: State of Alaska - AOC~C Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Lease acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActnre Diagnostic Services, inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fay (907) 245-6952 1) Temperature Survey 2) Temperature Survey 03-Feb-09 CD2.464 1 Color Log / EDE 50-103-2057400 02-Feb-09 CD2.470 ,` , Signed : r Print Name: 1 Color Log / EDE 50-103.20581.00 4 .~ ~~. ~~; .~ ; ~~~ ~, Date ~" ~, PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8957 FAX: (907)245-68952 E-MAIL: 3~c3~al~zl~~sacle(c~s~ernor¢!lop.c~~r WEBSITE:5~n.M,jt.§~2rar~,s9~~.~€:s~ C:1Documerts and Settings\Ownet\DesktoplTransmit_Conoco.doc~c ! ~ RECEIVE STATE OF ALASKA JAN 2 ~ Z00~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL O PERATIOI'~`~ka Oil & Gas Con 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other nC 1t~Q 'tic Pack ~ ~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConOCOPhillips Alaska, InC. Development ^~ Exploratory ^ 208-082 . 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20574-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 52' CD2-464 ' 8. Property Designation: 10. Field/Pool(s): ADL 380075 ~ Colville River Field / Qannik Oil Pool 11. Present Well Condition Summary: Total Depth measured 10776' feet true vertical 4088' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78' 16" 114' 114' SURFACE 2532' 10.75" 2568' 2371' INTERMEDIATE 5006' 7-5/8" 5042' 4082' LINER 5900' 3.5' 10766' 4088' Perforation depth: Measured depth: 5719' - 5750', 5938' - 6001', 6095' - 6906', 7247' - 10 511' true vertical depth: 4096' - 4095', 4084' - 4080', 4076' - 4080', 4080' - 40 89' Tubing (size, grade, and measured depth) 3.5" L-80 tubing @ 4887' Packers &SSSV (type 8 measured depth) Baker Premier Packer @ 4462' Camco SSSV @ 2324' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 620 917 None 553 251 Subsequent to operation 803 1105 None 567 241 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oi10 ! Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-447 contact Scott Reed Printed Name Sco Title Production Engineer Signature Phone 265-6548 Date j ~z,(7~©~' Pre ared 6 Jeanne L. Haas 263-4470 .C ~ (" t.~i . d' ~ y Form 10-404 Revised 0412006 S ~~ SAN ? 2 2009 ~ Only ~;) 1 ~ \ Submit O/ri • • Well Service Report `~CD2-464 s Drilling Support Capital ~ Hazen, Mike _.~, 12/18/2008 ~ JOB PERFORMED WHILE DOYON 19 1 FRAC EQUIP DRILLING :COSTS CAPTURED ON FIELD DAILY DRILLING REPORTS VIA NETWORK Er #10217919; J100, J200. _ _ _ - --- ~ 10217919 E~ $0 ~ $0 ~~ SLB-DS ~~GII/RSDORF _- ~ INITIAL T/IA/OA: ? NA/NA/675 (OA IS 7-5/8" BY 10-3/4" Initial & ..,ANNULUS) Final .,'FINAL T/IA/OA: 'Fields= QANNIK Pressures: A/NA/1222 (OA CIS 7-5/8" BY 10- -.3/4 ANNULUS) E .PUMPED 120-BBL OF LVT-200 ARCTIC PACK DOWN THE 7-5/8" BY 10-3/4" ANNULUS AT 2.2-BPM AND APPROXIMATELY 1400-1500-PSI. {Alpine Arctic Pack Formulas: [per Barrel w/LVT-200 Mineral Oil] 0.92-bbl LVT-200 (cold); 15-PPB IMG-400; 10-PPB Versacoat (1-drum/50-bbls); 4% v/v 9.3-ppg ` aCl brine; Following to be mixed while pumping down annulus - 10-PPB IMG- 400} ., , 04:00 PM JSM. OPEN TO WELL. START INJECTION TEST: 608- 04:07 PM PSI INTITAIL PUMP PRESSURE AT 0.0-BPM. JECTION TEST AS FOLLOWS: 1172-PSI, 0.3- 04:15 PM PM; 1439-PSI, 1.5-BPM; 1495-PSI, 2.1-BPM. MONITOR PUMP PRESSURE: STARTING 04:22 PM RESSURE 1489-PSI, 1305-PSI IN 2-MIN, 1281-PSI 3-MIN; 1271-PSI 5-MIN. END INJECTION TEST. PUMP 120-BBL ARCTIC PACK AT 2.2-BPM. ITIAL PUMP PRESSURE IS 1520-PSI. DOWN TO 04:30 PM 1478-PSI AT 50-BBL AWAY; 1435-PSI AT 100-BBL WAY; AND 1292-PSI FINAL PUMP PRESSURE. 05:15 PM PUMP 2-BBL LVT AT 2.1-BPM AND 1432-PSI. i ~ i R on ~~~'~~~~t~~t Cementing fob ep CemCAT v1.0 Well CD2-464 Client ConocoPhillips Field Qannik SIR No. Engineer Rob Clarke ~ Job Type Arctic Pack Country United States ~ Job Date 12-18-08 Time maeame ss:as --------------------- Pressure Rate Messages 16:15:35 ', '. '. '. ', ', '.. '. ' ~ Open To Well 16:21:00 '. - ', ', ' ', Start Injection Test ' ' 2bpm @ i500psi 16:26:00 ', '. . '. ~ 16:31:00 ',,. '.. ', ' '., ', End Test ', ', ', '. ', ', Reset Total, Vol = 6.92 bbl '. '. '. '. '.. '. Start Arctic Pack 16:36:00 '. '. 16:41:00 ' '. '. '. '. 16:46:00 ', ', I '. 16:51:00 ~ ', - ', '. ' '... '. ', ', I. SObbl I 16:56:00 '. '. '. 17:01:00 '. '. '. '. '. 17:06:00 '. 17:11:00 I ', I '.. ' '. 17:16:00 '. ', I I '. '. '. '. '. ', '. 100bb1 ~ 17:21:00 '' '', '. '. ', '', '. '. '. End Arctic Pack ', '. - Reset To[al, Vol = 120.00 bbl ', '. ', Start Displacement '. ', '. Start LVT 17:30:41 End LVT ', ', '. '. '. '. Reset Total, Vol = 1.98 bbl '. '. ' '. ' ' Pack in Place hh:mm'ss i o.oo zooo zoao 3000 +ooo soon i o.oo z.o a.o s.o e.o m.o ~enaama v:oo:.~ --._._- PSI BEM - u~la~~uua Li:si:.su ~~~~ ~h~ Stimulation Service Report Customer PHILLIPS-ALPINE Job Numhcr 2201090226 Well CD2 464 Location (legal) ~ Schlumberger Location Prudhoe Bay, AK Job Start 2008-Dec-18 Field ALPINE Formation Name/Type Deviation BkSize: 8.75 in Well MD 13,698 ft Well TVD 4,107 ft County Beechey Point State/Province ql( BHP BHST BHCT Pore Pres Gradient Well Maste 0631026599 API ~ ~ 50103205740000 psi °F °F psi/ft Rig Name Drilled For Service Via Casing/Liner DOYON 19 O il Land Depth, tt Size, in weight, Ib/ft Grade Thread offshore Zone Well Class well Type 2596 10.75 45.5 L-80 BTC New New Well Completion 4987 7.63 29.7 L-80 BTC PrimaryTreatingFluid Polymer Loading Fluid Density Tttb jng/DriIIPIpC Arctic Pack 25 1b/1000ga1 Ib/gal Depth, Size, in Weight, Ibltt Grade Thread Service Line Job Type 13688 3.5 9.3 Matrix Stimulation Pump Rental Max. Allowed Tubing Pressure Max. Allowed Ann. Pressure We1lHead Connection Perforations/Open Hol e 2000 ps i 2000 psi WECO 1502" Top, ff Bottom, ft spf No. of Shots Total Interval Service Instructions ft Perofrm Arctic Pack on 7 5/8" by 10 3/4" Annulus. Diameter AFE#10217919 in Activity Code J100,J Approver NWOODS Treatment#56365 200 Treat Down Annulus Displacement 2 bbl Packer Type Baker Packer Depth 4460 ft Job Scheduled For. 12/18/2008 16:00 Arrived on Location: 2008-Dec-18 16:00 Leave Location: 2008-Dec-18 20:00 Tubing Vol. bbl CasingVol. 333 bbl AnnularVol. 145 bbl OpenHoleVol bbl Date 7imQ 24 hr cluck CMT TREAT PRES psi CMT RATE bhllmin CMT voL Obl o 0 o 0 i ~ o 0 0 0 o 0 Message ~ I 2008-Dec-18 16:15 675 0.0 0.0 0 0 0 0 0 2008-Dec-18 16:17 676 0.0 0.0 0 0 0 0 0 2008-Dec-18 16:18 -49 0.0 0.0 0 0 0 0 0 2008-Dec-18 16:20 608 0.0 0.0 0 0 0 0 0 2008-Dec-18 16:20 Open To Well 2008-Dec-18 16:22 1172 0.3 0.1 0 0 0 0 0 2008-Dec-18 16:22 Start Injection Test 2008-Dec-18 16:22 1224 0.2 0.2 0 0 0 0 0 2008-Dec-18 16:23 1439 1.5 1.9 0 0 0 0 0 2008-Dec-18 16:25 1495 2.1 5.2 0 0 0 0 0 2008-Dec-18 16:25 1489 2.1 5.4 0 0 0 0 0 2008-Dec-18 16:25 2bpm @ 1500psi 2008-Dec-18 16:27 1305 0.0 6.9 0 0 0 0 0 2008-Dec-18 16:28 1281 0.0 6.9 0 0 0 0 0 2008-Dec-18 16:30 1271 0.0 6.9 0 0 0 0 0 2008-Dec-18 16:31 End Test 2008-Dec-18 16:31 1266 0.0 6.9 0 0 0 0 0 2008-Dec-18 16:31 1265 0.0 6.9 0 0 0 0 0 2008-Dec-18 16:31 Reset Total, Vol = 6.92 bbl 2008-Dec-18 16:31 Start Arctic Pack 2008-Dec-18 16:31 1264 0.0 0.0 0 0 0 0 0 2008-Dec-18 16:32 1520 2.2 0.6 0 0 0 0 0 2008-Dec-18 16:33 1506 2.2 4.2 0 0 0 0 0 2008-Dec-18 16:35 1514 2.2 7.9 0 0 0 0 0 2008-Dec-18 16:37 1501 2.2 11.5 0 0 0 0 0 2008-Dec-18 16:38 1494 2.2 15.1 0 0 0 0 0 2008-Dec-18 16:40 1501 2.2 18.8 0 0 0 0 0 2008-Dec-18 16:42 1515 2.2 22.4 0 0 0 0 0 Dec 19,2008 WRS3 v3.414SR Page 1 of 3 • Well CD2t1464 Field ALPINE rvice Date 2008-Deo-18 Customer PHILLIPS-ALPINE ~- Job IJum6er ~2~-i`~=20 Date 1, Time 24 hr dxk CMT TREAT PRES psi CMT RATE bllmin CMT VOL i ~ bbl ~ 0 0 0 ~ 0 0 0 0 0 0 Message 2008-Dec-18 16:43 1494 2.2 26.0 0 0 0 0 0 2008-Dec-18 16:45 1477 2.2 29.7 0 0 0 0 0 2008-Dec-18 16:47 1475 2.2 33.3 0 0 0 0 0 2008-Dec-18 16:48 1491 2.2 36.9 0 0 0 0 0 2008-Dec-18 16:50 1481 2.2 40.6 0 0 0 0 0 2008-Dec-18 16:52 1454 2.2 44.2 0 0 0 0 0 2008-Dec-18 16:53 1442 2.2 47.8 0 0 0 0 0 2008-Dec-18 16:54 50bb1 2008-Dec-18 16:54 1478 2.2 48.9 0 0 0 0 0 2008-Dec-18 16:55 1453 2.2 51.5 0 0 0 0 0 2008-Dec-18 16:57 1461 2.2 55.1 0 0 0 0 0 2008-Dec-18 16:58 1444 2.2 58.7 0 0 0 0 0 2008-Dec-18 17:00 1435 2.2 62.4 0 0 0 0 0 2008-Dec-18 17:02 1442 2.2 66.0 0 0 0 0 0 2008-Dec-18 17:03 1459 2.2 69.7 0 0 0 0 0 2008-Dec-18 17:05 1440 2.2 73.3 0 0 0 0 0 2008-Dec-18 17:07 1427 2.2 76.9 0 0 0 0 0 2008-Dec-18 17:08 1446 2.2 80.6 0 0 0 0 0 2008-Dec-18 17:10 1458 2.2 84.2 0 0 0 0 0 2008-Dec-18 17:12 1429 2.2 87.8 0 0 0 0 0 2008-Dec-18 17:13 1419 2.2 91.5 0 0 0 0 0 2008-Dec-18 17:15 1431 2.2 95.1 0 0 0 0 0 2008-Dec-18 17:17 1452 2.2 98.7 0 0 0 0 0 2008-Dec-18 17:17 1435 2.2 99.6 0 0 0 0 0 2008-Dec-18 17:17 100bb1 2008-Dec-18 17:18 1446 2.2 102.4 0 0 0 0 0 2008-Dec-18 17:20 1418 2.2 106.0 0 0 0 0 0 2008-Dec-18 17:22 1416 2.2 109.6 0 0 0 0 0 2008-Dec-18 17:23 1454 2.2 113.3 0 0 0 0 0 2008-Dec-18 17:25 1445 2.2 116.9 0 0 0 0 0 2008-Dec-18 17:27 End Arctic Pack 2008-Dec-18 17:27 1292 0.0 120.0 0 0 0 0 0 2008-Dec-18 17:27 Reset Total, Vol = 120.00 bbl 2008-Dec-18 17:27 1295 0.0 120.0 0 0 0 0 0 2008-Dec-18 17:27 Start LVT 2008-Dec-18 17:27 Start Displacement 2008-Dec-18 17:27 1293 0.0 0.0 0 0 0 0 0 2008-Dec-18 17:27 1279 0.0 0.0 0 0 0 0 0 2008-Dec-18 17:28 1432 2.1 2.0 0 0 0 0 0 2008-Dec-18 17:28 End LVT 2008-Dec-18 17:28 1297 0.8 2.0 0 0 0 0 0 2008-Dec-18 17:28 Reset Total, Vol = 1.98 bbl 2008-Dec-18 17:28 Close in Wellhead 2008-Dec-18 17:28 End job 2008-Dec-18 17:28 Pack in Place 2008-Dec-18 17:28 1303 0.0 0.0 0 0 0 0 0 2008-Dec-18 17:28 1274 0.0 0.0 0 0 0 0 0 2008-Dec-18 17:30 1222 0.0 0.0 0 0 0 0 0 Dec 1s,zoos wRSS v3.414SR Page 2 of 3 • Well Field ervice Date Customer Job Number CD2#484 ALPINE 2008-Deo-18 PHILLIPS-ALPINE '_'~~~~~~~~_''=~~ Date Tima CMT TREAT CMT RATE CMT VOL 0 0 0 0 o Message PRES 24 hr ~ ~~ psi bbllmin bbl 0 0 0 0 ~ 0 Post Job Sumrnary Average Injection Rates, bpm Volume of Fluid Injected, bbl Fluid N2 C02 Maximum Rate Bean Fluid Acid Oil C02 N2 (scf) 2 2 Treating Pressure Summary, psi Quantity of 8 placed, Ib liroakdown Maximum Final Average ISIP 15 Min. ISIP Total Injected Total Ordered/Designed 1500 1500 1220 N2 Percent C02 Percent Designed Fluid Volume Displacement Slurry Volume Pad Volume Percent Pad 50400 gal 2 bbl 120 bbl 7 gal °k CustomerorAuthorizedRepresentative SchlumbergerSupervisor Number of Stages Fracture Gradient ~ JobCompleted Burley, Dave Clarke, Robert psi/ft ^ screenout Dec 19,2008 WRS3 v3.414-SR Page 3 of 3 Customer: Conoco'Phillips Schlumberger District: PAK Representative: DS Supervisor: Rob Clarke Job Date: 12-18-08 Well: CD2-464 Time CMT TREAT PRES CMT RATE CMT VOL mm:dd:yyyy:hh:mm:ss psi bbl/min bbl 12:18:2008:16:15:35 12:18:2008:16:17:15 12:18:2008:16:18:55 12:18:2008:16:20:35 12:18:2008:16:20:35 12:18:2008:16:22:00 12:18:2008:16:22:00 12:18:2008:16:22:15 12:18:2008:16:23:55 12:18:2008:16:25:35 12:18:2008:16:25:39 12:18:2008:16:25:39 12:18:2008:16:27:15 12:18:2008:16:28:55 12:18:2008:16:30:35 12:18:2008:16:31:40 12:18:2008:16:31:40 12:18:2008:16:31:41 92:18:2008:16:31:41 12 `.18:20 08:16:31:4 2 12:18:2008:16:31:42 12:18:2008:16:32:15 12:18:2008:16:33:55 12:18:2008:16:35:35 12:18:2008:16:37:15 12:18:2008:16:38:55 12:18:2008:16:40:35 12:18:2008:16:42:15 12:18:2008:16:43:55 12:18:2008:16:45:35 12:18:2008:16:47:15 12:18:2008:16:48:55 12:18:2008:16:50:35 12:18:2008:16:52:15 12:18:2008:16:53:55 12:18:2008:16:54:25 `` 12:18:2008:16:54:25 12:18:2008:16:55:35 12:18:2008:16:57:15 12:18:2008:16:58:55 12:18:2008:17:00:35 12:18:2008:17:02:15 12:18:2008:17:03:55 12:18:2008:17:05:35 12:18:2008:17:07:15 12:18:2008:17:08:55 12:18:2008:17:10:35 12:18:2008:17:12:15 12:18:2008:17:13:55 12:18:2008:17:15:35 12:18:2008:17:17:15 12:18:2008:17:17:40 12:18:2008:17:17:40 12:18:2008:17:18:55 12:18:2008:17:20:35 12:18:2008:17:22:15 12:18:2008:17:23:55 675 0.0 676 0.0 -49 0.0 Open To Well 608 0.0 Start Injection Test 1172 0.3 1224 0.2 1439 1.5 1495 2.1 2bpm @ 1500psi 1489 2.1 1305 0.0 1281 0.0 1271 0.0 End Test 1266 0.0 Reset Total, Vol = 6.92 bbF 1265 0.0 Start Arctic Pack 1264 0.0 1520 2.2 1506 2.2 1514 2.2 1501 2.2 1494 2.2 1501 2.2 1515 2.2 1494 2.2 1477 2.2 1475 2.2 1491 2.2 1481 2.2 1454 2.2 1442 2.2 50bb1 1478 2.2 1453 2.2 1461 2.2 1444 2.2 1435 2.2 1442 2.2 1459 2.2 1440 2.2 1427 2.2 1446 2.2 1458 2.2 1429 2.2 1419 2.2 1431 2.2 1452 2.2 0.0 0.0 0.0 100bb1 0.0 0.1 0.2 1.9 5.2 5.4 6.9 6.9 6.9 6.9 6.9 0.0 0.6 4.2 7.9 11.5 15.1 18.8 22.4 26.0 29.7 33.3 36.9 40.6 44.2 47.8 48.9 51.5 55.1 58.7 62.4 66.0 69.7 73.3 76.9 80.6 84.2 87.8 91.5 95.1 98.7 1435 2.2 99.6 1446 2.2 102.4 1418 2.2 106.0 1416 2.2 109.6 1454 2.2 113.3 Paoe 1 of 2 Well: CD2-464 ~ ~ Job Date: 12-18-08 Time CMT TREAT PRES CMT RATE CMT VOL mm:dd:yyyy:hh:mm:ss psi bbl/min bbl 12:18:2008:17:27;04 End Arctic Pack 12:18:2008:17:27:04 1292 0.0 120.0 12:18:2008:17:27:05 Reset Total, Vol = 120.00 bbl 12:18:2008:17:27:05 1295 0.0 120.0 12:18:2008:17:27:06 Start Displacement 12:18:2008:17:27:06 Start LVT 12:18:2008:17:27:06 1293 0.0 0.0 12:18:2008:17:27:15 1279 0.0 0.0 12:18:2008:17:28:30 End` L_VT 12:18:2008:17:28:30 1432 2.1 2.0 12:18:2008:.17:28:31 Reset Total, Vol = 1.98 bbl 12:18:2008:17:28:31 1297 0.8 2.0 12:18:2008:17:28:34 Pack in Place 12:18:2008:17:28:34 Close in Wellhead 12:18:2008:17:28:34 End job 12:18:2008:17:28:34 1303 0.0 0.0 12:18:2008:17:28:55 1274 0.0 0.0 12:18:2008:17:30:35 1222 0.0 0.0 Page 2 of 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISP~JSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-082 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD2-464 2. Address: 4b. Well Status: Oil ^~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20574-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 308-234 7/3/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 374"' 374 totals (bbls): 2008 / 3rd 12574 100 0 12674 13 7/6/2008 8/23/2008 CD2-463, CD2-467, CD2-470 2008 / 4th 0 0 1 * 1 2009 / 1st 2009 / 2nd Total Ena~n9 Report is due on the 20th volume 12574 100 375` 13049 13 of the month following the final month of the quarter. Ex: (bbis>: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ . October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *Leak-Off test, in'ectivit test and freeze protect volumes onl 1 hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~• ~ Date: ~1~~~ Si t gna ure: Printed Name: G. C. Alvord Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ALASSA OIL A1~D GA5 CO1~T5ERQA'TIO1~T COAi1~II55IO1~T Scott Reed Production Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Qannik Oil Pool, CD2-464 Sundry Number: 308-447 Dear Mr. Reed: • SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Corrunission to witness any required test, contact the Commission's petroleixm field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Ccmmission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy . Foerster Conunissioner /,, -/~-- DATED this ~`~ day of December, 2008 Encl. b~ -~~ 08~ a • • ~~ ~ ,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION \~ APPLICATION FOR SUNDRY APPROVAL ~/~ ~ 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^/ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Arctic Pack Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development Q Exploratory ^ 208-082 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20574-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO Q CD2-464 • 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380075 RKB 52', 15.7' AMSL Colville River Field / Qannik Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10776' 4088' 10762' ~ 4088' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78' 16" 114' 114' SURFACE 2532' 10.75" 2568' 2371' INTERMEDIATE 5006' 7-5/8" 5042' 4082' LINER 5900' 3.5" 10766' 4088' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5719'-5750', 5938'-6001', 6095'-6906', 7247'-10511' 4096'-4095', 4084'-4080', 4076'-4080', 4080'-4089' 3.5" L-8~ 4887' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier pkr @ 4462' Camco SSSV @ 2324' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat December 19, 2008 Oil ^~ Gas ^ Plugg+ad ^ Abandoned 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Reed @ 265-6548 Printed Name Scott Reed Title: Production Engineer Signature SC' Phone 265-6548 Date h -/Z ~ Commission Use Onl resentative ma witness Commission so that a re Conditions of a roval: Notif Sundry Number: ~ 36 ~ ~ "(! y p y pp rity T st ^ Plug Integrity ^ BOP Test ^ Mechanical Integ earance tio n Cl Loca ^ e C Other. `7~p~`~3 fC. C'C,x~ t ~~55~ Cifc C10.''t~C~.~ ~ ~ ~ ~ VJ i ` ~ ~ l / ~V ~'1 . Subsequent Form Required: ~ ;~, ~: ~,~,, ~ ~ ZQ~~ APPROVED BY ISSION ~ 7/ D t Approved by: COMMISSIONER THE COMM a e: Form 10-403 Rev~ed 06/2006 ` ~~ ~ Submit in Duplicate L~ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 11, 2008 Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Arctic Pack CD2-464 (Permit to dri11208-082) Dear Tom: • .- ~Ol"1QCCl~'ll~~f As discussed through electronic correspondence dated December 11, 2008, well CD2-464 has been experiencing hydrate problems. CPAI would like to pump an Arctic Pack down the outer annulus of CD2- 464 to reduce heat loss to mitigate the hydrate formation. The well is currently flowing to production. Please see attached current condition well schematic. Pertinent information attached to this application includes the following: 1. Arctic Pack Procedure 2. Current status completion diagram 3. Well History Upon approval of this request, CPAI will commence with an injection test down the outer annulus of CD2-464. If injection can be established, the outer annulus will be Arctic Packed as per the attached well work procedure. If you have any questions or require further information, please contact Scott Reed, 265-6548, or Tim Schneider at 265-6859. Sincerely, ~~, ~> ~ ~ ~/mot" Scott Reed Production Engineer cc: CD2-464 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Lamont Frazer ATO 1754 Brian Noel ATO 1700 Tim Schneider ATO 1768 CD2-464 Well Work Procedure 1. Use Little Red Services to perform infectivity test on the OA; not to exceed 2000 psi. 2. Establish Injection with 20-30 bbls diesel then switch to pumping Arctic Pack fluid. 3. Pump 102 bbls of Arctic Pack fluid. Pumping should not exceed 2000 psi or 2 bbls/min. 4. Chase with 1-2 bbls of neat diesel. 5. Shut in well without bleeding off pressure. i _., ~c~r~cscoPh~llps ~ ~ ~ ~, ~~_~ - _. ~- ~ ~ 1 ~.. 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Staie+,i 52t5eg Toy T^~rd -ubv~~ F v~v-~=-o~° <.'a~~ 3'~a' :~>-J -J~o1 ~3 J^a0 ~fi~ ~~~E-t+1 ~~ V ITi 91t:'iaAR ~'1sL31tS T ,~~ oP t fT:'~.Tl {R1{8'i lop hici ;'7 Ytx+n '~9cs t`rrent iC~ ~r: __vz h''.P3s;}i &IV.;~ :._ ag F•ar~ar w ~.~r'~ -_ ~..~ `:r ~. & a=eg~' ad~a T=2 ~x~ ~ T: =::5-trE ~a~,'v, ~ ~, eis-~...« x ~- ~~.cl.°~. ..._ ~.~ ,. as ., .. ,-_ ia~~ur 'ac .E. *_ .. .. x,. .~, .wry ~. .~~z ~,5 r~. a- E,~trl"t-~~-• ssa-coy ~ ;_? ~~1 ..~5". 7S c~ S. P~~y - _ ' ~ sa: r rg's d-7 :,le ,..~ . ,''L=F- ~ ;-4'~' ..9& F~rf~r~zions '3 (itN6) ~tota$h$i Tt?p'T97D1 t~£t Bkrrs ~~ $on~ .~: Ceps {sss_. T• Y Cone=ienz ,'25 ~~ -. _. 4. .L ~,'~ .? ~ -- Slot; ti-mot -aa--e s:.,l2.z'< sere.~3 G^~~s _. _:.~ ~ ;r .~ t t9r3tes: General 8 5afet _ c~,. ~e _ _ . __ _ .v, ~, -,> tVlan~clrel Cfetail~ s~n c pIftKB} L~ h ~ fi'sL~ ~fYtC£7 3~.. M~ `F AOi~e tAa/Se3 d ?^ ,i rv} - ~~ ae~. r.r~+ i~~t...r TJ~ S~e fntt 7~£urr (ps[} u Oar nm-~.i-_ ~ ]ar ~U- ~. r ~ _ ~".-__ ~ ~i Well History • C D2-464 :501032057400 : 12/11/2008 Date Event 10/4/2008 DRIFT TBG TO XN NIP @ 4568' RKB TBG CLEAR, RUN 2.5" DRIVE DOWN BAILER TO 5008' SLM WHERE TOOLS STOP FALLING NO SAMPLE GAINED JOB COMPLETE 10/1/2008 CREW CHANGE OUT. FLIGHT DELAY TO ALPINE. GET UNIT READY FOR JOB IN THE A.M. 8/15/2008 GAUGED TBG TO 2.80" TO XN NIPPLE @ 4568' RKB. MEASURED BHP @ 4685' RKB: 1225 PSI. FUNCTION TESTES SSSV, GOOD. COMPLETE. 6/20/2008 PULL BALL & ROD FROM XN NIPPLE @ 4568' RKB, PULL SOV FROM STA #2 @ 4403' RKB, SET 1/4" OV @ SAME, PULL RHC PLUG BODY FROM XN NIPPLE @ 4568' RKB, RUN DUAL SAPPHIRE GAGES TO 4680' SLM, (MAX PSI 1852.31 & TEMP 91.34), PREFORM CLOSER TEST ON SSSV GOOD TEST JOB COMPLETE 4 records retrieved for Well History 10-403 Requirements for Arctic Packs ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, December 11, 2008 4:20 PM To: 'Reed, Scott' Cc: Schneider, Tim S.; Frazer, Lamont C; Regg, James B (DOA) Subject: RE: 10-403 Requirements for Arctic Packs Scott, Yes a sundry should be submitted. AP per se hasn't been done in some time. Thanks for asking. Tom Maunder, PE AOGCC From: Reed, Scott [mailto:Scott.Reed@conocophillips.com] Sent: Thursday, December 11, 2008 4:14 PM To: Maunder, Thomas E (DOA); Maunder, Thomas E (DOA) Cc: Schneider, Tim S.; Frazer, Lamont C Subject: 10-403 Requirements for Arctic Packs Tam, The Qannik wells out at alpine are experiencing hydrate problems and as a mitigation strategy 1 would like to Arctic Pack the OA in both CD2-470 and CD2-464. Does this work require a 10-403 sundry? Thanks Scott Reed Scott Reed Production Engineer WNS Subsurface Office: (907) 265-6548 Cell: (907) 575-3978 bo,SE~ o ~ ~ ~3f'~-t, `~ ~'G~s'. C.~~Q 0.t ~~/ ~ ~~~~/' ~' 12/15/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-082 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD2-464 2. Address: 4b. Well Status: Oil ^~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20574-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^~ or Continuation ^ or Final ^ 308-234 7/3/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 374* 374 totals (bbls): Zoos / 3rd 12574 100 0 12674 13 7/6/2008 8/23/2008 CD2-463, CD2-467, CD2-470 2008 / 4th 2009 / 1st 2009 / 2nd Total Ending Report is due on the 20th volume 12574 100 374* 13048 13 of the month following the final month of the quarter. Ex: (bbis>: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *Leak-Off test and freeze rotect volumes onl I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: Date: (~/t~~0~ Printed Name: G. C. Alvord Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate . Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, August 19, 2008 1:23 PM To: 'Allsup-Drake, Sharon K' Subject: RE: CD2-464 correction Sharon, No need for a new 407. I have made hand corrections. Tom Maunder, PE AOGCC From: Allsup-Drake, Sharon K [mailto:Sharon.K.Allsup-Drake@conocophillips.com] Sent: Tuesday, August 19, 2008 1:06 PM To: Maunder, Thomas E (DOA) Subject: FW: CD2-464 correction Tom - We have found an error on the completion report for CD2-464. The RKB should be corrected to 52' and the GL should be corrected to 15.7' AMSL. Should we send over a corrected completion report? Thank you, Sharon 263-4612 ~o~a ~p`d 8/19/2008 I~ I-.~ ConocoPhillips July 30, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-464 Dear Commissioner: G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ~e ?" s i. ~r~ ~ ~. ., _. ~~ _ . ~, ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Qannik well CD2-464. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, t `~ ~ ~.~- G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad ~ ~ - : ~~~ ~ ~~ STATE OF ALASKA ~~`' ~ '~ J ALASKA OIL AND GAS CONSERVATION COMMISSION ~.q ~-„, , WELL COMPLETION OR RECOMPLETION REPORT AND ,LOG .~~On~ 1a. Well Status: Oil ^/ Gas Plugged 20AAC 25d105 20AAC 25e110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: ^ xploratory ^ Developments / E Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., (q Q•3 or Aband.: June // , 2008 12. Permit to Drill Number: 208-082 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 3, 2008 ~ 13. API Number: 50-103-20574-00 ' 4a. Location of Well (Governmental Section): Surface: 2188' FNL, 1825' FEL, Sec. 2, T11 N, R4E, UM ' 7. Date TD Reached: ~ June 14, 2008 • 5 a 14. Well Name and Number: CD2-464 ' Top of Productive Horizon: 1518' FSL, 245' FEL, Sec. 2, T11N, R4E, UM 8. KB (ft above MSL): RKB Ground (ft MSL): ~AMSL ~5.~ field/Pool(s): Colville River Field Total Depth: 1079' FSL, 901' FWL, Sec. 12, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 10762' MD / 4088' TVD Qannik Oil Pool ' 4b. location of Well (State Base Plane Coordinates): Surface: x- 371409' y- 5974174 ' Zone- 4 10. Total Depth (MD + ND): • 10776' MD / 4088' TVD ' 16. Property Designation: ADL 3soo75 ' TPI: x- 372963 y- 5972574 Zone- 4 Total Depth: x- 374016 - 5966836 Zone- 4 11. SSSV Depth (MD + ND): 2324' MD / 2167' TVD 17. Land Use Permit: ADL 380075 18. Directional Survey: Yes 0 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): 1500' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" pre-installed 10.75" 45.5# L-80 37' 2568' 37' 2371' 13.5" 404 sx ASLite, 275 sx Class G 7-5/8" 29.7# L-80 37' 5042' 37' 4082' 9-7/8" 256 sx Class G 3.5" 9.3# L-80 4866' 10766' 4058' 4088' 6.75" slotted liner 23. Open to production or injection? Yes / No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 4886' 4461' slotted liner with 8 spf 5719'-5750' MD 4096'-4095' ND 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5938'-6001' MD 4084'-4080' ND DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6095'-6906' MD 4076'-4080' TVD none 7247'-10511' MD 4080'-4089' TVD 26. PRODUCTION TEST Date First Production July 3, 2008 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 7/8/2008 Hours Tested 12 hours Production for Test Period --> OIL-BBL 873 GAS-MCF 1056 WATER-BBL 20 CHOKE SIZE 70% GAS-OIL RATIO 1491 Flow Tubing press. 260 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1592 GAS-MCF 2373 WATER-BBL 40 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+ND 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. /.~ ?~ ~,yr~/y„y~. UY!~ p NONE , V~~!Fi~ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~ 9. 3- °~ ~RI~iN~~. s ~~~~~~~ ~~~ l~ ~~~ 9 ~~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No . If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1536' 1500' needed, and submit detailed test information per 20 AAC 25.071. C30 2610' 2406' C20 3052' 2778' K-3 4344' 3846' K-2 4932' 4069' N/A Formation at total depth: K-2 t 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey S ~ 265-6247 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Liz G81iu ~ Printed Na~ "~%r-Chin Alvord Title: Drillino Team Leader ' ~ ~ ( 3~ ~ a '~ °' ~a l °-~ Phone Z~-S--b~ ~v Date Signature ~ ~ INSTRUCTIONS Sharon Allsu/}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 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • • ~onocoPhillips Time Log & Summary WeiTv7ew Web Reporffng Report Well Name: CD2-464 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 6/2/2008 12:00:00 PM Rig Release: 6/18/200812:00:00 PM Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 6/02/2008 24 hr summary MIRU Over CD2-464; P/U 20 Stds 5" DP and 8 Stds 5" Hevi-Weight DP 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Move Rig Over CD2-464; Spot Pit Module, Ball Mill, & Pipe Shed; N/U Surface Riser Ri Acce ted 1800 on June 2 2 8 18:00 00:00 6.00 0 0 MIRU MOVE RURD P NU riser and flowline -Install turn buckles -fill pits with spud mud - P/U 5" DP for Surface Hole & Stand Back in Derrick 6/03/2008 Fin PU 5" DP, MU 13 1/2" Bit on BHA #1, Spudded well @ 04:15 hrs, drilled 13 1/2" hole f/114' to 1,375', was unable to et desired build rate from motor, POOH to BHA to chan a out motors. 00:00 00:30 0.50 0 0 MIRU MOVE RURD P PU & stand back 5"drill pipe 00:30 00:45 0.25 0 0 MIRU MOVE SFTY P PJSM on MU BHA 00:45 03:30 2.75 0 68 MIRU MOVE RURD P MU BHA #1- PU 8" motor -added ABI component to motor - MU bit - NMFS -IBS - HCIM - DM HOC - TM HOC - UBHO -Initialize MWD 03:30 04:00 0.50 68 68 MIRU MOVE RURD P Held Pre-Spud Safety and Opts meetin with crew and su ort staff 04:00 04:15 0.25 68 68 MIRU MOVE RURD P Fill riser and check for leaks - ressure test mud lines to 3500 si 04:15 12:00 7.75 68 716 SURFA( DRILL DDRL P S ud well 04:15 hours. Drill 13 1/2" hole w/ motor f/114' to 716' MD/ 714.5' TVD WOB 15/25 k RPM 60 GPM 500 @ 1070 psi String wt. PU 1105 SO 105 Rot 105 Torque on/off btm. - 6000/4500 ft/Ibs. @ 716' G ro surve s 79', 173', 264' & 357' 12:00 16:30 4.50 716 1,185 SURFA( DRILL DDRL P Drilled 13 1/2" hole from 716' to 1,185' MD/1,173' (469') ART 1.07 hrs, AST 2.07 hrs, ADT 3.14 hrs, 20-30K wob, 60 r m's, 650 mat 1,720 si. 16:30 17:30 1.00 1,185 1,185 SURFA( RIGMNT SVRG T Stood back 1 stand and changed out swivel ackin , RIH to btm. 17:30 18:15 0.75 1,185 1,288 SURFA( DRILL DDRL P Drilled 13 1/2" hole from 1,185' to 1,288' MD/1,273' (103') ART 0.37 hrs, AST 0.14 hrs ADT .51 hrs 18:15 18:45 0.50 1,288 1,288 SURFA( DRILL CIRC NP Picked up off btm and Sperry Sun discussed closed approach issues P~~e 1 tsf 16 Time Logs Date From To Dur 5 De th E. De th Ph se Code Subcode T Comment 18:45 19:30 0.75 1,288 1,375 SURFAC DRILL DDRL P Drilled 131!2" hole from 1,288' to 1,375' MD/1,353' TVD (87') ART 0 hrs, AST 0.5 hrs, ADT 0.50 hrs, 30-40K wob, 60 rpm's, 450 gpm at 1,300 psi. Off btm torque 4,500 ft-Ibs, on btm 6,500 ft-Ibs, rot wt 120K, up wt 123K, do wt 118K. 19:30 20:30 1.00 1,375 1,375 SURFA( DRILL CIRC NP Circ hole at 450 gpm and 870 psi while discussing with town the close approaches and motor not getting enough build rates, the decision was made to POOH and chance out motors. Monitored well-static 20:30 22:15 1.75 1,375 167 SURFAC DRILL TRIP T POOH on elevators from 1,375' to BHA at 905', monitored well-static, POOH standin back HWDP to 167'. 22:15 00:00 1.75 167 0 SURFAC DRILL TRIP T Stood back NMFDC's, downloaded MWD then LD Bit and Motor. 6/04/2008 MU BHA #2 w/2.12 deg mtr, RIH working thru tight spot at 585' to 622', Cont to RIH, Drill 13 1/2" hole f/1,375' to 1,659'. Circ clean, POOH & changed mtr to 1.83 deg bend. RIH W/BHA #3 working thru tight spots, washed & reamed to btm. Cont. to drill 13 1/2" hole to 2,378' 00:00 02:15 2.25 0 258 SURFAC DRILL PULD T MU Bit and Motor - set AKO @ 2.13 derees - MU FS, MWD Tools and UBHO -Scribe tools -initialise tools - RIH with NMFC's and 1 std hwdp - shallow test tools 02:15 04:15 2.00 258 1,374 SURFA( DRILL TRIP T RIH -Bit stopped @ 585' -Work through tight hole from 585' to 622' - 100 m/15 m-RIH to 1374' 04:15 07:00 2.75 1,374 1,659 SURFA( DRILL DDRL P Drill 13 1/2" hole w/ motor f/ 1375' to 1659' MD/ 1607' TVD ADT =1.53 hrs. ART=0.81 hrs. AST=0.72 hrs. WOB 35/40 k RPM 20 GPM 475 @ 1040 psi String wt. PU 120 SO 120 Rot 125 Torque on/off btm. - 6500/5500 fUlbs. 1659' 07:00 07:30 0.50 1,659 1,659 SURFAC DRILL CIRC T Circulate hole clean - 550 gpm / 1170 psi / 20 rpm -Flow check well, static 07:30 09:30 2.00 1,659 68 SURFAC DRILL TRIP T POOH on trip tank from 1564' to 68' - sli ht over ull 600' 09:30 12:15 2.75 68 166 SURFAC DRILL PULD T Down load MWD -Inspect bit, good - Change AKO setting on motor to 1.83 degrees -Scribe tools -Initialize MWD - MU NMFC's and RIH to 166' - shallow test tools 12:15 15:15 3.00 166 1,564 SURFA( DRILL TRIP T RIH from 166' to 1564' -work through tight spots from 999' to 1030', 1041' to 1045', 1165' to 1175' - 1301' to 1310' - 3-4 bpm /230-560 psi / 10-20 rm ?a~e2of16 • Time Logs Date From To Dur 5 De th E. De th Phase Code Subcode T Comment 15:15 16:00 0.75 1,564 1,659 SURFA( DRILL REAM T Wash and ream from 1564'to 1626', clean out fill from 1626' to 1659' - 550 gpm / 1160 psi / 60 rpm -observed coarse sand and ea ravel back across shakers 16:00 00:00 8.00 1,659 2,378 SURFA( DRILL DDRL P Drill 13 1/2" hole w/ motor f/ 1659' to 2,378' MD/ 2,205' TVD ADT =4.85 hrs. ART=3.83 hrs. AST= 1.02 hrs. WOB 20125 k RPM 60 GPM 650 @ 1,980 psi String wt. PU 140K, SO 120K, Rot 137K Torque on/off btm. - 8000/6500 ft/Ibs. 2,324' 6/05/2008 Drilled 131/2" hole f/2,378' to 2,578' (csg pt), Backreamed out of hole to HWDP w/no problems, RIH &circ hole clean, POOH & LD BHA #3 w/no problems. RU &RIH with 10 3/4", 45.5#, L-80, BTC-M csg and landed same at 2,568'. RD fill u tool & MU cmt head, circ & cond mud for cmt . 00:00 02:30 2.50 2,378 2,578 SURFA( DRILL DDRL P Drill 13 1/2" hole w/ motor f/ 2,378' to 2,578' MD/2,379' TVD ADT =2.09 hrs. ART=1.89 hrs. AST= 0.20 hrs. WOB 20/25 k RPM 60 GPM 700 @ 2,450 psi String wt. PU 145K, SO 119K, Rot 130K Torque on/off btm. - 8000/7000 ft/Ibs. 2,578' 02:30 03:45 1.25 2,578 2,514 SURFA( DRILL CIRC P CBU X2 - 700 gpm/ 2200 psi / 60 rpm -stood back one stand to 2,514' - Flow check well, static 03:45 06:30 2.75 2,514 903 SURFA( DRILL TRIP P POOH with pumps from 2514' to 903' - no problems - 650 gpm / 1870 psi / 60 rpm -reduced pumps to 550 gpm 1565 06:30 07:45 1.25 903 2,514 SURFA( DRILL TRIP P Flow check well, static RIH from 903' to 2,514' - no roblems -fill i e 07:45 08:45 1.00 2,514 2,578 SURFA( DRILL CIRC P Stage pumps up to 700 gpm - Precautionarywash and ream from 2,514' to 2,578' -Circulate and condition mud - 700 gpm / 2150 psi / 60 rpm @ 7000 ft/Ibs -Flow check well, static 08:45 12:00 3.25 2,578 68 SURFA( DRILL TRIP P Blow down top drive -POOH on TT from 2,578' to 68' -stood back hwd & NMFC's -hole appears in good condition 12:00 14:00 2.00 68 0 SURFA( DRILL PULD P Down load MWD- LD - TM HOC, DM HOC, HCIM, IBS - FS, Bit & Motor - cleartools from floor 14:00 15:15 1.25 0 0 SURFA( CASING RURD P RU to run 10 3/4" casing 15:15 15:30 0.25 0 0 SURFA( CASING SFTY P Held Prejob Safety and Opts meeting with crew ?age ~ of 'I6 `~ Time Lo s Date From To Dur S. De th E. D th Ph e Code Subcode T Comment 15:30 19:00 3.50 0 1,667 SURFA( CASING RNCS P Ran 10-3/4" 45.5# L-80 BTCM casing as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Halliburton super seal 11) - 1 jt csg all connections made up w/ BakerLoc -filled pipe & checked floats) RIH with 38 jts csg (41 jts total to 1,667' 19:00 19:30 0.50 1,667 1,667 SURFA( CASING CIRC P Est. circ and circ btms up staging pump up to 5 BPM at 250 psi - PU wt 145 SO wt. 125k 19:30 21:00 1.50 1,667 2,568 SURFA( CASING RNCS P Cont. to run 10-3/4" 45.5# L-80 BTCM f/ 1,667, made up FMC hanger and landed csg with shoe at 2,567.7' and flt collar at 2,482.8'. Ran 62 jts csg with flt equip and hanger 2,531.56'. St wt up 185K, do wt140K. 21:00 21:30 0.50 2,568 2,568 SURFA( CEMEN' RURD P RD Franks fill up tool and MU Dowell cement head. 21:30 23:45 2.25 2,568 2,568 SURFA( CEMEN" CIRC P Circ and cond. mud for cementing staged pump rate up from 2.25 bpm at 170 psi to 6.5 bpm at 270 psi, st wt up 185K, do wt 150K. Conditioned mud from 10.0 ppg to 9.8 ppg with less than 20 YP. Reciprocated pipe with full returns. 23:45 00:00 0.25 2,568 2,568 SURFA( CEMEN" SFTY P Held PJSM with rig crew, Dowell and vac truck drivers on cement 'ob. 6/06/2008 Cemented 10 3/4" csg w/149 bbls of cmt back at surface, tested csg to 3, 000 psi f/30 min, MU FMC wellhead, NU & tested ROPE 250/2,500/ 3,500 psi. Chuck Scheve w/AOGCC waived witnessing of the test. Stood back 5" DP, MU 9 7/8" BHA #4 &RIH. Drilled out shoe track & 20' of new formation to 2,598', Circ clean & RU to erfom LOT. f'aye4czf16 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 02:30 2.50 2,568 2,568 SURFA( CEMEN- DISP P Cemented 10 3/4" casing as follows: Pumped 50 bbls of 9.8 ppg mud with nut plug marker followed with 40 bbls of Biozan as pre flush w/ nut plug marker -Switch over to Dowell - Pumped 3 bbls of FW -tested lines to 3,000 psi -Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer @ 6 BPM @ 180 psi -Mixed & pumped 333 bbls (404 sxs) 10.7 ppg Lead slurry at 4.63 yield (ASL) @ 7.5 BPM / 220-175 psi -Observed nut plug marker @ shakers w/ 323 bbls lead slurry pumped - (pumped down surge can 333 bbls total) Switched to tail slurry -Mixed & pumped 58 bbls (275 sxs) 15.8 ppg lead slurry at 1.17 yield (Class G w/ additives) @ 5.5 BPM @ 175 psi -Dropped top plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cement w/ 218 bbls 9.8 ppg mud @ 7 BPM / 310 to 680 psi slowed pump to 4 BPM / 540 psi (for the last 10 bbls of displacement) Bumped plug to 1,050 psi -Check floats OK - CIP @ 02:20 hrs. -Full circulation hrou hout 'ob w/ 149 bbls 10.7 cement returns to surface - reci rotated i e while cementin and sto ed after um in 45 bbls into tail cmt a rox 132 bbls lead out of the shoe -hole was getting sticky and lost 25K SOW -landed casin for remainder of 'ob. 02:30 03:15 0.75 2,568 2,568 SURFA( CASING DHEQ P RU and test 10 3/4" casing to 3000 si for 30 minutes - RD & blow down lines 03:15 04:45 1.50 2,568 2,568 SURFA( CASING RURD P LD -cement head & landing joint - RD casing elevators and bails, LD mousehole and surface riser 04:45 05:30 0.75 2,568 2,568 SURFA( WELCTL NUND P Removed FMC speed head from conductor- Install FMC Unibody wellhead -test M/M seal to 1,000 psi for 5 minutes 05:30 07:30 2.00 2,568 2,568 SURFA( WELCTL NUND P NU BOPE stack -riser & flowline 07:30 12:30 5.00 SURFA( WELCTL BOPE P T tested rams, valves and manifold to 250 psi low and 3,500 psi high, tested annular to 250/2,500 psi. Performed Koomey test and used 5" test jt. no problems. NOTE: Chuck Scheve with AOGCC waived witnessin of test. 12:30 13:00 0.50 SURFA( DRILL PULD P Installed wear bushing 13:00 13:15 0.25 SURFA( DRILL RURD P RU short bales and elevators ~~® Page 5 of 16 Time Lo s D e From To Dur 5. De th E. De th Phase Code Subcode T Comment 13:15 14:30 1.25 SURFA( DRILL PULD P PJSM, PU and stood back 11 stds of 5" DP 14:30 17:30 3.00 0 733 SURFA( DRILL PULD P MU 9 7/8" BHA #4 RIH to 733'. MU 9 7!8" bit on motor with 1.5 deg. bend and MWD, oriented and uploaded same, RIH with HWDP and 'ars to 733'. Shallow tested MWD. 17:30 19:15 1.75 733 2,250 SURFAC DRILL PULD P RIH with BHA #4 PU 5" DP, singled in DP from 733' to 2,250' 16 stds 19:15 20:45 1.50 2,250 2,250 SURFA( RIGMNT SVRG P PJSM, slip and cut 60' of drlg line and serviced to drive. 20:45 21:15 0.50 2,250 2,472 SURFAf DRILL TRIP P RIH from 2,250 to 2,446', washed down and tagged cmt at 2,472', (FC 2 483' 21:15 22:45 1.50 2,472 2,578 SURFAC CEMEN' COCF P Drilled out plugs, flt collar, shoe track and shoe at 2,568' then cleaned out to TD at 2,578'. Drilled out with 5K wob, 40 r m's, 500 mat 1,420 si. 22:45 23:15 0.50 2,578 2,598 SURFA( DRILL DDRL P Drilled 20' of new hole for LOT. drilled to 2 598' MD/2 396' TVD ADT .33 hrs, 5-10K wob, 60 rpm's, 550 gpm, 1,720 psi, off btm torque 9K ft-Ibs, on btm 9K, rot wt 140K, up wt 160K, do wt 126K. 23:15 23:45 0.50 2,598 2,598 SURFAC DRILL CIRC P Circ hole clean for LOT, circ hole evening MW in and out at 9.6 ppg, circ at 550 gpm, 1,640 psi and 50 m's. 23:45 00:00 0.25 2,598 2,598 SURFAC DRILL RURD P RU to perform LOT 6/07/2008 Performed LOT to 17.7 ppg EMW then drilled 9 718" hole with motor from 2,598' to 4,341'. 00:00 00:30 0.50 2,598 2,598 SURFA( DRILL LOT P Performed LOT to 17.7 ppg EMW, 1 000 psi at 2 371' TVD with 9.6 ppQ MW. 00:30 12:00 11.50 2,598 3,507 INTRM1 DRILL DDRL P Displaced hole over to 9.6 ppg LSND mud while drilling 9 7/8" hole with motor from 2,598' to 3,507' MD/ 3,166' TVD (909') ADT 6.25 hrs, ART 6.25 hrs, AST -0-. 10-15K wob, 80 rpm's, 725 gpm at 2,140 psi, off btm torque 8,500 ft-Ibs, on btm 9,500 ft-Ibs. Rot wt 155K, up wt 164K, do wt 140K, 9.6 ppg MW, ave ECD 10.15 ppg. Pumping hi vis sweeps eve 300' with ood results. 12:00 00:00 12.00 3,507 4,341 INTRM1 DRILL DDRL P Drilled 9 7/8" hole with motor from 3,507' to 4,341' MD/ 3,846' TVD (834 ') ADT 7.85 hrs, ART 2.98 hrs, AST 4.87 hrs. 15-30K wob, 80 rpm's, 725 gpm at 2,400 psi, off btm torque 9,500 ft-Ibs, on btm 10,000 ft-Ibs. Rot wt 166K, up wt 175K, do wt 149K, 9.6 MW, ave ECD 10.5 r=~~,e s ~~ 16 ~ ~ Time Logs Da e From To Dur 5 Depth E. Depth Ph~,~,e Code Subcode T Comment 6/08/2008 z4 hr summary Drilled 9 7/8" hole with motor from 4 341' to 5 052' cs t. Circ clean, Wiped hole to 3,961' then RIH to btm w/no problems. Circ hole clean, POOH spotting Well Bore stability pill to 4,626', cont. to POOH on trip tank to shoe, monitored well-static, cont. to POOH & hole began to swab inside csg, CBU, cont. to pull & swab, um ed out of hole to HWDP 732'. 00:00 11:30 11.50 4,341 5,052 INTRM1 DRILL DDRL P Drilled 9 7/8" hole with motor from 4,341' to 5,052' MD/ 4082' TVD ADT 6.66 hrs, ART 1.62 hrs, AST 5.04 hrs. 15-25K wob, 80 rpm's, 725 gpm at 2,510 psi, PUW 172K SOW 142K Rt.Wt. 157K Torque on/off Btm 10,500 / 95000 ft-Ibs ECD 10.9 11:30 13:00 1.50 5,052 4,911 INTRM1 DRILL CIRC P CBU - 750 gpm / 2560 psi / 80 rpm - set back one stand to 5006' - Pumped 40 bbls high vis sweep - circulate sweep around - 750 gpm / 2560 psi / 80 rpm -set back one stand to 4911' -flow check well, static 13:00 14:45 1.75 4,911 3,961 INTRM1 DRILL TRIP P Wipe hole from 4,911' to 3961' - 650 gpm / 1950 psi ! 80 rpm - no roblems -flow check well, static 14:45 15:15 0.50 3,961 5,052 INTRM1 DRILL TRIP P RIH from 3,961' to 5052' - no roblems 15:15 16:45 1.50 5,052 5,052 INTRM1 DRILL CIRC P CBU - 750 gpm / 2570 psi / 80 rpm - set back 1 stand to 5,006' -pumped 40 bbls hi vis sweep around - 750 gpm / 2570 psi / 80 rpm -flow check well, static -pumped 50 bbls of WBS ill and dis lace to bit - RIH to 5052' 16:45 17:30 0.75 5,052 4,531 INTRM1 DRILL TRIP P Pump out from 5,052' to 4,531' spotting pill into open hole -flow check well, static 17:30 19:45 2.25 4,531 2,567 INTRM1 DRILL TRIP P POOH wet on the trip tank from 4,531' to 2,567' w/no problems, monitored well at the shoe-static. 19:45 20:00 0.25 2,567 2,345 INTRM2 DRILL TRIP P POOH from 2,567' to 2,345', observed 15-20K overpull and well swabbin . 20:00 20:30 0.50 2,345 2,345 INTRM2 DRILL CIRC P Circ btms up at 550 gpm, 1,350 psi and 40 r m's. 20:30 21:30 1.00 2,345 2,060 INTRM2 DRILL TRIP P POOH slow from 2,345' to 1,979' and cont. to see drag and not taking ro er hole fill, RIH to 2,060'. 21:30 00:00 2.50 2,060 732 INTRM2 DRILL TRIP P Cont. to pump out of hole at 3 bpm 210 psi from 2,060' to 1,108', attempted to pull on elevators and cont. to swab, cont. to pump out to the HWDP at 732'. 6/09/2008 Fin. pumping out & POOH LD BHA #4, C/O rams over to 7 5/8" csg & tested same to 250/3,500 psi, RU & RIH w/7 5/8" csg landing same @ 5,042' w/no problems. Circ & cond. mud then cemented csg w/full returns & reciprocation, no problems, est. TOC @ 4,150'. Installed 7 5/8" packoff & tested same to 5,000 psi for 10 min. Chan ed rams back over to VBR's. Paya ~ of'15 • • Time Logs Da e From To Dur S. De th E. D th Phase Code Suhco T Comment 00:00 01:00 1.00 732 177 INTRM2 DRILL TRIP P Monitored well at HWDP, pumped out of hole to 269' then stood back std of HWDP and 'ars to 177'. 01:00 04:15 3.25 177 0 INTRM2 DRILL PULD P LD NMFDC's and downloaded MWD, fin. LD BHA #4 and cleared ri floor. 04:15 04:30 0.25 0 0 INTRM2 DRILL PULD P Pulled wear bushing 04:30 07:00 2.50 0 0 INTRM2 CASING NUND P Changed out top set of pipe rams to 7 5/8" cs and tested same to 250/3,500 psi.. Sim-op: Changed out to drive saver sub to 4" XT-39. 07:00 07:15 0.25 0 0 INTRM2 CASING OTHR P Installed thin walled wear bushing. 07:15 08:30 1.25 0 0 INTRM2 CASING RURD P RU to run 7 5/8" csg with Franks fill u tool. 08:30 08:45 0.25 0 0 INTRM2 CASING SFTY P Held PJSM with crew on running casin . 08:45 13:30 4.75 0 3,104 INTRM2 CASING RNCS P Ran 7 5/8" 29.7# L-80 BTCM casin as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Halliburton super seal II) - 1 jt csg all connections made up w/ BakerLoc -filled pipe & checked floats) RIH with 69 jts csg (72 jts total to 3,104'. 13:30 14:15 0.75 3,104 3,104 INTRM2 CASING CIRC P Circ btms up while staging pump rate up to 7 BPM at 620 psi. PU wt 154 SO wt. 133. 14:15 16:45 2.50 3,104 5,042 INTRM2 CASING RNCS P Cont. RIH with 7 5/8" csg from 3,104', MU FMC hanger and landed csg at 5,041.74' and flt collar at 4,953' with no problems. PU wt 215K, SO wt 148K. Ran a total of 116 jts of 7 5/8", 29.7#, L-80, BTCM csg, total including float equip and hanger 5,007.89'. Ran 43 straight blade cent. er well Ian. 16:45 17:15 0.50 5,042 5,042 INTRM2 CEMEN" RURD P RD Franks fill up tool and MU Dowell cement head. 17:15 18:45 1.50 5,042 5,042 INTRM2 CEMEN' CIRC P Circ and cond. mud for cementing, staged pump rate up from 2 bpm at 260 psi to 7 bpm at 490 psi, cond. mud to 10.1 ppg in and out, held PJSM while circ hole, PU wt 200K, SO wt 150K . Page 8 c}` ~ 5 • • Time Logs D e From To Dur S. De th E. De th Phase Code Subcode T Comment ~ 18:45 20:15 1.50 5,042 5,042 INTRM2 CEMEN" DISP P Cemented casing as follows, pumped 5 bbls CW 100, pressure tested lines to 3,700 psi, fin. pumping 25 bbls (30 total) of CW 100 at 8.3 ppg, ave 2.75 bpm at 225 psi., then pumped 30 bbls of MudPush at 12.5 ppg, ave. 5 bpm and 325 psi. Dropped btm plug. Mixed and pumped 53.8 bbls (256 sxs) of class "G" tail cmt at 15.8 ppg and 1.17 yield including additives, ave 5.5 bpm at 225 psi. Dropped top plug and Dowell pumped 20 bbls water then turned over to the rig and rig fin. displacing cmt with 207 bbls of 10.1 ppg LSND mud, ave. 7 bpm, ICP 250 psi, max press. 600 psi, with 10 bbls to o stopped reciprocatin i and slowed to 3.5 bpm at 390 psi. Bumped plug to 1,200 psi. CIP 20:02 hrs. Reciprocated pipe and had full returns thru out 'ob, checked floats and held. Calc TOC 4 150'. 20:15 21:00 0.75 5,042 5,042 INTRM2 CASING DHEQ P RU and tested casin to 3 500 si for 30 min. 21:00 21:45 0.75 5,042 5,042 INTRM2 CASING RURD P RD cmt head, landing jt and long bales. 21:45 22:45 1.00 5,042 5,042 INTRM2 CASING OTHR P Pulled thin walled wear bushing and installed 7 5/8" packoff, tested same to 5,000 si for 10 min. 22:45 23:45 1.00 5,042 5,042 INTRM2 CASING NUND P PJSM, changed out top set of rams back to 3 ?" x 6" VBR's, set Sperry's Geo Span on rig floor and installed short bales. 23:45 00:00 0.25 5,042 5,042 INTRM2 WELCTL OTHR P Installed test plug and filled stack. 6/10/2008 Tested VBR's with 3 1/2", 4" & 4 1/2" test jts to 250/3,500 psi then LD 17 stds excess 5" DP. MU 6 3/4" Geopilot BHA #5, had to trouble shoot MWD problem then fin MU BHA w/RA sources. Singled in w/81 jts DP out of the shed then RIH tagging cmt at 4,911'. Drilled out cmt, flt collar, shoe track & 20' of new hole to 5,072', circ clean, RU & performed FIT to 12.0 ppg EMW. Held PJSM then began to displace hole over to 9.9 MOBM 00:00 01:15 1.25 5,042 5,042 INTRM2 WELCTL EQRP P Test top VBR w/ 3 1/2", 4" & 4 1/2" ttest 'ts to 250 & 3500 si 01:15 04:45 3.50 5,042 5,042 INTRM2 DRILL PULD P Change out 2 jts HWDP (for inspection) - LD jars & excess 5" DP 17 stds Ru fo 4" DP 04:45 08:15 3.50 5,042 5,042 INTRM2 DRILL PULD P MU BHA #5 - Pu Geo-plilot - MU bit - PU GP flex jt., Stab, MWD, Float sub, 1 NM flex DC & XO - MU Top drive - ressure test Geo-S an 08:15 11:45 3.50 5,042 5,042 INTRM2 DRILL OTHR T Plug in to initialize tools -unable to initialize MWD -trouble shoot - LD float sub, Change out battery in GP flex jt.- MU tools -initialize MWD- OK 11:45 12:30 0.75. 5,042 5,042 INTRM2 DRILL OTHR P MU XO - MU TD shallow pulse test tools 6 bbls/min 880 si i?a~r 9 ;`'6 f ~ Time Logs D e From To Dur S De th E. De th Phase Code Subcode T Comment 12:30 13:00 0.50 0 394 INTRM2 DRILL PULD P PJSM -Load RA sources into MWD - PU MN flex DC's (3) -RIH w! BHA # 5 w/ HWDP & 'ars to 394' 13:00 13:15 0.25 394 394 INTRM2 DRILL OTHR P RU for 4" DP 13:15 15:00 1.75 394 2,965 INTRM2 DRILL TRIP P RIH w/ BHA #5 -picking up 81 jts 4" D from i e shed RIH to 2,965' 15:00 16:15 1.25 2,965 4,808 INTRM2 DRILL TRIP P Cont. RIH with stands to 4,808' and to ed a cement strip er. 16:15 17:00 0.75 4,808 4,911 INTRM2 DRILL CIRC P Washed down from 4,808' and to ed cement at 4 911' FC 4 953' .250 gpm, 1,280 psi and 60 r m's. 17:00 20:15 3.25 4,911 5,052 INTRM2 CEMEN" DRLG P Drilled out cement, plugs, flt collar at 4,953', shoe track and shoe at 5,042' then cleaned out to TD at 5,052', 3-8K wob, 50 rpm's, 250 gpm 1,370 psi, torque off btm 9K ft-Ibs, on btm 9K, rot wt 138K, up wt 165K, SO wt 121 K. 20:15 21:00 0.75 5,052 5,072 INTRM2 DRILL DRLG P Drilled 20' of new hole for FIT to 5,072' MD/4,086' TVD, ADT .44 hrs 21:00 21:45 0.75 5,072 5,072 INTRM2 DRILL CIRC P Circ hole clean for FIT, circ at 250 gpm, 1,270 psi, 50 rpm's with 10.0 MW in and out. 21:45 22:30 0.75 5,072 5,072 INTRM2 DRILL LOT P RU and erformed an FIT to 12.0 ppg EMW, 425 psi, with 10.0 ppg MW at 4 082' TVD 22:30 23:00 0.50 5,072 5,072 PROD1 DRILL SFTY P Held PJSM with rig crew, MI and vac truck drivers on displacing hole over to MOBM, discussed potential hazards and otential roblems. 23:00 00:00 1.00 5,072 5,072 PROD1 DRILL CIRC P Began to displace hole over from 10.0 ppg LSND mud to 9.9 ppg MOBM, circ at 250 gpm, 1,660 psi and 50 r m's. 6/11 /2008 Drilled 6 3/4" hole with Geopilot from 5,072' to 7,014'. 00:00 00:30 0.50 5,072 5,072 PROD1 DRILL OTHR P Monitor well (static) Clean up under shaker after change over to OBM - Set up surface equipment for OBM - Obtain SPR & clean hole ECD @ 10.5 00:30 12:00 11.50 5,072 6,028 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section with Geopilot from 5,072' to 6,028' MD/4,079' TVD (956') ADT 7.23 hrs, 10-13K wob, 115 rpm's, 300 gpm, 2,850 psi, off btm torque 6,500 ft-Ibs, on btm 8,000 ft-Ibs, rot wt 135K, up wt 155K, so wt 116K. 10.1 ppg MW, ECD 11.15 Page Vii; ~:.v Time Logs Da. e From To Dur S. De th E. D th Ph e Code Subcode T Comment 12:00 00:00 12.00 6,028 7,014 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section with Geopilot from 6,028' to 7,014' MD/4,088' ND (986') ADT 7.85 hrs, 8-10K wob, 120 rpm's, 300 gpm, 3,190 psi, MW up to 10.55 ppg with 11.76 ppg ECD, slowed pump to 290 gpm, 2,910 psi with 11.68 ppg ECD. Off btm torque 6,500 ft-Ibs, on btm 8,000 ft-Ibs, rot wt 138K, up wt 160K, so wt 114K. Centrifuge down, began adding new 9.3 ppg mud to system at 23:00 hrs to lower MW. 6/12/2008 Drilled 6 3/4" hole with Geopilot from 7,014' to 8,959'. Began to see mud losses ave15-20 BPH and well breathin on connections. 00:00 12:00 12.00 7,014 8,020 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section w/ GP f/ 7014' to 8020' MD 4076' ND Footage - 1006' ATD 7.67 hrs. MW 10.2 ppg ECD- 11.49 ppg RPM 115 WOB 10/13 k GPM 300 @ 3210 psi String wt. PU 169 SO 111 Rot 125 Torque on/off btm,. - 9,000/7,000 fUlbs. Note. Sawco centifuge went down @ 0600 hrs acked-o 12:00 16:00 4.00 8,020 8,385 PROD1 DRILL DDRL P Drilled 6 3/4" hole with Geopilot from 8,020' to 8,385' MD/ 4,073' ND 365') ADT 2.87 hrs, 5-15K wob, 120 rpm's, 300 gpm at 3,190 psi, 10.2 MW, 11.4 ECD. Began to see mud loss 20-40 b hand well breathin on connections. 16:00 16:30 0.50 8,385 8,385 PROD1 DRILL OWFF P Monitored breathing and after 23 minutes well slowed to slight flow. Pum ed 40 bbl, 36 b LCM ill. 16:30 00:00 7.50 8,385 8,959 PROD1 DRILL DDRL P Drilled 6 3/4" hole with Geopilot from 8,385' to 8,959' MD/ 4,076' ND 574') ADT 4.87 hrs, 8-15K wob, 120 rpm's, 260-276 gpm at 2,700-2,875 psi, off btm torque 7,500 ft-Ibs, on btm 8,500 ft-Ibs, rot wt 137K, up wt 166K, so wt 109K, 10.0 MW, ECD ave 11.25. Ave 10-15 bph losses, last 12 hrs lost 179 bbls adding 4-6 sxs of Dyna Red fiber per hr. well cont. to breath on Conn but at a slower rate than earlier, centrifuge back on line at 13:00 hrs. . 6/13/2008 Drilled 6 3/4" hole with Geopilot from 8,959' to 10,462'. Cont. to drill with losses and well breathing. P; -11ot~~, ~ ~ Time Logs Da e From To Dur S. De th E. De th Pha e Code Subcode T Comm nt 00:00 12:00 12.00 8,959 9,820 PROD1 DRILL DDRL P Drilled 6 3/4" horizontal section f/ 8959' to 9820' MD 4080° ND Footage - 861' ADT - 8.37 hrs. ECD - 11.37 ppg RPM -115 WOB 10/15 k GPM 250 @ 2730 psi String wt. @ 9820' PU 178 SO 98 Rot 135 Troque on/off btm. -10,000/8,000 ft/Ibs. Note: Monitored well @ connection @ 9724' & observed flow drop f/ 27% to 0% flow in 18 mins. __~ Well taking fluid @ 35 bbls/hr & breathing on connections Lost 252 bbls 10.0 OBW last 12: hrs. 12:00 20:00 8.00 9,820 10,298 PROD1 DRILL DDRL P Drilled 6 3/4' horizontal section from 9,820' to 10,298' MD/4,089' ND 478' ADT 5.17 hrs 20:00 21:00 1.00 10,298 10,298 PROD1 DRILL OWFF P Monitored well, took 55 min for well to go from 25% to 0% flow. Gained 57 bbls, After 5 min flow rate was 3.4 bpm, after 30 min, .4 bpm and after 1 hr and showing 0% flow had .2 bpm gain last 5 min. Last 15 min ave .2 b m. 21:00 00:00 3.00 10,298 10,462 PROD1 DRILL DRLG P Drilled 6 3/4" horizontal section from 10,298' to 10,462' MD/4,087' ND (164') ADT 1.63 hrs, 8-12K wob, 120 rpm's, 250 gpm, 2,810 psi, off btm torque 7,500 ft-Ibs, on btm 9,500 ft-Ibs, rot wt 137K, up wt 174K, do wt 100K, 10.0 ppg MW, ave ECD 11.2 ppg, cont. to ave 30-50 bph mud losses. Lost 366 bbls OBM last 12 hrs. 618 bbls last 24 hrs. 797 bbls total OBM lost to hole. 6/14/2008 Drilled 6 3/4" hole with Geopilot from 10,462' to 10,776', Drilled with 80-120 bbl losses per std, well would breath back 70-90 bbls circ 2X btms up to clean up well. Monitored well 90 min, flow dropping off. Pumped out of hole from 10,776' to 4,866' no problems (shoe @ 5,042') Monitoring well, gained 10 bbls in 1 hr and flow dropping off. (Well static @ 00:35 hrs) NOTE: Decision was made to call TD on well due to losses and low volume of LVT 200 available. --- _ f'a~?~ 1~ cif 16 , • i Time Logs Date From To Dur S. De th E. De th Phase Code Suhcode T Comment 00:00 04:45 4.75 10,462 10,776 PROD1 DRILL DDRL P r / 10 776' MD 4088' P f/ 10 462' t , o . . S TVD Footage - 314' ADT - 2.78 hrs. ECD -11.31 ppg RPM 120 WOB 10/13 k GPM 250 @ 2760 psi String wt. PU 171 SO 106 Rot 138 Torque on/off btm. - 9500/8,000 ft/Ibs. Hole still takin fluid & breathin on "Note string wt values taken after circ 2x btms up -prior connection PU 188 SO 80 Rot 137 04:45 10:00 5.25 10,776 10,776 PROD1 DRILL CIRC P Circ 2 X btms up @ 4 bbls/min @ 1430 psi w/ 120 RPM's to attempt to reduce PU & SO wts. Continue to circ & blend in new load of OBM -Obtain survey & SPR's * Note: Conferred with Anchorage office on OBM volume & hole conditions - Discision made to call TD Cad 10.776' due to heavy muiT losses & low volume of LVT-200 to M 10:00 11:30 1.50 10,776 10,776 PROD1 DRILL OWFF P Monitor well for 90 mins.for breathing -gained 41 bbls in 1 hr. -Rate slowed to 1/2 bbl in 5 mins Lost 226 bbls OBM to formation last 12 hr 11:30 21:30 10.00 10,776 4,866 PROD1 DRILL TRIP P POOH w/pump @ 3.5 bblslmin 820 psi w/ 100 rpm's f/ 10776' to 4,866' (shoe @ 5,042'). Monitored well at shoe and well was static. 21:30 23:00 1.50 4,866 4,866 PROD1 DRILL CIRC P Circ 2X btms up and was clean at the shakers, circ hole at 4 bpm, 1,010 psi and 90 rpm's. 10.2 ppg MW in and out. 23:00 00:00 1.00 4,866 4,866 PROD1 DRILL OWFF P Monitoring well, gained 10 bbls in 1 hr, last 10 mins only gained .5 bbl, flow decreasing. NOTE, Last 12 hrs gained 13 bbls pumping out for a net loss of 213 bbls to hole last 24 hrs. Total lost as of 24:00 hrs 6/14/08 is 1,010 bbls 6/15/2008 Fin. monitoring well, well static for 25 min. POOH on trip tank then LD BHA #5, RU to run 31/2" liner, held PJSM then RIH w/3 1/2" liner per well plan to 5,763' when pin from air slips fell down hole. POOH 5,046' & attem ted to retrieve in from below wear bushin & 7 5/8" ackoff. Note recovered in 02:30 hrs 00:00 01:00 1.00 4,866 4,866 PROD1 DRILL OTHR P Continue to monitor well -gained .7 bbls last 35 mins.Well static - monitored for 25 mins Static 01:00 05:45 4.75 4,866 394 PROD1 DRILL TRIP P Blow down TD -Drop 2" hollow drift - POOH on TTf/ 4866' to 394' (BHA) recover drift -flow ck well static --- Page 13 of , p Time Lo s Da From To Dur S De th E. De th Ph se Code Subcode T Comm nt 05:45 06:30 0.75 394 144 PROD1 DRILL PULD P LD 2 jts HWDP & jars -Std back 1 std HWDP - LD 2 NM Flex DC's 06:30 07:00 0.50 144 114 PROD1 DRILL OTHR P PJSM on removing RA sources - Remove RA soucres f/ MWD tool 07:00 07:15 0.25 114 83 PROD1 DRILL OTHR P LD last NM flex DC - MU 7 toruge lifter -Pull up & plug into MWD to down-load 07:15 09:30 2.25 83 83 PROD1 DRILL OTHR P Download MWD - Simops -Pull up & service GeoPilot -Break bit 09:30 10:15 0.75 83 0 PROD1 DRILL PULD P LD MWD & Geopilot -Clean up rig floor -Static losses 1/2 bbl/hr - Calc. fill on trip out f/shoe 34 bbls, Actual fill 42 bbls. 10:15 10:45 0.50 0 0 COMPZ RPCOM RURD P Rig up to run 3 1/2" liner 10:45 11:00 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM on running liner w/ crew - Covered recent hand injury with ton s 11:00 17:00 6.00 0 5,763 COMPZ RPCOM RCST P Ran 3 1/2" 9.3# L-80 SLHT blank/slotted liner as per liner detail with 185 'ts of liner to 5 763" when a in from the air sli s fell down hole. 17:00 18:00 1.00 5,763 5,763 COMPZ RPCOM OTHR T Drained stack and attempt to locate pin, pin possibly on top of top constrictor. 18:00 20:30 2.50 5,763 5,046 COMPZ RPCOM TRIP T POOH from 5,763' to 5,046', string hung up a couple of times and worked free. 20:30 00:00 3.50 5,046 5,046 COMPZ RPCOM OTHR T Attempt to retrieve pin below wear bushin and 7 5/8" ack-off. 6/16/2008 Recovered pin from air slips. Cont. to RIH w/3 1/2" liner tagging btm, PU and set liner with TOL @ 4,866' & shoe @ 10,766' (no problems) CBU then POOH LD running tool. RU & ran 3 1/2" completion per welt plan to 2,709'. 00:00 02:45 2.75 5,046 5,046 PROD1 RPCOM OTHR T Retrieved pin from air slips. (used a ma net on the T-bar 02:45 03:15 0.50 5,046 5,763 PROD1 RPCOM TRIP T Ran back in hole with 3 1/2" liner to 5,763' 03:15 05:00 1.75 5,763 5,900 COMPZ RPCOM PULD P RIH 2 jts of 3 1/2" liner to 5,857' then MU Baker 5 1/2" x 7 5/8" Flex Lock hanger assembly RIH to 5,900'. Mixed Pall mix and placed it in debris barrier. St wt up 110K, do wt 100K. 05:00 05:30 0.50 5,900 5,931 COMPZ RPCOM OTHR P MU single on liner and est circ at 3.5 bpm at 300 psi, est rotation at 20-30 rpm's at 4K ft-Ibs torque per T & D en .Blew down to drive. 05:30 10:30 5.00 5,931 10,766 COMPZ RPCOM RCST P Cont. to RIH with 3 1/2" liner per plan and tagged btm, PU liner shoe 10' off btm at 10,766' and dropped 29/32" . ball. i~ae i~t of 16 • Time logs Date From To Dur S De th E. D th Ph e Code Subcode T Comment 10:30 11:00 0.50 10,766 4,875 COMPZ RPCOM HOSO P Pumped ball down to seat at 2 bpm and set hanger per Baker rep. No problems, PU st wt up 145K. Set TOL 4 865.52' with shoe at 10,766', Ran 54 blank jts, 1,683.62' of 3 1/2", 9.3#, L-80 SLHT liner and 134 slotted jts, 4,170.17', 9.3#, L-80 SLHT liner. 11:00 12:00 1.00 4,875 4,833 COMPZ RPCOM CIRC P PU out of TOL to 4,833' and circ btms u at 3 b mat 230 si. 12:00 12:30 0.50 4,833 4,833 COMPZ RPCOM OWFF P Monitored well-static, blew down top drive. 12:30 17:15 4.75 4,833 0 COMPZ RPCOM TRIP P POOH from 4,833' to 1,026', monitored well-static, cont. to POOH and LD Baker running tool. Calc fill on tri out 31 bbls, Actual fill 39 bbls. 17:15 17:45 0.50 0 0 COMPZ RPCOM PULD P Pulled wear bushing and installed tbg runin wear bushin for com letion. 17:45 18:15 0.50 0 0 COMPZ RPCOM RURD P RU to run 3 1/2" completion. 18:15 18:30 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM on running 3 1/2" completion detail and associated hazards. 18:30 22:30 4.00 0 2,554 COMPZ RPCOM RCST P RIH with 31/2" com letion er detail to 2,554', st wt u 92K, do wt 92K. 22:30 23:30 1.00 2,554 2,580 COMPZ RPCOM PULD P MU Camco 3 1/2" TRMAXX SSSV and control line and tested same. 23:30 00:00 0.50 2,580 2,709 COMPZ RPCOM RCST P Cont. to RIH with 3 1/2" completion to 2,709'. 6/17/2008 Continued to RIH w/ 3 1/2" Completion Tubing; Set Bottom of WLEG @ 4886' MD; No-Go Spaced Out 4.06 Above Liner Hanger @ 4861' MD; Terminated SSSV Control Line Through Hanger; Landed Hanger, Set Two-Way Check Valve & Tested Seals t/ 5,000 Psi; Flushed Stack, Lines, & Choke Manifold then Blew Down Same; Nippled Down BOPE and Nipple Up Tree; Tested Tree to 5,000 Psi; M/U FMC Lubricator and Pulled Two-Way Check Valve; Displaced Well Bore with 30 Bbls of Mineral Oil and 177 Bbls of Diesel; Dropped Rod & Ball Assy.; Set Packer w/ 4,500 Psi on Tubing; Then Tested Annulus -- Lost 200 Psi Over 30 minutes During Annulus Test; Tested Annulus Again Twice with Same Results; Pressured Both Tubing and Annulus to 3,500 Psi -- No Pressure Loss Observed During 30 Minute Test (Good); Bled Pressrue f/ Tubing and Sheared GLM SOV Open; Bled Remaining Tubing and Annulus Pressure to 400 Psi and Set BPV; Began La in Down 4' DP from Derrick and Cleanin Mud Pits of OBM 00:00 02:45 2.75 2,709 4,740 COMPZ RPCOM RCST P Continue RIH vy/ 3 1/2" 9.3# L-80 EUE tb f/ 2709' to 4740' 02:45 04:15 1.50 4,740 4,858 COMPZ RPCOM RCST P MU XO f/ tbg to DP & space out tbg locate liner top w/ shear locator -Std back DP & add space out jt & pup - MUX031/2"x41/2"-PU 2jts4 1/2' 12.6 # IBTM tb - 04:15 04:45 0.50 4,740 4,855 COMPZ RPCOM OTHR P Pull tbg running wear bushing 04:45 05:30 0.75 4,855 4,855 COMPZ RPCOM RCST P PU tbg hanger & terminate control line thru han er & test connection 05:30 07:00 1.50 4,855 4,886 COMPZ RPCOM RCST P Land tb w/ tail .4865.52 - XN nipple @ 4568' -Packer Cad 4461' - GLM w/shear @ 4403' -GLM w/ duimmy @ 3783' -SSSV @ 2324' - Run in lock downs - LD landing jt. - Set TWC - MU landing jt. B -test hanger seals to 5000 psi -land down = landin 't B Page ib of 15 • C~ Time Logs Da e From To Dur S. De th E. De th Phase Code Subcode T Comment 07:00 09:00 2.00 4,886 4,886 COMPZ RPCOM OTHR P MU stack washer -flush stack & flush mud lines -choke & kill lines & blow down lines -while cleaning rig floor 09:00 10:30 1.50 4,886 4,886 COMPZ RPCOM OTHR P NU BOPE - Simops -change junk sub in TD -Ins ect rab dies 10:30 10:45 0.25 4,886 4,886 COMPZ RPCOM OTHR P Terminate control line through wellhead 10:45 12:00 1.25 4,886 0 COMPZ RPCOM NUND P NU & Test Tree t/ 5,000 Psi 12:00 12:45 0.75 0 0 COMPZ RPCOM DHEQ P M/U FMC Lubricator & Pull Two-Wa Check V Iv 12:45 20:00 7.25 0 0 COMPZ RPCOM CIRC P PJSM; R/U f/ Displacement & Test Lines t/ 3,000 Psi; Displace Well Bore w/ 30 Bbl Mineral Oil Followed by 177 Bbls of Diesel; M/U & Drop Ball & Rod; Retest Lines t/ 4,000 Psi; Set Packer and Test Tubing to P i -Lost 200 Psi in 30 Minutes; Tested Annulus t/ 3,500 Psi - Lost 300 Psi in 30 Minutes; Retest Both Sides with Same Results; Pressrued U Tubin and Annulus t/ 3 500 Psi and Tested f/ 30 Minutes - No Pressure Loss Released Pressure and Sheared GLM Valve 20:00 21:15 1.25 0 0 COMPZ RPCOM NUND P M/U & Test Lubricator t/ 1,000 Psi; Set BPV 21:15 21:30 0.25 0 0 COMPZ MOVE SFTY P PJSM on installing Mouse Hole and La in Down DP 21:30 00:00 2.50 0 0 COMPZ MOVE DMOB P Install Mouse Hole and Begin Laying Down 4" DP & Cleanin Pits of OBM 6/18/2008 Finish laying down excess 4" Dp f/ derrick -Pull mouse hole -Finish cleaning pits & drip pans & pipe racks form OBM -Release ri 1200 hrs 00:00 05:00 5.00 0 0 COMPZ RPCOM PULD P Finish laying down excess 4" DP f/ derrick -Pull mouse hole 05:00 12:00 7.00 0 COMPZ RPCOM OTHR P Finish cleaning pits -drip pans -pipe racks ~ rig floor malts f/Oil Base mud Release ri 12:00 hrs Page 16 ~?f'Sfi ~ ~ ~ 1 NS CD2-464 ~W , /~~j~,, ^ r A- - API/UWI FiNd Name ~~ Well Status Max mum lnelination (°) ToU1Depth (RKB) 5010320574 OANNIK PROD 93.43 10776.0 _ Comment H25 (ppm) Date ~Annotati... End Date KB-Ground Distance (R) Rig Release Date w~icw~fW-HOi^~,.v~FL-~~_~. r~ ,-_, -a_ , TRDP ~LastWO: 6/16/2008 43.88 6/18/2008 - ~""" "Y' Anrmtatbn Depth (RKB) End Date Annotation End Date Last Tag: 6/1612008 Rev Reason: PULL BAWROD RHC . GLV C/O 6/21Y2008 ~ Casing Deacrlpdon OD (in) ID (in) Top (RKB) Set Deptn (itK6) Bet Depth (TVD) It6tB) Wt (ItuUR) limde lop t:onneMfc CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 ` ~ Casing Descriptlon OD (in) ID (in) Top (RKB) SN DepM (RKB) SN Depth (ND) (fIKB) Wt ObslR) Grade Top Conneetl< ~ ~~ ~ SURFACE ' 103/4 9.950 0.0 2,567.7 2,371.1 45.50 L-80 BTC-M ~ ' Casing Descriptor OD (in) ID (in) Top (RKB) SN Depth (RKB) SN Depth (TVD) (flKB) Wt QtudR) Orade Top Conneetic - - - - - - - - - - - - - - - INTERMEDIATE 75/8 6.875 0.0 5,041.7 4,082.6 29.70 L-80 BTCM 1 Cuing Description SLOTTED UNER OD (In) ID (in) Top (RKB) SN D pth (RKB) SN Depth (TVD) (RKB) Wt (Ihc/lt) Grade Top Connectic 3 1/2 2.992 4,865 5 10 766 0 4 087 9 9 30 L-80 SLHT ~ R 7 , y ~, r', ~••F - ~ -~~,r,~W~~ CONDUCTOR, 37114-+ z Top (RKB) Clem Ov ID xr Ft on _ ~t ti 3J 4,891.4 Crossover ? 7? - 5 1 /2" L-80 BTC > t i ~ u it ~, [ i D 3. ~ /~ p y s ~ ---r~4-. ra TAT. _ _ I ~e'~, ?.Z . ~~ ~ ~ l Tubing Duwiptbn .... Wtlib nl ~,~d. OC i~~I /D(in) ',Top IRK... tilL,rln ltucel tL»i,m lr~Ui inKBl 7op Connection Tubing- 31/2 2992 31.5 4 i 1~ 11 9 L-80 EUE-M ProduMion sssv.2.32s ~o. w w t ' . T ~ . ' !J Ta ~ : ~ i . ..-.s ~ »,.. . s » n ..s. _ : . ..:. lop (RKB) Item Description Comment ID [ % 31.5 HANGER FMC 4 1/2" Tbg hanger wl2 2T pup 3. f 2,324.8 SSSV 3 1@" Camco TRMAXX-5E SSSV wl 2.813" profile (TC-II B x P)ser # CXS0024 2. { ~ 3,783.9 GAS UF T Camco 3 1/2" x 1" KBMG GLM DMV BK-5 STA 1 2. f '~ 4,403.7 GAS LIFT CamCO 3 1/2" x 1" KBMG GLM w/OV BEK-5 STA 2 2. ~ ~ 4,462.0 PACKER Baker 3.5" x 7 5l8" Premier Packer 6.58" OD x 2.87" ID 2. 4 568 5 NIPPLE 3.5" HES XN Nlpple 3 94" OD x 2 75 ID 2. 1 4 862 5 MULE S HOE Pup - 3 1/7 16T Tu bmg WlMule shoe WLEG 24 49' 2. SURFACE, 0.2,586 ~ ~ w. - .. t f _.. - ° ~ sna calcw._ Btm Top (ND) Btm (TVD) Den Shot Top (RK8) (RKB) (RKB) (RKB) Type Zone Isho... Total Date I Comment GAS LIFT 3 784 5,719.0 5,750.0 4,097.0 4,095.1 Slots 32.0 992 6/16/2008 Akemating solid/slotted liner , , '~ 5,938.0 6,001.0 4,084.3 4,081.1 Slots 32.0 2,016 6/16/2008 Alternating solid/slotted liner 6,095.0 6.906.0 4.077.8 4.080.9 Slots 32.0 25,952 6/16/2008 Alternating solid/slotted liner GAS LIFT, 4,404 PACKER, 4,462 NIPPLE, 4,588 MULE SNOE, 4,663 I ~ .Set DepM ~ - ~ ~ Valve Latch Port TRU RUn 1 /Stn Teo fRKe11ND11RKB1 Make ModN ODf 1 Type TYPe (Size (In) (psi) Run Date Comment tl tl SLOTTED LINER, 4,88&10, 766 TD, 10,778 • ConocoPhillips(Alaska) Inc. Western North Slope CD2 Alpine Pad CD2-464 50-103-20574-00 Definitive Survey Report 18 June, 2008 li " ; $ ~• .. .. Sperry I3rifi[irsg Services ~,~ ~- o~~ ~onocoPhillips or its affiliates • Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD2-464 Project: Western North Slope TVD Reference: CD2-464 @ 52.18ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2-464 @ 52.18ft (Doyon 19) Well: CD2-464 North Reference: True Wellbore: CD2-464 Survey Calculation Method: Minimum Curvature Design: CD2.464 Database: EDM Alssks Prod v96 Project Western North Slope, North Slope Alaska Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor - Well CD2-464 - _ __-_ Well Position +N/-S O.OOft Northing: 5,974,174.42ft Latitude: 70° 20' 15.582 N +E/-W 0.00 ft Easting: 371,409.33 ft Longitude: 151 ° 2' 36.229 VV Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 15.70ft Wellbore CD2-464 __ - - MaOnatlc; M9d61 Name ~am~le DIl1~ ®o611nr~>lan I Atg An~lo Plelrf ~tr~ngf;h 1°) (°) (nT) BGGM2007 6/2!2008 16.97 79.59 57,233 BGGM2007 6/3/2008 16.97 79.59 57,233 Design CD2-464 -_ Audit Notes: Version; 1:0 Pha;e; AGTUAL Tle An BeptHt 3:46 j Vertical Section: Depth From (TVD) +N/-g +E/_yy Direction (ft) 3646 (ft) (ft) 0 00 0 00 (°) . . 168.57 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Descrip tion Survey Date 79.00 357,00 CD2-464 Gyro (CD2-464) GB-GYRO-S$ Camera bawd ~yr0 >;ir>s~la >~hQt 6l~i/2008 12~ 385.97 10,714.38 CD2-464 MWD+SAG+CA+IIFR+MS (CD MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/3/2008 12: -- S u rvey - Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section 1ft) (~) (~) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.48 0.00 0.00 36.48 -15.70 0.00 0.00 5,974,174.42 371,409.33 0.00 0.00 UNDEFWED 79.00 0.20 74.00 79.00 26.82 0.02 0.07 5,974,174.44 371,409.40 0.47 -0.01 CB-GYRO-SS (1) 173.00 0.20 102.00 173.00 120.82 0.03 0.39 5,974,174.44 371,409.72 0.10 0.05 CB-GYRO-SS (1) 264.00 0.20 152.00 264.00 211.82 -0.14 0.62 5,974,174.27 371,409.95 0.19 0.26 CB-GYRO-SS (1) 357.00 1.53 161.50 356.99 304.81 -1.46 1.09 5,974,172.94 371,410.39 1.43 1.65 CB-GYRO-SS (1) 385.97 1.90 166.79 385.94 333.76 -2.30 1.32 5,974,172.10 371,410.61 1.39 2.51 MWD+IFR-AK-CAZ-SC (2) 478.10 3.45 167.27 477.97 425.79 -6.49 2.28 5,974,167.89 371,411.50 1.68 6.81 MWD+IFR-AK-CAZ-SC (2) ~ 567.56 5.45 169.93 567.16 514.98 -13.30 3.62 5,974,161.06 371,412.72 2.25 13.75 MWD+IFR-AK-CAZ-SC (2) 662.39 7.44 166.23 661.38 609.20 -23.70 5.87 5,974,150.63 371,414.79 2.14 24.39 MWD+IFR-AK-CAZ-SC (2) j 753.92 8.95 161.08 751.98 699.80 -36.19 9.59 5,974,138.08 371,418.29 1.83 37.37 MWD+IFR-AK-CAZ-SC (2) ~ 846.53 10.80 157.98 843.21 791.03 -51.05 15,18 5,974,123.12 371,423.63 2.08 53.04 I MWD+IFR-AK-CAZ-SC (2) 941.55 1 13.50 153.53 936.10 883.92 -69.23 23.46 5,974,104.80 371,431.60 3.01 72.51 MWD+IFR-AK-CAZ-SC (2) 6/18/2008 2:48:49PM Page 2 COMPASS 2003.16 Build 42F i ConocoPhillips or its affiliates Defi nitive Survey Report Company: ConocoPhillips(Alaska) I nc. Local Co-ordinate Refe rence: Well CD2-464 Project: Western Nort h Slope TVD Reference: CD2-464 @ 52.18ft (Doyon 19) Site: CD2 Alpine P ad MD Reference: CD2-464 @ 52.18ft (Doyon 19) Well: CD2 -464 North Reference: True Wellbore: CD2 -464 Survey Ca lculation Met hod: Minimum Curvature Design: CD2 -464 Database: EDM Alaska Prod v16 'Survey - _- _ _- -- - - Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section ". (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,036.09 13.95 151.87 1,027.94 975.76 -89.16 33.75 5,974,084.70 371,441.54 0.63 94.08 MWD+IFR-AK-CAZ-SC (2) i 1,131.03 12.21 144.69 1,120.42 1,068.24 -107.45 44.95 5,974,066.23 371,452.43 2.50 114.22 MWD+IFR-AK-CAZ-SC (2) ~ 1,226.30 12.41 140.90 1,213.50 1,161.32 -123.61 57.23 5,974,049.85 371,464.43 0.87 132.50 MWD+IFR-AK-CAZ-SC (2) ~ 1,320.86 15.21 135.11 1,305.32 1,253.14 -140.29 72.40 5,974,032.92 371,479.30 3.30 151.85 MWD+IFR-AK-CAZ-SC (2) 1,390.16 20.96 127.81 1,371.18 1,319.00 -154.34 88.62 5,974,018.59 371,495.28 8.90 168.84 MWD+IFR-AK-CAZ-SC (2) 1,455.15 26.05 120.32 1,430.77 1,378.59 -168.69 110.14 5,974,003.88 371,516.55 9.07 187.17 MWD+IFR-AK-CAZ-SC (2) 1,510.48 27.44 113.39 1,480.19 1,428.01 -179.88 132.34 5,973,992.31 371,538.55 6.17 202.54 MWD+IFR-AK-CAZ-SC (2) 1,562.00 28.64 112.08 1,525.66 1,473.48 -189.24 154.67 5,973,982.57 371,560.72 2.62 216.14 MWD+IFR-AK-CAZ-SC (2) 1,605.58 31.29 109.53 1,563.41 1,511.23 -196.95 175.02 5,973,974.52 371,580.94 6.75 227.73 MWD+IFR-AK-CAZ-SC (2) 1,665.24 30.98 114.40 1,614.49 1,562.31 -208.47 203.60 5,973,962.51 371,609.31 4.25 244.68 MWD+IFR-AK-CAZ-SC (2) 1,701.03 32.51 116.76 1,644.93 1,592.75 -216.60 220.58 5,973,954.08 371,626.14 5.55 256.02 MWD+IFR-AK-CAZ-SC (2) 1,751.82 32.63 119.24 1,687.74 1,635.56 -229.44 244.71 5,973,940,84 371,650.05 2.64 273.38 MWD+IFR-AK-CAZ•SC (2) 1,9Q6.66 93.dd 1;1:96 1,96.29 1,613.07 =~~1.6~ 266:12 6,®73,l~26.16 991,670.64 9.6l~ 26l~.66 MWB*1~~=AK=CAt-~C (~) 1,891.08 32.97 125.29 1,804.34 1,752.16 -270.40 308.85 5,973,898.79 371,713.48 2.09 326.24 MWD+IFR-AK-CAZ-SC (2) 1,985.63 33.74 125.28 1,883.31 1,831.13 -300.43 351.29 5,973,868.04 371,755.39 0.81 364.09 MWD+IFR-AK-CAZ-SC (2) 2,080.93 32.75 125.75 1,963.02 1,910.84 -330.78 393.82 5,973,836.97 371,797.38 1.07 402.26 MWD+IFR-AK-CAZ-SC (2) 2,175.68 33.32 126.25 2,042.45 1,990.27 -361.14 435.60 5,973,805.89 371,838.64 0.67 440.30 MWD+IFR-AK-CAZ-SC (2) 2,271.22 32.52 126.35 2,122.65 2,070.47 -391.88 477.45 5,973,774.45 371,879.95 0.84 478.72 MWD+IFR-AK-CAZ-SG (2) 2,366.20 32.72 125.63 2,202.65 2,150.47 -421.98 518.88 5,973,743.88 371,920.85 0.46 516.42 MWD+IFR-AK-CAZ-SC (2) 2,461.30 33.55 124.23 2,282.28 2,230.10 -451.72 561.50 5,973,713.18 371,962.95 1.19 554.03 MWD+IFR-AK-CAZ-SC (2) 2,523.02 33.43 123.89 2,333.75 2,281.57 -470.79 589.71 5,973,693.62 371,990.83 0.36 578.32 MWD+IFR-AK-CAZ-SC (2) 2,591.39 33.26 123.68 2,390.87 2,338.69 -491.69 620.94 5,973,672.19 372,021.70 0.30 604.99 MWD+IFR-AK-CAZ-SC (2) 2,685.49 33.12 123.82 2,469.62 2,417.44 -520.31 663.78 5,973,642.85 372,064.03 0.17 641.53 MWD+IFR-AK-CAZ-SC (2) 2,781.10 32.65 124.29 2,549.91 2,497.73 -549.38 706.78 5,973,613.05 372,106.53 0.56 678.55 MWD+IFR-AK-CAZ-SC (2) 2,875.75 32.54 124.77 2,629.65 2,577.47 -578.28 748.79 .5,973,583.43 372,148.03 0.30 715.20 MWD+IFR-AK-CAZ-SC (2) 2,972.27 32.45 124.95 2,711.06 2,658.88 -607.92 791.34 5,973,553.07 372,190.06 0.14 752.68 MWD+IFR-AK-CAZ-SC (2) 3,067.33 32.26 124.10 2,791.36 2,739.18 -636.75 833.25 5,973,523.53 372,231.47 0.52 789.25 MWD+IFR-AK-CAZ-SC (2) 3,162.25 32.13 124.45 2,871.69 2,819.51 -665.23 875.04 5,973,494.34 372,272.76 0.24 825.45 MWD+IFR-AK-CAZ-SC (2) 3,257.39 31.79 123.48 2,952.41 2,900.23 -693.37 916.81 5,973,465.49 372,314.04 0.65 861.30 MWD+IFR-AK-CAZ-SC (2) 3,352,43 31.47 123,44 3,033.33 2,981.15 -720.85 958.39 5,973,437.3!] 372,355.14 0.34 896.48 MWD+IFR-AK-CAZ-SC (2) 3,448,39 30.75 124,18 3,)15,47 3 083,8 -748,45 898,81 5,875,408,gQ 373,385.$8 Q,81 @1,74 MINK+IFR-AK•GAZ•SC (2) 3,543.20 30.01 123.82 3,197.24 3,145.06 •775.2$ 1,039.38 5,973,381.49 372,435.18 0.54 965.8$ MWD+IFR-AK-CAZ-SC (2) 3,637.67 30.20 124.71 3,278.97 3,226.79 -801.96 1,078.54 5,973,354.15 372,473.87 0.51 999.79 MWD+IFR-AK-CAZ-SC (2) 3,732.59 31.50 125.80 3,360.46 3,308.28 -830.06 1,118.28 5,973,325.37 372,513.12 1.49 1,035.21 MWD+IFR-AK-CAZ-SC (2) 3,827.25 30.80 125.69 3,441.47 3,389.29 -858.66 1,158.02 5,973,296.09 372,552.36 0.74 1,071.12 MWD+IFR-AK-CAZ-SC (2) 3,922.55 32.31 127.08 3,522.68 3,470.50 -888.26 1,198.16 5,973,265.82 372,591.99 1.76 1,108.08 MWD+IFR-AK-GAZ-SC (2) 3,569.51 32.75 126.45 3,5s2.27 3,510.(79 -503.93 1,218.12 5,919,250.02 372,611.6$ 1.83 1,127.20 MWb+IFa-AK-CA2-5C (2) 4,018.04 34.30 129.66 3,602.73 3,550.55 -920.61 1,238.93 5,973,232.77 372,632.19 3.48 1,147.87 MWD+IFR-AK-CAZ-SC (2) 4,064.47 36.69 132.90 3,640.53 3,588.35 -938,41 1,259,17 5,973,214,63 372,652,12 6,55 1,169,33 MWD+IFR-AK-GAZ-SG (2) 4,112.90 38.97 133.35 3,678.78 3,626.60 -958.71 1,280.84 5,973,193.96 372,673.44 4.74 1,193.53 MWD+IFR-AK-CAZ-SC (2) 6/18/2008 2:4 8:49PM Page 3 COMPASS 2003.16 Build 42F ~onocoPhillips or its affiliates • Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: WeII CD2-464 Project: Western Nort h Slope TVD Reference: CD2-464 @ 52.18ft {Doyon 19) Site: C62 Alpine Pad Mb Reference: C~4-d6d ~ 5~.~8ft (~oyon 19j Well: CD2-464 North Reference: True Wellbore: CD2-464 Survey Calculation Met hod: Minimum C urvature Design: CD2-464 Database: EDM Alaska Prod v16 Survey _ L Map Map Vertl~al MD Inc Azi ND NDSS +N/-S +E/-1N Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) {°/100') (ft) Survey Tool Name 4,151.32 40.12 134.33 3,708.40 3,656.22 -975.66 1,298.48 5,973,176.72 372,690.79 3.41 1,213.63 MWD+IFR-AK-CAZ-SC (2) 4,207.98 d2.69 139.23 3,750.91 3,698.73 -1,002.98 1,324.10 5,973,148.97 372,715.93 7.30 1,2d5.d8 MWD+IFR-AK-CAZ-SC {2) 4,253.53 43.90 141.61 3,784.06 3,731.88 -1,027.05 1,343.99 5,973,124.56 372,735.40 4.46 1,273.02 MWD+IFR-AK-CAZ-SC (2) 4,302.81 47.37 145.05 3,818.52 3,766.34 -1,055.31 1,364.99 5,973,095.94 372,755.92 8.63 1,304.89 MWD+IFR-AK-CAZ-SC (2) 4,348.87 50.30 147.35 3,848.84 3,796.66 -1,084.13 1,384.27 5,973,066.80 372,774.69 7.39 1,336.95 MWD+IFR-AK-CAZ-SC (2) 4,398.03 53.24 150.17 3,879.26 3,827.08 -1,117.15 1,404.27 5,973,033.45 372,794.13 7.49 1,373.28 MWD+IFR-AK-CAZ-SC (2) 4,443.85 5571 15068 3,8A5,84 3;853:76 =1,14865 1,42:71 5;873;AA0,64 372;818,AA 6,46 1;40:78 MW9*I~Fi-X14-GaZ°~6~ (8) 4,492.59 58.56 152.97 3,932.34 3,880.16 -1,185.67 1,441.98 5,972,964.30 372,830.65 7.06 1,447.91 MWD+IFR-AK-CAZ-SC (2) 4,544.29 61.73 154.81 3,958.07 3,905.89 -1,225.93 1,461.70 5,972,923.71 372,849.68 6.86 1,491.28 MWD+IFR-AK-CAZ-SC (2) 4,587.51 63.55 156.93 3,977.93 3,925.75 -1,260.96 1,477.39 5,972,888.42 372,864.76 6.06 1,528.72 MWD+IFR-AK-CAZ-SC (2) 4,634.21 66.44 157.69 3,997.67 3,945.49 -1,300.00 1,493.71 5,972,849.10 372,880.41 6.36 1,570.23 MWD+IFR-AK-CAZ-SC (2) 4,682.61 69.97 159.11 4,015.64 3,963.46 -1,341.78 1,510.24 5,972,807.05 372,896.22 7.79 1,614.45 MWD+IFR-AK-CAZ-SC (2) 4,730.60 74.40 160.03 4,030.32 3,978.14 -1,384.58 1,526.18 5,972,763.98 372,911.42 9.41 1,659.57 MWD+IFR-AK-CAZ-SC (2) 4,777.85 78.45 161.81 4,041.41 3,989.23 -1,427.98 1,541.19 5,972,720.34 372,925.68 9.32 1,705.08 MWD+IFR-AK-CAZ-SC (2) 4,826.53 79.25 183.39 4,050.82 3,998.84 •1,473.58 1,555.47 5,972,874.53 372,999.17 3.58 1,752.58 MWD+IFR-AK-CAZ-SC (2) 4,873.00 79.65 165.33 4,059.33 4,007.15 -1,517.55 1,567.78 5,972,630.34 372,950.73 4.19 1,798.14 MWD+IFR-AK-CAZ-SC (2) 4,919.53 81.02 166.87 4,067.14 4,014.96 -1,562.07 1,578.80 5,972,585.63 372,960.98 4.39 1,843.96 MWD+IFR-AK-CAZ-SC (2) 4,967.52 82.68 169.12 4,073.95 4,021.77 -1,608.53 1,588.68 5,972,539.01 372,970.06 5.79 1,891.46 MWD+IFR-AK-CAZ-SC (2) 5,012.95 83.23 168.96 4,079.52 4,027.34 -1,852.80 1,597.25 5,972,494.81 372,977.87 1.28 1,938.55 MWD+IFR-AK-CAZ-SC (2) 5,089.39 $5.05 111.54 4,087.33 4,035.15 -1,727.73 1,610.12 5,972,419.47 372,989.48 4.12 2,012.54 MWD+II=R-AK-CAZ-SC (2) 5,184.47 88.61 172.14 4,092.58 4,040.40 -1,821.69 1,623.59 5,972,325.31 373,001.32 3.80 2,107.31 MWD+IFR-AK-CAZ-SC (2) 5,279.60 90.46 170.84 4,093.35 4,041.17 -1,915.76 1,637.67 5,972,231.01 373,013.78 2.38 2,202.31 MWD+IFR-AK-CAZ-SC (2) 5,374.69 89.48 169.00 4,093.40 4,041.22 -2,009.38 1,654.31 5,972,137.13 373,028.81 2.19 2,297.36 MWD+IFR-AK-CAZ-SC (2) 5,469.83 88.80 168.70 4,094.83 4,042.65 -2,102.71 1,672.71 5,972,043.51 373,045.60 0.78 2,392.49 MWD+IFR-AK-CAZ-SC (2) 5,564.90 88.30 168.35 4,097.24 .4,045.06 -2,195.85 1,691.62 5,971,950.06 373,062.91 0.64 2,487.53 MWD+IFR-AK-CAZ-SC (2) 5,660.00 90.59 168.09 4,098.18 4,045.98 -2,288.94 1,711.03 5,971,856.67 373,080.72 2.42 2,582.62 MWD+IFR-AK-CAZ-SC (2) 5,754.99 93.43 167.93 4,094.83 4,042.65 -2,381.79 1,730.75 5,971,763.50 373,098.84 2.99 2,677.54 MWD+IFR-AK-CAZ-SC (2) 5,850.13 93.27 168.42 4,089.27 4,037.09 -2,474.75 1,750.21 5,971,670.22 373,116.71 0.54 2,772.51 MWD+IFR-AK-CAZ-SC (2) 5,945.23 93.26 168.01 4,083.85 4,031.67 -2,567.69 1,769.60 5,971,576.97 373,134.50 0.43 2,867.45 MWD+IFR-AK-CAZ-SC (2) 6,040.37 92.22 168.64 4,079.30 4,027.12 -2,660.76 1,788.83 5,971,483.60 373,152.13 1.28 2,962.48 MWD+IFR-AK-CAZ-SC (2) 6,135.38 91.91 170.21 4,075.88 4,023.70 -2,754.09 1,806.26 5,971,389.99 373,167.95 1.68 3,057.42 MWD+IFR-AK-CAZ-SC (2) 6,230.53 89.93 169.84 4,074.35 4,022.17 -2,847.79 1,822.73 5,971,296.03 373,182.82 2.12 3,152.52 MWD+IFR-AK-CAZ-SC (2) 6,325.56 89.93 169.47 4,074.47 4,022.29 -2,941.27 1,839.80 5,971,202.27 373,198.28 0.39 3,247.53 MWD+IFR-AK-CAZ-SC (2) 6,421.06 90.06 168.98 4,074.48 4,022.30 -3,035.09 1,857.65 5,971,108.17 373,214.52 0.53 3,343.03 MWD+IFR-AK-CAZ-SC (2) 6,516.18 89.62 167.81 4,074.74 4,022.56 -3,128.26 1,876.79 5,971,014.69 373,232.05 1.31 3,438.14 MWD+IFR-AK-CAZ-SC (2) 6,611.31 89.87 169.09 4,075.17 4,022.99 -3,221.46 1,895.83 5,970,921.19 373,249.49 1.37 3,533.27 MWD+IFR-AK-CAZ-SC (2) 6,706.52 89.19 169.85 4,075.95 4,023.77 -3,315.06 1,913.23 5,970,827.31 373,265.28 1.07 3,628.46 MWD+IFR-AK-CAZ-SC (2) 6,801.76 88.95 169.35 4,077.49 4,025.31 -3,408.72 1,930.42 5,970,733.37 373,280.86 0.58 3,723.67 MWD+IFR-AK-CAZ-SC (2) 6,895.20 87.40 168.31 4,080.47 4,028.29 -3,500.34 1,948.51 5,970,641.46 373,297.38 2.00 3,817.06 MWD+IFR-AK-CAZ-SC (2) 6,991.91 89.07 166.85 4,083.45 4,031.27 -3,594.74 1,969.30 5,970,546.73 373,316.55 2.29 3,913.71 MWD+IFR-AK-CAZ-SC (2) 6/18/2008 2:48:49PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips or its affiliate. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc Project: Western North Slope Site: CD2 Alpine Pad Well: CD2-464 Wellbore: CD2-464 :Design: ~- - 'CD2-464 Survey MD Inc Azi 7,086.99 90.92 167.43 7,182.11 91.04 166.85 7,277.19 91.35 167.09 7,372.30 90.43 168.34 7,467.48 90.06 169.88 7,562.37 90.12 170.12 7,657.14 89.50 168.80 7,750.22 90.12 187.41 7,846.13 90.67 167.03 7, 943.01 90.55 166.20 8,038.17 89.93 165.46 8,132.10 90.12 165.30 8,227,66 90.61 185.13 8,322.88 89.93 165.49 8,419.08 89.07 163.85 9,614.69 90.96 166.0'7 8,610.39 89.87 168.87 8,706.04 89.56 170.79 8,801.70 89.93 170.95 8,897.12 90.12 170.01 8,993,12 90.55 168.12 9,088.65 89.75 168.40 9,184.36 89.75 167.11 9,279.78 87.40 167.23 9,375.42 89.99 169.99 9,469.18 88.70 173,08 9,566.27 89.62 175.58 9,662.30 90.36 177.20 9,754.53 90.92 176.78 9,854.21 90.61 174.56 9,949.30 89.75 173.89 10,041.76 88.57 173.14 10,138.59 88.39 170.38 10,236.24 90,43 167.25 10,331.75 89.75 163.13 10,427.39 88.51 159.76 10,522.96 88.02 161.20 10,617.09 89.93 163.85 10,714.38 91.91 165.61 10,776.00 91.91 165.61 Local Co-ordinate Reference: Well CD2-464 TVD Reference: CD2-464 @ 52.18ft (Doyon 19) MD Reference: CD2-464 @ 52.18ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM Alaska Prod v16 - - _ -- - Map Map Vertical TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,083.46 4,031.28 -3,687.43 1,990.47 5,970,453.70 373,336.11 2.04 4,008.75 MWD+IFR-AK-CAZ-SC (2) 4,081.83 4,029.65 -3,780.15 2,011.63 5,970,360.64 373,355.69 0.62 4,103.83 MWD+IFR-AK-CAZ-SC (2) 4,079.85 4,027.67 -3,872.76 2,033.06 5,970,267.68 373,375.52 0.41 4,198.85 MWD+IFR-AK-CAZ-SC (2) 4,078.37 4,026.19 -3,965.68 2,053.30 5,970,174.44 373,394.16 1.63 4,293.93 MWD+IFR-AK-CAZ-SC (2) 4,077.96 4,025.78 -4,059.14 2,071.28 5,970,080.69 373,410.53 1.66 4,389.11 MWD+IFR-AK-CAZ-SC (2) 4,077.81 4,025.63 -4,152.59 2,087.76 5,969,986.98 373,425.41 0.26 4,483.97 MWD+IFR-AK-CAZ-SC (2) 4,078.13 4,025.95 -4,245.76 2,105.09 5,969,893.53 373,441.14 1.54 4,578.72 MWD+IFR-AK-CAZ-SC (2) 4,078.44 4,028.28 -4,336.84 2,124.28 5,969,802.15 373,458.76 1.64 4,671.80 MWD+IFR-AK-CAZ-SC (2) 4,077.77 4,025.59 -4,430.37 2,145.49 5,969,708.27 373,478.36 0.70 4,767.68 MWD+IFR-AK-CAZ-SC (2) 4,076.74 4,024.56 -4,524.61 2,167.92 5,969,613.67 373,499.17 0.87 4,864.49 MWD+IFR-AK-CAZ-SC (2) 4,076.34 4,024.16 -4,616.87 2,191.21 5,969,521.03 373,520.88 1.01 4,959.54 MWD+IFR-AK-CAZ-SC (2) 4,076.30 4,024.12 -4,707.76 2,214.92 5,969,429.75 373,543.02 0.26 5,053.33 MWD+IFR-AK-CAZ-SC (2) 4,075.89 4,023.51 -4,800.18 2,239.31 5,989,336.98 373,585.82 0.54 5,148.72 MWD+IFR-AK-CAZ-SC (2) 4,075.25 4,023.07 -4,892.26 2,263.45 5,969,244.46 373,588.38 0.81 5,243.79 MWD+IFR-AK-CAZ-SC (2) 4,076.09 4,023.91 -4,985.03 2,288.88 5,969,151.28 373,612.21 1.92 5,339.76 MWD+IFR-AK-CAZ-SC (2) 4,076.14 4,023.98 -6,097,14 2,314.60 6,969,058,75 373,636.24 2,27 5,435.11 MWD+IFR-AK-CAZ-SC (2) 4,075.53 4,023.35 -5,170.36 2,336.07 5,968,965.19 373,656.21 4.10 5,530.76 MWD+IFR-AK-CAZ-SC (2) 4,076.01 4,023.83 -5,264.50 2,352.96 5,968,870.78 373,671.48 2.03 5,626.38 MWD+IFR-AK-CAZ-SC (2) 4,076.44 4,024.26 -5,358.94 2,368.14 5,968,776.09 373,685.04 0.42 5,721.96 MWD+IFR-AK-CAZ-SC (2) 4,076.39 4,024.21 -5,453.05 2,383.92 5,968,681.74 373,699.20 1.01 5,817.32 MWD+IFR-AK-CAZ-SC (2) 4,075.83 4,023.65 •5,547.30 2,402.13 5,968,587.20 373,715.79 2.02 5,913.31 MWD+IFR-AK-CAZ-SC (2) 4,075.58 4,023.40 -5,640.83 2,421.56 5,988,493.35 373,733.62 0.89 6,008.84 MWD+IFR-AK-CAZ-SC (2) 4,076.00 4,023.82 -5,734.36 2,441.86 5,968,399.50 373,752.31 1.35 6,104.54 MWD+IFR-AK-CAZ-SC (2) 4,078.37 4,026.19 -5,827.36 2,463.04 5,968,306.15 373,771.89 2.47 6,199.89 MWD+IFR-AK-CAZ-SC (2) 4,080.55 4,028.37 -5,921.08 2,481.92 5,968,212.14 373,789.16 3.96 6,295.49 MWD+IFR-AK-CAZ-SC (2) 4,081.62 4,028.44 -6,013.80 2,495.72 5,968,118.20 373,801.36 3.57 6,389.11 MWD+IFR-AK-CAZ-SC (2) 4,083.05 4,030.87 -6,110.39 2,505.31 5,968,022.46 373,809.29 2.74 6,485.69 MWD+IFR-AK-CAZ-SC (2) 4,083.06 4,030.88 -6,206.23 2,511.36 5,967,926.54 373,813.70 1.85 6,580.82 MWD+IFR-AK-CAZ-SC (2) 4,082.03 4,029.85 -6,298.33 2,516.20 5,967,834.39 373,816.96 0.76 6,672.05 MWD+IFR-AK-CAZ-SC (2) 4,080.70 4,028.52 -6,397.71 2,523.73 5,967,734.90 373,822.78 2.25 6,770.95 MWD+IFR-AK-CAZ-SC (2) 4,080.40 4,028.22 -6,492.31 2,533.29 5,967,640.15 373,830.72 1.15 6,865.58 MWD+IFR-AK-CAZ-SC (2) 4,081.76 4,029.58 -6,584.17 2,543.73 5,967,548.14 373,839.58 1.51 6,957.68 MWD+IFR-AK-CAZ-SC (2) 4,084.33 4,032.15 -6,679.95 2,557.61 5,967,452.13 373,851.81 2.86 7,054.32 MWD+IFR-AK-CAZ-SC (2) 4,085.'3 4~033.t5 -6775.73 21576,54 5~887i35R:9@ ~7~i$9$,1~ 3:~3 7i151;~$ MWD+IFft•,zlK•CAZ=SG (3) 4,085.18 4,033.00 -6,868.04 2,600.95 5,967,263.34 373,891.92 4.37 7,247.27 MWD+IFR-AK-CAZ-SC (2) 4,086.64 4,034.46 -6,958.69 2,631.38 5,967,172.20 373,920.79 3.75 7,342.14 MWD+IFR-AK-CAZ-SC (2) 4,089.53 4,037.35 -7,048.72 2,663.30 5,967,081.64 373,951.15 1.59 7,436.71 MWD+IFR-AK-CAZ-SC (2) 4,091.21 4,039.03 -7,138.48 2,691.55 5,966,991.42 373,977.86 3.47 7,530.29 MWD+IFR-AK-CAZ-SC (2) 4,089.65 4,037,47 -7,232.31 2,717.17 5,966,897.16 374,001.87 2.72 7,627.34 MWD+IFR-AK-CAZ-SC (2) 4,087.60 4,035.42 -7,291.97 2,732.48 5,966,837.26 374,016.15 0.00 7,688.85 PROJECTED to TD 6/18/2008 2:48:48PM Pa~@ ~ ~QMPAS~ ~QQ~:1 ~ ~tl1(d ~~F 02-J u I-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-464 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 36.48' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 10,776.00' 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 ~ _ _ Date ~ ~~ ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Tim Allen Survey Manager Attachment(s) X08- ~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-082 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD2-464 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20574-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal Q or Continuation ^ or Final ^ 308-234 7/3/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 374* 374 totals (bbls): 2008 / 3rd 2008 / 4th 2009 / 1st 2009 / 2nd Total ending * Report is due on the 20th volume 374 374 0 of the month following the final month of the quarter. Ex: (bbls>: Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *Leak-Off test and freeze rotect volumes onl nd correct to the best of my knowledge. a I hereby certify that the foregoi~true ~ _ 7 ~f ~~d ~ ` ""`' ~ z Date: Signature: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate i~6~ELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-464 July 1, 2008 AK-MW-5772561 CD2-464 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20574-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20574-00 Digital Log Images: 1 CD Rom 50-103-20574-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed: • • WELL LOG TRANSMITTAL To: State of Alaska July 1, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Data: CD2-464 AK-MW-5772561 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API# : 5 0-103 -205 74-00 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 Date: Signed: og -U°i5 2 lCoCo~ if ~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, July 11, 2008 1:55 PM To: 'tdoel, Brian'; Doyon 19 Company Man Cc: Galiunas, Elizabeth C Subject: RE: Annular Disposal--CD2-464 (208-082) Brian, Liz, et al, I think the monitoring frequency depends on how large a batch you might be pumping. If the pumping time is an hour or so, what you propose sounds appropriate however if the pumping time is several hours then additional readings during that time may be appropriate. I would suspect that if there were a sudden pressure loss on the pumping annulus that checking the surrounding annuli would be done promptly. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: Noel, Brian [mailto:Brian.Noel@conocophillips.com] Sent: Thursday, July 10, 2008 3:46 PM To: Maunder, Thomas E (DOA); Doyon 19 Company Man Cc: Galiunas, Elizabeth C Subject: FW: Letter to state for annular disposal See note below from Liz. While using CD2-464 for annular disposal, pressures (CD2-36, CD2-38, CD2-41). Thanks - Brian need to monitor following three wells OA -----Original Message----- From: egaliunas@mac.com [mailto:egaliunas@mac.com] Sent: Thursday, July 10, 2008 2:38 PM To: Noel, Brian Cc: Galiunas, Elizabeth C Subject: Letter to state for annular disposal Brian, I cannot log into the conocophillips login on my mac for some reason. Can you forward this to Tom Maunder and the rig? Tom, I appologize, i am unable to login right now from my home computer. To follow up on our converstaion, the Qannik wells to be monitored per the injector order are not yet hooked up. Therefore, this is not yet possible to use for annular disposal monitoring. The wells noted in the annular disposal sundry for CD2-464, will be monitored once before injection, once during an injection, and post injection to assure there is not communication. between surface shoe to surface shoe. We can monitor the annuli more often if needed. Let me know any comments or questions you have, Liz Galiunas 907-265-6247 907-441-4871 1 • e~ ~,, °°.~ - ,~ ~~ ~ ::.3 r~F ~, ~' d_~} ~W S~ 4 ~~ ~ E~ try' ~ ~~~ ~~ ALASKA OIL A1~TD GA,S CONSER'QA7'IOl~T COI-II-II55IO1~T Chip Alvord ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Qannik Oil Pool, CD2-464 Sundry Number: 308-234 Dear Mr. Alvord: SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, r~ DATED this day of July, 2006 Encl. Dan T. Seamount Chair ~6~~~~ • ~ ~~ ~~ ~ ~TATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ', '.;'''~''~ ~;~~~,~ ~01'~55jOTi ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 ~~,.. ~~n 1. Operator 3. Permit to Drill Name: 208-082 ConocoPhillips Alaska 4. API Number: 50-103-20574-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD2-464 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD2-14, CD2-16, CD2-17, CD2-19, CD2-22, ,CD2-25, CD2-26, Torok and Seabee formation, shale, siltstone and sandstone CD2-27, CD2-28, CD2-32, CD2-34, CD2-35, CD2-36, CD2-37, CD2-38, CD2-39, CD2-41, CD2-42, CD2-44, CD2-45, CD2-46, CD2-47, CD2-48, CD2-49, CD2-50, CD2-51, CD2-52, CD2-55, CD2-58 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and Gaystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2182 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. , Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act 16. Estimated start date: of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances 4-Jul-o8 that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) Q Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data ^~ Other ^' previous authorization for new product cleanup fluids for CD1 and CD2 t to the best of my knowledge. orrec 18. I hereby certify that the f oregoi ng is tr ue and c / ~ ~ / ~ ~ Signature: /,G~:.~+. /Y ~/~Z./`~~~ Title: D.B~G-b' S~'T /~/Q7~I~ C,l~79f?.SL'i~5 fOlL- ~' /92~tlOR~ Printed Phone Name: Chip Alvord Number: 265-6120 6/302008 ly Commission Use On ((~~ i ,, Conditions of approval: MCs+~~~:T' ~ ~ C.'T `~~, ~~~C~~ ,~~~ ~ `~/~ ~ ~ LOT review and approval: ~ 3,_v~, V.3\~~, ~it..j~C'~~.r`'~e ~y~+CZt,~wf:":«~~+~t4li.[;`:'C.:~°''~~'~~-%~•~L~-~i.~: r /~~y6~ _~f,G,.{/+ ~~ ~ v ` Subsequent form required: 1~ ~ ~r~ ~ Approval number: ~ APPROVED BY ~ ~~ /~ COMMISSIONER THE COMMISSION Date { / ~~'~~~i~~ 4 Approved by: Form 10-403RD Rev. 6/2004 INSTRUCTIONS ON REVERSE ORIGINAL +~~~~.~~~~a~x~ Submit in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 27, 2008 Alaska Oil and Gas Conservation Commission 333 West 7~` Avenue, Suite 100 Anchorage, Alaska 99501-3539 Dear Sir or Madam: well (C {,,,.~~,,,~., ~~. ;,~~ ConocoPhillips Alaska, Inc. hereby requests that CD2-464 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. The anticipated start date for annular disposal operations on CD2-464 is July 4, 2008. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells (Note: CD2-40's surface casing shoe is 1325' away) 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on surface x intermediate casing annulus. Zoomed in test to show change in slope and reason for choosing the LOT point at 710 psi. 11. Information regarding wells within ~/4 mile radius at AOGCC (total of 28 wells): CD2-14, CD2-16, CD2-17, CD2-19, CD2-22, ,CD2-25, CD2-26, CD2-27, CD2-28, CD2-32, CD2-34, CD2-35, CD2-36; CD2-37, CD2-38, CD2-39, CD2-41, CD2-42, CD2-44, CD2-45, CD2-46, CD2-47, CD2-48, CD2-49, CD2-50, CD2-51, CD2-52, CD2-55, CD2-58 12. Incremental information regarding remaining wells within '/4 mile radius: None 13. Copy of previous authorization (CD 1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (15.9 ppg) occurred at a lower equivalent mud weight than the casing shoe test (17.7 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerely, Liz Galiun Drilling Engineer cc: CD2-464 Well File Chip Alvord ATO-1577 Sharon Allsup-Drake ATO-1530 ConocoPhillips `~~, Af,~s~,a ail ~ N ~ ,1~~8 ~~~" ~~ ~ ~ Annulus Disposal Transmittal Form -Well CD2-464 ACIC:C`~ Reanlatinnc 2n AA(` 75 (1R(1 (hl 1 Desi nation of the well or wells to receive drillin wastes: CD2-464 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipment after producing drilling/completion fluid (see included note from CD1&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2182 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD2-466, CD2-463, CD2-465, CD2-73, CD2-74 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) v~~,~o~ i.o-,a~ os Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/fr Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lifr) 1,000 psi Maximum Fluid Density to avoid Burst of Surface Casing ~burst85 % - PHydrostatic +PApplied - PForma[ion 3,043 =( 2,371 * 0.052 *MWmax )+ 1500 - (0.4337 * 2,371 ) MWmax = 20.85501 PP1 Surface Casing Strin Size 10.75 in Weight 45.5 ppf Grade L 80 Pburstl00% 3,580 psi Pburst85% 3,043 Psi Depth of Shoe 2,371 ft FIT/LOT @ Shoe 17.7 ppg or 2,182 psi F1T/LOT for Annulus 15.9 ppg Max Surf. Pressure 1,500 psi Maximum Fluid Density avoid Collapse of 2nd Casing String Pconapse85 % - PHydrostatic +PApplied- PGasGradient - PHeader 4,072 =( 3,707* 0.052 ~` MWmax )+ 1,500 - (0.0700 * 3,707) - 1,000 MWmax = 19.87399 PPP, 2nd Casine Strin Size 7.625 in Weight 29.7 ppf Grade L 80 Pcollapse100% 4,790 Psl Pcollapse85% 4,072 Pst Top of Cement 3,707 fr Gas Gradient 0.07 psi/fr Max Sttrf Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmaxallowable-Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = (2,371 * .052 * 17.7 ) Pmax allowable - 2,182 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". Well CD2-464 Date 6/30/2008 • SURFACE CASING SHOE SEPARATION FROM CD2-464 CD2-464 X Y Surface Casino Shoe ASP 4 Coordinates' 372010.96 5973679.52 ells Details @ AOGCC ermit # ermit Date ource well Ann. Vol. **** tart Date nd Date rs ante from Object well* Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. CD2-01 2587 373114.47 5976019.06 CD2-02 3551 369431.33 5976119.22 CD2-03 2978 371040.60 5976495.42 CD2-05 0 1753 370258.60 5973735.40 CD2-O6 NA 0 2373 371610.81 5976018.45 CD2-07 NA 0 2617 372218.06 5976287.95 CD2-08 2029 372655.88 5975603.76 CD2-09 304-362 9/30/2004 418 3069 370318.00 5976239.00 CD2-10 304-289 7/30/2004 CD2-09, CD2-56 30703 8/27/2004 10/15/2004 2336 371800.58 5976006.36 CD2-11 2101 370835.25 5975420.76 CD2-12 303-365 12/12/20D3 CD2-57, CD2-31 320D0 5/15/2004 6/14/2004 2001 371071.29 5975445.60 CD2-13 2203 372658.78 5975785.31 CD2-14 301-288 1019120D1 CD2-45, CD2-47, CD2-32 31073 11/13/2001 3/5/2002 1296 372202.47 5974960.87 CD2-15 301-308 11/6/2001 CD2-50, CD2-25, CD2-44 31652 3/6/2002 9/21/2002 1758 370832.00 5974984.02 CD2-16 1198 372460.34 5974790.01 CD2-17 302-122 4/10/2002 CD-48, CD2-OS 18181 5/29/2002 2/7/2003 994 371774.00 5974645.00 CD2-18 2419 369825.76 5974716.05 CD2-19 y 303-083 4128/2003 CD2-58,CD2-52 31337 5/19/2003 6/27/2003 1039 372284.88 5974681.33 CD2-20 304-288 7/30!2^C4 452 1938 371366.14 5975507.11 CD2-21 2340 370286.77 5975261.48 CD2-22 302-274 9120!2002 CD2-O8, CD2-36, CD2-51 31253 2!7/2003 3/16/2003 i 943 371678.61 5974562.30 CD2-23 303-080 4/28/2003 CD2-18, CD2-55, CD2-06 32000 9/4/2003 1/1/2004 1712 371013.17 5975070.46 CD2-24 301-186 7113/200' CD2-33 (+A&B), CD2-39, CD2-14, CD2-15 33999 7/16/2001 10/9/2001 1730 370630.11 5974721.81 CD2-25 NA -'P 902 371594.00 5974479.00 CD2-26 302-068 3/4/2002 CD2-44, CD2-29, CD2-13 29626 9/7/2002 10/17/2002 ^a 900 371798.52 5974554.55 CD2-27 304-226 6/23/2004 CD2-53, CD2-05, CD2-09 32000 7/9/2004 8/27/2004 ~ 1200 373046.07 5973071.83 CD2-28 ~-1 1057 372139.80 5974728.95 CD2-29 303-249 8/25/20D3 CD2-O6, CD2-30, CD2-27 29036 10/8/2003 11/19/2003 1375 372652.44 5974896.02 CD2-30 NA 0 1539 370473.52 5973610.96 CD2-31 NA 0 2319 369824.37 5974451.30 CD2-32 302-119 4/30/2002 CD2-19, CD2-41, CD2-23 31113 6/14/2002 7/23/2002 949 371295.61 5974302.38 CD2-33 B""" 1867 370155.64 5973886.23 CD2-34 302-069 3/4/2002 CD2-13, CD2-37 22842 10/17/2002 11/28/2002 -~? 788 371803.06 5974439.79 CD2-35"" 453 372312.31 5974017.68 CD2-36 303-365 12/12/2003 CD2-43, CD2-31, CD2-57 32000 12/31/2003 7/9/2004 -~ 217 371848.22 5973535.38 CD2-37 918 371569.79 5972874.47 CD2-38 303-082 4/28/2003 CD2-40, CD2-30 30011 7/28/2003 9!4/2003 154 372033.86 5973527.13 CD2-39 301-281 10/9!2001 CD2-15, CD2-47, CD2-44 29945 10/10/2001 9/16/2002 343 372350.61 5973633.17 CD2-40 NA 0 1325 370691.67 5973801.44 CD2-404 307-154 5/8/2007 CD2-72 6764 5/14/2007 5/31/2007 2001 370646.55 5975142.76 CD2-41 303-081 4/28/2003 CD2-20, CD2-55,CD2-43 3200^ 6/27/2003 7/28/2003 125 371990.58 5973802.52 CD2-42 301-140 6/1/2001 CD2-24, CD2-33, CD2-33A, CD2-15 33992 6/1/2001 10/10/2001 ~^ 965 371098.46 5973992.48 CD2-43 Arctic acked 1674 370344.04 5973520.68 CD2-44 649 372034.57 5974328.53 CD2-45 301-345 12/13!2001 CD2-49, CD2-17 22991 1/20/2002 2/19/2002 774 372765.13 5973853.74 CD2-46 302-273 9/20/2002 CD2-51, CD2-12 31864 4/15/2003 5/19/2003 a 706 371694.80 5974310.85 CD2.464 Included 0 372010.96 5973679.52 CD2-47 301-322 12/3/2001 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 ~- 869 371231.72 5973294.19 CD2-48 302-275 9/20/2002 CD2-28, CD2-35a, CD2-45, CD2-08 32000 12/10/2002 2/4/2003 ~ 383 371631.74 5973736.14 CD2-49 302-070 3/4l20C2 CD2-50, CD2-46, CD2-22 27960 4/22/2002 5/28/2002 ->• 851 371252.38 5974065.93 CD2-50 302-121 4/30/2002 CD2-41, CD2-19, CD2-16, CD2-38 32000 7/24/2002 9!7/2002 ~ 648 371665.21 5974227.65 CD2-51 303-312 10/28/2003 CD2-07, CD2-10 31769 11/19/2003 12/24/2003 1 135 373114.02 5973411.81 CD2-52 NA 627 372637.61 5973661.63 CD2-53 304-361 9/30l2C04 CD2-56, CD2-54, CD2-02 26072 10/3/2004 8/5/2005 1468 372896.67 5972509.19 CD2-54 NA 0 2044 369991.09 5973363.59 CD2-55 ~ 1016 371118.23 5973194.84 CD2-56 305-307 10/11/2005 CD2-404 11167 5/7/2006 5/23/2006 2225 369875.93 5973053.08 CD2-57 305-238 8/17/2005 CD2-01 19181 8/22/2005 9/12/2005 1454 372537.05 5972324.37 CD2-58 NA -1- 1026 372102.03 5972657.80 CD2-59 2389 369650.94 5974049.86 CD2-60 1535 371269.33 5972336.05 CD2-72 308 4/28/2008 CD2-75, CD2-464, CD2-466 26074 5/3/2008 6/25/2008 2675 369745.64 5975101.63 CD2-75 y 2517 369536.59 5973218.56 "Lateral distance in feet, between surface casing shoes, in the X-Y plane *«CD2-35 was drilled from an ice pad in early 1998. The 9-518" x 7" annulus has not been permitted for annular disposal. ***CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. """ As of 6 /2 712 0 0 8 Note that this sheet is not the definitive record. `.- Calculatlon McNOtl: Mlnlmum Curvature E^orSyslem: IBCWBA ~ a , a° s M ` '°d°"°~ Project: Western North Slope ConocoPhillips e o r Error SUrlxe: Elli tical COnlc `a° ~ P Waming Me[hod: Rules Bazed CD2 AI ine Pad Site• p C D2-464 Geotletlc Datum: North American Datum 199J ' Well: CD2-464 j Magnetlc Model: BGGM200 ! wellbore: CD2-464 Quarter M i I e View Ground LC•ml: 15.70 f2Kli CD2464 ~~i2.18ft (Doyon l9) CD2-464 Rorthi n.If.15P Y'. 5973921.12 EastiiiylP.SV %_ 1511~14LOfl ~ __ -_ -. ~ ,~ u-vc 8' 1 4" ~ 12- -5/8" x 1 -1/4" - 14 29 -1/4"' 9-5/S" x 12-1/4 ~9- " x 12-1/ 17 28 8- 16 ,. 12-1/4" 500 - 9- 19 - - x 12-1/4" 1 " ' 22 26 ..... /8" x 12-1/4" j ~ 7" x 8-1/2" x 12-1/4 9 5/8 ~ x ~ 32 46 - 44 Q - 5O O 49 9-5/8" x 12- 4" O 35 42 ~ ~ ~ - 4„ " 1 9-5/8" x 12-1/4" 45 ~ I I 2-1/4" 12- 5/8' 41 -5/8 I x 8-1/2" ~ ~, ~ 40 •• -3/4" x 3-1/2' 9 48 I -1/4 - " x 1 O -500 12 5/ " ~ 5/ 52 464 °- _ - ~ x 12-1/ 8 39 9- " x 4' Z " x 12-1 36 38 -5/8" x 12-1/4" 51 ~ ~ 12 1/4" 5/8' x 1 l4" ~ ~ 47 v~1000 9 55 x 12- " " 5/8' 1 l4"" - _ 9 ~ ~ 7 x 8-1/2 - 27 /8" x /4" -5/8" x 1 -1/ ' 37 -5/8' x -1/4" -1500- -~ -58 7" x 8-1/2'. ~ ~~ 5/8" 12 1/4" " " ~ ~ i j '7-5/ X 9-7/8 ~~ ~I ~ 9-5/8" x 1 -114" - -- _ -- ~ ~~ 9 5l 8" x 12 1/4" ~~ -1500 -1000 -500 0 500 1000 1500 2000 2500 West(-)/East(+) (500 ft/in) i i CD2 -464 Casin Detail Well: CD2-as4 90 3/4" 45.5# L-80 BTC-M Casin Date: 6/5/2008 j"'~M~+~;~~'~ ~wn~ nn--~~..vn~ '' 11 Rig: Doyon 19 X ' ~• Depth Jt Number Joints ,~ Well Equipment Description and Comments ="° Page 1 Length Tops ............... ............... ............... ............... .... .... . ........ .......... . ........ ............ . ......... _.. .................. .................. .. _. Do on 19 RKB to Landin Rin Y 9 9 36.14 FMC Gen V Hanger 2.09 36.14 Jts 3 to 62 60 Jts 10-3/4" 45.5# L-80 BTC-M Csg 2444.59 38.23 Halliburton Float Collar 1.20 2482.82 Jts 1 to 2 2 Jts 10-3/4" 45.5# L-80 BTC-M Csg 81.49 2484.02 Ray Oil Tool Silver Bullet Float Shoe 2.19 2565.51 Shoe @ 2567.70 2567.70 10-3/4" Shoe @ 2568 ' MD / 2371' TVD 2567.70 2567.70 13-1/2" Hole @ 2,578' MD / 2,379.6' TVD 2567.70 2567.70 2567.70 2567.70 2567.70 2567.70 2567.70 2567.70 2567.70 2567.70 2567.70 RUN TOTAL 36 BOWSPRING CENTRALIZERS - 2567.70 2567.70 1 per jt on Jt #1 - #12 (stop ring on Jt #1 & 2) 2567.70 and over collars on jts # 14, 16, 18, 20, 22, 24, 26, 28, 30, 2567.70 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 2567.70 2567.70 2567.70 2567.70 2567.70 70 joints in the pipe shed. Run 62 joints 2567.70 Last 8 joints stay out 2567.70 Use Best-o-Life 2000 i e do a 2567.70 All joints drifted 9.875" 2567.70 MU torque - 9500 ft/Ibs 2567.70 Remarks: Up Wt 185K Dn Wt 150 K Block Wt 75 K Supervisors: Dave Burley /Peter Wilson /Steve Shultz Cement Detail Report CD2-464 ...• Surface Casing Cement 'C~ment Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 6/6/2008 00:00 6/6/2008 02:20 CD2-464 Comment Cemented 10 3/4" casing as follows: Pumped 50 bbls of 9.8 ppg mud with nut plug marker followed with 40 bbls of Biozan as pre flush w/nut plug marker - Switch over to Dowell -Pumped 3 bbls of FW -tested lines to 3,000 psi -Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer @ 6 BPM @ 180 psi - Mixed & pumped 333 bbls (404 sxs) 10.7 ppg Lead slurry at 4.63 yield (ASL) @ 7.5 BPM / 220-175 psi -Observed nut plug marker @ shakers w/ 323 bbls lead slurry pumped - (pumped down surge can 333 bbls total) Switched to tail slurry -Mixed & pumped 58 bbis (275 sxs) 15.8 ppg lead slurry at 1.17 yield (Class G w/ additives) @ 5.5 BPM @ 175 psi -Dropped top plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cement w/ 218 bbls 9.8 ppg mud @ 7 BPM / 310 to 680 psi slowed pump to 4 BPM / 540 psi (for the last 10 bbls of displacement) Bumped plug to 1,050 psi -Check floats OK -CIP @ 02:20 hrs. -Full circulation throughout job w/ 149 bbis 10.7 cement returns to surface - reci rotated i e while cementin and stopped after pumping 45 bbls into tail tint (approx 132 bbls lead out of the shoe)- hole was getting sticky and lost 25K SOW -landed casing or remain er o )o . Cement Sta es - - --- - -_ $ta e # <Sta a Number?> _ ___ Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Surface Casing Cement 0.0 2,568.0 Yes 149.0 Yes Yes Q (start) (bbl/min) O (end) (bbllmin) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 4 7 550.0 1,050.0 Yes 6.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cemented 10 3/4" casing as follows: Pumped 50 bbls of 9.8 ppg mud with nut plug marker followed with 40 bbis of Biozan as pre flush w/nut plug marker - Switch over to Dowell -Pumped 3 bbls of FW -tested lines to 3,000 psi -Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer @ 6 BPM @ 180 psi - Mixed & pumped 333 bbis (404 sxs) 10.7 ppg Lead slurry at 4.63 yield (ASL) @ 7.5 BPM / 220-175 psi -Observed nut plug marker @ shakers w/ 323 bbis lead slurry pumped - (pumped down surge can 333 bbls total) Switched to tail slurry -Mixed & pumped 58 bbis (275 sxs) 15.8 ppg lead slurry at 1.17 yield (Class G w/additives) @ 5.5 BPM @ 175 psi -Dropped top plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cement w/ 218 bbls 9.8 ppg mud @ 7 BPM / 310 to 680 psi slowed pump to 4 BPM / 540 psi (for the last 10 bbis of displacement) Bumped plug to 1,050 psi -Check floats OK -CIP @ 02:20 hrs. -Full circulation throughout job w/ 149 bbis 10.7 ppg cement returns to surface -reciprocated pipe while cementing and stopped after pumping 45 bbis into tail tint (approx 132 bbls lead out of the shoe)- hole was getting sticky and lost 25KSOW -landed casing for remainder of job. _ _ _ -- Cement Fluids & Additives - _ - ------- Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.0 2,068.0 404 G 333.0 Yield (ft lsack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 4.63 21.75 10.70 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type- Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,068.0 2,568.0 275 G 58.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Addtive Type Concentration Conc Unit label Page 1/1 Report Printed: 6116/2008 Security Level: Development Daily Drilling Report - CD2-464 Report Number: 5 . .• Rig: DOYON 19 Report Date: 6/6/2008 Network/ID # ~, _ _ - Total AFE+Sup AFE Type _ _ 10217918 T 8,085,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftK6) CD2-464 Development QANNIK 3.82 5.0 20.00 2,578.0 2,598.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,016.59 59,723.91 440,682.59 1,313,399.91 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 6/2/2008 6/3/2008 24.61 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,567.7ftK6 3 1/2 13,698.00 Ops and Depth @ Morning Report 24hr Forecast Drilling 9 7/8" Hole @ 3,000' Cont. to Drill 9 7/8" Hole Last 24hr Summary Cemented 10 3/4" csg w/149 bbls of cmt back at surface, tested csg to 3,000 psi f/30 min, MU FMC wellhead, NU & tested BOPE 250/2,500/ 3,500 psi. Chuck Scheve w/AOGCC waived witnessing of the test. Stood back 5" DP, MU 9 7/8" BHA #4 & RIH. Drilled out shoe track & 20' of new formation to 2,598', Circ clean & RU to perfom LOT. General Remarks Weather Head Count No Accidents and No Spills 37 Deg, Partly Cloudy, Wind SW @ 9 mph 49.0 Supervisor. _ `Title = Dave Burley, Rig Supervisor Rig Supervisor Peter Wilson, Rig Supervisor Rig Supervisor Steve Shultz, Rig Supervisor Rig Supervisor Time Lo , Start Time End Time Dur (hrs) ' phase Op Code OpSub-Code Time p-N-T TrtN Code Trbl Class. Depth Start (ftK6) Depth End (ftK6) Operation'. 00:00 02:30 2.50 SURFAC CEMENT DISP P 2,568.0 2,568.0 Cemented 10 3/4" casing as follows: Pumped 50 bbls of 9.8 ppg mud with nut plug marker followed with 40 bbls of Biozan as pre flush w/ nut plug marker - Switch over to Dowell -Pumped 3 bbls of FW -tested lines to 3,000 psi -Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer @ 6 BPM @ 180 psi -Mixed & pumped 333 bbls (404 sxs) 10.7 ppg Lead slurry at 4.63 yield (ASL) @ 7.5 BPM / 220-175 psi -Observed nut plug marker @ shakers w/ 323 bbls lead slurry pumped - (pumped down surge can 333 bbls total) Switched to tail slurry -Mixed & pumped 58 bbls (275 sxs) 15.8 ppg lead slurry at 1.17 yield (Class G w/ additives) @ 5.5 BPM @ 175 psi - Dropped top plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cement w/ 218 bbls 9.8 ppg mud @ 7 BPM / 310 to 680 psi slowed pump to 4 BPM / 540 psi (for the last 10 bbls of displacement) Bumped plug to 1,050 psi -Check floats OK - CIP @ 02:20 hrs. -Full circulation throughout job w/ 149 bbls 10.7 ppg cement returns to surface -reciprocated pipe while cementing and stopped after pumping 45 bbls into tail cmt (approx 132 bbls lead out of the shoe)- hole was getting sticky and lost 25K SOW -landed casing for remainder ofjob. ~~ i 02:30 03:15 0.75 SURFAC CASING DHEQ P 2,568.0 2,568.0 RU and test 10 3/4" casing to 3000 psi for 30 minutes - RD & blow down lines Latest BOP Test Data __ Date Comment - 6/6/2008 Tested BOPE 250/2,500/3,500 si. NOTE: Chuck Scheve w/AOGCC waived witnessin of test Page 113 Report Printed: 6/18/2008 Security Level: Development Daily Drilling Report - CD2-464 _ Report Number: 5 . .• Rig: DOYON 19 Report Date: 6/6/2008 Time L Start End Dur I Time i Depth Start Depth End Time Time (hrs) ' Phase Op Code OpSub-Code P-N-T Trbl Code i. Trbl Class. (ftKB) (ftKB) Operation 03:15 04:45 1.50 SURFAC CASING RURD P _ 2,568.0 2,568.0 LD -cement head & landing joint - RD casing elevators and bails, LD mousehole and surtace riser 04:45 05:30 0.75 SURFAC WELCTL NUND P 2,568.0 2,568.0 Removed FMC speed head from conductor -Install FMC Unibody wellhead -test M/M seal to 1,000 psi for 5 minutes 05:30 07:30 2.00 SURFAC WELCTL NUND P 2,568.0 2,568.0 NU BOPE stack -riser & flowline 07:30 12:30 5.00 SURFAC WELCTL BOPE P Tested BOPE, tested rams, valves and manifold to 250 psi low and 3,500 psi high, tested annular to 250/2,500 psi. Performed Koomey test and used 5" test jt. no problems. NOTE: Chuck Scheve with AOGCC waived witnessing of test. 12:30 13:00 0.50 SURFAC DRILL PULD P Installed wear bushing 13:00 13:15 0.25 SURFAC DRILL RURD P RU short bales and elevators 13:15 14:30 1.25 SURFAC DRILL PULD P PJSM, PU and stood back 11 stds of 5" DP 14:30 17:30 3.00 SURFAC DRILL PULD P 0.0 733.0 MU 9 7/8" BHA #4 RIH to 733'. MU 9 7/8" bit on motor with 1.5 deg. bend and MWD, oriented and uploaded same, RIH with HWDP and jars to 733'. Shallow tested MWD. 17:30 19:15 1.75 SURFAC DRILL PULD P 733.0 2,250.0 RIH with BHA #4 PU 5" DP, singled in DP from 733' to 2,250' (16 stds) 19:15 20:45 1.50 SURFAC RIGMNT SVRG P 2,250.0 2,250.0 PJSM, slip and cut 60' of drlg line and serviced top drive. 20:45 21:15 0.50 SURFAC DRILL TRIP P 2,250.0 2,472.0 RIH from 2,250 to 2,446', washed down and tagged cmt at 2,472', (FC @ 2,483') 21:15 22:45 1.50 SURFAC CEMENT COCF P 2,472.0 2,578.0 Drilled out plugs, flt collar, shoe track and shoe at 2,568' then cleaned out to TD at 2,578'. Drilled out with 5K wob, 40 rpm's, 500 gpm at 1,420 psi. 22:45 23:15 0.50 SURFAC DRILL DDRL P 2,578.0 2,598.0 Drilled 20' of new hole for LOT, drilled to 2,598' MD/2,396' TVD ADT .33 hrs, 5-10K wob, 60 rpm's, 550 gpm, 1,720 psi, off btm torque 9K ft-Ibs, on btm 9K, rot wt 140K, up wt 160K, do wt 126K. 23:15 23:45 0.50 SURFAC DRILL CIRC P 2,598.0 2,598.0 Circ hole clean for LOT, circ hole evening MW in and out at 9.6 ppg, circ at 550 gpm, 1,640 psi and 50 rpm's. 23:45 00:00 0.25 SURFAC DRILL RURD P 2,598.0 - 2,598.0 RU to perform LOT ---- Mud Check Data _ .Type Depth (ftKB) Dena(Iblgal) Vis(sJgt) PV Calc (cp) _ _ _ _ YP Calc Gel (10s) i, Gel (10m) Gel (30m) ~. (Ibf/100ft') (Ibf/100ft') (Ibf/100Jt') (Ibf/160tt') MBT - HTfi~ DensityTemp Solids, Corr. (Ib/bbp ~ (mU30mfn) ; pH j°F) (%) Spud Mud 2,578.0 9.60 41 15.0 11.000 3.0 21.0 0.000 25.0 10.0 8.0 ~ In'ection Fluid.. _ __ _ _ -- - _~- ~ _ Fluid - Source _ From Lease (bbl) _ _-'- ~_ Destlnation ~ Note Cementing F luids CD2-464 600.0 CD2-72 Returned Cmt & Cmt Contaminated mud Diesel 50.0 CD2-72 Freeze Protect Pit Rinsate 289.0 CD2-72 Water 190.0 CD2-72 Flush Water Based Mud CD2-464 1370.0 CD2-72 Page 2/3 Report Printed: 6/76/2008 l J i Security Level: Development Daily Drilling Report CD2-464 ..~ Report Number: 5 Rig: DOYON 19 Report Date: 6/6/2008 Drill Strip s: BHA No. 4 - Steerable / Bit Run No. 3 9 718in Hughes, HCM -5062 _7.1.10659 Depth In (ttK6) Depth Out (ftK8) TFA (incl Noz) (in') Nozzles (132") IADC Bit Dull String Wt (10001bf) 2,578.0 5,052.0 0-2-CT-G-X-2-NO-TD 35 Drill S_t_rin g Com orients Jts Item Description: 00 {in) ID (in) Top Conn Sz (in) Top Thread i Cum: Len (ft) HWDP 5 3.000 41/2 1F 431.41 Drilling Jars -Hydraulic 6.19 2.250 4 1/2 IF 464.19 HWDP 5 3.000 41/2 1F 556.80 Drill Collar 6.65 2.810 4 1/2 IF 587.87 Drill Collar 6.71 2.880 4 1/2 IF 618.98 Drill Collar 6 3/4 2.810 4 1/2 IF 650.07 Orientation Sub 6.67 2.815 4 1/2 IF 653.41 MWD (Dir & Logging) 6 3/4 1.920 4 1/2 IF 663.43 MWD (Dir & Logging) 6 3/4 1.920 4 1/2 IF 691.43 MWD (Directional) 6 3/4 1.920 4 1/2 IF 700.26 Stabilizer 6.55 2.250 41/2 1F 705.21 Float Sub 6 11/16 2.813 4 1/2 IF 707.34 Mud Motor 7 4.753 4 1/2 IF 732.77 PDC Bit Hughes HCM 5062 9 7/8 6 5/8 Reg 733.86 Drtllin P arameters I ~ _ -- - r- Start (RKB) ~ _ End (ftK8) Cum Depth (ft) Cum Drill Tlme (hrs) ~ T mte (hrs); ~ m) RPM i WOB (Ibf) (rPm) SPP (psl) ~' PU Str Wt Drill Str Wt ~ SO Str Wt (10001bf) (10001bf) (10001bf) Off Btm Tq ~ Drill Tq 2,578.0 2,598.0 20.00 0.33 0.00 550 10.0 60 1.720.0 160 1401 126'i 9,000.0 9,000.0 Wellbores Wellbore Name Wellbore API/UWI CD2-464 501032057400 _ _ ___ SECtIOn Stze {in). - ~ Act Top (ftK8) Act Btm (RKB) __ Start Date End Date COND1 16 0.0 114.0 SURFAC 13 1/2 114.0 2,578.0 6/3/2008 6/5/2008 INTRM1 9 7/8 2,578.0 5,052.0 6/7/2008 6/8/2008 PROD1 6 3/4 5,052.0 107,765.0 6/11/2008 6/14/2008 Surv Data '~ MD (ftK8) Ind (°) qzm (°) TVD (ftK8) VS (ft) _ _ _ NS (tt) EW (ft) ~ DLS (°I100rt) 2,591.39 _ 33.26 123.68 - - 2,390.87 604.99 - , -491.69 620.94 0.30 Cement -- - -- Surface Casin Cement -Started 6/6/2008 Type Wellbore Cemented String Cement Evaluation Results casing CD2-464 Surface, 2,567.7ftKB Stg No. Description Top (ttKB) Bottom (ftK8) O (end) (bbl/... P (final) (psi) Surface Casing Cement 0.0 2,568.0 4 550.0 Fluid - Class 'Jttn64mt{sack s) I V (bbp - - Density (Ib/gal) ~ - , YieIC {fN/sack) ~ -Est Top (ttKB) -- Est l3trrr (ftK8) Lead Cement G 4 04 333.0 10.70 4.63 36.0 2,068.0 Tail Cement G 2 75 58.0 15.80 1.17 2,068.0 2,568.0 Page 3/3 Report Printed: 6/1612008 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-464 Rig: Doyon 19 Date: 6/7/2008 Drilling Supervisor: D. Burley / P. Wilson Pump used: #i Mud Pump ~ Volume Input Volume/Stroke Pump Rate: strokes ~ 0.1000 Bbls/Strk ~ 6.00 Strk/min ~ Type of Test: Casing Shoe Test LoT/Frr ~ Pumping down i annulus and uP. ~ ~ Casin Test Pressure In te rity Test Hole Size: 13-1/z" ~ Casing Shoe Depth Hole Depth Pum ping Shut-in Pumping Shut-in RKB-CHF: 36.0 Ft Ft-MD 2371.0 Ft-TVD 2568.0 2598.0 Ft-MD 2396.0 Ft-TVD Strks psi Min psi Strks psi Min psi _ Casing Size and Description: 10-3/4" 45.5#/Ft L-80 BTC ~ 0 0 0 3020 0 0 0.00 1000 Casin Test Pressure Int ectritvTest 2 100 1 3020 1 40 0.15 995 Mud Weight: 9.8 ppg Mud Weight: 9.6 ppg 4 180 2 3020 2 60 0.30 980 Mud 10 min Gel: 18.0 Lb/100 Ft2 Mud 10 min Gel: 18.0 Lb/100 Ft2 6 340 3 3020 3 80 1.00 970 Test Pressure: 3000.0 psi Rotating Weight: 140000.0 Lbs 8 510 4 3020 4 120 1.50 960 Rotating Weight: 70000.0 Lbs Blocks/Top Drive Weight: 70000.0 Lbs 10 640 5 3020 5 160 2.00 950 Blocks/Top Drive Weight 70000.0 Lbs Desired PIT EMW: 18.0 ppg 12 800 6 3010 6 270 2.50 945 Estimates for Test: 2.8 bbls Estimates for Test: 1036 psi 0.9 bbl 14 950 7 3010 7 340 3.00 942 ~ 16 1125 8 3010 8 450 3.50 940 EMW =Leak-off Pressure + Mud Weight = 1000 PIT 15 Second 18 1250 9 3010 9 510 4.00 937 + 9 6 ,' , 0.052 x TVD 0.052 x 2371 Shut-in Pressure, psi 20 1350 10 3010 10 580 4.50 934 \ , ~ EMW at 2568 Ft-MD (2371 Ft-ND) = 17.7 ppg ~1- 995 22 1500 15 3010 11 650 5.00 932 aooo - Lost 10 ps i durin g test, held 24 1680 20 3010 12 Sv 700 5.50 930 99.7% of t est pre ssure. 26 1850 25 3010 13 _ 740 6.00 925 sooo - - - - 28 2050 30 3010 14 ~ 790 6.50 925 . ~ - - , 30 2250 15 _" 840 7.00 925 sooo - - - 32 2430 16 890 7.50 920 _ 34 2660 17 , 910 8.00 920 - 36 2840 18 ,.930 8.50 920 w zsoo ~ 38 3020 19 _ .950 9.00 920 - 20 " .. 970 9.50 , - 920 N zooo w ~ ~ 21 1000 10.00 ` 920 a 5~ laoo - ~ - "1 sooo - -- - 'S 500 0 3 4 0 5 1 0 1 5 20 2 5 30 0 1 2 Barrels OF ING TEST f LEAK ' F TEST Shut- O PIT In tim Point e, Minute s Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back - CAS 3.8 B s Bbls 2.1 B s B Is Comments: Tested Casing after bumping plug on cement job. ..~.~-T.,~ .~..~ ~u~~ .,may ~.. ~ ., ., .....,..~ Summary i CD2-464 7.625" Intermediate Casing Well: CD2-464 7 5/8" 29.7 f L-80 BTC-IVI Date: 6/9/2008 WI IV~ tN"! . it, hn. ~ ~_~ Depth Jt Number Joints Well Equipment Description and Comments Page 1 Length Tops __ _. __ _ _ _.. _. To of Strin or To of Flan e Do on 19 RKB to Lower lock down 33.89 FMC Gen V Han er 3.21 33.89 Jts 3 to 116 114 Jts 7 5/8" 29.7# L-80 BTCM CS 4916.27 37.10 Halliburton Float Collar 1.00 4953.37 Jts 1 to 2 2 Jts 7 5/8" 29.7# L-80 BTCM Csg 85.27 4954.37 Silver Bullet Float Shoe 2.10 5039.64 7 5/8' shoe @ 5041.74 5041.74 5041.74 5041.74 5041.74 5041.74 5041.74 5041.74 5041.74 5041.74 9 7/8" Hole TD @ 5,052' MD / 4,083.2' TVD 5041.74 7 5/8" Shoe @ 5041.74 ' MD / 4,082.4 'TVD 5041.74 5041.74 Total Centralizers - 43 5041.74 Straight blade centralizer one perjt on jts # 1-14 5041.74 Straight blade centralizer on jts # 59, 60, 61 5041.74 Straight blade centralizer one per jt on every other joint F/ # 63 TO # 113 5041.74 5041.74 5041.74 5041.74 5041.74 5041.74 125 joints in shed -116 total jts. to run 5041.74 Last 9 jts. out 5041.74 5041.74 5041.74 5041.74 5041.74 5041.74 Remarks: Used Run & Seal pipe dope, Ave MU 9K ft-Ibs Up Wt 200K Dn Wt 150 K Block Wt 75 K Supervisors: D. Burley / P. Wilson • °~ Cement Detail Report CD2-464 ...• Intermediate Casing Cement Cement Details , . Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 6/9/2008 18:30 6/9/2008 20:02 CD2-464 Comment Casing was cemented in 1 stage using surface tail cement at 15.8 ppg & 1.17 yield. - Cement Sta_ ges -- -- Sta a#1 Description Objective Top (ftK6) Bottom (ftKB) Full Return? Cmnt Rtrn ... Sop Plug? Btm Plug? Intermediate Casing Cement btm 892' of csg. 4,150.0 5,042.0 Yes 0.0 Yes Yes Cement O (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 7 6 390.0 1,250.0 Yes 8.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Cemented casing as follows, pumped 5 bbls CW 100, pressure tested lines to 3,700 psi, fin. pumping 25 bbls (30 total) of CW 100 at 8.3 ppg, ave 2.75 bpm at 225 psi., then pumped 30 bbls of MudPush at 12.5 ppg, ave. 5 bpm and 325 psi. Dropped btm plug. Mixed and pumped 53.8 bbls (256 sxs) of class "G" tail cmt at 15.8 ppg and 1.17 yield including additives, ave 5.5 bpm at 225 psi. Dropped top plug and Dowell pumped 20 bbls water then turned over to the rig and rig fin. displacing cmt with 207 bbls of 10.1 ppg LSND mud, ave. 7 bpm, ICP 250 psi, max press. 600 psi, with 10 bbls to go stopped reciprocating pipe and slowed to 3.5 bpm at 390 psi. Bumped plug to 1,200 psi. CIP @ 20:02 hrs. Reciprocated pipe and had full returns thru out job, checked floats and held. Calc TOC @ 4,150'. Cement Fluids & Additives - --- Fluid Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 4,150.0 5,042.0 256 G 53.8 Yield (ft'Isack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1l1 Report Printed: 6/16/2008., • • Security Level: Development Daily Drilling Report _ CD2-464 Report Number: 8 ..• Rig: DOYON 19 Report Date: 6/9/2008 AFE Type NetworWlD~... Total AFE+Sup 10217918 8,085,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (it) Depth Start (itKB) Depth End (ftKB) CD2-464 Development QANNIK 6.82 8.0 0.00 5,052.0 5,052.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 4,312.65 132,776.34 395,071.65 2,134,400.34 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 6/2/2008 6/3/2008 24.61 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 5,041.7ftKB 3 1/2 13,698.00 Ops and Depth ~ Morning Report 24hr Forecast Begin MU 6 3/4" Geopilot BHA #5 RIH W/BHA #5 PU 4" DP, Drill out, Perform FIT, Drill 6 3/4" Hole Last 24hr Summary Fin. pumping out & POOH LD BHA #4, C/O rams over to 7 5/8" csg & tested same to 250/3,500 psi, RU & RIH w/7 5/8" csg landing same @ 5,042' w/no problems. Circ & cond. mud then cemented csg w/full returns & reciprocation, no problems, est. TOC @ 4,150'. Installed 7 5/8" packoff & tested same to 5,000 psi for 10 min. Changed rams back over to VBR's. General Remarks Weather Head Count Floorhand got hand caught in csg tongs and was sent to town for further evaluation. 35 Deg., Cloudy/Overcast, Wind Var. 5 mph 53.0 SuperviSdr Trhe-< Dave Burley, Rig Supervisor Rig Supervisor Peter Wilson, Rig Supervisor Rig Supervisor Steve Shultz, Rig Supervisor Rig Supervisor Time Lo Start. End Dur ime Depth.Start Depth End Time Time (hrs) Phase Op Code OpSub-Cotle P-N-T "Trbl Code Trbl Class. (ftK6) (ftKB) Operation 00:00 01:00 1.00 INTRM1 DRILL TRIP P 732.0 177.0 Monitored well at HWDP, pumped out of hole to 269' then stood back std of HWDP and jars to 17T. 01:00 04:15 3.25 INTRM1 DRILL PULD P 177.0 0.0 LD NMFDC's and downloaded MWD, fin. LD BHA #4 and cleared rig floor. 04:15 04:30 0.25 INTRMI DRILL PULD P 0.0 0.0 Pulled wear bushing 04:30 07:00 2.50 INTRM1 CASING NUND P 0.0 0.0 Changed out top set of pipe rams to 7 5/8" csg and tested same to 250!3,500 psi.. Sim-op: Changed out top drive saver sub to 4" XT-39. 07:00 07:15 0.25 INTRMI CASING OTHR P 0.0 0.0 Installed thin walled wear bushing. 07:15 08:30 1.25 INTRM1 CASING RURD P 0.0 0.0 RU to run 7 5/8" csg with Franks fill up tool. 08:30 08:45 0.25 INTRM1 CASING SFTY P 0.0 0.0 Held PJSM with crew on running casing. 08:45 13:30 4.75 INTRM1 CASING RNCS P 0.0 3,104.0 Ran 7 5/8" 29.7# L-80 BTCM casing as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Halliburton super seal II) - 1 jt csg (all connections made up w/ BakerLoc -filled pipe & checked floats) RIH with 69 jts csg (72 jts total) to 3,104'. 13:30 14:15 0.75 INTRM1 CASING CIRC P 3,104.0 3,104.0 Circ btms up while staging pump rate up to 7 BPM at 620 psi. PU wt 154 SO wt. 133. 14:15 16:45 2.50 INTRM1 CASING RNCS P 3,104.0 5,042.0 Cont. RIH with 7 5/8" csg from 3,104', MU FMC hanger and landed csg at 5,041.74' and flt collar at 4,953' with no problems. PU wt 215K, SO wt 148K. Ran a total of 116 jts of 7 5/8", 29.7#, L-80, ~ BTCM csg, total including float equip and ~~ hanger 5,007.89'. Ran 43 straight blade cent. per well plan. 16:45 17:15 0.50 INTRMI CEMENT RURD P 5,042.0 5,042.0 RD Franks fill up tool and MU Dowell '~ cement head. Latest BOP Test Data --- - _ _ - Date Comment 6/6/2008 Tested BOPE 250/2,500/3,500 si. NOTE: Chuck Scheve w/AOGCC waived witnessin of test Page 1/3 Report Printed: 6/1612008 Security Level: Development Daily Drilling Report CD2-464 Report Number: 8 ..• Rig: DOYON 19 Report Date: 6/9/2008 Time Log -- -_ _ ..Start Time _ - End Time Dur (hrs). phase. Op Code Time OpSub-Code P-N-T Trbl Code Trbl Ctass. - Depth Start i (ftKB) - Depth End (ftKB) Operabp~ 17:15 18:45 1.50 INTRM1 CEMENT CIRC P 5,042.0 5,042.0 Circ and cond. mud for cementing, staged pump rate up from 2 bpm at 260 psi to 7 bpm at 490 psi, cond. mud to 10.1 ppg in and out, held PJSM while circ hole, PU wt 200K, SO wt 150K . 18:45 20:15 1.50 INTRM1 CEMENT DISP P 5,042.0 5,042.0 Cemented casing as follows, pumped 5 bbls CW 100, pressure tested lines to 3,700 psi, fin. pumping 25 bbls (30 total) of CW 100 at 8.3 ppg, ave 2.75 bpm at 225 psi., then pumped 30 bbls of MudPush at 12.5 ppg, ave. 5 bpm and 325 psi. Dropped btm plug. Mixed and pumped 53.8 bbls (256 sxs) of class "G" tail cmt at 15.8 ppg and 1.17 yield including additives, ave 5.5 bpm at 225 psi. Dropped top plug and Dowell pumped 20 bbls water then turned over to the rig and rig fin. displacing cmt with 207 bbls of 10.1 ppg LSND mud, ave. 7 bpm, ICP 250 psi, max press. 600 psi, with 10 bbls to go stopped reciprocating pipe and slowed to 3.5 bpm at 390 psi. Bumped plug to 1,200 psi. CIP @ 20:02 hrs. Reciprocated pipe and had full returns thru outjob, checked floats and held. Calc TOC @ 4,150'. 20:15 21:00 0.75 INTRMI CASING DHEQ P 5,042.0 5,042.0 RU and tested casing to 3,500 psi for 30 min. 21:00 21:45 0.75 INTRMI CASING RURD P 5,042.0 5,042.0 RD cmt head, landing jt and long bales. 21:45 22:45 1.00 INTRM1 CASING OTHR P 5,042.0 5,042.0 Pulled thin walled wear bushing and installed 7 5/8" packoff, tested same to 5,000 psi for 10 min. 22:45 23:45 1.00 INTRM1 CASING NUND P 5,042.0 5,042.0 PJSM, changed out top set of rams back to 3 ?" x 6" VBR's, set Sperry's Geo Span on rig floor and installed short bales. 23:45 00:00 0.25 INTRMI WELCTL - -_ _ OTHR P 5,042.0 5,042.0 Installed test plug and filled stack. _ _- Mud Check Data _ YP Calc Gel (1os) Gel (tOm) Gel (30m) - HTHP Filt ~ Density Temp Solids, Corr. Type Qepth(ftKB) Dens(Iblgap Vs(s7gt) 'PVCaIC(cp) _ (Ibf/100ft') (!bf/100ft~ Qbf/100ft') (Ibff100ft') MBT(Ib/bbl) (mL/30min) pH ( (°F) (~) LSND 5,052.0 10.00 41 10.0 18.000 7.0 9.0 11.000 20.0 9.4 3.0 - - -- lin'ection Fluid Fluitl. ~ Source From Lease (bbl) Destination ~- Note _ Water Based Mud CD2-464 280.0 CD1-19 ~~ ',Drill Strin s: BHA No. 4 - Steerable / Bit Run No. $ - 9 7/8in, Hu hes HCM -5052 7110659 Deptli In (ftK6) Depth Out (ftK6) TPA (incl Noz) (in') Nozzles (132") IADC Bit Dull String Wt (10001bf) 2,578.0 5,052.0 0-2-CT-G-X-2-NO-TD 35 Drill Strin Com onents Jts Item Description OD (in) I' ID (in) .Top Conn Sz {in) Top Thread Cum Len (ft) HWDP 5 3.000 41/2 1F 431.41 Drilling Jars -Hydraulic 6.19 2.250 4 1/2 IF 464.19 HWDP 5 3.000 41/2 1F 556.80 Drill Collar 6.65 2.810 4 1/2 IF 587.87 Drill Collar 6.71 2.880 4 1/2 IF 618.98', Drill Collar 6 3/4 2.810 4 1/2 IF 650.OT Orientation Sub 6.67 2.815 4 1/2 IF 653.41 MWD (Dir & Logging) 6 3/4 1.920 4 1/2 IF 663.43 Page 213 Report Printed: 8/18/2008 Security Level: Development - Daily Drilling Report - CD2-464 - Report Number: 8 ..~ Rig: DOYON 19 Report Date: 6/9/2008 Drill Strin Com onents ___- ~ _ - Jts item Description ' OD (ih) r iD (in) 7oprConn Sz (in) Top Thread um ten (ft) , , MWD (Dir & Logging) 6 3/4 1.920 4 1/2 IF 691.43 MWD (Directional) 6 3/4 1.920 4 1/2 IF 700.26 Stabilizer 6.55 2.250 41/2 1F 705.21 Float Sub 6 11/16 2.813 4 1/2 IF 707.34 Mud Motor 7 4.753 4 1/2 IF 732.77 PDC Bit Hughes HCM 5062 9 7/8 6 5/8 Reg 733.86 __ Wellbores _ - _ - ___ _ - _ Wellbore Name Wellbore APtlUWI CD2-464 501032057400 _ - -- Secfioh - Size (inj ,ACtTop (ftK8). - -- Act Btm (ftK8) Start Date End ate _ COND1 - -- 16 0.0 114.0 SURFAC 13 1/2 114.0 2,578.0 6/3/2008 6/5/2008 INTRMI 9 7/8 2,578.0 5,052.0 6/7/2008 6/8/2008 PROD1 6 3/4 5,052.0 107,765.0 6/11/2008 6/14/2008 _ - --- Casing Strings -- - __ Casing Desciptoon Run Date __ ~ OD'(n) Wt (Ibs/k) Grade LL .Set Depth (ftK8) Comment Intermediate 6/9/2008 7 5/8 29.70 L-80 5,041.7 Ran 7 5/8" 29.7# L-80 BTCM casing as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg - Float collar (Halliburton super seal II) - 1 jt csg (all connections made up w/ BakerLoc -filled pipe & checked floats) RIH with 69 jts csg (72 jts total) to 3,104'. Circ btms up while staging pump rate up to 7 BPM at 620 psi. PU wt 154 SO wt. 133. Cont. RIH with 7 5/8" csg from 3,104', MU FMC hanger and landed csg at 5,041.74' and flt collar at 4,953' with no problems. PU wt 215K, SO wt 148K. Ran a total of 116 jts of 7 5/8", 29.7#, L-80, BTCM csg, total including float equip and hanger 5,007.89'. Ran 43 straight blade cent. per well plan. Cemenf -__ - _ - Intermediate Casin Cement -Started 6/9/2008 Type Wellbore Cemented String Cement Evaluation Results casing CD2-464 Intermediate, 5,041.7ftKB Stg No. Description Top (ftK8) Bottom (ftK8) Q (end) (bbl/... P (final) (psi) 1 Intermediate Casing Cement 4,150.0 5.042.0 7 390.0 'Fiwd Class Amount (sacks) V (bbl) Density(IWgal) Yield(fN/sack) I Est Top (ftK6) _ Est BUYS (ftK6) Tail Cement G 256 53.8 15.80 1.17 4,150.0 5,042.0 Page 3/3 Report Printed: 6/1612008 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-464 Rig: Doyon 19 Date: 6/10/2008 Drilling Supervisor: D. Burl@y / P. W IISOn Pump used: Cement Unit ~ Volume Input Pump Rate: Barrels ~ Bbls/Strk ~ 0.80 Bbl/min ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test Pressure In tegrit Test Hole Size: 9-~/s" ~ Casing Shoe Depth Hole Depth Pum ping Shut-in Pumping Shut-in RKB-CHF: 33.0 Ft 2568.0 Ft-MD 2371.0 Ft-TVD 4150.0 Ft-MD 3708.0 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: ~-5/s" 29.7#/Ft L-80 BTC-MOD ~ 0 0 0 0.00 810 Chan es for Annular Ade uac Test Pressure Int e rit Test 1 0.5 245 0.15 766 Enter outer casing shoe test results in comments Mud Weight: 10.1 ppg 2 1 340 0.30 762 Casing description references outer casing string. Inner casing OD: 7.6 In. 3 1.5 475 1.00 757 Hole Size is that drilled below outer casing. 4 2 596 1.50 754 Use estimated TOC for Hole Depth. 5 2.5 710 2.00 751 Enter inner casing OD at right. Desired PIT EMW: 17.2 ppg 6 3 796 2.50 750 Estimates for Test: 875 psi 0.1 bbl 7 3.4 850 3.00 749 ~ ~ ~ 8 4 793 3.50 748 EMW =Leak-off Pressure + Mud Weight = 710 PIT 15 Second 9 4.5 797 4.00 747 + 10.1 0.052 x TVD 0.052 x 2371 Shut-in Pressure, psi 10 5 802 4.50 747 371 Ft-ND) _ 15.9 . ~'~ EMW at 2568 Ft-MD (2 __ 766 15 5.5 802 5.00 745 Joao . - - - - - 20 6 806 5.50 744 ~ I 25 6.5 810 6.00 744 ~ ,._ 30 6.50 743 ` ` .?~ 7.00 743 Aso - - y 7.50 742 i ~" ~ r a ~ ~ 8.00 741 w ^Ci ~ 8.50 740 ~ \ a ~ `~~~ 9.00 740 9.50 T3'9 N soo w -- 10.00 738 a __ 2so i 0 7 1 0 1 5 20 2 5 30 0 1 ~t~ 2 3 Barrels 4 5 tLEAK OFF TEST 6 0 5 Shut- O PIT In tim Point e, Minute s Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back CASING TES T - bls Bb s 6.5 Bbls b s Comments: 10 3/4" LOT 17.7 ppg Summary Pressure Integrity Test CD2-464 1500 - - i i Casing Test - - -Theoretical Minimum Volume Anticipated Leak-off Pressure ~"'~~Leak-off Test ~ - - - - - - - -Theoretical Maximum Volume O FIT Point 1000 ~i i - -Maximum Pressure W I , I N N W I, a 500 '~ '', , -- - - ~i 0 0.0 1.0 2.0 3.0 4.0 5.0 6.0 7.0 Barrels GUZ-464 Annulus LU 16-1U-Uii LGG .xls • PIT Plot Chart 1 • • Note to File CD2-464 (208-082...308-234) Colville River Unit (Qannik) ConocoPhillips Alaska, Inc ConocoPhillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. -- No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 150 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 38% XS of the calculated hole volume. -- On the initial leak off test, the pressure slope rises smoothly to 15.3 EMW and continues at a shallower slope to 17.7 EMW. Minimal fluid was pumped in. The pressure declined slightly during the observation period to about 17.0 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7-5/8" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. --An infectivity test down 10-3/4" x 7-5/8" annulus was conducted. Pressure steadily increases until the break at 17.0 EMW. The pressure declined with additional pumping to 16.7 EMW. During the observation period, the pressure declined to 16.1 EMW. The lower EMW of the pump in tes# indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --There are 28 welts within%4 mile radius of CD2-404 with 6 wells within 450'. The surface shoe of CD2-41 is closest, about 125' distant. CD2-15 was recommended for annular disposal in 2003. CD2-38 is 154' distant. AD was recommended for CD2-38 in 2003. CD2-36 is 217' distant and was also approved for AD. All proximate wells have been examined and are in my database. There are no ident~ed issues with any of the wells. Based on examination of the submitted ConocoPhillips' request for the subject well 38 and CD2-36, CPAI should monitor the while pumping on CD2-464. c"fV information, I recommend approval of Due to the proximities of CD2-41, CD2- outer annulus pressures on these wells Tom Maunder, PE Sr. Petroleum Engineer July 3, 2008 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\080703--CD2-464.doc Note to File CRU CD2-464 (PTD 2080820) July 2, 2008 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Welt CD2-4G4 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus surrounding the 7" casing within well CD2-464. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-S/8" surface casing shoe is set in this well at about 2,562' measured depth (-2,319' true vertical depth subsea, or "TVDSS"), near the base of a 400-foot thick shale and mudstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone, sandy siltstone, and sandstone open to the surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining layer is sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval 4. There are no potential USDWs in this area. S. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of about 100' from the wellbore. Discussion CPAI's application was reviewed along with records from nearby wells Nuiqsut 1 and Alpine 1. The discussion that follows is based on well logs from Nuiqsut 1, Alpine 1, Colville River Unit (CRU) CD2- SS, CD2-39, and CD2-S2. Index maps are provided in Figures Land 2, below. The CD2-464 development well was drilled to the Qannik Oil Pool within the Colville River Unit. ConocoPhillips intends to dispose of drilling wastes utilizing an open annulus within CD2-464 that extends downward from the 9-S/$" surface casing shoe, which is set at about 2,562' measured depth (-2,319' TVDSS), to the top of +cement for the T' casing string, which is estimated to lie at about 4,150' measured depth (-3,655' TVDSS). This annulus lies within Section 2 of TllN, R4E, UM (see Figures 1 and 2), and it lies more than three miles from the current boundary of the CRU. The section of open annulus that will most likely accept the injected waste fluids is a 120-foot thick portion of the Seabee formation that extends from 2,658' to 2,803' measured depth (-2,400' and -2,524' TVDSS; see Figure 3, below). This interval contains several 1- to S-foot thick beds of siltstone, sandy siltstone and sandstone that are separated by mudstone and shale. The aggregate thickness of the siltstone, sandy siltstone and sandstone beds is about 2S'. The apparent siltstone that lies immediately beneath the 9-S/8" casing shoe of CD2-464 is likely an artifact caused by circulating and cementing. In offset • • CD2-464 July 2, 2008 Note to File Page 2 of 6 exploratory wells, the correlative sediments to those surrounding the 9-5/8" casing shoe consist of shale, claystone, and minor amounts of siltstone (see Figure 4, below). The 9-5/8" surface casing shoe lies near the base of a 400-foot thick interval that is dominated by shale and mudstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely injection interval is a 50-foot thick zone of claystone and mudstone that is also continuous throughout the area. This interval, which lies between 2,848' and 2,905' measured depth (-2,562' and -2,610' TVDSS), and several similar underlying strata will provide lower confinement for injected wastes. Figure 1. Indez Map (The path of the cross-section shown on Figure 3 is highlighted with magenta) In vicinity of Drill Site CD2, the base of permafrost occurs at about -1,200' TVDSS, which is about 1,100' shallower than the top of the proposed injection interval. Conclusion 3 of Area Injection Order 18, which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. Alpine 1 is an exploratory well located about one mile southeast of Drill Site CD2. In Alpine 1, methane was first encountered at 760' measured depth (about -720' TVDSS), and it was encountered in significant quantities (more than 1% methane in air, or 50 units) at 1,155' measured depth (about -1,015' TVDSS). So, the entire proposed disposal zone likely contains some methane gas. i • CD2-464 July 2, 2008 Note to File Page 3 of 6 coase ~ ;~ __, ~ ~ \ .Ir ~ c /rte \ \ ~ i y2 ~ ,I 33 4 ~ z C~.54 CD 3]B 11qq \ \ KF I.I] t 01~i5~ \~ - - .~ i' ~. f1Ul SUT I ' , , , _._ Nuiqsut 1 ~° ` ~ _ ~~~ `~, CD2-464 V'~;`~. Alpine 1 Annulus ~~\~ ~ "~ ~~,,. IB ' 10 ~~ `~~~sA E'T In C 3~l ! T ].N I \ 178 \ 1 I ~ ~°' ~, C 2-44 I.SE I 2 S Q Cfr§ UI •.\ 1 ~ ~~ 15 5 ,.,,,I ~o Figure 2. Expanded Index Map (CRU CD2-464 open annulus highlighted with red; the path of the cross-section shown on Figure 3 is highlighted with magenta) The shallowest oil show encountered in Alpine 1 was a poor show observed between 2,980' and 3,080' measured depth (from about -2,940' to -3,040' TVDSS). However, the description of this show note does not mention oil staining; the show was noted based on sample and solvent cut fluorescence. The shallowest record of visible oil staining is found in the description of a fair oil show that occurs from 4,025' to 4,080' measured depth (about -3,985' to -4,040 TVDSS), which is about 950 true vertical feet below the most likely receptor beds for the injected material. So, at Drill Site CD2, the most likely disposal interval does not contain potentially commercial hydrocarbons. The chart presented in Figure 5, below, provides an estimate of the subsurface volume around CD2-464 that will be affected by the proposed annular disposal operations. There are about 25' of porous siltstone, sandy siltstone and sandstone beds within the most likely disposal interval, according to a count using the gamma ray curve from CD2-464. Porosity well logs were run across this interval in Alpine 1, CD2-32, and Nuiqsut 1, which are located 1 mile east, 1 mile west, and 3 miles west, respectively. Inspection of the density porosity measurements in offset wells Alpine 1 and Nuiqsut 1 suggests an average porosity of about 27% for the siltstone, sandy siltstone, and sandstone beds. Based on these values, the proposed annular injection activities will directly affect the receptor beds only to a radius of about 100' from the wellbore, as indicated below. CD2-464 Note to File Upper Confining Strata Most Likely Receptor Strata for Disposed Fluids Lower Confining Strata Lower Confining Strata • • Correlation Depth Ress r_;RfSGRCI <MD RT 1 i i api 24 200 ohmm 200.00 TVDSS; ,and -Silt -Shale T'~:~_~ -MD Surface Casing _:.;;.~, 3o -2350 `~ ~." 't~00 c- ;~ 2450 -2400 ~_ ~~. 2700 - } ?~;i ii i -2450 -r j 2550 -2500 - ' ~~~ ~' 2600 -2550 s 2650 -2600 f x 2700 -2650 ~ '~ '000 2750 ~. _~ -2700 ~ { ~ c-2u ~ .` ,.'^(III ~l50 July 2, 2008 Page 4 of 6 Figure 3. CD2-464 Well Log for Affected Intervals • CD2-464 Note to File July 2, 2008 Page 5 of 6 W 1980250 2031180 2060620 501032025300 11590 fl 501032006300 1016 fl 50103205]000 325 fl ARCO CONOCOPHILLIPS MASK CONOCOPHILLIPS MASK NUIDSUTI CULVILLE RN UNIT CD2-55 COLVILLE RN UNIT CO2d6.1 2011600 501032038100 296 fl CONOCOPHILLIPS ALASK COLVILLE RN UNIT CD2a9 2030930 501032045900 3062 fl CONDCOPHILLIP6 MASK COLVILLE RIV UNIT CD252 1901T20 501032021100 ARCO ALPINEI I T .y L ~ _.. ; - ., ~ ~~ ~ ~ -500 - ~ ~, _ ~-. TT .$pp - 't 1000 _. ~ - _ ~ - - - - .s ~ 1000 . 3( _ )) f . (g ~ - y - f _ _ - - t -1500 - ~ - -1500 - I J~ J j - - .. ~il ~. t ~ ~ _ , 9-5/8" casing shoe i -29~ ., ~~ ; Upper Cori fir~ing Strata - ,' -~ I I ~Y~C . ~ - ~ r - - ~ ~ - I r ~ ~ T' 2~ -- ~ ~ ` . ~ isposal Zone { ~ ~' ~ ` '' 2500 - F -4 t ( " ~ ~ . - ~ ~ ~ ~ L ~' I ~ } - -- ;. -~_ ____ - # 1 _ ower } - ~, ~ Confining i ~ 1 ~ ~~ P - - '~ - aao0 -~~ t ~ :Strata -~ F - ~ ~ - ~ ~ 4 ` - 1 gg t - ~ t ~ 1 ~ - f .~ - ~ ~ a50D - ' ~ ~- i s ~ r : _i f ~ -~ ~ t r' ~ ~___. _._. - _ Y S s S ~ 1 '~ t I ~ ~~ ~~ - - _ ~ ~ ro_1as9a +- - - ~; ~ ~ i ~ ~asoa I ~ nl ~ ~ 11 ~ - _ ~ _ ~ i 1 ~4sao Figure 4. Structural Cross-section from Nuiqsut 1 to Alpine 1 • CD2-464 July 2, 2008 Note to File Page 6 of 6 Injected Fluid vs Affected Radial Distance CD2-464 Wellbore (assumes 25' aggregate injection zone thickness and 27% porosity) 300 m 250 m `o a 200 E 0 m ~ 150 w A 100 d .. v m 50 Amount of Injected Fluid (barrels) Figure 5. Radial Distance Potentially Impacted by CD2-464 Injection Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains methane gas, is situated beneath about 1,100' of permafrost, and is bounded above and below by continuous layers of shale, mudstone and minor amounts of siltstone. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath CD2-Pad. The open annulus that will be used for disposal injection lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. 1 recommen approval of this annular disposal project. _ ~ Steve Davies Senior Petroleum Geologist ~~77 ~~~~ ~~ /. ~~~ , 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Page 1 of 1 Maunder, Thomas E (DOA) From: Noel, Brian [Brian.Noel@conocophillips.com] Sent: Thursday, July 03, 2008 12:17 PM To: Maunder, Thomas E (DOA) Cc: Reilly, Patrick J; Galiunas, Elizabeth C Subject: RE: CD2-464 (208-082) Tom - Drilling the 13-1/2" surface hole required an extra round trip to increase motor's AKO setting to achieve build rate needed to steer past adjacent wells from 1374 - 1659' MD. The BHA and wiper trips encountered occasional tight spots but the hole was drilled, circulated clean and casing run in 9.8 ppg gel/water spud mud without difficulty. The 9-7/8" intermediate section was drilled with a motor and 10 ppg LSND mud in one trip and casing run without any problems. Let me know if additional information is needed. Thanks -Brian From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, )uly 03, 2008 11:50 AM To: Noel, Brian Subject: CD2-464 (208-082) Brian, Could you provide a summary of how the surface and intermediate holes drilled on this well? I am reviewing the AD application and since the 407 has yet to be filed, I don't have much information other than the cementing. The cementing operations look very good. Thanks in advance, I look forward to your reply. Tom Maunder, PE AOGCC 7/3/2008 pp ~.; °- ~~, ~, a~,.~ f„3 f.,(,T~ 't~ "^~.° j ~ ~.1~w~.S ~ ~.:::~s l..d k~ ~. _~ } ;_!; ~.s~j ..) /~ ALASSA OIL A1~TD GAS CO1~T5~RQATIOIK CO1rII-IISSIOIQ C. Alvord WNS Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Colville River Qannik Undefined, CD2-464 ConocoPhillips Alaska, Inc. Permit No: 208-082 Surface Location: 2188' FNL, 1825' FEL, SEC. 2, T11N, R4E, UM Bottomhole Location: 1826' FNL, 3809' FEL, SEC. 13, T11N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit iri the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). incerely, .~~ Daniel T. Seamount, Jr. r Chair DATED this ~ day of May, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ;~ElVED STATE OF ALASKA ~iAY ~ 0 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~ l~~a Gii ~ Gas Cons. Commission ~1nChOta~2 1 a. Type of Work: Drill /^ Re-drill ^ Re-entry ^ 1 b. 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: CD2-464 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13698' ND: 4107' . 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 2188' FNL, 1825' FEL, Sec 2, T11 N, R4E, UM 7. Property Designation: ADL 380075 Qannik Oil Pool Top of Productive Horizon: 3848' FNL, 245' FEL Sec 2, T11N, R4E, UM 8. Land Use Permit: ALK 380075 13. Approximate Spud Date: 6/1/2008 Total Depth: 1826' FNL, 3809' FEL, Sec 13, T11 N, R4E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 2.5 mi from Alpine PA 4b. Location of Well (State Base Plane Coordinates): -3 °/~YNlrl .2R (. 1t 9S: !1 Surface: x- 371409. y- 5974174.4 `Zone- 4 10. KB Elevation ~ SZ ~.Sl.+ (Height above GL): 37' RKB feet S 2 15. Distance to Nearest p~~g • VVell within Pool: CD2-57 140' at 7567' MD 16. Deviated wells: Kickoff depth: 300 ~ ft. Maximum Hole Angle: gp° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1816 psig , Surface: 1433 psig 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size pec ca ons T op Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 114' pre-installed 13.5" 10-3/4" 45.5# L-80 BTCM 2559 37 37 2596 2400 578 sx ASL3, 270 sx 15.8 cl G 9.875" 7-5/8" 29.7# L-80 BTCM 4950 37 37 4987 4061 235 sx 15.8 cl G 3.5" 9.3# L-80 EUE-M 4805 32 32 4837 4038 Tbg 6.75" 3.5" 9.3# L-80 SLHT 8851 4837 4038 13688 4106 Slottled liner in open hole 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketct^ Drilling Progran0 Time v. Depth ^t Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch^ Seabed Reporl^ Drilling Fluid Prog / 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 L. Galiunas Printed Name C. Alvord Title WNS Drilling Team Lead Signature Phone ~ ~ ~ Date +~` (~q r 2~ \ 1 ~ - ~ '7 Only Commission U s e Permit to Drill Number: 26 ~ ~dg'Z. API Number: 50- /Q 3 ^ ?pS 7 T ~ ~~ Permit Approval Date: ~~ 0~3 ~~~ 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 ~meythane, gas hydrates, or gas contained in shales: Samples req'd: Yes - t=1 Mud log req'd: es ^ Other. ~~}~1 t H2~S`~leasures: Yes ~ ~t [~ Directional svy req'd ^'~: ° No 3 _ a ~ THE COMMISSION DATE: ~ - ~~ „/` ,COMMISSIONER ~rOfm 1U-4U1~hteVlSed 1'L/ZUUb `..! t ~ ~ '`-r' ~ ~ ° ' ~" ° ~uorry~i ni v ucare O „! ~cY, S $ ConocoPhillips Alaska, Inc Post Office Box 100360. Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 20, 2008 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-464 Dear Sir or Madam: ~C}I10COP""11~~1 5 ~~v~' MAY 2 a coos Alaska aiJ & Gas ~0ns° commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD2 drilling pad. The intended spud date for this well is 06/01/08. It is intended that Doyon Rig 19 be used to drill the well After setting 7-5/8" intermediate casing, the horizontal section will be drilled and the well completed as a slotted liner producer. At the end of the rig work program, the well will be flowed back for 2-3 days to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities connection that will allow the well to begin production. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At CD2, there has not been a significant show of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program. 3. A proposed completion diagram. 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b)~ Information pertinent to the application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Riser setup If you have any questions or require further information, please contact Liz Galiunas, 265-6247, or Chip Alvord at 265-6120. Sincerely, 0 Liz Galiuna Drilling Engineer Attachments cc: CD2-464 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Nina Anderson ATO 1704 Tim Schnieder ATO 1706 Lanston Chin Kuukpik Corporation CD2-464 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13-1 /2" Hole / 10-3/4" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low ~ Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations ' >2000' ND Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' ND ~ increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-3/4" Hole /Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7-5/8" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Low BOPE drills, Keep mud weight above 8.8 ppg. Check Pressure for flow during connections and if needed, increase ' mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas. Low HZS drills, detection systems, alarms, standard well control practices, mud scavengers Wellbore Stability Moderate Use mineral oil based mud. Maintaining high enough mud weight to stabilize shales. Use mirconized barite for increased weight without increasing ECD. Monitor and mana a ECDs throu hout lateral. ORIGINAL Procedure 1. Move on Doyon 19. 2. Rig up riser, dewater cellar as needed. 3. Drill 13-1/2" hole to the surface casing point as per the directional plan. (Directional/MWD). 4. Run and cement 10-3/4" surface casing. 5. Install and test BOPE to 3500 psi. 6. Pressure test casing to 2500 psi. 7. Pick up and run in hole with 9-7/8" drilling BHA. 8. Drill out 20' of new hole. Perform leak off test. i 9. Drill 9-7/8" hole to intermediate casing point in the Qannik sand. (LWD Program: GR/RES/PWD) 10. Run and cement 7-5/8" casing as per program. Carry out a leak off test down the 10-3/4"x7-5/8" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. BOPE test to 3500 psi. 12. Drill out 20' of new hole. Perform formation integrity test. 13. Drill 6-3/4" horizontal section to well TD (LWD Program: GR/RES/PWD). 14. Circulate the hole clean and pull out of hole. 15. Run lower completion with 3-1/2" slotted liner and liner hanger. 16. Run 3-'/, 9.3#, L-80 tubing with SCSSSV, gas lift mandrels, packer and stinger assembly. Sting in, space out and land hanger. 17. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 18. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 19. Circulate tubing to diesel and install freeze protection in the annulus. 20. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 21. Set BPV and secure well. Move rig off. ORIGINAL Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-56 is the nearest existing well to the CD2-464 plan at 11.8' well to well separation at 1281' MD. Drilling Area Risks: There are no high-risk events. Lost circulation: Micro-fracturing within the Qannik reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD2-464 will be injected into a permitted annulus on CD2, or the class 1 disposal well on CD1 pad. The CD2-464 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Qannik reservoir and there will be 500' of cement fill above the top of the Qannik as per regulations. Upon completion of CD2-464 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) " (0.052) * (Surf. Shoe ND) + 1,500 psi _ (12.0 ppg) " (0.052) * (2400') + 1,500 psi = 2997 psi Pore Pressure = 1,131 psi Therefore Differential = 2997 - 1131 = 1866 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 10-3/4" 45.5 L-80 3 BTC-M 2480 2108 psi 3580 psi 3043 psi 7-5/8" 29.7 L-80 3 BTC-M 4790 psi 4071 psi 6890 psi 5856 psi ORIGINAL • • DRILLING FLUID PROGRAM SPUD to 10-3/4"surface casing point -13- 1/2" Intermediate hole to 7- 5/8"" casing point - 9-7/8" Production Hole Section - 6 3/4" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 pP9 ~ PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 -30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10-15 10 minute gels <18 12-20 API Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) NA HPHT Fluid Loss at 160 12-14 cc/30 min PH 8.5-9.0 9.0-10.0 9.0-9.5 KCL 6% Oil/water ratio Approx. 60/40 Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a 60/40 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flashpoint (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. ORIGINAL Completion Schematic Updated 05/19/08 16" Conductor to 114' Sperry Drilling WP07 I s - 4-%2' space out pups -3--%2" x 4-%2' cross-over, 2 jts below 4-'h" hanger GL Qannik Producer CD2-464 Production Well Completion 3-1/2" Camco TRMAXX-5E SSSV Nipple (2.813" tD) With single Y+"x0.049" s/s control line Packer Fluid mix: Diesel in tubing and annulus 10-3/4" 45.5 ppf L-80 BTC-mod Uooer Completion MD TVD Surface Casing ' ' 1) Tubing Hanger 32' 32' @ 2596 MD / 2400 TVD 2) 4-''/=" 12.6 #/ft IBT-Mod Tubing (2) cemented to surface 3) 4-'/i' 12.6 #/ft IBT-Mod SPACE OUT PUPS 4) Crossover 5) 3-112", 9.3#!ft, EUE-Mod Tubing 6) Camco TRMAXX-5E SSSV w/ x profile 2655' 2450' 7) 3-1/2", 9.3#/ft, EUE-Mod Tubing 8) Camco KBMG GLM (2.867" ID) w/dummy 3771' 3400' 9) 3-1/2", 9.3#/ft, EUE-Mod Tubing 10) Camco KBMG GLM (2.867" ID) w/DCK2 shear 4410' 3878' 11) 3'/Z'9.3#/it,EUE-M (1) 12) Baker 3.5" X 7-5/8" Premier Packer 4460' 3905' 13) 3-Y:" 9.3#/ft, EUE-M (2) 14) HES "XN" 12.75" min ID)_(a) 64° 4560' 3953' 15) 3 Yz' 9.3#/ft, EUE-M 16) 3-'/~' 9.3#/ft, EUE-M with mule shoe WLEG sub 4818' 4038' bottom, 3' above Top of liner @ 4821' Lower Completion: Top MD TVD 17) Baker 5"x7" Flexlock Liner Hanger w/setting sleeve (150' up from shoe) 4837 4042' 18) 3-''/i', 9.3#/ft, SLHT Tubing 19) 3-'/~' 9.3#/ft L-80 SLHT liner w/ blanks and constrictors across shale and slots across sand 20) Baker Shoe 13688' 4106' Camco KBMG GLM (2.867" ID) With DCk-2 SOV set for 3000 psi io 3 '/i' 9.3#/ft SLHT liner: 8 slots / ft, 2 '/:' x 1 /8" slots TOC @ +(- 4150 MD 13708' TVD 300' above packer depth 6'/."iHole Top Qannik 4971 MD / 4060 TVD 7-5/8" 29.7 ppf L-80 BTC Mod Production Casing @ 4987' MD / 4061' TVD Well TD at 13,698' MD / 4107' ND ORIGINAL PRESSURE INFORMATION (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 10-3/4" 2596 / 2400 14.5 1086 1566 7-5/8" 4987 / 4061 16.0 1837 1431 N/A 13698 / 4107 16.0 1858 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASPS ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP=[(FGx0.052)-0.1]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (10-3/4") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1] x 2400 = 1569 psi OR ASP =FPP - (0.1 x D) = 1837 - (0.1 x 4061) = 1431 psi Drilling below intermediate casing (7-5/8") ASP =FPP - (0.1 x D) = 1858 - (0.1 x 4107') = 1447 psi ORIGINAL Cementing Program: 10-3/4" Surface Casing run to 2596' MD / 2400' TVD. Cement from 2596' MD to 2096' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2096' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1569' MD). Lead slurry: (2096-1569') X 0.3637 ft3/ft X 1.5 (50% excess) = 287.5 ft3 below permafrost 1569' X 0.3637 ft3/ft X 4 (300% excess) = 2282.6 ft3 above permafrost Total volume = 287.5 + 2282.6 = 2570 ft3 => 578 Sx @ 4.45 ft3/sk System: 578 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW' D044 freeze suppressant Tail slurry: 500' X 0.3637 ft3/ft X 1.5 (50% excess) = 272.8 ft3 annular volume 80' X 0.5397 ft3/ft = 43.1 ft3 shoe joint volume Total volume = 272.8 + 43.1 = 315.9 ft3 => 270 Sx @ 1.17 ft3/sk System: 270 Sx Class G + 0.2% D046 antifoamer, + 1 %S2, 0.2%D46, 0.3%D65 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7-5/$" Intermediate Casing run to 4987 MD / 4061' ND Cement from 4987' MD to 4150' MD (minimum 300' MD above the packer). Assume 40% excess annular volume. Tail: (4987' - 4150') X 0.2146 ft3/ft X 1.4 (40% excess) = 251.5 ft3 annular vol. 80' X 0.2577 ft3/ft = 20.6 ft3 shoe joint volume Total volume = 251.5 + 20.6 = 272.1 ft3 => 235 Sx @ 1.16 ft3/sk System: 235 Sx Class G + Class G + 1 %S2, 0.2%D46, 0.3%D65 @ 15.8 PPG yielding 1.16 ft3/sk By Weight Of mix Water, all other additives are BWOCemenAAt ~~ ii • ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD2 Alpine Pad Plan: CD2-464 Plan: CD2-464 Plan: CD2-464wp07 Standard Proposal Report 16 May, 2008 HALLIBURTC~IV Sperry Drilling Services ORDINAL r r.' E,ro, nrem:ISCwsA Scan Methotl: Trav. Cylin Cer NOrth ErtotSUrtace: EIIIptICalCOnlc Western North Slope ConoeoPhillips Waming Methotl: Rules Based Geotletlc Datum: NOrth Amerlwn Datum 1983 Magnetic Motlel: BGGM2007 CD2 Alpine Pad CD2 464wp07 Plan: CD2-464 ~r~:~n a.-P~el: o.oo RKB: Planned DA9 for '3ar?r.~k a 52.?Oft (Doyon 79 Plan: CD2-464 (36.3}15.8)1 v~orhingASP V: sB7BBZt.tz EastinglASP X: 15114A2.08 CD2-464W 07 P " " ~ 10-3/4 x 13-1/2 7-5/8" X 9-7/8" C o 3000 - - - ° 0 1 M_ ~ 1 .-. 6000 Z - 0 9000 - i J ~p2.464wP~ -6000 -3000 0 3000 6000 9000 West(-)/East(+) (3000 ft/in) ~ ~ 0 -_- _ o° ~ 10 O O N 20 ~ 30 Q 2000 - " " ~~ 10-3/4 x 13-1/2 ~ I 3`L n U ~ ~ N ~ `~ ~ 7-5/8" X 9-7/8" p 3-1 /2" x 6-3/4" 4000 - °`~° ooo v E- ~ 0 2000 4000 6000 8000 a 10000 12000 ORIGINAL ConoeoPhillips Ground t_evel: 0.00 Western North Slope RKB: 52.OOft (i~oyon 19 (3(i.3+15.7)) CD2 Alpine Pad Northing/ASP Y: 5973921.12 Plan: CD2-464 - CD2 Pl 464 D2 464wp 7 an: - E=acting/ASP X: 1511442.08 4035 --- _. 0 0 4050 - - -_ CD2-464wp06 To ~ 7-5/8" X 9-7/8" CD2-464wp06 Heel ~ 4065 - _ - - ~ - - _ ~ ~ o ~ ~ o 00 p 4080 - -- ---- - 0 - - -- - ~ ~ rn o ~ m _ ~ ~ ti o ~ ~ CD2-464wp06 Base ~ a I 3 4095 - - __ - -- ~ H N D ~ U 3-1/2" x 6-3/4" ~,.. 4110 ~ -- CD2-464wp06 Toe 4125 -- - - _-- I I i 0 1500 3000 4500 6000 7500 9000 10500 12000 13500 Vertical Section at 168.57° 1500 ftlin Opxalor. ConocoPMllipsl Alaska)Inc. ~WNS Gnd CancNon: -0.99 Job No: NN/A qeW: Wedxn NMM1 Sbpe MegneNe DecNiwlion: 3].09 AfE He: NN/A WNI: CD1-4N9wp01 dp: 90.69 API NO: NN/A Rlq: NN/A Deglep per 100 fl Sydxn (TV O) RNxance: Mean Sea level SVdpce localian Onyinal V3 %pne: 168.5) Parent We9: %arc Cd1-464 %: IS 11042.08 H View VS %pro: 168.5) RN8 HNgM: 93.00 N Y: 59]3921.12 h UnN System: API Bused /FPS ~ CD2-464wp07 Plan Along the-wellbore Vie .~~. w ~'^~ 1 s a m 0 0 E -1000 0 1000 2000 3000 4000 5000 -lODO 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 Along Well Departure (AWDJ Comments: Along Well View Page 1 of 1 (Toolboxl) 5/16/2008 12:31 PM •I CD2-484wp07 Repon Operator: ConocoPhillips(.4laska) Inc. -WNS Grid Correction: -0.99 Job No: Field: Western North Slope Magnetic Declination: 22.08 AFE No: Well: CD2-464wp07 Dip: 80.69 API No: Rig; Dogleg per: IOU ft North Reference: TRUE Surface Location Original VS Plane: 168.51 Parent Well: Plan: CD2-464 X: 15t 1442.08 "ft Vlew VS Mane: 168.57 RKB Height (above sysle .52.00 ft Y: 597392 L l2 ft Start Date: Ol /Ol /00 TD Date: 12/07/06 Meas. Incl. TRUE Subsea RICB Local ASP or Grid Dogleg Original ie Along Wellbore Tool Dist from Drilled T~vao. ~>n; UDI Depth (ft1 Angle (deg) Azi. (deg) TVD (8) TVD (ft) N(+)/S(-) lfl) E(+)/W(-) (fq N(+)/S(-) La[. (Y) E(+)/W(-) Dep. (X) Seventy (°/loo ft) VS (169°) (H) (1 (ft 11095 (it) Face (deg) VS Plane (ft) Distance (ft) Comments 'I~'~- JE i l~ia? 6.53 -.oo 3630 0 00 ~ 0.00 -15.70 36.30 r, o0 o.ou .... 5974174.42 371409.33 ~ 00 o.ou ## 0.00 0 0.00 100.00 0.00 0.00 48.00 100.00 0.00 0.00 5974174.42 371409.33 0.00 0.00 ## 0.00 0 0.00 63.70 CB-GYR0.SS (1 200.00 0.00 0.00 !48.00 200.00 0.00 0.00 5974174.42 371409.33 0.00 0.00 ## 0.00 0 0.00 163.70 300.00 0.00 0.00 248.00 300.00 0.00 0.00 5874174.42 371409.33 0.00 0.00 ## 0.00 0 0.00 263.70 KOP; 2.5 DLS 400.00 2.50 170.00 347.97 399.97 -2.15 0.38 5874172.27 371409.87 2.50 2.18 ## 2.18 170 0.05 3ti3.70 2.52 0.74 500.00 5.00 170.00 447.75 499.75 -8.59 1.51 5874185.81 371410.70 2.50 8.72 ## 8.72 0 0.22 463.70 5.02 1.64 600.00 8.22 157.67 547.07 599.07 -19.50 4.99 5874154.84 371413.98 3.50 20.10 ## 20.23 -30 -1.03 563.70 8.53 2.24 700.00 11.60 15236 645.57 697.57 -35.02 12.37 5974138.18 371421.09 3.50 36A8 ## 37.44 -18 -5.18 663.70 12.02 2.65 800.00 10.60 132.36 743.70 795.70 -52.08 2L30 5974121.99 371429.73 1.00 55.27 #!t 56.69 -180 -10.56 763.70 13.02 2.87 900.00 9.60 152.36 842.15 894.15 -67.61 29.44 597410&31 371437.60 -.00 72.11 ## 74.23 -180 -15.45 863.70 14.02 3.02 1000.00 8.60 152.36 940.88 992.88 -81.63 36.78 597409218 371444.69 1.00 87.30 ## 90.05 -180 -19.87 963.70 1.5.02 3.13 !050.00 8.10 152.36 990.35 1042.35 -88.06 40.14 5974085.69 371447.95 1.00 94.27 ## 97.31 -180 -21.90 1013.70 MWD+IFR-AK- 15.52 3.18 1100.00 10.22 143.93 1039.72 1091.72 -94.77 44.39 5974078.91 371452.08 5.00 101.68 ## 105.27 -37 -24.73 1063.70 18.03 3.28 1200.00 14.81 134.63 1137.32 1189.32 -110.92 58.72 5974082.51 371486.12 5.00 120.36 ## 126.93 -28 -35.57 1163.70 23.03 3.47 1300.00 19.60 129.73 1232.83 1284.83 -130.63 80.72 5974042.42 371487.78 5.00 144.04 ## 156.50 -19 -53.23 1263.70 28.03 3.65 1400.00 24.47 126.70 1325.50 1377.50 -153.74 110.24 5874018.81 371518.80 5.00 172.54 ## 194.00 -15 -77.59 1363.70 33.03 3.81 1500.00 29.38 124.64 1414.63 1466.63 -180.08 147.06 5973891.84 371553.24 5.00 205.65 ## 239.27 -12 -108.45 1463.70 3802 3.97 1546.83 31.69 - 123.57 1454.97 1506.97 -193.47 166.72 5973978.12 371572.88 5.00 222.67 ## 263.06 -10 -125.08 1510.53 40.37 4.04 1600.00 31.69 123.87 1500.21 1552.21 -20904 189.91 597398215 371585.59 0.00 242.53 ## 290.99 0 -144.72 1563.70 40.37 4.08 1700.00 31.59 123.87 1585.30 1637.30 -238.32 233.53 587393213 371838.88 0.00 279.87 ## 343.53 0 -181.67 1663.70 40.38 4.16 1800.00 31.69 123.87 1670.39 1722.39 -267.60 277.15 587390210 371881.80 0.00 317.22 ## 396.06 0 -218.62 1763.70 40.39 4.22 1900.00 31.69 123.87 1755.48 1807.48 -296.88 320.76 5973872.07 371724.90 0.00 354.56 ## 448.59 0 -255.57 1863.70 40.40 4.28 2000.00 31.69 123.87 1840.57 1892.57 -326.16 364.38 5973842.05 371768.00 0.00 391.90 ## 501.13 0 -292.52 1963.70 40.41 4.33 2100.00 3L69 123.87 1925.66 1977.66 -355.44 408.00 5873812.02 371811.10 0.00 429.25 ## 553.66 0 -329.47 2063.70 40.41 4.38 2200.00 31.69 123.87 2010.75 2062.75 -384.73 451.61 5973781.98 371854.20 0.00 466.59 ## 606.19 0 -366.41 2153.70 40.42 4.42 2300.00 31.69 123.87 2095.83 2147.83 -414.01 495.23 5873751.98 371887.30 0.00 503.94 ## 658.73 0 -403.36 2263.70 40.43 4.46 2400.00 31.69 123.87 2180.92 2232.92 -443.29 538.85 5873721.94 371940.40 0.00 541.28 ## 711.26 0 -440.31 2363.70 40.44 4.49 2500.00 31.69 123.87 2266.01 2318.01 -472.57 582.46 5873681.81 371883.50 0.00 578.62 ## 763.80 0 -477.26 2463.70 40.45 4.52 2596.35 31.69 123.87 2348.00 2400.00 -500.78 624.49 5973882.88 372025.03 0.00 614.61 ## 814.41 0 -512.86 2560.05 10-3/4" x 13-1/2" 40.45 4.55 2600.00 31:69 123.87 2351.10 2403.10 -501.85 626.08 5973661.88 372026.60 0.00 615.97 ## 816.33 0 -514.21 2563.70 40.46 4.55 2602.23 31.69 123.87 2353.00 2405.00 -502.50 627.03 5973881.21 372027.57 0.00 616.80 ## 817.50 0 -SI5.03 2555.93 C-30 40.47 4.55 2700.00 31.69 123.87 2436.19 2488.19 -531.13 669.69 5973831.86 372069.70 0.00 653.31 ## 868.86 0 -551.16 2663 70 40.48 4.58 2800.00 31.69 123.87 2521.28 2573.28 -560.41 713.31 5873801.83 372112.81 0.00 690.66 # 921.40 0 -588.11 2763.70 40.49 4.61 2900.00 31.69 123.87 2606.37 2658.37 -589.70 756.93 5873571.80 372155.91 0.00 728.00 ## 973.93 0 -625.06 2863.70 40.50 4.63 3000.00 3L69 123.87 269L46 2743.46 -618.98 500.54 5973541.78 372188.01 0.00 765.34 # 1026.46 0 -662.00 2963.70 40.50 4.b6 3031.19 31.69 123.87 2718.00 2770.00 -628.11 814.15 597353241 372212.45 0.00 776.99 ## 1042.85 0 -673.53 2994.89 C-20 40.51 4.66 3100.00 31.69 123.87 2776.55 2828.55 -648.26 844.16 5973511.75 37224211 0.00 802.69 ## 1079.00 0 -698.95 3063.70 40.52 4.68 3200.00 31.69 123.87 2861.64 2913.64 -677.54 857.75 5973481.72 372285.21 0.00 840.03 ## 1131.53 0 -735.90 3163.70 40.53 4.70 3300.00 31.69 123.87 .2946.73 2998.73 -706.82 931.39 5873451.70 372328.31 0.00 877.38 1184.07 0 -772.85 3263.70 40.54 4.72 3400.00 31.69 123.87 303 L82 3083.82 -736.10 975.01 5873421.87 $72371.41 0.00 914.72 ## 1236.60 0 -809.80 3363.70 40.54 4.74 3500.00 3L69 123.87 3116.91 3168.91 -765.38 1018.63 5973381.64 372414.51 0.00 952.07 ## 1289.13 0 -846.75 3463.70 40.55 4.76' 3600.00 31.69 123.87 3202.00 3254.00 -794.66 1062.24 5973361.82 372457.61 0.00 989.41 ## 1341.67 0 -883.70 3563.70 40.56 4.78 (CD2-464wp07 NAD27.xls) Page 1 of 4 5/2012008 4:03 PM CD2-464wp07 Report Meas. Incl. TRUE Subsea RICB Local ASP or Grid Dogleg Original ie Along Wellbore Tool Dist from Drilled 1 ortu:~;ir; DD1 Depth (ft) 3700.00 Angle (deg) 3169 Azi. (deB) 123.87 TVD (ft) 3287.09 TVD (ft) 3339.09 N(+)/S(-) (B) -823.95 E(+)/W(-) (ft) 1105.86 N(+)/S(-) Lat. (Y) 5973331.59 E(+)/VV(-) Dep. (%) 372500.72 Severity (°/100 ft) 0.00 VS (169°) (ft) ( 1026.75 (1 ft ## 11095 (ft) 1394.20 Face ~de9) 0 VS Plane (ft) -920.65 Distance (~) 3663.70 Comments ~E It-t-t~ 40.57 6.63 Loo 4.80 3800.00 3898.61 3900.00 4000.00 4100.00 4200.00 3L69 31.69 31.74 35.83 40.34 45.14 123.87 123.87 124.00 131.92 138.35 143.66 3372.18 3456.08 3457.26 3540.40 3619.12 3692.57 3424.18 3508.08 3509.26 3592.40 3671.12 3744.57 -853.23 -882.10 -882.51 -916.80 -960.58 -1013.36 1149.48 1192.49 1193.09 1236.72 1280.05 1322.60 5873301.56 5973271.85 5973271.53 5973236.49 5873197.98 5873138.48 372543.82 372585.32 372588.92 372529.94 372872.50 372714.13 0.00 0.00 6.00 6.00 6.00 6.00 1064.10 1100.92 1101.44 1143.70 1195.20 1255.36 ## ## ## ## ## tk# 1446.73 1498.54 1499.27 1554.87 1616.53 1684.37 0 0 51 51 44 39 -957.59 -994.03 -994.54 -1030.51 -1064.30 -1095.55 3763.70 3862.31 3863.70 3963.70 4063.70 4163.70 40.58 40.58 40.67 46.67 52.67 58.67 4.81 4.83 4.83 4.91 4.98 5,04 4300.00 50.15 148.13 3759.94 3811.94 -1074.56 1363.90 5973078.58 372754.37 6.00 1323.53 ## 1758.25 35 -1123.91 4263.70 64.67 5.11 4348 16 52 62 150.05 3790.00 3842.00 -1106.84 1383.22 5973043.97 372773.13 6.00 1359.00 ## 1795.87 32 -1136.44 4311.86 K-3 67.56 5.14 . 4400 00 . 31 55 151.99 3820.50 3872.50 -1143.52 1403.51 5973008.96 372782.79 6.00 1398.97 ## 1837.79 31 -1149.07 4363.70 70.68 5.17 . 4500.00 . 60.57 155.38 3873.57 3925.57 -1219.47 1441.00 5872930.37 372828.95 6.00 1480.85 ## 1922.51 30 -1170.75 4463.70 76.67 5.23 4600.00 4700.00 4797.63 4800.00 65.91 71.31 76.62 76 75 158.44 161.26 163.83 163.89 3918.59 3955.04 3982.00 3982.55 3970.59 4007.04 4034.00 4034.55 -1301.59 -1388.98 -1478.45 -1480.67 1475.94 1507.96 1536.06 1536.71 5972847.87 5972759.75 5972868.81 5872687.58 372862.47 372892.88 372819.53 372920.13 6.00 6.00 6.00 6.00 1568.26 1660.26 1753.53 1755.84 ## ## ## 2011.77 2104.85 2198.64 2200.95 28 26 25 25 -1188.73 -1202.80 -1212.61 -1212.80 4563.70 4663.70 4761.33 4763.70 K-3 Basal 82.67 88.67 94.52 94.61 5.28 5.34 5.39 5.39 4900.00 . 82.22 166.42 4000.79 4052.79 -1575.67 1561.86 6872572.18 372843.85 6.00 1853.94 ## 2299.24 25 -1218.64 4863.70 100.68 5.45 4987.34 87.00 168.57 4009.00 4061.00 -1660.53 1580.68 5972487.00 372981.00 6.00 1940.84 ## 2386.16 24 -1220.27 4951.04 K-2 - 7-5/8" X 9- 105.91 5.49 5000.00 87.00 168.57 4009.66 4061.66 -1672.92 1583.19 5972474.58 372963.29 0.00 1953.49 ## 2398.81 24 -1220.27 4963.70 10592 5.50 5100.00 87.00 168.57 4014.90 4066.90 -1770.81 1602.99 5972378.38 372981.40 0.00 2053.35 ## 2498.67 0 -1220.28 5063.70 105 93 5.52 5200.00 87.00 168.57 4020.13 4072.13 -186869 1622.79 5972278.16 372899.51 0.00 2153.21 ## 2598.53 0 -1220.28 5163.70 105.94 5.55 5300.00 5334.14 87.00 87.00 168.57 168.57 4025.35 4027.15 4077.36 4079.15 -1966.57 -1999.98 1642.58 1649.34 6972179.98 5872148.44 373017.81 373023.78 0.00 0.00 2253.08 2287.17 ## ## 2698.40 2732.48 0 0 -1220.29 -1220.30 5263.70 5297.84 105,95 10595 5.57 5.58 5400.00 87.66 168.57 4030.22 4082.22 -2064.47 1662.39 5872081.74 373035.72 1.00 2352.96 ## 2798.28 0 -1220.30 .5363.70 106.61 5.60 5500.00 88.66 168.57 4033.43 4085.43 -2162.43 1682.20 5971983.46 373053.84 100 2452.91 ## 2898.22 0 -1220.31 5463.70 107.61 5.62 5600.00 89.66 168.57 4034.90 4086.90 -2260.43 1702.02 5971885.14 373071.97 1.00 2552.89 ## 2998.21 0 -1220.32 5563.70 108.61 5.65 5634.14 90.00 168.57 4035.00 4087.00 -2293.89 1708.79 5971851.57 373078.16 1.00 2587.03 ## 3032.35 0 -1220.32 5597.84 !08.95 5.66 5692.14 90.58 168.57 4034.71 4086.71 -2350.74 1720.29 5971794.54 373088.67 100 2645.03 ## 3090.35 0 -1220.33 5655.84 109.53 5.67 00 5700 90.58 168.57 4034.63 4086.63 -2358.45 1721.55 5971786.80 373090.10 0.00 2652.89 ## 3098.21 0 -1220.33 5663.70 109.54 5.68 . 5800.00 90.58 168.57 4033.62 4085.62 -2456.46 1741.67 5971688.47 373108.23 0.00 2752.89 ## 3198.21 0 -1220.33 5763.70 109.55 5.70 5900.00 90.58 168.57 4032.60 4084.60 -2554.47 1761.50 5971590.14 373126.36 0.00 2852.88 ## 3298.20 0 -1220.34 5863.70 109.56 5.72 6000.00 90.58 168.57 403L59 4083.39 -2652.48 1781.32 5971491.81 373144.49 0.00 2952.55 ## 3398.20 0 -1220.35 5963.70 109.57 5.74 6100.00 90.58 168.57 4030.58 4082.58 -2750.49 1801.15 5971393.48 373162.62 0.00 3052.87 ## 3495.19 0 -1220.36 6063.70 109.57 5.76 6200.00 90.58 168.57 4029.57 4081.57 -2848.50 1820.97 5871295.15 373160.75 0.00 3152.87 ## 3598.19 0 -1220.37 6163.70 109.58 5.78 6300.00 90.58 168.57 4028.56 4080.56 -2946.51 1840.80 5971196.82 373198.88 0.00 3252.86 ## 3698.18 0 -1220.38 6263.70 109.59 5.80 6400.00 90.58 168.57 4027.54 4079.54 -3044.52 1860.62 5971098.48 373217.01 0.00 3352.86 ## 3798.18 0 -1220.39 6363.70 10960 5.81 6500.00 90.58 168.57 4026.53 4078.53 -3142.53 1880.44 5971000.16 373235.14 0.00 3452.85 ## 3898.17 0 -1220.39 6463.70 109.61 5.83 6600.00 90.58 168.57 4025.52 4077.52 -3240.54 1900.27 5870901.83 373253.27 0.00 3552.85 ## 3998.16 0 -1220.40 6563.70 109.62 5.85 6700.00 90.58 168.57 4024.51 4076.51 -3338.55 1920.09 5970803.50 373271.40 0.00 3652.84 ## 4098.16 0 -1220.41 6663.70 10962 5.87 6800.00 90.58 168.57 4023.49 4075.49 -3436.56 1939.92 5870705.17 373289.63 0.00 3752.84 ## 4198.15 0 -1220.42 6763.70 109.63 5.89 6900.00 90.55 168.57 4022.48 4074.48 -3534.57 1959.74 5970606.84 373307.68 0.00 3852.83 ## 4298.15 0 -1220.43 6863.70 109.64 5.90 7000.00 90.58 168.57 4021.47 4073.47 -3632.58 1979.57 5970508.51 373325.79 0.00 3952.83 ## 4398.14 0 -1220.44 6963.70 109.65 5.92 7100.00 90.58 168.57 4020.46 4072.46 -3730.59 1999.39 5970410.18 373343.92 0.00 4052.82 ## 4498.14 0 -1220.44 7063.70 109.66 5.93 7200.00 90.58 168.57 4019.44 4071.44 -3828.60 2019.21 5970311.85 373362.05 0.00 4152.82 ## 4598.13 0 -1220.45 7163.70 109.66 5.95 7300.00 90.58 168.57 4018.43 4070.43 -3926.61 2039.04 5970213.52 373380.18 0.00 4252.81 ## 4698.13 0 -1220.46 7263 70 109.67 5.97 7400.00 90.58 168.57 4017.42 4069.42 -4024.62 2058.86 5970115.18 373388.31 0.00 4352.80 ## 4798.12 0 -1220.47 7363.70 109.68 5.98 7500.00 90.58 168.57 4016.41 4068.41 -4122.63 2078.69 5970016.86 373416.44 0.00 4452.80 ## 4898.12 0 -1220.48 7463.70 109.69 6.00 7567.14 90.58 168.57 4015.73 4067.73 -4188.43 2092.00 5869950.84 373426.81 0.00 4519.93 ## 4965.25 0 -1220.48 7530.84 109.70 6.01 7600.00 90.25 168.37 4015.49 4067.49 -4220.64 2098.51 5868918,53 373434.57 1.00 4552.80 ## 4998.11 -180 -1220.49 7563.70 110.03 6.01 7625.14 90.00 168.57 4015.43 4067.43 -4245.27 2103.50 5869893.81 373438.12 1.00 4577.93 ## 5023.25 -180 -1220.49 7588.84 110.28 6.02 7700.00 89.25 168.57 4015.92 4067.92 -4318.65 2118.34 5868820.19 373452.70 L00 4652.79 ## 5098.11 -180 -1220.50 7663.70 111.03 6.03 7709.14 89.16 168.57 4016.05 4068.05 -4327.60 2120.15 5889811.21 373454.35 1.00 4661.93 ## 5107.25 -180 -1220.50 7672.84 111.12 6.03 (CD2-484wp07 NAD27.xls) Page 2 of 4 5120/2008 4:03 PM CD2-464wp07 Report Meas. Incl. TRUE Subsea RICE Local ASP or Grid Dogleg Original ie Along Wellbore Tool Dist from Drilled Twiu.~~i:y UUl Depth (ft) Angle (deg) Azi. (deg) TVD (ft) TVD (ft) N(+)/S(-) (tT) E(+)/W(-) (ft) N(+)/S(-) Lat. (Y) E(+)/W(-) Dep. (X) Severity (°/100 ft) VS (169°) (ft) (1 (fl 11095 (ft) fore deg) VS Plane (ft) Distance (ft) Comments 7 '~~- lE ~ l3 47 6.63 r.~ 7800.00 89.16 168.57 4017.38 4069.38 -4416.66 2138.16 5989721.87 373470.82 0.00 4752.78 ## 5198.10 0 -1220.30 7763.70 111.12 6.04 7900.00 89.16 168.57 4018.85 4070.85 -4514.66 2157.98 5988823.54 373488.95 0.00 4852.77 ## 5298.09 0 -1220.51 7863.70 Ill.l3 6.06 8000.00 89.16 168.57 4020.31 4072.31 -461266 2177.81 5888525.22 373507.08 0.00 4952.76 ## 5398.08 0 -1220.52 7963.70 111.14 6.07 8100.00 89.16 168.57 4021.78 4073.78 -4710.67 2197.63 5889426.89 373525.21 0.00 5052.75 ## 5498.07 0 -1220.53 8063.70 111.15 6.08 8200.00 8300.00 89.16 89.16 168.57 168.57 4023.25 4024.71 4075.25 4076.71 -4808.67 -4906.68 2217.45 2237.28 5989328.57 5989230.25 373543.34 373581.47 0.00 0.00 5152.74 5252.73 ## ## 5598.06 5698.05 0 0 -1220.54 -1220.55 8163.70 8263.70 111.16 111.17 6.10 6.11 8400.00 89.16 168.57 4026.18 4078.18 -5004.68 2257.10 5889131.92 373578.80 0.00 53.52.72 ## 3798.04 0 -1220.56 8363.70 111.!7 6.12 8500.00 89.16 168.57 402264 4079.64 -5102.69 2276.92 5989033.59 373597.73 0.00 5452.71 ## 5898.03 0 -1220.36 8463.70 111.18 6.14 8600.00 89.16 168.57 4029.11 4081.11 -5200.69 2296.75 5888835.27 373815.85 0.00 5552.70 ## 5998.02 0 -1220.37 8553.70 II1.19 6.15 8700.00 89.16 168.57 4030.58 4082.58 -5298.70 2316.57 5988838.85 373833.98 0.00 5652.69 ## 6098.00 0 -1220.58 8563.70 111.20 6.16 8800.00 89.16 168.57 4032.04 4084.04 -5396.70 2336.39 5988738.62 373852.11 0.00 5752.67 ## 6197.99 0 -1220.59 8763.70 111.21 6.17 8900.00 89.15 168.57 4033.51 4085.51 -5494.71 2356.22 5988640.30 373870.24 0.00 5852.66 ## 6297.98 0 -1220.60 8863.70 111.21 6.18 9000.00 89.16 168.57 4034.98 4086.98 -5592.71 2376.04 5968541.97 373888.37 0.00 5952.65 ## 6397.97 0 -1220.61 8963.70 ] l 1.22 6.20 9100.00 89.16 168.57 4036.44 4088.44 -5690.71 2395.86 5988443.65 373706.50 0.00 6052.64 ## 6497.96 0 -1220.61 9063.70 111.23 6.21 9200.00 89.16 168.57 4037.91 4089.91 -5788.72 2413.69 5888345.32 373724.63 0.00 6152.63 ## 6597.95 0 -1220.62 9153.70 11124 6.22 9300.00 89.16 168.57 4039.37 4091.37 -5886.72 2435.51 5988247.00 37374278 0.00 6252.62 ## 6697.94 0 -1220.63 9263.70 111.25 6.23 9400.00 89.16 168.57 4040.84 4092.84 -5984.73 2455.33 5888148.87 373760.88 0.00 6352.61 ## 6797.93 0 -1220.64 9363.70 111.25 6.24 9500.00 89.16 168.57 4042.31 4094.31 -6082.73 2475.16 5868050.35 373778.01 0.00 6452.60 tt# 6897.92 0 -1220.65 9463.70 i l 1.26 6.25 9584.14 89.16 168.57 4043.54 4095.54 -5165.19 2491.83 5867967.62 373794.27 0.00 6536.73 tt# 6982.05 0 -1220.66 9547.84 111.27 6.26 9600.00 89.32 168.57 4043.75 4095.75 -6180.74 2494.98 5987952.02 373797.14 1.00 6552.59 ## 6997.91 0 -1220.66 9553.70 311.43 6.26 9668.14 90.00 168.57 4044.15 4096.15 -6247.52 2508.49 5967885.02 373808.50 1.00 6620.72 ## 7066.04 0 -1220.66 963 L84 112.11 6.27 9700.00 90.32 168.57 4044.07 4096.07 -6278.75 2514.80 5967853.69 373815.27 1.00 6652.59 ## 7097.91 0 -1220.67 9663.70 112.43 6.28 9726.14 90.58 168.57 4043.86 4095.86 -5304.37 1519.98 5967827.99 373820.01 1.00 6678.72 ## 7124.04 0 -1220.67 9689.84 112.69 6.28 9800.00 90.58 168.57 4043.11 4095.11 -5376.76 2534.63 5867755.36 373833.40 0 00 6752.58 ## 7197.90 0 -1220.67 9753.70 112.70 6.29 9900.00 90.58 168.57 4042.10 4094.10 -6474.77 2554.45 5987657.03 373851.53 0.00 6852.58 ## 7297.90 0 -1220.68 9863.70 112.71 6.30 10000.00 90.58 168.57 4041.09 4093.09 -6572.78 2574.28 5967558.70 373869.88 0.00 6952.57 ## 7397.89 0 -1220.69 9963.70 112.72 6.31 10100.00 90.58 168.57 4040.08 4092.08 -5570.79 2594.10 5887460.37 373887.79 0.00 7052.57 ## 7497.89 0 -1220.70 10063.70 112.72 6.32 10200.00 90,58 168.37 4039.06 409L06 -5768.80 2613.93 596738204 373905.92 0.00 7132.56 ## 7597.88 0 -1220.71 10163.70 112.73 6.33 10300.00 90.58 168.57 4038.05 4090.05 -6866.81 2633.75 5887263.71 373924.05 000 7252.56 ## 7697.88 0 -1220.72 10263.70 112.74 6.34 10400.00 10500.00 90.58 90.58 168.57 168.57 4037.04 4035.03 4089.04 4088.03 -6964.82 -7062.83 2653.57 2673.40 5967165.38 5967067.05 37394218 373960.31 0.00 0.00 7352.55 7452.55 ## ## 7797.87 7897.87 0 0 -1220.72 -1220.73 10363.70 10453.70 112.75 112.76 6.35 6.36 10600.00 90.58 168.57 4035.01 4087.01 -7160.84 2693.22 5966968.71 373978.44 0.00 7552.54 ## 7997.56 0 -1220.74 10563.70 112.76 6.37 10700.00 90.58 168.57 4034.00 4086.00 -7258.85 2713.05 5866870.38 373996.57 0.00 7652.34 ## 8097.86 0 -1220.75 10663.70 112.77 6.38 10800.00 90.58 168.57 4032.99 4084.99 -7356.85 2732.87 596677205 374014.70 0.00 7752.53 ## 8197.85 0 -1220.76 10763.70 112.78 6.39 10900.00 90.58 168.57 403 L98 4083.98 -7454.87 2752.70 5888673.72 374032.83 0.00 7852.53 ## 8297.85 0 -1220.77 10853.70 112.79 6.40 11000.00 90.58 168.57 4030.97 4082.97 -7552.88 2772.52 5966575.39 374050.96 0 00 7932.52 ## 8397.84 0 -1220.78 10963.70 112.80 6.41 11100.00 90.58 168.57 4029.95 4081.95 -7650.89 2792.34 5966477.06 374069.09 0.00 8052.52 ## 8497.84 0 -1220.78 11063.70 112.80 6.42 11200.00 90.58 168.37 4028.94 4050.94 -7748.90 2812.17 5966378.73 374087.22 0.00 8152.51 ## 8597.83 0 -1220.79 11163.70 112.81 6.43 11300.00 90.58 168.57 4027.93 4079.93 -7846.91 2831.99 5968280.40 374105.35 0.00 8252.51 ## 8697.83 0 -1220.80 11253.70 112.82 6.43 11400.00 90.58 168.57 4026.92 4078.92 -7944.92 2851.82 5986182.07 374123.48 0.00 8352.50 ## 8797.82 0 -1220.81 11353.70 112.83 6.44 11500.00 90.58 168.57 4025.90 4077.90 -8042.93 2871.64 5986083.74 374141.81 0.00 8452.50 ## 8897.81 0 -1220.82 11463.70 112.84 6.45 11600.00 90.58 168.37 4024.89 4076.89 -8140.94 289L47 5965985.41 374158.74 0.00 8552.49 ## 8997.81 0 -1220.83 11563.70 112.85 6.46 1160L14 90.58 168.37 4024.88 4076.88 -8142.05 2891.69 5965984.30 374159.94 0.00 8553.63 ## 8998.95 0 -1220.83 11564.84 112.85 6.46 11659.14 90.00 168.57 4024.59 4076.59 -8198.90 2903.19 5965927.26 374170.46 1.00 8611.62 ## 9056.94 -180 -1220.83 11622.84 1]3.43 6.47 11700.00 89.59 168.57 4024.73 4076.73 -8238.96 2911.29 5985887.08 374177.87 1.00 8652.49 ## 9097.81 180 -1220.83 11563.70 113.84 6.47 11746.49 89.13 168.57 4025.25 4077.25 -8284.52 2920.51 5885841.36 374186.30 1.00 8698.98 ## 9144.30 180 -1220.84 11710.19 114.30 6.48 11800.00 89.13 168.37 4026.07 4078.07 -8336.96 2931.11 5885788.75 374188.00 0.00 8752.48 ## 9197.80 0 -1220.84 11763.70 114.31 6.48 11900.00 89.13 168.57 4027.59 4079.59 -8434.97 2950.94 5985680.43 374214.13 0.00 8852.47 ## 9297.79 0 -1220.85 11863.70 114.32 6.49 12000.00 89.13 168.57 4029.12 4081.12 -8532.97 2970.76 586559210 374232.26 0.00 8952.46 9397.78 0 -1220.86 11953.70 114.33 6.50 12100.00 89.13 168.57 4030.64 4052.64 -8630.97 2990.58 5965493.78 374250.39 0.00 9052.45 ## 9497.76 0 -1220.87 12063.70 114.34 6.51 12200.00 89.13 168.57 4032.17 4084.17 -8728.98 3010.41 5965395.46 374268.51 0.00 9152.43 ## 9597.73 0 -1220.88 12163.70 114.34 6.52 (CD2-464wp07 NAD27.xis) Page 3 of 4 5/20/2008 4:03 PM CD2-464wp07 Report Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original ie Along Wellbore Tool Dist from Dulled 1-um.~„~.ir, Ull1 Depth (ft) Angle (deg) Azi. (deb) TVD (ft) TVD (ft) N(+)/S(-) (R) E(+)/W(-) (ft) N(+)/S(-) Lat. (Y) E(+)/Vy(-) Dep. (%) Severity (°/100 ft) VS (169°) (ft) (1 (ft 1109.5 (ft) Face (deg VS Plane (ft) Distance (ft) Comments 'I~1E 7I-t?- 6.63 I-Va 12300.00 89.13 168.57 4033.69 4085.69 -882698 3030.23 5985297.13 374286.64 000 9232.42 ## 9697.74 0 -1220.89 !2263.70 114.35 6.52 12400.00 89.13 168.57 4035.22 4087.22 -8924.98 3050.05 5865188.81 374304.77 0.00 9352.41 ## 9797.73 0 -1220,89 12363.70 114.36 6.53 12500.00 89.13 168.57 4036.74 4088.74 -9022.99 3069.88 5965100.48 374322.90 0.00 9452.40 ## 9897.72 0 -1220.90 12463.70 114.37 6.54 12600.00 89.13 168.57 4038.27 4090.27 -9120.99 3089.70 5985002.16 374341.03 0.00 9552.39 ## 9997.71 0 -1220.91 12563.70 114.38 6.55 12700.00 89.13 168.57 4039.79 4091.79 -9218.99 3109.5E 5964903.84 374358.16 0.00 9652.38 ## 10097.69 0 -1220.92 12663.70 114.38 6.55 12800.00 89.13 168.57 4041.32 4093.32 -9317.00 3129.35 5964805.51 374377.28 0.00 9752.36 ## 10197.68 0 -1220.93 12763.70 114.39 6.56 12900.00 89.13 168.57 4042.84 4094.84 -9415.00 3149.17 5884707.18 374385.41 0.00 9852.35 ## 10297.67 0 -1220.94 12863.70 ! 14.40 6.57 13000.00 89.13 168.57 4044.36 4096.36 -9513.01 3168.99 5984808.86 374413.54 0.00 9951.34 ## 10397.66 0 -1220.94 12963.70 114.41 6.58 13100.00 89.13 168.57 4045.89 4097.89 -9611.01 3188.81 5984510.54 374431.67 0.00 10052.33 ## 10497.65 0 -1220.95 13063.70 114.42 6.58 13200.00 89.13 168.57 4047.41 4099.41 -9709.01 3208.64 598441222 374448.80 0.00 10152.32 ## 10597.64 0 -1220.96 13163.70 114.43 6.59 13300.00 89.13 165.57 4048.94 4100.94 -9807.02 3228.46 5864313.89 374467.83 0.00 10252.31 ## 10697.62 0 -1220.97 13263.70 114.43 6.60 13400.00 89.13 168.57 4050.46 4102.46 -9905 02 3248.28 5864215.57 374486.06 0.00 10352.29 ## 10797.61 0 -1220.98 13363.70 l 14.44 6.61 13500.00 89.13 !68.57 4051.99 4103.99 -10003.02 3268.11 5984117.24 374504.19 0.00 10452.28 ## 10897.60 0 -1220.99 13463.70 114.45 6.61 13600.00 89.13 168.57 4053.51 4103.51 -10101.03 3287.93 5884018.82 374522.31 0.00 10552.27 ## 10997.59 0 -1221.00 13563.70 II4.46 6.62 13697.56 89.13 168.57 4055.00 4107.00 -10196 64 3307.27 5863823.00 374540.00 0.00 10649.82 ## 11095.13 0 -1221.00 13661.26 CD2-464wp06 T 114 47 6.63 (CD2-464wp07 NAD27.xls) Page 4 of 4 5/20/2008 4:03 PM Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD2 Alpine Pad Well: Plan: CD2-464 Wellbore: Plan: CD2-464 Design: CD2-464wp07 ~ 5~2i Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report ~_~~ Well Plan: CD2-464 Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) True Minimum Curvature Project Western North Slope. North Slope Alaska. United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor __ Site CD2 Alpine Pad I, Site Position: From: Map Position Uncertainty: Well Plan: CD: Well Position +N/-S +E/-W Position Uncertainty Northing: 5,974,388.37 ft Latitude: Fasting: 1,511,728.98ft Longitude: 0.00 ft Slot Radius: 0" Grid Convergence: !-464 ~ - - 0.00 ft Northing: 5,973,921.12 ft Latitude: O.OOft Fasting: 1,511,442.08ft Longitude: 0.00 ft Wellhead Elevation: ft Ground Level: Wellbore Plan: CD2-464 Magnetics Model Name Sample Date Declination Dip Angle (°) (°) BGGM2007 5/15/2008 22.08 80.69 70° 20' 19.036 N 151 ° 2' 39.404 W -0.98 ° 70° 20' 14.392 N 151 ° 2' 47.549 W 15.70ft ~ Field Strength (nT) 57,580 ~esign CD2-464wp07 Audit Notes: Version: 21 Phase: PLAN Tie On Depth: 36.30 i Vertical Section: Depth From (TVD) +NlS +E/-W Direction (ft) (~) (tt) (°) 36.30 0.00 0.00 168.57 5/16/2008 12:07:44PM Page 2 COMPASS 2003.16 Build 42F ~'~!GINAL L HALLIBURTON Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope SRe; CD2 Alpine Pad Well: Plan: CD2-464 Wellbore: Plan: CD2-464 Design: CD2-464wp07 Plan Sections ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD2-464 TVD Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) MD Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical ND Depth Inclination Azimuth Depth System (ft) (°) (°) (ft) ft 36.30 0.00 0.00 36.30 -15.70 300.00 0.00 0.00 300.00 248.00 500.00 5.00 170.00 499.75 447.75 700.00 11.60 152.36 697.57 645.57 1,050.00 8.10 152.36 1,042.35 990.35 1,546.83 31.69 123.87 1,506.97 1,454.97 3,898.61 31.69 123.87 3,508.08 3,456.08 4,987.34 87.00 168.57 4,061.00 4,009.00 5,334.14 87.00 168.57 4,079.15 4,027.15 5,634.14 90.00 168.57 4,087.00 4,035.00 5,692.14 90.58 168.57 4,086.71 4,034.71 7,567.14 90.58 168.57 4,067.73 4,015.73 7,625.14 90.00 168.57 4,067.43 4,015.43 7,709.14 89.16 168.57 4,068.05 4,016.05 9,584.14 89.16 168.57 4,095.54 4,043.54 9,668.14 90.00 168.57 4,096.15 4,044.15 9,726.14 90.58 168.57 4,095.86 4,043.86 11,601.14 90.58 168.57 4,076.88 4,024.88 11,659.14 90.00 168.57 4,076.59 4,024.59 11,746.49 89.13 168.57 4,077.25 4,025.25 13,697.56 89.13 168.57 4,107.00 4,055.00 +N/S (ft) 0.00 0.00 -8.59 -35.02 -88.06 -193.47 -882.10 -1,660.53 -1,999.98 -2,293.89 -2,350.74 -4,188.43 -4,245.27 x,327.60 -6,165.19 -6,247.52 -6,304.37 -8,142.05 -8,198.90 -8,284.52 -10,196.64 +EI-W (ft) 0.00 0.00 1.51 12.37 40.14 166.72 1,192.49 1,580.68 1,649.34 1,708.79 1,720.29 2,092.00 2,103.50 2,120.15 2,491.83 2,508.49 2,519.98 2,891.69 2,903.19 2,920.51 3,307.27 Dogleg Rate (°/100ft) 0.00 0.00 2.50 3.50 1.00 5.00 0.00 6.00 0.00 1.00 1.00 0.00 1.00 1.00 0.00 1.00 1.00 0.00 1.00 1.00 0.00 Build Rate (°1100ft) 0.00 0.00 2.50 3.30 -1.00 4.75 0.00 5.08 0.00 1.00 1.00 0.00 -1.00 -1.00 0.00 1.00 1.00 0.00 -1.00 -1.00 0.00 Turn Rate (°/100ft) 0.00 0.00 0.00 -8.82 0.00 -5.73 0.00 4.10 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tool Face (°) 0.00 0.00 170.00 -30.00 180.00 -36.61 0.00 50.61 0.00 0.00 0.00 0.00 180.00 180.00 0.00 0.00 0.00 0.00 180.00 180.00 0.00 5/16/2008 12:07:44PM Page 3 COMPASS 2003.16 Build 42F OR!61NAL 1-1~-LL1E3~~~V Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD2 Alpine Pad Well: Plan: CD2-464 Wellbore: Plan: CD2-464 Design: CD2-464wp07 Planned Survey Measured Vertical Depth Inclination Azimuth Depth (ft) (°) (°) (ft) 36.30 0.00 0.00 36.30 100.00 0.00 0.00 100.00 200.00 0.00 0.00 200.00 300.00 0.00 0.00 300.00 KOP; 2.5 DLS 400.00 2.50 500.00 5.00 600.00 8.22 700.00 11.60 800.00 10.60 900.00 9.60 1,000.00 8.60 1,050.00 8.10 1,100.00 10.22 1,200.00 14.81 1,300.00 19.60 1,400.00 24.47 1,500.00 29.38 1,546.83 31.69 1,600.00 31.69 1,700.00 31.69 1,800.00 31.69 1,900.00 31.69 2,000.00 31.69 2,100.00 31.69 2,200.00 31.69 2,300.00 31.69 2,400.00 31.69 2,500.00 31.69 2,596.35 31.69 10314" x 13-i12" 2,600.00 31.69 2,602.23 31.69 c3o 2,700.00 31.69 2,800.00 31.69 2,900.00 31.69 3,000.00 31.69 3,031.19 31.69 ' C-20 3,100.00 31.69 3,200.00 31.69 3,300.00 31.69 3,400.00 31.69 3,500.00 31.69 170.00 399.97 170.00 499.75 157.67 599.07 152.36 697.57 152.36 795.70 152.36 894.15 152.36 992.88 152.36 1,042.35 143.93 1,091.72 134.63 1,189.32 129.73 1,284.83 126.70 1,377.50 124.64 1,466.63 123.87 1,506.97 123.87 1,552.21 123.87 1,637.30 123.87 1,722.39 123.87 1,807.48 123.87 1,892.57 123.87 1,977.66 123.87 2,062.75 123.87 2,147.83 123.87 2,232.92 123.87 2,318.01 123.87 2,400.00 123.87 2,403.10 123.87 2,405.00 123.87 2,488.19 123.87 2,573.28 123.87 2,658.37 123.87 2,743.46 123.87 2,770.00 123.87 2,828.55 123.87 2,913.64 123.87 2,998.73 123.87 3,083.82 123.87 3,168.91 ConocoPhillips Standard Proposal Report ~.. ~~. ; Local Co-ordinate Reference: Well Plan: CD2-464 TVD Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) MD Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) North Reference: True Survey Calculation Method: .Minimum Curvature TVDss ft -15.70 48.00 148.00 248.00 347.97 447.75 547.07 645.57 743.70 842.15 940.88 990.35 1,039.72 1,137.32 1,232.83 1,325.50 1,414.63 1,454.97 1,500.21 1,585.30 1,670.39 1,755.48 1,840.57 1,925.66 2,010.75 2,095.83 2,180.92 2,266.01 2,348.00 2,351.10 2,353.00 2,436.19 2,521.28 2,606.37 2,691.46 2,718.00 2,776.55 2,861.64 2,946.73 3,031.82 3,116.91 +N/S (ft) 0.00 0.00 0.00 0.00 -2.15 -8.59 -19.50 -35.02 -52.08 -67.61 -81.63 -88.06 -94.77 -110.92 -130.63 -153.74 -180.08 -193.47 -209.04 -238.32 -267.60 -296.88 -326.16 -355.44 -384.73 -414.01 -443.29 -472.57 -500.78 -501.85 -502.50 -531.13 -560.41 -589.70 -618.98 -628.11 +E1-W (ft) 0.00 0.00 0.00 0.00 0.38 1.51 4.99 12.37 21.30 29.44 36.78 40.14 44.39 58.72 80.72 110.24 147.06 166.72 189.91 233.53 277.15 320.76 364.38 408.00 451.61 495.23 538.85 582.46 624.49 Map Northing (ft) 5,973,921.12 5,973,921.12 5,973,921.12 5,973,921.12 5,973,918.97 5,973,912.51 5,973,901.54 5,973,885.90 5,973,868.69 5,973,853.01 5,973,838.88 5,973,832.39 5,973,825.61 5,973,809.21 5,973,789.13 5,973,765.52 5,973,738.55 5,973,724.83 5,973,708.86 5,973,678.84 5,973,648.81 5,973,618.79 5,973,588.76 5,973,558.74 5,973,528.71 5,973,498.69 5,973,468.67 5,973,438.64 5,973,409.71 626.08 5,973,408.62 627.05 5,973,407.95 669.69 5,973,378.59 713.31 5,973,348.57 756.93 5,973,318.54 800.54 5,973,288.52 814.15 5,973,279.15 Map Fasting (ft) 1,511,442.08 1,511,442.08 1,511,442.08 1,511,442.08 1,511,442.42 1,511,443.45 1,511,446.73 1,511,453.85 1,511,462.48 1,511,470.35 1,511,477.45 1,511,480.70 1,511,484.83 1,511,498.88 1,511,520.54 1,511,549.66 1,511,586.01 1,511,605.44 1,511,628.36 1,511,671.46 1,511,714.56 1,511,757.67 1,511,800.77 1,511,843.87 1,511,886.97 1,511,930.08 1,511,973.18 1,512,016.28 1,512,057.81 DLS -15.70 0.00 0.00 0.00 0.00 2.50 2.50 3.50 3.50 1.00 1.00 1.00 1.00 5.00 5.00 5.00 5.00 .5.00 5.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1,512,059.39 0.00 1,512,060.35 0.00 1,512,102.49 0.00 1,512,145.59 0.00 1,512,188.69 0.00 1,512,231.80 0.00 1,512,245.24 0.00 -648.26 844.16 5,973,258.49 1,512,274.90 0.00 -677.54 887.78 5,973,228.47 1,512,318.00 0.00 -706.82 931.39 5,973,198.44. 1,512,361.11 0.00 -736.10 975.01 5,973,168.42 1,512,404.21 0.00 -765.38 1,018.63 5,973,138.39 1,512,447.31 0.00 Vert Section 0.00 0.00 0.00 0.00 2.18 8.72 20.10 36.78 55.27 72.11 87.30 94.27 101.68 120.36 144.04 172.54 205.65 222.67 242.53 279.87 317.22 354.56 391.90 429.25 466.59 503.94 541.28 578.62 614.61 615.97 616.80 653.31 690.66 728.00 765.34 776.99 802.69 840.03 877.38 914.72 952.07 5/16/2008 12:07:44PM Page 4 COMPASS 2003.16 Build 42F ~~`~~~~L ALL1BllR'T~]111J Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD2 Alpine Pad Well: Plan: CD2-464 Wellbore: Plan: CD2-464 Design: CD2-464wp07 Planned Survey ConocoPhillips Standard Proposal Report .., Local Co-ordinate Reference: Well Plan: CD2-464 ND Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) MD Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) North Reference: True =Survey Calculation Method: Minimum Curvature Measured Vertical Map Map Depth Incl ination Azimuth Depth TVDss +N!-S +EI-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,202.00 3,600.00 31.69 123.87 3,254.00 3,202.00 -794.66 1,062.24 5,973,108.37 1,512,490.41 0.00 989.41 3,700.00 31.69 123.87 3,339.09 3,287.09 -823.95 1,105.86 5,973,078.34 1,512,533.52 0.00 1,026.75 3,800.00 31.69 123.87 3,424.18 3,372.18 -853.23 1,149.48 5,973,048.32 1,512,576.62 0.00 1,064.10 3,898.61 31.69 123.87 3,508.08 3,456.08 -882.10 1,192.49 5,973,018.71 1,512,619.12 0.00 1,100.92 3,900.00 31.74 124.00 3,509.26 3,457.26 -882.51 1,193.09 5,973,018.29 1;512,619.72 6.00 1,101.44 4,000.00 35.83 131.92 3,592.40 3,540.40 -916.80 1,236.72 5,972,983.26 1,512,662.75 6.00 1,143.70 4,100.00 40.34 138.35 3,671.12 3,619.12 -960.58 1,280.05 5,972,938.75 1,512,705.31 6.00 1,195.20 4,200.00 45.14 143.66 3,744.57 3,692.57 -1,013.36 1,322.60 5,972,885.25 1,512,746.95 6.00 1,255.36 4,300.00 50.15 148.13 3,811.94 3,759.94 -1,074.56 1,363.90 5,972,823.35 1,512,787.19 6.00 1,323.53 4,348.16 52.62 150.05 3,842.00 3,790.00 -1,106.84 1,383.22 5,972,790.74 1,512,805.95 6.00 .1,359.00 K-3 4,400.00 55.31 151.99 3,872.50 3,820.50 -1,143.52 1,403.51 5,972,753.73 1,512,825.61 6.00 1,398.97 4,500.00 60.57 155.38 3,925.57 3,873.57 -1,219.47 1,441.00 5,972,677.15 1,512,861.77 6.00 1,480.85 4,600.00 65.91 158.44 3,970.59 3,918.59 -1,301.59 1,475.94 5,972,594.44 1,512,895.30 6.00 1,568.26 4,700.00 71.31 161.26 4,007.04 3,955.04 -1,388.98 1,507.96 5,972,506.53 1,512,925.81 6.00 1,660.26 4,797.63 76.62 163.83 4,034.00 3,982.00 -1,478.45 1,536.06 5,972,416.59 1,512,952.37 6.00 1,753.53 K~ Basal 4,800.00 76.75 163.89 4,034.55 3,982.55 -1,480.67 1,536.71 5,972,414.36 1,512,952.97 6.00 1,755.84 ~ 4,900.00 82.22 166.42 4,052.79 4,000.79 -1,575.67 1,561.86 5,972,318.95 1,512,976.49 6.00 1,853.94 4,987.34 87.00 168.57 4,061.00 4,009.00 -1,660.53 1,580.68 5,972,233.78 1,512,993.84 6.00 1,940.84 K-2 - 7.518" X 9-718" - GD2-464wp06 HeeF 5,000.00 87.00 168.57 4,061.66 4,009.66 -1,672.92 1,583.19 5,972,221.35 1,512,996.14 0.00 1,953.49 5,100.00 87.00 168.57 4,066.90 4,014.90 -1,770.81 1,602.99 5,972,123.15 1,513,014.25 0.00 2,053.35 5,200.00 87.00 168.57 4,072.13 4,020.13 -1,868.69 1,622.79 5,972,024.95 1,513,032.36 0.00 2,153.21 5,300.00 87.00 168.57 4,077.36 4,025.36 -1,966.57 1,642.58 5,971,926.75 1,513,050.47 0.00 2,253.08 5,334.14 87.00 168.57 4,079.15 4,027.15 -1,999.98 1,649.34 5,971,893.23 1,513,056.65 0.00 2,287..17 5,400.00 87.66 168.57 4,082.22 4,030.22 -2,064.47 1,662.39 5,971,828.54 1,513,068.58 1.00 2,352.96 5,500.00 88.66 168.57 4,085.43 4,033.43 -2,162.43 1,682.20 5,971,730.25 1,513,086.71 1.00 2,452.91 5,600.00 89.66 168.57 4,086.90 4,034.90 -2,260.43 1,702.02 5,971,631.93 1,513,104.84 1.00 2,552.89 5,634.14 90.00 168.57 4,087.00 4,035.00 -2,293.89 1,708.79 5,971,598.37 1,513,111.03 1.00 2,587.03 5,692.14 90.58 168.57 4,086.71 4,034.71 -2,350.74 1,720.29 5,971,541.33 1,513,121.55 1.00 2,645.03 5,700.00 90.58 168.57 4,086.63 4,034.63 -2,358.45 1,721.85 5,971,533.60 1,513,122.97 0:00 2,652.89 5,800.00 90.58 168.57 4,085.62 4,033.62 -2,456.46 1,741.67 5,971,435.27 1,513,141.11 0.00 2,752.89 5,900.00 90.58 168.57 4,084.60 4,032.60 -2,554.47 1,761.50 5,971,336.94 1,513,159.24 0.00 2;852.88 6,000.00 90.58 168.57 4,083.59 4,031.59 -2,652.48 1,781.32 5,971,238.61 1,513,177.38 .0.00 2,952.88 6,100.00 90.58 168.57 4,082.58 4,030.58 -2,750.49 1,801.15 5,971,140.29 1,513,195.51 0.00 3,052.87 6,200.00 90.58 168.57 4,081.57 4,029.57 -2,848.50 1,820.97 5,971,041.96 1,513,213.65 0.00 3,152.87 6,300.00 90.58 168.57 4,080.56 4,028.56 -2,946.51 1,840.80 5,970,943.63 1,513,231.78 0.00 3,252.86 6,400.00 90.58 168.57 4,079.54 4,027.54 -3,044.52 1,860.62 5,970,845.30 1,513,249.91 0.00 3,352.86 6,500.00 90.58 .168.57 4,078.53 4,026.53 -3,142.53 1,880.44 5,970,746.97 1,513,268.05 0.00 3,452.85 6,600.00 90.58 168.57 4,077.52 4,025.52 -3,240.54 1,900.27 5,970,648.64 1,513,286.18 0.00 3,552.85 6,700.00 90.58 168.57 4,076.51 4,024.51 -3,338.55 1,920.09 5,970,550.32 1,513,304.32 0.00 3,652.84 6,800.00 90.58 168.57 4,075.49 4,023.49 -3,436.56 1,939.92 5,970,451.99 1,513,322.45 0.00 3,752.84 6,900.00 90.58 168.57 4,074.48 4,022.48 -3,534.57 1,959.74 5,970,353.66 1,513,340.58 0.00 3,852.83 7,000.00 90.58 168.57 4,073.47 4,021.47 -3,632.58 1,979.57 5,970,255.33 1,513,358.72 0.00 3,952.83 5/16/2008 12:07:44PM Page 5 COMPASS 2003.16 Build 42F OR161NAL ConocoPhillips ~..'~~L~~~~"`"~~ Standard Proposal Report Database: EDM v16 Prod `Local Co-ordinate Reference: Well Plan: CD2-464 Company: ConocoPhillips(Alaska) Inc. -WNS ND Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) Project: Western North Slope MD Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) Site: CD2 Alpine Pad North Reference: True Well: Plan: CD2-464 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD2-464 Design: CD2-464wp07 i Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 4,020.46 7,100.00 90.58 168.57 4,072.46 4,020.46 -3,730.59 1,999.39 5,970,157.00 1,513,376.85 0.00 4,052.82 7,200.00 90.58 168.57 4,071.44 4,019.44 -3,828.60 2,019.21 5,970,058.67 1,513,394.99 0.00 4,152.82 7,300.00 90.58 168.57 4,070.43 4,018.43 -3,926.61 2,039.04 5,969,960.34 1,513,413.12 0.00 4,252.81. 7,400.00 90.58 168.57 4,069.42 4,017.42 -4,024.62 2,058.86 5,969,862.02 1,513,431.26 0.00 4,352.80 7,500.00 90.58 168.57 4,068.41 4,016.41 -4,122.63 2,078.69 5,969,763.69 1,513,449.39 0.00 4,452.80 7,567.14 90.58 168.57 4,067.73 4,015.73 -4,188.43 2,092.00 5,969,697.67 1,513,461.56 0.00 4,519.93 7,600.00 90.25 168.57 4,067.49 4,015.49 -4,220.64 2,098.51 5,969,665.36 1,513,467.52 1.00 4,552.80 7,625.14 90.00 168.57 4,067.43 4,015.43 -4,245.27 2,103.50 5,969,640.64 1,513,472.08 1.00 4,577.93 7,700.00 89.25 168.57 4,067.92 4,015.92 -4,318.65 2,118.34 5,969,567.03 1,513,485.66 1.00 4,652.79 7,709.14 89.16 168.57 4,068.05 4,016.05 -4,327.60 2,120.15 5,969,558.04 1,513,487.31 1.00 4,661.93 7,800.00 89.16 168.57 4,069.38 4,017.38 -4,416.66 2,138.16 5,969,468.70 1,513,503.79 0.00 4,752.78 7,900.00 89.16 168.57 4,070.85 4,018.85 -4,514.66 2,157.98 5,969,370.38 1,513,521.92 0.00 4,852.77 8,000.00 89.16 168.57 4,072.31 4,020.31 -4,612.66 2,177.81 5,969,272.06 1,513,540.06 0.00 4,952.76 8,100.00 89.16 168.57 4,073.78 4,021.78 -4,710.67 2,197.63 5,969,173.73 1,513,558.19 0.00 5,052.75 8,200.00 89.16 168.57 4,075.25 4,023.25 -4,808.67 2,217.45 5,969,075.41 1,513,576.32 0.00 5,152.74 8,300.00 89.16 168.57 4,076.71 4,024.71 -4,906.68 2,237.28 5,968,977.09 1,513,594.46 0.00 5,252.73 8,400.00 89.16 168.57 4,078.18 4,026.18 -5,004.68 2,257.10 5,968,878.76 1,513,612.59 0.00 5,352.72 8,500.00 89.16 168.57 4,079.64 4,027.64 -5,102.69 2,276.92 5,968,780.44 1,513,630.72 0.00 5,452.71 8,600.00 89.16 168.57 4,081.11 4,029.11 -5,200.69 2,296.75 5,968,682.12 1.,513,648.86 0.00 5,552.70 8,700.00 89.16 168.57 4,082.58 4,030.58 -5,298.70 2,316.57 5,968,583.80 1,513,666.99 0.00 5,652.69 8,800.00 89.16 168.57 4,084.04 4,032.04 -5,396.70 2,336.39 5,968,485.47 1,513,685.12 0.00 5,752.67 8,900.00 89.16 168.57 4,085.51 4,033.51 -5,494.71 2,356.22 5,968,387.15 1,513,703.26 0.00 5,852.66 9,000.00 89.16 168.57 4,086.98 4,034.98 -5,592.71 2,376.04 5,968,288.83 1,513,721.39 0.00 5,952.65 9,100.00 89.16 168.57 4,088.44 4,036.44 -5,690.71 2,395.86 5,968,190.50 1,513,739.52 0.00 6,052.64 ~ 9,200.00 89.16 168.57 4,089.91 4,037.91 -5,788.72 2,415.69 5,968,092.18 1,513,757.66 0.00 6,152.63 9,300.00 89.16 168.57 4,091.37 4,039.37 -5,886.72 2,435.51 5,967,993.86 1,513,775.79 0.00 6,252.62 9,400.00 89.16 168.57 4,092.84 4,040.84 -5,984.73 2,455.33 5,967,895.53 1,513,793.92 0.00 6,352:61 9,500.00 89.16 168.57 4,094.31 4,042.31 -6,082.73 2,475.16 5,967,797.21 1,513,812.05 0.00 6,452.60 9,584.14 89.16 168.57 4,095.54 4,043.54 -6,165.19 2,491.83 5,967,714.49 1,513,827.31 0.00 6,536.73 9,600.00 89.32 168.57 4,095.75 4,043.75 -6,180.74 2,494.98 5,967,698.89 1,513,830.19 1.00 6,552.59 9,668.14 90.00 168.57 4,096.15 4,044.15 -6,247.52 2,508.49 5,967,631.89 1,513,842.54 1.00 6,620.72 9,700.00 90.32 168.57 4,096.07 4,044.07 -6,278.75 2,514.80 5,967,600.56 1,513,848.32. 1.00 6,652.59 9,726.14 90.58 168.57 4,095.86 4,043.86 -6,304.37 2,519.98 5,967,574.86 1,513,853.06 1.00 6,678.72 9,800.00 90.58 168.57 4,095.11 4,043.11 -6,376.76 2,534.63 5,967,502.23 1,513,866.46 0.00 6,752.58 9,900.00 90.58 168.57 4,094.10 4,042.10 -6,474.77 2,554.45 5,967,403.90 1,513,884.59 0.00 6,852.58 10,000.00 90.58 168.57 4,093.09 4,041.09 -6,572.78 2,574.28 5,967,305.57 1,513,902.73 0.00 6,952.57 10,100.00 90.58 168.57 4,092.08 4,040.08 -6,670.79 2,594.10 5,967,207.24 1,513,920.86 0.00 7,052.57 10,200.00 90.58 168.57 4,091.06 4,039.06 -6,768.80 2,613.93 5,967,108.91 1,513,938.99 0.00 . 7,152.56 10,300.00 90.58 168.57 4,090.05 4,038.05 -6,866.81 2,633.75 5,967,010.58 1,513,957.13 0.00 7,252.56 10,400.00 90.58 168.57 4,089.04 4,037.04 -6,964.82 2,653.57 5,966,912.26 1,513,975.26 0.00 7,352.55 10,500.00 90.58 168.57 4,088.03 4,036.03 -7,062.83 2,673.40 5,966,813.93 1,513,993.40 0.00 7,452.55 10,600.00 90.58 168.57 4,087.01 4,035.01 -7,160.84 2,693.22 5,966,715.60 1,514,011.53 0.00 7,552.54 10,700.00 90.58 168.57 4,086.00 4,034.00 -7,258.85 2,713.05 5,966,617.27 1,514,029.66 0.00 7,652.54 10,800.00 90.58 168.57 4,084.99 4,032.99 -7,356.86 2,732.87 5,966,518.94 1,514,047.80 0.00 7,752.53 10,900.00 90.58 168.57 4,083.98 4,031.98 -7,454.87 2,752.70 5,966,420.61 1,514,065.93 0.00 7,852.53 5/16/2008 12:07:44PM Page 6 COMPASS 2003.16 Build 42F ;~ry~ IHI~--LLIUA~T"t~l'~ Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD2 Alpine Pad Well: Plan: CD2-464 Wellbore: Plan: CD2-464 Design: CD2-464wp07 Planned Survey Measured Depth Inclination Azimuth 11,000.00 90.58 168.57 11,100.00 90.58 168.57 11,200.00 90.58 168.57 11,300.00 90.58 168.57 11,400.00 90.58 168.57 11,500.00 90.58 168.57 11,600.00 90.58 168.57 11,601.14 90.58 168.57 11,659.14 90.00 168.57 11,700.00 89.59 168.57 11,746.49 89.13 168.57 11,800.00 89.13 168.57 11,900.00 89.13 168.57 12,000.00 89.13 168.57 12,100.00 89.13 168.57 12,200.00 89.13 168.57 12,300.00 89.13 168.57 12,400.00 89.13 168.57 12,500.00 89.13 168.57 12,600.00 89.13 168.57 12,700.00 89.13 168.57 12,800.00 89.13 168.57 12,900.00 89.13 168.57 13,000.00 89.13 168.57 13,100.00 89.13 168.57 13,200.00 89.13 168.57 13,300.00 89.13 168.57 13,400.00 89.13 168.57 13,500.00 89.13 168.57 13,600.00 89.13 168.57 13,697.56 ~ 89.13 168.57 C~-46dwp06 Toe Targets Target Name - hit/miss target -Shape CD2-464wp06 Toe -plan hits target - Point CD2-464wp06 Heel -plan hits target - Point ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD2-464 TVD Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) MD Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Vertical Depth TVDss +N/-S (ft) ft (ft) 4,082.97 4,030.97 -7,552.88 4,081.95 4,029.95 -7,650.89 4,080.94 4,028.94 -7,748.90 4,079.93 4,027.93 -7,846.91 4,078.92 4,026.92 -7,944.92 4,077.90 4,025.90 -8,042.93 4,076.89 4,024.89 -8,140.94 4,076.88 4,024.88 -8,142.05 4,076.59 4,024.59 -8,198.90 4,076.73 4,024.73 -8,238.96 4,077.25 4,025.25 -8,284.52 4,078.07 4,026.07 -8,336.96 4,079.59 4,027.59 -8,434.97 4,081.12 4,029.12 -8,532.97 4,082.64 4,030.64 -8,630.97 4,084.17 4,032.17 -8,728.98 4,085.69 4,033.69 -8,826.98 4,087.22 4,035.22 -8,924.98 4,088.74 4,036.74 -9,022.99 4,090.27 4,038.27 -9,120.99 4,091.79 4,039.79 -9,218.99 4,093.32 4,041.32 -9,317.00 4,094.84 4,042.84 -9,415.00 4,096.36 4,044.36 -9,513.01 4,097.89 4,045.89 -9,611.01 4,099.41 4,047.41 -9,709.01 4,100.94 4,048.94 -9,807.02 4,102.46 4,050.46 -9,905.02 4,103.99 4,051.99 -10,003.02 4,105.51 4,053.51 -10,101.03 4,107.00 ~ 4,055.00 -10,196.64 Map +E/-W Northing (ft) Ift) 2,772.52 5,966,322.28 2,792.34 5,966,223.96 2,812.17 5,966,125.63 2,831.99 5,966,027.30 2,851.82 5,965,928.97 2,871.64 5,965,830.64 2,891.47 5,965,732.31 2,891.69 5,965,731.20 2,903.19 5,965,674.16 2,911.29 5,965,633.98 2,920.51 5,965, 588.26 2, 931.11 5, 965 , 535.66 2,950.94 5,965,437.33 2,970.76 5,965,339.01 2,990.58 5,965,240.69 3, 010.41 5,965,142.37 3,030.23 5,965,044.05 3,050.05 5,964,945.72 3,069.88 5,964,847.40 3,089.70 5,964,749.08 3,109.52 5,964,650.76 3,129.35 5,964,552.43 3,149.17 5,964,454.11 3,168.99 5,964,355.79 3,188.81 5,964,257.47 3,208.64 5,964,159.15 3,228.46 5,964,060.82 3,248.28 5,963,962.50 3,268.11 5,963, 864.18 3,287.93 5,963,765.86 3,307.27 5,963,669.94 Map Fasting DLS Vert Section (ft) 4,030.97 1,514,084.07 0.00 7,952.52 1,514,102.20 0.00 8,052.52 1,514,120.33 0.00 8,152.51 1,514,138.47 0.00 8,252.51 1,514,156.60 0.00 8,352.50 1,514,174.74 0.00 8,452.50 1,514,192.87 0.00 8,552.49 1,514,193.08 0.00 8,553.63 1,514,203.60 1.00 8,611.62 1,514,211.01 1.00 8,652.49 1,514,219.44 1.00 8,698.98 1,514,229.14 0.00 8,752.48 1,514,247.27 0.00 8,852.47 1,514,265.41 ~ 0.00 8,952.46 1,514,283.54 0.00 9,052.45 1,514,301.67 0.00 9,152.43 1,514,319.80 0.00 9,252.42 1,514,337.94 0.00 9,352.41 1,514,356.07 . 0.00 9,452.40 1,514,374.20 0.00 9,552.39 1,514,392.34 0.00 9,652.38 1,514,410.47 0.00 9,752.36 1,514,428.60 0.00 9,852.35 1,514,446.74 0.00 9,952.34 1,514,464.87 0.00 10,052.33 1,514,483.00 0.00 10,152.32. 1,514,501.13 0.00 10,252.31 1,514,519.27 0.00 10,352.29 1,514,537.40 0.00 10,452.28 1,514,555.53 0.00 10,552.27 1,514,573.22 0.00 10,649.82 Dip Angle Dip Dir. TVD +N!-S +E/-W Northing Fasting (°) (°) (ft) (ft) (ft) (ft) (ft1 0.00 0.00 4,107.00 -10,196.64 3,307.27 5,963,669.94 1,514,573.22 0.00 0.00 4,061.00 -1,660.53 1,580.68 5,972,233.78 1,512,993.84 5/16/2008 12:07:44PM Page 7 COMPASS 2003.16 Burld 42F ORIGINAL Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD2 Alpine Pad Well: Plan: CD2-464 Wellbore: Plan: CD2-464 Design: CD2-464wp07 Casing Points Measured Vertical Depth Depth (ft) (ft) 2,596.35 2,400.00 10-3/4" x 13-1/2" 4,987.34 4,061.00 7-5/8" X 9-7/8" 13,697.56 4,107.00 3-1/2" x 6-3/4" ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD2-464 ND Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) MD Reference: Plan CD2-464 (36.3+15.7) @ 52.OOft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Casing Hoie Diameter Diameter Neale (~~) (~~) 10-3/4 13-1 /2 7-5/8 9-7/8 3-1/2 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS pip Direction (ft) (ft) ft Name Lithology (°) (°) 2,602.23 2,405.00 C-30 4,987.34 4,061.00 K-2 4,797.63 4,034.00 K-3 Basal 4,348.16 3,842.00 K-3 3,031.19 2,770.00 C-20 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI.S +EI-W (ft) (ft) (ft) (ft) Comment I 300.00 300.00 0.00 0.00 KOP; 2.5 DLS 5/16/2008 12:07:44PM Page 8 COMPASS 2003.16 Build 42F ~~~~~~ ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD2 Alpine Pad Plan: CD2-464 Plan: CD2-464 CD2-464wpO7 ;~ ;5iperry Drilling services Clearance Summary Anticollision Report r-- 15 May, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-464 -Plan: CD2-464 -CD2-464wp06 Well Coordinates: 5,973,921.12 N, 1,511,442.08E (70° 20' 14.39" N, 151° 02' 47.55" W) Datum Height: Planned D19 for Qannik ~ 52.20ft (Doyon 19 (36.3+15.9)) Scan Range: 0.00 to 13,697.73 ft. Measured Depth. Scan Radius is 1,566.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Sperry Driliing 8srvicee ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Anticollision Report for Plan: CD2-464 -CD2-464wp07 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-464 -Plan: CD2-464 -CD2-464wp07 Scan Range: 0.00 to 13,697.73 ft. Measured Depth. Scan Radius is 1,566.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Western North Slope Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD2 Alpine Pad CD2-30 -CD2-30 -CD2-30 1,258.70 315.85 1,258.70 292.20 1,375.00 13.359 Centre Distance Pass -Major Risk CD2-30 -CD2-30 -CD2-30 1,274.79 316.17 1,274.79 292.16 1,400.00 13.168 Clearance Factor Pass -Major Risk CD2-35 -CD2-35 -CD2-35 335.20 407.66 335.20 401.44 325.00 65.575 Centre Distance Pass -Major Risk CD2-35 -CD2-35 -CD2-35 4,000.00 511.34 4,000.00 393.32 4,150.00 4.333 Clearance Factor Pass -Major Risk ti ^~ CD2-35 -CD2-35A -CD2-35A 322.39 407.66 322.39 401.68 325.00 68.212 Centre Distance Pass -Major Risk -.J CD2-35 -CD2-35A -CD2-35A 4,000.00 511.82 4,000.00 393.38 4,175.00 4.321 Clearance Factor Pass -Major Risk ~ CD2-36 -CD2-36 -CD2-36 2,317.54 107.15 2,317.54 67.35 2,400.00 2.693 Centre Distance Pass -Major Risk ~ CD2-36 -CD2-36 -CD2-36 2,337.61 108.26 2,337.61 66.96 2,425.00 2.622 Clearance Factor Pass -Major Risk CD2-36 -CD2-36PB1 -CD2-36PB1 2,317.54 107.15 2,317.54 67.35 2,400.00 2.692 Centre Distance Pass -Major Risk '"'°°` CD2-36 -CD2-36PB1 -CD2-36PB1 2,337.61 108.26 2,337.61 66.96 2,425.00 2.621 Clearance Factor Pass -Major Risk CD2-37 -CD2-37 -CD2-37 1,694.27 59.37 1,694.27 29.94 1,775.00 2.017 Centre Distance Pass -Major Risk '^°~~--~~ Y CD2-37 -CD2-37 -CD2-37 1,714.61 59.96 1,714.61 29.65 1,800.00 1.978 Clearance Factor Pass -Major Risk e-°°°"' CD2-38 -CD2-38 -CD2-38 2,314.55 88.44 2,314.55 37.00 2,325.00 1.719 Clearance Factor Pass -Major Risk CD2-38 -CD2-38 -CD2-38 2,360.64 87.02 2,360.64 38.89 2,375.00 1.808 Centre Distance Pass -Major Risk CD2-38 -CD2-38 (Sag) -CD2-38 (Sag) 2,337.26 79.83 2,337.26 28.60 2,350.00 1.558 Clearance Factor Pass -Major Risk CD2-38 -CD2-38 (Sag) -CD2-38 (Sag) 2,360.33 78.84 2,360.33 29.46 2,375.00 1.597 Centre Distance Pass -Major Risk CD2-39 -CD2-39 -CD2-39 4,931.42 166.86 4,931.42 48.84 4,750.00 1.414 Centre Distance Pass -Major Risk CD2-39 -CD2-39 -CD2-39 4,947.46 168.24 4,947.46 48.15 4,775.00 1.401 Clearance Factor Pass -Major Risk CD2-39 -CD2-39PB1 -CD2-39PB1 4,930.84 166.85 4,930.84 48.81 4,750.00 1.413 Centre Distance Pass -Major Risk CD2-39 -CD2-39PB1 -CD2-39P61 4,946.89 168.16 4,946.89 48.01 4,775.00 1.400 Clearance Factor Pass -Major Risk CD2-40 -CD2-40 - CD2-40 1,364.16 259.21 1,364.16 234.61 1,450.00 10.538 Centre Distance Pass -Major Risk CD2-40 -CD2-40 - CD2-40 1,380.18 259.28 1,380.18 234.37 1,475.00 10.409 Clearance Factor Pass -Major Risk CD2-40 -CD2-40PB1 -CD2-40PB1 1,364.16 259.21 1,364.16 234.61 1,450.00 10.538 Centre Distance Pass -Major Risk CD2-40 -CD2-40PB1 -CD2-40PB1 1,380.18 259.28 1,380.18 234.37 1,475.00 10.409 Clearance Factor Pass -Major Risk CD2-41 -CD2-41 - CD2-41 2,629.53 82.04 2,629.53 40.33 2,700.00 1.967 Centre Distance Pass -Major Risk CD2-41 -CD2-41 - CD2-41 2,649.84 82.96 2,649.84 39.95 2,725.00 1.929 Clearance Factor Pass -Major Risk CD2-42 -CD2-42 - CD2-42 1,486.13 311.39 1,486.13 284.11 1,550.00 11.418 Centre Distance Pass -Major Risk CD2-42 -CD2-42 - CD2-42 1,502.85 311.66 1,502.85 283.90 1,575.00 11.226 Clearance Factor Pass -Major Risk • 15 May, 2008 - 15:43 Page 2 of 7 COMPASS HALLIBURT[]N ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD2-464 -CD2-464wp07 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-464 -Plan: CD2-464 -CD2-464wp07 Scan Range: 0.00 to 13,697.73 ft. Measured Depth. Scan Radius is 1,566.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD2-42 -CD2-42PB1 -CD2-42P61 1,486.13 311.39 1,486.13 284.11 1,550.00 11.418 Centre Distance Pass -Major Risk CD2-42 -CD2-42PB1 -CD2-42PB1 1,502.85 311.66 1,502.85 283.90 1,575.00 11.226 Clearance Factor Pass -Major Risk CD2-43 -CD2-43 - CD2-43 1,305.99 159.03 1,305.99 134.72 1,400.00 6.542 Centre Distance Pass -Major Risk CD2-43 -CD2-43 - CD2-43 1,321.80 159.37 1,321.80 134.71 1,425.00 6.464 Clearance Factor Pass -Major Risk CD2-43 -CD2-43PB1 -CD2-43PB1 1,305.99 159.03 1,305.99 134.72 1,400.00 6.542 Centre Distance Pass -Major Risk CD2-43 -CD2-43P61 -CD2-43PB1 1,321.80 159.37 1,321.80 134.71 1,425.00 6.464 Clearance Factor Pass -Major Risk CD2-43 -Prelim: CD2-43A -CD2-43Awp02 1,305.99 159.03 1,305.99 134.71 1,400.00 6.538 Centre Distance Pass -Major Risk CD2-43 -Prelim: CD2-43A -CD2-43Awp02 1,321.80 159.37 1,321.80 134.70 1,425.00 6.460 Clearance Factor Pass -Major Risk CD2-47 -CD2-47 - CD2-47 1,489.02 98.16 1,489.02 72.27 1,550.00 3.792 Clearance Factor Pass -Major Risk CD2-48 -CD2-48 - CD2-48 2,086.16 234.11 2,086.16 198.07 2,150.00 6.496 Centre Distance Pass -Major Risk "~~ CD2-48 -CD2-48 - CD2-48 2,105.84 234.72 2,105.84 197.85 2,175.00 6.366 Clearance Factor Pass -Major Risk CD2-49 -CD2-49 - CD2-49 1,505.35 285.02 1,505.35 259.10 1,525.00 10.997 Clearance Factor Pass -Major Risk CD2-50 -CD2-50 -CD2-50 1,437.34 267.06 1,437.34 242.11 1,425.00 10.703 Centre Distance Pass -Major Risk CD2-50 -CD2-50 -CD2-50 1,459.98 267.07 1,459.98 241.81 1,450.00 10.573 Clearance Factor Pass -Major Risk CD2-50 -CD2-50PB1 -CD2-50PB1 1,437.34 267.06 1,437.34 242.11 1,425.00 10.703 Centre Distance Pass -Major Risk CD2-50 -CD2-50PB1 -CD2-50PB1 1,459.98 267.07 1,459.98 241.81 1,450.00 10.573 Clearance Factor Pass -Major Risk CD2-52 -CD2-52 -CD2-52 199.75 340.57 199.75 336.44 200.00 82.621 Centre Distance Pass -Major Risk CD2-52 -CD2-52 -CD2-52 299.72 341.04 299.72 334.75 300.00 54.186 Clearance Factor Pass -Major Risk CD2-53 -CD2-53 -CD2-53 74.87 339.08 74.87 337.50 75.00 215.259 Centre Distance Pass -Major Risk CD2-53 -CD2-53 -CD2-53 249.86 340.30 249.86 335.05 250.00 64.886 Clearance Factor Pass -Major Risk CD2-54 -CD2-54 -CD2-54 1,190.76 54.07 1,190.76 31.26 1,250.00 2.370 Clearance Factor Pass -Major Risk CD2-54 -CD2-54L1 -CD2-54L1 1,190.76 54.07 1,190.76 31.26 1,250.00 2.370 Clearance Factor Pass -Major Risk CD2-55 -CD2-55 -CD2-55 1,431.58 90.83 1,431.58 65.35 1,450.00 3.566 Clearance Factor Pass -Major Risk CD2-56 -CD2-56 -CD2-56 1,281.13 35.66 1,281.13 11.88 1,325.00 1.499 Clearance Factor Pass -Major Risk CD2-56 -CD2-56L1 -CD2-56L1 1,281.13 35.66 1,281.13 11.87 1,325.00 1.499 Clearance Factor Pass -Major Risk CD2-57 -CD2-57 -CD2-57 ~I, ;, ~ y ,. _,... ~ _ .. .... ... : .. . . .:: .. ft1 CD2-57 -CD2-57 -CD2-57 CD2-58 -CD2-58 -CD2-58 1,713.92 290.53 1,713.92 261.44 1,600.00 9.988 Clearance Factor Pass -Major Risk CD2-58 -CD2-58L1 -CD2-58L1 1,713.92 290.53 1,713.92 261.44 1,600.00 9.988 Clearance Factor Pass -Major Risk CD2-59 -CD2-59 -CD2-59 1,239.81 51.38 1,239.81 28.53 1,275.00 2.248 Clearance Factor Pass -Major Risk • i 15 May, 2008 - 15:43 Page 3 of 7 COMPASS ConocoPhillips(Alaska) Inc. -WNS NALLIBUR?t'~N Anticollision Report for Plan: CD2-464 -CD2-464wp07 Western North Slope Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-464 -Plan: CD2-464 -CD2-464wp07 Scan Range: 0.00 to 13,697.73 ft. Measured Depth. Scan Radius is 1,566.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD2-59 -CD2-59PB1 -CD2-59P61 1,239.81 51.38 1,239.81 28.53 1,275.00 2.248 Clearance Factor Pass -Major Risk CD2-60 -CD2-60 -CD2-60 1,475.22 239.05 1,475.22 213.35 1,425.00 9.299 Clearance Factor Pass -Major Risk CD2-60 -CD2-60P61 -CD2-60P61 1,475.22 239.05 1,475.22 213.35 1,425.00 9.299 Clearance Factor Pass -Major Risk CD2-72 -CD2-72 -CD2-72 347.67 158.12 347.67 150.65 350.00 21.174 Centre Distance Pass -Major Risk CD2-72 -CD2-72 -CD2-72 446.80 158.89 446.80 149.59 450.00 17.089 Clearance Factor Pass -Major Risk CD2-75 Rig -CD2-75 Rig -CD2-75wp10 275.30 220.08 275.30 210.38 275.00 22.689 Centre Distance Pass -Major Risk CD2-75 Rig -CD2-75 Rig -CD2-75wp10 350.05 220.53 350.05 209.34 350.00 19.696 Clearance Factor Pass -Major Risk CD2-75 Rig -CD2-75 Rig -CD2-75 Rig 274.89 219.75 274.89 214.64 275.00 43.033 Centre Distance Pass -Major Risk `"'"""'~„ CD2-75 Rig -CD2-75 Rig -CD2-75 Rig 324.79 219.97 324.79 213.93 325.00 36.426 Clearance Factor Pass -Major Risk °`""d Plan: CD2-461 -Plan: CD2-461 -CD2-461wp04 425.04 59.80 425.04 50.72 425.00 6.587 Centre Distance Pass -Major Risk ,.~„~ Plan: CD2-461 -Plan: CD2-461 -CD2-461wp04 574.80 60.79 574.80 48.44 575.00 4.921 Clearance Factor Pass -Major Risk -~"~ +~ Plan: CD2-462 -Plan: CD2-462 -CD2-462wp05 250.00 39.80 250.00 34.52 250.00 7.543 Centre Distance Pass -Major Risk Plan: CD2-462 -Plan: CD2-462 -CD2-462wp05 349.97 41.00 349.97 33.55 350.00 5.505 Clearance Factor Pass -Major Risk Plan: CD2-463 -Plan: CD2-463wp05 -CD2-463wp05 300.00 19.89 300.00 13.53 300.00 3.127 Centre Distance Pass -Major Risk Plan: CD2-463 -Plan: CD2-463wp05 -CD2-463wp05 375.02 20:62 375.02 12.63 375.00 2.581 Clearance Factor Pass -Major Risk Plan: CD2-465 -Plan: CD2-465 -CD2-465wp02 300.00 20.17 300.00 13.80 300.00 3.170 Centre Distance Pass -Major Risk Plan: CD2-465 -Plan: CD2-465 -CD2-465wp02 374.89 21.04 374.89 13.05 375.00 2.634 Clearance Factor Pass -Major Risk . Plan: CD2-466 -Plan: CD2-466 -CD2-466wp04 250.00 39.92 250.00 34.65 250.00 7.566 Centre Distance Pass -Major Risk Plan: CD2-466 -Plan: CD2-466 -CD2-466wp04 374.74 40.99 374.74 33.00 375.00 5.131 Clearance Factor Pass -Major Risk Plan: CD2-467 -Plan: CD2-467 -CD2-467wp03 275.00 60.20 275.00 54.38 275.00 10.345 Centre Distance Pass -Major Risk Plan: CD2-467 -Plan: CD2-467 -CD2-467wp03 499.21 61.30 499.21 50.60 500.00 5.730 Clearance Factor Pass -Major Risk Plan: CD2-468 -Plan: CD2-468 -CD2-468wp02 300.00 80.13 300.00 73.77 300.00 12.595 Centre Distance Pass -Major Risk Plan: CD2-468 -Plan: CD2-468 -CD2-468wp02 349.90 80.70 349.90 73.26 350.00 10.839 Clearance Factor Pass -Major Risk Plan: CD2-469 -Plan: CD2-469 -CD2-469wp04 300.00 100.04 300.00 93.68 300.00 15.725 Centre Distance Pass -Major Risk Plan: CD2-469 -Plan: CD2-469 -CD2-469wp04 399.72 100.69 399.72 92.16 400.00 11.806 Clearance Factor Pass -Major Risk Plan: CD2-470 -Plan: CD2-470 -CD2-470wp03 300.00 120.02 300.00 113.66 300.00 18.866 Centre Distance Pass -Major Risk Plan: CD2-470 -Plan: CD2-470 -CD2-470wp03 399.66 120.70 399.66 112.18 400.00 14.155 Clearance Factor Pass -Major Risk Plan: CD2-471 -Plan: CD2-471 -CD2-471wp01 1,389.85 64.23 1,389.85 39.19 1,425.00 2.565 Centre Distance Pass -Major Risk Plan: CD2-471 -Plan: CD2-471 -CD2-471wp01 1,413.46 64.29 1,413.46 39.06 1,450.00 2.548 Clearance Factor Pass -Major Risk Plan: CD2-73 -Plan: CD2-73 -CD2-73wp04 275.30 180.15 275.30 174.32 275.00 30.933 Centre Distance Pass -Major Risk 15 May, 2008 - 15:43 Page 4 of 7 COMPASS MALLIBURTC~N ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD2-464 -CD2-464wp07 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-464 -Plan: CD2-464 -CD2-464wp07 Scan Range: 0.00 to 13,697.73 ft. Measured Depth. Scan Radius is 1,566.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft Plan: CD2-73 -Plan: CD2-73 -CD2-73wp04 449.45 180.91 449.45 171.30 450.00 18.820 Clearance Factor Pass -Major Risk Plan: CD2-74 -Plan: CD2-74 -CD2-74wp03 275.30 200.17 275.30 194.35 275.00 34.371 Centre Distance Pass -Major Risk Plan: CD2-74 -Plan: CD2-74 -CD2-74wp03 449.41 201.00 449.41 191.39 450.00 20.912 Clearance Factor Pass -Major Risk CD4 Nanuq Pad --~--- Survey tool program From To SurveylPlan Survey Tool (ft) (ft) 36.30 1,000.00 CD2-464wp06 CB-GYRO-SS 1,000.00 13,697.73 CD2-464wp06 MWD+IFR-AK-CAZ-SC ~^---~ E Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 15 May, 2008 - 15:43 Page 5 of 7 COMPASS ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD2 Alpine Pad Plan: CD2-464 Plan: CD2-464 CD2-464wp07 Sperry Drillinc„~ .'a+~rvices Clearance Summary Anticollision Report 15 May, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-464 -Plan: CD2-464 -CD2-464wp06 Well Coordinates: 5,973,921.12 N, 1,511,442.08E (70° 20' 14.39" N, 151° 02' 47.55" W) Datum Height: Planned D19 for Qannik @ 52.20ft (Doyon 19 (36.3+15.9)) Scan Range: 0.00 to 13,697.73 ft. Measured Depth. Scan Radius is 1,566.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED` All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 H~ALL1BUIRTt'~!V Speirry Grilling 8~rvic®: CD2-464wp07 36.30 To 13697.73 D2-43 D2-43AwF D2-5 3w~o0 -7 D2- D2-466wpi -90 / -1. -463wp0 36 250 500 750 1000 1250 1500 zso 17so 500 2000 750 2500 1000 3000 1250 3500 1500 4000 1750 4500 0 / 360 D2-462wp0 D2-471 wp0 D2-461 wp0 0 / 360 D2-60P61 D2-6 39PB1 Ellipsoid Color 2000 5000 6000 14000 16000 2500 6000 7000 16000 ----- ---_- 18000 3000 7000 8000 18000 20000 3soo aooo sooo 20000 25000 4000 9000 10000 4500 10000 12000 5000 12000 14000 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 ft/in] Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Sepazation [25 IUin] CD2-56 -180 / 180 D2-56L1 ConocoPhillips(Alaska) Inc. -WNS HrQ-LLIBUFtTON Western North Slope Anticollision Report for Plan: CD2-464 -CD2-464wp07 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-464 -Plan: CD2-464 -CD2-464wp07 Scan Range: 0.00 to 13,697.73 ft. Measured Depth. Scan Radius is 1,566.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD2 Alpine Pad CD2-30 -CD2-30 -CD2-30 1,258.70 315.85 1,258.70 292.20 1,375.00 13.359 Centre Distance Pass -Major Risk CD2-30 -CD2-30 -CD2-30 1,274.79 316.17 1,274.79 292.16 1,400.00 13.168 Clearance Factor Pass -Major Risk CD2-35 -CD2-35 -CD2-35 335.20 407.66 335.20 401.44 325.00 65.575 Centre Distance Pass -Major Risk CD2-35 -CD2-35 -CD2-35 4,000.00 511.34 4,000.00 393.32 4,150.00 4.333 Clearance Factor Pass -Major Risk CD2-35 -CD2-35A -CD2-35A 322.39 407.66 322.39 401.68 325.00 68.212 Centre Distance Pass -Major Risk CD2-35 -CD2-35A -CD2-35A 4,000.00 511.82 4,000.00 393.38 4,175.00 4.321 Clearance Factor Pass -Major Risk CD2-36 -CD2-36 -CD2-36 2,317.54 107.15 2,317.54 67.35 2,400.00 2.693 Centre Distance Pass -Major Risk CD2-36 -CD2-36 -CD2-36 2,337.61 108.26 2,337.61 66.96 2,425.00 2.622 Clearance Factor Pass -Major Risk CD2-36 -CD2-36PB1 -CD2-36PB1 2,317.54 107.15 2,317.54 67.35 2,400.00 2.692 Centre Distance Pass -Major Risk CD2-36 -CD2-36P61 -CD2-36PB1 2,337.61 108.26 2,337.61 66.96 2,425.00 2.621 Clearance Factor Pass -Major Risk CD2-37 -CD2-37 -CD2-37 1,694.27 59.37 1,694.27 29.94 1,775.00 2.017 Centre Distance Pass -Major Risk CD2-37 -CD2-37 -CD2-37 1,714.61 59.96 1,714.61 29.65 1,800.00 1.978 Clearance Factor Pass -Major Risk !~"~ CD2-38 -CD2-38 -CD2-38 2,314.55 88.44 2,314.55 37.00 2,325.00 1.719 Clearance Factor Pass -Major Risk CD2-38 -CD2-38 -CD2-38 2,360.64 87.02 2,360.64 38.89 2,375.00 1.808 Centre Distance Pass -Major Risk CD2-38 -CD2-38 (Sag) -CD2-38 (Sag) 2,337.26 79.83 2,337.26 28.60 2,350.00 1.558 Clearance Factor Pass -Major Risk CD2-38 -CD2-38 (Sag) -CD2-38 (Sag) 2,360.33 78.84 2,360.33 29.46 2,375.00 1.597 Centre Distance Pass -Major Risk CD2-39 -CD2-39 -CD2-39 4,931.42 166.86 4,931.42 48.84 4,750.00 1.414 Centre Distance Pass -Major Risk CD2-39 -CD2-39 -CD2-39 4,947.46 168.24 4,947.46 48.15 4,775.00 1.401 Clearance Factor Pass -Major Risk CD2-39 -CD2-39PB1 -CD2-39PB1 4,930.84 166.85 4,930.84 48.81 4,750.00 1.413 Centre Distance Pass -Major Risk CD2-39 -CD2-39PB1 -CD2-39P61 4,946.89 168.16 4,946.89 48.01 4,775.00 1.400 Clearance Factor Pass -Major Risk CD2-40 -CD2-40 - CD2-40 1,364.16 259.21 1,364.16 234.61 1,450.00 10.538 Centre Distance Pass -Major Risk CD2-40 -CD2-40 - CD2-40 1,380.18 259.28 1,380.18 234.37 1,475.00 10.409 Clearance Factor Pass -Major Risk CD2-40 -CD2-40PB1 -CD2-40P61 1,364.16 259.21 1,364.16 234.61 1,450.00 10.538 Centre Distance Pass -Major Risk CD2-40 -CD2-40P61 -CD2-40P61 1,380.18 259.28 1,380.18 234.37 1,475.00 10.409 Clearance Factor Pass -Major Risk CD2-41 -CD2-41 - CD2-41 2,629.53 82.04 2,629.53 40.33 2,700.00 1.967 Centre Distance Pass -Major Risk CD2-41 -CD2-41 - CD2-41 2,649.84 82.96 2,649.84 39.95 2,725.00 1.929 Clearance Factor Pass -Major Risk CD2-42 -CD2-42 - CD2-42 1,486.13 311.39 1,486.13 284.11 1,550.00 11.418 Centre Distance Pass -Major Risk CD2-42 -CD2-42 - CD2-42 1,502.85 311.66 1,502.85 283.90 1,575.00 11.226 Clearance Factor Pass -Major Risk i 15 May, 2008 - 15:56 Page 2 of 7 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLI~URTON Western North Slope Anticollision Report for Plan: CD2-464 -CD2-464wp07 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-464 -Plan: CD2-464 -CD2-464wp07 Scan Range: 0.00 to 13,697.73 ft. Measured Depth. Scan Radius is 1,566.14 ft . Clearance Factor cutoff is Unlimited. Max El lipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD2-42 -CD2-42PB1 -CD2-42PB1 1,486.13 311.39 1,486.13 284.11 1,550.00 11.418 Centre Distance Pass -Major Risk CD2-42 -CD2-42P61 -CD2-42P61 1,502.85 311.66 1,502.85 283.90 1,575.00 11.226 Clearance Factor Pass -Major Risk CD2-43 -CD2-43 - CD2-43 1,305.99 159.03 1,305.99 134.72 1,400.00 6.542 Centre Distance Pass -Major Risk CD2-43 -CD2-43 - CD2-43 1,321.80 159.37 1,321.80 134.71 1,425.00 6.464 Clearance Factor Pass -Major Risk CD2-43 -CD2-43P61 -CD2-43PB1 1,305.99 159.03 1,305.99 134.72 1,400.00 6.542 Centre Distance Pass -Major Risk CD2-43 -CD2-43P61 -CD2-43PB1 1,321.80 159.37 1,321.80 134.71 1,425.00 6.464 Clearance Factor Pass -Major Risk ;~ CD2-43 -Prelim: CD2-43A-CD2-43Awp02 1,305.99 159.03 1,305.99 134.71 1,400.00 6.538 Centre Distance Pass -Major Risk CD2-43 -Prelim: CD2-43A -CD2-43Awp02 1,321.80 159.37 1,321.80 134.70 1,425.00 6.460 Clearance Factor Pass -Major Risk CD2-47 -CD2-47 - CD2-47 1,489.02 98.16 1,489.02 72.27 1,550.00 3.792 Clearance Factor Pass -Major Risk CD2-48 -CD2-48 - CD2-48 2,086.16 234.11 2,086.16 198.07 2,150.00 6.496 Centre Distance Pass -Major Risk ;"`~l CD2-48 -CD2-48 - CD2-48 2,105.84 234.72 2,105.84 197.85 2,175.00 6.366 Clearance Factor Pass -Major Risk ~~` CD2-49 -CD2-49 - CD2~9 1,505.35 285.02 1,505.35 259.10 1,525.00 10.997 Clearance Factor Pass -Major Risk CD2-50 -CD2-50 -CD2-50 1,437.34 267.06 1,437.34 242.11 1,425.00 10.703 Centre Distance Pass -Major Risk "?.... CD2-50 -CD2-50 -CD2-50 1,459.98 267.07 1,459.98 241.81 1,450.00 10.573 Clearance Factor Pass -Major Risk j~ CD2-50 -CD2-50P61 -CD2-50P61 1,437.34 267.06 1,437.34 242.11 1,425.00 10.703 Centre Distance Pass -Major Risk CD2-50 -CD2-50PB1 -CD2-50PB1 1,459.98 267.07 1,459.98 241.81 1,450.00 10.573 Clearance Factor Pass -Major Risk CD2-52 -CD2-52 -CD2-52 199.75 340.57 199.75 336.44 200.00 82.621 Centre Distance Pass -Major Risk CD2-52 -CD2-52 -CD2-52 299.72 341.04 299.72 334.75 300.00 54.186 Clearance Factor Pass -Major Risk CD2-53 -CD2-53 -CD2-53 74.87 339.08 74.87 337.50 75.00 215.259 Centre Distance Pass -Major Risk CD2-53 -CD2-53 -CD2-53 249.86 340.30 249.86 335.05 250.00 64.886 Clearance Factor Pass -Major Risk CD2-54 -CD2-54 -CD2-54 1,190.76 54.07 1,190.76 31.26 1,250.00 2.370 Clearance Factor Pass -Major Risk CD2-54 -CD2-54L1 -CD2-54L1 1,190.76 54.07 1,190.76 31.26 1,250.00 2.370 Clearance Factor Pass -Major Risk CD2-55 -CD2-55 -CD2-55 1,431.58 90.83 1,431.58 65.35 1,450.00 3.566 Clearance Factor Pass -Major Risk CD2-56 -CD2-56 -CD2-56 1,281.13 35.66 1,281.13 11.88 1,325.00 1.499 Clearance Factor Pass -Major Risk CD2-56 -CD2-56L1 -CD2-5tiL1. _ __ _ ___ .1 281.13_ ____ 35.66 __ .1 281,1.3 .__ _ . 11_.,87 1,325.0.0 _ 1.499 Cleearance Factor ___ _Pass Major Ris_k_ _ _ ___ __ _ CD2-57 -CD2-57 -CD2-57 ---- ---- - --------- 7,562.98 ------- -- 139.00 -- -- 7,562.98 _ 91.47 __ _ _ 6,450.00 - --- 2.924 Clearance Factor - - - -- Pass Minor 1/200 - ----.I CD2-58 -CD2-58 -CD2-58 1,713.92 290.53 1,713.92 261.44 1,600.00 9.988 Clearance Factor Pass -Major Risk CD2-58 -CD2-58L1 -CD2-58L1 1,713.92 290.53 1,713.92 261.44 1,600.00 9.988 Clearance Factor Pass -Major Risk CD2-59 -CD2-59 -CD2-59 1,239.81 51.38 1,239.81 28.53 1,275.00 2.248 Clearance Factor Pass -Major Risk CD2-59 -CD2-59PB1 -CD2-59PB1 1,239.81 51.38 1,239.81 28.53 1,275.00 2.248 Clearance Factor Pass -Major Risk 15 May, 2008 - 15:56 Page 3 of 7 COMPASS HALLIBURTC~N ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD2-464 -CD2-464wp07 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-464 -Plan: CD2-464 -CD2-464wp07 Scan Range: 0.00 to 13,697.73 ft. Measured Depth. Scan Radius is 1,566.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD2-60 -CD2-60 - CD2-60 1,475.22 239.05 1,475.22 213.35 1,425.00 9.299 Clearance Factor Pass -Major Risk CD2-60 -CD2-60P61 -CD2-60P61 1,475.22 239.05 1,475.22 213.35 1,425.00. 9.299 Clearance Factor Pass -Major Risk CD2-72 -CD2-72 -CD2-72 347.67 158.12 347.67 150.65 350.00 21.174 Centre Distance Pass -Major Risk CD2-72 -CD2-72 -CD2-72 446.80 158.89 446.80 149.59 450.00 17.089 Clearance Factor Pass -Major Risk CD2-75 Rig -CD2-75 Rig -CD2-75wp10 275.30 220.08 275.30 210.38 275.00 22.689 Centre Distance Pass -Major Risk CD2-75 Rig -CD2-75 Rig -CD2-75wp10 350.05 220.53 350.05 209.34 350.00 19.696 Clearance Factor Pass -Major Risk CD2-75 Rig -CD2-75 Rig -CD2-75 Rig 274.89 219.75 274.89 214.64 275.00 43.033 Centre Distance Pass -Major Risk CD2-75 Rig -CD2-75 Rig -CD2-75 Rig 324.79 219.97 324.79 213.93 325.00 36.426 Clearance Factor Pass -Major Risk ,„~,,,,,,~ Plan: CD2-461 -Plan: CD2-461 -CD2-461wp04 425.04 59.80 425.04 50.72 425.00 6.587 Centre Distance Pass -Major Risk ~`~`"'~ t Plan: CD2-461 -Plan: CD2-461 -CD2-461wp04 574.80 60.79 574.80 48.44 575.00 4.921 Clearance Factor Pass -Major Risk `*-~" ~P Plan: CD2-462 -Plan: CD2-462 -CD2-462wp05 250.00 39.80 250.00 34.52 250.00 7.543 Centre Distance Pass -Major Risk Plan: CD2-462 -Plan: CD2-462 -CD2-462wp05 349.97 41.00 349.97 33.55 350.00 5.505 Clearance Factor Pass -Major Risk ~, ~' ~ Plan: CD2-463 -Plan: CD2-463wp05 -CD2-463wp05 300.00 19.89 300.00 13.53 300.00 3.127 Centre Distance Pass -Major Risk Plan: CD2~63 -Plan: CD2-463wp05 -CD2-463wp05 375.02 20.62 375.02 12.63 375.00 2.581 Clearance Factor Pass -Major Risk ~""°"~'' Plan: CD2-465 -Plan: CD2-465 -CD2-465wp02 300.00 20.17 300.00 13.80 300.00 3.170 Centre Distance Pass -Major Risk Plan: CD2-465 -Plan: CD2-465 -CD2-465wp02 374.89 21.04 374.89 13.05 375.00 2.634 Clearance Factor Pass -Major Risk Plan: CD2-466 -Plan: CD2-466 -CD2-466wp04 250.00 39.92 250.00 34.65 250.00 7.566 Centre Distance Pass -Major Risk Plan: CD2-466 -Plan: CD2-466 -CD2-466wp04 374.74 40.99 374.74 33.00 375.00 5.131 Clearance Factor Pass -Major Risk Plan: CD2-467 -Plan: CD2-467 -CD2-467wp03 275.00 60.20 275.00 54.38 275.00 10.345 Centre Distance Pass -Major Risk Plan: CD2-467 -Plan: CD2-467 -CD2-467wp03 499.21 61.30 499.21 50.60 500.00 5.730 Clearance Factor Pass -Major Risk Plan: CD2~68 -Plan: CD2-468 -CD2-468wp02 300.00 80.13 300.00 73.77 300.00 12.595 Centre Distance Pass -Major Risk Plan: CD2-468 -Plan: CD2-468 -CD2-468wp02 349.90 80.70 349.90 73.26 350.00 10.839 Clearance Factor Pass -Major Risk Plan: CD2-469 -Plan: CD2-469 -CD2-469wp04 300.00 100.04 300.00 93.68 300.00 15.725 Centre Distance Pass -Major Risk Plan: CD2-469 -Plan: CD2-469 -CD2-469wp04 399.72 100.69 399.72 92.16 400.00 11.806 Clearance Factor Pass -Major Risk Plan: CD2-470 -Plan: CD2-470 -CD2-470wp03 300.00 120.02 300.00 113.66 300.00 18.866 Centre Distance Pass -Major Risk Plan: CD2-470 -Plan: CD2-470 -CD2-470wp03 399.66 120.70 399.66 112.18 400.00 14.155 Clearance Factor Pass -Major Risk Plan: CD2-471 -Plan: CD2-471 -CD2-471wp01 1,389.85 64.23 1,389.85 39.19 1,425.00 2.565 Centre Distance Pass -Major Risk Plan: CD2-471 -Plan: CD2-471 -CD2-471wp01 1,413.46 64.29 1,413.46 39.06 1,450.00 2.548 Clearance Factor Pass -Major Risk Plan: CD2-73 -Plan: CD2-73 -CD2-73wp04 275.30 180.15 275.30 174.32 275.00 30.933 Centre Distance Pass -Major Risk Plan: CD2-73 -Plan: CD2-73 -CD2-73wp04 449.45 180.91 449.45 171.30 450.00 18.820 Clearance Factor Pass -Major Risk u 15 May, 2008 - 15:56 Page 4 of 7 COMPASS ~"'~ALL~B~RT~~ ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD2-464 -CD2-464wp07 ,..~.... ~r '~ ~.~ .. -~~.~.,, Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad -Plan: CD2-464 -Plan: CD2-464 -CD2-464wp07 Scan Range: 0.00 to 13,697.73 ft. Measured Depth. Scan Radius is 1,566.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name -Design (ft) (ft) (ft) (ft) ft Plan: CD2-74 -Plan: CD2-74 -CD2-74wp03 Plan: CD2-74 -Plan: CD2-74 -CD2-74wp03 CD4 Nanuq Pad Survey tool program 275.30 200.17 275.30 449.41 201.00 449.41 From To (ft) (ft) 36.30 1,000.00 CD2-464wp06 1,000.00 13,697.73 CD2-464wp06 Survey/Plan Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between Wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 194.35 275.00 34.371 Centre Distance Pass -Major Risk 191.39 450.00 20.912 Clearance Factor Pass -Major Risk Survey Tool CB-GYRO-SS MWD+IFR-AK-CAZ-SC r~ ~J 15 May, 2008 - 15:56 Page 5 of 7 COMPASS C r `,-' ConoeoPhillips CalculaCOn Methotl: Minimum CUrvaNre EmorSyskm: iBCWBa Scan McMOd: Trav. Cytlnder NoM EmolBUrface: Eiiipe~aiconi~ Project: Western North Slope Site: CD2 AI me Pad P 7 CD2-464w Warning McNOd: Ruks BazM Geodetic Datum: North Pmeriwn DaNm 198] Well: Plan: CD2-464 p Magnetic Model: BGGM2991 Wellbore: Plan: CD2-464 (~ u a rte r M i l e View ..rou nd i ~~~r. o 00 ak;3 ~isnn~a oi~ a:r n,nne<«szzoa ~ooyon ~s ~~as. is ep CD2-464Wp07 i~n _y/n3F V. "J7197 t92 A O2;S 0 - i i -2500 - ~ ~ Q g9 O O ti ~~ y ~ G~~ - -5000 - ~ GoZ3y Z ~ ,~39 ag o -7500 oti3 a1 ~ G $~~ 2 -10000 - - - - 2.464WP p 1 ~yy ry1 O O G ~ ya . GO,~,y G G -- - - - B~ °Z 36P ~ ~ 5000 0 -5000 -2500 0 7500 10000 12500 15000 Operder. ecorbikpa(Aleske( Inc. -WX] ilekL Western NMN Slope Wok U1-46<wp0] Wk; XN/A ]Wle<e IOCaXOn x. n Y: 51)]921.12 II Comments: r~~~~/~j I/~~~+~ V ~ S_ a 0 O U J N N T P 00 L: CD2-464wp07 Plan: 4987' to 13697.73' MD CD2-39: 4000' to 4060' TVDss CD2-53: 4000' to 4060' TVDss CD2-27: 4000' to 4060' TVDss CD2-57: 4000' to 4060' TVDss CD2-38: 4000' to 4060' TVDss CD2-58: 4000' to 4060' TVDss GrM Cartedlen; leb XO: #N/A Megn.Hc O.clndlen: 11.11 AEE Ne: #N/A dp: 0.68 A%N.: #N/A Pogbq pot It ]ylam (rvpl X.Mranc.: vet a Original VS Plane: 168.57 r>.dwd: rwn:ao N#. View VS Plane: 168.57 XXk xaod: szm n um srnem: art eerea / sr] S.cHOn (V51 X.ISren<e: Sbl Ian Vie g - - _ - - - __-_ . ___._.. __ ._ ....._ . _. ___-__. _..... _ 5973 __ _._ __ i 5972 --- ~ 5971 --- -. ~~ 5970 . 1 If ... _.. __ _ _.. _ .... ._. 5969 I ~ I 59 1 I _ _._.._ _ __ 6 596 i96 i96 i96 i96 i96 i961 i96 soo soo 500 500 500 8500 7500 6500 5500 4s00 3500 2500 soo 0500 • 4800 5800 6800 o~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ ~ o 0 ~ N f`~') V N ~ ~ ~ P O N M Vertical Section along "View VS Plane" Combo Preview Page 1 of 1 (CD2-464wp06Toolbox.xls) 5/15/2008 155 PM Closest in POOL t.,~J 6 Closest Approach: Reference Well: CD2-464wp07 Plan Offset Well : CD2-57 3-D ctr- Coords. - Coords. - ctr ASP ASP Distance Meas. InG. TRUE Subsea N(+j/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Depth Angle Azi. ND E(+)/W(_ (168.57°) Comments Depth Angle Azi. ND E(+)/W(_ (168.57°) Comments POOL Min POOL Min Distance (140.88 ft Distance (140.88 ft in POOL (4987 - in POOL (4987 - 13697.73 MD) to 13697.73 MD) to CD2-57 (4000 - CD2-464wp06 Pla 140.8 7567.31 90.58 168.5 4015.67 596969 151346 4519.91 4060 NDss) 6469.6 55.73 159.4 3994. 596971 151360 4520. (4000 - 4060 Closest Approach: Reference Well: CD2-464wp07 Plan Offset Well : CD2-39 3-D ctr- Coords. - Coords. - ctr ASP ASP Distance .... Meas. InG. TRUE Subsea N(+)/S(-) View VS Meas. InG. TRUE Subsea N(+)/S(-) View VS Depth Angle Azi. ND E(+)/W(_ (168.57°) Comments Depth Angle Azi. TVD E(+j/w(_ (168.57°) Comments POOL Min POOL Min Distance (173.31 ft Distance (173.31 ft in POOL (4987 - in POOL (4987 - 13697.73 MD) to 13697.73 MD) to CD2-39 (4000 - CD2-464wp06 Pla 173.31 4987.51 87 168.5 4008.96 597223 151299 1940.81 4060 TVDss) 4792.1 39.11 146.1 3989. 597229 151315 2079.21 (4000 - 4060 Closest Approach: Reference Well: CD2-46 4wp07 Plan Offset Well : CD2-38 3-D ctr- Coords. - Coords. - ctr ASP ASP Distance ..-. Meas. InG. TRUE Subsea N(+)!S(-) View VS Meas. InG. TRUE Subsea N(+j/S(-) View VS - Depth Angle Azi. ND E(+)/W(_ (168.57°) Comments Depth Angle Azi. ND E(+)/yV(- (168.57°) Comments POOL Min POOL Min Distance (505.26 ft Distance (505.26 ft in POOL (4987 - in POOL (4987 - 13697.73 MD) to 13697.73 MD) to CD2-38 (4000 - CD2-464wp06 Pla 505.2 527 87 168.5 4024.01 597195 151304 2227.91 4060 TVDss) 4961.0 42.8 161.1 4074. 597185 151255 2408.2 (4000 - 4060 Closest Approach: Reference Well: CD2-46 4wp07 Plan Offset Well : CD2-58 3-D ctr- Coords. - Coords. - ctr ASP ASP Distance Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. InG. TRUE Subsea N(+)/S(-) View VS Depth Angle Azi. ND E(+)/W(_ (168.57°) Comments Depth Angle Azi. ND E(+)/W(_ (168.57°) Comments POOL Min POOL Min Distance (660.71 ft Distance (660.71 ft in POOL (4987 - in POOL (4987 - 13697.73 MD) to 13697.73 MD) to CD2-58 (4000 - CD2-464wp06 Pla 660.71 -.c8.&r 49.<- 735 90.58 168.5 4017.8 596991 151342 4302.61 40 NDss) 6263.5 54.46 164.9 4067.2 596979 151277 4281.9 (4000-4060 CD2-464wp06 PoolSummary.xls 5/15/2008 3:29 PM Ire J i~~~~ ~~ ~° t i ., • • TRANSMITT//JJAL LETTETTR CHECKLIST WELL NAME t.~/~~C r~y Z ~~' PTD# ~U '- ~~ Z V Developments Service Non-Conventional Well ~} // FIELD: t1~ f /'i(i~ l~i v~-r Exploratory Stratigraphic Test ~j~/i~/c /C ~ v~f^ 4 r! n i k (~rtd~~ root: t Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS SAT (OPTIONS) ~~ FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , APi No. SO- - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005{f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API cumber (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throw h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed me~tiane is not allowed for (name of weU) until after ~COlnDanv Name) has designed and implemented a water well. testing program to provide baseline data on water quality and quantity. SComnanv Name)_must contact the Commission to obtain advance approval of such water wait testing ro ram. Rev: i/11/ZOQ8 WELL PERINIT CHECKLIST Field & Pool COLVILLE RIVER, QANNIK OIL • 1201$0 Well Name: COLVILLE RIV QANN CD2-464 Program DEV Well bore sag ^ PTD#:2080820 Company CONOCOPHILLIPS ALASKA INC InRial ClasslType DEV I PEND GeoArea 890 Unit 50360 OnlOff Shore Qn Annular Disposal ^ Administration 1 Petmitfeeatta~hed- ---- ------- -- - ------- NA -- ----- - -- - - -- ----------- -- --- - 2 Lease number appropriate_________------------------- ----------Yes-- ----Entire well inADLQ380075._______________------------.------------___-- 3 Unique well nameartdnumbet___------------------------ ----------Yes-- -----------_ 4 Well located in-a_defnedpOO1__-_________-_____-__----_ ______---NA--- ----Qannik_poolrules-andAlO arecurtentlyinprogress.------------------------------------ 5 WeIUQCatedproperdis#anCeftomdrihingunitboundary______________ _____-._Yes._ _____Iniiial_QannikproducliQn-well-__-____-______-_______-__-__--_____--_ 6 Well locatedptoperdistanreftomctherwells-___-__-.--_------- ------__Yes__ __-__IniiialQannikproductipn_well___-__--___._-_-__-__--__--_____-__-____----__ 7 SufficieMacreageayaileblein_drillingunii--------------------- ---------Yes- -------------------------------------------------------------------- 8 Ifdeyiated,iswellboreplat_included_________________________ __________Yes__ ______--__--_------. 9 Operator only affected party------- ---- ----- -- - - ------Yes- - -- -- -- --- - - -- - - -- -- ------ 10 Operatorhas-appropriate bond in force------ - -- - --- -- - Yes-- ------ -- -- -- -- ---- --------- --- - - -- ---------- 11 Petmitcanbeissuedwithoutconseniation4rder------------------ ----------Yes-- --.----------------------------------------------------------------_--- Appr Date 12 Pe[mitcanbeissuadwithoutadmirlisttativ_e_approval-------------- ----------Yes-- ----------------------.-----------------------------.---,---------------- SFD 512112008 13 Can permit beapR~Vedbeforel5•daY-wait--------------------- ----------Yes- ------------------------------------------------------------ __--- 14 We1112catedv~ithigareaandstrataauthortzedbylpjection0tdet#(put-10#in-comments)-(Fpr_NA__ ___________________._____-____-_____________--__-__-______--__-_____-___ 15 _Ailwells_within114_mile_areaofteyiewidentified(Forsenrieewellonly)_____ __________ NA__ ____________--_______________.______-__--_--__--__-__--_______-__-_ 16 Pre•prOducedinlecfOr,durationofpreptoductio~lesethan3monihs-(For servicewelionlyj---NA-- --.---------_----------------------------------------------------------- 17 Nonconven: gas_conforms t° AS31,05.030(1.1.A),(1.2.A-D) - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductorstring-provided- ------ --- -- - ------ -- - ---Yes- --- - -- -- -- -- --- - - -- -- -- - -- - -- - 19 SurfacecasingproteetsallknpwnUSDWS_________-_.------ --------- NA-- -----_NOaquifers,Algt$A,conclusion3____________________________-------.-----____-- ~ 20 CMTvoladequatetoci[culate_on_conductor&surf_csg_---__--__-- _______--Yes- -------------------------------------------------------------___--- 21 CMTvoiadequatetptie-in long string toss~rfcsg - -- - - - - ------- KO ------- -- - - ------------- ------- - ~ - - -- - --------- 22 CMTwillcoyerallknownt~roductiveherizons____.-__-_________ _________No__ __--__Sl9tfedlinerc°millet[onptanned.-___________--_______-_____--_____--_________--_ 23 CasingdesgnsadequateforC,T B~peimafrost-- -- -- --- -- - --Yes- -- -- - - - --- --- -- - -------- -- ----- ----- 24 Adequatelankage_or tesenrepit _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Rig equipped with steel pits, No-reserve pit planned•_ All waste_tO approved annuti._ _ _ - - _ _ . _ _ _ _ _ 25 If_a_re-drill,bas_a10-403fQrabandortmantbeenappraved----------- ----------~A-- -----------------------------------------------------------.------------- 26 Adequate-wellbote separationpropOSed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - . - _ _ -Proximity analysis perfOtmed, Traveling cylipder path calculated, .Gyros likely_in surface hole, - - - - - . _ - - _ 27 If diverterrequired, does tt meet regulatipns_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ - _ _ _ _ Diyerte[ waiver requested, CD2 has no_histery of_shallowgas. _Approyal reccmmended._ _ _ _ - _ _ _ _ _ _ _ _ _ _ Appr Date 28 Drilling fluid_program schematic ~ equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Maximum expected formation pressure 8,7_~MW._ Plapned MW up to-9.$ ppg, - - . - - _ _ - _ _ - - _ _ _ _ _ _ _ _ _ TEM 5!21!2008 29 BOPES,dotheymeetregulation_-_________-_________- ______-_--Yes- --------------------------------------------------------------------_---- ~~~'d~ /I 30 BOPS-press rating appropriate; test to_(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ MASP calculated at 1433 psi, 3500-psi_BQP testplanned. _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ - - . _ - _ _ _ _ - _ - _ _ _ fir'°\ 31 Choke.menifcldccmpliegwfAPl_RP-63(May84)- -- - -- --- -- Yes ------- -- ------------------ ---- - - - - - -- -- 32 Work willOCCU[withoutoperationshutdown_____--------------- ---_-__--Yes- .-------------------------------------------------------------- __---- 33 I&presence-ofH2S gas probable------------------------- ----------_hlo-- ------H2$hasnotbeen reported at Alpine.---------------------------------------------- 34 Mechanical condition ofwel~wkhinAORyerfied(Forservicewellonty~---- ---------NA-- --------.---------------------------------------------------------------- Geology 35 Pe[mitean be issu~l wlo hydrogen. sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ None expected but detectors &_alanns will be used, Mud scavenger chemicals will beavailable. - - - _ - 36 Aata_presentert onpotential Overpressure zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ ~xpeCted reservolrpressure is 8.5-ppg EMW; will be dnlfed with mud wt to 9.3_ppg.- _ _ - _ _ . _ _ _ - - _ _ _ _ _ . _ Appr Date 37 Seismic-analysis-cf shallow gas_zorres_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ , - - _ _ Scores of wells drilled fr9m Pad CD2 have notencountered significant shallow_gas or hydrates.. _ _ - _ _ _ _ - - _ _ SFD 5!2112008 38 Seab_edconditionscroey_(ifoff-shorej________________________ __._____-KA_ _______.-___-___ -------------------------------------------------------- 39 Contact namelphone for weekiy_progress reports [exploratory Onlyj - - - - - - - - - - - - - - - NA_ _ _ - Geologic Commissioner: Engineering P Date: ommissioner: Date Co issio Date C ~~~~~s~zi ~~ ~'Z z- p ~a 0 Welt 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 information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. "~ - , cd2-464.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Jun 25 13:48:35 2008 Reel Header Service name .............LISTPE Date . ...................08/06/25 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library Tape Header Service name .............LISTPE Date . ...................08/06/25 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF Comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: scientific Technical Services scientific Technical services CD2-464 501032057400 ConocoPhillips Alaska, Inc. Sperry Sun 25-JUN-08 MWD RUN 5 Mw-000577256 E. QUAM D. MICKEY MWD RUN 4 Mw-000577256 J. BOBBITT D. BURLEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK. FLOOR: GROUND LEVEL: WELL CASING RECORD 2 11N 4E 2188 1825 .00 52.18 15.70 Page 1 ~Cx`s-pis 2 ~ /Cdo<~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: cd2-464.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 2568.0 6.750 7.625 5048.0 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 RUNS 1-3 WERE DIRECTIONAL ONLY - NO DATA PRESENTED. 4. MWD RUN 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDSr), AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUN 5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO DENSITY (ALD) GEO-PILOT ROTARY STEERABLE SYSTEM (G P), AND PRESSURE WHILE DRILLING (PWD). 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 1-5 REPRESENT CD2-464 WITH API#:50-103-20574-00. THIS WELL REACHED A TOTAL DEPTH OF 10776' MD / 4088' 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. Page 2 f cd2-464.tapx CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT 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: FIXED (6.75" BIT) AVG OFFSET: N/A MUD WEIGHT: 9.8 - 10.4 PPG MUD SALINITY: 57000 PPM CHLORIDES FORMATION WATER SALINITY: 22500 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. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/25 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 2532.5 10727.5 RPX 2563.0 10734.0 RPM 2563.0 10734.0 FET 2563.0 10734.0 RPS 2563.0 10734.0 RPD 2563.0 10734.0 ROP 2578.5 10776.0 NPHI 5043.0 10690.5 NCNT 5043.0 10690.5 RHOB 5043.0 10706.0 DRHO 5043.0 10706.0 PEF 5043.0 10706.0 FCNT 5043.0 10690.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- Page 3 BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 4 MWD 5 REMARKS: MERGED MAIN PASS. cd2-464.tapx MERGE TOP MERGE BASE 2532.5 5052.0 5052.5 10776.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging 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 Service unit Min Max Mean Nsam Reading Reading DEPT FT 2532.5 10776 6654.25 16488 2532.5 10776 FCNT MWD CP30 163.66 1257.99 327.778 11296 5043 10690.5 NCNT MWD CP30 15566.5 34584.4 21676.6 11296 5043 10690.5 RHOB MWD G/CC 2.228 2.698 2.39318 11327 5043 10706 DRHO MWD G/CC -0.001 0.328 0.111581 11327 5043 10706 RPD MWD OHMM 0.78 2000 17.5931 16255 2563 10734 RPM MWD OHMM 0.87 1840.84 16.5765 16255 2563 10734 RPS MWD OHMM 1.12 2000 16.285 16255 2563 10734 RPX MWD OHMM 1.11 1840.25 15.2671 16255 2563 10734 FET MWD HR 0.24 61.06 0.811155 16255 2563 10734 GR MWD API 32.04 185.1 81.8289 16391 2532.5 10727.5 PEF MwD B/E 2.26 7.01 4.08465 11327 5043 10706 ROP MWD FPH 0.67 287.83 129.489 16396 2578.5 10776 NPHI MWD Pu 11.03 42.27 30.4667 11296 5043 10690.5 First Reading For Entire File..........2532.5 Last Reading For Entire File...........10776 Page 4 • ~ cd2-464.tapx File Trailer Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/25 Maximum Physical Record..65535 File Type. .LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLi6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2532.5 5006.0 FET 2563.0 4998.5 RPX 2563.0 4998.5 RPD 2563.0 4998.5 RPM 2563.0 4998.5 RPS 2563.0 4998.5 ROP 2578.5 5052.0 LOG HEADER DATA DATE LOGGED: 08-JUN-O8 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: 30.0 MAXIMUM ANGLE: 83.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 10718512 EWR4 EWR Phase-4 96540 BOREHOLE AND CASING DATA Page 5 a ~ cd2-464.tapx OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 2568.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): 38.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 7.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 4.000 79.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.817 115.0 MUD FILTRATE AT MT: 3.400 79.0 MUD CAKE AT MT: 7.000 79.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin 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 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MwD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2532.5 5052 3792.25 5040 2532.5 5052 RPD MWD040 OHMM 0.78 2000 9.21266 4872 2563 4998.5 RPM MwD040 OHMM 0.87 1840.84 6.54506 4872 2563 4998.5 RPS MwD040 OHMM 1.12 2000 6.02452 4872 2563 4998.5 RPX MWD040 OHMM 1.11 1840.25 5.30793 4872 2563 4998.5 FET MwD040 HR 0.24 47.94 1.07853 4872 2563 4998.5 GR MwD040 API 53.09 185.1 114.564 4948 2532.5 5006 ROP MWD040 FPH 0.67 287.83 149.639 4948 2578.5 5052 Page 6 ~ ~ cd2-464.tapx First Reading For Entire File..........2532.5 Last Reading For Entire File...........5052 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/25 Maximum Physical Record..65535 File Ty e ................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.......08/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5006.5 10727.5 DRHO 5043.0 10706.0 RPx 5043.0 10734.0 RPM 5043.0 10734.0 FET 5043.0 10734.0 RPD 5043.0 10734.0 NPHI 5043.0 10690.5 RPS 5043.0 10734.0 PEF 5043.0 10706.0 RHOS 5043.0 10706.0 NCNT 5043.0 10690.5 FCNT 5043.0 10690.5 OP 5052.5 10776.0 $ LOG HEADER DATA DATE LOGGED: 14-)UN-O8 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: 85.1 Page 7 cd2-464.tapx MAXIMUM ANGLE: 93.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUM BER DGR Dual Gamma Ray 091360 CTN Comp Thermal Neutron 231708 EWR4 EWR Phase-4 159439 ALD Azimuthal Litho Dens 10859715 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5048.0 BOREHOLE CONDITIONS MUD TYPE: EMS-4200 MOBM MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 50.0 MUD PH: ,0 MUD CHLORIDES (PPM): 50000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 138.2 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .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 FONT MWD050 CP30 4 1 68 4 2 NCNT MWD050 CP30 4 1 68 8 3 RHOB MWD050 G/CC 4 1 68 12 4 DRHO MWD050 G/CC 4 1 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 RPM MWD050 OHMM 4 1 68 24 7 RPS MWD050 OHMM 4 1 68 28 8 RPX MWD050 OHMM 4 1 68 32 9 FET MWD050 HR 4 1 68 36 10 GR MWD050 API 4 1 68 40 11 PEF MwD050 B/E 4 1 68 44 12 Page 8 a ~ cd2-464.tapx RoP MwD050 FPH 4 1 68 48 13 NPHI MwD050 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5006.5 10776 7891.25 11540 5006.5 10776 FCNT MWD050 CP30 163.66 1257.99 327.778 11296 5043 10690.5 NCNT MwD050 CP30 15566.5 34584.4 21676.6 11296 5043 10690.5 RHOB MwD050 G/CC 2.228 2.698 2.39318 11327 5043 10706 DRHO MWD050 G/CC -0.001 0.328 0.111581 11327 5043 10706 RPD MWD050 OHMM 2.01 157.33 21.18 11383 5043 10734 RPM MWD050 OHMM 1.64 708.56 20.8701 11383 5043 10734 RPS MWD050 OHMM 2.86 51.89 20.6765 11383 5043 10734 RPX MWD050 OHMM 2.59 54.02 19.5297 11383 5043 10734 FET MwD050 HR 0.29 61.06 0.696714 11383 5043 10734 GR MWD050 API 32.04 99.45 67.6743 11443 5006.5 10727.5 PEF MWD050 B/E 2.26 7.01 4.08465 11327 5043 10706 ROP MWD050 FPH 0.79 183.79 120.779 11448 5052.5 10776 NPHI MwD050 Pu 11.03 42.27 30.4667 11296 5043 10690.5 First Reading For Entire File..........5006.5 Last Reading For Entire File...........10776 File Trailer service name... .......STSLIg.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/25 Maximum Physical Record..65535 File Tyk~e ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/06/25 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/06/25 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library scientific Technical services scientific Technical services Physical EoF Page 9 Physical EOF End Of LIS File cd2-464.tapx Page 10 r
