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206-050
Image Projeefi Well Nisfiory File Gover 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. ©~ - ~ s~ Well History File Identifier Organizing (done) Two-sided III IIII II II III ~~ III ^ Rescan Needed III Illl ll II ll Ill III R CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: .Diskettes, No. ~. ^ Maps: ~Greyscale Items: I ~~ ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ fJ /sl Project Proofing III IIIIII VIII II III BY: Maria Date: `j D /s/ ~' 1 g p ~~ + _~ =TOTAL PAGES ~~ ~/ Scannin Pre aration ,~ x 30 = (Count does not include cover sheet) BY: Maria Date: `,rj ~ /s/ Production Scanning II I II it II I I III I I III Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: ~ /~' ~ g /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. lI I II ~I II l Il ll I I III ReScanned III I'~IIIIIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III Illlll III Ills ill 10/6/2005 Well History File Cover Page.doc i ~ ~,,,,; ~~ ,~ ~~F ,~~ ;' '; ~ ,,~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6t",2008. 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 Klei ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/6/2008 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 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8!29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1 J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1 J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1 J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1 J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1 J-184 206-044 8" NA 8" NA 1.28 9/6/2008 ~~ DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2060500 Well Name/No. KUPARUK RIV U WSAK 1J-109 Operator CONOCOPHILLIPS ALASKA INC MD 15160 TVD 3782 Completion Date 8/15/2006 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-23307-00-00 UIC N REQUIRED INFORMATION , Mud Log No Samples No Directional Surv Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments - ---- ', og Cement Evaluation 5 Col 1 6700 10570 Case 8/23/2006 CBL, USIT, GR, WeIITec Tractor 7-Aug-2006 QED C Pds 14084 Corrosion 1 0 10542 Case 8/29/2006 Mem Multi-Finger Caliper Log, w/3-D Graphics r /~D C Lis 14105 Induction/Resistivity , ~ 4118 15160 Open 8/30/2006 GR, NPHI, FET, RHOB, / ROP w/Graphics ED C Lis 14105 Induction/Resistivity 4118 1104 Open 8/30/2006 P61 GR, NPHI, FET, E RHOB, ROP w/Graphics ~ D Asc Directional Survey 0 15160 Open 10/19/2006 ~ QED D Asc Directional Survey 0 11004 Open 10/19/2006 PB 1 C Lis 14577 Induction/Resistivity ~ ~'~ ~' 4118 15160 Open 4/4/2007 LIS Veri, GR NPHI, FET, NCNT, RHOB, ROP ~D C Lis 14577 Induction/Resistivity 4118 11004 Open 4/4/2007 P61 LIS Veri, GR NPHI, FET, NCNT, RHOB, ROP p...y, Ew4r~ 06 Log Pressure 5 Blu 0 10550 Open 7/10/2008 SBPH Survery, MaxTrac C Pds 16581 Pressure 0 10550 Open 7/10/2008 28-Jun-2008 SBPH Survery, MaxTrac 28-Jun-2008 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments r~ DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2060500 Well Name/No. KUPARUK RIV U WSAK 1J-109 Operator CONOCOPHILLIPS ALASKA INC MD 15160 TVD 3782 ADDITIONAL INFORMATION Well Cored? Y / Chips Received? `}`f1V" Analysis Y~d~- Received? Comments: Completion Date 8/15/2006 Completion Status 1-OIL Daily History Received? Formation Tops Compliance Reviewed By: Date: API No. 50-029-23307-00-00 UIC N L~ Current Status 1-OIL ~/ N ~/ N '# ; ^-f ~ k ]r 3 ~ ~ ~ ~ g~ p ~ ~ y ~~ 1y {p' ? ~. r ... 8. 3l ff Si i ALASSA OIL Ai~D GAS COlY5ERQATIOI~T COI~IDII55I011T Robert Christensen Production Engineering Technician ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-109 Sundry Number: 308-239 Dear Mr. Christensen: 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 the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). 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, Daniel T. Seamount, Jr. s ?,~ Chair DATED this ` day of July, 2008 Encl. ~~}Co-D~ ~i Conoc~hillips July 1, 2008 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7`" Ave. Ste. 100 Anchorage, AK 99501 Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 ~.~ _ »a ._ ~~a~~ Dear Mr. Maunder, ConocoPhillips Alaska, Inc. is requesting approval to covert West Sak 1J-109 (PTD 206- 050) from Oil production to Water Injection service. Enclosed you will find 10-403 Application for Sundry Approval. If you have any questions regarding this matter, please contact myself or Robert Buchholz at 659-7535. Sincerely, ,A ~~~ Robert D. Christensen Attachments ~,~~ STATE OF ALASKA ~~( ~~~ ~ ~~,x, ~ ~ ~ O ALASKA OIL AND GAS CONSERVATION COMMISSION ~. APPLICATION FOR SUNDRY APPROVAL `1~'`~ ~~ ~ 2008 ~ 20 AAC 25.280 Alga- ; 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ ' , Wailter ^ Other i ~ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Prod to WI 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 ^ Exploratory ^ 206-050 3. Address: Stratigraphic ^ Service Q 8. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23307-00 • 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 1J-109 9. Property Designation: ` 10. KB Elevation (ft): 11. Field/Pool(s): ADL 2$24$, 390705 RKB 122' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15160' 3782' 14218' 3687 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 30" 121' 121' SURFACE. 4151' 13-3/8" 4151' 2307 INTERMEDIATE 10853' 9-5/8" 10853 3757 D sand Slotted Liner 3571' 4-1/2" 14218' 3687 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11277-14190' 3768'-3687 3-1/2" L-80 10704' Packers and SSSV Type: Packers and SSSV MD (ft) Packer = HRD ZXP Liner top Packer Packer = 10647 SSSV =Nipple SSSV = 513' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: July 15, 2008 ' Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ 0 WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name,~~ obe t D. Christe sen Title: Production Engineerin Technician Signature ~ ~ ~ Phone 659-7535 Date Commission Use Onl Sundry Number: Conditions of approvai: Notify Commission so that a representative may witness ~- p2 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance Other. ~p~~~~~s~~ ~.~~~wr A~~ a 3 .. ~ ~~~.~ ,a ~~-_ ~ ~ zoaB Subsequent Form Required: ~® ~ , ~ ~ ~,'` ,~' APPROVED BY d b A p'fove y: C~MMISSIiNER THE C~MMISSI~N date: / Form 10-4Q3 ReJised (}6/2006 b in Duplic to -- • 1 J-109 • DESCRIPTION SUMMARY OF PROPOSAL ' ConocoPhillips Alaska Inc.. requests approval to begin Water Injection service in West Sak Well 1J-109. This well was completed as an Oil producer in late September 2006. Well 1J- 109 will provide Wsak D-sand pressure support to offset producers. The 13-3/8" Surtace casing (4151' and / 2307 tvd) was cemented with 800 sx AS Lite followed by 220 sx DeepCrete. The 9-5/8" Intermediate casing (10853' and / 3757' tvd) was cemented with 728 sx Class G. The injection tubing/casing annulus is isolated.via "HRD" ZXP 7" x 9-5/8" Liner Top Packer (10647 and ! 3728' tvd). The top of Wsak D sand was found at 10875' and / 3761' tvd. Due to the well completion, a CBL cannot be obtained. A WFL and Temperature Log will be submitted within three months of water injection service. .~-~ ~~ ~,- , ~, ~~ ; ,~ / ,i ~~?, ~ lit? e ~'"~ ~'~,, %J7',..s ,r/~1~%~~/i7 f''Y C~~J~i r~,-~ U r f~~ ~ ~ ~~ ~,, Tyr ; "~,r / C%' ~: ''`*`'C,:~? ~~, f - J''~~ t:' ~-; u ~,. ~: ~.~.r , <~ ,~: ~.7..1~ /fit'' /;?.,2~1f ~.~ • • KRU 1 J-109 ConocoPhillips Alaska, Inc. r'; / i // r; _.,-, h~um~erer NO. 4775 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07,10,08 2W-04 12061711 INJECTION PROFILE ja 06/24/08 1 1 1 L-20A 10215099 PRODUCTION PROFILE ~QU '~ 06/26/08 1 1 1 G-05 12080389 LDL (p 06/27/08 1 1 36-10 12061714 INJECTION PROFILE '-' _ t / - 06/27/08 1 1 2L-327 12061715 SBHP SURVEYu 06/28/08 1 1 iJ-109 12080390 SBHP SURVEY / ( 06/28/08 1 1 2N-323 12061716 SBHP SURVEY ~ 'f~.- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY C 06/29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY ~' 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY <j'-- ~~ 06/29/08 1 1 iG-09 12080401 INJECTION PROFILE (~ -- ( / 07/05/08 1 1 2H-05 12080396 SBHP SURVEY ~ ~ 06/30/08 1 1 2H-12 12080395 SBHP SURVEY _ ~ 06/30!08 1 1 2H-11 12080394 SBHP SURVEY ( 06/30/08 1 1 iD-07 12080398 SBHP SURVEY -~1 07/02/08 1 1 2N-341 12061720 SBHP SURVEY T 06/30/08 1 1 3C-15 11982441 USIT - (}~ / (p 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE `6 - (p 07/08/08 1 1 1 L-19 12061724 PRODUCTION PROFILE J O -6 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ~ 07/09/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. i;?, !"-5 .~ Imo' C:3.A.N I CAL INTEGRITY R.l' ORT ~~~ ~~~~ : l~ -l`~ ~ OPER = : UD u: I ~ FIELD ~ ~ ~ - ~ . .. . S ~ C: ~;~LL ~I NUMEER `.~ ry~ ~ :,.~G r E~~~ SC . nrLL ~~TG TD. ISM; ?~..~~~~ '?'VD; ?P TD. ~~~~~?ID ~15~ T~FD Corsi^.g C-~~~ Shoe: I1~~5~MD •~1`_~~ TVD; UV. (:ilk ?'ID ~1L~. -Ttr~i ~ ~. Shoe :~ __:,e.. TVD • _Cr . ?-ID ';~ :uo.^s ~j•.'~ P c er `~~~ '~ Imo; Set a~ ~l>~1~~ ~. ole S~~e ~ ~ ~~`-~ and ~ Pe'-'fs ~`~~~~ to ~~~,~-~E y ~Cc=..ei?~ =C~.~ 1NTEGRITY - ? 4.RT # I Ynrulas Press Test: _? 15 min 1 ~ ; ~0 min. C p 1 ` ~ . ~ ~F~ ~ ~ _ ~ \ oQents : ~ ~ ~c `~S~~~F S i '.~' CHI N 1 C~i., INTEGRT.T,~ - PAR-r ~ Z ~---'t '' =~vv~ h~.5 Cement Voles :• rent. Liner ~~ Csg 1) `~~y ~ DV ti's C~,t JoI to cove= aers T'c~t,. ~_~--~C~C~~~ ~.~`_~ ~ \ ~~1~ ~~~v .. c _ eoretical TCC C ~~ ~~ ~'~ ~l.r C- ~~ ~ `y _ _..,~ Cement Bond Lag (Yes or No) ~ In AOGCC File CBL Evaluation, gone above perfs Gfi~~~~' `.S ~~F ~ ~~ Production Log: 's'yve Evaluation i CONGLUS ~ ONS : ?art r 1 : __ - Page 1 of 2 • Maunder, Thomas E (DOA) From: NSK Prod Engr Tech [n1139@conocophillips.com] Sent: Tuesday, July 08, 2008 2:33 PM To: Maunder, Thomas E (DOA) Subject: RE: 1J-109 (206-050) Attachments: PMIT KRU 1J-109 08-31-06xls.xls Tom, Here is the PMIT Report Form for 1J-109. Bob Buchholz /Bob Christensen Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 08, 2008 12:59 PM To: NSK Prod Engr Tech Cc: Allsup-Drake, Sharon K Subject: RE: iJ-109 (206-050) Bob, Yes. Do you have this information in a "report form"? Is there much other operations information? I know this well was changed to gas lift at one time. Thanks in advance. Tom Maunder, PE AOGCC From: NSK Prod Engr Tech [mailto:ni139@conocophillips.com] Sent: Tuesday, July 08, 2008 12:57 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: FW: iJ-109 (206-050) Tom, Is the following information below what you needed? Let me know if you require any additional information. Thanks, Bob Buchholz Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) 7/8/2008 Page 2 of 2 • • From: NSK Well Integrity Proj Sent: Tuesday, July 08, 2008 12:45 PM To: NSK Prod Engr Tech; NSK Problem Well Supv Subject: RE: iJ-109 (206-050) Bob, 8131/06: CLOSED CMU AT 10555'. MITIA AT 3000 PSI FOR 30 MIN pre MIT T/I/O 280/260/190, Starting 275/3000/200, 15 min 235/2890/200, 30 min 221/2975/200 -Pass From: NSK Prod Engr Tech Sent: Tuesday, July 08, 2008 12:03 PM To: NSK Well Integrity Proj; NSK Problem Well Supv Subject: FW: 1J-109 (206-050) MJ/Brent, Can you help me with Tom M. requests? Bob Buchholz /Bob Christensen Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907} 659-7000 (924) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 08, 2008 11:41 AM To: NSK Prod Engr Tech; Allsup-Drake, Sharon K Subject: iJ-109 (206-050) Bob, Bob and Sharon, I am examining the sundry application to convert this well from producer to injector. The drilling reports submitted with the 407 end 8/1512006. As I read the reports, I did not see that any annulus pressure test had been conducted once the tubing was run and stung into the ZXP. When the liner was run on 8/6, a 1000 psi annulus test is noted to "check packer". Is there additional information after 8/15 available? I suspect that additional reports might be available due to this well being jet pumped. Also in the application it is stated that no bond log can be run due to the well configuration. That is a true statement, however a bond log was run 8/7/06 prior to running the completion. You can send any information via email Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 7/8/2008 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: ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: 1 J-109 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-029-23307-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final ^~ 306-285 8/31/2006 Kuparuk 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 totals (bbls); 2006 / 3rd 0 0 0 0 0 2006 / 4th 946 100 0 1046 2 10/2/2006 10/3/2006 1 J-115 2007 / 1st 0 0 0 0 0 2007 / 2nd 0 0 0 0 0 2007 / 0 0 0 0 0 3rd Total Ending Report is due on the 20th 946 100 0 1046 2 Volume of the month following the final month of the quarter. Ex: (bbls): 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): and correct to the best of my knowledge. I hereby certify that the foregoing is true ~ ~ Signature: ~ '~~--r.~-. Date: ~ ° ~~ ~a '~ 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 1J-109 (PTD 206050) gas lift test complete Page 1 of 1 Maunder, Thomas E {DOA) From: NSK Problem Well Supv [n1617@conocophillips.comj Sent: Saturday, October 06, 2007 3:25 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK West Sak Prod Engr; NSK Problem Well Supv Subject: 1J-109 (PTD 206050) gas lift test complete Tom & Jim, The 1 J-109 (PTD 2060500) gas lift test was completed on 9/11 /07. The weN has been converted back to jet pump configuration and is currently shut in waiting on the plant to bring the coalesces back online. Summary After a couple of failed attempts at getting the well to flow with gas lift, 1 J-109 was brought online in gas lift service on 8/29. Operations had to fight to keep the well ftom hydrating off during the 13 day flow period. We learned a few things from doing this test. 1) There was an obstruction below the jet pump that had restricted inflow. 2) The watercut of the welt is in the 4-7% range. 3) gas lift is not the ideal lift mechanism for this well due to hydrating issues. Below is a list of recent events including welMrork and well test data. Events 8/10/2007 Concentric Coil cleanout completed, Plant shutdown/coalesces work started around this time so the well was not brought online for a while. 8/29/2007 11:01AM. 1J-109 was brought online with gaslift. it appears the well did not start flowing until 18:21, when the casing pressure built high enough to push gas in#o the tubing. 8/30/2007 Welltest: 223 BOPD, 15 BWPD, 6% WC, 190 MSCF/D FGAS, 779 FGOR, 747 MSCF/D Lift Rate. 8/31/2007 Welltest: 204 BOPD, 15 BWPD, 7% WC, 269 MSCF/D FGAS, 9318 FGOR, 871 MSCF/D lift Rate. 9/10/2007 Welltest: 99 BOPD, 5 BWPD, 4%WC, 210 MSCF/D FGAS, 2128 FGOR, 1222 MSCF/D Lift Rate. 9/1112007 12:39PM. 1 J-109 was shut in for conversion back to jet pump tilt. Wellwosk had to wait because Doyon 141 was on 1 J-107 and blocked access to the wellhead. 9/17/2007 Coil Tubing jetted across the CMU profile and installed a jet pump. 9/19/2007 Slickline dummied off the GLV @ 2212'MD and PTd the tubing to make sure the GLV was set. We11 is ready downhole wise for jet pump lift. Please let me know if you have any questions. Brent Rogers Problem Wells Supervisor 659-7224 l O18I2007 1J-109 PTD # 206-050, notice of second attempt to produce well via gas lift Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv jn1617@conocophillips.com] Sent: Wednesday, August 29, 2007 4:40 PM To: Maunder, Thomas E {DOA); Regg, James 8 (DOA) Subiect: 1J-109 PTD # 206-050, notice of second attempt to produce well via gas lift Tom & Jim, 1J-109, PTD # 206-050 was placed on gas lift production today in a second attempt to flow the well. We will notify you of the results of the test once it is complete. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n 1617@conocophillips.com 10/8/2007 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. 206-050 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: 1 J-109 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-029-23307-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 306-285 8/31/2006 Ku aruk 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 totals (bbls): 2006 / 3rd 0 0 0 0 0 2006 / atn 946 100 0 1046 2 10/2/2006 10/3/2006 1 J-115 2007 / 1st 0 0 0 0 0 2007 / 2nd 0 0 0 0 0 Total Ending Report is due on the 20th volume 946 100 0 1046 2 (bbis>: of the month following the final month of the quarter. Ex: 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): I hereby certify that the foregoin is~true and correct to the best of my knowledge. f \ ` s i 7 ~S(© ms gnature: - Date: S Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 i Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 1J-109 PTD # 206-050, Gas lift. attempt. Page 1 of 1 ~~. ~..; Maunder, Thomas. E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, June 30, 2007 1:10 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: 1J-109 PTD # 206-050, Gas lift attempt. Attachments: 1 J-109. pdf Tom, Attempts to produce 1J-109,through the jet pump, via gas lift through an open sleeve have been unsuccessful. We plan to pull the jet pump and install live gas lift valves in stations 1 and 2 at 2212' and 10427' respectively. A second attempt to lift the well via the gas lift valves and the open sliding sleeve will be attempted at that time. Let me know if you have any questions. 1J-109 PTD # 206-050, Gas lift attempt correction Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv (n1617@conocophillips.com) Sent: Saturday, June 30, 2007 1:14 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA} Subject: 1J-109 PTD # 206-050, Gas lift attempt correction Tom, One correction, we will not attempt to reach and change the GLV at station # 2. Only one live valve will be installed at station # 1, 2212'. Sorry for the confusion. Perry Klein Problem Wel! Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com 7/2/2007 Maunder, Thomas E (DOA) • Page 1 of 2 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, June 23, 2007 11:07 AM To: tom maunder@admin.state.ak.us Cc: NSK Problem Well Supv Subject: FV-P 1 J-1(~9 (F'TD 2060500) Request for permission to temporarily gas lift with TxIA comm for RWO eval Tom: Today we started GL on 1 J-109. As per the previous e-mail; this will be for a limited time and we will notify you when it is discontinued. Please let us know if you have any questions. Jerry Dethlefs Bren# Rogers ConocoPhillips From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, June 20, 2007 10:12 AM To: NSK Problem Well Supv Cc: James Regg Subject: Re: 1J-109 (PTD 2060500) Request for permission to temporarily gas lift with TxIA comm for RWO eval Marie, I have spoken with Commissioner Foerster. No sundry is needed to produce the well on gas lift. When the production is reported, gas lift should be the reported production method not hydraulic pump. Good luck. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 6/20/2007 10:01 AM: Tom, West Sak surface powered jet pump producer 1J-109 (PTD 2060500) is scheduled for a sidetrack due to low productivity. It is currently on the rig schedule for Aug 2007. Due to the difficulty of metering a small quantity of oil in a large water stream, there is some question as to the actual production rate of this well. The well makes less than 100 BOPD with 2500 BWPD of power fluid. Before P&A'n this wellbore, a short term test on gas lift is desired to ensure it is not being prematurely abandoned. Permission to gas lift this well thru the jet pump for 2-4 weeks is requested. Since there is no check valve in the jet pump, the well would have TxIA communication on gas lift. Due to the high angle at the depth of the sliding sleeve and bottom GLM, coiled tubing would be required to close the sleeve and install an OV in the bottom GLM to gas lift the well without TxIA communication. Due to the difficulty of setting GLVs with CTU and potential for wellwork difficulties, it is preferable to gas lift the well thru the jet pump for this short term test. Operations is ready to start gas lift as soon as approval is granted. Please advise if it is acceptable to gas lift this well thru the jet pump or if a formal sundry application is required due to the TxIA communication. The well has 2 barriers as the production casing and surface casing have integrity. The production casing passed an MITIA to 3000 psi on 8/31/06 prior to opening the sleeve and installing the jet pump. Attached is a schematic. 7/2/2007 Page 2 of 2 am leaving today at noon and Perry Klein is on vacation for 1 week. If there are any questions regarding reservoir, please feel free to contact Neil Spencley for details. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617~conocophillips corr~ __ «1J-109.pdf» From: Spenceley, Neil Sent: Wednesday, June 20, 2007 7:50 AM To: NSK West Sak Prod Engr; Schwartz, Guy L Cc: Rodgers, James T; Pierson, Chris R Subject: 1J-109 Guy/ Hai/ Peter, Jim Smith called me this morning and prior to us abandoning iJ-109 BP would like to see what it is capable of on gas lift (i.e., take the jet pump power fluid overprint away so we know definitively what the well is making). 1J-109A is meant to be the next well on the rig schedule (effectively BP has stated that they need to see this test to determine if it should be P&A`d). Please reply to me with timing as to when we can expect this to happen. Thanks. Neil K. Spenceley West Sak Development Coordinator Phone: (907) 263-4906 Fax: (907) 263-4486 Cell: (907) 301-2819 email: neil.k,spenceley~a con©cophillips.com 7/2/2007 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-109, March 15, 2007 AK-MW-4474893 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-109: Digital Log Images: 50-029-23307-00 ~- t~:~ 1 CD Rom PLEASE ACI~'VOWLEDGE RECEIPT BY SIGNING AND RETLRNING A COPY OF TIIE TRANSVIITTAL LETTER TO TIIE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~- ~=- ;, Signed:~~~ f:'~-~'------_ ~~1~ .~~ N x ' ~ a ~~~~ ~ ~ RR~ _~~ ~ ~ ,, .._~~~:- 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: f~6-~15C} ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: 1 J-109 2. Address: 4b. Well Status: Oil ^~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-029-23307-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 306-285 8/31/2006 Ku aruk 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 totals (bbls): 2006 / 3rd 0 0 0 0 0 2006 / ath 946 100 0 1046 2 10/2/2006 10/3/2006 1 J-115 2007 / 1st 0 0 0 0 0 2007 / 2nd Total Ending Report is due on the ZOth volume 946 100 0 1046 2 Ex: of the month following the final month of the quarter (bbls): . July 20 for the second quarter, Apri120 for the first 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): I hereby certify that the foregoin~is true and correct to the best of my knowledge. G~ ~~ ~U \ ~`^-~ ~ D Signature: ate: 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 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: nm 208-Q50r ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. WeII Name: 1 J-109 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-029-23307-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g, Field: Initial Disposal ^~ or Continuation ^ or Final ^ 306-285 8/31/2006 Kuparuk 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 totals (bbls): 2006 / 3rd 0 0 0 0 0 Zoos / ath 946 100 0 1046 2 10/2/2006 10/3/2006 1 J-115 2007 / 1st 2007 / 2nd Total Ending Report is due on the 20th volume 946 100 0 1046 2 Ex: of the month following the final month of the quarter (bbls>: . July 20 for the second quarter, April 20 for the first 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): I hereby certify that the f re oing is true and correct to the best of my knowledge. Signature: ~'-' 4~'°`""'-""'~ Date: ~ r~~- ~G 7 Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 L Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • • 14-Sep-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-109 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,815.27' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 15,160.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICHC~HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. ~A.n~chorage, AK 99518 Da#~ ~~ 0~"~~ Signed 4 Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~o[r,~~~ • • 14-Sep-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-109PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey Projected Survey: 40.83' MD 0.00' MD (if applicable) 11,004.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICHC~?HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date~U \ ~u ~ Signed / Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~v-d~~ 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: 205-050 ConocoPhillipsAlaska, Inc. Development ~ Exploratory ^ 7. Well Name: 1J-109 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-029-23307-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ~ or Continuation ^ or Final ^ 306-285 8/31/2006 Ku aruk 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 totals (bbls): 2006 / 3rd 0 0 0 0 0 2006 / 4th 2007 / 1st 2007 / 2nd Total Ending Report is due on the 20th Volume (bbls): 0 0 0 0 0 of the month following the final month of the quarter. Ex: 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): I hereby certify that the foregoin true and correct to the best of my knowledge. / / , b (6 `O>~ Si t ! D gna ure: ate: 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 ConocoPhillips September 27, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 J-109 Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~~~~~ s~P ~ s 2aos Alaska Oil & Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the West Sak well 1J-109. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~~~E~ a STATE OF ALASKA ~ ~~p 2 g 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION a CpfllmiSSiQt1 WELL COMPLETION OR RECOMPLETION REPOF~T,1~A1~[~~~~' 1a. Well Status: Oil Q Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: August 15, 2006 ~ 12. Permit to Drill Number: 206-050 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: July 9, 2006 13. API Number: 50-029-23307-00 4a. Location of Well (Governmental Section): Surface: 2089' FSL, 2408' FEL, Sec. 35, T11 N, R10E, UM 7. Date TD Reached: August 4, 2006 14. Well Name and Number: 1J-109 At Top Productive Horizon: 1893' FSL, 746' FWL, Sec. 31, T11 N, R11 E, UM 8. KB Elevation (ft): 43' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 2371' FNL, 644' FWL, Sec. 6, T10N, R11 E, UM 9. Plug Back Depth (MD + TVD): 14218' MD / 3687' TVD • West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558800 * y- 5945901 Zone- 4 10. Total Depth (MD + TVD): 15160' MD / 3782' ND 16. Property Designation: , ADL 28248, 390705 TPI: x- 567235 y- 5945776 Zone- 4 Total Depth: x- 567171 y- 5941512 ~ Zone- 4 11. Depth where SSSV set: nipple @ 513' 17. Land Use Permit: ALK 591, 3818 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 7283' MD 21. Logs Run: GRlRes, Dens/Neu, USIT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 94# H-40 40' 122' 40' 122' 42" 340 sx AS 1 13.375" 68# L-80 43' 4152' 43' 2306' 16" 80o sx AS Lite, 220 sx DeepCRETE 9-5/8" 40# L-80 41' 10853' 41' 3758' 12.25" 728 sx Class G 4.5" 11.6# L-80 10647' 14218' 3728' 3687' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 10704' 10647' slotted liner from 11276'-14190' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production September 25, 2006 Method of Operation (Flowing, gas lift, etc.) surface powered jet pump oil producer Date of Test 9/27/2006 Hours Tested 12 hours Production for Test Period --> OIL-BBL 94 GAS-MCF 196 WATER-BBL 137 CHOKE SIZE 100% GAS-OIL RA710 2097 Flow Tubing press. 161 psi Casing Pressure 2240 Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". n, GOfri~ ,.ETiOtt x HATE NONE ~ m Form 10-407 Revised 12/2003 CONTINUED ON REVERSE /~~ ~~ 4'-~/ •OG o~~GiNA 2a. is. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-109 Top West Sak D 10875' 3761' Base West Sak D 15088' 3767' N/A 1 J-109P61 TD 11004' 3782' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Name Rar~~v Th Title: Greater Kuoaruk Area Drilling Team Leader y ~ r2 6 /~6 Si t D - ~ gna ure ~, one mss - 6 ~ j ~ ate INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Halliburton Company Survey Report Companyt ConocoPhillipsAlaska Inc . Date: 8/16/2006 Time: 1C:27:22 Page: Field: Kuparuk River Unit Co -ordinate(NE) Reference: V~ell: 1J-109, Tr ueNorth tine: Kuparuk 1J Pad Ve rtical (TVD) Reference: 1J-109: 121.8 ~~cIL• 1J-109 Section (VS}Reference: Well (O.OON,O.OOE,180.OOP,zI) ~~ellpath: 1J-109 5ur~~c}~ Calcidaton Method: Minimum Curvature Db: Grade Field: Kuparuk River Unit North Slope Alaska United States ~ Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre j Sys Datum: Mean Sea Level ~-- Geomagnetic Model: bggm2005 - WeII: 1 J-109 ~ Slot Name: ~ I Well Position: +N/-S -18.09 ft Northing: 5945901.64 ft Latitude: 70 15 46.080 N +E/-W 10.64 ft Easti ng : 55880 0.73 ft Longitude: 149 31 28.697 W Position Uncertainty: _ 0.00 ft ~ _ ~Wellpath: 1J-109 ~ Drilled From: 1J-109PB1 -- 500292330700 Tie-on Depth: 10815.27 ft Current Datum: 1J-109: Height 121.83 ft Above System Datum: Mean Sea Level ~; Magnetic Data: 7/5/2006 Declination: 24.04 deg Field Strength: 57565 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.83 0.00 0.00 180.00 _ ICI Survey Program for Definitive Wellpath ~' Date: 8/16/2006 Validated: No Version: 1 ' , Actual From To Survey Toolcode Tool Name ft ft 100.00 600.00 1J-109P61 gyro (100.00-600.00) CB-GYRO-SS Camera based gyro single shot 674.98 10815.27 1J-109PB1 (674.98- 10959.45) (0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 10882.00 15124.54 1J-109 (10 882.00-15124.54) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey A1D [ncl Azim TVD Sys'I'~'D N/S E/R' DiapN ~lapE ~ Tool ft deg deg ft ft ft ft ft ft r -- _ _ _ ____ _ _ - _ _ _ __ 40.83 0.00 0.00 40.83 -81.00 0.00 0.00 5945901.64 558800.73 ~ TIE LINE i 100.00 0.14 50.73 100.00 -21.83 0.05 0.06 5945901.69 558800.79 CB-GYRO-SS 'i 200.00 1.47 70.67 199.99 78.16 0.55 1.36 5945902.20 558802.09 CB-GYRO-SS '. I, 300.00 5.11 61.60 299.81 177.98 3.09 6.49 5945904.78 558807.20 CB-GYRO-SS I 400.00 8.21 65.51 399.12 277.29 8.17 16.91 5945909.94 558817.57 CB-GYRO-SS 500.00 11.54 70.27 497.63 375.80 14.51 32.83 5945916.40 558833.44 CB-GYRO-SS 600.00 14.23 71.95 595.10 473.27 21.70 53.93 5945923.75 558854.49 CB-GYRO-SS 674.98 16.37 77.19 667.42 545.59 26.89 73.00 5945929.10 558873.51 MWD+IFR-AK-CAZ-SC !, 770.64 20.60 79.36 758.13 636.30 32.99 102.70 5945935.43 558903.16 MWD+IFR-AK-CAZ-SC j 861.83 22.44 80.26 i 842.96 721.13 38.90 135.62 5945941.59 558936.03 MWD+IFR-AK-CAZ-SC ~ ~ 955.95 23.12 81.84 I 929.74 807.91 44.56 171.62 5945947.54 558971.98 MWD+IFR-AK-CAZ-SC I 1053.20 26.13 78.42 1018.14 896.31 51.57 211.51 5945954.86 559011.81 MWD+IFR-AK-CAZ-SC I 1148.64 28.92 78.59 1102.76 980.93 60.36 254.72 5945963.98 559054.95 MWD+IFR-AK-CAZ-SC I, 1243.33 31.58 79.56 1184.55 1062.72 69.38 301.56 5945973.37 559101.71 MWD+IFR-AK-CAZ-SC 1338.46 33.72 79.39 1264.65 1142.82 78.76 352.02 5945983.14 559152.09 MWD+IFR-AK-CAZ-SC 1434.00 35.53 81.92 1343.27 1221.44 87.54 405.57 5945992.34 559205.57 MWD+IFR-AK-CAZ-SC 1527.61 38.96 80.30 1417.78 1295.95 96.33 461.53 5946001.56 559261.45 MWD+IFR-AK-CAZ-SC 1623.22 43.29 81.36 1489.78 1367.95 106.32 523.60 5946012.04 559323.43 MWD+IFR-AK-CAZ-SC 1718.06 44.06 80.89 1558.37 1436.54 116.43 588.31 5946022.65 559388.05 MWD+IFR-AK-CAZ-SC ', 1812.62 47.01 80.14 1624.60 1502.77 127.56 654.86 5946034.30 559454.51 MWD+IFR-AK-CAZ-SC ~ ii 1908.00 49.47 79.95 1688.12 1566.29 139.86 724.93 5946047.14 559524.48 MWD+IFR-AK-CAZ-SC ~~ 2002.48 54.80 79.28 1746.10 1624.27 153.32 798.27 5946061.17 559597.70 MWD+IFR-AK-CAZ-SC ~, 2097.42 58.78 79.74 1798.08 1676.25 167.77 876.36 5946076.23 559675.67 MWD+IFR-AK-CAZ-SC 2195.30 63.16 79.65 1845.57 1723.74 183.08 960.54 5946092.19 559759.72 MWD+IFR-AK-CAZ-SC li 2289.98 68.10 79.10 1884.63 1762.80 198.98 1045.28 5946108.76 559844.32 MWD+IFR-AK-CAZ-SC ~~ 2384.68 74.16 77.78 1915.24 1793.41 216.95 1133.02 5946127.41 559931.91 MWD+IFR-AK-CAZ-SC 2479.39 76.99 76.62 1938.83 1817.00 237.27 1222.45 5946148.43 560021.18 MWD+IFR-AK-CAZ-SC I 2575.15 77.49 76.90 1959.98 1838.15 258.66 1313.37 5946170.52 560111.91 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Cnmp:wy: ConocoPhillipsAlaska Inc. Date: 8/16/20D6 lime 10:2722 Part: Ficl~: Kuparuk River Uni t Co-or dinate (NE) Reference. Well: 1J-10 9, True North ''' Site; Kuparuk 1J Pad Vertical (TVD) Reference. 1J-109: 121.8 Well: 1.1- 109 Sectio n (VS) Refe rence Well (O.OON,Q AOE,180':OOAzi) Wellpafh: 1J- 109 Survey Calculatiuu Vietiwd: Minimum C urv ature llb: Oracle Survey ',ltD lncl Azim CVD SysTVD NIS F./W 111ap~ MapE Tool ' ft r --- deg de g ft __ __ _ ft ft ft - __ ft - ft - ' 2669.88 78.45 77 .60 1979. 73 1857. 90 279 .11 1403. 73 5946191 .67 560202 .10 MWD+IFR-AK-CAZ-SC j 2765.74 77.81 78 .16 1999. 45 1877. 62 298 .80 1495. 45 5946212 .08 560293 .66 MWD+IFR-AK-CAZ-SC 2860.78 73.75 78 .87 2022. 79 1900. 96 317 .15 1585. 71 5946231 .13 560383 .76 MWD+IFR-AK-CAZ-SC i 2958.30 76.07 79 .51 2048. 17 1926. 34 334 .80 1678. 19 5946249 .51 560476 .09 MWD+IFR-AK-CAZ-SC ~ ~ 3053.40 79.20 78 .32 2068. 54 1946. 71 352 .67 1769. 34 5946268 .08 560567 .09 MWD+IFR-AK-CAZ-SC 3148.65 78.87 76 .47 2086 .66 1964. 83 373 .07 1860. 59 5946289 .19 560658 .17 MWD+IFR-AK-CAZ-SC 3243.93 78.25 76 .89 2105 .55 1983. 72 394 .59 1951. 46 5946311 .42 560748 .87 MWD+IFR-AK-CAZ-SC 3339.52 76.56 77 .79 2126 .40 2004. 57 415 .04 2042. 48 5946332 .57 560839 .71 MWD+IFR-AK-CAZ-SC 3434.70 75.74 78 .79 2149. 18 2027. 35 433 .79 2132. 97 5946352 .03 560930. 04 MWD+IFR-AK-CAZ-SC 3528.60 77.13 78 .85 2171. 21 2049. 38 451 .49 2222. 51 5946370 .43 561019. 44 MWD+IFR-AK-CAZ-SC 3621.99 74.49 79 .74 2194. 10 2072. 27 468 .31 2311. 47 5946387 .94 561108. 25 MWD+IFR-AK-CAZ-SC 3718.48 78.73 79 .55 2216. 44 2094. 61 485 .18 2403. 79 5946405 .53 561200. 42 MWD+IFR-AK-CAZ-SC 3813.01 76.72 79 .32 2236. 53 2114. 70 502 .12 2494. 58 5946423 .17 561291 .08 MWD+IFR-AK-CAZ-SC 3908.53 78.26 79 .98 2257. 22 2135. 39 518 .87 2586. 32 5946440 .64 561382 .67 MWD+IFR-AK-CAZ-SC i 4006.02 77.78 77 .74 2277 .46 2155. 63 537 .29 2679. 88 5946459 .79 561476 .08 t MWD+IFR-AK-CAZ-SC ~ 4098.46 79.02 77 .39 2296 .05 2174. 22 556 .79 2768. 31 5946479 .97 561564 .34 MWD+IFR-AK-CAZ-SC 4163.78 77.36 77 .37 2309 .42 2187. 59 570 .76 2830. 70 5946494 .43 561626 .61 MWD+IFR-AK-CAZ-SC I 4255.64 75.58 77 .33 2330. 91 2209. 08 590 .31 2917. 84 5946514 .66 561713. 59 MWD+IFR-AK-CAZ-SC i 4351.73 76.48 78 .14 2354. 11 2232. 28 610 .12 3008. 95 5946535 .18 561804. 54 MWD+IFR-AK-CAZ-SC 4448,51 75.47 79 .25 2377. 56 2255. 73 628 .53 3101. 02 5946554 .31 561896. 45 MWD+IFR-AK-CAZ-SC 4543.66 75.72 78 .68 2401. 23 2279. 40 646 .17 3191. 48 5946572 .65 561986 .76 MWD+IFR-AK-CAZ-SC 4639.40 75.58 79 .73 2424. 96 2303. 13 663 .54 3282. 59 5946590 .73 562077 .72 MWD+IFR-AK-CAZ-SC 4734.38 75.90 80 .46 2448 .36 2326. 53 679 .38 3373. 27 5946607 .27 562168 .27 MWD+IFR-AK-CAZ-SC !, 4829.35 76.72 81 .41 2470 .83 2349. 00 693 .91 3464. 39 5946622 .52 562259 .26 MWD+IFR-AK-CAZ-SC ~~ 4924.42 76.72 80 .39 2492 .67 2370. 84 708 .55 3555. 75 5946637 .86 562350 .50 MWD+IFR-AK-CAZ-SC 5019.94 76.98 80 .08 2514. 40 2392. 57 724 .32 3647. 42 5946654 .35 562442. 03 MWD+IFR-AK-CAZ-SC 5115.49 77.36 78 .85 2535. 62 2413. 79 741 .36 3739. 01 5946672 .10 562533. 47 MWD+IFR-AK-CAZ-SC 5210.67 76.74 79 .49 2556. 95 2435. 12 758 .79 3830. 11 5946690 .24 562624. 43 MWD+IFR-AK-CAZ-SC ~, 5305.42 76.60 80 .23 2578. 80 2456. 97 775 .02 3920. 87 5946707 .18 562715. 05 MWD+IFR-AK-CAZ-SC ~I 5400.49 76.99 81 .08 2600. 52 2478. 69 790 .05 4012. 20 5946722 .92 562806 .25 MWD+IFR-AK-CAZ-SC !, 5489.21 76.73 81 .52 2620. 68 2498. 85 803 .12 4097. 60 5946736 .65 562891 .54 MWD+IFR-AK-CAZ-SC 5589.42 76.86 82 .02 2643. 58 2521. 75 817 .08 4194. 15 5946751 .37 562987 .97 MWD+IFR-AK-CAZ-SC 5683.25 78.19 83 .98 2663 .85 2542. 02 828 .24 4285. 08 5946763 .24 563078 .80 MWD+IFR-AK-CAZ-SC 5779.37 78.50 83 .44 2683. 26 2561. 43 838 .55 4378. 65 5946774 .28 563172. 28 MWD+IFR-AK-CAZ-SC ~ ~I 5875.73 78.44 82 .02 2702. 53 2580. 70 850 .50 4472. 30 5946786 .96 563265. 83 MWD+IFR-AK-CAZ-SC !i 5970.65 77.81 80 .80 2722. 06 2600. 23 864 .37 4564. 15 5946801 .54 563357. 55 MWD+IFR-AK-CAZ-SC 6066.56 77.74 80 .38 2742. 37 2620. 54 879 .70 4656. 62 5946817 .59 563449. 89 MWD+IFR-AK-CAZ-SC 6158.84 77.23 79 .12 2762. 36 2640. 53 895 .73 4745. 27 5946834 .31 563538. 41 MWD+IFR-AK-CAZ-SC i 6256.37 78.18 79 .05 2783. 13 2661. 30 913 .77 4838. 84 5946853 .08 563631 .82 MWD+IFR-AK-CAZ-SC ' 6352.75 78.00 77 .97 2803. 02 2681. 19 932 .56 4931. 25 5946872 .59 563724. 08 MWD+IFR-AK-CAZ-SC 6447.69 78.51 78 .41 2822. 35 2700. 52 951 .58 5022. 24 5946892 .32 563814 .90 MWD+IFR-AK-CAZ-SC ~~ 6542.05 78.37 77 .55 2841. 26 2719. 43 970 .83 5112. 65 5946912 .27 563905 .16 MWD+IFR-AK-CAZ-SC 6638.20 77.74 77 .51 2861. 16 2739. 33 991 .15 5204. 50 5946933 .30 563996. 83 MWD+IFR-AK-CAZ-SC ~~, j 6732.51 77.23 75 .61 2881. 60 2759. 77 1012 .54 5294. 05 5946955 .39 564086. 20 MWD+IFR-AK-CAZ-SC 6828.14 77.56 74 .97 2902. 47 2780. 64 1036 .24 5384. 31 5946979 .79 564176. 27 MWD+IFR-AK-CAZ-SC 6922.89 77.42 75 .14 2922. 99 2801. 16 1060 .10 5473. 68 5947004 .34 564265. 44 MWD+IFR-AK-CAZ-SC 7017.56 77.50 75 .80 2943. 55 2821. 72 1083 .28 5563. 14 5947028 .22 564354. 71 MWD+IFR-AK-CAZ-SC 7113.53 77.62 75 .81 2964. 22 2842. 39 1106 .26 5653. 99 5947051 .91 564445. 37 MWD+IFR-AK-CAZ-SC 7208.03 77.75 76 .10 2984 .38 2862. 55 1128 .67 5743. 56 5947075 .01 564534 .75 MWD+IFR-AK-CAZ-SC ' 7302.79 77.42 75 .74 3004. 75 2882. 92 1151 .18 5833. 32 5947098 .22 564624 .33 MWD+IFR-AK-CAZ-SC II 7399.70 77.74 76 .60 3025. 59 2903. 76 1173 .80 5925. 22 5947121 .56 564716. 03 MWD+IFR-AK-CAZ-SC '~~ 7493.39 77.43 77 .23 3045. 73 2923. 90 1194 .52 6014. 34 5947142 .97 564804. 98 MWD+IFR-AK-CAZ-SC ', Halliburton Company Survey Report Company: ConocoPhillips Alaska lnc. Da1c: 8/16/2006 -time: 10:27:22 Page: 3 Field: Kuparu k River Uni t Co-ordinate {NE) Reference: Well: 1J-109, True North tine: Kuparu k 1J Pad Vertical (TVI)yReference: 1J-109: 121.8 ~~cll: 1J -109 Sectio n (VS) Itrfe rcnce: Well (0-OON,D.O OE,180.OOAzi) l~elipxth: '1J -109 Survey CalcuiAric~n itilethod: Minimum Gurvaiure Db: Oracle Survey ', SID Inc l Azim TVD Svs'i'VD N/S E,IW IvlapN D~1apE "Iuu! ft deg deg ft ft ft ft ft ft 7590.27 77 .04 79 .88 3067. 14 2945.31 1213.27 6106. 94 5947162. 44 564897.42 MWD+IFR-AK-CAZ-SC ~ 7685.84 77 .24 77 .06 3088. 42 2966.59 1231.89 6198. 22 5947181. 77 564988.55 MWD+IFR-AK-CAZ-SC 7779.08 76 .16 79 .17 3109. 87 2988.04 1250.58 6287. 01 5947201 .15 565077.18 MWD+IFR-AK-CAZ-SC 7875.82 74 .81 79 .24 3134. 12 3012.29 1268.12 6379. 00 5947219 .41 565169.02 MWD+IFR-AK-CAZ-SC 7979.07 76 .12 82 .53 3160. 04 3038.21 1283.94 6477. 67 5947236 .00 565267.55 MWD+IFR-AK-CAZ-SC 8072.07 76 .69 84 .90 3181. 90 3060.07 1293.83 6567. 51 5947246 .59 565357.31 MWD+IFR-AK-CAZ-SC 8167.52 75 .72 85 .83 3204. 66 3082.83 1301.33 6659. 90 5947254. 81 565449.63 MWD+IFR-AK-CAZ-SC 8263.21 75 .51 87 .40 3228. 43 3106.60 1306.80 6752. 43 5947261. 00 565542.10 MWD+IFR-AK-CAZ-SC 8357.67 75 .77 89 .27 3251. 86 3130.03 1309.46 6843. 89 5947264 .37 565633.53 MWD+IFR-AK-CAZ-SC 8452.05 75 .02 92 .24 3275. 66 3153.83 1308.26 6935. 20 5947263 .89 565724.84 MWD+IFR-AK-CAZ-SC 8548.29 76 .15 95 .20 3299. 63 3177.80 1302.20 7028. 20 5947258 .56 565817.88 MWD+IFR-AK-CAZ-SC 8639.23 77 .34 98 .22 3320. 48 3198.65 1291.86 7116. 10 5947248 .90 565905.84 MWD+IFR-AK-CAZ-SC 8739.98 76 .91 102. 42 3342. 94 3221.11 1274.27 7212. 71 5947232. 07 566002.57 MWD+IFR-AK-CAZ-SC 8835.59 76 .93 104 .36 3364. 58 3242.75 1252.70 7303. 30 5947211 .21 566093.32 MWD+IFR-AK-CAZ-SC 8930.15 74 .52 107 .50 3387. 90 3266.07 1227.57 7391. 41 5947186 .77 566181.61 MWD+IFR-AK-CAZ-SC I 9024.86 76 .07 111 .86 3411. 95 3290.12 1196.72 7477. 63 5947156 .60 566268.07 MWD+IFR-AK-CAZ-SC 9118.89 73 .29 113 .01 3436. 80 3314.97 1162.12 7561. 45 5947122 .65 566352.15 MWD+IFR-AK-CAZ-SC 9214.65 73 .48 115 .29 3464. 18 3342.35 1124.58 7645. 17 5947085 .77 566436.15 MWD+IFR-AK-CAZ-SC 9309.40 73 .60 117 .72 3491. 03 3369.20 1084.03 7726. 48 5947045 .86 566517.77 MWD+IFR-AK-CAZ-SC ~ 9403.10 74 .80 121 .98 3516. 55 3394.72 1039.16 7804. 65 5947001 .61 566596.28 MWD+IFR-AK-CAZ-SC 9498.28 77 .53 126 .00 3539. 32 3417.49 987.49 7881. 25 5946950 .55 566673.27 MWD+IFR-AK-CAZ-SC 9592.32 77 .66 129 .31 3559. 53 3437.70 931.39 7953. 95 5946895 .02 566746.40 MWD+IFR-AK-CAZ-SC 9690.83 81 .02 133 .96 3577. 76 3455.93 867.09 8026. 26 5946831 .29 566819.20 MWD+IFR-AK-CAZ-SC 9785.68 79 .66 138 .76 3593. 68 3471.85 799.44 8090. 77 5946764 .16 566884.23 MWD+IFR-AK-CAZ-SC j 9878.90 78 .09 142 .17 3611. 67 3489.84 728.92 8148. 99 5946694 .10 566943.00 MWD+IFR-AK-CAZ-SC 9974.53 79 .70 143 .99 3630. 09 3508.26 653.90 8205. 35 5946619 .53 566999.94 MWD+IFR-AK-CAZ-SC 10070.12 80 .97 149 .55 3646. 15 3524.32 575.11 8256. 96 5946541 .15 567052.16 MWD+IFR-AK-CAZ-SC 10164.62 81 .15 155 .03 3660. 85 3539.02 492.49 8300. 35 5946458 .88 567096.19 MWD+IFR-AK-CAZ-SC ', 10244.61 80 .09 157 .94 3673. 89 3552.06 420.14 8331. 84 5946386 .78 567128.23 MWD+IFR-AK-CAZ-SC i 10339.57 80 .20 160 .60 3690. 15 3568.32 332.64 8364. 95 5946299 .56 567162.03 MWD+IFR-AK-CAZ-SC 10434.48 82 .97 166. 37 3704. 04 3582.21 242.67 8391. 61 5946209. 81 567189.38 MWD+IFR-AK-CAZ-SC 10531.92 84 .00 171 .54 3715. 11 3593.28 147.69 8410. 15 5946114. 98 567208.66 MWD+IFR-AK-CAZ-SC 10626.17 83 .55 175 .84 3725. 33 3603.50 54.58 8420. 44 5946021 .97 567219.68 MWD+IFR-AK-CAZ-SC 10719.28 81 .95 176 .03 3737. 08 3615.25 -37.55 8426. 99 5945929 .90 567226.95 MWD+IFR-AK-CAZ-SC 10815.27 I 81 .10 177 .64 3751. 23 3629.40 -132.34 8432. 23 5945835 .16 567232.93 MWD+IFR-AK-CAZ-SC 10882.00 80 .61 180 .16 3761. 84 3640.01 -198.20 8433. 50 5945769 .32 567234.71 MWD+IFR-AK-CAZ-SC ~ 10955.02 82 .26 182. 81 3772. 71 3650.88 -270.38 8431. 63 5945697 .14 567233.40 MWD+IFR-AK-CAZ-SC '~ 11050.49 89 .31 186 .66 3779. 73 3657.90 -365.18 8423. 76 5945602. 28 567226.27 MWD+IFR-AK-CAZ-SC 11145.36 93 .39 189 .32 3777. 49 3655.66 -459.08 8410. 58 5945508 .29 567213.83 MWD+IFR-AK-CAZ-SC 11239.29 94 .75 184 .44 3770. 82 3648.99 -552.07 8399. 36 5945415 .23 567203.33 MWD+IFR-AK-CAZ-SC 11336.66 92 .94 184 .63 3764. 29 3642.46 -648.91 8391. 68 5945318 .34 567196.41 MWD+IFR-AK-CAZ-SC 11430.57 92 .96 182 .33 3759. 46 3637.63 -742.51 8385. 98 5945224 .70 567191.45 MWD+IFR-AK-CAZ-SC 11526.97 93 .53 183 .63 3754. 00 3632.17 -838.63 8380. 98 5945128 .56 567187.20 MWD+IFR-AK-CAZ-SC !, 11622.24 91 .31 182. 42 3749. 98 3628.15 -933.67 8375. 96 5945033. 49 567182.92 MWD+tFR-AK-CAZ-SC 'I 11717.38 92 .28 181 .19 3747. 00 3625.17 -1028.72 8372. 96 5944938 .44 567180.67 MWD+IFR-AK-CAZ-SC 11813.76 91 .97 180 .76 3743. 43 3621.60 -1125.01 8371. 32 5944842 .14 567179.78 MWD+IFR-AK-CAZ-SC ~~~ 11908.59 92 .21 179 .92 3739. 97 3618.14 -1219.78 8370. 76 5944747 .38 567179.96 MWD+IFR-AK-CAZ-SC 12002.17 93 .02 182 .13 3735. 70 3613.87 -1313.24 8369. 09 5944653 .92 567179.02 MWD+IFR-AK-CAZ-SC 12097.09 93 .14 181 .69 3730. 60 3608.77 -1407.97 8365. 93 5944559 .17 567176.60 MWD+IFR-AK-CAZ-SC 12192.64 91 .42 182 .67 3726. 80 3604.97 -1503.37 8362. 30 5944463 .76 567173.71 MWD+IFR-AK-CAZ-SC 12287.68 89 .81 182 .85 3725. 78 3603.95 -1598.29 8357. 72 5944368 .81 567169.88 MWD+IFR-AK-CAZ-SC 12407.45 92 .00 183 .52 3723. 89 3602.06 -1717.85 8351. 07 5944249 .21 567164.16 MWD+IFR-AK-CAZ-SC 12499.78 90 .76 184 .85 3721. 66 3599.83 -1809.91 8344. 33 5944157 .12 567158.14 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report t ompany: ConocoPhillipsAlaska Inc. Date: 8/16/2006 Time: '10:27:22 Page: -t Field: Kuparuk River Unit Co-ordioate(N~) Reference: Well: 1J-109, True North Site: Ku paruk 1 J Pad Vertical (TVD) Reference: 1 J-109' 121.8 Well: 1J -109 Section (VS) References' Well (O OON,O OOE.180.OOAzi) Wetlpath: 1J -109 Survey Calcula tion Method: Minimum Gurv sture Db: Oracle tinr~ev ___ MD lncl lcim TV1) Sys'I'~'D ~'/S F.NV iV1apA' ~~IapE Toolrr-_- ft deg deg ft ft ft ft ft ft 12593. 57 92.32 186.12 3719 .14 3597. 31 -1903. 23 8335.37 5944063. 74 567149.91 MWD+IFR-AK-CAZ-SC 12689. 05 90.45 185.47 3716 .83 3595. 00 -1998. 19 8325.74 5943968. 72 567141.02 MWD+IFR-AK-CAZ-SC 12784. 34 91.64 186.80 3715 .10 3593. 27 -2092. 91 8315.55 5943873. 92 567131.57 MWD+IFR-AK-CAZ-SC 12880. 00 93.00 187.95 3711 .22 3589. 39 -2187. 70 8303.29 5943779. 05 567120.05 MWD+IFR-AK-CAZ-SC 12971. 88 90.07 184.06 3708 .76 3586. 93 -2279. 02 8293.68 5943687. 67 567111.16 MWD+IFR-AK-CAZ-SC j 13069. 56 93.38 184.42 3705 .82 3583. 99 -2376. 37 8286.47 5943590. 28 567104.70 MWD+IFR-AK-CAZ-SC 13166. 21 95.11 181.95 3698 .67 3576. 84 -2472. 60 8281.11 5943494. 02 567100.10 MWD+IFR-AK-CAZ-SC 13259. 04 90.68 181.41 3693 .98 3572. 15 -2565. 24 8278.39 5943401. 36 567098.11 MWD+IFR-AK-CAZ-SC 13357. 91 90.46 178.84 3693 .00 3571. 17 -2664. 10 8278.18 5943302. 52 567098.66 MWD+IFR-AK-CAZ-SC 13451. 67 89.96 176.97 3692 .65 3570. 82 -2757. 79 8281.60 5943208. 86 567102.82 MWD+IFR-AK-CAZ-SC 13545. 96 90.40 176.88 3692 .36 3570. 53 -2851. 95 8286.66 5943114. 76 567108.61 MWD+IFR-AK-CAZ-SC 13640. 32 91.26 178.64 3690 .99 3569. 16 -2946. 22 8290.35 5943020. 53 567113.04 MWD+IFR-AK-CAZ-SC 13737. 61 91.32 180.62 3688 .80 3566. 97 -3043. 48 8290.98 5942923. 29 567114.42 I MWD+IFR-AK-CAZ-SC 13834. 24 90.76 180.58 3687 .04 3565. 21 -3140. 09 8289.97 5942826. 68 567114.17 MWD+IFR-AK-CAZ-SC 13928. 82 90.21 181.82 3686 .24 3564. 41 -3234. 64 8287.99 5942732. 13 567112.92 MWD+IFR-AK-CAZ-SC 14024. 42 89.03 182.66 3686 .88 3565. 05 -3330. 16 8284.25 5942636. 59 567109.93 MWD+IFR-AK-CAZ-SC 14118. 81 89.85 184.14 3687 .80 3565. 97 -3424. 38 8278.65 5942542. 34 567105.07 MWD+IFR-AK-CAZ-SC 14213. 66 90.65 181.47 3687 .39 3565. 56 -3519. 10 8274.01 5942447. 59 567101.17 MWD+IFR-AK-CAZ-SC 14308. 39 89.71 178.74 3687 .09 3565. 26 -3613. 82 8273.84 5942352. 88 567101.74 MWD+IFR-AK-CAZ-SC 14403. 29 91.27 177.32 3686 .28 3564. 45 -3708. 66 8277.10 5942258. 08 567105.74 MWD+IFR-AK-CAZ-SC 14492. 01 87.34 174.12 3687 .35 3565. 52 -3797. 10 8283.72 5942169. 71 567113.05 MWD+IFR-AK-CAZ-SC 14591. 40 81.92 174.36 3696 .65 3574. 82 -3895. 51 8293.64 5942071. 38 567123.74 MWD+IFR-AK-CAZ-SC 14688. 48 79.26 172.14 3712 .52 3590. 69 -3990. 61 8304.89 5941976. 38 567135.73 MWD+IFR-AK-CAZ-SC ~ 14783. 63 80.92 171.93 3728 .90 3607. 07 -4083. 43 8317.88 5941883. 68 567149.44 MWD+IFR-AK-CAZ-SC 14879. 07 82.74 174.85 3742 .46 3620. 63 -4177. 26 8328.75 5941789. 94 567161.04 MWD+tFR-AK-CAZ-SC 14974. 71 85.09 179.54 3752 .61 3630. 78 -4272. 22 8333.39 5941695. 04 567166.43 MWD+IFR-AK-CAZ-SC 15070. 28 81.08 178.61 3764 .11 3642. 28 -4367. 06 8334.92 5941600. 22 567168.70 MWD+IFR-AK-CAZ-SC ~ 15124. 54 77.36 179.93 3774 .26 3652. 43 -4420. 34 8335.60 5941546. 94 567169.79 MWD+IFR-AK-CAZ-SC 15160. 00 77.36 179.93 3782 .02 3660. 19 -4454. 95 8335.64 5941512. 35 . 567170.11 . PROJECTED to TD Halliburton Company • Survey Report Company: ConocoPhillips Alaska inc. Date: 8/16/2006 limn. 10:15'55 Page: 1 ' Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-109. True North Site: Kuparuk 1J Pad Ve rtical (TVII)'Rcfercncc: 1J-149PB1: 121 .8 Well: 1J-109 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-109PB1 Survey ('afeulati un iYie(hud: Minimum Curvature Db~ Oracle Field: Kuparuk River Unit North Slope Alaska ', United States ~ Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 ~, Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level _ Geomagnetic Model: bggm2005 Well: 1 J-109 Slot Name: Well Position: +N/-S -18.09 ft Northing: 5945901.64 ft Latitude: 70 15 46.080 N +E/-W 10.64 ft Easting : 558800.73 ft Longitude: 149 31 28.697 W Position Uncertainty: 0.00 ft ~ ~ - ' Wellpath: 1J-109PB1 Drilled From: Well Ref. Point ~ 500292330770 Tie-on Depth: 40.83 ft Current Datum: 1 J-109PB1: Height 121.83 ft Above System Datum: Mean Sea Level Magnetic Data: 7/5/2006 Declination: 24.04 deg Field Strength: 57565 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ! ~ 40.83 0.00 _ 0.00 180.00 Survey Program for Definitive Wellpa th Date: 3/8/2006 Validated: No V ersion: 3 Actual From To Survey Toolcode Tool Name ft ft 100.00 600.00 1J-109PB1 gyro (100.00-600.00) CB-GYRO SS Camera based gyro single shot 674.98 10959.45 1J-109PB1 (674.98- 10959.45) = MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey 111D Incl Azim TVll SysTVD N/S E/W Maplti MapE 1'uol ' ft deg deg ft ft ft ft ft ft ' 40.83 0.00 0.00 40.83 __ -81.00 0.00 0.00 5945901.64 558800.73 TIE LINE 100.00 0.14 50.73 100.00 -21.83 0.05 0.06 5945901.69 558800.79 CB-GYRO-SS 200.00 1.47 70.67 199.99 78.16 0.55 1.36 5945902.20 558802.09 CB-GYRO-SS 300.00 5.11 61.60 299.81 177.98 3.09 6.49 5945904.78 558807.20 CB-GYRO-SS ~ I 400.00 8.21 65.51 399.12 277.29 8.17 16.91 5945909.94 558817.57 CB-GYRO-SS ~; 500.00 11.54 70.27 497.63 375.80 14.51 32.83 5945916.40 558833.44 CB-GYRO-SS 600.00 14.23 71.95 595.10 473.27 21.70 53.93 5945923.75 558854.49 CB-GYRO-SS 674.98 16.37 77.19 667.42 545.59 26.89 73.00 5945929.10 558873.51 MWD+IFR-AK-CAZ-SC ~ 770.64 20.60 79.36 758.13 636.30 32.99 102.70 5945935.43 558903.16 MWD+IFR-AK-CAZ-SC ' I 861.83 22.44 80.26 842.96 721.13 38.90 135.62 5945941.59 558936.03 MWD+IFR-AK-CAZ-SC 955.95 23.12 81.84 929.74 807.91 44.56 171.62 5945947.54 558971.98 MWD+IFR-AK-CAZ-SC 1053.20 26.13 78.42 1018.14 896.31 51.57 211.51 5945954.86 559011.81 MWD+IFR-AK-CAZ-SC 1148.64 28.92 78.59 1102.76 980.93 60.36 254.72 5945963.98 559054.95 MWD+IFR-AK-CAZ-SC 1243.33 31.58 79.56 1184.55 1062.72 69.38 301.56 5945973.37 559101.71 MWD+IFR-AK-CAZ-SC it 1338.46 33.72 79.39 1264.65 1142.82 78.76 352.02 5945983.14 559152.09 MWD+IFR-AK-CAZ-SC ~ ~' 1434.00 35.53 81.92 1343.27 1221.44 87.54 405.57 5945992.34 559205.57 MWD+IFR-AK-CAZ-SC 1527.61 38.96 80.30 1417.78 1295.95 96.33 461.53 5946001.56 559261.45 MWD+IFR-AK-CAZ-SC , 1623.22 43.29 81.36 1489.78 1367.95 106.32 523.60 5946012.04 559323.43 MWD+IFR-AK-CAZ-SC ', 1718.06 44.06 80.89 1558.37 1436.54 116.43 588.31 5946022.65 559388.05 MWD+IFR-AK-CAZ-SC 1812.62 47.01 80.14 1624.60 1502.77 127.56 654.86 5946034.30 559454.51 MWD+IFR-AK-CAZ-SC 1908.00 49.47 79.95 1688.12 1566.29 139.86 724.93 5946047.14 559524.48 MWD+IFR-AK-CAZ-SC 2002.48 54.80 79.28 1746.10 1624.27 153.32 798.27 5946061.17 559597.70 MWD+IFR-AK-CAZ-SC i 2097.42 58.78 79.74 1798.08 1676.25 167.77 876.36 5946076.23 559675.67 MWD+IFR-AK-CAZ-SC 2195.30 63.16 79.65 1845.57 1723.74 183.08 960.54 5946092.19 559759.72 MWD+IFR-AK-CAZ-SC 2289.98 68.10 79.10 1884.63 1762.80 198.98 1045.28 5946108.76 559844.32 MWD+IFR-AK-CAZ-SC 2384.68 74.16 77.78 1915.24 1793.41 216.95 1133.02 5946127.41 559931.91 MWD+IFR-AK-CAZ-SC 2479.39 76.99 76.62 1938.83 1817.00 237.27 1222.45 5946148.43 560021.18 MWD+IFR-AK-CAZ-SC 2575.15 77.49 76.90 1959.98 1838.15 258.66 1313.37 5946170.52 560111.91 MWD+IFR-AK-CAZ-SC 2669.88 78.45 77.60 1979.73 1857.90 279.11 1403.73 5946191.67 560202.10 MWD+IFR-AK-CAZ-SC Halliburton Company, Survey Report Company: ConocoPhillipsAlaskalnc. Date: 8/1E/2006 Time: 10:15:55 I'a~c: 2 Field: Ku paruk River Unit Co-ordinate (NE) Reference: Well: 1J-109, Tr ue North Site: Kuparuk 1J Pad 'Vertical (TVD) Reference: 1J-109PB1. 121 .8 Well: 1J -109 Sectio n (~~~)'Reference: Well (O.OON,O.OOE,180.OOAzi) ' W'ellpath: 1J -i09PB1 Surce ~ (~alc uG3tiontilethod: Minimum Curvat ure Dh: Oracle Surece Jlll Incl Azim TVD _ _ Sys TVD N/S EJW V[apN l4apE __ Tool ft deg deg ft ft ft ft ft ft 2765.74 77.81 78.16 1999. 45 1877. 62 298.80 1495. 45 5946212 .08 560293.66 MWD+IFR-AK-CAZ-SC 2860.78 73.75 78.87 2022. 79 1900. 96 317.15 1585. 71 5946231 .13 560383.76 MWD+IFR-AK-CAZ-SC ' 2958.30 76.07 79.51 2048. 17 1926. 34 334.80 1678. 19 5946249 .51 560476.09 MWD+IFR-AK-CAZ-SC 3053.40 79.20 78.32 2068. 54 1946. 71 352.67 1769. 34 5946268 .08 560567.09 MWD+IFR-AK-CAZ-SC ~I 3148.65 78.87 76.47 2086. 66 1964. 83 373.07 1860. 59 5946289 .19 560658.17 MWD+IFR-AK-CAZ-SC ~ 3243.93 78.25 76.89 2105. 55 1983. 72 394.59 1951. 46 5946311 .42 560748.87 MWD+IFR-AK-CAZ-SC 3339.52 76.56 77.79 2126 .40 2004. 57 415.04 2042. 48 5946332 .57 560839.71 MWD+IFR-AK-CAZ-SC 3434.70 75.74 78.79 2149 .18 2027. 35 433.79 2132. 97 5946352 .03 560930.04 MWD+IFR-AK-CAZ-SC i, 3528.60 77.13 78.85 2171. 21 2049. 38 451.49 2222. 51 5946370 .43 561019.44 MWD+IFR-AK-CAZ-SC 3621.99 74.49 79.74 2194. 10 2072. 27 468.31 2311. 47 5946387 .94 561108.25 MWD+IFR-AK-CAZ-SC '~ 3718.48 78.73 79.55 2216. 44 2094. 61 485.18 2403. 79 5946405 .53 561200.42 MWD+IFR-AK-CAZ-SC ~~ 3813.01 76.72 79.32 2236. 53 2114. 70 502.12 2494. 58 5946423 .17 561291.08 MWD+IFR-AK-CAZ-SC 3908.53 78.26 79.98 2257. 22 2135. 39 518.87 2586. 32 5946440 .64 561382.67 MWD+IFR-AK-CAZ-SC 4006.02 77.78 77.74 2277 .46 2155. 63 537.29 2679. 88 5946459 .79 561476.08 MWD+IFR-AK-CAZ-SC 4098.46 79.02 77.39 2296 .05 2174. 22 556.79 2768. 31 5946479 .97 561564.34 MWD+IFR-AK-CAZ-SC 4163.78 77.36 77.37 2309 .42 2187. 59 570.76 2830. 70 5946494 .43 561626.61 MWD+IFR-AK-CAZ-SC I ~ 4255.64 75.58 77.33 2330. 91 2209. 08 590.31 2917. 84 5946514 .66 561713.59 MWD+iFR-AK-CAZ-SC 4351.73 76.48 78.14 2354. 11 2232. 28 610.12 3008. 95 5946535 .18 561804.54 MWD+IFR-AK-CAZ-SC 4448.51 75.47 79.25 2377. 56 2255. 73 628.53 3101. 02 5946554 .31 561896.45 MWD+IFR-AK-CAZ-SC I 4543.66 75.72 78.68 2401. 23 2279. 40 646.17 3191. 48 5946572 .65 561986.76 I MWD+IFR-AK-CAZ-SC II 4639.40 75.58 79.73 2424 .96 2303. 13 663.54 3282. 59 5946590 .73 562077.72 MWD+IFR-AK-CAZ-SC 4734.38 75.90 80.46 2448 .36 2326. 53 679.38 3373. 27 5946607 .27 562168.27 MWD+IFR-AK-CAZ-SC I 4829.35 76.72 81.41 2470 .83 2349. 00 693.91 3464. 39 5946622 .52 562259.26 MWD+IFR-AK-CAZ-SC I 4924.42 76.72 80.39 2492 .67 2370. 84 708.55 3555. 75 5946637 .86 562350.50 MWD+IFR-AK-CAZ-SC 5019.94 76.98 80.08 2514. 40 2392. 57 724.32 3647. 42 5946654 .35 562442.03 MWD+IFR-AK-CAZ-SC li 5115.49 77.36 78.85 2535. 62 2413. 79 741.36 3739. 01 5946672 .10 562533.47 MWD+IFR-AK-CAZ-SC ' 5210.67 76.74 79.49 2556 .95 2435. 12 758.79 3830. 11 5946690 .24 562624.43 MWD+IFR-AK-CAZ-SC i 5305.42 76.60 80.23 2578 .80 2456. 97 775.02 3920. 87 5946707 .18 562715.05 MWD+IFR-AK-CAZ-SC ', 5400.49 76.99 81.08 2600 .52 2478. 69 790.05 4012. 20 5946722 .92 562806.25 MWD+IFR-AK-CAZ-SC ~ 5489.21 76.73 81.52 2620 .68 2498. 85 803.12 4097. 60 5946736 .65 562891.54 MWD+IFR-AK-CAZ-SC 5589.42 76.86 82.02 2643 .58 2521. 75 817.08 4194. 15 5946751 .37 562987.97 MWD+IFR-AK-CAZ-SC 5683.25 78.19 83.98 2663 .85 2542. 02 828.24 4285. 08 5946763 .24 563078.80 MWD+IFR-AK-CAZ-SC 5779.37 78.50 83.44 2683. 26 2561. 43 838.55 4378. 65 5946774 .28 563172.28 MWD+IFR-AK-CAZ-SC 5875.73 78.44 82.02 2702. 53 2580. 70 850.50 4472. 30 5946786 .96 563265.83 MWD+IFR-AK-CAZ-SC 5970.65 77.81 80.80 2722 .06 2600. 23 864.37 4564. 15 5946801 .54 563357.55 MWD+IFR-AK-CAZ-SC ~ 6066.56 77.74 80.38 2742 .37 2620. 54 879.70 4656. 62 5946817 .59 563449.89 MWD+IFR-AK-CAZ-SC I 6158.84 77.23 79.12 2762 .36 2640. 53 895.73 4745. 27 5946834 .31 563538.41 MWD+IFR-AK-CAZ-SC ~ 6256.37 78.18 79.05 2783 .13 2661. 30 913.77 4838. 84 5946853 .08 563631.82 MWD+IFR-AK-CAZ-SC 6352.75 78.00 77.97 2803 .02 2681. 19 932.56 4931. 25 5946872 .59 563724.08 MWD+IFR-AK-CAZ-SC ~, 6447.69 78.51 78.41 2822 .35 2700. 52 951.58 5022. 24 5946892 .32 563814.90 MWD+IFR-AK-CAZ-SC 6542.05 78.37 77.55 2841 .26 2719. 43 970.83 5112. 65 5946912 .27 563905.16 MWD+IFR-AK-CAZ-SC 6638.20 77.74 77.51 2861. 16 2739. 33 991.15 5204. 50 5946933 .30 563996.83 MWD+IFR-AK-CAZ-SC ~ 6732.51 77.23 75.61 2881 .60 2759. 77 1012.54 5294. 05 5946955 .39 564086.20 MWD+IFR-AK-CAZ-SC i 6828.14 77.56 74.97 2902 .47 2780. 64 1036.24 5384. 31 5946979 .79 564176.27 MWD+IFR-AK-CAZ-SC 6922.89 77.42 75.14 2922 .99 2801. 16 1060.10 5473. 68 5947004 .34 564265.44 MWD+IFR-AK-CAZ-SC 7017.56 77.50 75.80 2943 .55 2821. 72 1083.28 5563. 14 5947028 .22 564354.71 MWD+IFR-AK-CAZ-SC 7113.53 77.62 75.81 2964 .22 2842. 39 1106.26 5653. 99 5947051 .91 564445.37 MWD+IFR-AK-CAZ-SC ~ 7208.03 77.75 76.10 2984 .38 2862. 55 1128.67 5743. 56 5947075 .01 564534.75 MWD+IFR-AK-CAZ-SC 7302.79 77.42 75.74 3004 .75 2882. 92 1151.18 5833. 32 5947098 .22 564624.33 MWD+IFR-AK-CAZ-SC 7399.70 77.74 76.60 3025 .59 2903. 76 1173.80 5925. 22 5947121 .56 564716.03 MWD+IFR-AK-CAZ-SC 7493.39 77.43 77.23 3045 .73 2923. 90 1194.52 6014. 34 5947142 .97 564804.98 MWD+IFR-AK-CAZ-SC 7590.27 77.04 79.88 3067 .14 2945. 31 1213.27 6106. 94 5947162 .44 564897.42 MWD+IFR-AK-CAZ-SC Halliburton Company S Survey Report ('umpany: ConocoPhillipsAlaskalnc. Date: 8/16/2006 __ Time: 10:15:55 Pagc: Field: Kuparu k River Unit Co-ordinatc (NE) Reference: Well: 1J-10 9, True North Site: Ku paru k 1J Pad Vertical (TVD)Reference: 1J-109P61 : 121 .8 ~~cll: 1J -109 Section (V'S) Itcferenee: Well (O.OON,O.OOE,180AOAzi) ~~cllpaUr 1J -109PB1 Sun~e y Calculation Method: Minimum C urvature Db: Oracle tiUl'Vl'V NtTI Tnc l` ~zim ~h~~ll Sys Il~ ll S';S F','~~' Maps' ~lapE Tuul ', ft deg deg ft ft ft ft ft ft i 2765.74 77 .81 78.16 1999. 45 1877 .62 298 .80 1495. 45 5946212. 08 560293. 66 MWD+IFR-AK-CAZ-SC 2860.78 73 .75 78.87 2022. 79 1900 .96 317 .15 1585. 71 5946231. 13 560383. 76 MWD+IFR-AK-CAZ-SC 2958.30 76 .07 79.51 2048. 17 1926 .34 334 .80 1678. 19 5946249. 51 560476. 09 MWD+IFR-AK-CAZ-SC 3053.40 79 .20 78.32 2068. 54 1946 .71 352 .67 1769. 34 5946268. 08 560567. 09 MWD+IFR-AK-CAZ-SC 3148.65 78 .87 76.47 2086. 66 1964 .83 373 .07 1860. 59 5946289. 19 560658. 17 MWD+IFR-AK-CAZ-SC 3243.93 78 .25 76.89 2105. 55 1983 .72 394 .59 1951. 46 5946311. 42 560748. 87 MWD+IFR-AK-CAZ-SC 3339.52 76 .56 77.79 2126. 40 2004 .57 415 .04 2042. 48 5946332. 57 560839. 71 MWD+IFR-AK-CAZ-SC 3434.70 3528.60 75 77 .74 .13 78.79 78.85 2149. 2171. 18 21 2027 2049 .35 .38 433 451 .79 .49 2132. 2222. 97 51 5946352. 5946370. 03 43 560930. 561019. 04 44 j MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC 3621.99 74 .49 79.74 2194. 10 2072 .27 468 .31 2311. 47 5946387. 94 561108. 25 MWD+IFR-AK-CAZ-SC i 3718.48 78 .73 79.55 2216. 44 2094 .61 485 .18 2403. 79 5946405. 53 561200. 42 MWD+IFR-AK-CAZ-SC 3813.01 76 .72 79.32 2236. 53 2114 .70 502 .12 2494. 58 5946423. 17 561291. 08 MWD+IFR-AK-CAZ-SC 3908.53 78 .26 79.98 2257. 22 2135 .39 518 .87 2586. 32 5946440. 64 561382. 67 MWD+IFR-AK-CAZ-SC 4006.02 77 .78 77.74 2277. 46 2155 .63 537 .29 2679. 88 5946459. 79 561476. 08 MWD+IFR-AK-CAZ-SC 4098.46 79 .02 77.39 2296. 05 2174 .22 556 .79 2768. 31 5946479. 97 561564. 34 MWD+IFR-AK-CAZ-SC 4163.78 77 .36 77.37 2309. 42 2187 .59 570 .76 2830. 70 5946494. 43 561626. 61 ~ MWD+IFR-AK-CAZ-SC 4255.64 75 .58 77.33 2330. 91 2209 .08 590 .31 2917. 84 5946514. 66 561713. 59 MWD+IFR-AK-CAZ-SC ~ 4351.73 76 .48 78.14 2354. 11 2232 .28 610 .12 3008. 95 5946535. 18 561804. 54 MWD+IFR-AK-CAZ-SC 4448.51 75 .47. 79.25 2377. 56 2255 .73 628 .53 3101. 02 5946554. 31 561896. 45 MWD+IFR-AK-CAZ-SC 4543.66 75 .72 78.68 2401. 23 2279 .40 646 .17 3191. 48 5946572. 65 561986. 76 MWD+IFR-AK-CAZ-SC 4639.40 75 .58 79.73 2424. 96 2303 .13 663 .54 3282. 59 5946590. 73 562077. 72 MWD+IFR-AK-CAZ-SC 4734.38 75 .90 80.46 2448. 36 2326 .53 679 .38 3373. 27 5946607. 27 562168. 27 MWD+IFR-AK-CAZ-SC 4829.35 76 .72 81.41 2470. 83 2349 .00 693 .91 3464. 39 5946622. 52 562259. 26 MWD+IFR-AK-CAZ-SC i 4924.42 76 .72 80.39 2492. 67 2370 .84 708 .55 3555. 75 5946637. 86 562350. 50 MWD+IFR-AK-CAZ-SC I 5019.94 76 .98 80.08 2514. 40 2392 .57 724 .32 3647. 42 5946654. 35 562442 .03 MWD+IFR-AK-CAZ-SC 5115.49 77 .36 78.85 2535. 62 2413 .79 741 .36 3739. 01 5946672. 10 562533. 47 MWD+IFR-AK-CAZ-SC ', 5210.67 76 .74 79.49 2556. 95 2435 .12 758 .79 3830. 11 5946690. 24 562624. 43 MWD+IFR-AK-CAZ-SC 5305.42 76 .60 80.23 2578. 80 2456 .97 775 .02 3920. 87 5946707. 18 562715. 05 MWD+IFR-AK-CAZ-SC I 5400.49 76 .99 81.08 2600. 52 2478 .69 790 .05 4012. 20 5946722. 92 562806. 25 MWD+IFR-AK-CAZ-SC 5489.21 76 .73 81.52 2620. 68 2498 .85 803 .12 4097. 60 5946736. 65 562891. 54 MWD+IFR-AK-CAZ-SC 5589.42 76 .86 82.02 2643. 58 2521 .75 817 .08 4194. 15 5946751. 37 562987. 97 MWD+IFR-AK-CAZ-SC 5683.25 78 .19 83.98 2663. 85 2542 .02 828. 24 4285. 08 5946763. 24 563078. 80 MWD+IFR-AK-CAZ-SC 5779.37 78 .50 83.44 2683. 26 2561 .43 838. 55 4378. 65 5946774. 28 563172. 28 MWD+IFR-AK-CAZ-SC 5875.73 78 .44 82.02 2702. 53 2580 .70 850 .50 4472. 30 5946786. 96 563265. 83 MWD+IFR-AK-CAZ-SC 5970.65 77 .81 80.80 2722. 06 2600 .23 864 .37 4564. 15 5946801. 54 563357. 55 MWD+IFR-AK-CAZ-SC 6066.56 77 .74 80.38 2742. 37 2620 .54 879 .70 4656. 62 5946817. 59 563449. 89 MWD+IFR-AK-CAZ-SC 'I 6158.84 77 .23 79.12 2762. 36 2640 .53 895 .73 4745. 27 5946834. 31 563538. 41 MWD+IFR-AK-CAZ-SC ', 6256.37 78 .18 79.05 2783. 13 2661 .30 913 .77 4838. 84 5946853. 08 563631. 82 MWD+IFR-AK-CAZ-SC 6352.75 78 .00 77.97 2803. 02 2681 .19 932 .56 4931. 25 5946872. 59 563724. 08 MWD+IFR-AK-CAZ-SC 6447.69 78 .51 78.41 2822. 35 2700 .52 951. 58 5022. 24 5946892. 32 563814. 90 MWD+IFR-AK-CAZ-SC 6542.05 78 .37 77.55 2841. 26 2719 .43 970. 83 5112. 65 5946912. 27 563905. 16 MWD+IFR-AK-CAZ-SC 6638.20 77 .74 77.51 2861. 16 2739 .33 991. 15 5204. 50 5946933. 30 563996. 83 t MWD+IFR-AK-CAZ-SC 6732.51 77 .23 75.61 2881. 60 2759 .77 1012 .54 5294. 05 5946955. 39 564086. 20 MWD+IFR-AK-CAZ-SC 6828.14 77 .56 74.97 2902. 47 2780 .64 1036 .24 5384. 31 5946979. 79 564176. 27 MWD+IFR-AK-CAZ-SC I ~ 6922.89 77 .42 75.14 2922. 99 2801 .16 1060 .10 5473. 68 5947004. 34 564265. 44 MWD+IFR-AK-CAZ-SC ~' ! 7017.56 77 .50 75.80 2943. 55 2821 .72 1083 .28 5563. 14 5947028. 22 564354. 71 MWD+IFR-AK-CAZ-SC 7113.53 77 .62 75.81 2964. 22 2842 .39 1106. 26 5653. 99 5947051. 91 564445. 37 MWD+IFR-AK-CAZ-SC 7208.03 77 .75 76.10 2984. 38 2862 .55 1128. 67 5743. 56 5947075. 01 564534. 75 MWD+IFR-AK-CAZ-SC j ~ 7302.79 77 .42 75.74 3004. 75 2882 .92 1151. 18 5833. 32 5947098. 22 564624. 33 MWD+IFR-AK-CAZ-SC ! 7399.70 77 .74 76.60 3025. 59 2903 .76 1173. 80 5925. 22 5947121. 56 564716. 03 MWD+IFR-AK-CAZ-SC 7493.39 77 .43 77.23 3045. 73 2923 .90 1194. 52 6014. 34 5947142. 97 564804. 98 MWD+IFR-AK-CAZ-SC 7590.27 77 .04 79.88 3067. 14 2945 .31 1213 .27 6106_ 94 5947162. 44 564897. 42 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Comp:~n.: ConocoPhillipsAlaska Inc. __ Date: 8/16/2006 Timc: 10:15'55 Page: 3 Field: Ku paruk-,Fiver Uni t Co-ordinate(NE)Reference: Well: 1J-109, True North Site: Ku paruk 1J Pad Vertical (TVD) Re ference: 1J-109P61: 121 .8 ~Ve~l: 1J- 109 Sectio n (VS ) Reference: Well (O.OON,O.OOE,180.OOAzi) ~~'eltpath: 1J -1C9P81 Survey Calculation Method: Mininaurn Curvat ure llb: Oracle Survey Mil Incl Azim TVT) C_vs IFD Y/S i./W ~1apN MapF. Tool ft deg deg ft ft ft' ft ft ft 7685.84 77.24 77. 06 3088.42 2966 .59 1231. 89 6198 .22 5947181. 77 564988.55 MWD+IFR-AK-CAZ-SC 7779.08 76.16 79. 17 3109.87 2988 .04 1250. 58 6287 .01 5947201. 15 565077.18 MWD+IFR-AK-CAZ-SC 7875.82 74.81 79. 24 3134.12 3012 .29 1268. 12 6379 .00 5947219. 41 565169.02 MWD+IFR-AK-CAZ-SC 7979.07 76.12 82. 53 3160.04 3038. 21 1283. 94 6477 .67 5947236. 00 565267.55 MWD+IFR-AK-CAZ-SC I 8072.07 76.69 84. 90 3181.90 3060 .07 1293. 83 6567 .51 5947246. 59 565357.31 MWD+IFR-AK-CAZ-SC ~ 8167.52 75.72 85. 83 3204.66 3082 .83 1301. 33 6659 .90 5947254. 81 565449.63 MWD+IFR-AK-CAZ-SC 8263.21 75.51 87. 40 3228.43 3106 .60 1306. 80 6752 .43 5947261. 00 565542.10 MWD+IFR-AK-CAZ-SC 8357.67 75.77 89. 27 3251.86 3130 .03 1309. 46 6843 .89 5947264. 37 565633.53 MWD+IFR-AK-CAZ-SC 8452.05 75.02 92. 24 3275.66 3153 .83 1308. 26 6935 .20 5947263. 89 565724.84 MWD+IFR-AK-CAZ-SC 8548.29 76.15 95. 20 3299.63 3177. 80 1302. 20 7028 .20 5947258. 56 565817.88 MWD+IFR-AK-CAZ-SC 8639.23 77.34 98. 22 3320.48 3198. 65 1291. 86 7116 .10 5947248. 90 565905.84 MWD+IFR-AK-CAZ-SC 8739.98 76.91 102. 42 3342.94 3221. 11 1274. 27 7212 .71 5947232. 07 566002.57 MWD+IFR-AK-CAZ-SC 8835.59 76.93 104. 36 3364.58 3242. 75 1252. 70 7303 .30 5947211. 21 566093.32 MWD+IFR-AK-CAZ-SC 8930.15 74.52 107. 50 3387.90 3266 .07 1227. 57 7391 .41 5947186. 77 566181.61 MWD+IFR-AK-CAZ-SC 9024.86 76.07 111. 86 3411.95 3290 .12 1196. 72 7477 .63 5947156. 60 566268.07 MWD+IFR-AK-CAZ-SC I 9118.89 73.29 113. 01 3436.80 3314 .97 1162. 12 7561 .45 5947122. 65 566352.15 MWD+IFR-AK-CAZ-SC I 9214.65 73.48 115. 29 3464.18 3342 .35 1124. 58 7645 .17 5947085. 77 566436.15 MWD+IFR-AK-CAZ-SC 9309.40 73.60 117. 72 3491.03 3369. 20 1084. 03 7726 .48 5947045. 86 566517.77 MWD+IFR-AK-CAZ-SC i 9403.10 i 74.80 121. 98 3516.55 3394. 72 1039. 16 7804 .65 5947001. 61 566596.28 MWD+IFR-AK-CAZ-SC 9498.28 77.53 126. 00 3539.32 3417. 49 987. 49 7881 .25 5946950. 55 566673.27 MWD+IFR-AK-CAZ-SC 9592.32 77.66 129. 31 3559.53 3437 .70 931. 39 7953 .95 5946895. 02 566746.40 MWD+IFR-AK-CAZ-SC 9690.83 81.02 133. 96 3577.76 3455 .93 867. 09 8026 .26 5946831. 29 566819.20 MWD+IFR-AK-CAZ-SC i 9785.68 79.66 138. 76 3593.68 3471. 85 799. 44 8090 .77 5946764. 16 566884.23 MWD+IFR-AK-CAZ-SC 9878.90 78.09 142. 17 3611.67 3489 .84 728. 92 8148 .99 5946694. 10 566943.00 MWD+IFR-AK-CAZ-SC 9974.53 ~ 79.70 143. 99 3630.09 3508. 26 653. 90 8205 .35 5946619. 53 566999.94 MWD+IFR-AK-CAZ-SC 10070.12 80.97 149. 55 3646.15 3524. 32 575. 11 8256 .96 5946541. 15 567052.16 MWD+IFR-AK-CAZ-SC 10164.62 81.15 155. 03 3660.85 3539. 02 492. 49 8300 .35 5946458. 88 567096.19 MWD+IFR-AK-CAZ-SC 10244.61 80.09 157. 94 3673.89 3552. 06 420. 14 8331 .84 5946386. 78 567128.23 MWD+IFR-AK-CAZ-SC 10339.57 80.20 160. 60 3690.15 3568. 32 332. 64 8364 .95 5946299. 56 567162.03 MWD+IFR-AK-CAZ-SC 10434.48 82.97 166. 37 3704.04 3582. 21 242. 67 8391 .61 5946209. 81 567189.38 MWD+IFR-AK-CAZ-SC 10531.92 84.00 171. 54 3715.11 3593. 28 147. 69 8410 .15 5946114. 98 567208.66 MWD+IFR-AK-CAZ-SC 10626.17 83.55 175. 84 3725.33 3603 .50 54. 58 8420 .44 5946021. 97 567219.68 MWD+IFR-AK-CAZ-SC 10719.28 81.95 176. 03 3737.08 3615. 25 -37. 55 8426. 99 5945929. 90 567226.95 MWD+IFR-AK-CAZ-SC i 10815.27 81.10 177. 64 3751.23 3629. 40 -132. 34 8432 .23 5945835. 16 567232.93 MWD+IFR-AK-CAZ-SC ~ 10911.10 80.60 178. 85 3766.47 3644. 64 -226. 90 8435 .13 5945740. 63 567236.57 MWD+IFR-AK-CAZ-SC 10959.45 79.99 178. 89 3774.62 3652. 79 -274. 55 8436 .07 5945693. 00 567237.88 MWD+IFR-AK-CAZ-SC i 11004.00 79.99 178. 89 3782.36 3660. 53 -318. 42 8436 .92 5945649. 14 567239.07 PROJECTED to TD ConocoPhilii s ~ Time Lo Summa w~,~„~.., ~~~~' ~.~,n~ 9 rY Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T COM 07/06/2006 12:00 14:00 2.00 0 0 MIRU MOVE SKID P PJSM. Skid rig floor from drilling -----~ position to moving position. Tie back pipe in derrick w/ tugger. Remove communication line. Disconnect air line under floor. 14:00 14:30 0.50 0 0 MIRU MOVE OTHR P Raise back support feet f/ cantilever. 14:30 16:00 1.50 0 0 MIRU MOVE MOB P Move pit module 455' (80 past well 109 osition .Set down. 16:00 18:00 2.00 0 0 MIRU MOVE MOB P Move drilling sub off of hole. Pickup mats and herculite. Clean up around cellar of 1 J-127. 18:00 20:30 2.50 0 0 MIRU MOVE OTHR P Set herculite. Move and set matting boards. 20:30 00:00 3.50 0 0 MIRU MOVE PSIT P Move drilling sub. Position rig over hole. Well to well move in line, 375' move. Note: Clearance next to well 1J-3 is 2-1/2" to 6". Drillsite operator was onsite while ositionin over well. 07/07/2006 00:00 02:00 2.00 0 0 MIRU MOVE SKID P Skid rig floor from moving position to drilling position. Start rigging up lines to rig floor. Note: Rig moved w/ 24 stands of Weatherford d in derrick. 02:00 04:00 2.00 0 0 MIRU MOVE PSIT P Move pits and set pits in position by drilling module. Start rigging up lines between its and drillin module. 04:00 06:00 2.00 0 0 MIRU MOVE RURD P Continue rigging up lines, start bermin u the ri . 06:00 08:30 2.50 0 0 MIRU MOVE RURD P Continue rigging up. Connect beaver slide to ri . 08:30 12:00 3.50 0 0 MIRU MOVE RURD P Set rockwasher. Rig up riser on top of annular. Berming rig. Note: Rig on Hi-line power @ 1000 hrs. Note: Rig accepted @ 1200 hrs on 7/7/2006. 12:00 15:00 3.00 0 0 MIRU WELCT NUND P Install turnbuckles on riser. Orient starting head adapter f/ diverter line to exit cellar wall by beaaver slide. Install master bushings in rotary table. Install track f/ iron roughneck. Clean and clear ri floor. 15:00 15:30 0.50 0 MIRU WELCT SFTY P PJSM on NU Diverter system. 15:30 18:00 2.50 0 0 MIRU WELCT NUND P RU diverter line. PU 5" equipment to floor. Load i e shed w/ BHA #1. s ~ ~ ~__~ ...._~ ~® eme®~~ ~ ~ ® .._..._ ~ € +~~ J, ~ y,~ "~ I L__~ ~ ~ ~ ~ ._._ ~. ~e_ ~m. Time Logs Date From To Dur th E. De th Phase Code Subcode T SUM 07/07/2006 18:00 21:00 3.00 0 0 MIRU WELCT NUND P Continue Picking up subs for BHA #1, pump up pressure sensors, ready dog collar clamps, install 5" elevators. RU tongs f/ BHA. Make sure proper bell guide is in place and correct dies f/ grabbers are installed in TOP Drive. Start conditioning mud f/ spud. Double check all mud lines. Install (2) 3" valves on starting head adapter in cellar. Installed 2" plug in starting head in cellar. Finish working on diverter line. 21:00 00:00 3.00 0 0 MIRU DRILL OTHR P Start loading pipe shed w/ 156 joints(52 stands) of Weatherford 5" dp. Strap and tally dp, strap and tally 20 joints of Weatherford 5" HWDP f/ BHA. 07/08/2006 00:00 00:30 0.50 0 0 MIRU WELCT SFTY P PJSM on picking up 5" dp. Discussed shallow gas diverter drill and actual. Talked about roles and responsibility of each crew member. 00:30 05:30 5.00 0 0 MIRU DRILL PULD P PU/MU/ stand back in derrick Weatherford 5" dp. 156 joints (52 stands). Drifted w/ 2.85" plastic drift while ickin u . 05:30 08:30 3.00 0 0 MIRU DRILL PULD P PU/MU/ stand back in derrick Weatherford 5" HWDP from pipe shed. Drifted w/ 2.85" plastic drift. Picked up total of 20 'oints + 'ars = 7 stands 08:30 09:30 1.00 0 0 MIRU WELCT BOPE P Begin function test of diverter system. AOGCC rep Jeff Jones waived witness of test. Time of 25 sec for bag to close. Had equip failure on hydraulic fittin on knife valve. Sto ed test. 09:30 10:30 1.00 0 0 MIRU RIGMN RGRP T Clean up spill. Refill Accumulator hyd tank. Replace hyd fitting on knife valve. RUG roe ui ment. 10:30 11:00 0.50 0 0 MIRU WELCT BOPE P Begin function test all over. Accumulator test: Manifold press 1600 psi. 200 psi build up in 25 seconds. Total time for system build up = 2min 24 seconds. 11:00 11:15 0.25 0 0 MIRU WELCT OTHR P Rack back stand of 5" HWDP used to test. 11:15 11:30 0.25 0 0 SURFA DRILL SFTY P PJSM on picking up BHA #1. 11:30 12:00 0.50 0 0 SURFA DRILL OTHR P Clear floor, PU lifting sub from beaver slide. Tie back ro tools. 12:00 14:30 2.50 0 0 SURFA DRILL PULD P PU BHA #1:16" bit,( Hughes MX-1), 8" Sperrydrill lobe4/5 5,3 stage mtr, 12-1/2" integral blade stabilizer, nm press drop sub, 8" MWD directional, nm float sub, nm UBHO, 7-5/8" nm flex collar. Oriented MWD w/ mtr, ad'usted UBHO. ~ a ~ _ .~ ee~ ~a~ ~ ~~" i;'3 ~_ ~ m ~ ! . ~, ~ ~~ ...~.~.. ~.._~. _~ ~. _.~ Time Los Date From To Dur th E. De th Phase Code Subcod~ ~UM 07/08/2006 14:30 16:00 1.50 0 0 SURFA WELCT BOPE P Tag bottom @ 107'. Fill hole and check f/ leaks while testing alarms. 40 bbls to fill hole. Flow indicator working properly. Troubleshooting TOTCO system f/ reason no mud volume/ pit level indicator. 16:00 18:00 2.00 0 0 SURFA RIGMN RGRP T Trouble shooting TOTCO system. Install manual pit level indicators in pit # 4. Cleaning oil base mud f/wind walls. Parts comin f/ TOTCO in Anch. 18:00 20:30 2.50 0 0 SURFA RIGMN RGRP T Trouble shooting TOTCO system. Electricians working w/ TOTCO rep in Anch to try to fix monitoring system. Informed that we needed a TOTCO rep f/ ANCH to further troubleshoot/ fix system @ 2030 hrs. Working on cleaning rig windwalls and drip pans. Working on manual pit level indicators in its. Turn off S er Sun MWD tool. 20:30 22:00 1.50 0 0 SURFA RIGMN RGRP T Working on cleaning rig windwalls and dri ans. 22:00 22:30 0.50 0 0 SURFA RIGMN RGRP T Stand BHA #1 back. Move 7 stands of 5" HWDP f/ driller's side of derrick to other side. 22:30 00:00 1.50 0 0 SURFA RIGMN RGRP T Loading pipe shed w/ Weatherford 4" d. 07/09/2006 00:00 03:00 3.00 0 0 SURFA RIGMN RGRP T Waiting on TOTCO rep's to arrive f/ Anch to fix PVT system. Loading pipe shed w/ Weatherford 4" dp. Strap and tally 195 joints. Cleaning windwalls on ri floor. 03:00 04:00 1.00 0 0 SURFA RIGMN RGRP T Waiting on TOTCO rep's to arrive f/ Anchorage to fix PVT system. Con't cleanin windwalls and rest of ri . 04:00 04:30 0.50 0 0 SURFA RIGMN RGRP T TOTCO rep's arrived to fix PVT system. PJSM on changing elevators f/ 5" to 4" for picking up 4" dp. RU to pick up 4" drillpipe f/ pipe shed. Adjust crown-o-matic. Totco system powered u and o erational 0430 hrs. 04:30 05:30 1.00 0 0 SURFA RIGMN RGRP T TOTCO program digital board f/ DAQ, calibrate PVT, clean gas detector, move fluid around to check G/L, perform system checks. PU/MU 33 joints (11 stands) of Weatherford 4" dp. Rack DP on driller's side. Drift dp w/ 2.34" rabbit. Torque 4" dp to 22000 ft Ib for ue. 05:30 06:00 0.50 0 0 SURFA RIGMN RGRP T Change elevators f/ 4" to 5". UD 4" handling equipment. Clear rig floor. Remove mousehole f/ rota table. 06:00 06:30 0.50 0 0 SURFA DRILL PULD P PU BHA #1 which was stood back in derrick. 06:30 07:00 0.50 0 0 SURFA DRILL OTHR P Sperry Sun upload MWD tool. 07:00 07:30 0.50 0 107 SURFA DRILL CIRC P Fill hole. RIH w/ BHA #1. ~. ® _ ~ ~ _ .~® ®.-_ ~ a .~ _ Time L~ Date From To Dur th E. De th Phase Code Subcode T M 07/09/2006 07:30 08:15 0.75 107 122 SURFA DRILL OTHR P Circulate and test lines to 3000 psi. Then clean out f/ 107' to 122'. Pumping 500 gpm w/ 830 psi. Torque 3k, rotate 30 r m. Note: re air leak on flowline. 08:15 12:00 3.75 122 217 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ ~~ 1.83 deg bend from 122' to 217' (95') (TVD = 217'). ART = .19 hrs, AST = 1.39 hrs. Total hrs on bit = 1.58 hrs., Total hrs on jars = 20.78 hrs, 5-20k WOB, 30-40 rpm's, 130-160 mtr rpm, 500-618 gpm w/ 9.4-9.5 ppg MW, on bottom press 1500 psi, off bottom press 1380 psi, on bottom torque 6-8k ft/Ib, off bottom torque 4k ft/ Ib, PU wt 95-105k, SO wt 95-108k, Rot wt 100-108k. Note: KOP @ 140'. Running Sperry Sun G ro's to 600'. °r-' 12:00 16:45 4.75 217 538 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.83 deg bend from 217' to 538' (321') (TVD = 533'). ART = .90 hrs, AST = 1.80 hrs. Total hrs on bit = 4.28 hrs., Total hrs on jars = 23.48 hrs, 5-20k WOB, 0-40 rpm's, 160-164 mtr rpm, 614-630 gpm w/ 9.4-9.5 ppg MW, on bottom press 1500-1550 psi, off bottom press 1380-1340 psi, on bottom torque 3-8k ft/Ib, off bottom torque 3-5k ft/ Ib, PU wt 95-105k, SO wt 95-108k, Rot wt 100-108k. Note: Sperry Sun Gyro survey's on connections. 16:45 17:15 0.50 538 538 SURFA DRILL CIRC P Circ and conditiion hole @ 538'. Pum in 617 m w/ 1600 si. 17:15 18:00 0.75 538 615 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.83 deg bend from 538' to 615' (77') (TVD = 612'). ART = .41 hrs, AST = .14 hrs. Total hrs on bit = 4.83 hrs., Total hrs on jars = 24.03 hrs, 15-20k WOB, 40 rpm's, 170 mtr rpm, 654 gpm w/ 9.4 ppg MW, on bottom press 1720 psi, off bottom press 1620 psi, on bottom torque 6-7k ft/Ib, off bottom torque 4k ft/ Ib, PU wt 110k, SO wt 110k, Rot wt 112k. Note: S er Sun ro's ran to 600'. ~~_ .~ ~~~~~~'3 Time Los _ Date From To Dur th E. De t h Phase Code Subcode T ~ M 07/09/2006 18:00 23:15 5.25 615 _ 978 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.83 deg bend from 615' to 978' (363') (TVD = 950'). ART = 1.57 hrs, AST = 1.2 hrs. Total hrs on bit = 7.6 hrs., Total hrs on jars = 26.8 hrs, 20-25k WOB, 40-50 rpm's, 167-170 mtr rpm, 643-654 gpm w/ 9.4-9.5 ppg MW, on bottom press 1720-1940 psi, off bottom press 1620-1700 psi, on bottom torque 4-5k ft/Ib, off bottom torque 3-4k ft/ Ib, PU wt 110-122k, SO wt 110-116k, Rot wt 112-122k. 23:15 00:00 0.75 978 978 SURFA RIGMN RGRP T Auger between pits and rockwasher developed problem. Stand back a stand. Recip pipe while working to re air au er. Hole in ood condition. 07/10/2006 00:00 04:00 4.00 978 978 SURFA RIGMN RGRP T Continue repair of short auger piece between its and rockwasher. 04:00 04:45 0.75 978 978 SURFA DRILL CIRC T Circ bottoms up while rotating and picking up only. Circ w/ 651 gpm, 1900 si. Hole in ood sha e. 04:45 06:00 1.25 978 1,084 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.83 deg bend from 978' to 1084' (106') (TVD = 1047'). ART = .62 hrs, AST = .38 hrs. Total hrs on bit = 8.6 hrs., Total hrs on jars = 27.8 hrs, 20-25k WOB, 50 rpm's, 167-170 mtr rpm, 654 gpm w/ 9.4-9.5 ppg MW, on bottom press 1940 psi, off bottom press 1740 psi, on bottom torque 4-5k ft/Ib, off bottom torque 3-4k ft/ Ib, PU wt 125k, SO wt 115k, Rot wt 122k. 06:00 10:45 4.75 1,084 1,482 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.83 deg bend from 1084' to 1482' (398') (TVD = 1378'). ART = 2.01 hrs, AST = 1.45 hrs. Total hrs on bit = 12.06 hrs., Totai hrs on jars = 31.26 hrs, 20-30k WOB, 50 rpm's, 168 mtr rpm, 648 gpm w/ 9.4-9.5 ppg MW, on bottom press 1940-2050 psi, off bottom press 1740-1860 psi, on bottom torque 5-7k ft/Ib, off bottom torque 3-4k ft/ Ib, PU wt 132k, SO wt 120k, Rot wt 128k. Addin water 50 b h. 10:45 12:45 2.00 1,482 1,482 SURFA DRILL REAM P Washing and reaming dogleg @ 1415' to 1482' (1378' TVD). Rotating 50 rpm, um in 648-700 m w/ 2050 si. e~~ . ~ - . -__ _ ~ _ ~® _~e~~_m Time Logs Date From To Dur th E De th Phase Code Subcode T M 07/10/2006 12:45 18:00 5.25 1,482 1,958 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.83 deg bend from 1482' to 1958' (476') (TVD = 1719'). ART = 1.4 hrs, AST = 2.08 hrs. Total hrs on bit = 15.54 hrs., Total hrs on jars =34.74 hrs, 20-25k WOB, 50 rpm's, 138-169 mtr rpm, 530-651 gpm w/ 9.4-9.5 ppg MW, on bottom press 1670-2200 psi, off bottom press 1530-2020 psi, on bottom torque 5-7k ft/Ib, off bottom torque 3-6k ft/ Ib, PU wt 135-138k, SO wt 120k, Rot wt 128-130k. Addin water 50 b h. 18:00 00:00 6.00 1,958 2,339 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.83 deg bend from 1958' to 2339' (381') (TVD = 1904'). ART = 1.26 hrs, AST = 1.3 hrs. Total hrs on bit = 18.1 hrs., Total hrs on jars = 37.3 hrs, 15-25k WOB, 50 rpm's, 166 mtr rpm, 640 gpm w/ 9.6-9.8 ppg MW, on bottom press 2270-2280 psi, off bottom press 1960 psi, on bottom torque 7-9k ft/Ib, off bottom torque 3-5k ft/ Ib, PU wt 142k, SO wt 120k, Rot wt 130-132k. Addin water 50-100 b h. 07/11/2006 00:00 02:15 2.25 2,339 2,528 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.83 deg bend from 2339' to 2528' (189') (TVD = 1949'). ART = 1.11 hrs, AST = .47 hrs. Total hrs on bit = 19.68 hrs., Total hrs on jars = 38.88 hrs, 15-25k WOB, 50 rpm's, 166 mtr rpm, 640 gpm w/ 9.6-9.8 ppg MW, on bottom press 2280 psi, off bottom press 1960 psi, on bottom torque 7-8k ft/Ib, off bottom torque 1-3k ft/ Ib, PU wt 135-138k, SO wt 115-110k, Rot wt 131-129k. Addin water 50-100 b h. 02:15 02:30 0.25 2,528 2,528 SURFA DRILL SFTY P PJSM on backreaming out of hole. 02:30 04:30 2.00 2,528 1,960 SURFA DRILL REAM P Pull one stand f/ 2528' to 2435' w/o pumps.Backream f/ 2435' to 1960'. Pulling speed 10-15 ft per min. Rotating 50 rpm w/ 5-8k ft Ib torque. Pumping 640 gpm w/ 2280 psi. Pumped total of 643 bbls while um in . Bottoms u is 568 bbls. 04:30 05:30 1.00 1,960 1,960 SURFA RIGMN RGRP T Repair check valve on fillup line to conductor in order to fill hole and monitor hole fill. 05:30 06:00 0.50 1,960 1,485 SURFA DRILL TRIP P POOH on elevators f/ 1960' to 1485' @ 0600 hrs. Record PU and SO wt's eve 5 stands. ~~e oaf £~ ~® ~a~m w _ _. ~ . ® ~~ .~ ,, __ ...._-.._~ _.. ....~. ~ ..- ~..... Time Logs Da e From To Dur th E De th Phase Code Subcode T M 07/11/2006 06:00 07:00 1.00 1,485 319 SURFA DRILL TRIP P Continue POOH f/ 1485' to 319'. Record PU and SO wt's every 5 stands. 07:00 09:30 2.50 319 70 SURFA DRILL TRIP P Work BHA from 319' to 70'. 09:30 10:00 0.50 70 70 SURFA DRILL OTHR P Download Sperry Sun MWD. Clean and clear ri floor. 10:00 11:00 1.00 70 0 SURFA DRILL OTHR P Continue POOH break bit, pull float, UD S er motor w/ 1.83 de bend. 11:00 11:30 0.50 0 0 SURFA DRILL OTHR P Clear and clean rig floor while grading bit. 11:30 11:45 0.25 0 0 SURFA DRILL SFTY P Pre job safety meeting on PU BHA #2. 11:45 12:30 0.75 0 135 SURFA DRILL PULD P PU BHA #2: 16" Hughes MX-1 RR1, 8" SperryDrill 4/5-5.3 stage Mtr w/ 1.15 deg bend, then 8" nm pony collar (6'), 12 1/4" IBS, nm x-o, 8" MWD, nm float sub, 2 7-5/8" nm flex dc's, 12:30 13:30 1.00 135 135 SURFA DRILL OTHR P Orient motor w/MWD, install rebuilt float sub, check MWD. 13:30 15:00 1.50 135 821 SURFA DRILL PULD P Break 3 joints 5" Weatherford dp, UD same. PU and replace. Then ran hw f/ derrick. Note: These were overtorqued when encounterin ti ht hole 191'. 15:00 15:30 0.50 821 1,110 SURFA DRILL TRIP P Con't RIH f/ 821' to 1110'. Note: Ghost reamer installed 986' above bit. in 2nd stand of HWDP . 15:30 16:00 0.50 1,110 1,110 SURFA RIGMN SVRG P Service rig. 16:00 17:15 1.25 1,110 2,528 SURFA DRILL TRIP P Continue trip in hole f/ 1110' to 2528' 1949' TVD . 17:15 18:00 0.75 2,528 2,528 SURFA DRILL CIRC P Circulate and condition mud and hole @ 2528'. Circulate @ 428 gpm w/ 1020 psi. Rotate 80 rpm w/ 5-6k ft Ib torque. Increase to 490 gpm w/ 1230 si, 580 m w/ 1500 si. 18:00 19:45 1.75 2,528 2,297 SURFA DRILL REAM P Backream f/ 2528' to 2297' while circulating. Pumping 240 gpm w/ 560 psi. Rotating 50 rpm w/ 3-5k ft Ib torque. Note: Will be adding 580 bbls new spud mud (250-300 vis) to system, about a 50/50 dilution. Only added 380 bbls now. 19:45 20:15 0.50 2,297 2,528 SURFA DRILL TRIP P Finish RIH f/ 2297' to 2528'. (2-1/2 stands . ~. ®..®e__ ®~ a _._~~ ®® ~~~~-~ ~~~_.®~ _~ ~%-~,n~~ cat Time Logs Da e From To _ Dur th E. De th Phase Code Subcode T _ M _ 07/11/2006 20:15 21:30 1.25 2,528 2,630 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 2528' to 2630' (102') (TVD = 1971'). ART = .61 hrs, AST = .19 hrs. Total hrs this run = .8 hrs. Total hrs on bit = 20.48 hrs., Total hrs on jars = 39.68 hrs, 10-20k WOB, 80 rpm's, 166 mtr rpm, 640 gpm w/ 9.2 ppg MW, on bottom press 1920 psi, off bottom press 1860 psi, on bottom torque 7-9k ft/Ib, off bottom torque 3-5k ft/ Ib, PU wt 135k, SO wt 110k, Rot wt 125k. Addin water 100 b h. 21:30 23:15 1.75 2,630 2,630 SURFA DRILL CIRC NP Circulate and condition thick mud. Set a stand back. Pumping 220 gpm w/ 480 psi. Rotate 50 rpm. Backreaming and continue mud swap due to hi vis mud @ shakers blinding screens. Adding water to lower vis and even out mud to avoid further dela s. 23:15 00:00 0.75 2,630 2,688 SURFA DRILL DDRL P Directional Drili 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 2630' to 2688' (58') (TVD = 1983'). ART = .38 hrs, AST = .16 hrs. Total hrs this run = 1.34 hrs. Total hrs on bit = 21.02 hrs., Total hrs on jars = 40.22 hrs, 5-20k WOB, 80 rpm's, 166 mtr rpm, 640 gpm w/ 9.2 ppg MW, on bottom press 1890 psi, off bottom press 1770 psi, on bottom torque 7-9k ft/Ib, off bottom torque 3-5k ft/ Ib, PU wt 135k, SO wt 110k, Rot wt 122k. Addin water 100 b h. 07/12/2006 00:00 00:45 0.75 2,688 2,725 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 2688' to 2725' (37') (TVD = 1991'). ART = .31 hrs, AST = .0.0 hrs. Total hrs this run = 1.65 hrs. Total hrs on bit = 21.64 hrs., Total hrs on jars = 40.53 hrs, 5-20k WOB, 80 rpm's, 166 mtr rpm, 640 gpm w/ 9.2 ppg MW, on bottom press 1890 psi, off bottom press 1770 psi, on bottom torque 7-9k ft/Ib, off bottom torque 3-5k ft/ Ib, PU wt 135k, SO wt 110k, Rot wt 122k. Addin water 75 b h. 00:45 01:45 1.00 2,725 2,725 SURFA DRILL REAM P Wash and ream f/ 2728' to 2635' twice to decrease hole angle f/ 78.45 deg. Prior survey was 77.49 deg. No difference was noted. ~ ~ e~ , Time Lo s Date From To Dur th E. De th Phase Code Subcode T M 07/12/2006 01:45 04:45 3.00 2,725 2,931 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 2725' to 2931' (206') (TVD = 2041'). ART = 1.0 hrs, AST = .58 hrs. Total hrs this run = 3.23 hrs. Total hrs on bit = 23.22 hrs., Total hrs on jars = 42.11 hrs, 15-25k WOB, 80 rpm's, 166-209 mtr rpm, 640-803 gpm w/ 9.3 ppg MW, on bottom press 1890-2280 psi, off bottom press 1770-2110 psi, on bottom torque 8-10k ft/Ib, off bottom torque 3-8k ft/ Ib, PU wt 135-150k, SO wt 110-100k, Rot wt 122-130k. Adding water @ 75 bph Note: While drilling @ 2820'-2850' had t shak Thi h f il/t a s ow o o ar a ers. s blinded off shakers as we proceeded ahead. Dropped 4 deg of angle in hole. At depth of 2765.74' inc was 77.81 deg, depth of 2860.78' hole angle was 73.75 de . 04:45 05:30 0.75 2,931 2,931 SURFA DRILL CIRC T Reciprocate @ reduced pump rate to keep mud on shakers. Sand and oil/tar blindin shakers. 05:30 06:30 1.00 2,931 2,160 SURFA DRILL TRIP T POOH total of 8 stands f/ 2931' to 2160' to circ and clean up hole. Rotate and PU strin onl w/ um son. 06:30 07:45 1.25 2,160 2,160 SURFA DRILL CIRC T Circulate at maximunm rate shakers will handle to circ bottoms up while picking up f/ 2160' to 2065'. Trying to remove tar/oii cuttings f/annulus. Increased rate up to 340 gpm. Circ 4000 strokes total (403 bbl). Adding water @ 75 bph. Note: Electrician working to fix and make operable the Derrick shaker closest to the scat er shakers. 07:45 08:00 0.25 2,160 2,600 SURFA DRILL TRIP T RIH 5 stands f/ 2160' to 2600'. 08:00 09:15 1.25 2,600 2,600 SURFA DRILL CIRC T Circulate and condition mud stagging rate up to what the shakes will handle. Changing shaker screens. Rotate 70 rpm, pumping 246 gpm w/ 430 psi. Pumping 359 gpm w/ 620 psi. Pumped an additional 200 bbls, total of 600 bbls circulated. 09:15 09:30 0.25 2,600 2,931 SURFA DRILL TRIP T RIH 3 more stands f/ 2600' to 2931'. .W.....~ ~~af Time Logs Date From To Dur ~ th E. De th Phase Code Subcode T M 07/12/2006 09:30 12:00 2.50 2,931 3,085 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 2931' to 3085' (154') (ND = 2071'). ART = .67 hrs, AST = 1.15 hrs. Total hrs this run = 5.05 hrs. Total hrs on bit = 24.73 hrs., Total hrs on jars = 43.93 hrs, 15-25k WOB, 80 rpm's, 208-167 mtr rpm, 799-641 gpm w/ 9.3 ppg MW, on bottom press 2280-1720 psi, off bottom press 2110-1620 psi, on bottom torque 8-12k fUlb, off bottom torque 4-8k ft/ Ib, PU wt 150-140k, SO wt 100-105k, Rot wt 130-120k. Addin water 75 b h 12:00 18:00 6.00 3,085 3,443 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w! 1.15 deg bend from 3085' to 3443' (358') (TVD = 2150'). ART = 3.16 hrs, AST = .8 hrs. Total hrs this run = 9.01 hrs. Total hrs on bit = 28.69 hrs., Total hrs on jars = 47.89 hrs, 15-25k WOB, 80 rpm's, 208-167 mtr rpm, 799-641 gpm w/ 9.3 ppg MW, on bottom press 2280-1720 psi, off bottom press 2110-1620 psi, on bottom torque 8-12k ft/Ib, off bottom torque 4-8k ft/ Ib, PU wt 150-140k, SO wt 100-105k, Rot wt 130-120k. Addin water 20 b h 18:00 00:00 6.00 3,443 3,934 SURFA DRILL DDRL P Directional Drill 16" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 3443' to 3934' (491') (TVD = 2261'). ART = 1.71 hrs, AST = 1.5 hrs. Total hrs this run = 12.22 hrs. Total hrs on bit = 31.9 hrs., Total hrs on jars = 51.11 hrs, 0-30k WOB, 80 rpm's, 208-167 mtr rpm, 701-550 gpm w/ 9.3 ppg MW, on bottom press 1950-1520 psi, off bottom press 1790-1280 psi, on bottom torque 8-15k ft/Ib, off bottom torque 6-12k ft/ Ib, PU wt 145-162k, SO wt 105-85k, Rot wt 122-120k. Addin water 40-60 b h '° W___ . a Time Logs Date From To Dur th E. De th Phase Code Subcode T M 07/13/2006 00:00 04:30 4.50 3,934 4,153 SURFA DRILL DDRL P Directional Drill 16" surface hole w! 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 3934' to 4153' (219') (TVD = 22306'). ART = 1.26 hrs, AST = 1.65 hrs. Total hrs this run = 15.13 hrs. Total hrs on bit =34.81 hrs., Total hrs on jars =54.02 hrs, 0-20k WOB, 80 rpm's, 143-208 mtr rpm, 550-800 gpm w/ 9.3 ppg MW, on bottom press 1520-2480 psi, off bottom press 1280-2290 psi, on bottom torque 10-15k ft/Ib, off bottom torque 8-12k ft/ Ib, PU wt 160k, SO wt 95k, Rot wt 122k. Addin water 40-60 b h 04:30 04:45 0.25 4,153 4,153 SURFA DRILL SFTY P PJSM on backreaming out of hole while circ 2+ BU. 04:45 06:00 1.25 4,153 3,965 SURFA DRILL CIRC P Backream out of hole slow f/ 4153' to 3965' (188'). Pulling speed 2.5 to 3.5 ft/min. Pumping 900 gpm w/ 3050 psi. Rotate 90 r m w/ 7-12k ft/ Ib for ue. 06:00 07:15 1.25 3,965 3,870 SURFA DRILL CIRC P Continue backreaming out of hole slow f/ 3965' to 3870' (95'). Pulling speed 2.5 to 3.5 ft/min. Pumping 900 gpm w/ 3050 psi. Rotate 90 rpm w/ 7-12k ft/ Ib torque. Total volume pumped while backreamin was 3125 bbls. 3+ BU 07:15 08:45 1.50 3,870 2,437 SURFA DRILL WPRT P POOH on elevators f/ 3870' to +/-2500'. Monitor well on tri tank. 08:45 10:00 1.25 2,437 4,153 SURFA DRILL WPRT P RIH on elevators f/ 2437' (2306'TVD) to 4153' MD. Tagged bottom, no roblems. 10:00 13:00 3.00 4,153 3,778 SURFA DRILL CIRC P Circulate and condition hole w/ 753 gpm w/ 2200 psi. Rotate 40 rpm w/ 8-9k ft Ib torque. PU sassing tools to rig floor. Mix dry job. Backreamed 5 stands f/ 4153' to 3778' while circ, standing back stands while circ. Circulate total of 2663 bbls while cleanin u hole after short tri . 13:00 13:30 0.50 3,778 3,778 SURFA DRILL CIRC P Monitor well, OK. Pump 20 bbl dry job. Blow down to drive. 13:30 16:30 3.00 3,778 73 SURFA DRILL TRIP P Continue POOH f/ 3778', SLM, UD ghost reamer, stand back HWDP and ~ars, stand back nm flex collars to 73' 16:30 17:00 0.50 73 73 SURFA DRILL OTHR P Download Sperry Sun MWD. PU more casing equipment to rig floor. Clear and clean ri floor. 17:00 18:00 1.00 73 0 SURFA DRILL PULD P UD BHA #2. SLM, no corrections. 18:00 20:45 2.75 0 0 SURFA CASIN( RURD P RU to run 13-3/8" 68ppf L-80 BTC casin . 20:45 21:15 0.50 0 0 SURFA CASIN( SFTY P Held PJSM w/ crew on running 13-3/8" surface casin . ' t'~~~;~: ,l ~ o ~.~_.~.~ ..® ~ ~.....__._.~. _~~.....,.,~ . ~ ,.~. _~ _..~_,v,~e_ Time Logs Date From To Dur th E. De th Phase Code Subcode T M 07/13/2006 21:15 00:00 2.75 0 1,271 SURFA CASIN( RNCS P Run 13-3/8" surface casing: 13-3/8" 68 ppf L-80 BTC. Circ 30 bbls thru float equip @ 112' removing air from shoe joints prior to leaving conductor shoe. 30 joints in hole @ midnight = 1271'. Good displacement. Record PU and SO wt's every 5 joints. Note: Installed centralizers: 10' above shoe, then collar of jt # 1, then collar of jt # 3-17. Baker locked to pin of #4 'oint. 07/14/2006 00:00 00:30 0.50 1,271 1,500 SURFA CASIN( RNCS P Run 13-3/8" surface casing: 13-3/8" 68 ppf L-80 BTC f/ Jt # 31 (1271'). Good displacement. Record PU and SO wt's every 5 joints. Run to half way in on jt # 36 1500' . takin wei ht. 00:30 00:45 0.25 1,500 1,527 SURFA CASIN( CIRC P Insert Frank's fillup tool, establish circ. pump @ 4bpm w/ 200 psi. Wash down jt # 36 f/ 1500' to 1527' due to casing taking wt (70k SO wt). Circulate 50 bbls. 00:45 02:15 1.50 1,527 2,500 SURFA CASIN( RNCS P Continue RIH w/ 13-3/8" 68 ppf L-80 BTC casing f/ 1527' to 2500'. Record PU and SO wt's every 5 joints. Monitor dis lacement. 02:15 03:30 1.25 2,500 2,500 SURFA CASIN( CIRC P Insert Frank's fillup tool. Circulate down joint # 59. Recip f/ 2500' to 2480'. 4bpm w/ 320 psi, 5bpm w/ 240 psi final circ rate and pressure.PU wt before circ was 270k, after 235-240k. SO wt before circ 95k, after 135k. Circ total of 282 bbls {BU = 188 bbls). Returns wei ht as much as 9.9 03:30 04:15 0.75 2,500 3,145 SURFA CASIN( RNCS P Continue RIH w/ 13-3/8" 68 ppf L-80 BTC casing f/ 2500' to 3145' (jt # 74 in hole). Record PU and SO wt's every 5 'oints. Monitor dis lacement. 04:15 04:30 0.25 3,145 3,177 SURFA CASIN( RNCS P PU and install TAM port collar w/ 15' pup jts on each end. Record PU and SO wt's every 5 joints. Monitor displacement. Note: Installed centralizer on collar of 't # 74 and on u above TAM. 04:30 06:00 1.50 3,177 3,765 SURFA CASIN( RNCS P Continue RIH w/ 13-3/8" 68 ppf L-80 BTC casing f/ 3177' to 3765' (jt # 88 in hole). Record PU and SO wt's every 5 joints. Monitor displacement. Washed jt # 87 down f/ 3680' to 3722' pumping 5bpm w/ 220 psi. PU wt w/ pumps on 280k, with out pumps 310k. SO wt with pumps 110k, with out pumps 100k. Note: Calculated idsplacement f/ 90 'oints = 95 bbls, actual 79 bbls. ~ ~ ~~ .~ _ e e ~ ~~€~ ~t~ ~ ~;3 Time Lo~_ Date From To Dur th E. De th Phase Code Subcode T M 07/14/2006 06:00 06:45 0.75 3,765 4,153 SURFA CASIN( RNCS P Continue RIH w/ 13-3/8" 68 ppf L-80 BTC casing f/ 3765' to 4153' Qt # 97 in hole minus 3", # 98 above table). Tag bottom of hole. Record PU and SO wt's every 5 joints. Monitor displacement. Washed jt # 97 down f/ 4136' to 4145" pumping 6 bpm w/ 390 psi. PU wt w/ pumps on 300k.S0 wt with pumps 135k. Note: Installed centralizer on collar of jt #94 and 't#95. 06:45 07:15 0.50 4,153 4,153 SURFA CASIN( CIRC P Circulate 7 bpm w/ 390 psi. Circualte 170 bbls. 07:15 08:30 1.25 4,153 4,151 SURFA CASIN( OTNR P Remove jt # 98 from string. UD same. Bad threads on collar of jt # 97, pin of 't #98.. Ordered new collar f/ box. 08:30 09:45 1.25 4,151 4,143 SURFA CASIN( CIRC P Circ w/ Frank's fillup tool. Establish circ, stage rate f/ 5 bpm to 7 bpm w/ 390 si. Circ total of 350 bbls. 09:45 10:00 0.25 4,151 4,151 SURFA CASIN( SFTY P PJSM on rigging down Frank's fillup tool. Changing out bad collar. Rigging u cement head. 10:00 11:15 1.25 4,151 4,151 SURFA CASIN( RURD P R/D Frank's fillup tool. Blow down top drive. Re lace collar on 't #97. 11:15 11:45 0.50 4,151 4,151 SURFA CEME~ RURD P RU dowel) cementing head. RU lines to circulate. 11:45 13:00 1.25 4,151 4,151 SURFA CEMEI~ CIRC P Circulate and condition mud and hole f/ cementing 13-3/8" casing.. Circulate @ 70 spm (7bpm) w/ 220 psi, 25% flow line reading. Circ total of 530 bbls. Total volume circulated prior to cement job = 950 bbls. Final mud wt 9.1 ppg w/ 61 vis in, 9.2 w/ 65 vis out. 13:00 13:30 0.50 4,151 4,151 SURFA CEMEI~ SFTY P PJSM on cement job w/ Rig team, dowel) and APC. 13:30 16:15 2.75 4,151 4,151 SURFA CEME~ OTHR P Dowell pump 10 bbls CW100, test lines to 3500 psi, pump 40 bbls CW100, 50 bbls mud push w/ red dye (10.5 ppg), Drop bottom plug. Pump 648.9 bbls ASI cement (10.7 ppg), follow w/ 93 bbls DEEPCrete tail (12.0 ppg). Drop top plug. pump 20 bbls water. Switch dis lacement to ri . 16:15 18:00 1.75 4,151 4,151 SURFA CEMEf~ DISP P Displace cement w/ rig pumps. Redo casing till 100 bbls into displacement. Displace @ 7.1-6. p w/ 370-650 psi till last 33 bbl, slow to 3 bpm w/ 540-600 PSI. Bump plug w/ 587.2 bbls mud pumped. Final circ pressure 600 psi, bump and hold 1100 psi f/ 5 min. CIP @ 1745 hrs 7/14/2006. 250 bbls of good 10.7 ppg cement circulated to surface. 18:00 19:00 1.00 4,151 4,151 SURFA CEME~ RURD P Rig down casing tools and cementing e ui ment. 19:00 19:30 0.50 4,151 4,151 SURFA WELCT NUND P Remove 16" diverter line f/ knife valve. Clean cement f/ surface a ui ment. ~~ess~ __d~~®®~ ~ w_ ~.~ ~m~__ ~ ~~®~®~~. ~ .m ~~m_.~~~_~_ma.~ ..~. ~m m ~ ..~. ~~ .~®~.~.~ ~~~~ ~;~ ~t Time Los ~ ~ Date From To Dur th E. De th Phase Code Subcode T~ M 07/14/2006 19:30 21:45 2.25 4,151 4,151 SURFA WELCT OTHR P Rg up to PU 20" Diverter w/ riser. Cleanin its. 21:45 23:00 1.25 4,151 4,151 SURFA WELCT OTHR P Trying to PU diverter stack. Remove lockdown bolts f/ slips. Working side to side to free up assembly. Finally pulled diverter stack free f/ conductor. Cleanin its. 23:00 23:30 0.50 4,151 4,151 SURFA WELCT OTHR P PU 13-3/8" casing f /160k on wt indicator to 230k, remove master bushings.PU Diverter high enough to rou h cut and set sli s. Cleanin its. 23:30 00:00 0.50 4,151 4,151 SURFA CEMEI~ OTHR P Clean out cement in between 20' x 13-3/8". Clean out to 2' below top of landing ring load shoulder. Cleaning its. 07/15/2006 00:00 04:30 4.50 4,151 4,151 SURFA WELCT OTHR T Trying to center up the 13-3/8" casing to set slips in landing ring profile. Pulling 13-3/8" casing towards stairwell in cellar. Used a comealong, and asuper tugger to pull. Used a porta-power against cellar box to jack against. Needing to move pipe 1-1/4"+ to center up. Cleanin its. 04:30 04:45 0.25 4,151 4,151 SURFA WELCT OTHR P Set slips @0430 hrs. Block wt 80k, wt indicator 230k before slack off. Slack off w/ jt # 97 4.58" above floor, after slips set, top @ 4.51' above rig floor. Cleanin its. 04:45 05:15 0.50 SURFA WELCT OTHR P Rough cut and Ub jt # 97 and cutoff remaining on jt # 96. Final cut will be 7-3/8"(.62') above landing ring top. (.91' above load shoulder). These measurements leave 36.98' of jt # 96 in hole to load shoulder (37.89' to final cut). Cleanin its. 05:15 08:00 2.75 SURFA WELCT NUND P Rig down flowline riser f/ 20" Diverter. Loading 100 joints of 5" drill pipe in i e shed. 08:00 11:30 3.50 SURFA WELCT NUND P Welder preparing and welding Vetco Gray 13-3/8" adapter with flange to casing. Finished with welding procedure @ 1130 hrs 7/15/2006. Wrap w/insulation to allow to cool off f/ 8 hrs before testing. UD casing equipment and cement head f/ rig floor. Change bales and elevators to PU 5" drill i e. 11:30 12:00 0.50 SURFA RIGMN SVRG P Service rig, top drive and crown. Also service choke manifold. 12:00 12:30 0.50 SURFA DRILL SFTY P PJSM on picking up bit and subs f/ beaver slide. Following w/ picking up 5" drill pipe in mousehole, standing back in derrick. ~m_ ~ _..._ ~ .~.~_ e®_ _ m®® ~ ~ ~~ 1~ ~. ~u. Time Logs Date From To Dur S. .. th E. De th Phase Code Subcode T~ M 07!15/2006 12:30 14:15 1.75 SURFA DRILL PULD P PU subs and bit. PU/MU/stand in derrick Weatherford 5" d . 14:15 15:15 1.00 SURFA WELCT NUND P Seperate Vetco Gray adapter f/ Diverter spool. Seperate diverter spool f/Annular. 15:15 18:30 3.25 SURFA DRILL PULD P Continue picking up Weatherford 5" dp and stand back in derrick. Total of 33 stands were picked up f/ total of 109 stands in derrick. 18:30 19:30 1.00 SURFA WELCT OTHR P Prepare to PU/MU Vetco Gray Multibowl 222A. 19:30 20:30 1.00 SURFA WELCT OTHR P Unwrap weld on adapter, RU to test same. Screw on threaded flange, ra lock seal rin and seal sub. 20:30 21:00 0.50 SURFA WELCT OTHR P Test void and weld to 1800 psi (80% of collapse) f/ 10 min. OK. Note: Ri floor to flan e = 41.83' 21:00 23:30 2.50 SURFA WELCT NUND P Set Vetco gray Multibowl 222A, tighten bolts. Test seal sub and graylock seal to 5000 psi f/ 10 min. Changeout cable on off driller's side bridge crane. Inspect cable on driller's side bridge crane. Note: Rig floor to top flange of Vetco Gra multibowl = 35.80'. 23:30 23:45 0.25 SURFA WELCT SFTY P Hold PJSM in doghouse on nippling u. 23:45 00:00 0.25 SURFA WELCT NUND P PU/MU spacer spool on top of Vetco Gra multibowl wellhead. 07/16/2006 00:00 01:30 1.50 SURFA WELCT NUND P PU/MU BOP stack. Hammer up flanges, install turnbuckles and tighten same. 01:30 05:00 3.50 SURFA RIGMN SVRG P RU and change element in 13-5/8" annular.UD otato masher. 05:00 06:00 1.00 SURFA WELCT NUND P Finish NU BOP stack, choke and kill lines. Double check flanges. Pick up tools. 06:00 08:30 2.50 SURFA WELCT OTHR P Function test new annular 5-6 times. Then function test rest of equipment. RU test equipment. Fill stack w/water. Clear and clean ri floor. 08:30 14:30 6.00 SURFA WELC7 BOPE P Test 13-5/8" ROPE. Annular w/ new element, upper pipe rams (3-1/2" x 6"), lower pipe rams (9-5/8"), blind rams, floor safety valves, upper and lower IBOP valves on top drive, HCR and manual valves on kill and choke lines, choke manifold. All test @ 250 psi low f/ 5 min, then 3000 psi high f/ 5 min. Perform accumulator test: 200 psi build up in 39 seconds, full pressure in 3 min 35 sec. Chart test. Witness of test by AOGCC in, Spector Chuck Sheve. 14:30 16:00 1.50 SURFA WELCT OTHR P Rig down test equipment. Install long wear bushin . _m _~ _ ®. ~ -~a ..~...~_ ~_ _~~m ~ .~ Time Logs ~ ~ Date From To Dur th E. De th Phase Code Subcode T ~ ~CJM _ 07/16/2006 16:00 18:00 2.00 SURFA WELCT NUND P Install bell nipple. Connect flow line. Clean and clear ri floor. 18:00 21:00 3.00 0 116 SURFA DRILL PULD P PU/MU BHA#3: 12-1/4" Security FSF2563 bit, 8" 9600 series Sperry Sun geopilot (ser # 097), nm geo flex collr, 8" MPT wDGR+EWR, 12-1/8" smart stab, 8" HCIM, 8" MPT w/ SLD + CTN, 8" pulsar, nm float sub to 116.05' 21:00 23:00 2.00 65 65 SURFA DRILL OTHR P Sperry Sun upload. 23:00 23:15 0.25 65 65 SURFA DRILL SFTY P PJSM on installing nuke sources. 23:15 23:30 0.25 65 116 SURFA DRILL OTHR P Install sources in Sperry Sun tools. 23:30 00:00 0.50 116 680 SURFA DRILL TRIP P MU stand of 7-3/4" NM flex drill collars, follow w/ Daily jars, then Weatherford 5" DP to total of 5 stands HW in hole to 680' 07/17/2006 00:00 00:15 0.25 680 865 SURFA DRILL TRIP P Continue trip in w/ BHA #3: Run 2 stands Weatherford 5" dp for a total of 7 stands HW in hole to 864.61'. 00:15 00:30 0.25 865 1,025 SURFA DRILL PULD P Run 5 joints, then PU/MU 12-1/4" ghost reamer in stand # 2 of Weatherford 5" dp. Ghost reamer 1024.97' f/ bit. 00:30 01:00 0.50 1,025 2,771 SURFA DRILL TRIP P Continue RIH w/ Weatherford 5" dp, total of 20 stands in hole to 2771.36' 01:00 01:30 0.50 2,771 2,771 SURFA DRILL CIRC P Fill pipe. Circ surf to surface. Pumping 700 gpm w/ 1500 psi. 800 gpm w/ 2100 psi. Break in Sperry Sun 9600 series GeoPilot w/ 7-10 rpm, stage up to 30 r m. 01:30 01:45 0.25 2,771 2,960 SURFA DRILL TRIP P RIH 2 stands Weatherford 5" dp. Circ and check out Sperry Sun MWD tools. OK 01:45 02:15 0.50 2,960 2,960 SURFA DRILL CIRC P Circ and check out Sperry Sun MWD tools. OK 02:15 03:30 1.25 2,960 4,005 SURFA DRILL TRIP P RIH f/ 2960' to 4005'. Stand # 33 in hole. 03:30 03:45 0.25 4,005 4,005 SURFA DRILL OTHR P Move 4" DP in derrick. 03:45 04:45 1.00 4,005 4,054 SURFA DRILL CIRC P PU stand # 34, establish circ, tag up on cement @ 4054'. Circulate 862 bbls. Pumping 750 gpm w/ 1950 psi, 730 m w, 1790 si. 04:45 05:15 0.50 4,054 4,002 SURFA CASIN( DHEQ P Stand back stand #34. RU to test casin 05:15 06:00 0.75 4,002 4,002 SURFA CASIN( DHEQ P Test 13-3/8" 68 ppf L-80 BTC casing to 3050 psi. Chart test f/ 30 min. Lost 20 psi in 30 min, good test. Pumped total of 73 strokes. 06:00 06:15 0.25 4,002 4,002 SURFA DRILL OTHR P R/D test equipment. 06:15 06:30 0.25 4,002 4,056 SURFA DRILL TRIP P PU/MU stand #34, establish circulation. RIH to to cement 4056' _ ~ -a ~ ~. ~ ~ ~ ~ ~.~_.~ ® t f ___s_®m e_ _e®0 ~ .~.. ~ ..~ .~ ~__ _._ - .~.~...~ ~ ~_.. ~.ee~ Time logs ~~- Date From To Dur th E. De th Phase Code Subcode T ~M 07/17/2006 06:30 09:45 3.25 4,056 4,173 SURFA CEME~ DRLG P Drilling cement, wiper plugs and FC @ 4065' (4062' DPM), cement, FS, rat hole, to 4153', plus 20' new hole to 4173' (2309' TVD). ART = .19 hrs, bit hrs .19, Jar hrs = 54.2 hrs. Drill w/ 4-10k WOB, 50 rpm w/ 10k ft Ib torque on bottom, 8-13k ft Ib off bottom. Pumping 627 gpm w/ 1420 psi on bottom, 1360 psi off bottom. ECD's 9.47 ppg. PU wt 170k, SO wt 90k, Rot wt125k. 09:45 10:30 0.75 4,173 4,173 SURFA DRILL CIRC P Circulate bottom's up @ 4173' (2309' TVD). Pumping 555 gpm w/ 1090 psi, 50 rpm w/ 10-13k ft Ib. Circ total of 700 bbls. 10:30 10:45 0.25 4,173 SURFA DRILL SFTY P PJSM on mud swap out to 9.0 LSND. 10:45 12:00 1.25 4,173 4,173 SURFA DRILL CIRC P Displace to 9.0 ppg LSND mud. Pump 37 bbls spacer, follow w/ 600 bbls new 9.0 ppg LSND mud. Pumping 555 gpm w/ 1090 si. 12:00 14:30 2.50 4,173 4,173 SURFA DRILL LOT P RU and perform LOT @ 4173' MD (2310' TVD). LOT 15.5 ppg EMW. Pumped total of 62 strokes @ 5 bpm. Max of 830 psi. Bleed off to 420 psi. Bleed back .5 bbl. R/D test equipment, blow down kill line. R/D test manifold, re are to drill. 14:30 18:00 3.50 4,173 4,570 INTRM1 DRILL DDRL P Directional Drill 12-1/4" intermediate hole w/ 9-5/8"" Sperry GeoPilot f/ 4173' to 4570' (397') (TVD = 2409'). ART = 1.86 hrs. Total hrs on bit = 2.05 hrs., Total hrs on jars = 56.06 hrs, 0-20k WOB, 120 rpm's, 752-650 gpm w/ 9.1 ppg MW, on bottom press 1460-1250 psi, off bottom press 1320-1200 psi, on bottom torque 8-14k ft/Ib, off bottom torque 5-12k ft/ Ib, PU wt 172-165k, SO wt 92-100k, Rot wt 128-132k. ECD's 9.3-9.4 18:00 00:00 6.00 4,570 5,307 INTRM1 DRILL DDRL P Directional Drill 12-1/4" intermediate hole w/ 9-5/8"" Sperry GeoPilot f/ 4570' to 5307' (737') (TVD = 2581'). ART = 2.11 hrs. Total hrs on bit = 4.16 hrs., Total hrs on jars = 58.17 hrs, 5-20k WOB, 80-70 rpm's, 520-575 gpm w/ 9.1 ppg MW, on bottom press 1020-900 psi, off bottom press 1050-900 psi, on bottom torque 5-15k ft/Ib, off bottom torque 8-17k fU Ib, PU wt 165-180k, SO wt 100-90k, Rot wt 132-130k. ECD's 9.6 . . , ~ ~ , _ __. ®~ ~ ~~m~ ®®e ~......._~ m_._~ ~. __ ..e ®~~~ ---....._...~ ~. Time Lo s Date From To Dur .~ E. De th Fhase Code Subcode T M 07/18/2006 00:00 06:00 6.00 5,307 5,808 NTRM1 DRILL DDRL P Directional Drill 12-1/4" Intermediate hole w/ 9-5/8"" Sperry GeoPilot f/ 5307' to 5808' (501') (TVD = 2687'). ART = 1.73 hrs. Total hrs on bit = 5.89 hrs., Total hrs on jars = 59.9 hrs, 5-20k WOB, 80-100 rpm's, 525 gpm w/ 9.1 ppg MW, on bottom press 1050 psi, off bottom press 970 psi, on bottom torque 10-15k ft/Ib, off bottom torque 8-14k ft/ Ib, PU wt 170-185k, SO wt 92-99k, Rot wt 130-135k. ECD's 9.6-9.64 06:00 10:00 4.00 5,808 6,286 INTRM1 DRILL DDRL P Directional Drill 12-1/4" Intermediate hole w/ 9-5/8"" Sperry GeoPilot f/ 5808' - 6286 (478') (TVD = 2789'). ART = 1.51 hrs. Total hrs on bit = 7.4 hrs., Total hrs on jars = 61.41 hrs, 70 -100 rpm's, 575 gpm w/ 9.1 ppg MW, YP = 19, Visc = 56, 5-20K WOB, 80-100 rpm's, ECD's 9.6-9.64 ppg, On bottom press 1260 PSI, On bottom torque 14-16K fUlb, Off bottom torque 10-12K ft/ Ib, UP WT= 189k, SO WT 95K, ROT WT= 135K. ECD's 9.6-9.64 ppg, Max as - 123 Units 10:00 11:15 1.25 6,286 6,286 INTRM1 RIGMN RGRP T Retorque Housing Bolts on Shot Pin Assembly on Top Drive. Attach Safety Wire. Service Top Drive. Work Drill string and obtain SPR"S. #1 pump - 20 SPM -110 PSI, 30 SPM - 150 PSI. #2 pump - 20 SPM - 110 PSI, 30 SPM - 150 PSI. 11:15 12:00 0.75 6,286 6,381 INTRM1 DRILL DDRL P Continue Directional Drill 12-1/4" Intermediate hole w/ 9-5/8"" Sperry GeoPilot f! 6286' - 6381' (95') (TVD = 2807'). ART = .28 hrs. Total hrs on bit = 7.68 hrs., Total hrs on jars = 61.69 hrs, 10-12K WOB, 9.2 PPG MW YP = 18 ,Visc = 56, 10-20K WOB, 80-100 rpm's, 525 gpm , On bottom press 1180 psi, On bottom torque 14-16k ft/Ib, off bottom torque 10-12K ft/ Ib, PU wt 195K, SO WT 93K, ROT WT = 135k. ECD's 9.65 ppg ,Max gas - 120 Units ..~~ eQ.e~_.~~~ .-______~ -~ __-..~.._~ _~ . ~____°_°_°~ ----°°~ °~ ~ 1 ~:a d v3 Time Los Date From To Dur 5. _ th E. De th Phase Code Subcode T M 07/18/2006 12:00 18:00 6.00 6,381 6,951 INTRM1 DRILL DDRL P Continue Directional Drill 12-1/4" Intermediate hole w/ 9-5/8" Sperry GeoPilot f/ 6381' - 6951' (570') (TVD = 2928'). ART = 2.20 hrs. Total hrs on bit = 9.88 hrs., Total hrs on jars = 63.89 hrs, 10-20K WOB, 100 rpm's, 575 gpm w/ 9.1 ppg MW, YP = 19, Visc = 56, On bottom press 1290 psi, On bottom torque 12-18k ft/Ib, off bottom torque 10-15K ft/ Ib, PU wt 189K, SO WT 98K, ROT WT = 140k. ECD's 9.82 ppg ,Max gas - 26.7 Units. Crew Chan e 18:00 00:00 6.00 6,951 7,619 INTRM1 DRILL DDRL P Continue Directional Drill 12-1/4" Intermediate hole w/ 9-5/8" Sperry GeoPilot f/ 6951' - 7619' (668') (TVD = 3073'). ART = 2.15 hrs. Total hrs on bit = 12.03 hrs., Total hrs on jars = 66.04 hrs, 10-20K WOB, 120 rpm's, 575 gpm w/ 9.2 ppg MW, YP = 18, Visc = 55, On bottom press 1780 psi, On bottom torque 10-15k ft/Ib, off bottom torque 5-10K ft/ Ib, PU wt 185K, SO WT 100K, ROT WT = 142k. ECD's 10.01 ,Max as - 29 Units 07/19/2006 00:00 03:00 3.00 7,619 7,917 INTRM1 DRILL DDRL P Continue Directional Drill 12-1/4" Intermediate hole w/ 9-5/8" Sperry GeoPilot f/ 7619' - 7917' (298') (TVD = 3145'). ART = .92 hrs. Total hrs on bit = 12.95 hrs., Total hrs on jars = 66.96 hrs, 10-20K WOB, 120 rpm's, 575 gpm w/ 9.2 ppg MW, YP = 20, Visc = 57, On bottom press 1780 psi, On bottom torque 10-15k ft/Ib, off bottom torque 5-10K ft/ Ib, PU wt 185K, SO WT 105K, ROT WT = 145K. ECD's 9.88 ppg ,Max gas - 29 Units. Observed Geo-pilot failed allowing sli in ,would not hold tool face. 03:00 04:00 1.00 7,917 7,917 INTRM1 DRILL CIRC T Pump 10.8 PPG - 180 Visc Hi Visc sweep @ 575 GPM's - 1850 PSI. Reciprocate & rotate drill string. Observe 75% increase in cuttings on sahkers when swee returned. 04:00 06:00 2.00 7,917 7,050 INTRM1 DRILL REAM T BROOH from 7917' - 7050'. Pumps @ 750 GPMs - 1650 PSI. Obtain SPR's before BROOH. Pump #1 = 30 SPM - 230 PSI, 40 SPM - 300 PSI. Pump #2 - 30 SPM - 220 PSI, 40 SPM - 290 PSI. 06:00 12:00 6.00 7,050 4,290 lNTRM1 DRILL REAM T Continue BROOH from 7050' - 4290'. Pumps @ 750 GPM's - 1500 PSI - 120 RPM's. 12:00 13:00 1.00 4,290 4,100 INTRM1 DRILL REAM T Continue BROOH from 4290' - 4100'. Pumps @ 750 GPM's - 1500 PSI - 120 RPM's. ,_ _ ~e ~. i i s. >i~f.~ ~~ C7~ Time Logs Date From To Dur ._ ,>t th E. Depth Phase Code Subcode T M 07/19/2006 13:00 15:00 2.00 4,100 4,100 INTRM1 DRILL CIRC T Wlth Bit inside shoe, Rotate & reciprocate drill string while pump 40 BBL Hi Visc weighted sweep. 10.6 PPG - 102 Visc. Pumps @ 800 GPM's 2250 PSI with 60 RPM's. Pump & circulate out Lube ill. 15:00 15:15 0.25 4,100 4,100 INTRM1 DRILL OWFF T Monitor well -static. Pump dry job. 15:15 18:00 2.75 4,100 2,581 INTRM1 DRILL TRIP T Continue POOH on elevators from 4100' - 2581'. (1519'). Install Super sliders on every joint (3 per stand ) while POOH. Crew Chan e 18:00 21:00 3.00 2,581 864 INTRM1 DRILL TRIP T Continue POOH on elevators from 2581' - 864. (1717'). Install Super sliders on every joint (3 per stand ) while POOH. Breakout & lay down Ghost reamer. 21:00 22:00 1.00 864 206 INTRM1 DRILL PULD T POOH standing back 7 stands of 5" HWDP with Dailey Drilling Jars (655.58'}. Stand back 3 Non Mag Flex drill collars (93.03'). Breakout & lay down Non ma float sub 92.42' . 22:00 23:00 1.00 206 206 INTRMI DRILL PULD T Held PJSM with crew & Sperry Sun Reps. Discuss Safety Issues and procedure for pulling Nuclear Sources, and remaining BHA. Pull Nuclear sources and secure same. 23:00 00:00 1.00 206 206 INTRM1 DRILL OTHR T Rig Up and download MWD assembly. 07/20/2006 00:00 01:30 1.50 206 0 INTRM1 DRILL PULD T Breakout & lay down remaining BHA as per Sperry Sun reps. Lay down 8" MPT Pulsar (11.19'), 8" MPT w/SLD + CTN (37.53'), 8" HCIM (7.01'), 8" Smart Stabilizer (2.16'), 8" MPT w/ DGR + EWR (23.12'), Non Mag Geo Flex (9.20'), 9 5/8" 9600 Series Geo-Pilot (21.68'), and 12 1/4" FSF 2563 Long Gauge PDC bit (1.74'). Inspect & gauge bitat2/3/WT/ALL/X/I/ BT / DTF. 01:30 06:00 4.50 0 0 INTRM1 RIGMN RGRP T PJSM with crew. Discuss safety issues and procedure for rigging up to repair Top drive. Rig up, Trouble shoot & repair Shot pin assembly on Top Drive. Crew Chan e 06:00 12:00 6.00 0 0 INTRM1 RIGMN SVRG T PJSM with crew. Discuss safety issues and procedure for rigging up to repair Top drive. Rig up, Trouble shoot & repair Shot pin assembly on Top Drive. 12:00 12:15 0.25 0 0 INTRM1 DRILL SFTY T PJSM with crew 7 Sperry Sun Reps. Discuss Safety Issues and procedure for making up BHA #4, 8" Motor assembl . ~~ ~ a s~~~ ~# ~~ }~s .~C I Time Logs Date From To Dur th E. De th Phase Code Subcode T M 07/20/2006 12:15 14:00 1.75 0 75 INTRM1 DRILL PULD T Make up BHA #4. Make up 12 1/4" Security FSF2663 bit with 8 x 16's for jet = TFA of 1.571 sq. in. (1.23'), 8" Sperry Drill lobe 4/5 - 5.3 stage with a 1.5 degree bend in motor. (28.68'), 8" Integral Blade Stabilizer (7.02'), 8" Non Mag crossover sub (1.32'), 8" Directional (9.18'), and 8" Gamma /Res/PWD/ HCIM (27.80'). Observe the pin end threads were 6 5/8" H90, and the needed crossover to 6 5/8" Regular thread was on old MWD tool. 14:00 17:00 3.00 75 75 INTRM1 DRILL PULD T Lay down Gamma/Res/PWD/HCIM tool. Pick up last MWD asembly with crossover. Rig up breakout & lay down Crossover. Lay down last MWD assembly. Pick up new MWD assembly and make up to drilling assembly as above.Breakout Hard connect connections from old assembly and install hard connect 7 lockin collar in new assembl . 17:00 18:00 1.00 75 135 INTRM1 DRILL PULD T Continue make up BHA #4. Make up 8" Neutron density /CTN (37.69'), 8" MPT Pulsar (11.19') and 8" Non Mag Float Sub 2.42' . Crew Chan e 18:00 19:30 1.50 135 135 INTRM1 DRILL PULD T Plug in and down load MWD assembly. Hold PJSM with crew. .Discuss Safety Issues and procedure for installing Nuclear sources in MWD assembly. Finish down load. Install sources. 19:30 20:00 0.50 135 423 INTRM1 DRILL PULD T Continue make up remaining BHA. Make up 3 -Non Mag Flex Drill Collars (93.03'), 8" Dailey drilling Jars (40.27'), and 5 joints - 5" HWDP (153.92'). Total BHA length = 413.75'. Note: Sensor distances from bit= DIR -42.58', DGR -51.29', EWR - 59.03', PWD - 67.26', SLD - 88.42', A-CAL -102.43', and CTN -105.83'. Jar hours at start of run = 66.96 HRS. 20:00 22:00 2.00 423 423 INTRM1 RIGMN SVRG P PJSM with crew. Discuss safety issues and procedure for slipping & cutting drilling line. Discuss "Pinch Points" & "Handling Wire rope safely". Slip & cut 18 wraps of drilling Line. Inspect drawworks, adjust brakes, Service Top drive 7 drawworks. Clean Floor area, re are for TIH. 22:00 23:00 1.00 423 2,771 INTRM1 DRILL TRIP T Trip in hole with BHA #4 from 423' - 2771'. Observe ro er hole fill. ~--~ ~m. ~_ ~~~ _a .®~~ _ _..®. ~.~®_ ~.m~~. _ _ __~ ~ ~~~~_p_~~~*~ ~g Time Logs Date From To Dur _pth E. Depth Phase Code Subcode T M _ 07/20/2006 23:00 23:30 0.50 2,771 2,771 INTRM1 DRILL TRIP T _ Fill drill string and pump for checkshot MWD survey. Observe tool pulsing without pumping up a survey. Repeat attempts. Suspect air in mud. decision to run 10 stands and repeat checkshot attem t. 23:30 00:00 0.50 2,771 3,723 INTRM1 DRILL TRIP T Continue trip in hole from 2771' - 3723'. Observe ro er hole fill 07/21/2006 00:00 00:30 0.50 3,723 3,723 INTRM1 DRILL TRIP T Fill drill string and obtain successful check shot surve as er MWD re . 00:30 01:15 0.75 3,723 4,100 INTRM1 DRILL TRIP T Continue trip in hole with BHA #4 from 3723' - 4100'. Observe proper hole fill. Observe mud weight out @ 9.6 - 9.8 PPG, Viscosity 42, YP - 16. Move 6 stands of HWDP in derrick. Reposition pipe to accomodate for drill pipe with sliders reviousl installed on TOH. 01:15 02:15 1.00 4,100 4,100 INTRM1 DRILL CIRC T Make Top Drive connection @ Shoe and circulate to condition mud weight to 9.2 PPG In /Out. Visc - 56. Reciprocate & rotate drill string as per DD. Pumps @ 600 GPMs - 880 PSI. RPM's -80. UP WT = 138K, SO WT = 102K, ROT WT = 120K. TQ = 5K. Monitor well -static 02:15 05:00 2.75 4,100 7,917 INTRM1 DRILL TRIP T Continue trip in hole from 4100' into open hole to 5656'. Observe tagging up and taking 20K set down weight. Make Top Drive connection and wash & rotate through spot @ 5656' with no issues. Continue RIH on elevators occasionally making TD connections to wash through spots @5405'- 5460', 5945- 6035', 6460', 6530', 6645'- 6705', 6745' -6800'. and finally washing each stand down to tag TD @ previously drilled de th of 7917'. 05:00 06:00 1.00 7,917 7,917 INTRM1 DRILL CIRC T Pump Hi Visc sweep & circulate to condition mud @ 9.1 PPG, 58 Visc with a YP of 22. Pumps @ 600 GPMs - 1320 PSI. UP WT = 130K, SO WT = 100K. Crew Chan e 06:00 07:00 1.00 7,917 7,917 INTRM1 DRILL CIRC T Observe pump pressure lower than expected @ 1000 PSI with 500 GPMs. Check & pressure test surface equipment, calibrate & re orient MWD. All s stems checked out OK. ®..em _ ~ e®.m _a~ _. ~._~....._~. ~ ~c?e ~s Time Logs Date From To Dur th E. De th Phase Code Subcode T M _ 07/21/2006 07:00 12:00 5.U0 7,917 8,355 INTRM1 DRILL DDRL P Directional Drill 12 1/4" Hole from 7917' - 8355' (438') TVD = 3251'. UP WT = 190K, SO WT = 100K, ROT WT = 140K. 90 RPM's, 15-20K WOB. Pumps @ 735 GPM's - 1800 PSI. Torque on Bottom = 13-15K, Torque Off Bottom = 12-13K. ART = 1.06 HRS. AST = 1.22 HRS. Total Bit HRS = 2.28. Total Jar HRS = 69.24. MAx Gas observed = 28.2 Units. ECD's 9.56 PPG. Baseline ECD @ 9.6 PPG. Survey @ 8357.67 MD, INC = 75.77 DEG, AZ = 89.27 DEG, TVD = 3283.52'. 12:00 15:00 3.00 8,355 8,660 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 8355' - 8660' (305') TVD = 3325'. UP WT = 200K, SO WT = 100K, ROT WT = 145K. 90 RPM's, 15-20K WOB. Pumps @ 735 GPM's - 1800 PSI. Torque on Bottom = 14-16K, Torque Off Bottom = 11-12K. ART = .47 HRS. AST = .97 HRS. Total Bit HRS = 3.72. Total Jar HRS = 70.68. MAx Gas observed = 101 Units. ECD's 9.88 PPG. Survey @ 8639.23' MD, INC = 77.34 DEG, AZ = 98.22 DEG, TVD = 3376.88'. 15:00 16:00 1.00 8,660 8,660 INTRM1 DRILL CIRC P Pick up off bottom observing Shaker screens blanking off from Tar & Sand returns and losing excessive mud over shakers. Work drill string from 8660' - 8560'. UP WT = 210K, SO WT = 98K, Slow pumps to 170 GPM - 240 PSI while work to clean and change shaker screens. 16:00 16:30 0.50 8,660 8,401 INTRM1 DRILL REAM P Pump out of hole from 8600' - 8401' MD. 16:30 18:00 1.50 8,401 8,401 INTRM1 DRILL CIRC P Continue cleaning shaker screens while circulating @ 175 GPM - 250 PSI. Slowly increase pump rates to 350 GPM - 500 PSI, and 430 GPM - 710 PSI. Reciprocate & rotate drill string @ UP WT = 210K, SO WT = 98K, ROT WT = 140K. Tar & sand cleaning up allowing better pump rates for downhole & shaker screens. Crew Chan e 18:00 18:30 0.50 8,401 8,401 INTRM1 DRILL CIRC P Continue cleaning shaker screens while circulating @ 430 GPM - 710 PSI, and up to 750 GPM's - 1520 PSI. Reciprocate & rotate drill string @ UP WT = 210K, SO WT = 98K, ROT WT = 140K. Tar & sand cleaning up allowing better pump rates for downhole & shaker screens. Trip back to bottom 8660' MD m~ ® ~e~ sw ~w ~'~e ~;~ ~°r~i ~3 Time Logs _ Date From To Dur th E. De t_h Phase Code Subcode T M _ 07/21/2006 18:30 00:00 5.50 8,660 8,940 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 8660' - 8940' (280') TVD = 3391'. UP WT = 220K, SO WT = 90K, ROT WT = 150K. 90 RPM's, 15-20K WOB. Pumps @ 735 GPM's - 1800 PSI. Torque on Bottom = 14-16K, Torque Off Bottom = 11-12K. ART = 2.39 HRS. AST = 3.45 HRS. Total Bit HRS = 5.84.Total Jar HRS = 70.68. MAx Gas observed = 92 Units. ECD's 9.73 PPG. Survey @ 8930.15' MD, INC = 74.52 DEG, AZ = 107.50 DEG, TVD = 3473.34'. 07/22/2006 00:00 06:00 6.00 8,940 9,255 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 8940' - 9255' (315') TVD = 3475'. UP WT = 215K, SO WT = 90K, ROT WT = 152K. 80 RPM's, 3-10K WOB. Pumps @ 655 GPM's - 1820 PSI. Torque on Bottom = 12-18K, Torque Off Bottom = 8-15K. ART = 2.73 HRS. AST = 5.3 HRS. Total Bit HRS = 8.38.Total Jar HRS = 78.71. Max Gas observed = 42 Units. ECD's 9.65 PPG. Survey @ 9214.65' MD, INC = 73.48 DEG, AZ = 115.29 DEG, TVD = 3464.18'. Crew Chan e 06:00 10:15 4.25 9,255 9,337 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 9255' - 9337' (82') TVD = 3497'. UP WT = 210K, SO WT = 98K, ROT WT = 152K. 80 RPM's, 10-20K WOB. Pumps @ 730 GPM's - 1750 PSI. Torque on Bottom = 12-18K, Torque Off Bottom = 14-16K. ART = 0.0 HRS. AST = 1.45 HRS. Total Bit HRS = 9.86.Total Jar HRS = 76.82. Max Gas observed = 40 Units. ECD's 9.75 PPG. Survey @ 9309.40' MD, INC = 73.60 DEG, AZ = 117.72 DEG, TVD = 3491.03'. Observe difficulty in sliding, decision to BROOH 10 stands. 10:15 10:30 0.25 9,337 9,337 INTRM1 DRILL SFTY P PJSM with Crew. Discuss Saftey issues and rocedure for BROOH. 10:30 12:00 1.50 9,337 8,786 INTRM1 DRILL REAM P BROOH from 9337' - 8786' MD. Pumps @ 735 GPM's- 1750 PSI. UP WT = 155K, 60 RPM's with 15K for ue. 12:00 12:45 0.75 8,786 8,406 INTRM1 DRILL REAM P BROOH from 8786' - 8406' MD. 10 stands total. Pumps @ 735 GPM's- 1700 PSI. UP WT = 155K, 60 RPM's with 15K for ue. 12:45 13:15 0.50 8,406 9,337 INTRM1 DRILL TRIP P Trip in hole from 8406' - 9261'. Make Top Drive connection, pump 40 BBLS of Lube pill while washing to bottom with @ 9337' MD with 650 GPM - 1560 PSI. ee~~~ ®~ -. m __.. - .~ ~® ~ ~_~ ,.n, ~.. -, .... .~ ____ .~..m, ~...._._~~ .. Time Logs Date From To Dur th E. De th Phase Code Subcode T M 07/22!2006 13:15 18:00 4.75 9,337 9,638 INTRM1 DRILL DDRL _ P Continue Directional Drill 12 1/4" Hole from 9337' - 9638' (301') TVD = 3569'. UP WT = 220K, SO WT = 100K, ROT WT = 150K. 80 RPM's, 10-20K WOB. Pumps @ 650 GPM's - 1740 PSI. Torque on Bottom = 12-18K, Torque Off Bottom = 14-16K. ART = 0.04 HRS. AST = 1.95 HRS. Total Bit HRS = 11.85.Total Jar HRS = 78.81. Max Gas observed = 114 Units. ECD's 9.70 PPG. Survey @ 9592.32' MD, INC = 77.66 DEG, AZ = 129.31 DEG, TVD = 3559.52'. Observe hole cleaned up good allowing for better drilling and slide control. Crew Chan e. 18:00 00:00 6.00 9,638 9,923 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 9638' - 9923' (285') TVD = 3621'. UP WT = 220K, SO WT = 85K, ROT WT = 150K. 80 RPM's, 3-10K WOB. Pumps @ 655 GPM's - 1820 PSI. Torque on Bottom = 15-25K, Torque Off Bottom = 10-15K. ART = 0.85 HRS. AST = 1.65 HRS. Total Bit HRS = 14.35.Total Jar HRS = 81.31 Max Gas observed = 35 Units. ECD's 9.85 PPG. Survey @ 9878.90' MD, INC = 78.06 DEG, AZ = 142.17 DEG, TVD = 3611.67'. Observe drilled into a hi torque zone from 9915' - 9920' MD. Max for ue observed = 35K. 07/23/2006 00:00 04:00 4.00 9,923 10,208 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 9923' - 10208' (285') TVD = 3667'. UP WT = 220K, SO WT = 85K, ROT WT = 150K. 80 RPM's, 3-10K WOB. Pumps @ 659 GPM's - 1860 PSI. Torque on Bottom = 18-20K, Torque Off Bottom = 15-18K. ART = 0.21 HRS. AST = 1.54 HRS. Total Bit HRS = 16.10.Total Jar HRS = 83.00 Max Gas observed = 76 Units. ECD's 9.96 PPG. Survey @ 10164' MD, INC = 81.15 DEG, AZ = 155.03 DEG, TVD = 3660.84'. Decision to BROOH 10 stands as Sliding became difficult to control and we needed wiper trip to clean u the hole. 04:00 06:00 2.00 10,208 9,641 INTRM1 DRILL REAM P BROOH from 10208' - 9641' with pumps @ 750 GPMs - 1750 PSI. 60 RPM's, ECD = 10.24 PPG, Torque = 12K. Back ream rate = 10 - 15 FUMin. Crew Chan e 06:00 06:45 0.75 9,641 9,261 INTRM1 DRILL REAM P Continue BROOH from 9641' - 9261'. 10 stands total @ 750 GPMs - 1750 PSI. 60 RPM's, ECD = 10.24 PPG, Torque = 12K. Back ream rate = 10 - 15 FUMin. ~® ~ _ ~ ~~ me~ ~_ ~_ ~ ~~ ____r m~ m., ~~ Time Logs Date From To _ Dur th E De th Phase Code Subcode T M 07/23/2006 06:45 07:30 0.75 9,261 10,197 INTRM1 DRILL TRIP P Trip in hole from 9261' - 9736'. RIH with 5 stands push Pipe, (adjust pipe tally), and continue trip in hole to 10197' with 5" Drill i e. 07:30 08:00 0.50 10,197 10,205 INTRM1 DRILL CIRC P Fill Drill string and obtain surveys as er MWD. 08:00 10:15 2.25 10,208 10,324 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 10208' - 10324' (119') TVD = 3687'. UP WT = 220K, SO WT = 112K, ROT WT = 160K. 80 RPM's, 3-10K WOB. Pumps @ 672 GPM's - 2060 PSI. Torque on Bottom = 15-17K, Torque Off Bottom = 13-14K. ART = 0.28 HRS. AST = .59 HRS. Total Bit HRS = 16.99 .Total Jar HRS = 83.95 Max Gas observed = 31.2 Units. ECD's 9.99 PPG. Survey @ 10244' MD, INC = 80.09 DEG, AZ = 157.94 DEG, TVD = 3673.88'. Decision to BROOH 10 stands as Sliding became difficult to control and we needed wiper tri to clean u the hole. 10:15 13:45 3.50 10,324 9,261 INTRM1 DRILL REAM P BROOH from 10324' - 9261' with pumps @ 750 GPMs - 2120 PSI. 60 RPM's, ECD = 10.24 PPG, Torque = 14-15K. ROT WT = 162K. Back ream rate = 10 - Ft/Min. 13:45 14:00 0.25 9,261 9,261 INTRM1 DRILL OWFF P Monitor well -static. 14:00 14:30 0.50 9,261 10,324 INTRM1 DRILL TRIP P Trip back in hole from 9261' - 10324'. Observe good hole conditions and ro er hole fill. 14:30 15:00 0.50 10,324 10,324 INTRM1 DRILL CIRC P Fill drill string and obtain surveys as per MWD rep. Work string to orient at 70 de ri ht of hi h side. 15:00 17:15 2.25 10,324 10,530 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 10324' - 10530' (206') TVD = 3713'. UP WT = 230K, SO WT = 115K, ROT WT = 160K. 80 RPM's, 3-10K WOB. Pumps @ 650 GPM's - 1750 PSI. Torque on Bottom = 15-17K, Torque Off Bottom = 13-14K. ART = 0.13 HRS. AST = 1.14 HRS. Total Bit HRS = 18.26 .Total Jar HRS = 85.22 Max Gas observed = 114 Units. ECD's 9.85 PPG. Surrey @ 10531' MD, INC = 84.00 DEG, AZ = 171.54 DEG, TVD = 3715'. -_~_ __.~ ~~~~~.~ v® ~ -...~.. _~ a v..~ ~®m.~.~ _.~~ _~. ~ ~ ~ ~?Kac~e ~ ~ ~~ ~3 { Time Logs Dat From To Dur th E. Depth Phase Code Subcode T _ M 07/23/2006 17:15 18:00 0.75 10,530 10,530 INTRM1 DRILL OTHR NP Observed while sliding @ 70 Degrees right of high side, the Top Drive spun the drill string left at a high rate for a moment, and connection was backed off. Top Drive immediately was shut down, along with pumps. Top Drive connection was made up again. We were able to gain full pump rate & string weight. It was observed that the connection on the bottom of the stand had also been backed out 4 -5 threads. All connections were checked for torque. CO. Rep & Tool Pusher were notified and on Rig, as well as Field Supt, and CPAI Safety Specialists. Perform Investigation. UP WT = 220K, SO WT = 110K. Top Drive backed off from the stand causing approximately 1 bbl of mud to spill to the rig floor. The string was on bottom and the elevators were latched. It is unknown at this time the mechanism that caused the Top drive to back off the string. The spill has been reported to environmental and security. A PIR was sent out. Crew Chan e 18:00 19:30 1.50 10,530 10,197 INTRM1 DRILL TRIP NP POOH from 10530' - 10197'. Check all connections for torque, and any damage. It was observed that the connection on the bottom of the stand we were drilling on had also been backed out 4 -5 threads. Inspect Saver Sub on Top drive. threads indicated very minor gaulding, decision to change out saver sub. Install TIW valve in strip .Lower strip into sli s. 19:30 21:30 .2.00 10,197 10,197 INTRM1 RIGMN RGRP T PJSM with crew. Discuss Safety Issues and procedure for replacing Top Drive Saver Sub. Discuss working in a timely manner to minimize the time that the drill string was not being moved. Change out saver sub with no issues. Move drill string 2 times while chap in out saver sub. 21:30 22:00 0.50 10,197 10,530 INTRM1 DRILL TRIP NP Trip in hole from 10197' - 10530'. Observe good hole conditions and ro er hole fill. 22:00 22:30 0.50 10,530 10,530 INTRM1 DRILL CIRC P Establish circulation and obtain parameters. Obtain survey with pumps @715GPMs-1900 PSI. UP WT= 220K, SO WT = 120K. Orient to begin drillin . ~~..~~ ...~®~ ~~ .,....~.~~ _ ~____.®em___ P~ x~ ~~ ~sf Time Lo s Date From To Dur th E. De th Phase Code Subcode T M 07/23/2006 _ 22:30 00:00 1.50 10,530 10,540 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 10530' - 10540 (10') TVD = 3716'. UP WT = 220K, SO WT = 120K, ROT WT = 160K. 3-10K WOB. Pumps @ 650 GPM's - 1750 PSI. ART = 0.0 HRS. AST = .34 HRS. Total Bit HRS = 18.60 .Total Jar HRS = 85.56 Max Gas observed = 81.3 Units. ECD's 9.66 PPG. Survey @ 10531' MD, INC = 84.00 DEG, AZ = 171.54 DEG, TVD = 3715'. Observed difficulty in Sliding with little or no ROP. Trouble holding toolface &stallin motor. 07/24/2006 00:00 06:00 6.00 10,540 10,653 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 10540' - 10653 (113') TVD = 3728'. UP WT = 220K, SO WT = 120K, ROT WT = 160K. 5-15K WOB. Pumps @ 667 GPM's - 1670 PSI. ART = .28 HRS. AST = 1.92 HRS. Total Bit HRS = 20.80 .Total Jar HRS = 87.72 Max Gas observed = 64 Units. ECD's 9.7 PPG. Survey @ 10626' MD, INC = 83.55 DEG, AZ = 175.84 DEG, TVD = 3725.33'. Observed difficulty in Sliding .Trouble holding toolface & stallin motor. Crew Chan e 06:00 09:45 3.75 10,653 10,743 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 10653' - 10743' (90') TVD = 3739'. UP WT = 236K, SO WT = 115K, ROT WT = 166K. 10-15K WOB. 80 RPM's. Torque on bottom = 18-22K, Torque off bottom = 16-18K. Pumps @ 650 GPM's - 1750 PSI. ART = .32 HRS. AST = .73 HRS. Total Bit HRS = 21.85 .Total Jar HRS = 88.81 Max Gas observed = 113.7 Units. ECD's 9.84 PPG. Survey @ 10719' MD, INC = 81.95 DEG, AZ = 176.03 DEG, TVD = 3737.08'. Observed difficulty in Sliding .Trouble holding toolface & stalling motor. Strin han in u . 09:45 10:00 0.25 10,743 10,743 INTRM1 DRILL SFTY P PJSM with crew. Diwscuss Safety Issues and rocedure for BROOH. 10:00 12:00 2.00 10,743 10,106 INTRMI DRILL REAM P BROOH from 10743' - 10106' with pumps @ 750 GPMs - 2120 PSI. 60 RPM's, ECD = 9.87 PPG, Torque = 14-15K. ROT WT = 165K. Back ream rate = 10 -FUMin. 12:00 13:30 1.50 10,106 9,920 INTRM1 DRILL REAM P Continue BROOH from 10106' - 9920' with pumps @ 750 GPMs - 2050 PSI. 60 RPM's, ECD = 9.87 PPG, Torque = 14-15K. ROT WT = 155K. Back ream rate = 10 -FUMin. 13:30 14:00 0.50 9,920 10,743 INTRM1 DRILL TRIP P Monitor well -static. Trip in hole from 9920' - 10743'. Observe good hole conditions and ro er hole fill. ®m ~.~_e ®.m __ ~ Time Logs _ Date From To Dur th E. De th Phase Code Subcode OM 07/24/2006 14:00 18:00 4.00 10,743 10,873 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 10743'. - 10873 (130') TVD = 3760'. UP WT = 236K, SO WT = 112K, ROT WT = 160K. 10-15K WOB. 80 RPM's. Torque on bottom = 18-22K, Torque off bottom = 16-18K. Pumps @ 650 GPM's - 1750 PSI. ART = .31 HRS. AST = 1.23 HRS. Total Bit HRS = 23.39 .Total Jar HRS = 90.35 Max Gas observed = 114 Units. ECD's 9.76 PPG. Survey @ 10815' MD, INC = 81.10 DEG, AZ = 177.64 DEG, TVD = 3751.22'. Observed difficulty in Sliding .Trouble holding toolface & stalling motor. Strin han in u .Crew Chan e 18:00 19:30 1.50 10,873 10,930 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 10873' - 10930' (57') TVD = 3760'. UP WT = 220K, SO WT = 115K, ROT WT = 165K. 5-30K WOB. 80 RPM's. Torque on bottom = 14-28K, Torque off bottom = 15-20K. Pumps @ 650 GPM's - 1800 PSI. ART = .14 HRS. AST = .22 HRS. Total Bit HRS = 23.75 .Total Jar HRS = 90.71 Max Gas observed = 25 Units. ECD's 9.90 PPG. Survey @ 10911' MD, INC = 80.58 DEG, AZ = 178.85 DEG, ND = 3766.48'. Observed difficulty in Sliding .Trouble holding toolface & stalling motor. String han in u . 19:30 20:15 0.75 10,930 10,770 INTRM1 DRILL REAM P BROOH from 10930' - 10770'. Pumps @ 750 GPMs - 1850 PSI. ROT WT = 165K. Torque = 13 -14K. Discuss options with town engineer. Decision to continue rotate 30-50' more in the sand to verify "wet" sand as per rig Geolo ist. 20:15 20:30 0.25 10,770 10,930 INTRM1 DRILL TRIP P Trip in hole from 10770' - 10930'. (160'). Observe hole in ood condition. Time Logs date From To Dur pth E. De th Phase Code Subcode OM 07/24/2006 20:30 21:45 1.25 10,930 11,004 INTRM1 DRILL DDRL P Continue Directional Drill 12 1/4" Hole from 10930' - 11004' (74') TVD = 3789'. UP WT = 220K, SO WT = 115K, ROT WT = 165K. 5-30K WOB. 80 RPM's. Torque on bottom = 15-28K, Torque off bottom = 13-14K. Pumps @ 650 GPM's - 1850 PSI. ART = .27 HRS. AST = 0 HRS. Total Bit HRS = 24.02 .Total Jar HRS = 90.98 Max Gas observed = 48 Units. ECD's 9.78 PPG. Survey @ 10959' MD, INC = 79.99 DEG, AZ = 178.89 DEG, TVD = 3774.64'. Observed difficulty in Sliding .Trouble holding toolface & stalling motor. String hanging up. Rotated the last 74'. Projected Survey @ bit = 11004' MD, 3781.16 TVD, 80 Deg INC. 178.90 Deg. AZ. Verified Sand NOT wet @ 30 OHMS. ` 21:45 22:15 0.50 11,004 11,004 INTRM1 DRILL CIRC P Pump 40 BBL Hi Viscweighted sweep @ 750 GPM - 1850 PSI. Reciprocate & Rotate dril string while sweep around bit. 22:15 00:00 1.75 11,004 10,100 INTRM1 DRILL REAM P BROOH from 11004' - 10100'. back ream rate @ 60 RPM's , 750 GPMs - 1800 PSI. 177 SPM. ROT WT = 160K. 30 -40 Ft/ min 07/25/2006 00:00 06:00 6.00 10,100 7,535 INTRM1 DRILL REAM P Continue BROOH from 10100' - 7535'. Back ream rate @ 60 RPM's , 750 GPMs - 1800 PSI. 177 SPM. ROT WT = 160K. 30 -40 Ft/ min. Work through tight spot @ 8460' until cleaned up. Observed Drill Pipe torque excessive with 30 - 60K FT/LBS to breakout connections starting on stand #87 in the hole. Continue obtain T & D parameters as per rig engineer every 5 stands in o en hole. Crew Chan e 06:00 12:00 6.00 7,535 5,552 INTRM1 DRILL REAM P Continue BROOH from 7535' - 5552'. Back ream rate @ 60 RPM's , 750 GPMs - 1750 PSI. 177 SPM. ROT WT = 155K. 30 -40 FU min, slowing to 20 minutes per stand as we observed ECD's @ 10.75 PPG. Observed Drill Pipe torque excessive with 30 - 60K FT/LBS to breakout connections starting on stand #87 in the hole. Continue obtain T & D parameters as per rig engineer every 5 stands in open hole. ~. ~ _ em~- ~ _ ® - - - ~~ ~_~ ~ ~ ~a ~s~ ~ .e~ ~ mm~ .~_~ ~~.....,,,r< ~. _ ~ .-.. ~,. m Time Logs s~ Date From To Dur th E. De th Phase Code Subcode T OG M 07/25/2006 12:00 13:15 1.25 5,552 5,430 INTRM1 DRILL REAM P Continue BROOH from 5552' - 5430'. Back ream rate @ 60 RPM's , 560 GPMs - 1600 PSI. ROT WT = 130K. 30 -40 Ft/ min, slowing to 20 minutes per stand as we observed ECD's @ 10.75 PPG. Observed hole unloading and plugging up flow line & possum belly. Continue obtain T & D parameters as per rig engineer every 5 stands in o en hole. 13:15 14:00 0.75 5,430 5,430 INTRM1 DRILL REAM P Shut down BROOH. Clean possum belly in pits and clean out flowline. Observed hole unloading bringing excessive cuttings to surface. Continue to slowly pump, reciprocate & rotate drill strin . 14:00 16:30 2.50 5,430 4,100 INTRM1 DRILL REAM P Continue BROOH from 5430' - 4100' inside shoe @ 4151' MD.. Back ream rate @ 60 RPM's , 750 GPMs - 1380 PSI. ROT WT = 138K. UP WT = 140K, SO WT = 115K. 30 -40 Ft/ min, Observed hole continuing to unload. Continue obtain T & D parameters as per rig engineer every 5 stands in open hole. 16:30 17:30 1.00 4,100 4,100 INTRM1 DRILL CIRC P Pump 40 BBL Hi Visc 10 PPG weighted sweep @ 800 GPMs - 1350 PSI. U,P WT = 128K, SO WT = 112K, ROT WT = 125K. Pump 2 bottoms up plus until hole cleaned up. Observe Cement blocks, Large Clay balls, and Coal pieces in cuttings when Sweep hole. Reciprocate & rotate drill string while pumping. Hole cleaned up well, with ECD's back down to 9.89 PPG. 17:30 17:45 0.25 4,100 4,100 INTRMI DRILL OWFF P Monitor well -static. Pump dry job, & blow down To Drive & lines. 17:45 18:00 0.25 4,100 3,626 INTRM1 DRILL TRIP P POOH on elevators from 4100' - 3626'. Observed ro er hole fill. Crew Chan e 18:00 18:30 0.50 3,626 2,317 INTRM1 DRILL TRIP P Continue POOH on elevators from 3626' - 2317'. Top Drive bales were extended while lowering to rig floor, contacted windwall on back of derrick. Damage to windwall. Shut down o eration 1845 HRS. Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 07/25/2006 18:30 00:00 5.50 2,317 2,317 INTRMI RIGMN RGRP T Shut down tripping operations. Inspect damage to windwall, ensure well secure installing TIW valve. Notify ALL HSE reps, Safety reps, and Field Supt. Rig engineer, and Team Leader. Notify 1J Pad operator & CPF3 Supervisor. PJSM with entire Rig team. Discuss safety issues, potential risks, and procedure for safely removing damaged windwall from derrick. Rig up, tie on and lower windwall to catwalk on backside of of derrick on top of doghouse. Secure with chains for future removal and safely out of way. Perform Derrick inspection. Remove Pin Kit from derrick. 07/26/2006 00:00 02:00 2.00 2,317 2,317 INTRM1 DRILL TRIP T Continue perform Derrick Inspection. Inspect Top Drive. Remove & inspect Link Tilt pins for cracks or fatigue. Change out 5" Drill pipe elevators. Remove old set from service for ins ection. 02:00 02:15 0.25 2,317 2,317 INTRM1 DRILL SFTY P PJSM with rig crew & Sperry Sun reps. Discuss Safety Issues and procedure for POOH with 20 Stands of Drill pipe & Lay down BHA. Discuss removing Nuclear sources. Also monitor well -static. No fluid lost or ained while shut down. 02:15 03:30 1.25 2,317 413 INTRM1 DRILL TRIP P Continue POOH on elevators from 2317' - 413'. Observe ro er hole fill. 03:30 04:00 0.50 413 0 INTRM1 DRILL PULD P Stand back 5" HWDP with Dailey Drillin Jars 194.26' . 04:00 04:15 0.25 0 0 INTRM1 DRILL SFTY P Held PJSM with crew & Sperry Sun MWD reps. Discuss Safety issues and procedure for laying down MWD assembly. Discuss Safety procedure for handlin Nuclear sources in BHA. 04:15 04:30 0.25 0 0 INTRM1 DRILL PULD P Stand back 3 - 8" Non Mag Flex Drill Collars (93.03').Breakout & lay down 8" Non Ma Float Sub 2.42' . 04:30 05:00 0.50 0 0 INTRM1 DRILL PULD P Remove Nuclear sources from MWD assembly. Load in container & secure same. 05:00 06:00 1.00 0 0 INTRM1 DRILL PULD P Plug in and download MWD assembly. 06:00 07:15 1.25 0 0 INTRM1 DRILL SFTY P Perform Safety Stand Down with entire Rig 15 Rig Team, HSE reps, and CPAI Re sand all Third a Vendors. 07:15 07:30 0.25 0 0 INTRM1 DRILL SFTY P PJSM with crew. Discuss safety issues and procedure for laying down BHA. ___. _ ~~~ ~._ ~_.me ~_~ ~ _~ ~~~_._._.~e®, _ ~ 5 ~ Time Logs ~ Date From To Dur th E. De th Phase Code Subcode CM 07/26/2006 07:30 08:00 0.50 0 0 INTRM1 DRILL PULD P Continue Breakout & lay down 8" Neutron density / CTN (37.69'), 8" MPT Pulsar (11.19'), 12 1/4" Security FSF2663 bit with 8 x 16's for jet = TFA of 1.571 sq. in. (1.23'), 8" Sperry Drill lobe 4/5 - 5.3 stage with a 1.5 degree bend in motor. (28.68'), 8" Integral Blade Stabilizer (7.02'), 8" Non Mag crossover sub (1.32'), 8" Directional (9.18'), and 8" Gamma /Res/PWD/ HCIM (27.80'). Inspect & Gauge bit to 1 /4/BT/G/X/3/ST/TD 08:00 08:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM with crew. Discuss making up BHA # 5, hole opener assembly. Clean & clear Ri Floor. Pull Tools to floor. 08:15 10:45 2.50 0 771 INTRM1 DRILL PULD P Make up BHA #5. Make up 12 1/4" Hole opener (7.91'), Bit Sub with ported float (3.01'), 1 -Non MAg Flex Drill Collar (31.04'), Integral Blade centralizer (5.40'), 2 -Non MAg Flex Drill Collars 961.99'), Dailey Jars 40.27'), 2 - jnts 5" HWDP (61.57'), Ghost Reamer {6.00'), and 18 -jnts 5" HWDP 553.72' .Total BHA = 770.91'. 10:45 12:00 1.25 771 3,620 INTRM1 DRILL TRIP P Trip in hole with BHA #5 from 771' - 3620'. Fill drill string every 25 stands. obtain T & D parameters as per rig engineer, every 10 stands in cased hole. 12:00 18:00 6.00 3,620 9,500 INTRM1 DRILL TRIP P Continue trip in hole with BHA #5 from 3620' - 9500'. Fill drill string every 25 stands. Obtain T & D parameters as per rig engineer, every 5 stands in open hole. Starting at stand # 78, check all breaks in 5" Dp as they were overtorqued and were breaking out at up to 60K FUlbs. Dope each connection and. remake to correct make u for ue. Crew Chan e 18:00 20:00 2.00 9,500 10,880 INTRM1 DRILL TRIP P Continue trip in hole with BHA #5 from 9500' - 10880'. Observe no hole issues in open hole tripping to bottom. Fill drill string every 25 stands. Obtain T & D parameters as per rig engineer, every 5 stands in open hole. Continue check all breaks in 5" DP as they were overtorqued and were breaking out at up to 60K FUlbs. Dope each connection and remake to correct make u for ue. ... ~e~ ___ mm~m~ __...---_____.. ____m~__~~~ ~.~. s~ ~.~ ~ .~~ m..~ _. ~ .w_~_®~~..~ _ _~~._.._. . ~ . Time Logs Date From To Dur eth E. De th Phase Code Subcode ._ ~M 07/26/2006 20:00 00:00 4.00 10,880 10,880 INTRM1 DRILL CIRC _ P _ Establish circulation @ 850 GPMs- 2500 PSI. Observed shaker screens blinding off with UGNU tar, mud running over. Change out shaker screens to accomodate flow rate. reciprocate & rotate drill string while pump 40 BBLS of 9.3 PPG Hi vise weighted sweep. UP WT = 195K, SO WT = 105K, ROT WT = 145K. Torque = 5-8K. Circulate sweep out plus bottoms u to clean hole. 07/27/2006 00:00 00:15 0.25 10,880 10,880 INTRM1 DRILL OWFF P Monitor well -static 00:15 00:45 0.50 10,880 10,464 INTRM1 DRILL TRIP P POOH with 5 stands on elevators from 10880' - 10464'. Observe good hole conditions and proper hole fill. Obtain SLM on Drill i e. 00:45 01:15 0.50 10,464 10,464 INTRM1 DRILL TRIP P Monitor well -static. Pump dry job 2 ounds over mud wei ht. 01:15 05:15 4,00 10,464 4,100 INTRM1 DRILL TRIP P Continue POOH on elevators. Observing good hole conditions with proper hole fil from 10464' - 4100'. Inside shoe. Obtain SLM on Drill pipe, and T & D parameters as per rig engineer on every 5 stands in open hole, eve 10 stands in cased hole. 05:15 06:00 0.75 4,100 4,100 INTRM1 DRILL CIRC P Establish Circulation. Pump Hi Visc weighted sweep and follow with 40 BBL Steel Lube pill. Pumps @ 850 GPMs - 1850 PSI. Reciprocate & rotate drill string. UP WT = 152K SO WT = 102K ROT WT = 122K with 125 RPM's. Crew Chan e. 06:00 07:45 1.75 4,100 4,100 INTRM1 DRILL CIRC P Continue Pump Hi Visc weighted sweep and follow with 40 BBL Steel Lube pill. Pumps @ 850 GPMs - 1850 PSI. Reciprocate & rotate drill string. Up WT = 140K, SO WT = 126K. Slow pump rate as sweep returned to 350 GPM's - 300 PSI as steel lobe pill ran over shaker screens. 07:45 08:00 0.25 4,100 4,100 INTRM1 DRILL OWFF P Monitor well -static. Pump Dry Job. Blow down To Drive & lines. 08:00 09:45 1.75 4,100 820 INTRM1 DRILL TRIP P Continue POOH from 4100' - 820'. 09:45 10:45 1.00 820 0 INTRM1 DRILL PULD P Breakout & lay down Ghost Reamer (6.00'), and 18 - jnts 5" HWDP 553.72' . 10:45 11:00 0.25 0 0 INTRM1 RIGMN SFTY P PJSM with crew. Discuss Safety Issues and procedure for slipping and cuttin drillin line. 11:00 12:00 1.00 0 0 INTRM1 RIGMN SVRG P Slip & cut 153' of drilling line. Inspect & service drawworks and To Drive. ~ ~'~cae ~ ~ ~~ ~m~~ _®_ , . ~ ~_®m _®~ ®®~ ~ . , ' . ® ~m~~_ m ._._~ ..~ ,,. _ Time Logs_ Date From To Dur th E. De th Phase Code Subcode T OM 07/27/2006 12:00 13:30 1.50 0 0 INTRMI DRILL PULD P Continue breakout & lay down 12 1/4" Hole opener (7.91'), Bit Sub with ported float (3.01'), 1 -Non Mag Flex Drill Collar (31.04'), Integral Blade centralizer (5.40'), 2 -Non Mag Flex Drill Collars 961.99'), Dailey Jars 40.27'), 2 - jnts 5" HWDP (61.57'), Total BHA = 770.91'. 13:30 14:15 0.75 0 0 INTRM1 CASIN( RURD P Rig up to run 9 5/8" casing. Rig up running tool and RIH to pull wear bushing. Lay down running tool.Pull centralizers to ri floor. 14:15 14:30 0.25 0 0 INTRM1 CASIN( SFTY P Held PJSM with rig crew, GBR casing reps. Discuss safety issues, hazards, and procedure for rigging up and runnnin 9 5/8" casin . 14:30 17:30 3.00 0 0 INTRM1 CASIN( RURD P Continue rig up to run 9 5/8" Casing. Pull all running equipment to rig floor and rig up as per GBR reps. Pull centralizers to floor. Rig down short bales on top drive, and make up long bales. Pull cement head to rig floor. Make up Franks Fill -Up tool. Check all casin &runnin order. 17:30 18:00 0.50 0 75 INTRM1 CASIN( SFTY P Pick up 9 5/8" Casing Shoe joint. RIH. Make up joint # 2 as per detail with baker loc in threads. Crew Chan e 18:00 19:00 1.00 75 110 INTRM1 CASIN( RNCS P Make up joint # 3 with Float collar. Fill casin and check floats. 19:00 19:30 0.50 110 110 INTRM1 CASIN( RNCS P Install Franks fill up tool. Break circulation. Circulate to check floats pumping 25 BBLS as per Co. Rep. Pressure = 300 PSI 5 BPM 19:30 20:00 0.50 110 110 INTRM1 CASIN( SFTY P Held PJSM with new crew on tour. Discuss safety issues and hazards when running casing. Discuss rocedure for runnin casin . 20:00 00:00 4.00 110 2,632 INTRM1 CASIN( RNCS P Continue RIH picking up 9 5/8" casing from pipe shed. RIH from 110' - 2632'. Install tandem Rise centralizers on each joint, with 2 TR centralizers on second joint with stop rings, 10' above collar and 10 'below collar as planned. Make u for ue = 9000 FUlbs. 07/28/2006 00:00 02:00 2.00 2,632 4,150 INTRM1 CASIN( RNCS P Continue run 9 5/8" casing from 2632' - 4150. Shoe depth. Install tandem Rise centralizers on each joint to joint # 58. Install Bow Spring Centralizer on joints 59 - 108. Obtain T & D parameters as per rig engineer. Fill each joint for 10 joints, and circulate down next joint while RIH slow. Make up torque = 9000 FUlbs. ~~~s~r ;~S c~~ ~~ Time Logs Date From To Dur pth E De th Phase Code Subcode OM 07/28/2006 02:00 03:00 1.00 4,150 4,150 INTRM1 CASIN( CIRC P Circulate bottoms up @ 5 BPM - 600 PSI. Reciprocate casing string while pumping. Mud wt = 9.0 PPG, Visc = 50, YP = 20 Bring more centralizers to ri floor while circulatin . 03:00 06:00 3.00 4,150 6,000 INTRM1 CASIN( RNCS P Continue run 9 5/8" casing from 4150' - 6000'. Install Bow Spring Centralizer on joints 59 - 108.Obtain T & D parameters as per rig engineer. Make up torque = 9000 FUlbs. Fill each joint for 10 joints, and circulate down next 2 'oints while RIH slow. 06:00 15:00 9.00 6,000 10,823 INTRM1 CASIN( RNCS P Continue run 9 5/8" casing from 6000' - 10823'. Install Lodrag Roller Centralizers on each joint from joint 180 - 283, floating. Ran a total of 285 joints. Used a total of 58 Tandem Rise Centralizers, 50 Bowsprings, and 2 stops. Used a total of 104 Lodrag roller centralizers. Obtain T & D parameters as per rig engineer. Make up torque = 9000 FUlbs. Fill each joint for 10 joints, and circulate down next 2 joints while RIH slow. 15:00 15:15 0.25 10,858 10,858 INTRM1 CASIN( CIRC P Circulate with Franks fill up tool @ 44 SPM - 340 PSI. UP WT = 270K, SO WT = 105K. Pump 70 BBLS while reciprocate casing string from 10858 - 10838 30'. 15:15 16:30 1.25 10,858 10,858 INTRM1 CASIN( RURD P Rig down Franks Fillup tool. Install Dowell Cement Head & Lines. Dowell Cementer loaded plugs. PU WT = 310K, SO WT = 140K. 16:30 21:00 4.50 10,858 10,858 INTRM1 CEMEf~ CIRC P Circulate & condition mud to pre cement properties of 9.0 PPG, Visc = 45, PV = 8, YP = 19, with Gels @ 7/10/12. Final pump pressure @ 170 PSI with 65 SPM. Reciprocate Casing `~~' String in 30' increments. UP WT = 265K, SO WT = 135K. Held PJSM with crew, Dowell cementers and all Truck Drivers. Discuss safety issues and procedure for pumping entire cement job. Designate a Spill Cham ion. P~c~e Time Logs Date From To Dur nth E. De th Phase Code Subcode OM 07/28/2006 21:00 23:00 2.00 10,858 10,858 INTRM1 CEME~ CIRC P Turn Rig over to Dowell Cementers @ 2100 HRS. Pump 10 BBLS of 8.35 PPG CW 100 @ 2.5 BPM - 265 PSI. SHut down. Pressure test lines to 3500 PSI. Good test. Continue pump 406BLSofCW100@5.56PM-320 PSI. Pump 75 BBLS of 11.0 PPG Mud push II Spacer @ 5 BPM - 315 PSI. Drop Botom plug @ 21:44 HRS. Batch Mix & pump 12.5 PPG Deep Crete Cement @ initial pump pressure of 315 PSI @ 5.5 BPM. Pump 299.7 BBLS of cement as planned. Pump 5 BBIs of water to flush lines. Reciprocate Casing String with UP WT = 270K, SO WT = 145K 23:00 00:00 1.00 10,858 10,858 INTRM1 CEME~ DISP P Turn over to Rig pumps. Pump 8.9 PPG MOBM at 6.5 BPM to catch cement and continue @ 6.5 BPM to displace 450 BBIs of 813 planned. Reciprocate casing String UP WT = 255K, SO WT = 140K. 07/29/2006 00:00 01:00 1.00 10,858 10,853 INTRM1 CEME~ DISP P Continue displace well with 8.9PPG MOBM @ 6.5 BPM -with pressure to 750 PSI at 7970 SPM. Slow pumps to 3 BPM - 610 PSI. Observe bumping plug with 8091 Strokes. 813 BBLS pumped in displacement. Pressure to 1100 PSI to hold floats. Pipe movement stopped at 7100 strokes with observed UP WT 240K, SO WT 80K and SHoe depth @ 10853'. CIP 0100 HRS. 01:00 01:30 0.50 10,853 10,853 INTRM1 CEMEt~ DISP P Hold floats for 10 minutes. Bleed pressures and check floats. Held ood. 01:30 02:00 0.50 10,853 10,853 INTRM1 CEMEf~ RURD P Rig down cement head & lines. 02:00 04:15 2.25 10,853 10,853 INTRM1 WELCT NUND P Nipple down BOP stack & lift. Rig up & set 9 5/8" emergency slips with 245K pulled on casing as per Vetco Gray reps. Cut off jint = 26.94'. (#284). Rig up hose to vac out inside of casing down below casin head. 04:15 06:00 1.75 10,853 10,853 INTRM1 CASIN( OTHR P Rig Up WACHS pneumatic casing cutter & cut casing as per VETCO GRAY reps. Dress top of 9 5/8" casing stub. 06:00 08:30 2.50 0 0 INTRM1 WELCT NUND P Nipple up BOP stack on casing head. 08:30 09:00 0.50 0 0 INTRM1 WELCT BOPE P Rig up test pump. Test 13 3/8" x 9 5/8" packoff to 2500 PSI as per Vetco Gray reps. Hold pressure 10 minutes, witnessed b Co. Re . 09:00 10:00 1.00 0 0 INTRM1 WELCT BOPE P Rig down long bales on Top Drive. install short bales. C7.~C.~~ II ~~'Y ~.y i ~ «e.. e,. Ase ..tee .«. . m~ ~ .,~.® .» w.,,~,,,.0..~-~....~«~..-... . . . . ®m~„se~,,,.m- ®~ .u . . ~ Time Lo s Date From To Dur ~ th E. De th Phase Code Subcode OM ~, 07/29/2006 10:00 12:00 2.00 0 0 INTRM1 WELCT BOPE P Rig up to test BOP's with chart recorder. Make up test plug & install same. Ri u lines. 12:00 17:00 5.00 0 0 INTRM1 WELCT BOPE P Test 13-5/8" BOPE. Annular w/ new element, upper pipe rams (3-1/2" x 6"), blind rams, floor safety valves, upper and lower IBOP valves on top drive, HCR and manual valves on kill and choke lines, choke manifold. All test @ 250 psi low f/ 5 min, then 3500 psi high f/ 5 min. Perform accumulator test: 200 psi build up in 41 seconds, full pressure in 3 min 54 sec. Chart test. Witness of test by AOGCC ins ector John Cris . 17:00 18:00 1.00 0 0 INTRM1 WELCT BOPE P Rig down all test equipment. Crew Chan e 18:00 18:45 0.75 0 0 INTRM1 WELCT BOPE P Continue Rig down all test equipment. Pull test lu & la down same. 18:45 19:15 0.50 0 0 INTRM1 WELCT NUND P Install wear bushing & RILDS. Record dimesions for WB. 13 3/8" OD x 9" ID. 38 1/4" in len th. 19:15 20:45 1.50 0 0 INTRM1 RIGMN RGRP T Inspect & trouble shoot Top Drive shot in assembl .Checked out ood. 20:45 22:00 1.25 0 0 INTRM1 DRILL PULD P Pull all equipment to rig floor. Lift subs, crossovers etc... Change out elevators to 3 1/2" for BHA makeup. Held PJSM with crew & Sperry Sun reps. Discuss Safety Issues and procedure for makin u BHA # 6. 22:00 23:15 1.25 0 99 INTRM1 DRILL PULD P Make up BHA #6. Make up 6 3/4" Smith PDC bit MDT52 with 6 x 13's jets for a TFA of .778 Sq. In.(.84'), 5" Sperry Drill Lobe 6/7 -6.0 stg with ABI (32.57'), 4 3/4" Non MAg float sub with ported float (2.35'), 4 3/4" Welded Blade Stabilizer 94.59'), 4 3/4" Non MAg Termination sub (1.85'), 4 3/4 MWD RES/Gamma Tool (24.07'), MWD Directional (8.41'), 4 3/4" PWD 10.78'), and 4 3/4" TM -HOC (10.86') and crossover sub (2.99'). Make up 1 - Non MA Flex drill Collar 31.00' . 23:15 00:00 0.75 99 99 INTRM1 DRILL OTHR P Turn on battery as per MWD rep, plug in and u load MWD. 07/30/2006 00:00 00:45 0.75 99 99 INTRM1 DRILL OTHR P Make Top Drive Connection. Pertorm Shallow pulse test @ 90'. Pumps @ 280 GPM - 1310 PSI. Good test. 00:45 01:30 0.75 99 192 INTRM1 DRILL PULD P Continue Make up BHA #6. Make up 1 joint of 4" HWDP (30.69'), DNT Dailey Drilling Jars (31.96'), and 1 Joint od 4" HWDP (30.68'). Change out elevators for picking up 4" DP. Discuss Safety issues, hazards and procedure for icki u DP from Shed. ~~.~_..~~~_.. a~~ ~~ ~ ~~ ~3 Time Logs _ Date From To Dur .z th E. Depth Phase Code Subcode OM 07/30/2006 01:30 02:30 1.00 192 1,409 INTRM1 DRILL PULD P RIH with 11 stands of 4" DP from Derrick (1217.05'). Continue pick up 4" drill pipe from pipe shed for space out of A itator & Shock Sub. 02:30 03:30 1.00 1,409 1,964 INTRM1 DRILL PULD P Make up crossover (2.97'), Agitator (8.77'), Shock Tool (7.02'), Crossover (3.00'), 9 -joints of 4" DP (281.79'), 4 3/4" DNT Dailey Drilling Jars (32.08), 3 - joints of 4" DP (94.03'), and 4 3/4" Dailey Accelerators (32.09'). Total BHA = 1964.66' 03:30 06:00 2.50 1,964 4,777 INTRMI DRILL PULD P Continue trip in hole with BHA #6, from 1964' - 4777' picking up singles of 4" Drill pipe from Shed. Drift all DP to 2.35". Crew Chan e. 06:00 08:00 2.00 4,777 6,469 INTRM1 DRILL PULD P Continue trip in hole with BHA #6, from 4777' - 6469 picking up singles of 4" Drill pipe from Shed. Drift all DP to 2.35". 08:00 08:45 0.75 6,469 6,469 INTRM1 DRILL TRIP P Fill drill string. Observe proper hole fill. Pulse test MWD with pumps @ 200 GPM's - 1650 PSI. UP WT = 130K, SO WT = 99K. SIMOPS -working on crown section li hts. 08:45 10:45 2.00 6,469 6,469 INTRM1 RIGMN RGRP T Work on & repair lights for crown & top section. 10:45 11:30 0.75 6,469 7,010 INTRM1 DRILL TRIP P Change out elevators to 5". Trip in hole with 5" drill pipe singles from pipe shed from 6469' - 7010'. 541' . 11:30 12:00 0.50 7,010 6,469 INTRM1 DRILL TRIP P POOH back to 6469' racking back 5" drill i e in off drillers side of derrick. 12:00 12:15 0.25 6,469 6,469 INTRM1 DRILL TRIP P Clean & clear floor area of MOBM. 12:15 13:15 1.00 6,469 9,983 INTRM1 DRILL TRIP P Trip in hole with 5" Drill pipe from derrick with super sliders installed from 6469' - 9983'. Note: Decision to reposition super sliders deeper in hole as er en ineer. 13:15 13:30 0.25 9,983 9,983 INTRM1 DRILL TRIP P Transfer remaining stands of 5" DP in derrick for repositioning super sliders on drill string. Double check all drill strin tallies. 13:30 14:15 0.75 9,983 10,776 INTRM1 DRILL TRIP P Continue trip in hole with BHA #6 from 9983' - 10745'. (762'). MAke Top drive connection. Wash down to 10776' tagging float equipment. UP WT = 170K, SO WT = 123K, ROT WT = 133K. Torque @ 7-8K. RPM's = 40. Pum sat 72 SPM - 3300 PSI. 14:15 16:30 2.25 10,776 10,776 INTRMI CASIN( CIRC P Circulate & condition mud to 8.68 PPG, YP 19, Visc = 67. Gels - 15/24. Pumps @ 300 GPM's, 3280 PSI. UP WT = 170K, SO WT = 123K, ROT WT = 133K. 16:30 17:15 0.75 10,776 10,776 INTRM1 CASIN( DHEQ P Rig up lines and equipment for casing test. j._____._ _~ ~ ®® ~ ~ ~-ew~ e~ ~ E-».~.,....,...,.......,m,,, sm._d_ _....,........,m...s® .m„,e - - me® ,....... ....m~~_.,....„,_......,..n _~»..........® ~_ - e.._~_....A.,,1 Time Logs Date From To Dur eth E_ .Depth Fhase Code Subcod~ iFOM _ 07/30/2006 17:15 18:00 0.75 10,776 10,776 INTRM1 CASIN( DHEQ P Pressure test 9 5/8" casing to 3000 PSI. Hold test for 30 minutes, record on chart. Observe loss of 140 PSI in 30 minutes. Pumped 113 strokes, bled back 11.3 BBLS. Test mud wt = 8.65 PPG. Crew Chan e. 18:00 18:45 0.75 10,776 10,776 INTRMI CASIN( DHEQ P Bleed pressure. Rig down test e ui ment. Monitor well -static. 18:45 19:00 0.25 10,775 10,775 INTRM1 CEME~ DRLG P Make Top Drive connection. Wash down to Float collar. Tagged Float collar @ 10775'. Drill Float equipment & Shoe track down to 10775', continuing to drill 25' of new hole to 10882'. Pumps @ 300 GPM - 3420 PSI. 2-5K WOB, 30 RPM's with 7-9K for ue. 19:00 19:15 0.25 10,775 10,785 INTRM1 CEMEf~ DRLG P Continuing to drill shoe track cement from 10775' - 10785'. Pumps @ 300 GPM - 3420 PSI.2-5K WOB, 30 RPM's with 7-9K for ue. 19:15 19:45 0.50 10,785 10,785 INTRM1 DRILL CIRC T Lost MWD signal. Trouble shoot problems, finally switching to Pump #2. MWD signal returned to normal. Inspection of pump #1 indicated failed valve guide inserts & 1 valve. Cleaned suction screens. 19:45 22:45 3.00 10,856 10,882 INTRM1 CEMEf~ DRLG P Continue drilling shoe track cement from 10785' - 10856', tagged Shoe @ 10856' DPM. Drill cement and new hole from 10856' - 10882'. Pumps at 300 GPM's - 3420 PSI. 3100 PSI off bottom. 2-5K WOB, 7-9K torque on bottom. 22:45 00:00 1.25 10,882 10,882 INTRM1 DRILL CIRC P Circulate & condition mud to 8.68 PPG, YP 19, Visc = 67. Gels - 15/24. Pumps @ 300 GPM's, 3280 PSI. UP WT = 170K, SO WT = 123K, ROT WT = 133K. 30 RPM's. 10856' MD. TVD = 3758'. Circulated 650 BBLS. 07/31/2006 00:00 01:00 1.00 10,882 10,882 INTRM1 DRILL CIRC P Continue Circulate & condition mud to 8.68 PPG, YP 19, Visc = 67. Gels - 15/24. Pumps @ 300 GPM's, 3280 PSI. UP WT = 170K, SO WT = 123K, ROT WT = 133K. 30 RPM's. 10856' MD. TVD = 3758'. Circulated 650 BBLS total.Reciprocate & rotate drill strin . 01:00 02:45 1.75 10,882 10,882 INTRM1 DRILL LOT P Rig up lines & valves to drill string & annulus to perform LOT. Pump @ .5 BPM to 52 strokes observing pressure break over @ 52 strokes with 1030 PSI. 10 minute shut in bled back to 850 PSI. Calculated MWE = 13.97 PPG. Record on chart. Rig down all e ui ment. ~~ee_ ~ ~ _ ~ -..~ ~._m .._...~__W ~. ~ ...._ __~... .,~ c~c~~ ~~ cat ~~ { . _~~ __a~. ~ ~° ~ - - _ r, . .._ ~.~_ ._._.~~ __... m _m~_ Time Logs _ Date__ From To Dur th E. De th Phase Code Subcode OM ~ 07/31/2006 02:45 03:00 0.25 10,882 10,882 INTRM1 DRILL CIRC P Make Top drive connection. Obtain parameters establishing circulation. Wlth bit below shoe, establish baseline ECD' at 280 GPM - 9.6 PPG. 8.65 Mud wt. 03:00 05:45 2.75 10,860 10,882 PROD1 DRILL DDRL P Troughing 6 3/4" production hole for sidetrack from 10860' - 10882'.MD. TVD = 3762'. 05:45 06:00 0.25 10,882 10,884 PROD1 DRILL DDRL P Directional Drill 6 3/4" production hole from 10882' - 10884'.MD. TVD = 3762'. UP WT = 185K, SO WT = 105K, ROT WT = 130K. 2-5K WOB. Pumps @ 300 GPM's -3420 PSI. ART = 0 HRS. AST = .32 HRS. Total Bit HRS = .32 .Total Jar HRS # 0043 = 45.35 HRS, Total Jar HRS #0019 = 136.09 HRS. Max Gas observed = 0 Units. ECD's 9.46 PPG. Survey @ 10882' MD, INC = 80.61 DEG, AZ = 180.16 DEG, TVD = 3761.83'. Observed bad detection for MWD with pump #1. Crew Chan e 06:00 12:00 6.00 10,884 11,217 PROD1 DRILL DDRL P Directional Drill 6 3/4" production hole from 10884' - 11217'.MD. TVD = 3764'. UP WT = 200K, SO WT = 99K, ROT WT = 132K. 5-10K WOB. RPM = 80. Pumps @ 275 - 300 GPM's - 3100 PSI. ART = .82 HRS. AST = 3.05 HRS. Total Bit HRS = 4.19 .Total Jar HRS # 0043 = 49.22 HRS, Total Jar HRS #0019 = 140.28 HRS. Max Gas observed = 30.01 Units. ECD's 9.75 PPG. Survey @ 11145' MD, INC = 93.39 DEG, AZ = 189.32 DEG, TVD = 3777.49'.Observed bad detection for MWD with um #1. 12:00 13:45 1.75 11,217 11,312 PROD1 DRILL DDRL P Directional Drill 6 3/4" production hole from 11217' - 11312'.MD. TVD = 3765'. UP WT = 200K, SO WT = 99K, ROT WT = 132K. 10-12K WOB. RPM = 80. Pumps @ 300 GPM's - 3380 PSI. ART = .66 HRS. AST = .37 HRS. Total Bit HRS = 5.22 .Total Jar HRS # 0043 = 50.25 HRS, Total Jar HRS #0019 = 141.31 HRS. Max Gas observed = 30.01 Units. ECD's 9.93 PPG. Survey @ 11239' MD, INC = 94.75 DEG, AZ = 184.44 DEG, TVD = 3770.82'.Observed bad detection for MWD with um #1. 13:45 14:45 1.00 11,312 11,312 PROD1 DRILL CIRC T Trouble shoot MWD surveys, bad detection. switch pumps to #2. Replace all valves & seats in #1. Attempts to get good data with #1 pump failed. #2 pump good. Continue trouble shoot um #1. ,_._~_ Wn®~~_ ~- ~_ ~ s ~ _e ~. -. ~ _ ® `drs~ ~ ~`f ~i :~ ~ ~ e-.~_..-.... ~ __-__, ~~. ~m_ .~.... m-~~ ......,. A m ~.. a~.~,.~_. Time Logs _ ~ Date From To Dur _ th E. Death Phase Code Subcod ~COM _ 07/31/2006 14:45 18:00 3.25 11,312 11,593 PROD1 DRILL DDRL P Directional Drill 6 3/4" production hole from 11312' - 11593'.MD. TVD = 3751'. UP WT = 200K, SO WT = 99K, ROT WT = 132K. 5-10K WOB. RPM = 80. Pumps @ 275 - 300 GPM's - 3100 PSI. ART = 1.07 HRS. AST = .59 HRS. Total Bit HRS = 6.88. Total Jar HRS # 0043 = 51.91 HRS, Total Jar HRS #0019 = 142.97 HRS. Max Gas observed = 30 Units. ECD's 10.1 PPG. Survey @ 11526' MD, INC = 93.53 DEG, AZ = 183.63 DEG, TVD = 3754'. Obtain SPR's. Pump #1 20 SPM - 610 PSI. 30 SPM - 870 PSI. Observed bad detection for MWD with um #1. Crew Chan e 18:00 00:00 6.00 11,593 11,884 PROD1 DRILL DDRL P Directional Drill 6 3/4" production hole from 11593' - 11884'.MD. TVD = 3742. UP WT = 210K, SO WT = 85K, ROT WT = 140K. 5-10K WOB. RPM = 80. Pumps @ 300 GPM's - 3640 PSI. ART = .99 HRS. AST = 1.02 HRS. ADT = 2.01 HRS Total Bit HRS = 9.19 Total Jar HRS # 0043 = 53.92 HRS, Total Jar HRS #0019 = 144.66 HRS. Max Gas observed = 70 Units. ECD's 10.14 PPG. Survey @ 11813' MD, INC = 91.97 DEG, AZ = 180.76 DEG, TVD = 3753'. Concretion depths for the day = 11570'-11573' (3'), 11645'-11649' (4'), 11660'-11668' (8'), 11716'-11718' (2'). Mud Wt = 8.75 PPG, YP 20, Visc = 73.Observed bad detection for MWD with um #1. 08/01/2006 00:00 06:00 6.00 11,884 12,359 PROD1 DRILL DDRL P Directional Drill 6 3/4" production hole from 11884' - 12359' .MD (475'). TVD = 3727'. UP WT = 200K, SO WT = 90K, ROT WT = 140K. 5-10K WOB. RPM = 80. Pumps @ 300 GPM's - 3540 PSI. ART = 1.17 HRS. AST = .30 HRS. ADT = 1.47 HRS Total Bit HRS = 12.24, Total Jar HRS # 0043 = 57.28 HRS, Total Jar HRS #0019 = 146.13 HRS. Max Gas observed = 71 Units. ECD's - 10.31 PPG. Survey @ 12192' MD, INC = 91.42 DEG, AZ = 182.67 DEG, TVD = 3726'. Mud Wt = 8.8 PPG, YP 20, Visc = 79. Observed bad detection for MWD with um #1. Time Logs Date From To Dur th E_De~th Phase Code Subcode OM 08/01/2006 06:00 06:30 0.50 12,359 12,383 PROD1 DRILL DDRL PI Directional Drill 6 3/4" production hole from 12359' - 12383' (24').MD. TVD = 3727. UP WT = 195K, SO WT = 90K, ROT WT = 140K. 5-8K WOB. RPM = 80. Pumps @ 300 GPM's - 3540 PSI. ART = .16 HRS. AST = 0 HRS. ADT = .16 HRS Total Bit HRS = 12.40, Total Jar HRS # 0043 = 57.43 HRS, Total Jar HRS #0019 = 148.17 HRS. Max Gas observed = 33 Units. ECD's - 10.35 PPG. Survey @ 12287 MD, INC = 89.81 DEG, AZ = 182.85 DEG, TVD = 3726'. Mud Wt = 8.8 PPG, YP 20, Visc = 79.Obseroed bad detection for MWD with pump #1. Lost detection allto ether. 06:30 07:00 0.50 12,383 12,383 PROD1 DRILL CIRC T Lost detection. Trouble shoot while circulate & reciprocate drill string attem tin to re ain without success. 07:00 12:15 5.25 12,383 10,856 PROD1 DRILL REAM P PJSM, Discuss safety issues and plan to BROOH. BROOH from 12383' - to shoe @ 10856'. Pumps @ 300 GPM's -3450 PSI. 80 RPM's with 10K torque. Add 5 BBLS /HR of LVT to s stem. 12:15 12:30 0.25 10,856 10,856 PROD1 DRILL OWFF P' Monitor well -static. 12:30 12:45 0.25 10,856 10,856 PROD1 DRILL CIRC P Pump 35 BBLS dry job, & blow down lines & To Drive. 12:45 18:00 5.25 10,856 7,550 PROD1 DRILL TRIP P POOH on elevators from shoe @ 10856' - 7550'. Inspect all super sliders on drill string. Observe some loose bolts. Remove super sliders on stands # 75, 70, 65, and 60. Lay down these joints for future inspection due to previously being over torqued. Observe ro er hole fill. Crew Chan e. 18:00 19:45 1.75 7,550 6,468 PROD1 DRILL TRIP P Continue POOH on elevators (wet string) from 7550' - 6468' inspecting all super sliders.Breakout & lay down XO from 5" D to 4" DP. 19:45 20:30 0.75 6,468 6,468 PROD1 DRILL TRIP P Change out drill pipe elevators for 4" drill string. Change out stripping rubbers in rotary table, and mud bucket rubbers. Clear & clean floor area of MOBM. 20:30 23:00 2.50 6,468 1,964 PROD1 DRILL TRIP P', Continue POOH with 4" DP on elevators from 6468' - 1964'. Obtain torque & drag parameters as per rig engineer every 10 stands in cased hole. 23:00 23:45 0.75 1,964 1,521 PROD1 DRILL TRIP P Continue POOH from 1964' - 1521'. Lay down top single of stand #110. Stand back Drillin 'ars. 23:45 00:00 0.25 1,521 1,521 PROD1 DRILL TRIP P'' POOH standing back stand #5 of BHA. Breakout & lay down DAiley Accelerators (32.09'), Crossover 3.00' .Pull tools to ri floor for BHA. ~ ___~ eee®es ~ ~E~~~ l._~ e ~. ®eme®~ .- ~ ~ _ __._...__._... _.~~...._._~..w...~._,_,._ ._~.__.._...~_.._~.. Time Loci Date From To Dur 2 th E. De th Phase Code Subcode T~^ COM 08/02/2006 00:00 00:15 0.25 1,521 1,502 PROD1 DRILL PULD P Breakout & lay down 4 3/4" Shock Sub (7.02'), Agitator (8.7T), and crossover 2.97' . 00:15 01:15 1.00 1,502 180 PROD1 DRILL TRIP P' POOH racking back 13 stands of 4" Drill pipe. Stand back 1 stand 4" HWDP with 'ars. 01:15 01:45 0.50 180 96 PROD1 DRILL PULD P' Change out elevators for 3 1/2" lift sub. Make up lift sub, POOH racking back 1 stand of 4 3/4 Non MAg Flex drill collars 93.22' .Pull stri in rubbers. 01:45 02:30 0.75 96 96 PROD1 DRILL OTHR P' Plug in and down load MWD assembly. PJSM -discuss safety issues and procedure for breaking out remainnin BHA. 02:30 02:45 0.25 96 0 PROD1 DRILL PULD P Pull up and drain mud motor. Breakout & lay down Bit. Inspect & gauge bit to 2/4/BT/G/X/I/CT/BHA 02:45 03:15 0.50 0 0 PROD1 DRILL PULD P Breakout & change out MWD Pulsar assembl . 03:15 04:00 0.75 0 0 PROD1 DRILL PULD P' Continue breakout & lay down MWD tools on rig floor. Lay down4 3/4" Non Mag float sub with ported float (2.35'), 4 3/4" Welded Blade Stabilizer 94.59'), 4 3/4" Non MAg Termination sub (1.85'), 4 3/4 MWD RES/Gamma Tool (24.07'), MWD Directional (8.41'), 4 3/4" PWD 10.78'), and 4 3/4" TM - HOC 10.86' 04:00 04:30 0.50 0 0 PROD1 DRILL OTHR P Clean & clear Floor area. Inspect & gauge bit. PJSM. Discuss Safety issues and procedure for making up BHA as er DD &MWD re s. 04:30 06:00 1.50 0 91 PROD1 DRILL PULD P Make up BHA # 7. Make up Security Bit FMF 36412 - LG PDC with jets of 3 x 21's for a TFA of 1.015 sq in. (1.31'). 5200 series Geo pilot TL -023 (16.19'). 4 3/4 Non Mag Geo pilot Flex DC (11.55'), MWD Directional (8.41'), 4 3/4" Smart Stabilizer 93.60'), MWD RES?Gamma tool (24.07), PWD (10.78'), TM_HOC (10.86'), Non Mag Float sub (2.35') and 4 3/4" Welded blade Stabilizer 4.59' .Crew Chan e 06:00 07:00 1.00 91 91 PROD1 DRILL OTHR P' Plug in and Upload MWD assembly. 07:00 08:00 1.00 91 290 PROD1 DRILL PULD P' Continue make up BHA #7. RIH with 3 - joints Non Mag Flex drill collars (93.22'), Crossover sub (2.99'), 1 joint of 4" HWDP (30.68'), 4 3/4" DNT Dailey drilling jars (31.96'), 1 joint 4" HWDP (30.69'), Crossover (2.83'), Baker Circulation sub (2.02'), Crossover (2.60'). Run 1 stand of 4" DP from derrick. 08:00 08:15 0.25 290 290 PROD1 DRILL PULD P Perform Shallow pulse test with pumps @ 320 GPM's - 1440 PSI. test with both um s - ood tests. ~ ®m ~ _ ~ ~ ~~ _ m ®. ., ®, Pic .. ~'? .t ~ 1 ~ ? Time Los ~---- Date From To Dur e th E. De th Phase Code Subcode O~ M 08/02/2006 08:15 10:00 1.75 290 1,948 PROD1 DRILL PULD P Continue RIH with 48 -joints of 4" DP (1498.84'), picking up 4 3/4" DNT Dailey drilling jars (32.08'), 3 -joints of 4" DP (94.03'), and 4 3/4" Dailey Accelerators (32.09'). Total BHA = 1947.74'. 10:00 12:00 2.00 1,948 1,948 PROD1 RIGMN RGRP T' PJSM with crew. Discuss Safety issues. Trouble shoot Top Drive Shot Pin Assembl .Service Mud um s. 12:00 13:45 1.75 1,948 4,292 PROD1 DRILL TRIP P Continue trip in hole from 1948' - 4292'. Fill drill string every 25 stands, pulse test - OK. Observe ro er hole fill. 13:45 15:00 1.25 4,292 4,292 PROD1 DRILL CIRC P, Fill Drill String @ 4292' MD. Pump #1 - 230 GPMK's- 1500 PSI. Break in Geo Pilot assembly. 30 RPM's with 4k for ue. 15:00 16:00 1.00 4,292 6,372 PROD1 DRILL TRIP P Continue trip in hole with 4" DP from 4292' - 6372'. Rig down 4" Elevators and slips. Rig up 5" DP Handling e ui ment.Observe ro er hole fill. 16:00 18:00 2.00 6,372 7,690 PROD1 DRILL TRIP P Continue trip in hole with 5" Drill pipe from 6372' - 7690'. Recheck every Super Slider, repostion each one and retorque bolts to 25 FULbs as per VWVf rep. Observe proper hole fill. Crew Chan e 18:00 19:45 1.75 7,690 9,018 PROD1 DRILL TRIP P Continue trip in hole with 5" Drill pipe from 7690' - 9018'. Recheck every Super Slider, repostion each one and retorque bolts to 25 FULbs as per VWVf re .Observe ro er hole fill. 19:45 20:00 0.25 9,018 9,018 PROD1 DRILL CIRC P' Make Top Drive connection @ 9018'. Downlink to Geo Piloy as per D. Check shot for ABI. 20:00 21:00 1.00 9,018 9,587 PROD1 DRILL TRIP P Continue RIH from 9018' - 9587'. Recheck every Super Slider, repostion each one and retorque bolts to 25 FULbs as per WWT rep.Observe ro er hole fill. 21:00 21:15 0.25 9,587 9,967 PROD1 DRILL TRIP P Continue RIH from 9587'- 9967'. Recheck every Super Slider, repostion each one in the middle of the joint from stands # 82 - 85, and retorque bolts to 25 FULbs as per VWVf rep.Observe ro er hole fill. 21:15 22:30 1.25 9,967 11,846 PROD1 DRILL TRIP P' Continue trip in hole from 9967 - 11846' MD. Observe ro er hole fill. 22:30 23:30 1.00 11,846 11,948 PROD1 DRILL TRIP P Make Top Drive connection @ 11846' MD. Obtain checkshot surveys @ 11846', and 11948'. Reset Tool deflection, calibrate MWD tools. 23:30 00:00 0.50 11,948 12,383 PROD1 DRILL TRIP P' Trip in hole from 11948' - 12383' -last TD. . _.m~ _~ m _ ~~~~ ~ _ ..e.®® ®~ e.~_ i ~ _....~ ~ _ _ _ p JJ ~ em ~-~ __..~......__...v.~_......~,.. a....mrr.. .. ®.~m m~-.,,.._~~. .®m,~....-~~..~_.«~..._ - ~_.~~..~...........,.® e.m~«...........a....«mm®m~®{ `:Togs Date From To Dur e th E. De th Phase Code Subcode „OM 08!03/2006 00:00 06:00 6.00 12,383 12,864 PROD1 DRILL DDRL P j Directional Drill 6 3/4" production hole from 12383' - 12864' (481').MD. TVD = 3712'. UP WT = 210K, SO WT = 85K, ROT WT = 130K. 8-10K WOB. RPM = 120. Pumps @ 280 GPM's - 2480 PSI. ART = 3.95 HRS. AST = 0 HRS. Total Bit HRS = 3.95, Total Jar HRS # 0043 ', = 61.38 HRS, Total Jar HRS #0019 = 152.12 HRS. Max Gas observed = ', 128 Units. ECD's - 10.37 PPG. Survey '', @ 12784' MD, INC = 91.64 DEG, AZ = 186.80 DEG, TVD =.3715.09'. Mud Wt = 8.8 PPG, YP 20, Visc = 79. Crew Chan e 06:00 12:00 6.00 12,864 13,183 PROD1 DRILL DDRL P Directional Drill 6 3/4" production hole from 12864' - 13183' (319').MD. TVD = 3695'. UP WT = 210K, SO WT = 80K, ROT WT = 130K. 10-12K WOB. RPM = 90. Pumps @ 300 GPM's - 2550 PSI. ART = 4.38 HRS. AST = 0 HRS. Total Bit HRS = 8.33, Total Jar HRS # 0043 = 65.76 HRS, Total Jar HRS #0019 = 156.50 HRS. Max Gas observed = 75 Units. ECD's - 10.30 PPG. Survey @ 13166' MD, INC = 95.11 DEG, AZ = 181.95 DEG, TVD = 3698'. Mud Wt = 8.8 PPG, YP 20, Visc = 79. 12:00 18:00 6.00 13,183 13,706 PROD1 DRILL DDRL P' Directional Drill 6 3/4" production hole from 13183' - 13706' (523').MD. TVD = 3689'. UP WT = 220K, SO WT = 75K, ROT WT = 138K. 10-12K WOB. RPM = 90. Pumps @ 300 GPM's - 2700 PSI. ART = 3.52 HRS. AST = 0 HRS. Total Bit HRS = 11.85, Total Jar HRS # 0043 = 69.28 HRS, Total Jar HRS #0019 = 160.02 HRS. Max Gas observed = 75 Units. ECD's - 10.38 PPG. Survey @ 13640' MD, INC = 91.26 DEG, AZ = 178.64 DEG, TVD = 3691'. Mud Wt = 8.65 PPG, YP 20, Visc = 77. 18:00 21:45 3.75 13,706 13,868 PROD1 DRILL DDRL P', Directional Drill 6 3/4" production hole from 13706' - 13868' (162').MD. TVD = 3685'. UP WT = 215K, SO WT = 75K, ROT WT = 140K. 10-12K WOB. RPM = 120. Pumps @ 310 GPM's - 2680 PSI. ART = 3.35 HRS. AST = 0 HRS. Total Bit HRS = 15.20, Total Jar HRS # 0043 = 72.63 HRS, Total Jar HRS #0019 = 163.37 HRS, Max Gas observed = 116 Units. ECD's - 10.53 PPG. Survey @ 13834' MD, INC = 90.76 DEG, AZ = 180.58 DEG, TVD = 3687. Mud Wt = 8.80 PPG, YP 20, Visc = 77. Time Logs ~ _-- Date From To Dur ? th E. De th Phase Code Subcode T`w COM _ 08/03/2006 21:45 22:15 0.50 13,868 13,868 PROD1 DRILL CIRC P'~ Back ream out 1 stand. Obtain Slow pump rates @ 13868' MD. Pump #1 - 20 SPM - 490 PSI, 30 SPM - 710 PSI, ', #2 pump - 20 SPM -490 PSI, 30 SPM ', -710 PSI. Inspect grabbers on Top Drive. 22:15 00:00 1.75 13,868 13,956 PROD1 DRILL DDRL P' Directional Drill 6 3/4" production hole from 13868' - 13956' (88').MD. TVD = 3686'. UP WT = 215K, SO WT = 75K, ROT WT = 140K. 10-12K WOB. RPM ', = 120. Pumps @ 310 GPM's - 2680 PSI. ART = 1.29 HRS. AST = 0 HRS. Total Bit HRS = 16.49, Total Jar HRS # 0043 = 73.92 HRS, Total Jar HRS ' #0019 = 164.66 HRS. Max Gas observed = 116 Units. ECD's - 10.51 ', PPG. Survey @ 13834' MD, INC = 90.76 DEG, AZ = 180.58 DEG, TVD = 3687. Mud Wt = 8.80 PPG, YP 20, Visc = 77. Total Concretions drilled today - 13129-13134(5'), 13170-13185 (15'), 13204-13205 (1'), 13497-13500 (3'), 13828-13840 (12'), 13877-13884 (T), 13887-13890 (3'), and 13909-13912 (3'). total concretions = 49'. 08!04/2006 00:00 06:00 6.00 13,956 14,361 PROD1 DRILL DDRL P' Directional Drill 6 3/4" production hole from 13956' - 14361' (405').MD. TVD = 3687. UP WT = 220K, SO WT = 75K, ROT WT = 130K. 10-12K WOB. RPM = 120. Pumps @ 280 GPM's - 2410 PSI. ART = 4.18 HRS. AST = 0 HRS. Total Bit HRS = 20.67, Total Jar HRS # 0043 = 78.10 HRS, Total Jar HRS #0019 = 168.84 HRS. Max Gas observed = 197 Units. ECD's - 10.81 ', PPG. Survey @ 14308' MD, INC = ', 89.71 DEG, AZ = 178.74 DEG, TVD = 3687. Mud Wt = 8.85 PPG, YP 2b, Visc = 75. Crew Chan e 06:00 12:00 6.00 14,361 14,845 PROD1 DRILL DDRL P' Directional Drill 6 3/4" production hole from 14361' - 14845' (484').MD. TVD = 3738'. UP WT = 245K, SO WT = 75K, ROT WT = 140K. 10-12K WOB. RPM = 130. Pumps @ 345 GPM's - 3200 PSI. ART = 4.13 HRS. AST = 0 HRS. Total Bit HRS = 24.80, Total Jar HRS # 0043 = 82.23 HRS, Total Jar HRS #0019 = 172.97 HRS. Max Gas observed = 40 Units. ECD's - 11.36 ', PPG. Survey @ 14783' MD, INC = 80.92 DEG, AZ = 171.93 DEG, TVD = 3729'. Mud Wt = 8.85 PPG, YP 20, Visc = 77. ~ ®~ _.~.e a ~®~_ ase .. ~.~ ~ w®~~ ~..__....~, Time Los Date From To D ur th E. De th Phase Code Subcode .,OM _ 08/04/2006 12:00 15:30 _ _ 3.50 14,845 15,160 PROD1 DRILL DDRL Pj ~ Directional Drill 6 3/4" production hole j from 14845' - 15160 (315').MD. TVD = ~! 3782'. UP WT = 250K, SO WT = 75K, ROT WT = 140K. 10-12K WOB. RPM = 130. Pumps @ 345 GPM's - 3200 PSI. ART = 2.34 HRS. AST = 0 HRS. Total Bit HRS = 27.14, Total Jar HRS # 0043 = 84.57 HRS, Total Jar HRS #0019 = 175.31 HRS. Max Gas observed = 40 Units. ECD's - 11.30 I PPG. Survey @ 15160' MD, INC = j 77.36 DEG, AZ = 179.93 DEG, TVD = 3782'. Mud Wt = 8.85 PPG, YP 20, Visc = 77. Geology called TD early '~ due to "wet sands". 15:30 18:00 2.50 15,160 14,490 PROD1 DRILL REAM P~I BROOH from 15160' - 14490'. Back ', ream speed inintially 15 ft/min. Pumps @ 350 GPM's - 3220 PSI. Circulate 5 minutes before each connection. Rotate 120 RPM's with 11-12K torque. Hole in ood condition. Crew Chan e 18:00 20:45 2.75 14,490 13,445 PROD1 DRILL REAM P'~, Continue BROOH from 14490' - 13445' MD. Back ream speed inintially 15 ', ft/min., increasing to 35-40 ft/min. Pumps @ 350 GPM's - 3060 PSI. Circulate 5 minutes before each connection. Rotate 120 RPM's with 9K ', torque. ECDs = 10.71 PPG. Hole in good condition. Obtain SLM on Drill Pi a while BROOH. 20:45 00:00 3.25 13,445 11,950 PROD1 DRILL REAM P, Continue BROOH from 13445' - 11950' MD. Back ream speed 35-40 ft/min. Pumps @ 350 GPM's - 3060 PSI. Circulate 2 minutes before each ~' connection. Rotate 120 RPM's with 9K ', torque. ECDs = 10.71 PPG. Hole in good condition. Obtain SLM on Drill Pi a while BROOH. 08/05/2006 00:00 02:30 2.50 11,950 10,853 PROD1 DRILL REAM PI Continue BROOH from 11950' - 10853' MD. Back ream speed 35-40 ft/min. Pumps @ 350 GPM's - 3060 PSI. Circulate 2 minutes before each connection. Rotate 120 RPM's with 9K ', torque. ECDs = 10.71 PPG. Hole in good condition. Obtain SLM on Drill Pi a while BROOH. 02:30 04:00 1.50 10,853 10,853 PROD1 DRILL CIRC PI Circulate & drop 1.90" Dart to land & open circulation sub with 2200 PSI. Continue circulate 44 BBLS High Visc weighted sweep @ 550 GPM's - 3300 ', PSI. reciprocate & rotate drill string while pump sweep until hole clean. Swee = 9.0 PPG , 160 Visc. 04:00 04:15 0.25 10,853 10,853 PROD1 DRILL OWFF P' Monitor well -static. 04:15 04:30 0.25 10,853 10,853 PROD1 RIGMN SVRG P', LO/TO Brake. Grease Crown section. Grease Swivel ackin . ..,..:_. ~ ~®®_..~d ~M.__ ~ ~ __,...~®~~___._~ ~_ ~ _ ~f Time Logs ~ Date _ From To Dur th E~De~th Fhase Code Subcod QM 08/05/2006 04:30 06:00 1.50 10,853 14,632 PROD1 DRILL TRIP P Trip in hole with BHA #7 into openhole !, from 10853' -14632', without utilizing Top Drive to get back to 14632'. Observe ood hole conditions. 06:00 07:15 1.25 14,632 14,632 PROD1 DRILL CIRC P'. Make Top Drive connection. Establish ', circulation. Pump 20 BBIs of 8.8 PPG ', MOBM, follow with 225 BBLS of 8.8 PPG SFMOBM to spot in open hole section of well. pumps @ 350 GPM's - 2250 PSI. Reciprocate & rotate drill string while pumping. Pump 10.8 PPG d 'ob. Blow down To Drive & lines. 07:15 10:15 3.00 14,632 10,345 PROD1 DRILL TRIP P', PJSM with crew. Discuss safety issues and hazard recognition. POOH on elevators from 14632' - 10345'. Obtain T & D parameters as per rig j engineer. Observe good hole conditions with ro er hole fill. 10:15 11:30 1.25 10,345 10,820 PROD1 RIGMN RGRP T', Repair iron Roughneck. Circulate hi- visc weighted sweep while mix second ', dry job. Trip in hole 5 stands back to 10820'. 11:30 13:30 2.00 10,820 10,820 PROD1 DRILL CIRC P Cirdculate 30 BBL sweep as per Co. ', Rep @ 10820'. Reciprocate & rotate ', drill string with 120 RPM's ,pumps @ 650 GPM's - 4000 PSI. Torque = 8K ft/Ibs. 13:30 14:00 0.50 10,820 10,820 PROD1 DRILL CIRC PI Pump 20 BBLS dry job, 2 LBS over mud weight. Monitor well -static. Service To Drive, while monitor well. 14:00 18:00 4.00 10,820 6,451 PROD1 DRILL TRIP P'' POOH on elevators from 10820' - 6451', racking back all 5" DP. Observe ', proper hole fill. Obtain SLM on DP. Crew Chan e. 18:00 20:15 2.25 6,451 1,947 PROD1 DRILL TRIP P~ Change out drill pipe elevators to 4", continue POOH on elevators from 6451' - 1947. Observe ro er hole fill. 20:15 20:30 0.25 1,947 1,915 PROD1 DRILL PULD P' Breakout & lay down 4 3/4 Accelerators 32.09' . 20:30 20:45 0.25 1,915 1,883 PROD1 DRILL TRIP P' POOH racking back 1 stand 4" DP. Breakout & lay down 4 3/4" DNT drillin 'ars 32.08' . 20:45 21:00 0.25 1,883 384 PROD1 DRILL TRIP PI I POOH racking back 16 stands of 4" !, Drill i e. 1498.84' . 21:00 22:15 1.25 384 94 PROD1 DRILL PULD P', POOH breakout & lay down 3 -joints Non Mag Flex drill collars (93.22'), Crossover sub (2.99'), 1 joint of 4" HWDP (30.68'), 4 3/4" DNT Dailey ', drilling jars (31.96'), 1 joint 4" HWDP (30.69'), Crossover (2.83'), Baker Circulation sub (2.02'), Crossover 2.60' . 22:15 22:45 0.50 94 94 PROD1 DRILL OTHR P', Plug in and download MWD asembly. ', SIMOPS: Pull tools to rig floor for 4 1/2" liner run. _ . _..~.d ~,. -- ~e ~ _ ~ ~ ®_ em~~ . _~ ..~ ~~~ ~.~ ~a ~ w. e. ~....~ ~ ..._m . _. m ~~ ~..w~_ _. ~....~~. _ ~e~ ~_ _____~... . Time Logs Date From To Dur e th E. De th Phase Code Subcode .,OM _ 08/05/2006 22:45 23:45 1.00 94 0 _ PROD1 DRILL PULD P' Continue POOH breakout & lay down ~~ Security Bit FMF 36412 - LG PDC with ', jets of 3 x 21's for a TFA of 1.015 sq in. (1.31'). 5200 series Geo pilot TL ', -023 (16.19').4 3/4 Non Mag Geo pilot ', Flex DC (11.55'), MWD Directional (8.41'), 4 3/4" Smart Stabilizer 93.60'), MWD RES/Gamma tool (24.07), PWD ', (10.78'), TM_HOC (10.86'), Non Mag ', Float sub (2.35') and 4 3/4" Welded ', blade Stabilizer (4.59'). Inspect & rade bit to 1/2/CT/N/X/I/BT/TD. 23:45 00:00 0.25 0 0 COMPZ DRILL PULD P Clean & clear rig floor area. Double check tools & e ui ment for liner run. 08/06/2006 00:00 00:30 0.50 0 0 COMPZ CASIN( RURD P, Continue RU to run 4 1!2" Slotted liner assembly. Rig up all GBR liner running e ui ment. 00:30 00:45 0.25 0 0 COMPZ CASIN( SFTY P'. PJSM with crew &GBR reps. Discuss Safety Issues and procedure for runnin 4 1/2" Slotted liner assembl . 00:45 03:45 3.00 0 3,582 COMPZ CASIN( PUTB P Make up 4 1/2" "Orange Peeled "shoe joint (8.2T), 4 1/2" Swell Packer with ', pups (19.54'), continue with 68 joints of j 4 1/2" Slotted liner with spiralglider centralizers and a stop ring made up in ~' the middle of each joint (2913.59'). !i Continue make up Swell packer #2 ', (19.54'), and 13 joints of 4 1/2" Blank ', Liner with spiralglider centralizers and a stop ring in the middle of each joint (552'). Make up torque = 5000 ft/Ibs. All joint & pups have Torque rings installed. 03:45 04:15 0.50 3,582 3,582 COMPZ CASIN( PUTB P Change out power tongs, & elevators ', to 5" DP. Make up Baker 80-40 6.25" x 4.75" Casing seal Bore Extension with ', 4.5" Crossover & 4.5" Pup (25.02'), ', and 9 5/8" x 7" Flexlock Liner Hanger (9.79') with RS packoff Seal Nipple (2.83'), and 9 5/8" HRD ZXP liner Top Packer (18.62') with ball seat & shear out sub assembly installed. Make up Torque = 8400 FUlbs. Total Length of ', Liner assembly (3581.85'). Up Wt = ' 100K, SO WT = 93K. 04:15 04:30 0.25 3,582 3,582 COMPZ CASIN( RURD P Rig down all liner running equipment. 04:30 06:00 1.50 3,582 5,958 COMPZ CASIN( RUNL ~ Trip in hole with 5" DP and 4 1/2" Slotted liner assembly from 3582' - ~, 5958'. Observe proper hole fill. Crew Chan e 06:00 06:45 0.75 5,958 5,958 COMPZ CASIN( RUNL P Pick up 6 joints 5" HWDP from pipe shed and rack in derrick for liner run. 06:45 10:30 3.75 5,958 10,811 COMPZ CASIN( RUNL P Continue run 4 1!2" Slotted liner from 5958' - 10811'. Observe ro er hole fill. x`~C:g63 ~~ 6=3 ~: Time Logs - ~ - Date__ From To _ Dur 9,., e~th E. De th F'hase Code Subcode T'~ COM 08/06/2006 10:30 11:00 0.50 10,811 10,811 COMPZ CASIN( CIRC P' Fill drill string, taking 7.5 BBLS. ', Obtain rotating parameters @ 25 ~! RPMs with 6-8K torque. Set top Drive ', max torque @ 19K ft/Ibs. Pumps @ 35 SPM - 400 PSI. UP WT = 185K, SO WT = 102K, ROT WT = 152K, at the shoe. 11:00 14:15 3.25 10,811 14,218 COMPZ CASIN( RUNL P' Continue run 4 1/2" Slotted liner into ', open hole from 10811' - 14218' on ', depth. Drift drill string to 2 3/88 drift for ', setting ball. No string rotation needed to et liner to de th. 14:15 15:30 1.25 14,218 14,218 COMPZ CASIN( RUNL P', With Liner on depth, drop 1 3/4" ball as per BOT rep. Allow to fall pumping ', down drill string @ 153 GPMs - 490 PSI to observe ball seated @ 1700 Strokes, 170 BBLS 15:30 16:30 1.00 14,218 14,218 COMPZ CASIN( RUNL P' Pressure up to 2000 PSI to set ZXP ', packer @ 10647 MD, with Flexlock ', Liner hanger @ 10668', and Swell ', Packer depths of 11263', and 14196' as planned. Bleed pressures. Work ', drill string, pressure back up to 1000 '~ PSI with Annular closed to test PKR. Good test. Pressure to 4000 PSI to release from setting tool. Pull up to observe proper release. UP WT = ', 235K, SO WT = 90K. All tests and ressures recorded on chart recorder. 16:30 17:30 1.00 14,218 14,218 COMPZ CASIN( CIRC P' Pull up above liner top. Circulate bottoms up. 380 BBLs total pumped. Monitor well -static. pump dry job, and blow down To Drive and lines. 17:30 18:00 0.50 10,647 10,636 COMPZ CASIN( RUNL P', POOH with Liner running & setting tool to 10636'. Crew Chan e. 18:00 22:30 4.50 10,636 0 COMPZ CASIN( RUNL P~' Continue POOH with Liner running & settin tool from 10636' - to surface. 22:30 23:00 0.50 0 0 COMPZ CASIN( OTHR P' Breakout & lay down Baker running & setting tools. Make service breaks as ', per BOT rep. Inspect tool. Tools com lete with no issues. 23:00 00:00 1.00 0 0 COMPZ CASIN( RURD P Clean & clear rig floor area. Send tools outside. Pull thread protectors to rig floor for 4" & 5" DP. Install Mousehole in Rotary table for laying down drill pipe. held PJSM with crew. Discuss ', Safety issues and procedure for Isying ', down DP from derrick. Discuss Hazard reco nition. 08/07/2006 00:00 03:45 3.75 0 0 COMPZ CASIN( OTHR P, Breakout & lay down 22 stands of 5" Drill pipe from derrick. Observe ', breaking out Tight connections utilizing rig tongs as Iron Roughneck would not break 5" DP connections, on 11 stands. _.ae. _ ~m ~.~ ~ ~ ~ ~~~ m ~~ ~ _~_._ d ~. _ ~m ® _ ~_~ kv_®~ m ~. ~~m ~ ® .~.. Time Logs Date From To Dur e th E. De th Phase Code Subcode T OM 08/07/2006 03:45 06:00 2.25 0 0 COMPZ CASIN( OTHR P Change out elevators and slips for 4" ~~ Drill pipe. Continue breakout & lay ~~, down 4" drill pipe in derrick, 30 stands. ~, Pull mouse hole in rotary table every 10 stands, monitor hole. Crew Chan e. 06:00 10:15 4.25 0 0 COMPZ CASIN( OTHR P'~ Continue breakout & lay down 4" drill ~, pipe in derrick, 35 stands. Pull mouse II hole in rotary table every 10 stands, '~ monitor hole. 10:15 10:30 0.25 0 0 COMPZ CASIN( OTHR P Clean & clear rig floor area. Monitor well -static. 10:30 11:30 1.00 0 0 COMPZ EVALFI RURD N~ Schlumberger Wireline crew rigging !, ~ up. Notified rig personnel of spill at the unit. Rig crew responded. Observed Hydraulic spill from loose connection '~, in unit. Spill reported and a PIR sent out b Co. Re . 11:30 12:30 1.00 0 0 COMPZ EVALFI RURD NP ACS rep on location to estimate volume of spill at 3/4 Gal. 1/2 Gal on the gravel. Move wireline truck. Clean i up and bag spill contents to be sent to ~'I 1 H pad. Lay pit liner under truck and re osition wireline truck for ri in u . 12:30 12:45 0.25 0 0 COMPZ EVALFI SFTY PI PJSM wit crew Well Tech &SWS reps. Discuss safety issues and rocedure for ri in u and wirelinin . 12:45 14:00 1.25 0 0 COMPZ EVALFI RURD PI Rig up SWS wireline crew. Install I~ sheaves and pull tools to rig floor. ', SIMOPS: Tuboscope on rig floor magna fluxing equipment on rig, tongs, elevators etc.... 14:00 18:00 4.00 0 0 COMPZ EVALFI OPNW PI Make up WeIlTech Tractor,&SWS ~, wireline tools. Wireline in hole to 3208'. Tractor in the hole from 3208' - 10600' ~, @ 3500 ft/hr. Note SWS PU depth = 10570'. 18:00 20:30 2.50 0 0 COMPZ EVALFI OPNW PI Schlumberger log from 10570' - 6500'. ', Tractor in hole from 6500' - 7700'. Repeat log from 7700' - 6785'. Observed cement 7350' WLM. 20:30 21:30 1.00 0 0 COMPZ EVALFI OPNW P!, Wireline out of hole from 6785' - 4333'. Observed "Birdcaged" damaged & ', tangled wireline come through rotary ~ table. The E-line had twisted itself into I a knot of about 12' in len th. 21:30 21:45 0.25 0 0 COMPZ EVALFI SFTY P'i PJSM with crew &SWS. Discuss safety issues and procedure for cutting line using a T-Bar, and getting line spooled on truck. All hands notified of otential hazard & dan er. i ,ems.. m.®~ ~°`~~5~~,~. ~~ 3'3J - I .~ _,~.. ,~e~® .. . ~ ...._...._..,.. _ ~_ ._ ® ..... . Time Logs _ Date From To Dur th E. De th Phase Code Subcode OM 08/07/2006 21:45 22:30 0.75 0 0 COMPZ EVALFI OPNW P SWS hands clamped off wireline in table with T-bar. Slack was given form unit drum. The line was cut, bad line removed, and tied back into itself. The line was secured and pulled through sheaves to the unit drum with no incident.The line was then secured to unit drum for POOH. 22:30 00:00 1.50 0 0 COMPZ EVALFI OPNW P Continue wireline out of hole from 4333' to surface. Breakout & lay down Well Tech Tractor assembly and SWS tools. Monitor well -static. 08/08/2006 00:00 02:00 2.00 0 0 COMPZ EVALVI~ RURD P Remove bad E line section from unit drum (4350' ). Rehead line. Make up new head for Well Tech tractor. Prepare tools for Caliper log in the 9 5/8" casing. SIMOPS: Continue prepare tools on rig floor for Tuboscope Ma na Flux ins ection. 02:00 02:15 0.25 0 0 COMPZ EVAL1l~ SFTY P PJSM with crew. Discuss Wireline Safet issues and hazard reco nition. 02:15 02:45 0.50 0 0 COMPZ EVALV~ RURD P Make up Well Tech Tractor on Eline with Precision Diagnostic Services Cali er to in tools. Zero CCL. 02:45 03:15 0.50 0 2,700 COMPZ EVALV~ ELOG P RIH w1 Precision Diagnostic Services 40 arm caliper memory log on Schlumber er wireline to 2700' WLM. 03:15 06:00 2.75 2,700 10,600 COMPZ EVALV\ ELOG P Continue in hole with Welltech tractor f/ 2700' to 10600' WLM. Schlumber PU wt 10580'. 06:00 08:00 2.00 10,580 10,580 COMPZ EVALV4 OTHR P Wait on PDS 40 arm caliper tool to o en. 08:00 08:15 0.25 10,580 10,580 COMPZ EVAL~/1~ OTHR P Check out tool to verify open and ready to to . 08:15 11:15 3.00 10,580 0 COMPZ EVALVI~ ELOG P POOH w/ PDS 40 arm caliper memory log. Logging f/ 10580' to surface. Pulling speed 3600' per minute (3600' er hour . 11:15 12:45 1.50 0 0 COMPZ EVALV~ RURD Out of hole @ 1115 hrs. Downloading information. Checking data, rig down wireline equipment. Appears to have ood data. 12:45 14:00 1.25 0 0 COMPZ CASIN( OTHR PJSM. Clear and clean rig floor. UD thread protectors, 4" elevators and e ui ment. 14:00 14:15 0.25 0 0 COMPZ DRILL OWFF Monitor well. Static. 14:15 14:30 0.25 0 0 COMPZ DRILL SFTY PJSM on RIH w/ 5" dp to displace OBM to 9.7 brine. 14:30 18:00 3.50 0 8,370 COMPZ DRILL TRIP RIH w/ 5" drillpipe to 8370' (88 stands) 18:00 18:15 0.25 8,370 8,370 COMPZ DRILL SFTY PJSM on RIH w/ 61 joints 5" dp f/ pipe shed. 18:15 20:30 2.25 8,370 10,304 COMPZ DRILL PULD PU/MU/RIH w/ 61 joints of 5" drill pipe f/ 8848' to 10304'. PU wt 200 to 210k, SO wt 100k. ~~~_,__.~~ ~.~ _e eme e~e~~ ;.~~~m ~ ~ ~~ ®ee~. s~ _.. _~mm® ~~~~~,~___.~ .~._ ®-_ - Time Logs _ Date From To Dur e th E. De th Phase Code Subcode OM 08/08/2006 20:30 20:45 0.25 10,304 10,304 COMPZ DRILL SFTY PJSM on RU for displacement f/ 8.9 MOBM to 9.7 brine. 20:45 21:00 0.25 10,304 10,304 COMPZ DRILL RURD RU f/ displacement. 21:00 21:30 0.50 10,304 10,304 COMPZ DRILL SFTY PJSM on displacement by reverse circulation. 21:30 00:00 2.50 10,304 10,304 COMPZ DRILL CIRC Displace well f/ 8.9 ppg MOBM to 9.7 ppg brine. Reverse circ w/ mule shoe @ 10304'. Initial circ rate 3.5 bpm w/ 400 psi. Pump 40 bbls LVT(6.8 ppg), follow 50 bbls high vis brine spacer (9.0 ppg), follow w/ 50 bbls water (8.34 then follow w/ 9.7 brine. 08/09/2006 00:00 04:00 4.00 10,304 10,304 COMPZ DRILL OTHR P Not through with displacement. Monitor well. Initial shut in 20 psi on 5" dp, 52 psi on 9-5/8" x 5" drill pipe. Service rig. Wait for 290 bbls 9.7 ppg brine to arrive and finish displacement. Connect lines. Final shut in 100 psi on 5" d , 60 si on 9-5/8" x 5" d . 04:00 04:30 0.50 10,304 10,304 COMPZ DRILL CIRC Displace well f/ 8.9 ppg MOBM to 9.7 ppg brine. Reverse circ w/mule shoe @ 10304'. Initial circ rate 3 bpm w/ 220 psi. Pump total of 55 bbls 9.7 ppg brine. Brine to surface after 787.1 total bbls of brine pumped. Total brine pumped 807.6 bbls. Monitor pressures. OK. Allow to "U" tube. OK. Short 162 bbls MOBM to surface. 04:30 05:00 0.50 10,304 10,304 COMPZ DRILL RURD Rig down circulation lines. Blow down kill line. 05:00 05:15 0.25 10,304 10,304 COMPZ DRILL SFTY PJSM on laying down 5" drill pipe. 05:15 10:15 5.00 10,304 6,290 COMPZ DRILL PULD L/D Weatherford 5" drill pipe. f/ 10304' to 6290'. 10:15 10:30 0.25 6,290 6,290 COMPZ RIGMN SFTY PJSM on cutting 1-3/8" drilling line. 10:30 11:45 1.25 6,290 6,290 COMPZ RIGMN SVRG Slip and cut 144' of 1-3/8" drilling line. 11:45 12:45 1.00 6,290 6,290 COMPZ RIGMN SVRG Service rig. 12:45 18:30 5.75 6,290 1,806 COMPZ DRILL PULD Continue Laying down Weatherford 5" drill pipe f/ 6290' to 3818', then continue removing Western Well Tools HD 5" super sliders f/ 3818' to 1806'. Cleanin its of MOBM. 18:30 19:45 1.25 1,806 1,806 COMPZ RIGMN RGRP Trouble shoot rig floor hydraulic system. Electricain replaced a fuse. Cleanin its of MOBM. ~~~ ~ ~~ ~~ Time Los ~ r Date From To Dur e>> th E. De th Phase Code Subcode OM 08/09/2006 19:45 00:00 4.25 1,806 400 COMPZ DRILL PULD P Continue Laying down Weatherford 5" drill pipe f/ 1806' to 400', continue removing Western Well Tools HD 5" super sliders f/ 1806' to 400'. Breaking tight pipe with rig tongs, steaming connections. Cleanin its of MOBM. 08/10/2006 00:00 01:00 1.00 400 0 COMPZ DRILL PULD P Continue Laying down Weatherford 5" drill pipe f/ 400' to surface, continue removing Western Well Tools HD 5" super sliders f/ 400' to surface. Breaking tight pipe with rig tongs, steaming connections. Note: Cleaning pits of MOBM continues throughout the day. 23 bbls over calculated displacement on trip out of hole. 01:00 01:15 0.25 0 0 COMPZ DRILL OTHR P Pull Vetco Gray wear bushing (13-3/8" OD x 12- 5/16" ID, 60" long) Vetco rep Kevin Supervised and ex lained wellhead to floor hands. 01:15 01:45 0.50 0 0 COMPZ DRILL PULD P Clear rig floor of uneccessary tools. Prepare to PU 3-1/2" completion strin . 01:45 02:00 0.25 0 0 COMPZ RPCOti SFTY P PJSM on rigging up to run 3-1/2" com letion w/ GBR. 02:00 04:30 2.50 0 0 COMPZ RPCOh RURD P Rig up to run 3-1/2" completion. GBR tongs and slips, Spooler w/ 11,100' Tectube 1/4" w/ 18 AWG wire. Ser # of spool is 101364916-01, batch 0000345678. Install sheave @ derrick board and run line to floor. Bring to floor (235) Cannon clamps P/N 303131 3-1/2" across collar clam s . 04:30 05:00 0.50 0 0 COMPZ RPCOCV SFTY PJSM on running 3-1/2" completion w/ rig crew, Baker Oil tools rep, Centralift, Weatherford, tourpusher and rig su ervisor. 05:00 06:00 1.00 0 100 COMPZ RPCOCV RCST PU/MU/RIH w/ Baker 80-40 seals w/ baker locator (5.50" OD), 3-1/2" 9.3 ppf L-80 EUE 8rd-mod pup jt, one jt of 3-1/2" 9.3 ppf L-80 EUE 8rd-mod tubing, 3-1/2" Camco "D" nipple w/ 2.75" profile, one jt 3-1/2" 9.3 ppf L-80 EUE 8rd-mod tubing, crossover, crossover pup jt, 4-1/2" EUE I-Pump TCS guage (A well/ Weatherfrod), crossover pup jt, crossover, one jt 3-1/2" 9.3 ppf L-8- EUE 8rd-mod. This is a total of three joints of 3-1/2" tubing with jewelry made up to 100'. Weatherford connect 1/4"TecTube to guage and make checks on guage and wire. MU 1/4" stainless control line up to guage which will run to ported nipple which will be installed above Baker CMU. ~~ ee~ ~ ____~~ __ ~ ~ _r.,_...~ 4 ~~Y~L~ Via"' -F~ ~s~ ~ »,.._.~.._~_-_. ,..~..______~»-~...._..... .,....,.......--......., .d._. ,.....~ .. e~~ .... ... Time Logs ~ Date _ From To Du e th E. De th Fhase Code Subcode OM 08/10/2006 06:00 07:15 1.25 100 100 COMPZ RPCOh OTHR P Start installing 1-1/4" stainless bands starting above guage on crossover pup jt. Two bands on crossover pup, then one band on jt # 3 at pin end =total of 3 bands.. 07:15 07:30 0.25 100 100 COMPZ RPCOh SFTY P PJSM on running 3-1/2" completion w/ rig crew, Baker Oil tools rep, Centralift, Weatherford, and ri su ervisor. 07:30 08:00 0.50 100 187 COMPZ RPCOh RCST P PU/MU/RIH w/ 3-1/2" 9.3 ppf L-80 EUE 8rd-mod pup jt, fluted wire protector, Baker CMU w/ 2.812" profile, fluted wire protector, 3-1/2" 9.3 ppf L-80 EUE 8rd-mod pup jt, then one jt 3-1/2" 9.3 ppf L-80 EUE 8rd-mod Qt #4). Depth 187'. 1-1/4" stainless bands on pup jt below fluted wire protector, and above top fluted wire protector = 2 bands more for total of 5 bands. 08:00 08:30 0.50 187 200 COMPZ RPCOh RCST P Continue PU/MU/RIH w/ 3-1/2" 9.3ppf L-80 EUE 8rd-mod pup jt, ported nipple, 3-1/2" 9.3 ppf L-80 EUE 8rd-mod pup jt. Depth 200'. Installed two more 1-1/4" stainless bands: One on pup jt below ported nipple and one above ported nipple. Total bands so far= 7. 08:30 09:15 0.75 200 200 COMPZ RPCOti OTHR P Connect 1/4" stainless line to ported ni le. Install 1-1/4" stainless bands 09:15 09:30 0.25 200 285 COMPZ RPCOti RCST P Continue running 3-1/2" completion f/ 200' to 285': Run two joints (# 5 & #6), then pup jt, then 3-1/2" x 1" KBMG GLM w/ dummy valve, 3-1/2" pup jt. Install Cannon clamp across pup jts and full 'ts. 09:30 18:00 8.50 285 5,256 COMPZ RPCOh RCST Continue running 3-1/2" completion f/ 285' to 5256' :Run Jts # 7- #165. Test I wire and presure guage @ 1162', 2285', 3280', and 4376'. Install cannon clamps across all collars. 18:00 22:45 4.75 5,256 7,416 COMPZ RPCOh RCST Continue running 3-1/2" completion f/ 5256' to 7416' :Run Jts # 166- #234 in hole (#235 made up). Test I wire and presure guage @ 5370' and 6674'.. Install cannon clamps across all collars up to box of 234 and pin of 235. All 235 cannon #303131 clamps used u. 22:45 00:00 1.25 7,416 7,416 COMPZ RPCOti RURD PU Tyco heat trace cable to rig floor, install sheave in derrick w/wire to floor. Brin Cannon clam s to floor. 08/11/2006 00:00 01:45 1.75 7,416 7,416 COMPZ RPCOh WOEQ P Trying to locate 8 Cannon across the collar clams 303131 I _~ _ m._ mme___ _._ma . _~ ®®.~~. ~ e~ m~ ~.~ .~~ ~~~~ .a~ ~ ~® ~.~ R~..... _ ~..~.~® a~~~ ~~ ,~t ~~ M.~ ___.~....~_ .. .~..~~..,.. _, . ~ Time Logs _ --~- Oate _ From To Dur 9~fe th E. De th Phase Code Subcode OM 08/11/2006 01:45 03:00 1.25 7,416 7,291 COMPZ RPCOh PULD P Rig up and laydown jts 235, 234, 233, 232, 231, remove Cannon across the collar clams 303131 . 03:00 03:15 0.25 7,291 7,197 COMPZ RPCOti PULD P POOH jts 230, 229, and 228. Remove Cannon across the collar clamps 303131 . 03:15 03:30 0.25 7,197 7,291 COMPZ RPCOh RCST P Run in hole installing Cannon across the collar clamps every other joint. RIH MU jt # 235. Last continuous jt is jt #226 box, then 228, 230, 232, 234. 03:30 03:45 0.25 7,291 7,670 COMPZ RPCOh RCST Continue RIH w/ 3-1/2" completion f/ jt # 235 to 242 in hole. Install Cannon across the collar clamps every other jt. Clam son 236,238,240, and 242 box. 03:45 06:00 2.25 7,670 8,135 COMPZ RPCOh RCST Continue running 3-1/2" completion f/ 7670' to 8135' (jt # 257 in hole): Started running Tyco heat trace 2' f/ pin end ofjt #243. Installing continuous Mid joint clamps and dual across the collar clam s. 06:00 08:15 2.25 8,135 8,476 COMPZ RPCOh RCST Continue running 3-1/2" completion f/ 8135' to 8476' (jt # 268 in hole): Running Tyco heat trace. Installing continuous Mid joint clamps and dual across the collar clam s. 08:15 08:30 0.25 8,476 8,499 COMPZ RPCOti RCST Continue running 3-1/2" completion f/ 8476' to 8499' (make up pup, 3-1/2" x1" GLM, pup): Running Tyco heat trace. Installing continuous Mid joint clamps and dual across the collar clamps. Install a 1-1/4" stainless band above and below GLM f/ total of (2). Total of 9 stainless bands now in hole on strin . 08:30 11:15 2.75 8,499 9,182 COMPZ RPCOh RCST Continue running 3-1/2" completion f/ 8499' to 9182' (jt # 269 to jt # 290): Running Tyco heat trace and Awell/ Weatherford pressure guage line. Installing continuous Mid joint clamps and dual across the collar clamps. Testing pressure guage and heat trace every 1000'. Tested @ 8871'. Test heat trace to 2500 volts, OK. 11:15 11:45 0.50 9,182 9,182 COMPZ RPCOh PULD PU more Cannon clamps to rig floor. 11:45 13:00 1.25 9,182 9,560 COMPZ RPCOh RCST Continue running 3-1/2" completion f/ 9182' to 9560' (jt # 290 to jt # 302: Running Tyco heat trace and Awell/ Weatherford pressure guage line. Installing continuous Mid joint clamps and dual across the collar clamps. Testing pressure guage and heat trace every 1000'. Tested @ 9560'. Test heat trace to 2500 volts. 13:00 14:00 1.00 9,560 9,560 COMPZ RIGMN RGRP Hose on laydown machine developed a leak. Repair with new hose while ickin u more clam s. ~~ Time Logs + ~ Date From To Dur e th E. De th Phase Code Subcod~ OM 08/11/2006 14:00 18:00 4.00 9,560 10,530 COMPZ RPCOh RCST P Continue running 3-1/2" completion f/ 9560' to 10530' Qt # 302 to jt # 333): Running Tyco heat trace and Awell/ Weatherford pressure guage line. Installing continuous Mid joint clamps and dual across the collar clamps. Testing pressure guage and heat trace every 1000'. Test heat trace to 2500 volts. Replaced jt # 316 with jt # 339. Pick u remainin clam s. 18:00 20:30 2.50 10,530 10,660 COMPZ RPCOh RCST P Continue running 3-1/2" completion f/ 10530' to 10660' Qt # 302 to jt # 337 + 1-1/2' on 338): Running Tyco heat trace and Awell/ Weatherford pressure guage line. Installing continuous Mid joint clamps and dual across the collar clamps. PU wt 135k, SO wt 85k. Slack off to block wt of 70k @ 10660'. T to work mule shoe down. 20:30 21:00 0.50 10,660 10,660 COMPZ RPCOh RURD P PJSM, rig up to circulate w/ 2" circulatin hose. 21:00 21:30 0.50 10,660 10,660 COMPZ RPCOti CIRC P Circulate 100 spm w/ 2250 psi. Work string up 20' and down 20' to block wt. of 75k. PU wt 135k, SO wt 85k. 21:30 22:45 1.25 10,660 10,660 COMPZ RPCOti CIRC P Circulate bottoms up w/ mule shoe @ 10660' (CMU open @ 10515'). Circulate 100 spm w/ 2150 psi. Circ 7000 strokes. No MOBM noticed at the shakers, returns are 9.7 brine. 22:45 23:00 0.25 10,660 10,660 COMPZ RPCOh SFTY P PJSM for rigging down circulating hose and a ui ment. 23:00 23:15 0.25 10,660 10,660 COMPZ RPCOh RURD P Rig down circulating equipment. 23:15 00:00 0.75 10,660 10,330 COMPZ RPCOh TRIP T Pull out of hole standing back 3-1/2" 9.3 ppf L-80 EUE 8rd-mod tubing. Reel up Tyco heat trace and Weatherford I Wire f/ pressure guage. Remove Cannon clamps. POOH lay down jt # 338, then stand back 3-1/2" f/ to 10330' Jt # 326 in hole + 08/12/2006 00:00 06:00 6.00 10,330 6,231 COMPZ RPCOh TRIP T Pull out of hole standing back 3-112" 9.3 ppf L-80 EUE 8rd-mod tubing f/ 10330' to 6231'. Reel up Tyco heat trace and Weatherford I Wire f/ pressure guage. Remove Cannon clamps. Heat trace was run to end of jt #243. POOH, SLM, stand back jt # 326- #197 . 06:00 09:00 3.00 6,231 4,442 COMPZ RPCOh TRIP T Pull out of hole standing back 3-1/2" 9.3 ppf L-80 EUE 8rd-mod tubing f/ 6231' to 4442'. Reel up Weatherford I Wire f/ pressure guage. Remove Cannon clamps. POOH, SLM, stand back 't # 196- #140 . 09:00 09:45 0.75 4,442 4,442 COMPZ RPCOh PULD T Remove Cannon clamps f/ rig floor. Clear work area. ~.w ~,_~ j_n ~e -emm~ e w~® m Time Logs _ Date From To Dur 5. epth E. De th Phase Code Subcode OM 08/12/2006 09:45 12:00 2.25 4,442 1,817 COMPZ RPCOh TRIP T Pull out of hole standing back 3-1/2" 9.3 ppf L-80 EUE 8rd-mod tubing f/ 4442' to 1817'. Reel up Weatherford I Wire f/ pressure guage. Remove Cannon clamps. POOH, SLM, stand back 't # 139- #56 . 12:00 15:30 3.50 1,817 0 COMPZ RPCOh TRIP T Pull out of hole standing back 3-1/2" 9.3 ppf L-80 EUE 8rd-mod tubing f/ 1817' to surface.'. Reel up Weatherford I Wire f/ pressure guage. Remove Cannon clamps. POOH, SLM, stand back jt # 55- #8, then lay jts 7 to 1 with jewelry to pipe shed. Total of 235 clamps (across the collars- single f/ I Wire) (#303131) Total of 93 clamps (across the collars- dual f/ I wire and Heat trace (#303129) Total of 451 clamps (5' mid joint) (#303115) Total of 7 clamps (3-1/2' Mid joint) (#303132) Total of 5 clamps (3' mid jt) (#303128) Total of 2 clamps (2- 1/2' mid jt) (#303130) Total of 8 clamps (2' mid jt) (#303127) Total of 1 clamp (end shoe f/ heat trace) (#303132) Grand total of (802) Cannon clamps Total of (9) 1-1/4" stainless steel bands 15:30 15:45 0.25 0 0 COMPZ WELCT SFTY P PJSM on testing BOPE. 14 day test due today. Notified AOGCC inspectors @ approx 2130 hrs yesterday, 8-11-2006 . 15:45 17:15 1.50 0 0 COMPZ WELCT OTHR P RU to test BOP equipemnt. 17:15 18:00 0.75 0 0 COMPZ WELCT BOPE P 14 Day BOPE test. Test upper pipe rams (3-1/2x 6" variables) with 3-1/2" test joint. Test annular w/ 3-1/2" test joint. Test to 250 psi low and 3000 psi high. Hold each test for 5 min. Witness of test waived by AOGCC ins ector John Cris . 18:00 00:00 6.00 0 0 COMPZ WELCT BOPE P Continue 14 Day BOPE test. Test all valves, top pipe rams (3-1/2" x 6"), Annular, floor safety valve and IBOP to 250 psi low and 3000 psi high. Use 3-1/2" test joint to test with. Hold each test for 5 minutes.Test accumulator. Test gas detectors. Witness of test waived by AOGCC inspector John Cris . . m . ~ ~ _ _.._. ®~ .~ss~, ._._m...,..w....».,........-..~. em.~m.w ~ ,.. ®..,. ~~°~~ k m.~____~..~ ............ .. ~ ..~,..,,..... ~... ., ~ ~..,,,.e Time Logs Date __ From To Dur _ ,pth E De th Phase Code Subcod_e T OM ___ 08/13/2006 00:00 01:00 1.00 0 0 COMPZ WELCT OTHR T Pull test plug, rig down testing equipment. Blow down kill and choke lines. 01:00 02:00 1.00 0 0 COMPZ RPCOti RURD T Rig up to run 3-1/2" completion. MU 3-1/2" floor safety valve to 3-1/2" EUE crossover. 02:00 02:30 0.50 0 0 COMPZ RPCOti SFTY T Pre job safety meeting w/ rig crew, GBR, Baker Oil tools, Centralift and Weatherford. 02:30 03:00 0.50 0 137 COMPZ RPCOti RCST T PU/MU Baker 80-40 seal assembly (4.00" OD), locator, 3-1/2" pupjt, jt#1, 3-1/2" Camco 2.75" profile nipple, jt #2, x-o, xo pup jt, I-Pump TCS guage, x-o u 't, x-o, then 't #3. 03:00 04:15 1.25 137 232 COMPZ RPCOh OTHR T Connect Weatherford guage to TecTube I-wire. Connect 1/4" control line, Run the 3-1/2" pup jt, fluted wire protector, Baker 2.812" DB profile CMU, fluted wire protector, 3-1/2" pup jt, jt #4, 3-1/2" pup jt, ported nipple, 3-1/2" pup jt, then jt #5. Connect 1/4" stainless tubing f/ pressure guage to orted ni le. Check out wire, OK. 04:15 04:45 0.50 232 317 COMPZ RPCOh RCST T Run Jt 36, 3-1/2" pup jt, Camco 3-1/2" x1" KBMG GLM w/ dummy valve installed, 3-1/2" pup jt, then jt #7. (7) 1-1/4" stainless clamps in the hole to this point. (6) accross the collar clamps in the hole to this oint. 04:45 06:00 1.25 317 1,912 COMPZ RPCOh RCST T Start running 3-1/2" completion f/ derrick. Installing Cannon clamps. Checking line every 1000'. Recording PU and SO wt"s every 1000'. Depth @ 0600 hrs = 1912'. Jt # 58 in the hole. 06:00 09:15 3.25 1,912 4,536 COMPZ RPCOti RCST T Continue running 3-1/2" completion f/ derrick. Installing Cannon accross the collar clamps every collar to 4536' (Jt # 142). Checking wire every 1000'. Record PU and SO wt's every 1000'. Test line 3400' and 4536'. 09:15 09:45 0.50 4,536 4,536 COMPZ RPCOh PULD T PU more Cannon clamps to floor. 09:45 12:45 3.00 4,536 7,671 COMPZ RPCOh RCST T Continue running 3-1/2" completion f/ derrick. Installing Cannon accross the collar clamps every collar to 7671' (Jt # 142). Checking wire every 1000'. Record PU and SO wt's every 1000'. Test line 5476' and 7671'. 12:45 13:15 0.50 7,671 7,671 COMPZ RPCOh RURD Rig up heat trace lines in derrick. 13:15 14:45 1.50 7,671 8,476 COMPZ RPCOti RCST Continue running 3-1/2" completion f/ derrick. Installing Cannon accross the collar clamps every collar to 8476' (Jt # 268). Checking wire every 1000'. Record PU and SO wt's eve 1000'. i .m ~~ ~. _ ~~ ee.e ~ ~®..e ~ s~ _® ~~ ~. ~, Time Loc,~s _ Date From To Dur th E. De t_h Phase Code Subcode OM 08/13/2006 14:45 15:15 0.50 8,476 8,499 COMPZ RPCOh PULD T PU more clamps to floor. PU/MU glm after 't # 268. 15:15 16:45 1.50 8,499 9,247 COMPZ RPCOti RCST T Continue running 3-1/2" completion f/ derrick. Installing Cannon accross the collar clamps every collar to 9247' (Jt # 292). Checking wire every 1000'. Record PU and SO wt's every 1000'. Test line 8592'. 16:45 17:15 0.50 9,247 9,247 COMPZ RPCOh PULD T PU more clamps to floor. 17:15 18:00 0.75 9,247 9,750 COMPZ RPCOti RCST T Continue running 3-1/2" completion f/ derrick. Installing Cannon accross the collar clamps every collar to 9750' (Jt # 308). Checking wire every 1000'. Record PU and SO wt's eve 1000'. 18:00 20:15 2.25 9,750 10,660 COMPZ RPCOh RCST T Continue running 3-1/2" completion f/ derrick. Installing Cannon accross the collar clamps every collar to 10660' (Jt # 338). Checking wire every 1000'. Record PU and SO wt's eve 1000'. 20:15 20:30 0.25 10,660 10,709 COMPZ RPCOh RCST P Continue running 3-1/2" completion f/ derrick. Installing Cannon accross the collar clamps every collar to 10708.62' (18' in on jt # 339. Checking wire every 1000'. Record PU and SO wt's every 1000'. Tag on locator @ 10691.07' & mule shoe 10708.62'. 20:30 21:30 1.00 10,709 10,627 COMPZ RPCOh PULD P PU and break offjts # 339, 338 and 337. 21:30 23:00 1.50 10,627 10,665 COMPZ RPCOh HOSO P Space out with 6.07' pup after jt # 336, then x-o, then 4-1/2" jt made up to hanger. Install clamps on 4-1/2" as lowering to floor. Install penetrators into han er. 23:00 00:00 1.00 10,665 10,665 COMPZ RPCOh OTHR P Cut and install pigtails to both the heat trace and Tec Tube I wire. Rig down GBR equipment and extra clamps on floor. 08/14/2006 00:00 02:00 2.00 10,665 10,665 COMPZ RPCOh OTHR P Cut and install pigtails to both the heat trace and Tec Tube I wire. Rig down GBR equipment and extra clamps on floor. 02:00 04:30 2.50 10,665 10,704 COMPZ RPCOh OTHR P RIH and land tubing (mule shoe @ 10704.06') in Vetco Gray Multibowl. PU wt 125k, SO wt 85k. Run in upper and lower lockdown screws. Torque to 600 ft lbs. Test upper body seals on hanger to 250 psi and 5000 psi. Test lower hanger body seals to 250 psi and 5000 psi. Hold each test 10 min. Rig down sheaves in derrick f/ I wire and heat trace. Clear spools f/ rig floor. Prepare cellar for nippling down BOPE. Lay down 4-1/2" landing joint (4.409 MCA top thread on hanger). Remove lower annulus double valve, install com anion flan e. "s....._..,._~ _ ., t" c Cv & C3i ~,~ y ._~,.~._~...........,~~..»____.~..,......~,.... _.....3 Time Logs Date From To Dur th E. De th Phase Code Subcode OM 08/14/2006 04:30 05:00 0.50 0 0 COMPZ RPCOti OTHR P _ Install back pressure valve in tubing han er. 05:00 13:30 8.50 0 0 COMPZ RPCOh NUND P Cleaning pits and pollution pans under rig floor. Clear and clean rig floor. Nipple down kill and choke lines. Remove turnbuckles, flow line, flow ni le. O en doors on BOP's. 13:30 15:00 1.50 0 0 COMPZ RPCOh OTHR P Remove rams f/ cavities of BOP's. Clean out cavities. for level 1 inspection. Cleaning pits, windwalls and ollution ans. 15:00 17:30 2.50 0 0 COMPZ RPCOh NUND P Inspect rams w/ Hydril rep. Continue nippling down BOPE. Break bolts on riser/ wellhead. Break bolts on riser/BOP's. Celaning pits. Change out u er seal late on blind rams. 17:30 17:45 0.25 0 0 COMPZ RPCOh SFTY P PJSM on picking up BOP stack and riser, then setting back on stump. Cleanin its. 17:45 19:00 1.25 0 0 COMPZ RPCOh NUND P PU stack and riser, set back same. Cleanin its. 19:00 19:15 0.25 0 0 COMPZ RPCOh SFTY P PJSM on nippling up Vetco Gray tree. Cleanin its. 19:15 21:15 2.00 0 0 COMPZ RPCOh NUND P Nippling up Vetco Gray tree. Rig down choke lines. Test hanger void to 250 psi low and 5000 psi high, 10 min each, OK. Nippling up 2 1/16 IA accuated valve. 21:15 21:30 0.25 0 0 COMPZ RPCOti SFTY P PJSM on rigging up to test tree. 21:30 23:00 1.50 0 0 COMPZ RPCOh DHEQ P Test Tec tube wire f/ pressure guage, rading 1865 psi. Test heat trace (10.2 ohms 1-2, 2-3, 1-3). All OK. Pull BPV, install two way check. Fill tree w/ diesel. 23:00 00:00 1.00 0 0 COMPZ RPCOti DHEQ P Test tree to 250 psi low f/ 10 min. OK. Testing tree to 5000 psi. Recording on chart recorder. 08/15/2006 00:00 01:00 1.00 0 0 COMPZ RPCOh DHEQ P Continue to Test tree to 250 psi low f/ _ 10 min. OK. Testing tree to 5000 psi. Recordin on chart recorder. 01:00 01:15 0.25 0 0 COMPZ RPCOh DHEQ P Rig down tree test equipment. Clean Cellar area. 01:15 01:30 0.25 0 0 COMPZ RPCOti SFTY P PJSM with crew. Discuss Safety Issues and procedure for Freeze protecting well with Diesel. Designate S ill Cham ion. 01:30 01:45 0.25 0 0 COMPZ RPCOh FRZP P Rig up lines in cellar to tree. Pressure test lines to 2500 PSI. Good test. 01:45 02:00 0.25 0 0 COMPZ RPCOh FRZP P Pump Freeze protect Diesel, pumping rate gradually up to 25 BBLS pumped awa 600 PSt. 02:00 03:30 1.50 0 0 COMPZ RPCOh FRZP P Allow well to U-tube until dead. Observe shut in pressure @ 60 PSI on tubin . mn ~ ~~~ a ~~ ®~~.,~ w _~w~~ ®~ m .®® j ~~ _ ~ ~ ._.~__ _. ~_ ~s.°e _ -_J t~~~ ~ ~~ cs t~ _ __ _... a.. . __ m s~ Time Logs ~ Date From To Dur th E. De th Phase Code Subcode OM 08/15/2006 03:30 04:00 0.50 0 0 COMPZ RPCOti _ FRZP _ P Blow down & rig down all lines in cellar.Secure tree, and all valves. 04:00 04:30 0.50 0 0 COMPZ RPCOh OTHR P Rig up Vetco Gray lubricator & install BPV as per VG rep. Record well shut in pressures. Upper annulus = 0 PSI, Lower Annulus = 250 PSI, and Tubing = 25 PSI. SIMOPS: Rig down Rockwasher, and blow down all steam lines to it module. 04:30 05:00 0.50 0 0 COMPZ RPCOh OTHR P Install All companion flanges & gauges on tree. Continue Rig down Rockwasher, and blow down all steam lines to pit module. Clean out Pollution an under Rota Table. 05:00 06:00 1.00 0 0 COMPZ RPCOh OTHR P Rig down Cellar equipment, Mud lines. Blow down Steam to rig floor.Continue Rig down Rockwasher, and blow down all steam lines to pit module. Clean out Pollution pan under Rotary Table. Prepare rig floor for Skid. Lower support braces. Rig released @ 0600 HRS, 8/15/06 ___~.__ve_e~ ~m ___-___.m~a ~~.~ .eem~_w ___~®®®e ~~ ~s~®~~~~.m.~ _~a_w~ C] Email to:jim.regg~alaska.gov; OPERATOR: FIELD /UNIT! PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO MISSION Mechanical Integrity Test 08/31/06 KRU / 1J-1 Inc_ Packer Pretest Initial 15 Min. 30 Min. We11 1J-109 T In'. N TVD 3,728' Tubi 280 27 235 221 Interval O P.T.D. 2060500 T test P Test 1500 Cali 260 3, 2,890 2,975 P/F P Notes: MITIA prior SPJP service OA 190 200 200 Well T In". TVD Tubi Irerval P.T.D. T test Test Cali PtF Notes: OA Well T In". TVD Tubi Interval P.T.D. T test Test P/F Notes: OA Well T 1n'. TVD TutH Interval P.T.D. T test Test P/F Notes: OA Well T Iri . TVD Tu " Interval P.T.D. T test Test Casa P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus NAAwriEorirrg P =Standard Pressure Test R = IMemal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes 1=Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O = Otiier (describe in notes) MIT Report Form BFL 11127/07 MIT KRU 1 J-109 08-31-06x1s (2).xls FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mike Greener Staff Drilling Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-11 Sundry Number: 306-285 Dear Mr. Greener: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-re erenced well. Please note that any disposal into the surface/productio casing annulus of a well approved for annular disposal must comply ith 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 rants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 's considered timely if it is received by 4:30 PM on the 23rd day following he date of this letter, or the next working day if the 23rd day falls on a oliday or weekend. A person may not appeal a Commission decision to uperior Court unless rehearing has been requested. Sincerely C DATED this~~day of August, 2006 Encl. ConocoPhillips Post Office Boz 100360 Anchorage, Alaska 99510-0360 Phillip Hayden Phone (907) 265-6481 Fax: (907) 265-1336 Email: Phillip.hayden@conocophillips.com August 16, 2006 Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 Annular Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that 1J-109 be permitted for an a result of drilling operations, per regulation 20 ACC 25.080. It is intended on 1J-109 approximately October 1, 2006. Please find attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe) 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during ce 8. Wellbore schematic 9. Formation LOT on 13-3/8" x 9-5/8" casing annulus with daily Drilling Re 10. Plan View of Existing Adjacent Wells 11. Details on all planned and existing wells within'/4 mile of 1J-109 at the si 1J-118, and the 1J-120). With reference to point ~ above, this deeper LOT occurred at a lower equiv~ shoe test. Therefore we conclude that waste will not migrate above the confir with sustained surface pressures that will cause pressures at the surface shoe t If you have any questions or require further information, please contact Mike Thomas at 265-6830. Sincerely, Mike Greener Staff Drilling Engineer Cc: 1J-109 Well File Randy Thomas ATO-1576 Sharon Allsup-Drake ATO-1530 RECEIVED AUG 2 1 2006 Oil & Gas Cons. Commission Anchorage ~lar pumping of fluids occurring as begin annular disposal operations b Daily Drilling Report. job. casing shoe (1J-107, 1J-111, ;nt mud weight than the casing ig zone provided we do not inject be in excess of the shoe FIT/LOT. at 263-4820, or Randy STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM 10 AUG ~ 1 LUUb ANNULAR DISPOSAL APPLICAT O Alaska ~~I & Gas Cons. Gomm~ssion 20 AAC 25.080 1. Operator Name: ConocoPhillips Alaska, Inc. 3. Permit to Drill No: 06-050 , 4. API Number: 50- 29-23307-00 ' 2. Address: P.O. Box 100360 5. Well Name: J-109 Anchorage, Alaska 99510-0360 6. Field: est Sak 7. Publicly recorded wells 8. Stratigraphic descriptio n a) Interval exposed to K-13 a) All wells within one- Only future wells will ~ within the 114 mile radius of open annulus: quarter mile: the fJ-109 surface shoe. They are-1J-107, 1J-111, 1J-118, attd the 1J-120. b) Waste receiving K-13 zone: b) water wells within one mile: NONE c) Confinement: K-13 9. Depth to base of 10. Hydrocarbon zones permafrost: 1,403' above waste receiving none zone: 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 0 bbls 6.7 to 12 ppg 1,859 psi 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 BBLS Drilling mud, drilling cuttin s, reserve pit fluids, cement-contaminated drilling mud, completion fluids, di sel, formation fluids associated with the act of drilling a well, drill rig was fluids, cement rinsate, domestic waste water, any added water needed to fa ilitate pumping of drilling mud or drilling cuttings, 16. Estimated start date: and any other fluids asso fated with drilling a well. Densities range from diesel to 12#/gal. Maximum vol me to be pumped is 35,000 bbls. 1-Oct-06 17. Attachments: WeA Schematic (Include MD and TVD) ~ Cement Bond Log (if required) ^~ FIT Records w/ LOT Graph Intermediate casing and ementing data Surf. Casing Cementing Data ^~ Other 0 •13-3/8" x 9-5/8" annular OT data Daily drilling reports, for ementing periods for both casing strings. 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~/~%`~~%~ ~i ~ Lj~Y. o~~ Title: ~ ,~ 1, ~~ f I/S(Ce Printed Name: i ~(~ Phone Number: 3-• 'j~ S''a0 Date: ~ ~p-~06 Commission Use Onl Conditions of approval: ~ OT review and approval "'(~Co ~ Subsequent form Approval required: number. •' Approved APPROV D S ~~/~J'V BY by: COMMISSIONER THE COM ISSION Date: ~ ~'~~ L--'' R~ S ~F~, sE? o ~~ 20D6 • ~ ~~~l~r~~•~4 Form 10-403RD Rev.6/2004 ~ ~ ~ ~ ~ n' ~,It~STRUCTIONS ON REVERSE Submit in Duplicate Annulu3~bisposal Transmittal Form - W~f 1J- A(~('TC(' Regulations 20 AA(; 25.080 (hl 1 Desi nation of the well or wells to receive drillin wastes: 1 J-109 2 The depth to the base of freshwater aquifers and permafrost, i No Aquifers / Base P rmafrost = +/- 1,403' SSTVD resent. 3 A stratigraphic description of the interval exposed to the open From the 13-3/8" sho to the cement top all that is open is annulus and other information sufficient to support a interbedded clayston , siltstone and shale with occasional commission fmding that the waste will be confined and will minor non-hydrocarb n bearing sands. not come to the surface or contaminate freshwater. 4 A list of all publicly recorded wells within one-quarter mile See attached map ind cati,ng 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 e drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-co taminated drilling mud, completion fluids, diesel, formati n fluids associated with the act of drilling a well., drill r g wash fluids, domestic waste water, any added water nee ed to facilitate pumping of drilling mud or drilling cuttings, a d any other fluids associated with drilling a well. Dens ties 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 waste under h 3 of this section. 7 An estimate of maximum anticipated pressure at the outer Maximum anticipate pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations i 1,859 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: semen ing 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 mmary 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/FI 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 1J-137, 1J-115, 1J-1 3, 1J-118, 1J-105, 1J-120, 1J-107, 1J- will be generated. 122, 1J-102, 1J-182, 1J-136, 1J-180, 1J-160, 1J-158, 1J-162, 1J-135 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com Hance 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 (tor submital with Annular Disposal Application) v°~s;°~ t o-J,°~os Well 1J -1 09 Assumptions Date 8/15 /2 006 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 0.432 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.43 psi/ft Header Pressure (for wells on gas lift) 0 psi on h Maximum Fluid Density to avoid Burst of Surface Casing U Pburst85°a -PHydrostatic +PApplied - PFomtation 4,267 = ( 2,306 * 0.052 * MW,,,~ ) + 1500 - ( 0.4320 * 2,306 ) r M MWmax = 31.4 PPg 2,306 TVD Surface Casing Stringy Size 13.375 in .o _ Weight 68 ppf '~ '~ Grade L 80 on k' "~' r 5,020 burst 100 /o Psi .~ Pburst85% 4,267 psi U Depth of Shoe 2,306 ft FIT/LOT (u7 Shoe 15.5 ppg or 1,859 psi FIT/LOT for Annulus 12.4 ppg Max Surf. Pressure 1,500 psi c~ ~IY)C Last. 'u 7.350' MD ' TVD 3,014 Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% -PHydrostatic +PApplied - PGasGradient - PHeader 2,627 = ( 3,014 * 0.052 * MW,,,~ ) + 1,500 - ( 0.4300 * 3,014) - 0 MWmax = 15.5 PPg 3.5 "Tubing 2nd Casing String Size 9.625 in 3,760 TVD Weight 40 ppf Grade L 80 Pcollapsel00% 3,090 psi Pcollapse85°/ 2,627 psi Top of Cement 3,014 ft Gas Gradient 0.43 psi/ft Max Surf. Pressure 1,500 psi Header Press 0 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax auo,tiable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable - ( 2,306 * .052 * 15.5 ) Pmax allowable - 1,859 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Well 1J-109 Assumptions Date 8/15/2006 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 0.432 psi/ft Version LO-Jan'OS Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 0 psi un Maximum Fluid Density to avoid Burst of Surface Casing U Pburst85% -PHydrostatic +PApplied - PFormation _ 4,267 = ( 2,306 * 0.052 * M Wm~ ) + 1500 - ( 0.4320 * 2,306 ) MWmaX = 31.4 PPg 2,306 TVD on c .~ ca U TOC Est. c 7,350' MD \ 3,014' TVD 3.5 "Tubing \3.760 TVD Surface Casing Strin Size 13.375 in Weight 68 ppf Grade L 80 rburstloo°ro 5,020 Ps' Pburst85% 4,267 Ps' Depth of Shoe 2,306 ft FIT/LOT n Shoe 15.5 ppg or 1,859 psi FIT/LOT for Annulus 12.4 ppg Max Surf. Pressure 1,500 psi Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85°o -PHydrostatic +PApplied - PGasGradient - PHeader 2,627 = ( 3,014 * 0.052 * MWm~ ) + 1,500 - ( 0.0700 * 3,014) - 0 = 8 53 MW C~SS~Ie.,.~S ~GS`\~~ W . max PPg S v t-~-~ C - E ~~sS VrE 2nd Casing Size String 9.625 ~ in ~ V`~` ` ~O"~JE~C;,~~~ Weight 40 ppf pJ~~r ``~~~ ~S ~ ~' ^ ` Grade L 80 Pcollapse100% 3,090 [ ~ ,/ psj `)~C ht~~ e /~~ 1-1 ~ Pcollapse85"~° 2,627 psi rJ ~ Top of Cement 3,014 3U ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 0 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax avowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable - ( 2,306 * .052 * 15.5 ) Pmax allowable - 1,859 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". ~f, g"~ Casing Detail Report 1J-109 .:..~ Surface Casin Casing Description Set Depth (ftKB) Run Date Set Tension (kips) Surface 4,151.6 7/14/2006 Centralizers Scratchers 21 Casin Com onents Mk-up Tq Itembescription OD (in) Wt (Ibs/ft) Grade Top Thread Jts Len (ft) Top (ftKB).. Btm (ftKB) ' (ft-Ibs) Class Max OD (in) ID (in) Casing Joint (Cut off 13 3/8 68.00 L-80 1 36.98 43.2 80.2 9,000 13.375 12.415 joint to load shoulder) Casing Joints 13 3/8 68.00 L-80 Buttress 21 894.23 80.2 974.4 9,000 14.410 12.415 Thread Casing Pup Joint 13 3/8 68.00 L-80 Buttress 15.01 974.4 989.4 9,000 14.410 12.415 Thread TAM Port Collar 13 3/8 68.00 L-80 Buttress 1.73 989.4 991.2 9,000 15.520 12.415 Thread Casing Pup Joint 13 3/8 68.00 L-80 Buttress 14.75 991.2 1,005.9 9,000 14.410 12.415 Thread Casing Joints 13 3/8 68.00 L-80 Buttress 72 3,059.83 1,005.9 4,065.8 9,000 14.410 12.415 Thread Float Collar 13 3/8 68.00 Buttress" 1.45 4,065.8 4,067.2 9,000 14.410 12.378 Thread Casing Joints 13 3/8 68.00 L-80 Buttress 2 82.73 4,067.2 4,149.9 9,000 14.410 12.415 Thread Float Shoe 13 3/8 68.00 1.70 4,149.9 4,151.6 14.410 12.378 Page 1/1 Report Printed: 8/15/2006 ~~~``~ .. p Cement Detail Re ort 1 J-109 urface Casing Cemenfi Primary Job Type DRILLING ORIGINAL Job Category DRILLING AFE / RFE 10139809 Start Date 7/6/2006 Spud Date 7/9/2006 End Date Cement Details Description Surface Casing Cement Gementing Start Date 7/14/2006 13:38 Cementing End Date 7/14/2006 17:45 Wellbore Name 1J-109 Comment 250 bbls 10.7 ppg lead ASLite circulated to s urface. Cement Sta es Sta e # 1 Description Surface Casing Cement Objective Cement surface casing Top (ftKB) 43.2 Bottom (ftKB) 4,153.0 Full Return? Yes Cmnt Rtrn (... 250.0 Top Plug? Yes Btm Plug? Yes Q (start) (bbllmin) 7 Q (end) (bbl/min) 3 Q (avg) (bbl/min) 7 P (£nal) (psi) 600.0 P (bump) (psi) 1,100.0 Recip? Yes Stroke (ft) Rotated? No Pipe RPM (rpm) Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Circulated 250bb1s AS Lite lead cement to su rface Cement Fluids & Additives Fluid Fluid Type CW 100 Fiuid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) 50.1 Yield (ft'lsack) Mix H2O Ratio {gal/sa... Free Water (%) Density (Ib/gal) 8.30 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type MudPush Fluid Description Estimated Top (ftKB) 4,153.0 Est Btm (ftKB) 4,153.0 Amount (sacks) Class Volume Pumped (bbl) 48.9 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) 10.50 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type AS Lite Fluid Description Estimated Top (ftKB) 43.2 Est Btm (ftKB) 3,573.0 Amount (sacks) 800 Class AS cite Volume Pumped (bbl) 648.9 Yield (ft'/sack) 4.45 Mix H2O Ratio (gal/sa... 20.72 Free Water (%) Density (Ib/gal) 10.70 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive S-001 Type Accelerator Concentration 1.5 Conc Unit label %BWOC Additive D-046 Type Antifoam Concentration 0.6 Conc Unit label %BWOC Additive D-065 Type Dispersant Concentration 0.5 Conc Unit label %BWOC Additive D-079 Type Extender Concentration 1.5 Conc Unit label %BWOC Additive D-124 Type Extender Concentration 50.0 Conc Unit label %BWOC Additive D-044 Type Salt Concentration 9.0 Conc Unit label %BWOW Additive D-053 Type Thixotrop Concentration 30.0 Conc Unit label %BWOC Fluid Fluid Type DeepCrete Fluid Description Estimated Top (ftKB) Est Btm (ftKB) 4,153.0 Amount (sacks) 220 Class DeepCRETE Volume Pumped (bbl) 93.3 Yield (ft'/sack) 2.46 Mix H2O Ratio (gal/sa... 7.51 Free Water (%) Density (Ib/gal) 12.00 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive D-186 Type Accelerator Concentration 0.05 Conc Unit label gal/sx Additive D-046 Type Antifoam Concentration 0.6 Conc Unit label %BWOC Page 1/2 Report Printed: 8/15/2006 ~ ~' Cement Detail Report ~r 3}~ ° ,_ 1J-109 y.... ,y ~ • ~. Surface Casing Cement Additives Additive Type Concentration Conc Unit label D-124 Extender 38.0 %BWOC Additive Type Concentration Conc Unit label B-160 Low Temp Dis 0.2 %BWOC Additive Type Concentration Conc Unit label D-178 Silica 24.0 %BWOC Page 2/2 Report Printed: 8/15/2006 .I - ' Daily Drilling Report =~-~. 1 J-109 Report Date: 7/13/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 8 4.66 3, 934.0 4,153.0 219.00 1 J-109 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 7/9/2006 DOYON 15 WEST SAK Development 16,636.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ftlhr) 10139809 4,668,037.00 75.3 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Conductor, 122.OftK6 4 1/2 14,218.00 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Running 13-3/8" @ 3765' @ 060 0 hrs. 116,452.57 1,210,709.30 24hr Forecast Daily Mud Cost Cummulative Mud Cost Run 13-3/8" surf casing, circ, cement, set slips, N/D, NU, change annulus 20,878.57 93,912.80 Last 24hr Summary Drill 16" surface hole to 4153' MD (2306.1 TVD), BR to 3870', POOH to 2500', RIH, circ, POOH, UD BHA, RU/Run 13-3/8" surf asing. General Remarks Weather Head Count Rig on Hi-Line 34 deg, no wind 48.0 Supervisor Title Fred Herbert Rig Supervisor Granville Rizek Rig Supervisor Time Lo Start End Time Depth Start Depth End Time Time Dur (hrs) Phase. Op Code OpSub-Code P-N-T Trbl Code (ftKB) (ftKB) Comm/Operalion 00:00 04:30 4.50 SURFAC DRILL DDRL P 3,934.0 4,153.0 Directional Drill 16" surface hole w/ 8" Sperry drill 415 lobe - 5.3 stage mtr w/ 1.15 deg bend from 3934' to 4153' (219') (TVD = 22306'). ART = 1.26 hrs, AST = 1.65 hrs. Total hrs this run = 15.13 hrs. Total hrs on bit = 34.81 hrs., Total hrs on jars = 54.02 hrs, 0-20k WOB, 80 rpm's, 143-208 mtr rpm, 550-800 gpm w/ 9.3 ppg MW, on bottom press 1520-2480 psi, off bottom press 1280-2290 psi, on bottom torque 10-15k ft/Ib, off bottom torque 8-12k ft/ Ib, PU wt 160k, SO wt 95k, Rot wt 122k. Adding water @ 40-60 bph 04:30 04:45 0.25 SURFAC DRILL SFTY P 4,153.0 4,153.0 PJSM on backreaming out of hole while circ 2+ BU. 04:45 06:00 1.25 SURFAC DRILL CIRC P 4,153.0 3,965.0 Backream out of hole slow f/ 4153' to 3965' (188'). Pulling speed 2.5 to 3.5 ft/min. Pumping 900 gpm w/ 3050 psi. Rotate 90 rpm w/ 7-12k ft/ Ib torque. 06:00 .07:15 1.25 SURFAC DRILL CIRC P 3,965.0 3,870.0 Continue backreaming out of hole slow f/ 3965' to 3870' (95'). Pulling speed 2.5 to 3.5 ft/min. Pumping 900 gpm w/ 3050 psi. Rotate 90 rpm w/ 7-12k ft/ Ib torque. Total volume pumped while backreaming was 3125 bbls. (3+ BU) 07:15 08:45 1.50 SURFAC DRILL WPRT P 3,870.0 2,437.0 POOH on elevators f/ 3870' to +/-2500'. Monitor well on trip tank. 08:45 10:00 1.25 SURFAC DRILL WPRT P 2,437.0 4,153.0 RIH on elevators f/ 2437' (2306'TVD) to 4153' MD. Tagged bottom, no problems. 10:00 13:00 3.00 SURFAC DRILL CIRC P 4,153.0 3,778.0 Circulate and condition hole w/ 753 gpm w/ 2200 psi. Rotate 40 rpm w/ 8-9k ft Ib torque. PU Gassing tools to rig floor. Mix dry job. Backreamed 5 stands f/ 4153' to 3778' while circ, standing back stands while circ. Circulate total of 2663 bbls while cleaning up hole after short trip. 13:00 13:30 0.50 SURFAC DRILL CIRC P 3,778.0 3,778.0 Monitor well, OK. Pump 20 bbl dry job. Blow down top drive. 13:30 16:30 3.00 SURFAC DRILL TRIP P 3,778.0 73.0 Continue POOH f/ 3778', SLM, UD ghost reamer, stand back HWDP and jars, stand back nm flex collars to 73' 16:30 17:00 0.50 SURFAC DRILL OTHR P 73.0 73.0 Download Sperry Sun MWD. PU more casing equipment to rig floor. Clear and clean rig floor. 17:00 18;00 1.00 SURFAC DRILL PULD P 73.0 0.0 UD BHA #2. SLM, no corrections. 18:00 20:45 2.75 SURFAC CASING RURD P 0.0 0.0 RU to run 13-3/8" 68ppf L-80 BTC casing. 20:45 21:15 0.50 SURFAC CASING SFTY P 0.0 0.0 Held PJSM w/ crew on running 13-3/8" surface casing. Latest BOP Test Data Date Comment Page 1/2 Report Printed: 8/15/2006 i~ Daily Drilling Report , , ~T-~ _ 1 J-109 . ..• Report Date: 7/13/2006 Time Lo Start End Time Depth Start Depth End Time Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code - (ftKB) (ftKB) Comm/Operalion 21:15 00:00 2.75 SURFAC CASING RNCS P 0.0 1,271.0 Run 13-3%8" surface casing: 13-3/8" 68 ppf L-80 BTC. Circ 30 bbls thru float equip @ 112' removing air from shoe joints prior to leaving conductor shoe. 30 joints in hole @ midnight = 1271'. Good displacement. Record PU and SO wt's every 5 joints. Note: Installed centralizers: 10' above shoe, then collar of jt # 1, then collar of jt # 3-17. Baker locked to pin of #4 joint. Mud Check Data YP Calc Gel (10s) Gel (10m) Gel (30m) HTHP Fitt Density Temp Solids, Corr. Type Depth (ftKB) Dens {Iblgal) Vis (s/qt) PV Calc (cp) (Ibf/100ft') (Ibf/100ft') (Ibf/100ft') (Ibfl100ft') MBT (Ib/bbl) (mL/30min) pH (°F) (%) Spud Mud 4,153.0 9.00 72 20.0 30.000 15.000 33.000 37.000 20.0 8.4 1.5 In'ection Fluid Fluid Source From Lease (bbl) Destination Note Cuttings 1J-109 22.0 DS 4 G&I cu yds Water Based Mud 1J-109 720.0 1R-18 bbls Drill Strin s: BHA No. 2 - Surtace Tan ent / Bit Run No. 2 - 16in Hu hes, MX-1, 6045785 Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (132") IADC Bit Dull String Wt (10001bf) WOB (max) (100... WOB (min) (1000... 2,528.0 4,153.0 1-1-WT-A-E-2-ST-TD 0 0 Drill Strin Com onents Jts Item Description OD (in) ID (in) Top Conn Sz (in) Top Thread Cum Len (ft) 1 8" SperryDrill Lobe 4/5 5.3 stg 8 3.500 0 H-90 30.16 1 Non Mag Pony Collar 8 8.000 0 H-90 35.98 1 Integral blade stabilizer 8 8.020 0 H-90 43.50 1 Non Mag Crossover Sub 8 7.910 0 REG 45.15 1 8" MWD Directional Only 8 1.920 0 H-90 70.52 1 Non-Mag Float Sub 7.97 2.750 0 H-90 72.99 1 Non-Mag Flex Collar X 1 7.65 2.880 O H-90 103.98 1 Non-Mag Flex Collar X 1 7.65 2.880 O H-90 134.97 1 Non-Mag Flex Collar X 1 8 2.880 O H-90 166.01 1 Dailey Jars W/ Slinger 7.73 3.000 0 IF 206.28 20 20 X HWDP 5 3.000 0 IF 821.57 5 5" Drillpipe 5 4.270 0 IF 999.57 1 Ghost Reamer 5 3.000 0 IF 1,005.57 55 5" Drillpipe to surface 5 4.270 0 IF 2,688.03 Drillirr Parameters Drilling Time Sliding Hrs Cum Drill 0 (flow) Start (ftKB) End (ftKB) (hrs) (min/ft) Cum Depth (ft) Time (hrs) Int Depth (ft) (gPm) WOB (Ibf) RPM (rpm) SPP (psi) Drill Tq 3,934.0 4,153.0 2.91 1,625.00 15.13 219.00 550 15.0 80 1,520.0 15,000.0 Wel /bores Wellbore Name Wellbore API/UWI 1J-109 500292330700 Section Size (in) Act Top (ftKB) Act Btm (ftKB) Start Date End Date' PROD1 CON D 1 42 43.2 121.2 12/21 /2005 12/27/2005 SURFAC 16 121.2 4,153.0 7/9/2006 7/13/2006 INTRMI 12 1/4 4,153.0 11,004.0 7/17/2006 7/24/2006 Plug Back 0 10,850.0 11,004.0 7/24/2006 7/30/2006 Surve Data MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS (°l100ft) 4,006.02 77.78 77.74 2,277.46 -537.29 537.29 2,679.88 2.30 4,006.02 77.78 77.74 2,277.46 -537.29 537.29 2,679.88 2.30 4,098.46 79.02 77.39 2,296.05 -556.79 556.79 2,768.31 1.39 4,098.46 79.02 77.39 2,296.05 -556.79 556.79 2,768.31 1.39 Page 2/2 Report Printed: 8/15/2006 i(: ~~ ~~ Daily Drilling Report q-~~~ ~' ; 1 J-109 Report Date: 7/14/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 9 5.66 4,153.0 4,153.0 0.00 1 J-109 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 7/9/2006 DOYON 15 WEST SAK Development 16,636.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ftlhr) 10139809 4,668,037.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 4,151.6ftKB 4 1/2 14,218.00 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost N/D riser on 20" annular. 732,927.86 1,943,637.16 24hr Forecast Daily Mud Cost Cummulative Mud Cost Set slips, rough cut 13-3/8", UD jt #97 & cutoffjt (#96)N/D diverter, Weld on adapter, & componets, NU Vetco 11,342.86 105,255.66 Gay wellhead, NU BOPE, change element in hydril. Last 24hr Summary Finish running 13-3/8" casing, circ, change out collar of jt #97, circ, PJSM, cement 13-3/8", displ cement, bump plug, CIP 1745 hrs 7/14/2006, RID csg tools, clean flow line and stack, PU diverter, setting slips General Remarks Weather Head Count Rig on Hi-Line 43 deg, calm, cloudy 48.0 Supervisor Title Fred Herbert Rig Supervisor Granville Rizek Rig Supervisor Time Lo Start Time End. Time Dur (hrs) Phase Op Code OpSub-Code Time P-N-T Trbl Code Depth Start (ftKB) Depth End (ftKB) Comm/Operation 00:00 00:30 0.50 SURFAC CASING RNCS P 1,271.0 1,500.0 Run 13-3/8" surface casing: 13-3/8" 68 ppf L-80 BTC f/ Jt # 31 (1271'). Good displacement. Record PU and SO wt's every 5 joints. Run to half way in on jt # 36 (1500'). taking weight. 00:30 00:45 0.25 SURFAC CASING CIRC P 1,500.0 1,527.0 Insert Frank's fillup tool, establish circ. pump @ 4bpm w/ 200 psi. Wash down jt # 36 f/ 1500' to 1527' due to casing taking wt (70k SO wt). Circulate 50 bbls. 00:45 02:15 1.50 SURFAC CASING RNCS P 1,527.0 2,500.0 Continue RIH w/ 13-3/8" 68 ppf L-80 BTC casing f/ 1527' to 2500'. Record PU and SO wt's every 5 joints. Monitor displacement. 02:15 03:30 1.25 SURFAC CASING CIRC P 2,500.0 2,500.0 Insert Frank's fillup tool. Circulate down joint # 59. Recip f/ 2500' to 2480'. 4bpm w/ 320 psi. 5bpm w/ 240 psi final circ rate and pressure.PU wt before circ was 270k, after 235-240k. SO wt before circ 95k, after 135k. Circ total of 282 bbls (BU = 188 bbls). Returns weight as much as 9.9 ppg. 03:30 04:15 0.75 SURFAC CASING RNCS P 2,500.0 3,145.0 Continue RIH w/ 13-3/8" 68 ppf L-80 BTC casing f/ 2500' to 3145' (jt # 74 in hole). Record PU and SO wt's every 5 joints. Monitor displacement. 04:15 04:30 0.25 SURFAC CASING RNCS P 3,145.0 3,177.0 PU and install TAM port collar w/ 15' pup jts on each end. Record PU and SO wt's every 5 joints. Monitor displacement. Note: Installed centralizer on collar of jt # 74 and on pup above TAM. 04:30 06:00 1.50 SURFAC CASING RNCS P 3,177.0 3,765.0 Continue RIH w/ 13-3/8" 68 ppf L-80 BTC casing f/ 3177' to 3765' Qt # 88 in hole). Record PU and SO wt's every 5 joints. Monitor displacement. Washed jt # 87 down f/ 3680' to 3722' pumping 5bpm w/ 220 psi. PU wt w/ pumps on 280k, with out pumps 310k. SO wt with pumps 110k, with out pumps 100k. Note: Calculated idsplacement f/ 90 joints = 95 bbls, actual 79 bbls. 06:00 06:45 0.75 SURFAC CASING RNCS P 3,765.0 4,153.0 Continue RIH w/ 13-3/8" 68 ppf L-80 BTC casing f! 3765' to 4153' (jt # 97 in hole minus 3", # 98 above table). Tag bottom of hole. Record PU and SO wt's every 5 joints. Monitor displacement. Washed jt # 97 down f/ 4136' to 4145" pumping 6 bpm w/ 390 psi. PU wt w/ pumps on 300k.S0 wt with pumps 135k. Note: Installed centralizer on collar of jt # 94 and jt # 95. Latest BOP Test Data Date Comment Page 1/3 Report Printed: 8/15/2006 Daily Drilling Report _.f_?eAr,i . . 1 J-109 .. Report Date: 7/14/2006 Time Lo Start End Time Depth Start Depth End Time` Time;:. Dur (hrs) .Phase Op Code.. OpSub-Code P-N-T Trbl Code (ftKB) (ftKB) Comm/Operation.. 06:45 07:15 0.50 SURFAC CASING CIRC P 4,153.0 4,153.0 Circulate 7 bpm w/ 390 psi. Circualte 170 bbls. 07:15 08:30 1.25 SURFAC CASING OTHR P 4,153.0 4,151.0 Remove jt # 98 from string. UD same. Bad threads on collar of jt # 97, pin of jt #98.. Ordered new collar f/ box. 08:30 09:45 1.25 SURFAC CASING CIRC P 4,151.0 4,143.0 Circ w/ Frank's fillup tool. Establish circ, stage rate f/ 5 bpm to 7 bpm w/ 390 psi. Circ total of 350 bbis. 09:45 10:00 0.25 SURFAC CASING SFTY P 4,151.0 4,151.0 PJSM on rigging down Frank's fillup tool. Changing out bad collar. Rigging up cement head. 10:00 11:15 1.25 SURFAC CASING RURD P 4,151.0 4,151.0 R/D Frank's fillup tool. Blow down top drive. Replace collar on jt #97. 11:15 11:45 0.50 SURFAC CEMENT RURD P 4,151.0 4,151.0 RU dowel) cementing head. RU lines to circulate. 11:45 13:00 1.25 SURFAC CEMENT CIRC P 4,151.0 4,151.0 Circulate and condition mud and hole f/ cementing 13-3/8" casing.. Circulate @ 70 spm (7bpm) w/ 220 psi, 25% flow line reading. Circ total of 530 bbis. Total volume circulated prior to cement job = 950 bbis. Final mud wt 9.1 ppg w/ 61 vis in, 9.2ppg w/ 65 vis out. 13:00 13:30 0.50 SURFAC CEMENT SFTY P 4,151.0 4,151.0 PJSM on cement job w/ Rig team, dowel/ and APC. 13:30 16:15 2.75 SURFAC CEMENT OTHR P 4,151.0 4,151.0 Dowell pump 10 bbis CW100, test lines to 3500 psi, pump 40 bbls CW100, 50 bbis mud push w/ red dye (10.5 ppg), Drop bottom plug. Pump 648.9 bbls ASI cement (10.7 ppg), follow w/ 93 bbls DEEPCrete tail (12.0 ppg). Drop top plug. pump 20 bbls water. Switch displacement to rig. 16:15 18:00 1.75 SURFAC CEMENT DISP P 4,151.0 4,151.0 Displace cement w/ rig pumps. Recip casing till 100 bbis into displacement. Displace @ 7.1-6.7 bpm w/ 370-650 psi till last 33 bbl, slow to 3 bpm w/ 540-600 PSI. Bump plug w/ 587.2 bbis mud pumped. Final circ pressure 600 psi, bump and hold 1100 psi f/ 5 min. CIP @ 1745 hrs 7/14/2006. 250 bbls of good 10.7 ppg cement circulated to surface. 18:00 19:00 1.00 SURFAC CEMENT RURD P 4,151.0 4,151.0 Rig down casing tools and cementing equipment. 19:00 19:30 0.50 SURFAC WELCTL NUND P 4,151.0 4,151.0 Remove 16" diverter line f/ knife valve. Clean cement f/ surface equipment. 19:30 21:45 2.25 SURFAC WELCTL OTHR P 4,151.0 4,151.0 Rg up to PU 20" Diverter w/ riser. Cleaning pits. 21:45 23:00 1.25 SURFAC WELCTL OTHR P 4,151.0 4,151.0 Trying to PU diverter stack. Remove lockdown bolts f/ slips. Working side to side to free up assembly. Finally pulled diverter stack free f/ conductor. Cleaning pits. 23:00 23:30 0.50 SURFAC WELCTL OTHR P 4,151.0 4,151.0 PU 13-3/8" casing f /160k on wt indicator to 230k, remove master bushings.PU Diverter high enough to rough cut and set slips. Cleaning pits. 23:30 00:00 0.50 SURFAC CEMENT OTHR P 4,151.0 4,151.0 Clean out cement in between 20' x 13-3/8". Clean out to 2' below top of landing ring load shoulder. Cleaning pits. Mud Check Data YP Cale. Gel (10s} Gel (10m) Gel (30m) HTHP Filt Density Temp Solids, Corr. Type Depth (ftKB) Dens (Ib/gap Vis (s/qt) PV Calc (cp) (Ibf/10Dft') (Ibf/100ft') ; (Ibf/100ft') (Ibf/100ft') MBT (Ib/bbq (mU30min) pH (°F) (°~) Spud Mud 4,153.0 9.20 65 21.0 23.000 12.000 27.000 31.000 15.0 8.0 3.7 Iri'ection Fluid Fluid Source From Lease (bbl) Destination Note Cuttings 1J-109 14.0 DS 4 G&I cu yds Water Based Mud 1 J-109 1750.0 1 R-18 bbis Wellbores Wellbore Name Welibore API/UWI 1J-109 500292330700 Section Size (in) Act Top (ftKB) Act Btm (ftKB) ~ Start Date End Date PROD1 COND1 42 43.2 121.2 12/21 /2005 12/27/2005 SURFAC 16 121.2 4,153.0 7/9/2006 7/13/2006 INTRM1 12 1/4 4,153.0 11,004.0 7/17/2006 7/24/2006 Plug Back 0 10,850.0 11,004.0 7/24/2006 7/30/2006 Page 2/3 Report Printed: 8/15/2006 lis I ~_~;_~ ., Daily Drilling Report 1 J-109 eport Date: 7/14/2006 Casin Strin s Casing Description Run Date OD (in) Wt (Ibs/ft)_ Grade Set Depth (ftKB) Comment Surface 7/14/2006 133/8 68.00 L-80 4,151.6 Cement Surface Casin Cement -Started 7/14/2006 Type casing Wellbore 1J-109 String Surface, 4,15 1.6ftKB Cement Evaluation Results Stg No. 1 CW 100 MudPush AS Lite DeepCrete Description Surface Casing Cement Fluid. Class '• AS lite DeepCRETE Top (ftKB) 43.2 Amount (sacks) V (bbl) Density (Iblgal)> 50.1 8.30 48.9 10.50 800 648.9 10.70 220 93.3 12.00 Bottom (ftKB) 4,153.0 _ Yield (ft'Jsack) s 4.45 2.46 Q (end) (bbl/... P {final) (psi) 3 600.0 Est Top'(ftKB) Est Btm (ftKB)' 4,153.0 4,153.0 43.2 3,573.0 4,153.0 Page 3/3 Report Printed: 8/15/2006 I I ' ~ Daily Drilling Report r. 1 J-109 .. Report Date: 7115/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 10 6.66 4,153.0 4,153.0 0.00 1 J-109 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftK6) 7/9/2006 DOYON 15 WEST SAK Development 16,636.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10139809 4,668,037.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Surface, 4,151.6ftKB 4 1!2 14,218.00 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Hook up kill and choke lines. 80,882.00 2,024,519.16 24hr Forecast Daily Mud Cost Cummulative Mud Cost NU BOPE, change element in hydril, finish NU, Test BOPE, MU BHA #3, RIH, test casing, drill cement, shoe 1,795.00 107,050.66 track & 20' new hole, LOT, drill 12-1/4" intermediagte hole. Last 24hr Summary Set slips on 13-5/8", rough cut, N/D diverter, final cut, weld Vetco Gray adapter, PU 5" DP, test weld, NU multibowl, test seal sub and flange, NU spacer spool. General Remarks Weather Head Count Off hi line 1645 hrs, back on @ 1930 hrs. 50 deg, winds 4 knots ENE . 46.0 Supervisor Title Fred Herbert Rig Supervisor Granville Rizek Rig Supervisor Time Lo Start. End Time Depth Start Depth End Time Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code (ftKB) (ftK6) CommlOperation 00:00 04:30 4.50 SURFAC WELCTL OTHR T Wellhead... 4,151.0 4,151.0 Trying to center up the 13-3/8" casing to set slips in landing ring profile. Pulling 13-3/8" casing towards stairwell in cellar. Used a comealong, and asuper tugger to pull. Used a Aorta-power against cellar box to jack against. Needing to move pipe 1-1/4"+ to center up. Cleaning pits. 04:30 04:45 0.25 SURFAC WELCTL OTHR P 4,151.0 4,151.0 Set slips @ 0430 hrs. Block wt 80k, wt indicator 230k before slack off. Slack off w/ jt # 97 4.58" above floor, after slips set, top @ 4.51' above rig floor. Cleaning pits. 04:45 05:15 0.50 SURFAC WELCTL OTHR P Rough cut and L/D jt # 97 and cutoff remaining on jt # 96. Final cut will be 7-3/8"(.62') above landing ring top. (.91' above load shoulder). These measurements leave 36.98' of jt # 96 in hole to load shoulder (37.89' to final cut). Cleaning pits. 05:15 08:00 2.75 SURFAC WELCTL NUND P Rig down flowline riser f/ 20" Diverter. Loading 100 joints of 5" drill pipe in pipe shed. 08:00 11:30 3.50 SURFAC WELCTL NUND P Welder preparing and welding Vetco Gray 13-3/8" adapter with flange to casing. Finished with welding procedure @ 1130 hrs 7/15/2006. Wrap w/ insulation to allow to cool off f/ 8 hrs before testing. L/D casing equipment and cement head f/ rig floor. Change bales and elevators to PU 5" drill pipe. 11:30 12:00 0.50 SURFAC RIGMNT SVRG P Service rig, top drive and crown. Also service choke manifold. 12:00 12:30 0.50 SURFAC DRILL SFTY P PJSM on picking up bit and subs f/ beaver slide. Following w/ picking up 5" drill pipe in mousehole, standing back in derrick. 12:30 14:15 1.75 SURFAC DRILL PULD P PU subs and bit. PU/MU/stand in derrick Weatherford 5" dp. 14:15 15:15 1.00 SURFAC WELCTL NUND P Seperate Vetco Gray adapter f/ Diverter spool. Seperate diverter spool f/ Annular. 15:15 18:30 3.25 SURFAC DRILL PULD P Continue picking up Weatherford 5" dp and stand back in derrick. Total of 33 stands were picked up f/ total of 109 stands in derrick. 18:30 19:30 1.00 SURFAC WELCTL OTHR P Prepare to PU/MU Vetco Gray Multibowl 222A. 19:30 20:30 1.00 SURFAC WELCTL OTHR P Unwrap weld on adapter, RU to test same. Screw on threaded flange, graylock seal ring and seal sub. 20:30 21:00 0.50 SURFAC WELCTL OTHR P Test void and weld to 1800 psi (80% of collapse) f/ 10 min. OK. Note: Rig floor to flange = 41.83' Latest BOP Test Data Date Comment '' Page 1/2 Report Printed: 8/15/2006 ~ - ~.. Daily Drilling Report 1 J-109 Report Date: 7/15/2006 Time Lo Start 'Time End Timer Dur(hrs) Phase Op Code OpSub-Code Time P-N-T TrblCode Depth Start (ftk6); Depth End (ftK8) Comm/ope~atioh 21:00 23:30 2.50 SURFAC WELCTL NUND P Set Vetco gray Multibowl 222A, tighten bolts. Test seal sub and graylock seal to 5000 psi f/ 10 min. Changeout cable on off driller's side bridge crane. Inspect cable on driller's side bridge crane. Note: Rig floor to top flange of Vetco Gray multibowl = 35.80'. 23:30 23:45 0.25 SURFAC WELCTL SFTY P Hold PJSM in doghouse on nippling up. 23:45 00:00 0.25 SURFAC WELCTL NUND P PU/MU spacer spool on top of Vetco Gray multibowl wellhead. In"ection Fluid Fluid Source From Lease (bbl) Destination Note Cuttings 1J-109 21.0 DS 4 G&I cu yds Water Based Mud 1 J-109 380.0 1 R-18 bbls Wellbores- Wellbore Name Wellbore API/UWI 1J-109 500292330700 Section Size (in) Act Top (ftK6) Act Btm (ftK6) Start Date End Date PROD1 COND1 42 43.2 121.2 12/21 /2005 12/27/2005 SURFAC 16 121.2 4,153.0 7/9/2006 7/13/2006 INTRMI 12 1/4 4,153.0 11,004.0 7/17/2006 7/24/2006 Plug Back 0 10,850.0 11,004.0 7/24/2006 7/30/2006 Page 2/2 Report Printed: 8/15/2006 .,. . , Daily Drilling Report ~r~ . ~, 1J-109 . ,• Report Date: 7/17/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 12 8.66 4,153.0 5, 307.0 1,154.00 1 J-109 Spud Date Contractor Ri g Name/No Field Name Well Type Target Depth (ftK6) 7/9!2006 DOYON 15 WEST SAK Development 16,636.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ftlhr) 10139809 4,668,037.00 277.4 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 4,151.6ftKB 4 1/2 14,218.00 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Drilling 12-1/4" @ 5810' (TVD 26 88') 178,487.81 2,356,049.52 24hr Forecast Daily Mud Cost Cummulative Mud Cost Drill 12-1/4" intermediate hole f/ 5307'. 62,543.81 173,160.22 Last 24hr Summary RIH w/ BHA #3 (12-1/4" bit & geoPilot), Tag plugs above FC, circ, test csg to 3000 psi, drill shoe track + 20' new to 4173', circ, displ to LSND, LOT to 15.5 ppg, Drill 12-1 /4" w/ GeoPilot to 5307' . General Remarks Weather Head Count Rig on Hi-Line 49 deg, winds 3 knots S, cloudy 46.0 Supervisor Title Fred Herbert Rig Supervisor Granville Rizek Rig Supervisor Time Lo , Start End Time Depth Start Depth End Time" .Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code (ftKB) (ftKB) Comm/Operation 00:00 00:15 0.25 SURFAC DRILL TRIP P 680.0 864.6 Continue trip in w/ BHA #3: Run 2 stands Weatherford 5" dp for a total of 7 stands HW in hole to 864.61'. 00:15 00:30 0.25 SURFAC DRILL PULD P 864.6 1,025.0 Run 5 joints, then PU/MU 12-1/4" ghost reamer in stand # 2 of Weatherford 5" dp. Ghost reamer 1024.97' f/ bit. 00:30 01:00 0.50 SURFAC DRILL TRIP P 1,025.0 2,771.4 Continue RIH w/ Weatherford 5" dp, total of 20 stands in hole to 2771.36' 01:00 01:30 0.50 SURFAC DRILL CIRC P 2,771.4 2,771.4 Fill pipe. Circ surf to surface. Pumping 700 gpm w/ 1500 psi. 800 gpm w/ 2100 psi. Break in Sperry Sun 9600 series GeoPilot w/ 7-10 rpm, stage up to 30 rpm. 01:30 01:45 0.25 SURFAC DRILL TRIP P 2,771.4 2,960.0 RIH 2 stands Weatherford 5" dp. Circ and check out Sperry Sun MWD tools. OK 01:45 02:15 0.50 SURFAC DRILL CIRC P 2,960.0 2,960.0 Circ and check out Sperry Sun MWD tools. OK 02:15 03:30 1.25 SURFAC DRILL TRIP P 2,960.0 4,005.0 RIH f/ 2960' to 4005'. Stand # 33 in hole. 03:30 03:45 0.25 SURFAC DRILL OTHR P 4,005.0 4,005.0 Move 4" DP in derrick. 03:45 04:45 1.00 SURFAC DRILL CIRC P 4,005.0 4,054.0 PU stand # 34, establish circ, tag up on cement @ 4054'. Circulate 862 bbis. Pumping 750 gpm w/ 1950 psi, 730 gpm w, 1790 psi. 04:45 05:15 0.50 SURFAC CASING DHEQ P 4,054.0 4,002.0 Stand back stand #34. RU to test casing 05:15 06:00 0.75 SURFAC CASING DHEQ P 4,002.0 4,002.0 Test 13-3/8" 68 ppf L-80 BTC casing to 3050 psi. Chart test f/ 30 min. Lost 20 psi in 30 min, good test. Pumped total of 73 strokes. 06:00 06:15 0.25 SURFAC DRILL OTHR P 4,002.0 4,002.0 R/D test equipment. 06:15 06:30 0.25 SURFAC DRILL TRIP P 4,002.0 4,056.0 PU/MU stand #34, establish circulation. RIH to tag cement @ 4056' 06:30 09:45 3.25 SURFAC CEMENT DRLG P 4,056.0 4,173.0 Drilling cement, wiper plugs and FC @ 4065' (4062' DPM), cement, FS, rat hole, to 4153', plus 20' new hole to 4173' (2309' TVD). ART = .19 hrs, bit hrs .19, Jar hrs = 54.2 hrs. Drill w/ 4-10k WOB, 50 rpm w/ 10k ft Ib torque on bottom, 8-13k ft Ib off bottom. Pumping 627 gpm w/ 1420 psi on bottom, 1360 psi off bottom. ECD's 9.47 ppg. PU wt 170k, SO wt 90k, Rot wt 125k. 09:45 10:30 0.75 SURFAC DRILL CIRC P 4,173.0 4,173.0 Circulate bottom's up @ 4173' (2309' TVD). Pumping 555 gpm w/ 1090 psi, 50 rpm w/ 10-13k ft Ib. Circ total of 700 bbls. 10:30 10:45 0.25 SURFAC DRILL SFTY P 4,173.0 PJSM on mud swap out to 9.0 ppgLSND. 10:45 12:00 1.25 SURFAC DRILL CIRC P 4,173.0 4,173.0 Displace to 9.0 ppg LSND mud. Pump 37 bbls spacer, follow w/ 600 bbis new 9.0 ppgLSND mud. Pumping 555 gpm w/ 1090 psi. Latest BOP Test Data Date CommenF Page 1/3 Report Printed: 8/15/2006 -; ; Daily Drilling Report :_, i 1 J-109 ....:, , Report Date: 7/17/2006 Time Lo .Start End Time Depth Start Depth End Time 'Time. Dur (hrs) - -Phase Op Code OpSub-Code P-N-T Trbl Code (ftKB) (ftKB) Comm/Operation 12:00 14:30 2.50 SURFAC DRILL LOT P 4,173.0 4,173.0 RU and. perform LOT ~ 4173' MD (2310' TVD). LOT 15.5 ppg EMW. Pumped total of 62 strokes ~ 5 bpm, Max of 830 psi, Bleed off to 420 psi. Bleed back .5 bbl. R/D test equipment, blow down kiln line. R/D test manifold, prepare to drill. 14:30 18:00 3.50 INTRMI DRILL DDRL P 4,173.0 4,570.0 Directional Drill 12-1 /4" intermediate hole w/ 9-5/8"" Sperry GeoPilot f/ 4173' to 4570' (397') (TVD = 2409'). ART = 1.86 hrs. Total hrs on bit = 2.05 hrs., Total hrs on jars = 56.06 hrs, 0-20k WOB, 120 rpm's, 752-650 gpm w/ 9.1 ppg MW, on bottom press 1460-1250 psi, off bottom press 1320-1200 psi, on bottom torque 8-14k ft/Ib, off bottom torque 5-12k ft/ Ib, PU wt 172-165k, SO wt 92-100k, Rot wt 128-132k. ECD's 9.3-9.4 ppg 18:00 00:00 6.00 INTRM1 DRILL DDRL P 4,570.0 5,307.0 Directional Drill 12-1/4" intermediate hole w/ 9-5/8"" Sperry GeoPilot f/ 4570' to 5307' (737') (TVD = 2581'). ART = 2.11 hrs. Total hrs on bit = 4.16 hrs., Total hrs on jars = 58.17 hrs, 5-20k WOB, 80-70 rpm's, 520-575 gpm w/ 9.1 ppg MW, on bottom press 1020-900 psi, off bottom press 1050-900 psi, on bottom torque 5-15k ft/Ib, off bottom torque 8-17k ft/ Ib, PU wt 165-180k, SO wt 100-90k, Rot wt 132-130k. ECD's 9.6 ppg Mud Check Data YP Calc Gel (10s) Gel (10m) Gel (3Dm) HTHP Filt Density Temp Solids, Corr: Type Depth (ftKB) Dens (Iblgal) Vis (s/qt) PV Calc (cp) (Ibf/100ft') (Ibf/100ft') (Ibf/100ft') (Ibf/100ft') MBT (Ib/bbl) (mL/30min) pH (°F) (~) LSND 5,307.0 9.00 55 13.0 17.000 8.000 12.000 14.000 9.0 9.3 3.0 In'ection Fluid Fluid Source From lease (bbl) Destination Note Cuttings 1J-109 35.0 DS 4 G&I cu yds Water Based Mud 1J-109 870.0 1R-18 bbis Drill Strin s: BHANo. 3 - 12-1/4" Geo-Pilot / Bit Run No. 3 - 12 1/4in, Securi , FSF2553, 10696335RW Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (ins) Nozzles (132") IADC Bit Dull String Wt (10001bf) WOB (max) (700... WOB (min) (1000... 4,153.0 7,619.0 1.85 22/16/22120/16/16/16 2-3-WT-A-X-I-BT-DTF 0 0 Drill Strin Com onents Jts Item Description OD (in) ID`{in) Top Conn Sz (in) ` Top Thread Cum Len (ft) Geo-Pilot 9600 W/Top Stabilizer 9 5/8 1.920 23.42 Non Mag Geo Flex Collar W/ Directional 8 1.920 32.62 8" MPT w/ DGR + EWR 8 1.920 55.74 Smart Stabilizer 8.06 1.920 57.90 8"HCIM 8 1.920 64.91 8" MPT w/ SLD + CTN 8 1.920 102.44 8" MPT Pulser 8 1.920 113.63 Non Mag Float Sub 8 2.750 116.05 Non Mag Flex Drill Collar 7.65 2.880 147.04 Non Mag Flex Drill Coilar 7.863 2.880 178.04 Non Mag Flex Drill Collar 8 2.880 209.08 Dailey Jar w/ Slinger 7.73 3.000 249.35 20 joints 5" HWDP 5 3.000 864.61 5 Joints 5" Drillpipe 5 3.000 1,021.92 Ghost Reamer 7 2.880 1,027.91 5" Drillpipe to surface 5 3.000 5,305.26 Drillin Parameters Drilling Time .Sliding Hrs Cum Drill Q (flow) Start (ftKB) End (ftKB) (hrs) (min/ft) Cum Depth (ft) Time (hrs) Int Depth (ft) (gPm)_ , WOB (Ibf) RPM (rpm) SPP (psi) Drill Tq 4,153.0 4,173.0 0.19 20.00 0.19 20.00 600 8.0 50 1,400.0 11,000.0 4,173.0 4,570.0 1.86 417.00 2.05 397.00 .650 _8.0 120 1,250.0 11,000.0 4,570.0 5,307.0 2.11 1,154.00 4.16 737.00 550 10.0 80 1,050.0 12,000.0 Welibores Wellbore Name Wellbore API/UWI 1J-109 500292330700 Page 2/3 Report Printed: 8/15/2006 ~,~, . Daily Drilling Report 1 J-109 ..• Report Date: 7/17/2 006 Section Size (in) Act Top. (ftkB) Act Btm jftK6) Start Date End Date PROD1 CON D 1 42 43.2 121.2 12/21 /2005 12/27/2005 SURFAC 16 121.2 4 ,153.0 7/9/2006 7/13/2006 INTRM1 12 1/4 4,153.0 11 ,004.0 7/17/2006 7/24/2006 Plug Back 0 10,850.0 11 ,004.0 7/24/2006 7/30/2006 Surve Data MD (ftK6) Incl (°) Azm (°) TVD (ftK8) VS (ft) NS (ft) EW (ft) DLS (°/100ft) 4,163.78 77.36 77.37 2,309.42 -570.76 570.76 2,830.70 2.54 4,163.78 77.36 77.37 2,309.42 -570.76 570.76 2,830.70 2.54 4,255.64 75.58 77.33 2,330.91 -590.32 590.32 2,917.84 1.94 4,255.64 75.58 77.33 2,330.91 -590.32 590.32 2,917.84 1.94 4,351.73 76.48 78.14 2,354.11 -610.12 610.12 3,008.96 1.24 4,351.73 76.48 78.14 2,354.11 -610.12 610.12 3,008.96 1.24 4,448.51 75.47 79.25 2,377.56 -628.53 628.53 3,101.02 1.53 4,448.51 75.47 79.25 2,377.56 -628.53 628.53 3,101.02 1.53 4,543.66 75.72 78.68 2,401.23 -646.17 646.17 3,191.48 0.64 4,543.66 75.72 78.68 2,401.23 -646.17 646.17 3,191.48 0.64 4,639.40 75.58 79.73 2,424.96 -663.54 663.54 3,282.59 1.07 4,639.40 75.58 79.73 2,424.96 -663.54 663.54 3,282.59 1.07 4,734.38 75.90 80.46 2,448.36 -679.38 679.38 3,373.27 0.82 4,734.38 75.90 80.46 2,448.36 -679.38 679.38 3,373.27 0.82 4,829.35 76.72 81.41 2,470.83 -693.91 693.91 3,464.39 1.30 4,829.35 76.72 81.41 2,470.83 -693.91 693.91 3,464.39 1.30 4,924.42 76.72 80.39 2,492.67 -708.55 708.55 3,555.75 1.04 4,924.42 76.72 80.39 2,492.67 -708.55 708.55 3,555.75 1.04 5,019.94 76.98 80.08 2,514.40 -724.32 724.32 3,647.42 0.42 5,019.94 5,115.49 76.98 77.36 80.08 78.85 2,514.40 2,535.62 -724.32 -741.36 724.32 741.36 3,647.42 3,739.01 0.42 1.32 5,115.49 5,210.67 77.36 76.74 78.85 79.49 2,535.62 2,556.95 -741.36 -758.79 741.36 758.79 3,739.01 3,830.11 1.32 0.92 5,210.67 76.74 79.49 2,556.95 -758.79 758.79 3,830.11 0.92 5,305.42 76.60 80.23 2,578.80 -775.02 775.02 3,920.87 0.77 5,305.42 76.60 80.23 2,578.80 -775.02 775.02 3,920.87 0.77 Page 3/3 Report Printed: 8/15/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: 1 J-109 Rig: Doyon Rig 15 Date: 7/17/2006 Volume Input VolumelStroke Pum Rate: Drilling Supervisor: Fred Herbert/ Granville Rizek Pump used: #1 Mud Pump ~ strokes ~ 0.1007 Bbls/strk ~ 0.50 strk/min ~ Type of Test: casing shoe Test LoT/FtT ~ Pumping down annulus and DP. ~ Casin Test Pressure Inte rit Test Hole Size: 12-1/4" ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 35.8 Ft 4151.6 Ft-MD 2306.0 Ft-TVD 4173.0 Ft-MD 2310.0 Ft-TVD Strks si Min si Strks si Min si Casing Size and Description: 13-3/8" 68#/Ft L-80 BTC ~ 0 0 0 3050 0 0.00 820 Casin Test Pressure Int e rit Tes t 1 40 1 3040 2 40 0.25 790 Mud Weight: 1 9 ppg Mud Weight: 9.0 ppg 2 60 2 3040 4 ~ ~ 80 0.50 740 Mud 10 min Gel: . 16 0 Lb/100 Ft2 Mud 10 min Gel: 14.0 Lb/100 Ft2 3 90 3 3040 6 130 1.00 700 Test Pressure: . 3000 0 psi Rotating Weight: ~# Lbs 4 125 4 3040 8 .200 1.50 Rotating Weight: . 128 0 Lbs Blocks/Top Drive Weight: 70000.0 Lbs 5 175 5 3040 10 .350 2.00 Drive Weight Blocks/To . 70 0 Lbs Desired PIT EMW: 12.0 ppg 6 205 6 3040 12 25 2.50 600 p Estimates for Test: . 7 2 bbls Estimates for Test: 360 psi 0.8 bbls 7 250 7 3040 14 ~ ;490 3.00 575 . - l ~ ~ 8 295 8 3040 16 540 3.50 550 _ EMW =Leak-off Pressure + Mud Weight = 783 PIT 15 Second 9 340 9 3040 18 -,4.00 5~5 + 9 052 x TVD 0.052 x 2306 ~ 0 Shut-in Pressure, si 10 380 10 3040 2 660 4.50 510 . .63 Ft-MD (2306 Ft-TVD) = 15.5 pp W at 415 1 EM 790 _ 11 425 15 3040 22 5.00 510 . __ _ 3soo Lost 20 psi during test, held 12 475 20 3035 24 ~ 725 5.50 500 _ 99.3% of test pressure. 13 525 25 3035 26 ~: 750 6.00 500 ~~• •-.-`~--R 14 575 30 3030 28 775 6.50 490 soon - - ___- _ ___ ___ _ i 15 610 30 790 7.00 480 - _ I 20 820 32 800 7.50 475 2soo - ~ 25 1050 34 800 8.00 460 30 1240 36 820 8.50 450 Zooo ~ 35 1410 38 830 9.00 440 ~ ~ 40 1620 40 830 9.50 435 v~ 45 1830 >~{ 42 830 10.00 a lsoo _ - 50 2025 44 830 55 2240 46 830 loon _ 60 2465 48 830 _ - ~ 65 2680 50 830 , 70 2900 55 830 soo 60 830 ~_ ~ i , _ 72 2990 ~ ~ 73 3050 62 830 0 1 2 3 4 5 6 7 8 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes i PIT P t Volume PUm ed Volume Bled Back Volume Pum ed Volume Bled Back n o 'CASING TEST -LEAK-OFF TEST O S S S S Comments: - - - u ace es Summary Casing Detail Report 1 J-109 ~asm Casing Description Intermediate Set Depth (ftKB) 10,853.0 Run Centralizers 212 Scra Casin Com onents Item Description OD (iri) Wt (Ibslft) Grade Top Thread Jts Len Cut off Joint #284 9 5/8 40.00 L-80 1 Casing Joints 9 5/8 40.00 L-80 BTC-mod 283 10, i Float Collar 9 5/8 BTC-mod 1 Casing Joints 9 5/8 40.00 L-80 BTC-mod 1 Casing Joints 9 5/8 37.00 J55 BTC-mod 1 Float Shoe 9 5/8 BTC-mod 1 9 5/8 Intermediate Set Tension (kips) 7/27/2006 250,000.0 Mk-up, Tq ift) Top (ftKB) Btm (ftKB) (ft-1bs) Class Max OD (in) ID (in) 26.94 40.5 67.5 8.835 03.70 67.5 10,771.2 8.835 1.50 10, 771.2 10, 772.7 35.66 10,772.7 10,808.3 8.835 10,808.3 10,851.3 10,851.3 10,853.0 10,853.0 10,853.0 Page 1/1 Report Printed: 8/15/20061 Tea .~ . Cement Detail Report 1 J-109 .• Intermediate Casing Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10139809 7/6/2006 7/9/2006 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing 7/27!2006 21:00 7/28/2006 01:00 1 J-109 Comment Turn Rig over to Dowell Cementers @ 2100 HRS. Pump 10 BBLS of 8.35 PPG CW 100 @ 2.5 BPM - 265 PSI. SHut down. Pressure test lines to 3500 PSI. Good test. Continue pump 40 BBLS of CW 100 @ 5.5 BPM - 320 PSI. Pump 75 BBLS of 11.0 PPG Mud push II Space r @ 5 BPM - 315 PSI. Drop Botom plug @ 21:44 HRS. Batch Mix & pump 12.5 PPG Deep Crete Cement @ initial pump pressure of 315 PSI @ 5.5 BPM. Pump 200 BBLS out of 299 Planned. Reciprocate Casing Strin with UP WT = 270K, SO WT = 145K. 'Cement Sta es Sta e # <Sta a Number?> Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Cement 9 5/8" 6,643.7 10,853.0 No 0.0 Yes Yes Q (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 3 6 610.0 1,100.0 Yes 30.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Turn Rig over to Dowell Cementers @ 2100 HRS. Pump 10 BBLS of 8.35 PPG CW 100 @ 2.5 BPM - 265 PSI. SHut down. Pressure test lines to 3500 PSI. Good test. Continue pump 40 BBLS of CW 100 @ 5.5 BPM - 320 PSI. Pump 75 BBLS of 11.0 PPG Mud push II Space r @ 5 BPM - 315 PSI. Drop Botom plug 21:44 HRS. Batch Mix & pump 12.5 PPG Deep Crete Cement @ initial pump pressure of 315 PSI @ 5.5 BPM. Pump 200 BBLS out of 299 Planned. Reciprocate Casing Strin with UP WT = 270K, SO WT = 145K. Cement Fluids & Additives Fluid - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 6,793.0 10,853.0 728 G 299.8 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 2.24 7.56 12.50 5.50 Additives Additive Type Concentration Conc Unit label D046 Antifoam Ibs/bbl Additive Type Concentration Conc Unit label D031 Barite CW Additive Type Concentration Conc Unit label Cementing Plug Bott P/ Cor P/ Wpr Additive Type Concentration Conc Unit label D827 Chem Wash %BWOC Additive Type Concentration Conc Unit label B160 Dispersant Ibs/bbl Additive Type Concentration Conc Unit label D962 LiteCrete Ibs/sx Additive Type Concentration Conc Unit label D186 Low Temp Enhancer %BWOC Additive Type Concentration Conc Unit label D970 MudPush II %BWOC Additive Type Concentration Conc Unit label Cementing Plug Plug Additive Type Concentration Conc Unit label D110 Retarder %BWOC Additive Type Concentration Conc Unit label D167 UniFlac %BWOC Page 1/1 Report Printed: 8/15/2006 ~,,.. Daily Drilling Report 1 J-109 ... • , Report Date: 7/27/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 22 18.66 11, 004.0 11,004.0 0.00 1 J-109 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 7/9/2006 DOYON 15 WEST SAK Development 16,636.0 AFE ! RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10139809 4,668,037.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 10,853.OftK6 41/2 14,218.00 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Running 9 5/8" Casing in open h ole @ 6000'. 109,659.12 3,674,991.49 24hr Forecast Daily Mud Cost Cummulative Mud Cost Continue Run 9 5!8 Casing to bottom @ 10858'. Circulate & condition mud. Pump 290 BBL cement job, 27,863.92 406,941.49 displace with 9.0 PPG OBM. Set Casing in Emergency Slips . Last 24hr Summary POOH Breakout & lay down BHA. &HWDP. Rig up & run 9 5/8" casing to 2632'. General Remarks Weather Head Count Rig on Hi-Line 51 Deg, Partly Cloudy, Winds SE @ 5 MPH 40.0 Supervisor. Title Scott Heim Rig Supervisor Granville Rizek Rig Supervisor Time Lo Start. Time End Tima Dur (hrs) Phase Op Code OpSub-Code Time P-N-T Trbl Code Depth Start (ftKB) Depth End (ftKB) Comm/Operation 00:00 00:15 0.25 INTRM1 DRILL OWFF P 10,880.0 10,880.0 Monitor well -static 00:15 00:45 0.50 _ INTRM1 DRILL TRIP P 10,880.0 10,464.0 POOH with 5 stands on elevators from 10880' - 10464'. Observe good hole conditions and proper hole fill. Obtain SLM on Drill pipe. 00:45 01:15 0.50 INTRM1 DRILL TRIP P 10,464.0 10,464.0 Monitor well -static. Pump dry job 2 pounds over mud weight. 01:15 05:15 4.00 INTRM1 DRILL TRIP P 10,464.0 4,100.0 Continue POOH on elevators. Observing good hole conditions with proper hole fil from 10464' - 4100'. Inside shoe. Obtain SLM on Drill pipe, and T & D parameters as per rig engineer on every 5 stands in open hole, every 10 stands in cased hole. 05:15 06:00 0.75 INTRM1 DRILL CIRC P 4,100.0 4,100.0 Establish Circulation. Pump Hi Visc weighted sweep and follow with 40 BBL Steel Lube pill. Pumps @ 850 GPMs - 1850 PSI. Reciprocate & rotate drill string. UP WT = 152K SO WT = 102K ROT WT = 122K with 125 RPM's. Crew Change. 06:00 07:45 1.75 INTRMI DRILL CIRC P 4,100.0 4,100.0 Continue Pump Hi Visc weighted sweep and follow with 40 BBL Steel Lube pill. Pumps @ 850 GPMs - 1850 PSI. Reciprocate & rotate drill string. Up WT = 140K, SO WT = 126K. Slow pump rate as sweep returned to 350 GPM's - 300 PSI as steel tube pill ran over shaker screens. 07:45 08:00 0.25 INTRM1 DRILL OWFF P 4,100.0 4,100.0 Monitor well -static. Pump Dry Job. Blow down Top Drive & lines. 08:00 09:45 1.75 INTRM1 DRILL TRIP P 4,100.0 820.0 Continue POOH from 4100' - 820'. 09:45 10:45 1.00 INTRM1 DRILL PULD P 820.0 0.0 Breakout & lay down Ghost Reamer (6.00'), and 18 -jnts 5" HWDP (553.72'). 10:45 11:00 0.25 INTRM1 RIGMNT SFTY P 0.0 0.0 PJSM with crew. Discuss Safety Issues and procedure for slipping and cutting drilling line. 11:00 12:00 1.00 INTRM1 RIGMNT SVRG P 0.0 0.0 Slip & cut 153' of drilling line. Inspect & service drawworks and Top Drive. 12:00 13:30 1.50 INTRM1 DRILL PULD P 0.0 0.0 Continue breakout & lay down 12 1/4" Hole opener (7.91'), Bit Sub with ported float (3.01'), 1 -Non Mag Flex Drill Collar (31.04'), Integral Blade centralizer (5.40'), 2 -Non Mag Flex Drill Collars 961.99'), Dailey Jars (40.27'), 2 - jnts 5" HWDP (61.57'), Total BHA = 770.91'. 13:30 14:15 0.75 INTRM1 CASING RURD P 0.0 0.0 Rig up to run 9 5/8" casing. Rig up running tool and RIH to pull wear bushing. Lay down running tool.Pull centralizers to rig floor. Latest BOP Test Data Date Comment Page 1/3 Report Printed: 8/15/2006 -~, - Daily Drilling Report 1 J-109 •- r•' a Report Date: 7/27/2006 Time Lo Start End Time Depth Start Depth End Time Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code (ftKB) (ftKB) Comm/Operation'. 14:15 14:30 0.25 INTRM1 CASING SFTY P 0.0 0.0 Held PJSM with rig crew, GBR casing reps. Discuss safety i ssues, hazards, and procedure for rigging up and runnning 9 5/8" casing. 14:30 17:30 3,00 INTRMI CASING RURD P 0.0 0.0 Continue rig up to run 9 5/8" Casing. Pull all running equipment to rig floor and rig up as per GBR reps. Pull centralizers to floor. Rig down short bales on top drive, and make up long bales. Pull cement head to rig floor. Make up Franks Fill -Up tool. Check all casing & running order. 17:30 18:00 0.50 INTRM1 CASING SFTY P 0.0 75.0 Pick up 9 5/8" Casing Shoe joint. RIH. Make up joint # 2 as per detail with baker loc in threads. Crew Change 18:00 19:00 1.00 INTRM1 CASING RNCS P 75.0 110.0 Make up joint # 3 with Float collar. Fill casing and check floats. 19:00 19:30 0.50 INTRMI CASING RNCS P 110.0 110.0 Install Franks fill up tool. Break circulation. Circulate to check floats pumping 25 BBLS as per Co. Rep. Pressure = 300 PSI @ 5 BPM 19:30 20:00 0.50 INTRM1 CASING SFTY P 110.0 110.0 Held PJSM with new crew on tour. Discuss safety issues and hazards when running casing. Discuss procedure for running casing. 20:00 00:00 4.00 INTRM1 CASING RNCS P 110.0 2,632.0 Continue RIH picking up 9 5/8" casing from pipe shed. RIH from 110' - 2632'. Install tandem Rise centralizers on each joint, with 2 TR centralizers on second joint with stop rings, 10' above collar and 10 'below collar as planned. Make up torque = 9000 FUlbs. Mud Check D ata YP Calc Gel (10s) Gel (10m) Gel (30m) HTHP Filt - Density Temp Solids, Cort Type Depth (ftKB) Dens (Ib/gal) Vis (s/qt) PV Calc (cp) (Ibf/100ft') (Ibf/100f1') (Ibf/100ft') {Ibf/100ft') MBT (Ib/bbl) (mL/30min) pH (°F) (°~ ) Water 11,004.0 9.00 45 10.0 23.000 10.000 16.000 20.000 15.0 8.5 8.0 Based Mud In'ection Fluid - Fluid Source From Lease (bbl) Destination Note Cuttings 7.0 DS 4 G&I Water Based Mud 580.0 1 R-18 Drill Strin s: BHA No. 5 - 12-1/4" Hole O ener / Bit Run No: 5 - <Drill Bit?> Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (132") IADC Bit Dull String Wt (10001bt) WOB (max) (100... WOB (min) (1000... 10, 775.0 15,160.0 1-1-NO-A-X-O-NO-Clean 12 0 out Drill Strin Com onents Jts Item Description ' OD {in) ID (in) Top Conn Sz (in) .Top Thread Cum Len (ft) Hole Opener W/ 4' Bullnose 1.031 TFA 8 2.880 6 5/8 Reg 7.91 Bit Sub 8 3.250 6 5/8 H-90 10.92 Non Mag Flex Drill Collar 8 2.880 6 5/8 H-90 41.96 Integral Blade Stabilizer 8 1/8 .3.000 6 5/8 H-90 47.36 Non Mag Flex Drill Collar 7.86 2.880 6 5/8 H-90 78.36 Non Mag Flex Drill Collar 7.65 2.880 6 5/8 H-90 109.35 Dailey Jar W/ Slinger 7.73 3.000 4.5 IF 149.62 2 X HWDP 5 3.000 4.5 IF 211.19 Ghost Reamer 7 2.812 4.5 IF 217.18 18 X HWDP 5 3.000 4.5 IF 770.90 5" Drill Pipe to Surface 5 4.276 4.5 IF 11,003.90 Wellbores Wellbore Name Wellbore API/UWI 1J-109 500292330700 Section s Size (in) ;! Act Top (ftKB) Act Btm (ftKB) Start Date End Date PROD1 COND1 42 43.2 121.2 12/21 /2005 12/27/2005 SURFAC 16 121.2 4,153.0 7/9/2006 7/13/2006 INTRM1 12 1/4 4,153.0 11,004.0 7/17/2006 7/24/2006 Page 2/3 Report Printed: 8/15/2006 ' ..• Daily Drilling Report 1 J-109 Report Date: 7/27/2006 Section" Size (in) Act Top(ftKB) Act Btm (ftK8) Stag Date - End Date Plug Back 0 10,850.0 11,004.0 7/24/2006 7/30/2006 Casn Strin s Casing Description Run Date : OD (in) Wt (lbsift) Grade Set Depth (ftKB) < Comment _ Intermediate 7/27/2006 9 5/8 40.00 L-80 10,853.0 Total of 2 Stop Rings, 58 Tandem Rise, And 50 Bow Spring Centralizers.Run 104 Lodrag Roller Centralizers. Cement Intermediate Casin -Started 7/27/2006 Type casing Wellbore 1J-109 String Intermediate, 10,853.OftK6 Cement Evaluation Results Stg No. Description Intermediate Casing Fluid Intermediate Cement Class. G Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 6,643.7 10,853.0 3 610.0 Amount (sacks) V (bbl) ` Density (Ib/gal) veld (ft'/sack} Est Top (ftKB): EsiBtm (ftKB) 728 299.8 12.50 2.24 6,793.0 10,853.0 I I Page 3/3 Report Printed: 8/15/2006 Daily Drilling Report ~~•_ 1 J-109 ,_ , . Report Date: 7/28/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 23 19.66 11, 004.0 11, 004.0 0.00 1 J-109 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 7/9/2006 DOYON 15 WEST SAK Development 16,636.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10139809 4,668,037.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 10,853.OftKB 4 1/2 14,218.00 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Nipple up BOPS. 146,047.11 3,821,038.60 24hr Forecast Daily Mud Cost Cummulative Mud Cost Set emergency Slips & cut casing. Nipple up & test BOP's. Make up 6 3/4 Drilling BHA #6 7,343.11 414,284.60 Last 24hr Summary Continue run 9 5!8" Casing to shoe @ 4151'. Circulate & condition mud. Run 9 5/8" casing into open hole to set shoe @ 10853' as planned. Circulate & condition mud for cement job. Pump 299.7 BBL Cement Job, displace with 813 BBLs OBM to bump plug with 8091 strokes. General Remarks Weather Head Count Rig on Hi-Line 47 Deg, Cloudy, Winds ESE @ 5 MPH. 41.0 Supervisor Title Scott Heim Rig Supervisor Granville Rizek Rig Supervisor Time Lo Start End Time Depth Start Depth End Time Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code (ftKB) (ftKB) Comm/Operation 00:00 02:00 2.00 INTRM1 CASING RNCS P 2,632.0 4,150.0 Continue run 9 5/8" casing from 2632' - 4150. Shoe depth. Install tandem Rise centralizers on each joint to joint # 58. Install Bow Spring Centralizer on joints 59 - 108. Obtain T & D parameters as per rig engineer. Fill each joint for 10 joints, and circulate down next joint while RIH slow. Make up torque = 9000 FUlbs. 02:00 03:00 1.00 INTRM1 CASING CIRC P 4,150.0 4,150.0 Circulate bottoms up @ 5 BPM - 600 PSI. Reciprocate casing string while pumping. Mud wt = 9.0 PPG, Visc = 50, YP = 20 Bring more centralizers to rig floor while circulating. 03:00 06:00 3.00 INTRM1 CASING RNCS P 4,150.0 6,000.0 Continue run 9 5/8" casing from 4150' - 6000'. Install Bow Spring Centralizer on joints 59 - 108.Obtain T & D parameters as per rig engineer. Make up torque = 9000 Ft/Ibs. Fill each joint for 10 joints, and circulate down next 2 joints while RIH slow. 06:00 15:00 9.00 INTRM1 CASING RNCS P 6,000.0 10,823.0 Continue run 9 5/8" casing from 6000' - 10823'. Install Lodrag Roller Centralizers on each joint from joint 180 - 283, floating. Ran a total of 285 joints. Used a total of 58 Tandem Rise Centralizers, 50 Bowsprings, and 2 stops. Used a total of 104 Lodrag roller centralizers. Obtain T & D parameters as per rig engineer. Make up torque = 9000 Ft/lbs. Fill each joint for 10 joints, and circulate down next 2 joints while RIH slow. 15:00 15:15 0.25 INTRMI CASING CIRC P 10,858.0 10,858.0 Circulate with Franks fill up tool @ 44 SPM - 340 PSI. UP WT = 270K, SO WT = 105K. Pump 70 BBLS while reciprocate casing string from 10858 - 10838 (30'). 15:15 16:30 1.25 INTRM1 CASING KURD P 10,858.0 10,858.0 Rig down Franks Fillup tool. Install Dowell Cement Head & Lines. Dowell Cementer loaded plugs. PU WT = 310K, SO WT = 140K. 16:30 21:00 4.50 INTRMI CEMENT CIRC P 10,858.0 10,858.0 Circulate & condition mud to pre cement properties of 9.0 PPG, Visc = 45, PV = 8, YP = 19, with Gels @ 7/10/12. Final pump pressure @ 170 PSI with 65 SPM. Reciprocate Casing String in 30' increments. UP WT = 265K, SO WT = 135K. Held PJSM with crew, Dowell cementers and all Truck Drivers. Discuss safety issues and procedure for pumping entire cement job. Designate a Spill Champion. Latest BOP Test Data Date Comment Page 1/2 Report Printed: 8/15/2006 ~; Daily Drilling Report ~~~ ,~y - ~ 1 J-109 ... Report Date: 7/28/2006 Time Lo Start End ' Time Depth Start Depth End Time Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code (ftKB) (ftKB) Comm/Operation _ - 21:00 23:00 2.00 INTRM1 CEMENT CIRC P 10,858.0 10,858.0 Turn Rig over to Dowell Cementers @ 2100 HRS. Pump 10 BBLS of 8.35 PPG CW 100 @ 2.5 BPM - 265 PSI. SHut down. Pressure test lines to 3500 PSI. Good test. Continue pump 40 BBLS of CW 100 @ 5.5 BPM - 320 PSI. Pump 75 BBLS of 11.0 PPG Mud push II Spacer @ 5 BPM - 315 PSI. Drop Botc~m plug @ 21:44 HRS. Batch Mix & pump 12.5 PPG Deep Crete Cement @ initial pump pressure of 315 PSI @ 5,5 BPM. Pump 299.7 BBLS of cement as planned. Pump 5 BBIs of water to flush lines. Reciprocate Casing String wi#h UP WT = 270K, SO WT = 145K 23:00 00:00 1.00 INTRM1 CEMENT DISP P 10,858.0 10,858.0 Turn over to Rig pumps. Pump $.9 PPG MOBM at 6.5 BPM to catch cement and continue @ 6.5 BPM to displace 450 BBIs of 813 planned. Reciprocate casing String UP WT = 255K, SO WT = 140K. Mud Check D ata YP Calc Gel (10s) Gel (10m) Gel (30m) HTHP Filt Density Temp Solids, Corr: Type Depth (ftKB) Dens (Ib/gal) Vis (s/qt) PV Calc (cp) (Ibflt00ft') (Ibf/100ft') ` (Ibf/100ft') (Ibf/100fN) MBT (Ib/bbl) (mU30min) pH ' (°F) (%) Water 11,004.0 9.05 43 8.0 19.000 7.000 10.000 12.000 13.0 8.5 8.0 Based Mud In'ection Fluid Fluid Source From Lease (bbl) Destination. Note Cuttings 0.0 Water Based Mud 1650.0 1 R-18 Drill Strin s: BHA No. 5 - 12-114" Hole O ener / Bit Run No. 5 - <Drill Bit?> Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (132") IADC Bit Dull String Wt (10001bf) WOB (max) (100... WOB (min) (1000... 10, 775.0 15,160.0 1-1-NO-A-X-O-N O-Clean 12 0 out Drill Strin Com onents Jts Item Description OD (in) ID (in) Top Conn Sz (in) ' Top Thread Cum Len (ft) Hole Opener W/ 4' Bullnose 1.031 TFA 8 2.880 6 5/8 Reg 7.91 Bit Sub 8 3.250 6.5/8 H-90 10.92 Non Mag Flex Drill Collar 8 2.880 6 5/8 H-90 41.96 Integral Blade Stabilizer 8 1/8 3.000 6 5/8 H-90 47.36 Non Mag Flex Drill Collar 7.86 2.880 6 5/8 H-90 78.36 Non Mag Flex Drill Collar 7.65 2.880 6 5/8 H-90 109.35 Dailey Jar W/ Slinger 7.73 3.000 4.5 IF 149.62 2 X HWDP 5 3.000 4.5 IF 211.19 Ghost Reamer 7 2.812 4.5 IF 217.18 18 X HWDP 5 3.000 4.5 IF 770.90 5" Drill Pipe to Surface 5 4.276 4.5 IF 11,003.90 Wellbores Wellbore Name Wellbore API/UWI 1J-109 500292330700 Section Size (in) Act Top (ftKB) Act Btm (ftKB) Start Date End Date PROD1 COND1 42 43.2 121.2 12/21 /2005 12/27/2005 SURFAC 16 121.2 4,153.0 7/9/2006 7!13/2006 INTRM1 12 1/4 4,153.0 11,004.0 7/17/2006 7/24/2006 Plug Back 0 10,850.0 11,004.0 7/24/2006 7/30/2006 Page 2/2 Report Printed: 8/15/2006 Daily Drilling Report ~, . . 1 J-109 . . • ... Report Date: 7/29/2006 Report Number Days Fro m Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 24 20.66 10, 882.0 1 J-109 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 7/9/2006 DOYON 15 WEST SAK Development 16,636.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ftlhr) 10139809 4,668,037.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 10,853.OftKB 4 1/2 14,218.00 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost TIH picking up 4" DP from shed with BHA #6 1,052,763.09 4,873,801.68 24hr Forecast Daily Mud Cost Cummulative Mud Cost RIH with BHA #6. Tag FC. CBU. Test Casing to 3000 PSI. Drill Shoe track plus 20' of hole. Perform LOT. 194,836.91 609,121.50 Directional drill 6 3/4" production hole. Last 24hr Summary Continue displace with a total of 813 BBLs OBM to bump plug with 8091. Check Floats. RD Cement Equipment. ND Lift BOP stack.. Set emergency Slips & cut casing. Nipple up & test BOP's. Make up 6 3/4 Drilling BHA #6 General Remarks Weather Head Count Rig on Hi-Line 54 Deg, Cloudy, Winds NE @ 3 MPH. 42.0 Supervisor Title Scott Heim Rig Supervisor Granville Rizek Rig Supervisor Time Lo Start End Time Depth Start Depth End Time Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code (ftKB). (ftKB) Comm/Operation 00:00 01:00 1.00 INTRM1 CEMENT DISP P 10,858.0 10,853.0 Continue displace well with 8.9PPG MOBM @ 6.5 BPM -with pressure to 750 PSI at 7970 SPM. SLow pumps to 3 BPM - 610 PSI. Observe bumping plug with 8091 Strokes. 813 BBLS pumped in displacement. Pressure to 1100 PSI to hold floats. Pips movement stopped at 7100 strokes with observed UP WT 240K, SO WT 80K and SHoe depth @ 10853'. CIP @ 0100 HRS. 01:00 01:30 0.50 INTRM1 CEMENT DISP P 10,853.0 10,853.0 Hold floats for 10 minutes. Bleed pressures and check floats. Held good. 01:30 02:00 0.50 INTRM1 CEMENT RURD P 10,853.0 10,853.0 Rig down cement head & lines. 02:00 04:15 2.25 INTRM1 WELCTL NUND P 10,853.0 10,853.0 Nipple down BOP stack & lift. Rig up & set 9 5/8" emergency slips with 245K pulled on casing as per Vetco Gray reps. Cut offjint = 26.94'. (#284). Rig up hose to vac out inside of casing down below casing head. 04:15 06:00 1.75 INTRM1 CASING OTHR P 10,853.0 10,853.0 Rig Up WACHS pneumatic casing cutter & cut casing as per VETCO GRAY reps. Dress top of 9 5/8" casing stub. 06:00 08:30 2.50 INTRM1 WELCTL NUND P 0.0 0.0 Nipple up BOP stack on casing head. 08:30 09:00 0.50 INTRM1 WELCTL BOPE P 0.0 0.0 Rig up test pump. Test 13 3/8" x 9 5/8" packoff to 2500 PSI as per Vetco Gray reps. Hold pressure 10 minutes, witnessed by Co. Rep. 09:00 10:00 1.00 INTRMI WELCTL BOPE P 0.0 0.0 Rig down long bales on Top Drive. install short bales. 10:00 12:00 2.00 INTRM1 WELCTL BOPE P 0.0 0.0 Rig up to test BOP's with chart recorder. Make up test plug & install same. Rig up lines. 12:00 17:00 5.00 INTRM1 WELCTL BOPE P 0.0 0.0 Test 13-5/8" BOPE. Annular w/ new element, upper pipe rams (3-1/2" x 6"), blind rams, floor safety valves, upper and lower IBOP valves on top drive, HCR and manual valves on kill and choke lines, choke manifold. All test @ 250 psi low f/ 5 min, then 3500 psi high f/ 5 min. Perform accumulator test: 200 psi build up in 41 seconds, full pressure in 3 min 54 sec. Chart test. Witness of test by AOGCC inspector John Crisp. 17:00 18:00 1.00 INTRM1 WELCTL BOPE P 0.0 0.0 Rig down all test equipment. Crew Change 18:00 18:45 0.75 INTRM1 WELCTL BOPE P 0.0 0.0 Continue Rig down all test equipment. Pull test plug & lay down same. 18:45 19:15 0.50 INTRM1 WELCTL NUND P 0.0 0.0 Install wear bushing & RILDS. Record dimesions for WB. 13 318" OD x 9" ID. 38 1/4" in length. Latest BOP Test Data Date Comment Page 1/2 Report Printed: 8/15/2006 r~ _ Daily Drilling Report ~ , 1 J-109 .. Report Date: 7/29/2006 Time Lo Start End Time Depth Start Depth End Time Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Coda (ftKB) (ftKB) CommlOperatioh 19:15 20:45 1.50 INTRM1 RIGMNT RGRP T Rig 0.0 0.0 Inspect & trouble shoot Top Drive shot pin assembly. Checked out good. 20:45 22:00 1.25 INTRM1 DRILL PULD P 0.0 0.0 Pull all equipment to rig floor. Lift subs, crossovers etc... Change out elevators to 3 1/2" for BHA makeup. Held PJSM with crew & Sperry Sun reps. Discuss Safety Issues and procedure for making up BHA # 6. 22:00 23:15 1.25 INTRM1 DRILL PULD P 0.0 99.0 Make up BHA #6. Make up 6 3/4" Smith PDC bit MDT52 with 6 x 13's jets for a TFA of .778 Sq. In.(.84'), 5" Sperry Drill Lobe 6/7 -6.0 stg with ABI (32.57'), 4 3/4" Non MAg float sub with ported float (2.35'), 4 3/4" Welded Blade Stabilizer 94.59'), 4 3/4" Non MAg Termination sub (1.85'), 4 3/4 MWD RES/Gamma Tool (24.07'), MWD Directional (8.41'), 4 3/4" PWD 10.78'), and 4 3/4" TM -HOC (10.86') and crossover sub (2.99'). Make up 1 -Non MAg Flex drill Collar (31.00'). 23:15 00:00 0.75 INTRM1 DRILL OTHR P 99.0 99.0 Turn on battery as per MWD rep, plug in and upload MWD. Mud Check D ata YP Calc Gel (10s) Gel (10m) Gel (30m) HTHP Filt Density Temp Solids, Corr. Type Depth (ftK8) Dens (Ib/gal) Vis (s/qt) PV Calc (cp) (Ibf/100ft~) (Ibf/100ft') (Ibf/100ft') (Ibf/100ft') MBT (Iblbbl) (mL/30min) pH (°F) (%) Oil Based 10,853.0 8.60 61 20.0 20.000 15.000 20.000 21.000 4.0 12.0 Mud In`ection Fluid Fluid Source From Lease (bbl) Destination Note Cuttings 0.0 Water Based Mud 1350.0 1 R-18 Drill 5trin s: BHA No. 5 - 12-1/4" Hole O ener I Bit Run No. 5 - <Drill Bit?> Depth In (ftKB) Depth Out (ftK6) TFA (incl Noz) (in') Nozzles (132") IADC Bit Dull String Wt (10001bf) WOB (max) (100... WOB (min) (1000... 10,775.0 15,160.0 1-1-NO-A-X-O-NO-Clean 12 0 out Drill Strin Com onents Jts Item Description OD (in) ID (in) Top Conn Sz (in) Top Tfiread .Cum Leh (ft) Hole Opener W/ 4' Bullnose 1.031 TFA 8 2.880 6 5/8 Reg 7.91 Bit Sub 8 3.250 6 5/8 H-90 10.92 Non Mag Flex Drill Collar 8 2:880 6 5/8 H-90 41.96 Integral Blade Stabilizer 8 1/8 3.000 6 5/8 H-90 47.36 Non Mag Flex Drill Collar 7.86 2.880 6 5/8 H-90 78.36 Non Mag Flex Drill Collar 7.65 2.880 6 5/8 H-90 109.35 Dailey Jar W/ Slinger 7.73 3.000 4.5 IF 149.62 2 X HWDP 5 3.000 4.5 IF 211.19 Ghost Reamer 7 2.812 4.5 IF 217.18 18 X HWDP 5 3.000 4.5 IF 770.90 5" Drill Pipe to Surface 5 4.276 4.5 IF 11,003.90 Wellbores Wellbore Name Wellbore API/UWI 1J-109 500292330700 Section Size (in) Act Top (ftKB) Act Btm (ftKB) Start Date End Date PROD1 CON D1 42 43.2 121.2 12/21 /2005 12/27/2005 SURFAC 16 121.2 4,153.0 7/9/2006 7/13/2006 INTRM1 12 1/4 4,153.0 11,004.0 7/17/2006 7/24/2006 Plug Back 0 10,850.0 11,004.0 7/24/2006 7/30/2006 Page 2/2 Report Printed: 8/15/2006 ~. ~~~'' ' Daily Drilling Report . ~ ,_. ~' -:;;. ` 1 J-109 i r.-Y~~ Report Date: 7/30/2006 Report Number Days From Spud ( days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 25 21.66 10, 775.0 11, 884.0 1,109.00 1 J-109 Spud Date Contractor Rig Name/No Field Name Wetl Type Target Depth (ftKB) 7/9/2006 DOYON 15 WEST SAK Development 16,636.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10139809 4,668,037.00 551.7 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 10,853.OftK6 4 1/2 14,218.00 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Directional drill 6 3/4" hole @ 10 900' 171,869.21 5,045,670.89 24hr Forecast Daily Mud Cost Cummulative Mud Cost Directional Drill 6 3/4" hole. 60,122.20 669,243.70 Last 24hr Summary RIH with BHA #6. Tag FC. CBU. Test Casing to 3000 PSI. Drill Shoe track plus 20' of hole to 10882' MD. Perform LOT to 13.97 PPG MWE @ 3758' TVD. Directional drill 6 3/4" production hole from 18882' - 10900 General Remarks Weather Head Count Rig on Hi-Line 49 Deg, Cloudy, Winds ENE 2 9 MPH. 39.0 Supervi sor Ti[fe Scott Heim Rig Supervisor Granville Rizek Rig Supervisor Time Lo Start End Time Depth Start Depth End Time Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code (ftKB) (ftKB) CommlOperation 00:00 00:45 0.75 INTRM1 DRILL OTHR P 99.0 99.0 Make Top Drive Connection. Perform Shallow pulse test @ 90'. Pumps @ 280 GPM - 1310 PSI. Good test. 00:45 01:30 0.75 INTRM1 DRILL PULD P 99.0 192.0 Continue Make up BHA #6. Make up 1 joint of 4" HWDP (30.69'), DNT Dailey Drilling Jars (31.96'), and 1 Joint od 4" HWDP (30.68'). Change out elevators for picking up 4" DP. Discuss Safety issues, hazards and procedure for pickig up DP from Shed. 01:30 02:30 1.00 INTRMI DRILL PULD P 192.0 1,409.0 RIH with 11 stands of 4" DP from Derrick (1217.05'). Continue pick up 4" drill pipe from pipe shed for space out of Agitator & Shock Sub. 02:30 03:30 1.00 INTRM1 DRILL PULD P 1,409.0 1,964.0 Make up crossover (2.97'), Agitator (8.77'), Shock Tool (7.02'), Crossover (3.00'), 9 -joints of 4" DP (281.79'), 4 314" DNT Dailey Drilling Jars (32.08), 3 -joints of 4" DP (94.03'), and 4 3/4" Dailey Accelerators (32.09'). Total BHA = 1964.66' 03:30 06:00 2.50 INTRM1 DRILL PULD P 1,964.0 4,777.0 Continue trip in hole with BHA #6, from 1964' - 4777' picking up singles of 4" Drill pipe from Shed. Drift all DP to 2.35". Crew Change. 06:00 08:00 2.00 INTRM1 DRILL PULD P 4,777.0 6,469.0 Continue trip in hole with BHA #6, from 4777' - 6469 picking up singles of 4" Drill pipe from Shed. Drift all DP to 2.35". 08:00 08:45 0.75 INTRM1 DRILL TRIP P 6,469.0 6,469.0 Fill drill string. Observe proper hole fill. Pulse test MWD with pumps @ 200 GPM's - 1650 PSI. UP WT = 130K, SO WT = 99K. SIMOPS -working on crown section lights. 08:45 10:45 2.00 INTRM1 RIGMNT RGRP T Rig .6,469.0 6,469.0 Work on & repair lights for crown & top section. 10:45 11:30 0.75 INTRM1 DRILL TRIP P 6,469.0 7,010.0 Change out elevators to 5". Trip in hole with 5" drill pipe singles from pipe shed from 6469' - 7010'. (541'). 11:30 12:00 0.50 INTRM1 DRILL TRIP P 7,010.0 6,469.0 POOH back to 6469' racking back 5" drill pipe in off drillers side of derrick. 12:00 12:15 0.25 INTRM1 DRILL TRIP P 6,469.0 6,469.0 Clean & clear floor area of MOBM. 12:15 13:15 1.00 INTRM1 DRILL TRIP P 6,469.0 9,983.0 Trip in hole with 5" Drill pipe from derrick with super sliders installed from 6469' - 9983'. Note: Decision to reposition super sliders deeper in hole as per engineer. 13:15 13:30 0.25 INTRM1 DRILL TRIP P 9,983.0 9,983.0 Transfer remaining stands of 5" DP in derrick for repositioning super sliders on drill string. Double check all drill string tallies. Latest BOP Test Data Date Commenf Page 1/3 Report Printed: 8/16/2006 Daily Drilling Report ¢~._,~ 1 ~~_' 1 J-109 ,... Report Date: 7/30/2006 Time Lo Start End Time Depth Start Depth End Time Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code (ftK6) (ftKB) Comm/Operation 13:30 14:15 0.75 INTRM1 DRILL TRIP P 9,983.0 10,776.0 Continue trip in hole with BHA #6 from 9983' - 10745'. (762'). MAke Top drive connection. Wash down to 10776' tagging float equipment. UP WT = 170K, SO WT = 123K, ROT WT = 133K. Torque @ 7-8K. RPM's = 40. Pumps at 72 SPM - 3300 PSI. 14:15 16:30 2.25 INTRM1 CASING CIRC P 10,776.0 10,776.0 Circulate & condition mud to 8.68 PPG, YP 19, Visc = 67. Gels - 15/24. Pumps @ 300 GPM's, 3280 PSI. UP WT = 170K, SO WT = 123K, ROT WT = 133K. 16:30 17:15 0.75 INTRM1 CASING DHEQ P 10,776.0 10,776.0 Rig up lines and equipment for casing test. 17:15 18:00 0.75 INTRM1 CASING DHEQ P 10,776.0 10,776.0 Pressure test 9 5/8" casing to 3000 PSI. Hold test for 30 minutes, record on chart. Observe loss of 140 PSt in 30 minutes. Pumped 113 strokes, bled back 11.3 BBLS: Test mud wt = 8.65 PPG. Crew Change. 18:00 18:45 0.75 INTRM1 CASING DHEQ P 10,776.0 10,776.0 Bleed pressure. Rig down test equipment. Monitor well -static. 18:45 19:00 0.25 INTRM1 CEMENT DRLG P 10,775.0 10,775.0 Make Top Drive connection. Wash down to Float collar. Tagged Float collar @ 10775'. Drill Float equipment & Shoe track down to 10775', continuing to drill 25' of new hole to 10882'. Pumps @ 300 GPM - 3420 PSI. 2-5K WOB, 30 RPM's with 7-9K torque. 19:00 19:15 0.25 INTRM1 CEMENT DRLG P 10,775.0 10,785.0 Continuing to drill shoe track cement from 10775' - 10785'. Pumps @ 300 GPM - 3420 PSI. 2-5K WOB, 30 RPM's with 7-9K torque. 19:15 19:45 0.50 INTRM1 DRILL CIRC T Operational 10,785.0 10,785.0 Lost MWD signal. Trouble shoot problems, finally switching to Pump #2. MWD signal returned to normal. Inspection of pump #1 indicated failed valve guide inserts & 1 valve. Cleaned suction screens. 19:45 22:45 3.00 INTRM1 CEMENT DRLG P 10,856.0 10,882.0 Continue drilling shoe track cement from 10785' - 10856', tagged Shoe @ 10856' DPM. Drill cement and new hole from 10856' - 10882'. Pumps at 300 GPM's - 3420 PSI. 3100 PSI off bottom. 2-5K WOB, 7-9K torque on bottom. 22:45 00:00 1.25 INTRM1 DRILL CIRC P 10,882.0 10,882.0 Circulate & condition mud to 8.68 PPG, YP 19, Visc = 67. Gels - 15/24. Pumps @ 300 GPM's, 3280 PSI. UP WT = 170K, SO WT = 123K, ROT WT = 133K. 30 RPM's. 10856' MD. TVD = 3758'. Circulated 650 BBLS. Mud Check D ata YP Calc Gel (10s) Gel (10m) Gel (30m) HTHP Filt Density Temp Solids, Corr. Type Depth (ftK6) Dens (Ib/gal) Vis (s/qt) PV Calc (cp) (Ibf/100ft') (Ibf/100ft') (Ibf/100fN) (Ibf1100ft') MBT (Ib/bbl) (mU30min) pH (°F) (°~ ) Oil Based 10,882.0 8.65 65 14.0 18.000 19.000 22.000 24.000 3.0 12.5 Mud Ih'ection Fluid - Fluid Source From Lease (bbl) Destination Note Cuttings 17.0 DS 4 G&I Water Based Mud 170.0 1 R-18 Drill Strin s: BHA No. 5 - 12-1/4" Hole 0 ener I Bit Run No: 5 - <Drill Bit?> Depth In (ftK6) Depth Out (ftK6) TFA (incl Noz) (in') Nozzles (/32") IADC Bit Dull String Wt (10001bf) WOB (max) (100... WOB (min) (1000... 10, 775.0 15,160.0 1-1-NO-A-X-O-NO-Clean 12 0 out DrillStrin Jts Com onents Item Description OD {in) ID (in) Top Conn Sz (in) Top Thread Cum Len (ft) Hole Opener W/ 4' Bullnose 1.031 TFA 8 2.880 6 5/8 Reg 7.91 Bit Sub 8 3.250 6 5/8 H-90 10.92 Non Mag Flex Drill Collar 8 2.880 6 5/8 H-90 41.96 Integral Blade Stabilizer 8 1/8 3.000 6 5/8 H-90 47.36 Non Mag Flex Drill Collar 7.86 2.880 6 5/8 H-90 78.36 Non Mag Flex Drill Collar 7.65 2.880 6 5/8 H-90 109.35 Dailey Jar W/ Slinger 7.73 3.000 4.5 IF 149.62 2 X HWDP 5 3.000 4.5 IF 211.19 Page 2/3 Report Printed: 8/16/2006 Daily Drilling Report ~t~~ ._,~ 1 J-109 ., Report Date: 7/30/2006 Drill Strin Com onents Jts Item Description - OD (in) ID (in) Top Corin Sz (in) Top Thread Cum Len (ft) Ghost Reamer 7 2.812 4.5 IF 217.18 18 X HWDP 5 3.000 4.5 IF 770.90 5" Drill Pipe to Surface 5 4.276 4.5 IF 11,003.90 Wel /bores Wellbore Name Welibore API/UWI 1J-109 500292330700 Section' Size (in) AcfTop (ftK6) Act etm (ftK6) StarYDate End Date PROD1 COND 1 42 43.2 121.2 12/21 /2005 12/27/2005 SURFAC 16 121.2 4,153.0 7/9/2006 7/13/2006 INTRMI 12 1/4 4,153.0 11,004.0 7/17/2006 7/24/2006 Plug Back 0 10,850.0 11,004.0 7/24/2006 7/30/2006 Surve Data MD (ftKB) Incl (°) Azm (°) ND (ftK6) VS (ft) NS (ft) EW (ft) DLS (°/100ft) 10,815.27 81.10 177.64 3,751.23 132.36 -132.36 8,432.10 1.88 Page 3/3 Report Printed: 8/16/2006 ~~ ~ Daily Drilling Report ~ ~~ , -,III'; 1 J-109 :; <~ ~ 4.: ~'~ F. Report Date: 7/31/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 26 22.66 10,882.0 12,383.0 1,501.00 1 J-109 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 7/9/2006 DOYON 15 WEST SAK Development 16,636.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10139809 4,668,037.00 121.0 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 10,853.OftKB 4 1/2 14,218.00 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Directional Drill 6 3/4" hole @ 12 375' MD 110,979.26 5,156,650.15 24hr Forecast Daily Mud Cost Cummulative Mud Cost Directional Drill 6 3/4" hole. 9,265.14 678,508.84 Last 24hr Summary Directional Drill 6 3/4" hole 10884' - 11884' (1000'). General Remarks Weather Head Count Rig on Hi-Line 41 Deg, Cloudy, Winds W @ 6 MPH 39.0 Supervisor Title=° ~~ Scott Heim Rig Supervisor Granville Rizek Rig Supervisor Time Lo Start End Time Depth Start Depth End Time Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code (ftKB) (ftKB) Comm/Operation 00:00 01:00 1.00 INTRM1 DRILL CIRC P 10,882.0 10,882.0 Continue Circulate & condition mud to 8.68 PPG, YP 19, Visc = 67. Gels - 15/24. Pumps @ 300 GPM's, 3280 PSI. UP WT = 170K, SO WT = 123K, ROT WT = 133K. 30 RPM's. 10856' MD. ND = 3758'. Circulated 650 BBLS total.Reciprocate & rotate drill string. 01:00 02:45 1.75 INTRM1 DRILL LOT P 10,882.0 10,882.0 Rig up lines & valves to drill string & annulus to perform LOT. Pump @ .5 BPM to 52 strokes observing pressure break over (~ 52 strokes with 1030-PSI. 10 minute shut in bled back fe 850 PSI. Calculated MWB s 13.9 PPG. Rec`z~rd on chart. Rig down all equipment. 02:45 03:00 0.25 INTRM1 DRILL CIRC P 10,882.0 10,882.0 Make Top drive connection. Obtain parameters establishing circulation. Wlth bit below shoe, establish baseline ECD' at 280 GPM - 9.6 PPG. 8.65 Mud wt. 03:00 05:45 2.75 PROD1 DRILL DDRL P 10,860.0 10,882.0 Troughing 6 3/4" production hole for sidetrack from 10860' - 10882'.MD. ND = 3762'. 05:45 06:00 0.25 PROD1 DRILL DDRL P 10,882.0 10,884.0 Directional Drill 6 314" production hole from 10882' - 10884'.MD. ND = 3762'. UP WT = 185K, SO WT = 105K, ROT WT = 130K. 2-5K WOB. Pumps @ 300 GPM's - 3420 PSI. ART = 0 HRS. AST = .32 HRS. Total Bit HRS = .32 .Total Jar HRS # 0043 = 45.35 HRS, Total Jar HRS #0019 = 136.09 HRS. Max Gas observed = 0 Units. ECD's 9.46 PPG. Survey @ 10882' MD, INC = 80.61 DEG, AZ = 180.16 DEG, ND = 3761.83'. Observed bad detection for MWD with pump #1. Crew Change 06:00 12:00 6.00 PROD1 DRILL DDRL P 10,884.0 11,217.0 Directional Drill 6 3/4" production hole from 10884' - 11217'.MD. ND = 3764'. UP WT = 200K, SO WT = 99K, ROT WT = 132K. 5-10K WOB. RPM = 80. Pumps @ 275 - 300 GPM's - 3100 PSI. ART = .82 HRS. AST = 3.05 HRS. Total Bit HRS = 4.19 .Total Jar HRS # 0043 = 49.22 HRS, Total Jar HRS #0019 = 140.28 HRS. Max Gas observed = 30.01 Units. ECD's 9.75 PPG. Survey @ 11145' MD, INC = 93.39 DEG, AZ = 189.32 DEG, ND = 3777.49'.Observed bad detection for MWD with pump #1. Latest BOP Test Data Date Comment Page 1/3 Report Printed: 8/16/2006 ..i. i~=~ .. Daily Drilling Report -~-~ ~~- r' s_ 1J-109 • ~ _^ • i Report Date: 7/31/2006 Time Lo Start: End Time Depth Start Depth End Time Time Dur (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code (ftKB) (ftKB) Comm/Operation 12:00 13:45 1.75 PROD1 DRILL DDRL P 11,217.0 11,312.0 Directional Drill 6 3/4" production hole from 11217' - 11312'.MD. TVD = 3765'. UP WT = 200K, SO WT = 99K, ROT WT = 132K. 10-12K WOB. RPM = 80. Pumps @ 300 GPM's - 3380 PSI. ART = .66 HRS. AST = .37 HRS. Total Bit HRS = 5.22 .Total Jar HRS # 0043 = 50.25 HRS, Total Jar HRS #0019 = 141.31 HRS. Max Gas observed = 30.01 Units. ECD's 9.93 PPG. Survey @ 11239' MD, INC = 94.75 DEG, AZ = 184.44 DEG, TVD = 3770.82'.Observed bad detection for MWD with pump #1. 13:45 14:45 1.00 PROD1 DRILL CIRC T Rig 11,312.0 11,312.0 Trouble shoot MWD surreys, bad detection. switch pumps to #2. Replace all valves & seats in #1. Attempts to get good data with #1 pump failed. #2 pump good. Continue trouble shoot pump #1. 14:45 18:00 3.25 PROD1 DRILL DDRL P 11,312.0 11,593.0 Directional Drill 6 3/4" production hole from 11312' - 11593'.MD. TVD = 3751'. UP WT = 200K, SO WT = 99K, ROT WT = 132K. 5-10K WOB. RPM = 80. Pumps @ 275 - 300 GPM's - 3100 PSI. ART = 1.07 HRS. AST = .59 HRS. Total Bit HRS = 6.88. Total Jar HRS # 0043 = 51.91 HRS, Total Jar HRS #0019 = 142.97 HRS. Max Gas observed = 30 Units. ECD's 10.1 PPG. Survey @ 11526' MD, INC = 93.53 DEG, AZ = 183.63 DEG, TVD = 3754'. Obtain SPR's. Pump #1 20 SPM - 610 PSI. 30 SPM - 870 PSI. Observed bad detection for MWD with pump #1. Crew Change 18:00 00:00 6.00 PROD1 DRILL DDRL P 11,593.0 11,884.0 Directional Drill 6 3/4" production hole from 11593' - 11884'.MD. TVD = 3742. UP WT = 21 OK, SO WT = 85K, ROT WT = 140K. 5-10K WOB. RPM = 80. Pumps @ 300 GPM's - 3640 PSI, ART = .99 HRS. AST = 1.02 HRS. ADT = 2.01 HRS Total Bit HRS = 9.19 Total Jar HRS # 0043 = 53.92 HRS, Total Jar HRS #0019 = 144.66 HRS. Max Gas observed = 70 Units. ECD's 10.14 PPG. Survey @ 11813' MD, INC = 91.97 DEG, AZ = 180.76 DEG, TVD = 3753'. Concretion depths for the day = 11570'-11573' (3'), 11645'-11649' (4'), 11660'-11668' (8'), 11716'-11718' (2'). Mud Wt = 8.75 PPG, YP 20, Visc = 73.Observed bad detection for MWD with pump #1. Mud C heck Data YP Calc Gel (10s) Gel (10m) Gel (30m) HTHP Filt Density Temp Solids, Corr. Type Depth (ftKB) Dens (Ib/gal) Vis (s/qt) PV Calc (cp) (Ibf/1DOft') (Ibf/100ft') (Ibf/100tt') (Ibf/100ft') MBT (Ib/bbl) (mL/30min) pH (°F) (% ) Oil Based 11,884.0 8.75 71 16.0 19.000 22.000 24.000 27.000 3.0 12.0 Mud In'ection Fluid Fluid Source From Lease (bbl) Destination Note Cuttings 14.0 DS 4 G&I Oil Based Mud 0.0 Produced Water 10.0 CPF 1 Drillsites Drill Strin s: BHA No. 5 - 12-1 /4" Hole O ener / Bit Run No. 5 - <Drill Bit?> Depth In (ftKB) Depth Out (ftKB) TFA (Intl Noz) (ins) Nozzles (/32") IADC Bit Dull String Wt (10001bf) WOB (max) (100... WOB (min) (1000... 10, 775.0 15,160.0 1-1-NO-A-X-O-NO-Clean 12 0 out Drill Strin Com onents Jts Item Description OD (in) ID (in) Top Conn Sz (in) Top Thread Cum Len (fl) Hole Opener W/ 4' Bullnose 1.031 TFA 8 2.880 6 5/8 Reg 7.91 Bit Sub 8 3.250 6 5/8 H-90 10.92 Non Mag Flex Drili Collar 8 2.880 6 5/8 H-90 41.96 Integral Blade Stabilizer 8 1/8 3.000 6 5/8 H-90 47.36 Non Mag Flex Drill Collar 7.86 2.880 6 5/8 H-90 78.36 Non Mag Flex Drill Collar 7.65 2.880 6 5/8 H-90 109.35 Page 2/3 Report Printed: 8/16/2006 Ae ~'t'~° Daily Drilling Report p T { 7~Y"' ~` 1 J-109 °; ~ : . • • a Report Date: 7/31/2006 Drill Strin Com onents Jts Item Description OD (in) ID (in) Top ConnBz (in) Top Thread , Cum Len (ft) Dailey Jar W/ Slinger 7.73 3.000 4.5 IF 149.62 2 X HWDP 5 3.000 4.5 IF 211.19 Ghost Reamer 7 2.812 4.5 IF 217.18! 18 X HWDP 5 3.000 4.5 IF 770.90 5" Drill Pipe to Surface 5 4.276 4.5 IF 11,003.90 Interval Problems Start Date Start Depth (ftKB) End Depth (ftKB) Type Sub-type Wellbore 7/31/2006 10,882.0 12,383. 0 DSTRING/DHOLE EQU DHOLE DRILLING TOOL 1J-109 Wellbores Wellbore Name Wellbore API/UWI 1J-109 500292330700 Sectiori Size' (in) ? Act Top (ftKB) Acl Btm (ftKB) Start Date End Date PROD1 COND 1 42 43.2 121.2 12/21 /2005 12/27/2005 SURFAC 16 121.2 4,153.0 7/9/2006 7/13/2006 INTRMI 12 1/4 4,153.0 11,004.0 7/17/2006 7/24/2006 Plug Back 0 10,850.0 11,004.0 7/24/2006 7/30/2006 Page 3/3 Report Printed: 8/16/2006 O 3 ~~ C6 w ~• m N N d N N ~ ~ G ti tp C ~ .~. ~o;o ~~ ~ ro L 0 tO Insulated Conductor Tubing String: 4-'/:" 12.61!, L-80 to 58.2' MD Casing, 20", 94#, K55 x ~ '3-l/2", 9.30#, L-80, EUE 8 rnd (2.91" special drift to 500' MD) to 10,691.7 MD, 3,730' TVD 34", 0.312" WT @. ~ r +/- 80' MD J Profile nipples 501 A' MD 13-3/8", 68#, L-80, BTC, R3 ~ Gas Lift Mandrel, CAMCO 3-I/2" x I" Model KBMG, @ 1,845' TVD / 2,200' MD @ 63 degrees @ 4,15 l' MD / 2,306' TVD ~~ @ 77 degrees TD l6" bolt 3000' Of Downhole Heat'frace TOp OT Ugnu C nA Gas Lift Mandrel, CAMCO 3-I/2" x 1" Model KBbIG, 3,700' TVD / IQ,414 G' MD @ 82 Degree ]nclination 7,283' MD / 3,000"CVD Sliding Sleeve, CMU, 2 812" DS, @ 1Q,543.8' MD @ 84 Degrees 1-Wire A-Well Gauge Carrier for Tubing Jet Pump Intake Pressure @ 10,593.7 (I) Profile Nipple 37.52' above Baker Locator assembly ZXP Liner Top Packer Flex-Lot Liner Hanger C 0 ~~ ~~ ~c N~~~ a .. ',~ Top of West Sak D (a~ ~ 10,850' NlD / 3,757' TVD ~ ~-~ 9-5/8", 40#, L-SQ BTCbI, R3 Csg ~ @ 10,853' MD / 3,757 TVD 80 degrees TD I2-1/4" hole 80-00 Sealbore @ 10,647' MD IJ-109: D Sand Liner, 4-1/2", 11.6#, L80, BTC, R3 6-3/4" D sand lateral 10,701' - 1 1,263' (blank), 11,263' - 11,273' (swell packer), 1 1273' - TD 14,218' MD / 3,fi88' TVD 11,276' (blank), 11,276' - 14,190' (slotted), 14,190' - 14,196' (blank, Angle 82 degrees 14,196' - 14,207' (swell packer), 14,207' - 14,218' (blank) o PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: Drilling Supervisor: 1J-109 Rig: Doyon Rig 15 Date: 7/29/2006 G. Rizek/ S. Heim Pump used: #1 Mud Pump ~ ' Volume Input Strokes ~ Volume/Stroke Pum Rate: 0.10071 Bbls/Strk'i ~ S.OO'~ Strk/min I ~ Type of Test: , Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test Pressure In te rit Test Hole Size: i2-i/4" ~ ~ Casin Shoe De th Hole De th Pum in Shu t-in Pum in Shut-in RKB-CHF: 8 Ft 35 4151.6 Ft-MD 2306.0 Ft-TVD 2.3 Ft-TVD 6643.7 Ft-MD 286 Strks si Min si Strks si Min si _ . Casing Size and Description: 13-3/a" 68#/Ft L-80 BTC ~ 0 0 0 3050 0 0 0.00 400 Chan es for Annular Ade uac Test Pressure Int e rit Test 1 40 1 3040 6 160 0.25 380 Enter outer casing shoe test results in comments Mud Weight: 9.0 ppg 2 60 2 3040 12 200 0.50 365 Casing description references outer casing string. Inner casing OD: 9.6 In. 3 90 3 3040 18 , 230 1.00 345 Hole Size is that drilled below outer casing. 4 125 4 3040 24 ~ 260 1.50 Use estimated TOC for Hole Depth. 5 175 5 3040 30 ~ 295 2.00 Enter inner casing OD at right. Desired PIT EMW: 16.0 ppg 6 205 6 3040 36 320 2.50 300 Estimates for Test: 839 psi 1.2 bbls - 7 250 7 3040 42 . 340 3.00 290 -- ~ 8 295 8 3040 48 350 3.50 275 EMW =Leak-off Pressure + Mud Weight = 410 + 9 PIT 15 Second 9 340 9 3040 52 365 4.00 260 0.052 x TVD 0.052 x 2306 ~ Shut-in Pressure, si 10 380 10 3040 56 375 4.50 245 EMW at 4151.6 Ft-MD (2306 Ft-TVD) = 12.4 380 11 425 15 3040 60 ~ 385 5.00 240 ssoo Lost 20 psi during test, held - 12 475 20 3035 64 390 5.50 240 99.3% of test pressure. 13 525 25 3035 68 395 6.00 208 • ~..-J1e~~ k~•i. ~ ' ' - 14 575 30 3030 72 400 6.50 202 sooo -i _ 15 610 76 405 7.00 199 i 20 820 80 410 7.50 194 2soo I ___ 25 1050 84 410 8.00 186 ' 30 1240 88 410 8.50 180 w - - 35 1410 92 410 9.00 177 ~ 2000 ~ ~~ _ 40 1620 96 410 9.50 171 ~ ~ 45 1830 100 410 10.00 ~ lsoo - 50 2025 104 410 a 55 2240 108 400 112 400 sooo 60 2465 400 65 2680 116 - 70 2900 120 400 soo 72 2990 124 400 _ 73 3050 132 400 0 136 400 0 2 4 6 8 10 12 14 16 0 5 10 15 20 25 30 c~ Volume Volume Vol ume Vol ume Barrels Sh ut-In time, Minutes -,} ~~CASING TEST -LEAK-OFF TEST O PIT Point Pum ed Bled Back PUm ed Bled Back s .4 s s s Comments: Original test when drilled out 13-3/8" casing was 15.5ppg EMW Summary `~ ConocoPh~~~i s Project: Kuparuk River Unit Site: Kuparuk1JPad 3i~ ~~ P p Well: Plan 1J-109 AlaSkd ~ Wellbore: Plan 1J-109 H A LL I B U RTO N Design: 1 J-109 1 Sperry Crllling Servioes ~tot,n~~~~~~ „~ ,,. akd I>~.,~, iznu lu~ i~, Darr iuoyo~,, , i4o~api „ Florthing/ASP Y: 5945901.b4 EastinglASP X: 558800.73 - - _-- 10 3/4" 13 3/8" 10 3/4" ~ 13 3/8" Plan 1 J-120 1 J-109 _ _ 13 3/8" ~ ---~ ~ Plan 1J-111 / Plan 1 J-118 Plan 1 J-107 Closest in POOL CiosestApproach: Reference Well: 1J-109 Offset Well: 1J-118 (wp03) Coords. - Coords. - ASP ASP 3-D ctr-ctr t Meas. InG. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Min. Dist. Depth Angle TRUE Azi. ND E(+)/W(-) (180°) Comments Depth Angle TRUE Azi. ND E(+)/N/(-) (180°) Comments POOL Min Distance POOL Min Distance (1250.59 ft) in POOL (1250.59 ft) in POOL (4150 - 4200 MD) to (4150 - 4200 MD) to 1 J-118 (wp03) (3180 - 1 J-109 (3180 - 3200 1250.59 i'?^ ' ' 4150 77.71 77.37 2185.433 5946487 561615.5 -562.7415 3200 MD) 3200 66.76 93.3 2097.415 5945634 560704.4 282.2966 MD) Closest Approac h: Reference Weit: 1J-109 Offset Well: 1J-1 07 (wp02) Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Min. Dist. Depth Angle TRUE Azi. ND E(+)/W(-) (180°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (180°) Comments POOL Min Distance POOL Min Distance (823.11 ft) in POOL (823.11 ft) in POOL (4150 - 4200 MD) to (4150 - 4200 MD) to 1J-107 (wp02) (3370 - 1J-109 (3370 - 3400 823.11 4150 77.71 77.37 2185.433 5946487 561615.5 -562.7415 3400 MD) 3400 70.6 76 2098.938 5946478 560796.9 -560.6801 MD) Closest Approac h: Reference Well: 1J-109 Offset Well: 1J-1 11 (wp0 3) Coords. - Coords. - ASP ASP 3-D ctr-ctr ( Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Min. Dist. Depth Angle TRUE Azi. ND E(+)/W(-) (180°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (180°) Comments POOL Min Distance POOL Min Distance (522.92 ft) in POOL (522.92 ft) in POOL (4150 - 4200 MD) to (4150 - 4200 MD) to 1 J-111 (wp03) (3620 - 1 J-109 (3620 - 522.92 4150 77.71 77.37 2185.433 5946487 561615.5 -562.7415 3700 MD) 3700 76.17 81 2108.086 5946253 561154 -332.8054 MD) Closest Approac h: Reference Well: 1J-109 Offset Well: 1J-1 20 (wp02) Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Min. Dist. Depth Angle TRUE Azi. ND E(+)/W(-) (180°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (180°) Comments POOL Min Distance POOL Min Distance (1248.1 ft) in POOL (1248.1 ft) in POOL (4150 - 4200 MD) to (4150 - 4200 MD) to 1 J-120 (wp02) (3720 - 1 J-109 (3720 - 3800 1248.1 i2~f{a ` 4150 77.71 77.37 2185.433 5946487 561615.5 -562.7415 3800 MD) 3800 71.65 100 2116.083 5945265 561370.2 657.0998 MD) 1J-109 Srfc Csg POOLSummary.xls 8/17/2006 10:16 AM Note to File 1 J-109 (206-050...306-285) Kuparuk River Unit (West Sak) ConocoPhillips Alaska, Inc Phillips 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. --This is the first West Sak well where annular disposal has been proposed. As such, the casing sizes are nominally larger and the surface casing is set shallower than on Kuparuk wells in the field. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 250 bbls of cement .was circulated to surface. The net cement remaining in the surface hole was 54% XS of the calculated hole volume. --On the initial leak off test, the pressure slope rises smoothly then "lays" over to the determined LOT point at 15.5 EMW. Pump in is steady at that pressure. Examining the pressure change indicates a departure from straight line at about 14.5 EMW. During the observation period, the pressure declined to about 12.6 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 9-5/8" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. --An infectivity test down 13-3/8" x 9-5/8" annulus was conducted. The shape of the curve is similar to the original test. The pressure rises smoothly then "lays" over to the determined LOT point at 12.4 EMW. Pump in is steady at that pressure. Examining the pressure change indicates a departure from straight line at about 11.5 EMW. During the observation period, the pressure declined to 10.4 EMW. The lower EMW of all of these pressures indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA ran a bond log on the production casing. TOC is indicated at 7350' and which is approximately 1000' and above the top of the Ugnu C. --At this time, there are no wells within '/4 mile of the surface casing shoe. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. c7''~'l ¢ Tom Maunder, PE Sr. Petroleum Engineer August 30, 2006 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\060824--1J-109.doc • • Note to File KRU 1J-109 (PTD 2060500) August 30, 200b Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within We111J-109 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus of 1J-109. Recommendation Approve ConocoPhillips' request. Discussion CPAI's application was reviewed along with records from nearby wells KRU 1 J-03, KRU 1 J-09 and KRU 1J-14 (formerly known as Silvertip 1J-14). The operator reports the base of permafrost at about 1403' in this area. My estimate for base of permafrost in this area is approximately 1570' measured depth ("MD") and 1450' true vertical feet subsea ("TVDSS"), or about 2580' MD (830' TVDSS) above the top of the proposed injection interval (see attached schematic cross-section). Supporting documentation provided by the operator states "...all the proposed injection strata fall within the KRU boundary within which the aquifers are exempt from the definition of freshwater."i Although the aquifers beneath the Kuparuk River Unit have been exempted by 40 CFR 147.102(b}(3) for Class II injection activities, annular disposal is not considered a Class II activity. However, any aquifers that may contain freshwater in this section lie beneath permafrost and at such a depth that they will never be developed as sources of drinking water far a public water system. The proposed injection interval in KRU 1J-109 lies in the Sagavanirktok formation and the uppermost Ugnu formation within Section 36 of T11N, R10E, UM, which is over 2 miles from the boundary of the Kuparuk River Unit. The surface casing shoe of 1J-109 lies within a sandy zone that is overlain by a 35-foot thick claystone interval that appears to be well developed throughout this area. This claystone interval will act as the upper confining layer. The annulus proposed for disposal of drilling wastes extends from the 13-3/8" surface casing shoe at 4153' MD and 2279' TVDSS to the top of cement for the 7" casing string, which is estimated to be at about 7350' MD and 2987' TVDSS. The disposal injection zone in 1J-109 consists of a 700-foot thick sequence of sandstone and silty sandstone with scattered interbeds of siltstone and claystone. Several layers of claystone and siltstone will provide lower confinement. These layers appear to be continuous throughout the area and have an aggregate thickness of about 30' to 35'. CRU CD4-208 ~ ~ August 30, 2006 Note to File Page 2 of 2 In nearby wells, ahydrocarbon-bearing sand within the Sagavanirktok formation lies above the proposed injection interval. This sand displayed afair-quality oil show in samples collected in KRU 1J-14. The operator evaluated this sand in KRU 1J-121, and found it to be severely biodegraded. Their technical staff considers this to be poorer quality oil than that found within the Ugnu. In addition, this oil-bearing Sagavanirktok sand is shallower, and therefore cooler, than the Ugnu.2 Consequently, the oil is not considered producible at this time. In any event, this sand will be protected as it is behind pipe and separated from the injection interval by several claystone and siltstone intervals having an aggregate thickness of about 75'. Conclusions 1. The 9-5/8" surface casing shoe is set just below the base of a 35-foot thick claystone and siltstone interval that persists throughout the area and will provide upper confinement to prevent migration of drilling waste into freshwater or to the surface. 2. There appears to be a sufficient volume of sandstone and silty sandstone open to the annulus of KRU 1J-109 to accept the proposed injected fluids. 3. The lower confining layers are sufficiently thick (30' to 35' aggregate thickness) and laterally persistent to ensure injected materials remain within the target interval. 4. There are no potential sources of underground drinking water in this area that could ever reasonably supply a public water system. 5. Correlative rights will be protected. 6. Casing and the upper confining layer will protect anoil-bearing Sagavanirktok sand that overlies the proposed injection interval. The oil within this sand is not considered to be potentially producible at this time. I recommend approval of the proposed program to inject drilling waste into the annulus of KRU 1J-1 Steve Davies Senior Petroleum Geologist ' Randy Thomas, 2004, Application for Amendment to Area Injection Order 2B Cover Letter, dated September 8, 2004. z Michael Werner, 2006, Email to S. Davies of AOGCC dated August 30, 2006. North South 500282300'200 t ]510 500282:89000 CONOCOPHILLIPS ALASK GONOCOPNILLIPS 4LASK KVPARUK RN UlR 1}0] SILVERTIP I}Id 165] FSL 2d08 FEL 21 O' FSL 2i 19 FEL T':P I I N-Range. 10 E -Sec ]5 TVJP: I I N-Range. f 0 E- 5e~:. 35 KRU 1J-03 KRU 1J-109 KRU 1J-14 A..r a.y qyl. ~- t+ar .~..Iry i ggOepllf <TVD ba DT ] GM/U i a 2 ONNM tai a Oa0 uSliT f e ! 000 agta a~uln'ny canna P<y away ran- agoi ' ggoe <T VD r.o taw or a. - - w ax/u " i + 1 z oNRM zue !i aai user e~ ~a Permafrost Permafrost IWD. ~» Oi MI Iii ... i Na.P+~d, ... 1 Q tl1/OC : wNZS iwnM'n ® -- a of r w.. Ia o P eoo art zoo iei Iw as ~ ~ irw I~~ Dss ~ a aia vlv u i -1500 -1500 Upper Confining Zone Sagavanirktok -2500 Lower Confining Zone Ugnu Sands -3soo West Sak Sands teoo ,eaD 4a66 3000 „~~ z.~ .~, ,,.... sooo ' SUgU azoo '2'll~ ~>,. adoo seoo ~,, ti4 „, 8000 TD=1221) Confining layers Cement I Injection Zone Annulus Cement Y 13-3/8" a z3o6• TVD 2278' TVDSS Injection Zone Top Cement a~ 3014' TVD 2986' TVDSS 9-5/8" 4i 3760' TV D 3732' TVDSS reoD teen ,eoo 2000 ~M_ aulted Ou 2400 3200 3100 aoge le„J 3200 ,, f.: ., 3aoo 3600 TD=Iwo] A10 2B.003 Disposal Injection Zona -2000 Upper Confining Zone Sagavanirktok -2500 Lower Confining Zone Ugnu C -3000 Authorized by AIO 2B 003, but not in S. 76, 11 N, I OE Ugnu B & A Authorized by AIO 2 end 2A t'or all of 17N, l0E West Sak -3500 Sands AOGCC August 30, 2006 S. Davies • • WELL LOG TRANSMITTAL • To: State of Alaska August 15, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-109 & 1J-109 PB1, AK-MW-4474893 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23307-00, 70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETIli2NING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed: AUG 3 0 2006 ql Qil & Gas Cons. Commission Anchorage RE: KRU 1J-109 -Question • • Subject: RE: KRU 1J-109 -Question From: "Werner, Michael" <Michael.Werner@conocophillips.com> Date: Wed, 30 Aug 2006 10:50:53 -0800 To: steve davies@admin.state.ak.us CC: "Buchanan, Andrew" <Andrew.Buchanan@conocophillips.com>, "Greener, Mike R" <Mike.RGreener@conocophillips.com>, "Allsup-Drake, Sharon K" <Sharon.K.Allsup-Drake@conocophillps.com> Steve, Shows through this Sagavanirktok sand (2180 and in 1J-14) are generally characterized by dark brown oil, often with excessive oil over the shakers. In the late 1990's, ditch samples from this interval were evaluated in 1D-121 on strike to the north around 2150' md. Geochemical analysis indicated severe biodegradation. As a result, we generally feel this interval is of poorer oil quality than the deeper Ugnu oils which range from 9-12 API in southeast KRU. Even at the same API, this interval is shallower and cooler and would be much more viscous that the Ugnu. As a result we have characterized this interval as tar. However, we do not have an API measurement on the interval in question. Contact me if you have any other questions. Michael Werner Staff Geologist ConocoPhillips Alaska, Inc. (907) 265-6191 mchael.werner@conocophillips.com -----Original Message----- From: Buchanan, Andrew Sent: Wednesday, August 30, 2006 7:54 AM To: Werner, Michael Subject: FW: KRU 1J-109 - Question Do you have any insight into this. Andrew Buchanan Operations Geologist West Sak Team ConocoPhillips Alaska Inc. Office: (907) 265-6788 Cell: (907) 250-6545 Fax: (907) 263-9486 -----Original Message----- From: Greener, Mike R. Sent: Wednesday, August 30, 2006 6:46 AM To: Buchanan, Andrew Subject: FW: KRU 1J-109 - Question Another question for you, -----Original Message----- From: Stephen Davies [mailto:steve davies@admin.state.ak.us] Sent: Tuesday, August 29, 2006 6:25 PM To: Greener, Mike R. Cc: Tom Maunder Subject: KRU 1J-109 - Question Mike, One more question for the project geologist. In 1J-14, there is a hydrocarbon-bearing sand that lies shallower than the proposed disposal interval in 1J-109. The documents you provided mention the sand as being a tar sand. What is the basis for categorizing this as tar rather 1 of 2 8/30/2006 11:02 AM • Subject: RE: KRU 1J-109 Questions From: "Crreener, Mike R" <Mike.RCrreener@conocophillips.com> Date: Tue, 29 Aug 2006 08:57:32 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: Stephen Davies <steve davies@admin.state.ak.us>, David Raby <dave roby@admin.state.ak.us>, "Thomas, Randy L„ <Randy.L.Thomas@conocophillips.com>, Jim Regg <jim regg@admin.state.ak.us> My notes are in red. -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, August 29, 2006 8:01 AM To: Greener, Mike R. Cc: Stephen Davies; David Roby; Thomas, Randy L; Jim Regg Subject: Re: KRU iJ-109 Questions Mike, Thanks for the reply, a couple of further questions. 1. On the "auto-select", what is the criteria? Is it no differential pressure change point to point? You are correct. The program reviews the data. and ].oaks for ;~ definitive break over in the pressure readings. If it does not find one, then the engineer or foreman has to resort to old fashioned mental exercise to deterniiie the break over. 2. Having the annulus filled with power water would give collapse pressure backup, however according to the permit application the drawing shows the well equipped with and ESP. Has the completion plan been changed? The schematic that you are referring to might be the one for the drilling permit. The schematic in the stuldry application for the annular injection permit has the current confign~ration that is in the ground on the 1J-109. A little background an the drilling permit schematic and what is in the ground is in order. When this well was originally being planned it was considered to use an ESP to produce the well. Upon further review (after the permit to drill was submitted) it was determined that the well may not produce enough fluid froth the single Lateral since it was far from any current injection support to be able to warrant using an ESP to produce the well. At that time a jet pump with gas lift backup was settled upon as the production method best suited to produce this well. The schematic that was included in the sundry for the permit to annular inject has the current configl~ration of what was placed in the well. We have recently found that the longer reach wells have difficulty being produced with gas lift as the gas tends to override the oil production. This was found to be the case on. • the 1 J-1.84 during its pre-production period. pump would help clean this well up better. Tom Maunder, PE AOGCC It is cun~ently being analyzed to see if a jet Greener, Mike R. wrote, On 8/28/2006 10:12 AM: My answers in red below. -----0riginal Message----- F~t't: Thomas Maunder fmailto:tom_maunder@admin.state.ak.us] Sent: Friday, August 25, 2006 2:34 PM To: Greener, Mike R. Cc: Stephen Davies; David Roby; Thomas, Randy L; Jim Regg Subject: Re: KRU 1J-109 Questions Mike, Further to Steve's questions, I have a few as well. 1. What is the rationale for choosing the "leak off' points on the pressure plots? By examining the differential between counted strokes, I estimate pump in is initially indicated ~6b0 psi (14.5 EMW) on the initial leak off and 300 psi (11.5 EMW) on the freeze protect. Yau have a goad paint. Please review the attachment for the initial. surface LOT which auto calculated the leak off based on the 2"d flat line. Also, please review the annular plot which auto calculated the leak off. Bath were based on the flat line hreak over. 2. Your stated maximum surface pressure is the standard 1500 psi, however in your collapse calculation that surface pressure gives a maximum allowable mud weight of 8.5 ppg. This is significantly below the 12.0 ppg maximum stated elsewhere on the page and likely below what your actual waste slurry might weigh. It appears that the allowable surface pressure needs to be adjusted in order to honor the likely slurry weights. The 8.5 ppg calculation was for when (and if} the 1 J-109 goes to gas lift. The higher mud weightcalculation was for jet pump conditions where the annulus would be flied with power fltud. If injection approval is given, the annular injection program will specifically state that injection will not be allowed if the 1 J-109 is on gas lift. The doctunent showing the 8. S ppg mud weight was to show the collapse conditions for tl~e intermediate casing. 3. In the box at the bottom of the page, I believe what you calculate is the maximum allowable pressure at the surface casing shoe not the maximum anticipated. Based on my comments in point 1 above, this value may need to be revised. The maximum allowable pressLUe is the pressure at the shoe that we cannot exceed. Please find attached a pumping schedule for different fluid weights and the injection pressures that they can be pumped at so that the maximum allowable pressure at the surface casing shoe is not exceeded. Look forward to your replies, Tom Maunder, PE AOGCC Stephen Davies wrote, On 8/24/2006 12:43 PM: Mike, I have a couple of questions and comments for you and the project geologist regarding the proposed annular disposal at KRU 1J-109. Please respond to each and provide supporting information. 1. Demonstrate that the injected waste will be confined to the proposed injection zone. (A cross-section with the injection zone and upper and lower confining zones annotated would help support this contention.) 2. What is the basis for stating in the application that there are no freshwater aquifers in this area? 3. Discuss whether any shallow hydrocarbon-bearing zones exist in this area and whether they will be affected by the proposed annular injection operations. (Are there any oil or gas shows or other indications of hydrocarbons in nearby wells? If so, do they constitute potentially producible accumulations of hydrocarbons?) Attached are two items (one a pdf and t11e other a power point) that our geologist made that I hope will answer your questions. Please let me know if they do not. Thanks, Steve Davies Sr. Petroleum Geologist AOGCC 793-1224 ConocoPhilli s p • KRU Area Injection Order Amendment Attachment 1 Top Ugnu Depth Structure and Index to existing wells Top Ugnu Depth Structure ~ Kuparuk Bottom Hole Locations C1=100 ft ~ West Sak Pilot BHL 1 Mile top Ugnu Penetration '~ 4 1J 0 9 s coPhilli C Wes t Sa k 1 1 J- 10 -- ~; - p ono SN MD OIL R 1 LD 7 GR MVYD 5 SN MD MNID S PD ~? S OR_MVJD_5 1 SNO MD PD MWD_S_ GR FIXJ R 1 _ _ _ _ I _ _ _ _ _ _ _ _ n ~o 000 2800 4100 r 3800 3100 r; 2700 4200 I 3700 2700 a 3100 3200 aoo 2800 Req ueste ~._ , Ugnu C 2800 4500 3900 Additional as 32°° 3300 4600 I 4000 Disposal ~ ~ 2900 Interval 4700 aloo 3 4800 3400 U g n u B 30~ 4200 ~ A1O2B ~ 3400 3~0 5000 I Disposal L 3500 Ugnu A sloo 3100 aaoo Interval w~ ' 5 3100 5200 4500 O J 3500 3600 5300 ~ 3200 4800 K-13 S h 3200 5400 3600 3700 5500 3300 4700 West Sak 33~ 4800 KRU Area Injection Order Amendment 3800 5700 Attachment 2 West Sak 1 Type Log and Stratigraphic Correlation Section to 1J Area West a E UP_3411-10_1 0 2]00 ~ 240 '® 2.00 2900 °° 1J-10 ~~ .n 2900 2600 0 ~ ,5P . , RMWD_6_1 ®6 2600 M° 1100 1 J-09 ~ '" 2500 2850 2]0 ~ 9000 2]00 2]00 4100 .300 1 J-03 ~ m'~ 2100 2]5 slop asoo UGNU C 3]50 aw 28 2600 w 1390 3 9 4900 d600 ~L C B]o ~ 2900 3300 0 4]oa 2w5 4800 uGNU 6 2a50 3m0 9a 3000 3000 4900 ~m 6000 UG 355 100 ~` w~ ~k 3500 3100 100 5100 NUq ""e 50 m 3t 9 '4. ~ s2oo s300 -13 ANT A tw 3 ~0 320o x405 m 3G ~F ~0 ss00 'M fiAy4 3300 990 WEST S ~~ 3350 WEST m 3450 ]~0 3 3590 ~]yw m 396] R MWD_6_t WD~_ 9600 2]00 9]00 eoo 2600 V 3900 4000 2900 a 100 9000 d20 asoo 9100 asoo asoo yq 3200 4fi00 k. 4]00 9300 4800 C 00 q E ~ - -- 6 Mo pR MWD_e_i PO MWD_e_ 2e0a asoo 4600 4]00 2900 4800 4900 9000 9000 6100 ez5a 5900 eao5 3200 5500 5fi00 5]00 5000 5900 3x00 6000 6100 6200 3300 fi300 6000 :ast ~~ ConocoPhilli s p C] • KRU Area Injection Order Amendment Addendum Structural Section Kup 34-11-10 to 1J-03 10 ~ ~ ~.~,,/! 1 J-~0~" STVD MD NPHIS_MWD_5_t GR MWD 5 1 RPD MWD 5 1 HOB MWD u 1::` o aiw ~m i aww~ iooo i x. .. ci 2100 --"°~' =f 22°° _~we~. Ta ~ _~ t- - E~ c 2300 ( ( - ~~E'-~- ~ ~- 2400 J\ ~ -_$.~ _ ~,. 2000 ~ . `~ ~. ~=~'°~ - ~ Surface sg 2soo ~~ ~ '~~~ _'-__ ._ Y z,oo 2800 --'___ ~_ `%-_ a_ ~ ~ ~ 200 ~ ~ `~ _ ~~ ~ zzoo _ 2800 - - _ - _,, _~___ 1 2900 -- y- '_ 2300 ~ -'F dr _ r 3000 ~_ ~. . ~~ ~ 2400 3100 _ `- _ .~_ - 3200 ~~i._ 2500 3300 S gz~F4 1 J Proposed Annular Injection r Sand ~ Cows? Annular Injection Interval • Top - 550' ss below T3 Sand @ Proposed surface casing shoe • Base - 250' ss above Top Ugnu @Top cement (~ 500' and above Ugnu) • Good Sand through out interval • Ugnu Confining Zone in 1 J Area 1 J ~9~ X05 ~'"( RPD_MWD_S_1 1 OHMM 1000 MWD_S_1 ROP RPM_MWD_S_1 NPHIS_MWD_S_1 _ 750 PPtiR 0 SSTVD MD ~ OHMM 1000 60 PU 0 GR MWD S 1 RPS_MWD_S_~ RHOB_MWO_S_1 0 GAP( 150 t _ UHMM 1000 1.85 G/L3 2 65 - - - 2600 3500 `_~' {~ ___a~ 3600 =~ 50' muc '-- ~ ~F ca 2700 ` -_ 70' inter) ~, 3700 muds '~ ~ An - - __ - siltst - 3800 -~ -, 2800 - .~~ 3900 ~ 6~= Ugn u C =~ aooo Zsoo -~ _- aioo z~ Ugnu Confining Zone • Ugnu C overlain by ~70' of interbededded mudstone and siltstone with a 50' mudstone cap • Simulation and field tests (stone demonstrate it is extremely p unlikely that vertical fractures Bedded can be propoagated through tone similar mudstones in the West d Sak one • Injection in the Ugnu will be below formation parting pressure Top Confining Zone • Surface Casing Annular Injection Interval • } Basal Seal (interbedded clay and silt) West East Depth Structure on Top Annular Injection Interval (550 feet below T3 Sand) Annular Injection Interval • Top - 550' TVD below T3 Sand @ Proposed surface casing shoe , • Base - 250' TVD above Top Ugnu @Top cement (~ 500' and above Ugnu) ~~ Wellbore intersection with annular injection interval Based on Wellplan Proposals Dated 6/20/04 1J-109 Annular Injection • Cross section shows Upper and Lower confining zones. • • Refer to Memo in regards to fresh water aquifer • There are no identified hydrocarbon zones identified in the injection interval. • -There is a tar sand above the injection interval behind surface casing and above the confining clay. ConocoPhilli s p Containment to Ugnu • Injection in the Ugnu will be below formation parting pressure. A ConocoPhillips internal study of Ugnu as a disposal zone states that "vertical containment for the injected volume is maintained if bottom hole injection pressure at the slurry volume injected does not exceed the minimum horizontal stress in the layers above and below the injection interval." The horizontal stress of confining mudstone is estimated at 2600 psi from a log of 1 J-10. Injection simulations done at expected rates and solids loading indicate that the bottom hole injection pressure will not exceed this 2600 psi value, and injected fluids and solids will therefore be contained to the Ugnu sands. • • ~5, ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7tfi Avenue Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] 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 V!/ELL LOG Ti4.4NSlIlI/7°T~4L • ~~~~~ ~uc~ ~`~ ~~to tJil & Gas Cons. t~ommissic,rl /111C110~~ ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1) 1 BL / EDE Disk 2] 3) 4) 5] 6] 7] 1 J-109 Caliper Report 08 Aug-06 Signed Print Name: fC ~;1 ~~, ` n P O. ,~1 P VI Date ~, PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE(U~MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D'\00 PDSANC-200612 W d\Distrib ti \T 1 Sh \T or u on ransmitta _ eels ransmd_Ongmal.doc ~DCo--~50 1`~b~~l - - ~o~-c~so ~ 1 ~~/ • ~' Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhiliips Alaska, Inc. Well: 1J-109 Log Date: August 8, 2006 Field: Kuparuk ', Log No.: 8044 State: Alaska Run No.: 1 API No.: 50-029-23307-00 Pipet Desc.: 9 5/8" 40 Ib. BTC-M Top Log Intvl1.: Surtace Pipet Use: Casing Bot. Log Intvl1.: 10,542 Ft. (MD) Inspection Type : Casing Wear, Corrosive, and Mechanical Damage Inspection COMMENTS This caliper data is tied into the Casing Hanger @ 0' Depth. This tog was run to assess the condition of the 9.625" casing with respect to corrosive and casing wear damages. The 9.625" casing logged appears to be in good condition with respect to casing wear and corrosive damage. No significant penetrations, areas of cross-sectional wall foss, casing wear, or I.D. restrictions are recorded throughout the 9.625" casing interval logged. Due to the high deviation of this well (~71 degrees) at _2,000' the caliper remained off-center to the low side of the casing in the interval between -2,000' and 10,542; preventing half of the 40 caliper fingers from reaching the internal diameter of the high side of the casing. This resulted in a loss of coverage for almost half of the high side of the casing. However, the recordings of the low side of the internal diameter indicate no significant corrosive damage or casing wear. The recordings in the top 2, 000' of the casing also indicate no significant corrosive damage, casing wear, or 1. D. restriction. The distribution of maximum -recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 10%) are recorded throughout the 9.625" casing interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 8%) are recorded throughout the 9.625" casing interval logged. MAXIMUM RECORDED lD RESTRICTIONS No significant I.D. restrictions are recorded throughout the 9.625" casing interval logge ~~~~~~ rr (~ AUG 2 9.2006 Oil & Gas Cons Co~xrlission Anc~~ora9e Field Engineer: R_ Richey/Wm. McCrossan Analyst: M. Tahtouh Witness: Granville/Helm/Herbet ~it:~Q,C~I V%C. LlaCflGStlC SE'Cv IC2;: 1lC. P. ~. 5c;;t_ 1.~6~, Sta~O~'d, Ti< ~,~' i`=}}j ~%~ e: 0:821 a~~;888~ 565-~~85 ~-a:.. ,~8?) 5:~5-1'r:~ E-ma'; PnS:1n1~~~oryiec,Cur?i Frua!'~o? Say FiA?CI utfiice fl~~~re: {~a(;% 6Sy-23~i Via;, !?~,~) y8g-~'1~ • • PDS Report Overview ~ s~ Body Region Analysis Well: 1J-109 Survey Date: August 8, 2006 Field: Kuparuk Tool Type: MFC 40 UW No. 210357 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: M. Tahtouh Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 9.625 ins 40 f L-80 8.835 ins 9.625 ins 1.2 ins 1.2 ins Penetration and Metal Loss (% wall) ~ penetration body = metal loss body 300 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 8$% 8$% Number of 'oints anal sed total = 2 77 gene. 1 276 0 0 0 0 loss 218 59 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 2 2 0 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 1 51 Bottom of Survey = 2 7 100 101 151 201 251 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 40.0 ppf L-80 Well: 1 J-109 Body Wall: 0.395 in Field: Kuparuk Upset Wall: 0.395 in Company: Conoco Phillips Alaska, Inc. Nominal l.D.: 8.835 in Country: USA Survey Date: August 8, 2006 Joint No. Jt. Depth (Ft.) I'c~n. l 11 set (Ins.) Pen. Body (Ins.) I'c~n. "r~ ~1c~t,~l I oss ",~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 1 -0 u 0.01 4 8.72 2 28 +! 0.01 ~ 8.74 3 66 l) 0.01 ! ~ 8.67 Lt. De osits. 4 107 +! 0.02 ~ 8.66 5 146 t! 0.01 1 8.75 6 184 i? 0.01 8.73 7 220 a 0.01 > 8.77 8 260 U 0.03 r _' 8.76 9 299 U 0.01 ~ a 8.78 10 338 t! 0.03 - 8.72 11 377 +! 0.01 ~ 8.70 12 415 +? 0.01 -J 8.69 13 454 ~ ? 0.02 ~ 8.74 14 495 !? 0.01 8.76 15 533 ~.? 0.01 i > 8.70 16 572 t? 0.02 ~ a 8.73 17 609 +? 0.02 ~ -1 8.75 18 647 E? 0.01 3 E, 8.74 19 685 +! 0.01 4 5 8.76 20 722 U 0.02 (~ - 8.62 Lt. De osits. 21 762 +! 0.01 ~ 8.74 22 800 U 0.01 8.74 23 838 i! 0.02 t, -I 8.69 Lt. De o its. 24 876 U 0.01 4 8.74 25 913 +! 0.02 > 8.77 26 951 a 0.02 5 ! 8.74 27 988 U 0.02 4 8.71 28 1025 +) 0.02 5 8.73 29 1064 E> 0.01 ~ 8.74 30 1103 U 0.02 E, 8.75 31 1141 t? 0.01 i 8.76 32 1180 t? 0.01 -1 8.73 33 1219 +? 0.03 7 8.74 34 1257 U 0.03 7 a 8.75 35 1296 i) .02 U 8.71 36 1334 E! 0.01 3 s 8.74 37 1372 t! 0.02 E~ a 8.74 38 1408 i! 0.01 i ~' 8.76 39 1446 i ? 0.00 i 8.74 40 1482 ~ ! 0.02 t~ 8.75 41 1519 +! 0.02 b 8.73 42 1556 +! 0.02 r, -1 8.75 43 1595 +! 0.01 '~ 8.72 44 1631 +1 0.02 5 8.71 45 1669 U 0.02 v 4 8.73 46 1707 U 0.01 3 E9 8.74 47 1745 t! 0.02 ~ 8.75 48 1782 ! ! 0.02 5 ~~ 8.75 49 1820 1! 0.02 i - 8.71 50 1858 U 0.02 4 ~ 8.73 Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 40.0 ppf L-80 Well: 1J-109 Body Wall: 0.395 in Field: Kuparuk Upset Wall: 0.395 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 8.835 in Country: USA Survey Date: August 8, 2006 Joint No. Jt. Depth (Ft.) Ncn. 111„c~i fln>.) Pen. E3ody (Ins.) I'en. "r<~ ~1rt,il I ~xt °~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 1896 (~ 0.01 ~ t ~ 8.74 52 1934 (~ 0.02 (~ r, 8.73 53 1973 U 0.01 ~' ~ 8.72 54 2009 (~ 0.02 (~ -J 8.72 55 2048 i ~ 0.02 (, 8.69 56 2086 n 0.02 i~ 8.67 Lt De osits. 57 2124 (~ 0.02 5 N A Bottom Half of LD. 58 2163 a 0.02 (~ I N A Bottom Half of LD. 59 2202 (1 0.02 (~ 1 N A Bottom Half of LD. 60 2241 t~ 0.02 4 I N A Bottom Half of LD. 61 2278 i~ 0.02 5 ( N A Bottom Half of LD. 62 2316 U 0.02 5 1 N A Bottom Half of LD. 63 2355 i ~ 0.01 -t I N A Bottom Half of LD. 64 2394 ! ~ 0.02 ~ i N A Bottom Half of LD. 65 2433 U 0.02 5 I N A Bottom Half of LD. 66 2476 U 0.02 i I N A Bottom Flalf of LD. 67 2513 i I 0.01 ~' I N A Bottom Half of LD. 68 2550 (~ 0.02 -i I N A Bottom Half of LD. 69 2588 U 0.01 ~ I N A Bottom Half of LD. 70 2624 i ~ 0.01 I N A Bottom Half of LD. 71 2663 (~ 0.01 I N A Bottom Half of LD. 72 2700 (I 0.01 -1 I N A Bottom Half of LD. 73 2739 (~ 0.01 ~ u N A Bottom Half of LD. 74 2776 (~ 0.01 ~ I N A Bottom Half of LD. 75 2815 a 0.01 -t I N A Bottom Half of LD. 76 2859 a 0.02 (~ I N A Bottom Half of LD. 77 2896 (1 0.01 3 I N A Bottom Half of LD. 78 2935 i) 0.02 5 I N A Bottom Half of LD. 79 2974 a 0.02 4 I N A Bottom Half of LD. 80 3013 ~ ~ 0.02 `; I N A Bottom Half of LD. 81 3052 i ~ 0.01 i I N A Bottom Half of LD. 82 3092 i ~ 0.01 -t I N A Bottom Half of LD. 83 3130 U 0.01 ~ I N A Bottom Half of LD. 84 3167 U 0.01 I N A Bottom Half of LD. 85 3202 U 0.02 (> I N A Bottom Half of LD. 86 3239 (1 0.02 5 I N A Bottom Half of LD. 87 3278 U 0.02 i I N A Bottom Half of LD. 88 3315 i ~ 0.01 ~ I N A Bottom Half of LD. 89 3354 U 0.01 1 I N A Bottom Half of LD. 90 3392 a 0.01 4 I N A Bottom Half of LD. 91 3429 a 0.01 I N A Bottom Half of LD. 92 3467 (~ 0.02 i I N A Bottom Half of LD. 93 3504 (I 0.02 6 I N A Bottom Half of LD. 94 3543 U 0.02 5 I N A Bottom Half of LD. 95 3581 U 0.02 G 1 N A Bottom Half of LD. 96 3619 U 0.02 5 I N A Bottom Half of LD. 97 3655 (~ 0.01 =t I N A Bottom Half of LD. 98 3694 i~ 0.02 i I N A Bottom Half of LD. 99 3733 0.01 I N A Bottom Half of LD. 100 3772 0.01 a I N A Bottom I-calf of LU. Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 40.0 ppf L-80 Well: 1 J-109 Body Wall: 0.395 in Field: Kuparuk Upset Wall: 0.395 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 8.835 in Country: USA Survey Date: August 8, 2006 Joint No. Jt. Depth (Ft.) I'c~n. lllrs~~l (ln>J Pen. Body (Ins.) I'c~n. `% ~h~t~rl I ~z~s ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 101 3810 U 0.02 5 I N A Bottom Half of LD. 102 3848 tl 0.01 4 I N A Bottom Half of I.D. 103 3886 n 0.01 4 I N A Bottom Half of LD. 104 3924 U 0.01 3 I N A Bottom Half of LD. 105 3960 t~ 0.02 i I N A Bottom Half of LD. 106 3997 ~I 0.01 -l I N A Bottom Half of LD. 107 4035 U 0.02 4 I N A Bottom Half of LD. 108 4072 II 0.02 4 I N A Bottom Half of LD. 109 4110 a 0.01 -3 1 N A Bottom Half of LD. 110 4148 a 0.02 6 I N A Bottom Half of LD. 1 1 1 4186 U 0.02 ~1 I N A Bottom Half of LD. 112 4225 U 0.02 (~ I N A Bottom Flalf of LD. 113 4263 cl 0.02 r, I N A Bottom Flalf of LD. 114 4301 rl 0.02 5 I N A Bottom Fialf of LD. 115 4340 ll 0.02 -t I N A Bottom Half of LD. 116 4379 l1 0.01 -i I N A Bottom Half of LD. 117 4417 n 0.01 ~ I N A Bottom Half of LD. 118 4454 U 0.02 b I N A Bottom Half of LD. 119 4493 I I 0.02 5 I N A Bottom Half of LD. 120 4533 U 0.02 5 I N A Bottom Half of LD. 121 4569 a 0.02 6 1 N A Bottom Half of LD. 122 4607 i t 0.02 5 1 N A Bottom Half of LD. 123 4646 tl 0.02 5 I N A Bottom Half of LD. 124 4684 tr 0.02 E~ I N A Bottom Half of LD. 125 4723 II 0.02 5 I N A Bottom half of LD. 126 4761 O 0.02 6 I N A Bottom Half of LD. 127 4798 (1 0.02 b 1 N A Bottom Half of LD. 128 4837 U 0.02 (~ I N A Bottom Half of LD. 129 4876 t) 0.02 > I N A Bottom Half of LD 130 4911 II 0.02 5 I N A Bottom Half of LD. 131 4946 t~ 0.02 S 1 N A Bottom Half of LD. 132 4985 tl 0.03 (~ I N A Bottom Half of LD. 133 5024 ~ ~ 0.02 -1 I N A Bottom Half of LD. 134 5063 U 0.01 -~ I N A Bottom Half of LD. 135 5102 Il 0.01 '' 1 N A Bottom Half of LD. 136 5140 U 0.02 5 I N A Bottom Half of LD. 137 5178 U 0.02 (> I N A Bottom Half of LD. 138 5217 ~) 0.02 (i I N A Bottom Half of LD. 139 5256 tl 0.02 4 I N A Bottom Half of LD. 140 5294 a 0.02 ~ I N A Bottom Half of LD. 141 5332 tl 0.02 ~ I N A Bottom Half of LD. 142 5371 n 0.01 -1 1 N A Bottom Half of LD. 143 5410 U 0.02 -1 I N A Bottom Half of LD. 144 5446 r I 0.02 ~ I N A Bottom Half of LD. 145 5485 a 0.01 -1 1 N A Bottom Half of LD. 146 5523 U 0.02 5 I N A Bottom Half of LD. 147 5561 U 0.02 5 I N A Bottom Half of LD. 148 5598 tl 0.02 -1 1 N A Bottom Half of LD. 149 5635 a 0.01 d 1 N A Bottom Half of LD. 150 5674 U 0.02 4 I N A Bottom Half of LD. _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 40.0 ppf L-80 Well: 1 J-109 Body Wall: 0.395 in Field: Kuparuk Upset Wall: 0.395 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 8.835 in Country: USA Survey Date: August 8, 2006 Joint No. Jt. Depth (Ft.) I'~~n. Ill~sc~t (ln~.) Pen. Body (Ins.) Pf°n. °o ~1c~t,il I ~>~~ ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 151 5713 t! 0.02 5 I N A Bottom Half of I.D. 152 5751 !? 0.02 ~ 1 N A Bottom Half of LD. 153 5789 ~) 0.02 5 I N A Bottom Half of LD. 154 5829 U 0.02 b I N A Bottom Half of LD. 155 5866 U 0.01 a I N A Bottom Half of LD. 156 5906 t t 0.02 -1 I N A Bottom Half of LD. 157 5943 t? 0.01 _' I N A Bottom Half of LD. 158 5983 a 0.02 -1 I N A Bottorn Half of LD. 159 6022 I! 0.01 -t I N A Bottom half of LD. 160 6061 tt 0.02 5 I N A Bottom Half f LD. 161 6099 U 0.01 ~ i N A Bottom Half of LD. 162 6138 ll 0.01 -1 I N A Bottom Half of LD. 163 6175 t I 0.02 ~ I N A Bottom Half of LD. 164 6212 t! 0.02 ~ I N A Bottom Half of LD. 165 6250 U 0.02 ~ N A Bottom Half of LD. 166 6289 ~? 0.01 I N A Bottorn Half of LD. 167 6328 t! 0.02 > I N A Bottom Half of I.D. 168 6365 U 0.04 1l) I N A Shallow ittin .Bottom Half of LD. 169 6404 t) 0.03 ~) U N A Shallow ittin .Bottom Half of LD. 170 6443 ti 0.01 4 1 N A Bottorn Half of LD. 171 6482 t l 0.01 4 I N A Bottom Half of LD. 172 6519 ~ I 0.01 2 I N A Bottom Half of LD. 173 6557 U 0.01 ~ I N A Bottom Half of LD. 174 6594 l1 0.02 ~ u N A Bottom Half of LD. 175 6633 t! 0.01 i I N A Bottom Half of LD. 176 6673 tt 0.01 _' I N A Bottom Half of LD. 177 671 1 U 0.01 4 I N A Bottom Half of LD. 178 6749 t! 0.02 4 I N A Bottom Half of LD. 179 6789 a 0.02 (> I N A Bottom Half of LD. 180 6828 U 0.02 G I N A Bottom Half of LD. 181 6864 tl 0.02 (> I N A Bottom Half of LD. 182 6901 t! 0.03 ~ I N A Bottorn Half of LD. 183 6939 t? 0.02 i~ I N A Bottom Half of LD. 184 6976 t) 0.01 i I N A Bottom Half of LD. 185 7014 t) 0.01 ~ I N A Bottom Half of LD. 186 7053 U 0.02 U I N A Bottom Half of LD. 187 7090 t) 0.01 4 I N A Bottom Half of LD. 188 7127 t! 0.02 (~ I N A Bottom Half of LD. 189 7162 l! 0.02 (~ N A Bottom Half of LD. 190 7201 U 0.02 5 I N A Bottom Half of LD. 191 7241 U 0.02 b I N A Bottom Half of LD. 192 7279 t! 0.02 5 I N A Bottom Half of LD. 193 7316 a 0.02 5 I N A Bottorn Half of LD. 194 7355 t) 0.01 i I N A Bottom Half of I.D. 195 7394 U 0.02 .5 1 N A Bottom Half of LD. 196 7431 U 0.02 5 I N A Bottom Half of LD. 197 7470 t? 0.01 I N A Bottorn Hal(of LD. 198 7508 ~? 0.02 ~ I N A Bottorn Half of LD. 199 7548 0.01 I N A Bottorn Half of LD. 200 7586 0.01 -1 N A Bolcom Half of LD. ®Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 40.0 ppf L-80 Well: 1 J-109 Body Wall: 0.395 in Field: Kuparuk Upset Wall: 0.395 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 8.835 in Country: USA Survey Date: August 8, 2006 Joint No. Jt. Depth (Ft.) I'~~n. L 11 ~x~ I (In.) Pen. Body (Ins.) I'c~n. "/o 'vtct~rl I o~tis `,<, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 201 7625 t) 0.02 5 I N A Bottom Half of LD. 202 7664 !? 0.02 t> I N A Bottom Half of I.D. 203 7702 !) 0.02 5 it N A Bottom Half of LD. 204 7740 t) 0.02 -1 1 N A Bottom Half of LD. 205 7776 a 0.01 4 I N A Bottom Half of LD. 206 7812 t) 0.01 I N A Bottom Half of I.D. 207 7850 ~) 0.01 ~ i N A Bottom Half of LD. 208 7888 t) 0.01 I N A Bottom Half of LD. 209 7926 tt 0.01 > I N A Bottom Half o(LD. 210 7965 U 0.01 I N A Bottom Half of LD. 211 8004 U 0.01 ~ I N A Bottom Half of LD. 212 8043 a 0.01 3 1 N A Bottom Half of LD. 213 8081 t) 0.01 4 I N A Bottom Half of LD. 214 8119 U 0.01 11 N A Bottom Half of LD. 215 8156 t) 0.02 ~ I N A Bottom Half of LD. 216 8195 t) 0.01 a i) N A Bottom Half of LD. 217 8232 t) 0.01 I N A Bottom Half of I.D. 218 8272 U 0.01 -I t I N A Bottom Half of LD. 219 8310 U 0.01 I N A Bottom Half of LD. 220 8347 U 0.01 3 t i N A Bottom Half of LD. 221 8386 U 0.01 I N A Bottom Half of LD. 222 8424 U 0.02 -t I N A Bottom Half of LD. 223 8459 U 0.02 1 I N A Bottom Half of LD. 224 8496 t 1 0.02 > i N A Bottom Half of LD. 225 8535 a 0.01 4 I N A Bottom Half of LD. 226 8573 (1 0.01 -3 I N A Bottom Half of LD. 227 8612 U 0.01 ; I N A Bottom alf of LD. 228 8651 t) 0.01 4 1 N A Bottom Half of LD. 229 8690 tl 0.02 5 I N A Bottom Half of LD. 230 8727 tl 0.01 4 I N A Bottom Half of LD. 231 8762 i) 0.02 5 I N A Bottom Half of LD. 232 8801 t? 0.02 ~1 I N A Bottom Half of LD. 233 8838 U 0.01 4 I N A Bottom Half of LD. 234 8876 tl 0.01 ~i N A Bottom Half of LD. 235 8914 t) 0.02 i ~) N A Bottom Half of LD. 236 8953 t? 0.02 •1 ti N A Bottom Half of LD. 237 8992 t) 0.02 <t I N A Bottom Half of LD. 238 9030 t~ 0.02 5 I N A Bottom Half of LD. 239 9068 t) 0.01 4 t) N A Bottom Half of I. 240 9106 t) 0.01 4 U N A Bottom Half of LD. 241 9144 t) 0.02 4 U N A Bottom Half of LD. 242 9182 i) 0.01 4 t) N A Bottom Half of LD. 243 9221 !? 0.02 -t 1 N A Bottom Half of LU. 244 9258 a 0.01 S I N A Bottom Half of LD. 245 9297 a 0.01 I N A Bottom Half of LD. 246 9335 t) 0.01 3 I N A Bottom Half of LD. 247 9373 U 0.01 3 I N A Bottom Half of LD. 248 9413 U 0.01 4 tl N A Bottom Half of LD. 249 9454 a 0.02 a I N A Bottom Half of LD. 250 9491 t) 0.01 i~ N A Bottom Half of LD. Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 40.0 ppf L-80 Well: 1 J-109 Body Wall: 0.395 in Field: Kuparuk Upset Wall: 0.395 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 8.835 in Country: USA Survey Date: August 8, 2006 Joint No. Jt. Depth (FL) I'~~n. Ul~,c~i (In.} Pen. Body (Ins.) I'~•n. `;~~ ~ict,~l log; `;<, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 251 9530 t? 0.01 4 1 N A Bottom Half of LD. 252 9568 i? 0.02 5 I N A Bottom Half of LD. 253 9607 t1 0.01 4 I N A Bottom Half of LD. 254 9646 i? 0.02 -t I N A Bottom Half of LD. 255 9686 !? 0.01 a I N A Bottom Half of LD. 256 9724 t? 0.01 s I N A Bottom Half of LD. 257 9762 t? 0.01 -1 I N A Bottom Half of LD. 258 9801 a 0.01 ~# I N A Bottom Half of LD. 259 9838 tl 0.01 4 I N A Bottom Half of LD. 260 9873 t? 0.01 ~ I N A Bottom Half of LD. 261 9910 U 0.01 3 I N A Bottom Half of LD. 262 9949 t? 0.01 I N A Bottom Half of LD. 263 9989 t? 0.01 ~ I N A Bottom Half of LD. 264 10025 ~? 0.01 S I N A Bottom Half of LD. 265 10063 a 0.01 ~ i N A Bottom Half of LD. 266 10101 L? 0.02 4 I N A Bottom Half of LD. 267 10138 t? 0.01 4 i? N A Bottom Half of LD. 268 10177 t? 0.01 ; t ~ N A Bottom Half of LD. 269 10216 a 0.02 5 1 N A Bottom Half of LD. 270 10254 t? 0.02 5 1 N A Bottom Half of LD. 271 10292 t? 0.02 ~ I N A Bottom Half of LD. 272 10330 ~? 0.02 -t I N A Bottom Half of LD. 273 10366 i! 0.01 -1 I N A Bottom Half of I. 274 10406 ~? 0.02 -1 1 N A Bottom Half of LD. 275 10445 ti 0.02 i N A Bottom Half of LD. 276 10484 a 0.02 5 1 N A Bottom Half of LD. 277 10522 U 0.01 -1 1 N A Fnd of Lo _ Penetration Body Metal Loss Body Page 6 08/22/06 S~b6erger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~ ,;~~,;G 2 3 2006 ~~~,~ Cil ,~ ~ I;~ns. Gpmmission Anchorage ~-os~ Well Job # Log Description NO. 3936 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2E-05 11249943 SBHP SURVEY 08/08/06 1 1J-109 11235392 CBL/USIT 08/07/06 1 3Q-11 11213793 LDL 08/14/06 1 2T-28 11235394 INJECTION PROFILE 08/16/06 1 1H-17 11213794 PROD PROFILE W/DEFT 08/15/06 1 1L-22 11235395 INJECTION PROFILE 08/17/06 1 1J-166 40013010 MD VISION RESISTIVITY 01/19/06 1 1 iJ-166 40013010 ND VISION RESISTIVITY 01/19/06 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Nabors 3S well control & Doyon 15 fire incident n Subject: NaMors 3S tia-ell control ~~ Dayon 15 Ii re incidem From:JeffJ~nes ~jcff~jones~a atlmin.state.ak.us~% ~, Date: Wed, 2 ~ au~~ 2006 1~ X5:04 -0~~0 ~~-~r(`( ~ ~~~~~~~ To: James Re~~ ~ jin~_reg~(~i~admin.statc.ak.us% Hello Jim, Zc-0~ FYI , •~ Nabors 3S (John Freeborn) contacted me on 8/21/06 to report that they had used the annular and choke to circulate some gas out of well KRU ~. They said it was a minor amount of gas that they observed & assumed was residual gas in the control line armour sheathing while TOH with the ESP completion while perfoming the W/O. I told them to test BOPE as soon as they were out of the hole if conditions were stable. I~.~,t. ~ ,T- ~~`1 CPAI (Wendy Mahan) contacted me 8/22/06 to report a fire incident on Doyon 15. Insulation was ignited by welding sparks during repairs in the mud pits causing heat & smoke and was extinguished. My scheduled flight to Anchorage this morning has been cancelled due to weather flight minimums and the fact that the FAA has an equipment malfunction that requires visual flight rules for aircraft landing at Deadhorse. I am scheduled to depart on the evening flight and arrive Anchorage around 10:00 PM if the weather improves and AA can land a plane. Thanks, Jeff 1 of 1 8/23/2006 12:44 PM • • ~~ - osd Subject: RE: electronic data for the state From: Cary Taylor <Cary.Taylor@Halliburton.com> Date: Wed, 23 Aug 2006 15:24:59 -0800 To: "Greener, Mike R." <Mike.RGreener@conocophillips.com> CC: steve_davies@admin.state.ak.us Mike, Here is the data that you requested for 1J-109. Please let me know if there is anything else that I can get for you. Regards, Cary Taylor Technical Professional -Well Design Halliburton Energy Services 6900 Arctic Blvd Anchorage, AK 99518 PH:907--273-3520 Cel1:907-748-3920 Fax:907-273-3535 ~ ~ ~ ~ n~ / -g. ~~F This e-mail, including any attached files, may contain confidential and privileged information for the sole use of the intended recipient. Arty review, use, distribution, or disclosure by others is strictly prohibited. If you are not the intended recipient (or authorized to receive information for the intended recipient), please contact the sender by reply e-mail and delete all copies of this message. From: Greener, Mike R. [mailto:Mike.R.Greener@conocophillips.com] Sent: Tuesday, August 22, 2006 2:54 PM To: Cary Taylor Cc: steve_davies@admin.state.ak.us Subject: electronic data for the state I have submitted a sundry application to annular inject into the 1J-109. The state needs the following data before approval: Survey data MWD/LWD information Could you please email this information over to them. I realize that we have a 30 day window to get this information to them but we would like to get the injection permit moving along. Email it to Steve Davies (the cc address on this email) Thanks. P.S. Please let me know when the info has been sent. Thanks again. Mike Greener • ~-osa «Greener, Mike R..vcf» __ __ __ __ Content-Description: 1J-109 SURVEY.ZIP 1J-109 SURVEY.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 __ _ _ __ ___ __ __ __...__ Content-Description: 1J-109 PB1 SURVEY.ZIP 1J-109 PBl SURVEY.ZIP Content-Type: applicationlx-zip-compressed Content-Encoding: base64 __ __ Content-Description: 1J-109 PB1 ASCII.ZIP 1J-109 PBl ASCILZIP Content-Type: applicationlx-zip-compressed Content-Encoding: base64 __ 'Content-Description: 1J-109 ASCILZIP 1J-109 ASCII.ZIP Content-Type: applicationlx-zip-compressed Content-Encoding: base64 __ RE: FW: 1J-109 USIT- 9.625" Subject: RE: FW: IJ-I09 USIT- 9.6?5" Fram: "Greener, Mike R." <Mike.R.Greener(~conocophillips.com> llate: Tue, 0~ :~1u~; 2(11)(i 14:46:25 -000 To: "[~homas Maunder °~tonl maunder(«;admin.statc.ak.us = We are currently doing a caliper log of the 9-518" casing to look far wear. Don't expect any but it uTiil be nice to have a log. Then we will run the completion. ~s far as the cement volumes go, we usually use 25% excess on the intermediate and the bond log indicate that seems to be enough. ~ ~~~~~ -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, August 08, 2006 2:35 PM To: Greener, Mike R. Subject: Re: FW: iJ-109 USIT- 9.625" Hi Mike, Never hurts to have a bond log. I agree with your call on TOC. How did the jobs go? Not sure I have seen the completion reports yet. What sort of basis did you use for the cement calculation? Tom Greener, Mike R. wrote, On 8/8/2006 1:33 PM: Tom, here is the reshlts of the USIT :log we ran on. the 1:1-109. the l:1-109 is a producer but we ran the log anyway to get a feel. for how high. the cement came on the intermediate casing. I called it at about 7,350' A1.so, listed below are the hydracarban tops from our gealagst. Here are the oil shows from the logs for the 109 and the '933 wells in the Ugnu 1 J-109 U nu C 836 ' - 694' U nu 8850' - 919" Ugnu A 94 6" - 9534' -----Original Message----- From: Doyon 15 Company Man Sent: Tuesday, August 08, 2006 6:49 AM To: Greener, Mike R. Subject: 1J-109 USIT- 9.625" «1J-109 usit 8-7-06 Combined.PDS» 1 of 2 8/8/2006 3:11 PM fi ~9 ~1 5 ;~' ~ if '~ ~ ~ ~ ~ l ~ ~~ I r i i d LuiL~-7~ OII/ C011T5ER~ATI011I COAII~II55IO1~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 J~ ~~ FRANK H. MURKOWSKI, GOVERNOR ~' 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-109 ConocoPhillips Alaska, Inc. Permit No: 206-050 Surface Location: 2089' FSL, 2408' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1187' FSL, 4404' FEL, SEC. 6, TlON, R11E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to vvt~'iu3'aw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907)3607 (pager). K. N DATED this~day of April, 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips Alaska Post 0?ffice Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com March 22, 2006 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1J-109 Dear Commissioners: ~~~~~~~ MAR ~ ]. 2006 ~~ ~~~ f~~, ,. ~ ~t-.n t ~r „~,... ~',~"w_r~'G _~ _ _._~ ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a horizontal well in the West Sak ~~D" sand.' The main bore of the well will be designated 1J-109. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. The expected spud date of iJ-109 is May 12, 2006. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL W(~ 20 AAC 25.005 1a. Type of Work: Drill ^/ - Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil Q 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: 1J-109 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 16821" TVD: 3728' ' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2089' FSL, 2408' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: 39o7os ADL 28248 & ,`_~ West Sak Oil Pool Top of Productive Horizon: 1830' FSL, 4346' FEL, Sec. 31, T11 N, R11 E, UM ° 8. Land Use Permit: ALK 591 & 3818 13. Approximate Spud Date: 5/12/2006 Total Depth: 1187' FSL, 4404' FEL, Sec. 6, T10N, R11 E, UM ~ 9. Acres in Property: JSS~I (ZZ~ -~~..6D y.4. cG 14. Distance to Nearest Property: 4346' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558800 `~ y- 5945901 Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1J-03 , 4338' @ 6550' 16. Deviated wells: Kickoff depth: 262 ft. Maximum Hole Angle: 94° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1689 psig' Surface: 1276 psig ` 18. Casing Program S if ti Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 16" 13.375" 68# L-80 BTC 4344' 28' 28' 4373' 2297' 790 sx AS Lite, 220 sx DeepCRETE 12.25" 9.625" 40# L-80 BTCM 10894' 28' 28' 10894' ~ 3753' ~ 720 sx DeepCrete 6.75" 4.5" 11.6# L-80 BTC 6222' 10600' 3719' 16822' ~ 3728' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be com pleted for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume Mp r-„ ~ - F Conductor/Structural ~ > ~~~:~~ Surface Intermediate Production Liner ~: ~~ai. - -..__~ ~ oS'+1 Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee O BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~ ~`"'~~--._~.~` Phone ZL- S ~..~ 5C~ Date 5 / '3 l Sf~ C> -L:- ~ ' "-"'> P All Commission Use Only Permit to Drill Number: .Z~ ~ ~ f~ S ~ API Number: 50- ~Z.9' ~"J 3~ ~'D ~ Permit Approval Date: ~ ° a ~ 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 methane, rates, or gas contained in shales: Samples req'd: Yes ^ No ^~ ud log req'd: Yes ^ No Other: ~7Q~ QSt ~~ ~5~ G5~7~CJ~nC~ ~H2S measures: Yes ^ No [v~ ire al svy req'd: Yes ~~ No ^ APPROVED BY THE COMMISSION DATE: ~ ~D ,COMMISSIONER Form 10-401 Revised 12/2005 /'1 ~ ~ ~t„/( ~ ~ ~ ~ ~ Sun ,Dluplicated 7 'lv ~~o • Permit It -West Sak Well #1J-109 App/ication for Permit to Dri// Document cation for Permit to Drill, Well 1J-109 Revision No.0 Saved: 29-Mar-06 Ma~~mi:~ VMell Value Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (1) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information .......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information .................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ............................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information .................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ..............................................................................................4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (extended bentonite) .......................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 5 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ......................................................................................................5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 1J-109 PERMITIT.doc Page 1 of 7 Printed: 29-Mar-06 ORIGINAL • cation for Permit to Drill, Well 1 J-109 Revision No.0 Saved: 29-Mar-06 12. Evidence of Bonding ................................................................................................6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ......................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments ..............................................................................................................7 Attachment 1 Directional Plan ................................................................................................................ 7 Attachment 2 Drilling Hazards Summary ................................................................................................ 7 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 7 Attachment 4 Well Schematic ................................................................................................................ 7 1. Well Name Requirements of 20 AAC 25.005 (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25,D4()(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the we/l by the commission. The well for which this Application is submitted will be designated as 1J-109. 2. Location Summary Requirements of 20 AAC 25.OO5(c)(2) An application for a Permit to Dri/l must be accompanied by each of the fo/%wing items, except for an item a/ready on h7e with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the we// at the surface, at the top of each objective formation, and at total depth, referenced to governmental section tines (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 2 089' FSL 2 408' FEL Section 35 T11N R10E ASPZone 4 NAD 17 Coordinates RKB Elevation 108.0' AMSL Northings: 5,945,901 Eastings: 558,800 Pad Elevation 80.0' AMSL Location at Top of Productive Interval West Sak "D" Sand 1,830' FSL, 4,346' FEL, Section 31, T11N, R11E ASP Zone 4 NAD 27 Coordinates Measured De th RKB.' 10 893 Northings 5,945,712 Eastings: 567,152 Total I/erticalDe th RKB: 3 753 Total ~ertica/ De th SS.' 3 632 Location at Total De th 1 187' FSL 4 404' FEL Section 6 T10N RilE ASP Zone 4 NAD 27 Coordinates Measured De th RKB,' 16 821 Northings: 5,939,790 Eastings: 567,171 Total ~ertica/De th RKB,• 3 728 Total t/ertical De th SS.' 3 607 and 1J-109 PERMIT IT.doc Page 2 of 7 Printed: 29-Mar-O6 JRIGINAL • (D) other information required by 20 AAC 25, 050(6); cation for Permit to Drill, Well 1 J-109 Revision No.O Saved: 29-Mar-06 Requirements of 20 AAC 25.050(6) If a well is to be intentional/y deviated, the app/ication for a Permit to Dri/I (Form 10-401) must (1) include a plat, drawn to a suitab/e scale, showing the path of the proposed we//bore, including all adjacent welJbores within 200 feet afany portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for a!l wells within 200 feet of the proposed we/!bore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (e) state that the applicant is the only affected owner The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fo!/owing items, except for an item already on fi/e with the commission and identified m the application: (3) a diagram and description of the blowout prevention equipment (HOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well iJ-109. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 9-5/8" rams in the lowermost cavity. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). Immediately prior to running the intermediate string of 9-5/8" casing, a test plug will be set below the lowermost rams, and those rams will be closed and tested to 3,000 psi on a 9-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/icatron for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW ®` (equivalent mud weight). These pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,276 psi, calculated thusly: MPSP =(3,753 ft TVD)(0.45 - 0.11 psi/ft) =1,276 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (CJ data concerning potential causes ofhote problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differentia! sticking; Please see Attachment 2: 1J-109 Drilling Hazards Summary. 1J-109 PERMIT IT.doc Page 3 of 7 Printed: 29-Mar-O6 ORIGINAL cation for Permit to Drill, Well 1J-109 Revision No.0 Saved: 29-Mar-06 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Oril! must be accompanied by each of the following items, except for an item already on fi/e with the rnmmission and identified in the app/ication: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC25.030(1) 1J-109 will be completed with 9-5/8" intermediate casing landed at the top of the West Sak D sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application For a Permit to Drill must be accompanied by each of the fol/owing items, except for an item a/ready on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted /finer, pre- perforated !finer, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Si-e .Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pr ram 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCREI'E Cemented to Surface with 13-3/8 16 68 L-80 BTC 4,344 28 / 28 4,373 /2,297 790 sx ASLite Lead, 220 sx DeepCRETE Tail Cement Top planned @ 9-5/8 12-1/4 40 L-80 BTCM 10894 28 / 28 10 894 / 3,753 TVD. 6'85 ' Ce ented w/ 720 sx Dee Rf_ rE 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 6,222 10,600 / 3,719 16,822 / 3,728 slotted- no cement slotted Lateral (1J-109) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dri/t must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1J-109. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication far a Permit to Drill must be accompanied try each of the fo/lowing items, except for an item already an file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-109 PERMIT IT.doc Page 4 of 7 Printed: 29-Mar-06 ORIGINAL • Surface Hole Mud Program (extended bentonite) cation for Permit to Drill, Well 1J-109 Revision No.0 Saved: 29-Mar-06 Spud to Base of Permafrost Base of Permafrost to 13 3/B" Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.9 9.2 9.5 9.6 Funnel Viscosity 150 250 200 300 seconds Yield Point cP 50-70 50-70 30-50 30-50 Plastic Viscostiy 20-45 20-45 15-20 15-20 Ib/100 s pH 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 API Filtrate cc / 30 min NC-8.0 NC-8.0 5.0-7.0 5.0-7.0 *9.6 ppg if hydrates are encountered '` Intermediate Hole Mud Program (LSND) 13-3/B"Casing Shoe to 9-S/B" Casin Point Initial Value Density (ppg) 9.0-9.1 Funnel Viscosity 45-60 seconds) Plastic Viscostiy 12-18 (Ib/100 s Yield Point 26-35 (cP API Filtrate 4-6 cc / 30 min Chlorides (mg/I) <500 pH 9.0-9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) D sand lateral Value Densit 8.6 Plastic Viscostiy 15-25 Ib/100 s fl Yield Point 18-28 (cP) HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water 70 / 30 Ratio Electrical >600 Stabilit J Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to ©ril! must be accompanied by each of the fol/owing items, except for an item already on frle with the commission and identified in the application: (9) for an exploratory or stratigraphic test we/I, a tabu/ation setting out the depths ofpredicted abnorma/!y geo pressured strata as required by 2l1 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. " 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identified in the application: (1 D) for an exp/oratory or stratigraphic test we!/, a seismic refraction or reflection analysis as required by 20 AAC25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1J-109 PERMIT IT.doc Page 5 of 7 Printed: 29-Mar-O6 • cation for Permit to Drill, Well 1 J-109 Revision No.O Saved: 29-Mar-06 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Permit to Dri/! must be accompanied by each of the fot/owing items, except far an item already on file with the commission and identified in the application: (11) for a well drilled from an ofI`shore platform, mobile bottom-founded structure, hack-up rig, or floating drilling vessel, an analysis ofseabed conditions as required by ZO AAC25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/ccation for a Permit to DriJ1 must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of20 AAC 25.015 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Dri// must be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the app/ication: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. r 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Install 21-1/4" Annular with 16"diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 4,373' MD / 2,297' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 12-1/4" bit and 6-1/4"drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 9-5/8" casing point at 10,894 MD / 3,753' TVD, the prognosed top of the D sand. 9. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 7,400' MD / 3,007' TVD if Ugnu C formation is oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 13-3/8" x 9-5/8"annulus with water, followed by diesel. 12. PU 5" x 4" tapered string with a 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4" lateral modeled to be less than 12.0 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 16,822' MD / 3,728' TVD as per directional plan. 7J-109 PERMIT IT.doc Page 6 of 7 Printed: 29-Mar-O6 ORIGINAL • cation for Permit to Drill, Well 1 J-109 Revision No.O Saved: 29-Mar-O6 15. POOH, back reaming out of lateral to 9-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 16. PU and run 4-1/2" slotted liner. 17. Land liner, set liner hanger @ +/- 10,600' MD / 3,719' ND. POOH. 18. POOH, laying down drill pipe as required. 19. PU completion as required and RIH to depth. Land tubing. Set BPV. 20. Nipple down BOPE, nipple up tree and test. Pull BPV. 21. Freeze protect well with diesel. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to ©ri!l must be accompanied by each of the fo/%wing items, except for an item already on t</e with the commission and identified in the application: (14) a genera/ description ofhow the operatorplans to dispose ofdri!/ing mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the wet%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic 1J-109 PERMIT IT.doc Page 7 of 7 Printed: 29-Mar-06 ORIGINAL • Cona-coPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-109 -Slot 1J-109 Plan 1J-109 Plan: 1J-109 (wp05) Proposal Report 15 March, 2006 • ~~e.~~..r~~~~rc ear t'~ri~~~~ +~r~r~~+ Project: Kuparuk River Uni ConocoPhilli 5 Site: Kuparuk 1J Pad sHt.@2069ftFSL82408ftFEL-Sec 35-T11N-R10E r Well: Plan 1J-109 Alaska Wellbore: Plan 1J-109 ~~ ~KDP @ 262ft MD, 262ft ND -Build @ 2.5°nooet Plan: 1 J-109 (wp05) ~ ~ Continue Build @ 4°nooft , 703ft MD, 700ft ND , ~' ~ rSail @ 49° Inc : 1641ft MD, 1500ft Nq ,~~ ~ / Continue Build @ 5.5°/101Nt , 1741k MD, 1566ft NI~ i~ -425 / Sail @ 76° Inc : 2248ft MD, 1798ft ND 0 o° 850 1275 ~~oo ~.. 125 550 297 4250 4675 GASINCi Ut I AILJ No TVD MD Name Size 1 2297.00 4373.43 13 3/8" 13-3/8 2 3753.00 10893.82 9 5/8" 9-518 3 3728.00 16821.84 41/2" 4-1/2 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 1524.00 1677.46 Base of Permafros 2 1672.00 1919.10 T3 3 1995.00 3087.24 K15 4 2297.00 4373.43 T3 + 550 5 2996.00 7350.39 Ugnu C 6 3314 00 8693 01 Ugnu B 13 3I8" Cag @ 4373ft MD, zzs7ft ND 7 3397.00 9031.45 Ugnu A ta, 8 3563.00 9741.24 K13 9 3752.00 10884.25 West SAk D -;Turn @ 3°/100ft, 7746ft MD, 3069k ND 20° ' NALLIBLIRTCiN 30° Sperry drilling Servlses 49° Sail @ 63°Azi : 7910ft MD, 3127ft ND -------aiBaseofPermafrost-----~- ~" ----~~T3; ---------- _-- - 5p° f0° -' '?urn @ 3°/100ft, 7960ft MD, 3139ft N ----K15i-- -----'---------- -------- -----------"----------------------------------------------- -~ , - - _ , ' ~ Sail @ 88°Azi : 6122ft MD, 3177ft ND - - - ~3 + 550 - yJ~ - - - - - - - - - - - - - - - - - - - - - - ~-'= - -'- - - - _-_ _ - =~- - - - - - - - - - - - - - - - - - - - - -- -- - -- - -- - - - - - ' , ' ' ~ - , - - - Turn @ 3°I100ft,6172ft MD,3189ft N _ _ , ' ~ ~ _ _ - ' " - _ _ - - - - Sail @ 90°Azi : 6237ft MD, 3204ft TVD UgnuC ,_, '~,__,----' ---------- --- ------------ TD@16822ftMD,3728ftND-4112 - _ Tum @ 3.50°/100ft, 8287ft MD, 3216ft N Sail @ 126°Azi : 9276ft MD, 3456ft TVD UgnuB =-- ----------------- _----------------__ 1J-109 T3 (wp05Jr -- - - -- - - - - - - - - - - - - - - - - - - - - - - - - - -- - -- - -- - - - - - - " - 1J-109 T1 Dtop (wp05)) 1J-109 T2 (wpOSj - _. , 'Ugnu A- - -' - -- - - - ~- c .. - ._ __ ~ . w.~ m -fir - . . - - - - - - - - - - --.d / - - - - - - - - - - - - - - - - - - - - - - - -_ - - - - - - - - - - - - - - ~ ~ N `~ ~ ; ~ `~ ° ° 1J-109 (wp05)1 '~, ` iK13 ~ ~ ' ~ ~ ~ ~ i ~ i ~ ' i ~ West SAk D ~ ~ ~ , ~ ' ~ ` Continue GeoSteer in DSand 11251ft MD, 3761ft ND ~~ Sail @ 84°Inc 8.180°Azi : 10794ft MD, 3743ft NQ) 'Build @ 3°I100ft to 94° linc - 10914ft MD, 3755ft ND BuildlTurn @ 4°I100ft, 9438ft MD, 3494ft N 9 5/8" Csg @ 10894ft MD, 3753ft N i 1J-109 T4 (wp05. I ~ i ~ 1J-109 TS (wp05 '1J-109 T6 Toe (wp051 5100 -1700 -1275 -850 -425 0 425 850 1275 1700 2125 2550 2975 3400 3825 4250 4675 5100 5525 5950 6375 Project: Kuparuk Rlver Unlt f 13 3/8"Csg @ 4373ft MD, 2297ft TV Site: Kuparuk 1J Pad Well: Plan 1 J-109 Wellbore: Plan 1J-109 Plan: 1J-109 (wp05) 1250 _SHL@2089ftFSL82406ftFEL-Sec 35-T11N-R10E ~\ ~~ 625 Turn @ 3°/100ft, 7960ft MD, 3139ft TVD Turn L 3"/100tt, 6172tt MD, 31698 TVq 'Sail @ 88°Azi : 6122ft MD, 3177ft N Sail @ 83°Azi : 7910ft MD, 3127ft TVq ` Sail @ 90°Azi : 8237ft MD, 3204ft TVD __ , ~~ , _ ,~ ,__- Turn @ 3°NOOft, 7748ft MD, 3089ft TV ,~ , , - ' ~ Turn @ 3.50°/100ft, 8287ft MD, 3216ft TV _-__ ~ a,_ ______ - - - _ - - - - - Sail @ 126°Azi : 9276ft MD, 3456ft TVD _ ~ ---- o ^ _ _ _ ~~-109 l`Np_ U51, - - - - ~-~ _ Begin BuildlTurn @ 4°/100ft,9436ft MD,3494ft TV rn 1yp 0 ~ _ ` ` - _ ~ a ~ ~ ~ ~ ~ , (Sail @ 84°Inc 8 180°Azi : 10794ft MD, 3743ft TV - - - - - ~ ` `~ -_ / ~ ~ ' ~ Sail @ 76°Inc : 2248ft MD, 1798ft TVD _ - - - ~ , -625 ~ , - _ _ _ , , ~ ~ ' 9 518" Csg @ 10694ft MD, 3753ft Nb ` Continue Build @ 5.5°I100ft , 1741ft MD, 1566ft TV 1250 ' \ Sail @ 49° Inc : 1641ft MD, 1500ft N[~ Build @ 3°/100ft to 94° linc - 10914ft MD, 3755ft TVD Continue Build @ 4°/100ft , 703ft MD, 700ft TV w+.~J C O lf7 .~~~ N ~~ L 0 Z z~ - r r in 3750 KOP @ 262ft MD, 262ft TVD -Build @ 2.5°/100~t •4375 CASING DETAILS No TAD' (Vl'0 Name Size.. 1 2297.00 4373.43 13 3/8" 13-3/8; 5000 2 3753.0010893.82 9 5/8" 9-5/8 3 3728.0016821.84 4 1 /2" 4-1 /2 T M "Azimuths to True North Magnetic North: 24.54` Magnetic Field Strength: 57578.1 nT Dip Angle: 80.72` Date: 11 / 18/2004 Model: BGGM2004 ~Oi'iOCOP'~1~~~t~35 APaska Sperry Drilling Services Continue GeoSteer in D-Sand 11251ft MD, 3761ft Np 175° 1J-109 T1 Dtop (wp05) I i I 11J-109 T2 (wp05) 180° I1J-109 DD Polygon (wp05)~---- _ ______ _ ~ _ _ _ _ DD Polygon Describes a corridor 100' wide with a 50'+/-allowance E/W from the i proposed wellbore. 160° 180° _ i 1J-1o~ ra (wpOS~ __-_~ ' 160° 1J-1091 TD @ 16822ft MD, 3728ft TVD- 4 112' ~I~ ' ~ ~ LJ-109 T6 Toe (wp05 - - ~ 180° -~_ 1l, -1875 -1250 -625 0 625 1250 1875 2500 3125 3750 4375 5000 5625 6250 6875 7500 8125 8750 9375 10000 r--' ~ Halliburton Energy Services ~ WAt~l.~BURTt~N ~'~~'~~~'~~~~~~"~ Planning Report -Geographic ----~- -- - ----~--- Alasi<.~ terry Drtllfng ~t3lNi~~S Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-1C19 Slot 1J-109 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Plan RKB @ 121.OOft (Doyon 15 (40+81 )) Project: Kuparuk River Unit MD Reference: Plan RKB @ 1Z1.OOft (Doyon 15 (40+81 )) Site: Kuparuk 1J Pad North Reference: True We11: Plan 1J-109 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-109 Design: 1J-109 (wp05) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using VHOfl Reference Point Map Zone: Alaska Zone 04 Using g~ridetic scale factor Well Plan 1J-109 - Slot 1J-109 Well Position +N!-S 0.00 ft Northing: 5,945,901.84 ft Latitude: 70° 15' 46.080" N +E!-W 0.00 ft Easting: 558,800.73 ft > Longitude: 149° 31' 28.697" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore Plan 1J-109 Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2004 11/1812004 24.5438 80.7240 57,578 - - -- _-_ - Design Audit Notes: Version: Vertical Section: 1J-109 (wp05) Phase: PLAN Tie On Depth: 40.00 Depth From (TVD) +N/-S +E!-W Direction (ft) (~) (~) (°) 40.00 0.00 0.00 180.00 3/1512006 2:40:06PM Page,2 f ~0 COMPASS 2003.11 Build 50 ~-' ~ Halliburton Energy Services • HALLtBUFITOIV ~~'~ ~~~~~'~ Planning Report -Geographic - ~ __ ~_~ A;aska aperry Dnllling Serrvi~es Database: EDM 2003.11 Single User Db Local Co-ordina#e Reference: Well Plan 1J-10y -Slot 1J-109 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Plan RKB @ 121.t}Oft (Doyon 15 (40+81 )) Project: Kuparuk River Unit MD Reference: Plan RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-109 Survey Calculation Method: Minimum Cur~atui~ Wellbore: Plan 1J-109 Design: 1J-109 (wp05) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (~) (~) (ft) (f}) (ft) (°/1OOff) (°/1OOft) (°/1OtNt) (off 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 0.0000 262.00 0.00 0.00 262.00 0.00 0.00 0.00 0.00 0.00 0.0000 702.71 11.02 78.00 700.00 8.78 41.32 2.50 2.50 0.00 78.0000 1,641.20 48.56 78.00 1,500.00 103.99 489.25 4.00 4.00 0.00 0.0000 1,741.20 48.56 78.00 1,566.19 119.58 562.57 0.00 0.00 0.00 0.0000 2,247.79 76.42 78.00 1,797.90 212.08 997.74 5.50 5.50 0.00 0.0000 7,747.79 76.42 78.00 3,089.31 1,323.62 6,227.15 0.00 0.00 0.00 0.0000 7,909.80 76.42 83.00 3,127.37 1,349.60 6,382.41 3.00 0.00 3.09 90.5874 7,959.80 76.42 83.00 3,139.11 1,355.53 6,430.65 0.00 0.00 0.00 0.0000 8,121.80 76.42 88.00 3,177.17 1,367.88 6,587.59 3.00 0.00 3.09 90.5874 8,171.80 76.42 88.00 3,188.91 1,369.57 6,636.16 0.00 0.00 0.00 0.0000 8,236.61 76.42 90.00 3,204.13 1,370.67 6,699.14 3.00 0.00 3.09 90.2348 8,286.61 76.42 90.00 3,215.87 1,370.67 6,747.74 0.00 0.00 0.00 0.0000 9,276.38 76.42 125.67 3,455.65 1,081.28 7,647.15 3.50 0.00 3.60 94.3252 9,438.37 76.42 125.67 3,493.69 989.46 7,775.06 0.00 0.00 0.00 0.0000 10,793.82 84.00 180.26 3,742.55 -155.43 8,350.79 4.00 0.56 4.03 87.6169 10, 893.82 84.00 180.26 3, 753.00 -254.88 8, 350.33 0.00 0.00 0.00 0.0000 10,913.82 84.00 180.26 3,755.09 -274.77 8,350.24 0.00 0.00 0.00 0.0000 11,250.70 94.11 180.27 3,760.65 -611.17 8,348.68 3.00 3.00 0.00 0.0697 11,538.38 94.11 180.27 3,740.05 -898.10 8,347.32 0.00 0.00 0.00 0.0000 11,606.62 92.06 180.33 3,736.38 -966.24 8,346.96 3.00 -3.00 0.08 178.3845 12,006.62 92.06 180.33 3,722.00 -1,365.98 8,344.66 0.00 0.00 0.00 0.0000 12,076.05 90.67 180.26 3,720.34 -1,435.38 8,344.30 2.00 -2.00 -0.11 -176.9043 13,806.94 90.67 180.26 3,700.00 -3,166.14 8,336.60 0.00 0.00 0.00 0.0000 14,028.64 85.13 180.21 3,708.11 -3,387.60 8,335.70 2.50 -2.50 -0.02 -179.5461 14,700.05 85.13 180.21 3,765.10 -4,056.59 8,333.24 0.00 0.00 0.00 0.0000 14,910.01 90.38 180.26 3,773.32 -4,266.31 8,332.37 2.50 2.50 0.02 0.5355 15,410.01 90.38 180.26 3,770.00 -4,766.29 8,330.10 0.00 0.00 0.00 0.0000 15,453.17 91.24 180.31 3,769.39 -4,809.45 8,329.89 2.00 2.00 0.10 3.0041 16,209.27 91.24 180.31 3,753.00 -5,565.36 8,325.86 0.00 0.00 0.00 0.0000 16,266.88 92.39 180.26 3,751.17 -5,622.93 8,325.58 2.00 2.00 -0.08 -2.3496 16,821.85 92.39 180.26 3,728.00 -6,177.42 8,323.08 0.00 0.00 0.00 0.0000 3/15/2006 2:40:06PM ~ ~~ A L COMPASS 2003.11 Build 50 r-' ,~ Hafliburton Energy Services ~ i'11ALt:~BUpTON ~~~'~~~~~~' Pl hi i R t G -------- -- _ - --.- eograp c ann ng epor - r'~i~isk,~ ~~~rry Drilling S~rrric~s Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-109 -Slot 1J-109 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Plan RKB @ 121.OOft {Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 121.[30ft (Doyon 15 (40+81)) Site: Kupanak 1J Pad North Reference: True Well: Plan 1J-109 Survey Calculation Method: Minimum Curv~~ture Wellbore: Plan 1J-109 Design: 1J-109 (wp05) Planned Survey 1J-109 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section (ft? ~°) t°) (ft) eft) eft) (ft} tft) eft) (°f100ft) {ft) 40.00 0.00 0.00 40.00 -81.00 0.00 0.00 5,945,901.64 558,800.73 0.00 0.00 SHL @ 2089ft FSL S 2408ft FEL -Sec 35 - T11 N - R10E 100.00 0.00 0.00 100.00 -21.00 0.00 0.00 5,945,901.64 558,800.73 0.00 0.00 200.00 0.00 0.00 200.00 79.00 0.00 0.00 5,945,901.64 558,800.73 0.00 0.00 262.00 0.00 0.00 262.00 141.00 0.00 0.00 5,945,901.64 558,800.73 0.00 0.00 KOP @ 2S2ft MD, 2S2ft TVD -Build @ 2.5°l100fk 300.00 0.95 78.00 300.00 179.00 0.07 0.31 5,945,901.71 5513,801.04 2.50 -0.07 400.00 3.45 78.00 399.92 278.92 0.86 4.06 5,945,902.54 556,804.79 2.50 -0.86 500.00 5.95 78.00 499.57 378.57 2.57 12.08 5,945,904.30 556,812.79 2.50 -2.57 600.00 8.45 78.00 598.78 477.78 5.17 24.34 5,945,907.01 558,825.02 2.50 -5.17 700.00 10.95 78.00 697.34 576.34 8.68 40.81 5,945,910.64 558,841.47 2.50 -8.68 702.71 11.02 78.00 700.00 579.00 8.78 41.32 5,945,910.75 558,841.98 2.50 -8.78 Continue Build @ 4°/100ft , 703ft MD, 700ft TVD 800.00 14.91 78.00 794.79 673.79 13.32 62.66 5,945,915.45 556,863.28 4.00 -13.32 900.00 18.91 78.00 890.45 769.45 19.37 91.11 5,945,921.72 558,891.68 4.00 -19.37 1,000.00 22.91 78.00 983.84 862.84 26.78 126.01 5,945,929.41 556,926.52 4.00 -26.78 1,100.00 26.91 78.00 1,074.52 953.52 35.54 167.20 5,945,938.48 556,967.63 4.00 -35.54 1,200.00 30.91 78.00 1,162.04 1,041.04 45.59 214.48 5,945,948.90 559,014.83 4.00 -45.59 1,300.00 34.91 78.00 1,245.98 1,124.98 56.88 267.61 5,945,960.61 559,067.86 4.00 -56.88 1,400.00 38.91 78.00 1, 325.92 1,204.92 69.37 326.34 5,945, 973.55 559,126.49 4.00 -69.37 1,500.00 42.91 78.00 1,401.48 1,280.48 82.98 390.38 5,945,987.66 559,190.42 4.00 -82.98 1,600.00 46.91 78.00 1,472.29 1,351.29 97.65 459.42 5,946,002.87 559,259.34 4.00 -97.65 1,641.20 48.56 78.00 1,500.00 1,379.00 103.99 489.25 5,946,009.44 559,289.11 4.00 -103.99 Sail @ 49° Inc : 1641ft MD, 1500ft TVD 1,677.46 48.56 78.00 1,524.00 1,403.00 109.64 515.83 5,946,015.30 559,315.65 0.00 -109.64 Base of Pe rmafrost 1,700.00 48.56 78.00 1,538.92 1,417.92 113.16 532.36 5,946,018.94 559,332.14 0.00 -113.16 1,741.20 48.56 78.00 1,566.19 1,445.19 119.58 562.57 5,946,025.60 559,362.30 0.00 -119.58 Continue Build @ 5.5°f100ft , 1741 ft MD, 1566ft TVD 1,800.00 51.79 78.00 1,603.84 1,482.84 128.97 606.74 5,946,035.33 559,406.38 5.50 -128.97 1,900.00 57.29 78.00 1,661.83 1,540.83 145.89 686.38 5,946,052.88 559,485.88 5.50 -145.89 1,919.10 58.34 78.00 1,672.00 1,551.00 149.25 702.19 5,946,056.36 559,501.66 5.50 -149.25 T3 2,000.00 62.79 78.00 1,711.75 1,590.75 163.90 771.09 5,946,071.54 559,570.45 5.50 -163.90 2,100.00 68.29 78.00 1,753.14 1,632.14 182.82 860.09 5,946,091.16 559,659.29 5.50 -182.82 2,200.00 73.79 78.00 1,785.61 1,664.61 202.47 952.57 5,946,111.53 559,751.60 5.50 -202.47 2,247.79 76.42 78.00 1,797.90 1,676.90 212.08 997.74 5,946,121.48 559,796.69 5.50 -212.08 Sail @ 76° Inc : 2248ft MD, 1798ft TVD 2,300.00 76.42 78.00 1,810.15 1,689.15 222.63 1,047.38 5,946,132.42 559,846.24 0.00 -222.63 2,400.00 76.42 78.00 1,833.63 1,712.63 242.84 1,142.46 5,946,153.37 559,941.15 0.00 -242.84 2,500.00 76.42 78.00 1,857.11 1,736.11 263.05 1,237.54 5,946,174.32 560,036.06 0.00 -263.05 2,600.00 76.42 78.00 1,880.59 1,759.59 283.26 1,332.62 5,946,195.27 560,130.97 0.00 -283.26 2,700.00 76.42 78.00 1,904.07 1,783.07 303.47 1,427.70 5,946,216.22 560,225.88 0.00 -303.47 2,800.00 76.42 78.00 1,927.55 1,806.55 323.68 1,522.78 5,946,237.17 560,320.79 0.00 -323.68 2,900.00 76.42 78.00 1,951.04 1,830.04 343.89 1,617.86 5,946,258.12 560,415.70 0.00 -343.89 3,000.00 76.42 78.00 1,974.52 1,853.52 364.10 1,712.94 5,946,279.07 560,510.61 0.00 -364.10 3/15/2006 2.40:O6PM Page 4 of 10 COMPASS 2003.11 Build 50 IGINAL r•' • Halliburton Energy Services ~ ~-IALLIBURTON '~UI"tt~!I~~'3~I~~fS Plannin Re ort -Geo ra hic - __ _-- - __ ~___ g g p p Al~,ta Sperry Drlllirtg Serei~ces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-109 -Slot 1J-109 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Plan RKB @ 1~1.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 121 OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-109 Survey Calculation Method: Minimum Cuni:~ture Wellbore: Plan 1J-109 Design: 1J-109 (wp05) Planned Survey 1J-109 (wp05) Map Wlap MD Inclination Azimuth TVD SSTVD +N/-S +E(-W Northing Fasting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 3,087.24 76.42 78.00 1,995.00 1,874.00 381.73 1,795.89 5,946,297.35 580,593.41 0.00 -381.73 K15 3,100.00 76.42 78.00 1,998.00 1,877.00 384.31 1,808.02 5,946,300.02 560,605.52 0.00 -384.31 3,200.00 76.42 78.00 2,021.48 1,900.48 404.52 1,903.10 5,946,320.97 580,700.43 0.00 -404.52 3,300.00 76.42 78.00 2,044.96 1,923.96 424.73 1,998.18 5,946,341.92 56Q,795.34 0.00 -424.73 3,400.00 76.42 78.00 2,068.44 1,947.44 444.94 2,093.26 5,946,362.87 580,890.25 0.00 -444.94 3,500.00 76.42 78.00 2,091.92 1,970.92 465.15 2,188.34 5,946,383.82 560,985.16 0.00 -465.15 3,600.00 76.42 78.00 2,115.40 1,994.40 485.36 2,283.42 5,946,404.77 561,080.07 0.00 -485.36 3,700.00 76.42 78.00 2,138.88 2,017.88 505.57 2,378.50 5,946,425.72 569,174.99 0.00 -505.57 3,800.00 76.42 78.00 2,162.36 2,041.36 525.78 2,473.58 5,946,446.67 561,269.90 0.00 -525.78 3,900.00 76.42 78.00 2,185.84 2,064.84 545.99 2,568.66 5,946,467.62 56'1,364.81 0.00 -545.99 4,000.00 76.42 78.00 2,209.32 2,088.32 566.20 2,663.74 5,946,488.57 581,459.72 0.00 -566.20 4,100.00 76.42 78.00 2,232.80 2,111.80 586.41 2,758.82 5,946,509.52 561,554.63 0.00 -586.41 4,200.00 76.42 78.00 2,256.28 2,135.28 606.62 2,853.90 5,946,530.47 581,649.54 0.00 -606.62 4,300.00 76.42 78.00 2,279.76 2,158.76 626.83 2,948.98 5,946,551.42 56'1,744.45 0.00 -626.83 4,373.43 76.42 78.00 2,297.00 2,176.00 641.67 3,018.80 5,946,566.80 581,814.14 0.00 -641.67 13 3/8" Csg @ 4373ft MD, 2297ft TVD - 2731ft FSL & 4668ft FEL -Sec 36 - T11 N - R10E - T3 + 550 -133/8" 4,400.00 76.42 78.00 2,303.24 2,182.24 647.04 3,044.06 5,946,572.37 581,839.36 0.00 -647.04 4,500.00 76.42 78.00 2,326.72 2,205.72 667.25 3,139.14 5,946,593.32 561,934.27 0.00 -667.25 4,600.00 76.42 78.00 2,350.20 2,229.20 687.46 3,234.22 5,946,614.27 562,029.18 0.00 -687.46 4,700.00 76.42 78.00 2,373.68 2,252.68 707.67 3,329.30 5,946,635.22 582,124.09 0.00 -707.67 4,800.00 76.42 78.00 2,397.16 2,276.16 727.88 3,424.38 5,946,656.17 582,219.00 0.00 -727.88 4,900.00 76.42 78.00 2,420.64 2,299.64 748.09 3,519.46 5,946,677.12 582,313.91 0.00 -748.09 5,000.00 76.42 78.00 2,444.12 2,323.12 768.29 3,614.54 5,946,698.07 582,408.82 0.00 -768.29 5,100.00 76.42 78.00 2,467.60 2,346.60 788.50 3,709.62 5,946,719.02 582,503.73 0.00 -788.50 5,200.00 76.42 78.00 2,491.08 2,370.08 808.71 3,804.70 5,946,739.97 582,598.64 0.00 -808.71 5,300.00 76.42 78.00 2,514.56 2,393.56 828.92 3,899.78 5,946,760.92 562,693.55 0.00 -828.92 5,400.00 76.42 78.00 2,538.04 2,417.04 849.13 3,994.86 5,946,781.87 562,788.46 0.00 -849.13 5,500.00 76.42 78.00 2,561.52 2,440.52 869.34 4,089.94 5,946,802.81 582,883.37 0.00 -869.34 5,600.00 76.42 78.00 2,585.00 2,464.00 889.55 4,185.02 5,946,823.76 562,978.28 0.00 -889.55 5,700.00 76.42 78.00 2,608.48 2,487.48 909.76 4,280.10 5,946,844.71 588,073.19 0.00 -909.76 5,800.00 76.42 78.00 2,631.96 2,510.96 929.97 4,375.18 5,946,865.66 563,168.10 0.00 -929.97 5,900.00 76.42 78.00 2,655.44 2,534.44 950.18 4,470.27 5,946,886.61 563,263.01 0.00 -950.18 6,000.00 76.42 78.00 2,678.92 2,557.92 970.39 4,565.35 5,946,907.56 563,357.92 0.00 -970.39 6,100.00 76.42 78.00 2,702.40 2,581.40 990.60 4,660.43 5,946,928.51 563,452.83 0.00 -990.60 6,200.00 76.42 78.00 2,725.88 2,604.88 1,010.81 4,755.51 5,946,949.46 583,547.74 0.00 -1,010.81 6,300.00 76.42 78.00 2,749.36 2,628.36 1,031.02 4,850.59 5,946,970.41 583,642.65 0.00 -1,031.02 6,400.00 76.42 78.00 2,772.85 2,651.85 1,051.23 4,945.67 5,946,991.36 563,737.56 0.00 -1,051.23 6,500.00 76.42 78.00 2,796.33 2,675.33 1,071.44 5,040.75 5,947,012.31 563,832.47 0.00 -1,071.44 6,600.00 76.42 78.00 2,819.81 2,698.81 1,091.65 5,135.83 5,947,033.26 563,927.38 0.00 -1,091.65 6,700.00 76.42 78.00 2,843.29 2,722.29 1,111.86 5,230.91 5,947,054.21 5b=1,022.29 0.00 -1,111.86 6,800.00 76.42 78.00 2,866.77 2,745.77 1,132.07 5,325.99 5,947,075.16 SFr~i,117.20 0.00 -1,132.07 6,900.00 76.42 78.00 2,890.25 2,769.25 1,152.28 5,421.07 5,947,096.11 564,212.12 0.00 -1,152.28 7,000.00 76.42 78.00 2,913.73 2,792.73 1,172.49 5,516.15 5,947,117.06 5Fi4,307.03 0.00 -1,172.49 7,100.00 76.42 78.00 2,937.21 2,816.21 1,192.70 5,611.23 5,947,138.01 584,401.94 0.00 -1,192.70 7,200.00 76.42 78.00 2,960.69 2,839.69 1,212.91 5,706.31 5,947,158.96 564,496.85 0.00 -1,212.91 7,300.00 76.42 78.00 2,984.17 2,863.17 1,233.12 5,801.39 5,947,179.91 564',591.76 0.00 -1,233.12 7,350.39 76.42 78.00 2,996.00 2,875.00 1,243.31 5,849.30 5,947,190.47 564,639.58 0.00 -1,243.31 Ugnu C 31i5l2006 2:40:06PM Page 5 of 10 COMPASS 2003.11 Build 50 ORIGINAL ~-' • Halliburton Energy Services ~~~'~'~~~~~~~' Planning Report -Geographic r~it~SlC ~ Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-109 Wellbore: Plan 1J-109 Design: 1J-109 (wp05) HALLI~U~ITON Sperry Drilling Services Local Co-ordinate Reference: Well Plan 1J-1 f)9 -Slot 1J-109 TVD Reference: Plan RKB @ 121.OOft (Doyon 15 (40+g1)) MD Reference: Plan RKB @ 1?1.OOft (Doyon 15 (40+81)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1J-109 (wp05) MD Inclination Azimuth TVD SSTVD +N/-S Ift) (°) (°) (ft) (ft) (ft) 7,400.00 76.42 78.00 3,007.65 2,886.65 1,253.33 7,500.00 76.42 78.00 3,031.13 2,910.13 1,273.54 7,600.00 76.42 78.00 3,054.61 2,933.61 1,293.75 7,700.00 76.42 78.00 3,078.09 2,957.09 1,313.96 7,747.79 76.42 78.00 3,089.31 2,968.31 1,323.62 Turn @ 3°/100ft, 774$ft MD, 30$98 TVD 7,800.00 76.41 79.61 3,101.57 2,980.57 1,333.47 7,900.00 76.42 82.70 3,125.07 3,004.07 1,348.42 7,909.80 76.42 83.00 3,127.37 3,006.37 1,349.60 Sail @ 83°Azi : 7910ft MD, 3127ft TVD 7,959.80 76.42 83.00 3,139.11 3,018.11 1,355.53 Turn @ 3°/100ft, 7960ft MD, 3139ft TVD 8,000.00 76.41 84.24 3,148.56 3,027.56 1,359.87 8,100.00 76.41 87.33 3,172.05 3, 051.05 1, 367.01 8,121.80 76.42 88.00 3,177.17 3, 056.17 1, 367.88 Sail @ 8$°Azi : 8122ft MD, 3177ft TVD 8,171.80 76.42 88.00 3,188.91 3,067.91 1,369.57 Turn @ 3°1 100ft, 8172ft MD, 3189ft TVD 8,200.00 76.42 88.87 3,195.54 3,074.54 1,370.32 8,236.61 76.42 90.00 3,204.13 3,083.13 1,370.67 Sail @ 90°Azi : 8237ft MD, 3204ft TVD 8,286.61 76.42 90.00 3,215.87 3,094.87 1,370.67 Turn @ 3.50°/100Ft, 8287ft MD, 3216ft TVD 8,300.00 76.39 90.48 3,219.02 3,098.02 1,370.62 8,400.00 76.15 94.07 3, 242.76 3,121, 76 1, 366.76 8,500.00 75.98 97.68 3,266.85 3,145.85 1,356.82 8,600.00 75.85 101.28 3,291.20 3,170.20 1,340.85 8,693.01 75.78 104.64 3,314.00 3,193.00 1,320.63 Ugnu B 8,700.00 75.78 104.89 3,315.72 3,194.72 1,318.90 8,800.00 75.76 108.50 3,340.31 3,219.31 1,291.05 8,900.00 75.80 112.11 3,364.88 3,243.88 1,257.42 9,000.00 75.89 115.72 3,389.34 3,268.34 1,218.11 9,031.45 75.93 116.86 3,397.00 3,276.00 1,204.60 Ugnu A 9,100.00 76.03 119.33 3,413.61 3,292.61 1,173.28 9,200.00 76.23 122.93 3,437.58 3,316.58 1,123.10 9,276.38 76.42 125.67 3,455.65 3,334,65 1,081.28 Sail @ 126°Azi : 9276ft MD, 3456ft TVD 9,300.00 76.42 125.67 3,461.19 3,340.19 1,067.90 9,400.00 76.42 125.67 3,484.68 3,363.68 1,011.21 9,438.37 76.42 125.67 3,493.69 3,372.69 989.46 Begin Build/Turn @ 4°NOOft, 9438ft MD, 3494ft TVD 9,500.00 76.53 128.20 3,508.11 3,387.11 953.46 Map Map +E/-W Northing fasting DLSEV Vert Section (ft) (ft) eft) (°/100ft) (ft) 5,896.47 5,947,200.86 564,686.67 0.00 -1,253.33 5,991.55 5,947,221.81 5F~4,781.58 0.00 -1,273.54 6,086.63 5,947,242.76 564,876.49 0.00 -1,293.75 6,181.71 5,947,263.71 564,971.40 0.00 -1,313.96 6,227.15 5,947,273.72 565,016.76 0.00 -1,323.62 6,276.93 5,947,283.96 565,066.45 3.00 -1,333.47 6,372.96 5,947,299.65 565,162.36 3.00 -1,348.42 6,382.41 5,947,300.91 565,171.80 3.00 -1,349.60 6,430.65 5,947,307.21 565,219.98 0.00 -1,355.53 6,469.49 5,947,311.86 565,258.78 3.00 -1,359.87 6,566.41 5,947,319.76 565,355.64 3.00 -1,367.01 6,587.59 5,947,320.79 565,376.80 3.00 -1,367.88 6,636.16 5,947,322.86 565,425.36 0.00 -1,369.57 6,663.56 5,947,323.83 565,452.75 3.00 -1,370.32 6,699.14 5,947,324.45 565,488.32 3.00 -1,370.67 6,747.74 5,947,324.83 565,536.91 0.00 -1,370.67 6,760.76 5,947,324.88 565,549.93 3.49 -1,370.62 6,857.80 5,947,321.78 565,647.00 3.50 -1,366.76 6,954.33 5,947,312.60 565,743.59 3.50 -1,356.82 7,049.98 5,947,297.38 565,839.35 3.50 -1,340.85 7,137.85 5,947,277.84 5&5,927.37 3.50 -1,320.63 7,144.40 5,947,276.17 565,933.93 3.48 -1,318.90 7,237.23 5,947,249.05 586,026.96 3.50 -1,291.05 7,328.12 5,947,216.12 588,118.10 3.50 -1,257.42 7,416.74 5,947,177.51 566,207.02 3.50 -1,218,11 7,444.08 5,947,164.22 586,234.47 3:50 -1,204,60 7,502.75 5,947,133.36 586,293.37 3.50 -1,173.28 7,585.84 5,947,083.84 566,376.85 3.50 -1,123.90 7,647.15 5,947,042.50 566,438.47 3.50 -1,081.28 7,665.80 5,947,029.27 566,457.22 0.00 -1,067.90 7,744.76 5,946,973.21 568,536.62 0.00 -1,011.21 7,775.06 5,946,951.69 566,567.09 0.00 -989.46 7,822.95 5,946,916.07 586,615.25 4.00 -953.46 3/15/2006 2:40:06PM =,,~ ~, P ge 6 of 10 COMPASS 2003.11 Build 50 -~~~~l~L ~--' ~ Halliburton Energy Services ~ M/o-Lt1~tURTC~N ~~'~"~'~~~~ Planning Report -Geographic ----- ----- - --- ~--- ~I~~<a Sperry Dri@i~g S®rvices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-10n -Slot 1J-109 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Plan RKB @ 1z1 00ft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 121 OOft (Doyon 15 (40+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-109 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-109 Design: 1J-109 (wp05) Planned Survey 1J-109 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E!-W Northing fasting DLSEV Vert Section {ft) {°) {°) {ft1 (ft) {ft) (ft) {ft) {ft) (°1100ft) {ft) 9,600.00 76.77 132.31 3,531.20 3,410.20 890.60 7,897.19 5,946,853.79 SeE,689.97 4.00 -890.60 9,700.00 77.08 136.40 3,553.83 3,432.83 822.51 7,966.82 5,946,786.26 566,760.12 4.00 -822.51 9,741.24 77.22 138.09 3,563.00 3,442.00 792.99 7,994.11 5,946,756.96 566,787.64 4.00 -792.99 K13 9,800.00 77.45 140.48 3,575.88 3,454.88 749.54 8,031.50 5,946,713.80 566,825.37 4.00 -749.54 9,900.00 77.88 144.55 3,597.26 3,476.26 672.03 8,090.93 5,946,636.77 566,885.39 4.00 -672.03 10,000.00 78.37 148.61 3,617.84 3,496.84 590.36 8,144.81 5,946,555.53 566,939.90 4.00 -590.36 10,100.00 78.92 152.65 3,637.54 3,516.54 504.94 8,192.87 5,946,470.49 506,988.62 4.00 -504.94 10,200.00 79.52 156.68 3,656.25 3,535.25 416.17 8,234.89 5,946,382.06 567,031.33 4.00 -416.17 10,300.00 80.17 160.69 3,673.90 3,552.90 324.49 8,270.66 5,946,290.67 567,067.81 4.00 -324.49 10,400.00 80.87 164.68 3,690.38 3,569.38 230.34 8,300.00 5,946,196.77 5fi7,097.88 4.00 -230.34 10,500.00 81.61 168.66 3,705.62 3,584.62 134.19 8,322.78 5,946,100.80 567,121.41 4.00 -134.19 10,600.00 82.39 172.62 3,719.55 3,598.55 36.50 8,338.87 5,946,003.26 587,138.26 4.00 -36.50 10,700.00 83.20 176.57 3,732.09 3,611.09 -62.25 8,348.21 5,945,904.59 567,148.37 4.00 62.25 10,793.82 84.00 180.26 3,742.55 3,621.55 -155.43 8,350.79 5,945,811.44 567,151.67 4.00 155.43 Sail @ 84°Inc $ 180°Azi : 10794ft MD, 3743ft TVD 10,800.00 84.00 180.26 3,743.19 3,622.19 -161.58 8,350.76 5,945,805.30 587,151.69 0.00 161.58 10,884.25 84.00 180.26 3,752.00 3,631.00 -245.37 8,350.38 5,945,721.51 567,151.97 0.00 245.37 West SAk D 10,893.82 84.00 180.26 3,753.00 3,632.00 -254.88 8,350.33 5,945,712.00 567,152.00 0.00 254.88 9 5/8" Csg @ 1089dft MD, 3753ft TVb -1830ft FS L & 4346ft FEL -Sec 31 - T11N - R11 E - 9 5/8" -1J-109 T1 Dtop (wp05) ~~ 10,900.00 84.00 180.26 3,753.65 3,632.65 -261.03 8,350.31 5,945,705.85 567,152.02 0.00 261.03 10,913.82 84.00 180.26 3,755.09 3,634.09 -274.77 8,350.24 5,945,692.11 567,152.07 0.00 274.77 Build @ 3°/100ft to 94° linc - i0914ft MD, 3755ft TVD 11,000.00 86.58 180.26 3,762.16 3,641.16 -360.65 8,349.85 5,945,606.24 567,152.34 3.00 360.65 11,100.00 89.58 180.27 3,765.50 3,644.50 -460.58 8,349.39 5,945,506.31 567,152.66 3.00 460.58 11,200.00 92.58 180.27 3,763.61 3,642.61 -560.55 8,348.92 5,945,406.35 567,152.97 3.00 560.55 11,250.70 94.11 180.27 3,760.65 3,639.65 -611.17 8,348.68 5,945,355.74 567,153.13 3.00 611.17 Continue Geo Steer in D-Sand 11251ft MD, 3781ft TVD 11,300.00 94.11 180.27 3,757.12 3,636.12 -660.34 8,348.45 5,945,306.58 567,153.28 0.00 660.34 11,400.00 94.11 180.27 3,749.96 3,628.96 -760.08 8,347.97 5,945,206.84 587,153.58 0.00 760.08 11,500.00 94.11 180.27 3,742.80 3,621.80 -859.82 8,347.50 5,945,107.11 507,153.89 0.00 859.82 11,538.38 94.11 180.27 3,740.05 3,619.05 -898.10 8,347.32 5,945,068.84 567,154.01 0.00 898.10 11,600.00 92.26 180.32 3,736.63 3,615.63 -959.63 8,347.00 5,945,007.32 567,154.17 3.00 959.63 11,606.62 92.06 180.33 3,736.38 3,615.38 -966.24 8,346.96 5,945,000.70 567,154.18 3.00 966.24 11,700.00 92.06 180.33 3,733.02 3,612.02 -1,059.56 8,346.42 5,944,907.39 567,154.37 0.00 1,059.56 11,800.00 92.06 180.33 3,729.43 3,608.43 -1,159.49 8,345.85 5,944,807.47 567,154.58 0.00 1,159.49 11,900.00 92.06 180.33 3,725.83 3,604.83 -1,259.43 8,345.27 5,944,707.54 567,154.78 0.00 1,259.43 12,000.00 92.06 180.33 3,722.24 3,601.24 -1,359.36 8,344.70 5,944,607.62 567,154.99 0.00 1,359.36 12,006.62 92.06 180.33 3,722.00 3,601.00 -1,365.98 8,344.66 5,944,601.00 567,155.00 0.00 1,365.98 1J-109 T2 {wp05) 12,076.05 90.67 180.26 3,720.34 3,599.34 -1,435.38 8,344.30 5,944,531.60 567,155.19 2.00 1,435.38 12,100.00 90.67 180.26 3,720.06 3,599.06 -1,459.33 8,344.20 5,944,507.65 567,155.27 0.00 1,459.33 12,200.00 90.67 180.26 3,718.89 3,597.89 -1,559.32 8,343.75 5,944,407.67 567,155.60 0.00 1,559.32 12,300.00 90.67 180.26 3,717.71 3,596.71 -1,659.32 8,343.31 5,944,307.69 567,155.94 0.00 1,659.32 12,400.00 90.67 180.26 3,716.54 3,595.54 -1,759.31 8,342.86 5,944,207.70 567,156.28 0.00 1,759.31 12,500.00 90.67 180.26 3,715.36 3,594.36 -1,859.30 8,342.42 5,944,107.72 567,156.61 0.00 1,859.30 3/15/2006 2:40:06PM Page 7 of f 0 COMPASS 2003.11 Build 50 r.' ~ Halliburton Energy Services. ~ lat*~cr®tviR~rt3N ~~~~~~~~~~ Planning Report -Geographic --- - ~- ~Stti3 Perry Drilling ~~rvi~es Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-1L19 -Slot 1J-109 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Plan RKB @ 121.OQft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 1L1:UOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-109 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-109 Design: 1J-109 (wp05) Planned Survey 1J-109 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section (ft) {°) {°) (ft) (ft) (ft) (ft) (ft) {ft) (°/100ft) {ft) 12,600.00 90.67 180.26 3,714.19 3,593.19 -1,959.29 8,341.97 5,944,007.74 5ti7,156.95 0.00 1,959.29 12,700.00 90.67 180.26 3,713.01 3,592.01 -2,059.28 8,341.53 5,943,907.76 567.,157.28 0.00 2,059.28 12,800.00 90.67 180.26 3,711.84 3,590.84 -2,159.28 8,341.08 5,943,807.77 567,157.62 0.00 2,159.28 12,900.00 90.67 180.26 3,710.66 3,589.66 -2,259.27 8,340.64 5,943,707.79 567,157.95 0.00 2,259.27 13,000.00 90.67 180.26 3,709.48 3,588.48 -2,359.26 8,340.19 5,943,607.81 567,158.29 0.00 2,359.26 13,100.00 90.67 180.26 3,708.31 3,587.31 -2,459.25 8,339.75 5,943,507.82 567,158.63 0.00 2,459.25 13,200.00 90.67 180.26 3,707.13 3,586.13 -2,559.24 8,339.30 5,943,407.84 567,158.96 0.00 2,559.24 13,300.00 90.67 180.26 3,705.96 3,584.96 -2,659.24 8,338.86 5,943,307.86 567,159.30 0.00 2,659.24 13,400.00 90.67 180.26 3,704.78 3,583.78 -2,759.23 8,338.41 5,943,207.88 567,159.63 0.00 2,759.23 13,500.00 90.67 180.26 3,703.61 3,582.61 -2,859.22 8,337.97 5,943,107.89 567,159.97 0.00 2,859.22 13,600.00 90.67 180.26 3,702.43 3,581.43 -2,959.21 8,337.52 5,943,007.91 567,160.31 0.00 2,959.21 13,700.00 90.67 180.26 3,701.26 3,580.26 -3,059.20 8,337.08 5,942,907.93 567,160.64 0.00 3,059.20 13,800.00 90.67 180.26 3,700.08 3,579.08 -3,159.20 8,336.63 5,942,807.94 587,160.98 0.00 3,159.20 13,806.94 90.67 180.26 3,700.00 3,579.00 -3,166.14 8,336.60 5,942,801.00 587,161.00 0.00 3,166.14 1 J-109 T3 (wp05} 13,900.00 88.35 180.24 3,700.80 3,579.80 -3,259.19 8,336.20 5,942,707.96 567,161.33 2.50 3,259.19 14,000.00 85.85 180.22 3,705.86 3,584.86 -3,359.05 8,335.81 5,942,608.11 587,161.71 2.50 3,359.05 14,028.64 85.13 180.21 3,708.11 3,587.11 -3,387.60 8,335.70 5,942,579.56 587,161.83 2.50 3,387.60 14,100.00 85.13 180.21 3,714.17 3,593.17 -3,458.70 8,335.44 5,942,508.47 567,162.12 0.00 3,458.70 14,200.00 85.13 180.21 3,722.66 3,601.66 -3,558.34 8,335.07 5,942,408.84 567.,162.53 0.00 3,558.34 14,300.00 85.13 180.21 3,731.14 3,610.14 -3,657.98 8,334.70 5,942,309.21 587,162.94 0.00 3,657.98 14,400.00 85.13 180.21 3,739.63 3,618.63 -3,757.62 8,334.34 5,942,209.58 587,163.36 0.00 3,757.62 14,500.00 85.13 180.21 3,748.12 3,627.12 -3,857.26 8,333.97 5,942,109.95 567,163.77 0.00 3,857.26 14,600.00 85.13 180.21 3,756.60 3,635.60 -3,956.89 8,333.60 5,942,010.32 567,164.18 0.00 3,956.89 14,700.05 85.13 180.21 3,765.10 3,644.10 -4,056.59 8,333.24 5,941,910.64 587,164.59 0.00 4,056.59 14,800.00 87.63 180.23 3,771.41 3,650.41 -4,156.32 8,332.85 5,941,810.91 587,164.98 2.50 4,156.32 14,900.00 90.13 180.26 3,773.36 3,652.36 -4,256.30 8,332.42 5,941,710.95 587,165.33 2.50 4,256.30 14,910.01 90.38 180.26 3,773.32 3,652.32 -4,266.31 8,332.37 5,941,700.94 587,165.36 2.51 4,266.31 15,000.00 90.38 180.26 3,772.72 3,651.72 -4,356.29 8,331.96 5,941,610.96 567,165.66 0.00 4,356.29 15,100.00 90.38 180.26 3,772.06 3,651.06 -4,456.29 8,331.51 5,941,510.97 56?,165.99 0.00 4,456.29 15,200.00 90.38 180.26 3,771.39 3,650.39 -4,556.29 8,331.06 5,941,410.99 5Fi7,166.31 0.00 4,556.29 15,300.00 90.38 180.26 3,770.73 3,649.73 -4,656.28 8,330.60 5,941,311.00 567,166.64 0.00 4,656.28 15,400.00 90.38 180.26 3,770.07 3,649.07 -4,756.28 8,330.15 5,941,211.01 587,166.97 0.00 4,756.28 15,410.01 90.38 180.26 3,770.00 3,649.00 -4,766.29 8,330.10 5,941,201.00 567,167.00 0.00 4,766.29 1J-109 T4 (wp05) 15,453.17 91.24 180.31 3,769.39 3,648.39 -4,809.45 8,329.89 5,941,157.85 587,167.12 2.00 4,809.45 15,500.00 91.24 180.31 3,768.37 3,647.37 -4,856.26 8,329.64 5,941,111.04 587,167.24 0.00 4,856.26 15,600.00 91.24 180.31 3,766.21 3,645.21 -4,956.24 8,329.11 5,941,011.07 56?,167.49 0.00 4,956.24 15,700.00 91.24 180.31 3,764.04 3,643.04 -5,056.21 8,328.58 5,940,911.10 567,167.74 0.00 5,056.21 15,800.00 91.24 180.31 3,761.87 3,640.87 -5,156.19 8,328.04 5,940,811.14 567,167.98 0.00 5,156.19 15,900.00 91.24 180.31 3,759.70 3,638.70 -5,256.16 8,327.51 5,940,711.17 587,168.23 0.00 5,256.16 16,000.00 91.24 180.31 3,757.54 3,636.54 -5,356.14 8,326.98 5,940,611.20 587,168.48 0.00 5,356.14 16,100.00 91.24 180.31 3,755.37 3,634.37 -5,456.11 8,326.45 5,940,511.24 567,168.73 0.00 5,456.11 16,200.00 91.24 180.31 3,753.20 3,632.20 -5,556.09 8,325.91 5,940,411.27 587,168.98 0.00 5,556.09 16,209.27 91.24 180.31 3,753.00 3,632.00 -5,565.36 8,325.86 5,940,402.00 587,169.00 0.00 5,565.36 1J-109 T5 (wp05} 16,266.88 92.39 180.26 3,751.17 3,630.17 -5,622.93 8,325.58 5,940,344.43 587,169.17 2.00 5,622.93 16,300.00 92.39 180.26 3,749.79 3,628.79 -5,656.03 8,325.43 5,940,311.34 582,169.28 0.00 5,656.03 16,400.00 92.39 180.26 3,745.61 3,624.61 -5,755.94 8,324.98 5,940,211.44 567,169.61 0.00 5,755.94 3/15/2006 2:40:06PM page 8 of 10 COMPASS 2003.11 Suild 50 ORIGINAL ~--' ~ Halliburton Energy Services ~ HALLBUF~iTON ~~~~~~~'~ Planning Report -Geographic ___ __~_.~ r"-tiSSlt~ 3pe~rry tirilleng s~'errri!ce~ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-109 -Slot 1J-109 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Plan RKB @ 121.OC7ft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well; Plan 1J-109 Survey Calculation Method: Minimum Curvatwe Wellbore: Plan 1J-109 Design: 1J-109 (wp05) Planned Survey 1J-109 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N!-S +E!-W Northing fasting DLSEV Vert Section (ft) (°) (°) (ft) (ft) 1ft) (ft) (ft) (ft) {°/100ft) (ft) 16,500.00 92.39 180.26 3,741.44 3,620.44 -5,855.85 8,324.53 5,940,111.54 5~i,169.94 0.00 5,855.85 16,600.00 92.39 180.26 3,737.26 3,616.26 -5,955.76 8,324.08 5,940,011.63 567,170.27 0.00 5,955.76 16,700.00 92.39 180.26 3,733.09 3,612.09 -6,055.67 8,323.63 5,939,911.73 587.,170.60 0.00 6,055.67 16,800.00 92.39 180.26 3,728.91 3,607.91 -6,155.59 8,323.18 5,939,811,83 587,170.93 0.00 6,155.59 16,821.85 92.39 180.26 3,728.00 3,607.00 -6,177.42 8,323.08 5,939,790.00 5ti7,171.00 0.00 6,177.42 TD @ 16822ft MD, 3728ft TVD : 1187ft FSL & 4404fE FEL -Sec 6 - T10N - R11E - 4112" -1J-109 T6 Toe (wp05) Geologic Targets Plan 1J-109 TVD Target Name +NI-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,753.00 1J-109 DD Polygon (wp05) -254.88 8,350.33 5,945,712.00 567,152.00 - Polygon Point 1 -50.00 0.39 5,945,712.00 567,102.00 Point 2 -55.68 -1,110.71 5,944,601.00 567,105.00 Point 3 -63.74 -2,910.87 5,942,801.00 567,111.00 Point4 -70.23 -4,511.02 5,941,201.00 567,117.00 Point 5 -74.47 -5,310.09 5,940,402.00 567,119.00 Point 6 -77.25 -5,922.15 5,939,790.00 567,121.00 Point 7 22.75 -5,922.93 5,939,790.00 567,221.00 Point 8 25.53 -5,310.87 5,940,402.00 567,219.00 Point 9 29.77 -4,511.80 5,941,201.00 567,217.00 Point 10 36.27 -2,911.65 5,942,801.00 567,211.00 Point 11 44.33 -1,111.49 5,944,601.00 567,205.00 Point 12 50.00 -0.39 5,945,712.00 567,202.00 3,722.00 1J-109 T2 (wp05) -1,365.98 8,344.66 5,944,601.00 567,155.00 - Point 3,753.00 1J-109 Geo Polygon (wp05) -254.88 8,350.33 5,945,712.00 567,152.00 - Polygon Point 1 -60.00 0.47 5,945,712.00 567,092.00 Point 2 -98.47 -3,004.61 5,942,707.00 567,077.00 Point 3 -137.26 -5,921.68 5,939,790.00 567,061.00 Point 4 91.76 -5,923.47 5,939,790.00 567,290.00 Point 5 81.53 -3,007.02 5,942,706.00 567,257.00 Point 6 70.00 -0.55 5,945,712.00 567,222.00 3,770.00 1J-109 T4 (wp05) -4,766.29 8,330.10 5,941,201.00 567,167.00 - Point 3,753.00 1J-109 T5 (wp05) -5,565.36 8,325.86 5,940,402.00 567,169.00 - Point 3,728.00 1J-109 T6 Toe (wp05) -6,177.42 8,323.08 5,939,790.00 567,171.00 - Point 3,700.00 1J-109 T3 fwp05) -3,166.14 8,336.60 5,942,801.00 567,161.00 - Point 3,753.00 1J-109 T1 Dtop (wp05)) -254.88 8,350.33 5,945,712.00 567,152.00 - Point 3/1512006 2:40:06PM Page 9 of 10 COMPASS 2003.11 Build 50 I •-' ~ Halliburton Energy Services ~ 11AUL~~uFITON ~~tlac~rf i ~1~7rS Planning Report -Geographic -----~~- _ __ v.-_,_ Riaska terry ~tr-Iling S~rvtces Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Wetl: Plan 1J-109 Wellbore: Plan 1J-109 Design: 1J-109 (wp05) Prognosed Casing Points Local Co-ordinate Reference: Well Plan 1J-109 -Slot 1J-109 TVD Reference: Plan RKB @ 121.OOft {Doyon 15 (40+81)) MD Reference: Plan RKB @ 1?1:UC~ft (Doyon 15 (40+81)) North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Casing Hole Depth Depth Diameter Diameter lft) eft) t~~) ~~~) 4,373.43 2,297.00 13-3/8 16 10,893.82 3,753.00 9-5/$ 12-114 16,821.84 3,728.00 4-1/2 6~3l4 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +NI-E +E/-W eft) (~) {o) tft) (ft) ~~) Name 1,677.46 48.56 78.00 1,524.00 109.64 515.83 Base of Permafrost 1,919.10 58.34 78.00 1,672.00 149.25 702.19 T3 3, 087.24 76.42 78.00 1, 995.00 381.73 1, 795.89 K15 4,373.43 76.42 78.00 2,297.00 641.67 3,018.80 T3 + 550 7,350.39 76.42 78.00 2,996.00 1,243.31 5,849.30 Ugnu C 8,693.01 75.78 104.64 3,314.00 1,320.63 7,137.85 Ugnu B 9,031.45 75.93 116.86 3,397.00 1,204.60 7,444.08 Ugnu A 9,741.24 77.22 138.09 3,563.00 792.99 7,994.11 K13 10,884.25 84.00 180.26 3,752.00 -245.37 8,350.38 West SAk D 3/i5/2006 2:40:06PM Page 10 of 10 COMPASS 2003.71 Build 50 ~ ~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-109 Plan 1J-109 1J-109 (wp05) Anticollision Report 15 March, 2006 hfALLIE-~URTO Sp~erlry Qrilling Sielr~rca ~~~~~~ Uele: 20U6-U3-1OT00:0U:00 \'elidated: l'ec Fersion: Uepth From Depth'I'o SenrylPlan Tool 40.W 8W.U0 (J-LU9 C~~Y05) C'B-GYRO-SS BUU.UO 1fi82L85 1J-I09 (~rpOC) 41ND+1FR-AK-CALSC 1J-103 (wp02) 1J-102 (wp06) ~~, ~~ C WSP- 1 J-0: 1(J~'-154 ~~~...~~/yy '~1° .~+~-- I1 -158 (w WSP- '1J- 61 0 I 7J.12 Pilot so From Colour To MD 40 250 250 500 500 750 750 1000 1000 1250 1250 _ 1500 lsaa 175a 1750. 2000 2000 2250 2250 2500 2500 2750 1ao 2750 3000 1J-115 (wp02) WSP-04 ~ 3000 ~ 4000 r 4000 "'°° 1J-111 (wp03) ""°_"_ 5000 5000 6000 'T'ravelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [75 ft/inl 6000 7000 7000 8000 8000 9000 9000 -~~__.. .__._...__ 17000 REFERENCE INFORMATION Co-ordinate (NIE) Reference: Wel I Plan 1J•109 -Slot 1 J-109, True North Vertical (TVD) Reference: Plan RKB @ 121.OOft (Doyon 15 (40+et)) Section (VS) Reference: Slot - iJ-109(O.OON, O.OOE) Measured Depth Reference: Plan RKB @ 121.OOft (Doyon 15 (40+81)) Calculatlon Method: Minimum Curvature ANTI•COLLISION SETTINGS Ground Level: 81.00 Interpolation Method: MD Interval: 50Statlons +NI•S +EI•W Northing Eastlng Latlttude Longitude Slot Depth Range From: 40.00 To 16821.85 0.00 0.00 5945901.64 558800.73 70°15'46.08N 149°31'29.697W 1J-109 Maximum Range:1878.18508259221 Reference: Plan: 1J-109 (wp05) 1J-03 300 0 330 Drilling 8 Wells Wes[ Sak Calculatlon Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Enor Surtace: Elliptical Conic Warning Method: Rules Based 30 60 240 91 120 210 ~"'_ 150 ' t.<y`~N 180 Travelling C--ylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [[5 tt/in] Sec MD Inc Azl TVD +N/S +E/-W DLeg TFace VSec Target _ 1 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.0000 0.00 2 262.00 0.00 0.00 262.00 0.00 0.00 0.00 0.0000 0.00 3 702:71' 11.02 78100" 704:00: 8!7&~ 41.32 250.78;0000- -8;78 4 - 1841'.20 48:5.6: 78:0.0; 150D:00 103':99- 489;25- 4:00. 0:0000' -193:94 5.~ 1741:20 48:5:6 78:00 1566.19' 119.58 56257 Q00 0.0000 -'119.58 6` 2247:79 76:42 78J10' 1797.90 2i2:08~ 997.74 S.SD 0:0000' •2i2:08~ 7 7747.79 76.42 78.00 3089.31 1323.62 6227.15 0.00 0.0000 -1323.62 8 7909.80 76.42 83.00 3127.37 1349.60 6382.41 3.00 90.5874 -1349.60 9 7959.80 76.42 83.00 3139.11 1355.53 6430.65 0.00 0.0000 -1355.53 10 8121.80 76.42 88.00 3177.17 1367.88 6587.59 3.00 90.5874 -1367.88 11 8171.80 76.42 88.00 3188.91 1369.57 6636.16 0.00 0.0000 -1369.57 12 8236.61 76.42 90.00 3204.13 1370.67 6699.14 3.00 90.2348 •1370.67 13 8286.61 76.42 90.00 3215.87 1370.67 6747.74 0.00 0.0000 -1370.67 14 9276.38 76.42 125.67 3455.65 1061.28 7647.15 3.50 94.3252 -1081.28 15 9438.37 76.42 125.67 3493.69 989.46 7775.06 0.00 0.0000 •989.46 16 10793.82 84.00 180.26 3742.55 -155.43 8350.79 4.00 87.6169 155.43 17 10893.82 84.00 180.26 3753.00 -254.88 8350.33 0.00 0.0000 254.88 1J-109 T1 Dtop (wp05)) 18 10913.82 84.00 180.26 3755.09 -274.77 8350.24 0.00 0.0000 274.77 1911250.70 94.11 180.27 3760.65 -611.17 8348.68 3.00 0.0697 611.17 20 11538.38 94.11 180.27 3740.05 -898.10 8347.32 0.00 0.0000 898.10 21 11606.62 92.06 180.33 3736.38 •966.24 8346.96 3.00178.3845 966.24 22 12006.62 92.06 180.33 3722.00 •1365.98 8344.66 0.00 0.0000 1365.98 iJ•109 T2 (wp05) 23 12076.05 90.67 180.26 3720.34 -1435.38 8344.30 2.00176.9043 1435.38 24 13806.94 90.67 180.26 3700.00 -3166.14 8336.60 0.00 0.0000 3166.14 1J•109 T3 (wp05) 25 14028.64 85.13 180.21 3708.11 -3387.60 8335.70 2.50179.5461 3387.60 2fi 14700.05 85.13 180.21 3765.10 -0056.59 8333.24 0.00 0.0000 4056.59 27 14910.01 90.38 180.26 3773.32 -4266.31 8332.37 2.50 0.5355 4266.31 28 15410.01 90.38 180.26 3770.00 -0766.29 8330.10 0.00 0.0000 4766.29 iJ•109 T4 (wp05) 29 15453.17 97.24 180.31 3769.39 -0809.45 8329.89 2.00 3.0041 4809.45 30 16209.27 91.24 180.31 3753.00 •5565.36 6325.86 0.00 0.0000 5565.36 iJ-109 TS (wp05) 31 16266.88 92.39 180.26 3751.17 -5622.93 8325.58 2.00 -2.3496 5622.93 Halliburton Energy Services ~ C Ph N HALLlBURTON onaCO ~ ips Anticollision Report Alaska gperry Drilling S®rviaes Company: ConocoPhillips Alaska ,(Kuparuk) Local Co-ordinate Reference: Well Plan 1 J-109 - lot 1 J-109 Project: Kuparuk River Unit TVD Reference: Plan RKB @ 121_COft (Doyon 15 (40+81)) Reference Site: Kuparuk 1J :Pad MD Reference: Plan RKB @ 121:OOft (Doyon 15 (40+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-109 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore Plan 1J-109 Database: EDM 2003.11 bindle User Db Reference Design: 1J-109 (wp05) Offset TVD Reference: Offset Datum Reference 1 J-109 (wp05) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,878.18ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 3(1012006 From To ~ (ft) (ft) Survey (Wellbore) Tool Name Description 40.00 800.00 1J-109 (wp05) (Plan 1J-109) CB-GYRO-SS Camera basi:d gyro single shot 800.00 16,821.85 1J-109 (wp05) (Plan 1J-109) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/J5J2006 3:34:52PM Page 2 of 6 COMPASS 2003. J 1 Suild 50 ~GINL / ~ Halliburton Energy Services ~ an h l i HgLLIBURTON C ocaP i l ps Anticollision Report Alaska Sperry Drilling Services Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1 J-109 - Sfot 1 J-109 Project: Kuparuk River Unit ND Reference: Plan RKB @ 121.OOff (Doyon 15 (40+81)) Reference Site: Kuparuk 1J Pad MD Reference: Plan RKB @ 121.OOft (Doyon 15 (40+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-109 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore Plan 1J-109 Database: EDM 2003.11 Single3 lJser Db Reference Design: 1 J-109 (wp05) Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Aad 1J-03 - 1J-03 - 1J-03 803.15 800.00 25.42 15.21 10.39 Pass -Major Risk 1J-09 - 1J-09 - 1J-09 255.94 250.00 178.53 4:5$ 173.94 Pass -Major Risk 1J-10 - 1J-10 - 1J-10 304.08 300.00 158.71 5.49 153.22 Pass -Major Risk 1J-101 - 1J-101 - 1J-101 460.95 450.00 194.71 9.8$ 184.83 Pass -Major Risk 1J-101 - 1J-101 L1 - 1J-101 L1 460.95 450.00 194.71 9.8$ 184.83 Pass -Major Risk 1J-101 - 1J-101 L1 PB1 - 1J-101 L1 PB1 460.95 450.00 194.71 9.8$ 184.83 Pass -Major Risk 1J-101 - 1J-101 L2 - 1J-101 L2 460.95 450.00 194.71 9.8$ 184.83 Pass -Major Risk 1J-101-1J-101PB1-1J-101P61 460.95 450.00 194.71 9.8$ 184.83 Pass-Major Risk 1 J-14 - 1 J-14 - 1 J-14 400.00 400.00 637.45 7.2'7 630.20 Pass -Major Risk 1J-154 - 1J-154 - 1J-154 355.95 350.00 167.49 7.77 159.72 Pass -Major Risk 1J-154 - 1J-154 L1 -1J-154 L1 355.95 350.00 167.49 7.77 159.72 Pass -Major Risk 1 J-154 - 1 J-154 L2 - 1 J-154 L2 355.95 350.00 167.49 7.77 159.72 Pass -Major Risk 1J-159 - 1J-159 - 1J-159 308.98 300.00 149.33 6.84 142.49 Pass -Major Risk 1J-159 - 1J-159 L1 - 1J-159 L1 308.98 300.00 149.33 6.84 142.49 Pass -Major Risk 1J-159 - 1J-159 L1 P81 - 1J-159 L1 PB1 308.98 300.00 149.33 6.84 142.49 Pass -Major Risk 1J-159 - 1J-159 L1 P62 - 1J-159 L1 PB2 308.98 300.00 149.33 6.84 142.49 Pass -Major Risk 1 J-159 - 1 J-159 L2 - 1 J-159 L2 308.98 300.00 149.33 6.84 142.49 Pass -Major Risk 1J-159 - 1J-159 P61 - 1J-159 PB1 308.98 300.00 149.33 6.84 142.49 Pass -Major Risk 1 J-164 - 1 J-164 - 1 J-164 309.07 300.00 202.82 6.84 195.98 Pass -Major Risk 1J-164 - 1J-164 L1 - 1J-164 L1 309.07 300.00 202.82 6.73 196.09 Pass -Major Risk 1J-164 - 1J-164 L2 - 1J-164 L2 309.07 300.00 202.82 6.73 196.09 Pass -Major Risk 1J-164 - 1J-164 L2 PB1 - 1J-164 L2 PB1 309.07 300.00 202.82 6.73 196.09 Pass -Major Risk 1 J-166 - 1 J-166 - 1 J-166 356.17 350.00 233.14 7.77 225.37 Pass -Major Risk 1J-166 - 1J-166 L1 - 1J-166 L1 356.17 350.00 233.14 7.8$ 225.26 Pass -Major Risk 1J-166 - 1J-166 L1 PB1 - 1J-166 L1 PB1 356.17 350.00 233.14 7.77 225.37 Pass -Major Risk 1 J-166 - 1 J-166 L2 - 1 J-166 L2 356.17 350.00 233.14 7.77 225.37 Pass -Major Risk 1J-166 - 1J-166 L2 P61 - 1J-166 L2 PB1 356.17 350.00 233.14 7.8$ 225.26 Pass -Major Risk Plan 1J-102 - 1J-102 - 1J-102 (wp06) 399.57 400.00 160.53 8:57 151.96 Pass -Major Risk Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp06) 399.57 400.00 160.53 8:57 151.96 Pass -Major Risk Plan 1 J-102 - 1 J-102 L2 - 1 J-102 L2 (wp06) 399.57 400.00 160.53 8:57 151.96 Pass -Major Risk Plan 1J-103 -Plan 1J-103 - 1J-103 (wp02) 411.61 400.00 141.17 8.80 132.37 Pass -Major Risk Plan 1J-105 -Plan 1J-105 - 1J-105 (wp02) 461.37 450.00 101.22 9.89 91.34 Pass -Major Risk Plan 1J-107 -Plan 1J-107 - 1J-107 (wp02) 908.71 900.00 64.85 19.86 45.03 Pass -Major Risk Plan 1J-111 -Plan 1J-111 - 1J-111 (wp03) 810.46 800.00 44.23 17.6$ 26.59 Pass -Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 E Lateral - 1J-12 498.29 500.00 60.93 10.73 50.19 Pass -Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 Pilot- 1J-12 Pilot 498.29 500.00 60.93 10.73 50.19 Pass -Major Risk Plan 1 J-112 Kuparuk Prelim -Plan 1 J-12 W Lateral 498.29 500.00 60.93 10.73 50.19 Pass -Major Risk Plan 1J-115 -Plan 1J-115 - 1J-115 (wp02) 560.69 550.00 121.06 12.0$ 108.99 Pass -Major Risk Plan 1J-118 -Plan 1J-118 -Plan 1J-118 (wp01) 661.85 650.00 182.58 13.0$ 169.50 Pass -Major Risk Plan 1J-120 -Plan 1J-120 - 1J-120 (wp01) 463.04 450.00 22028 9.24 211.04 Pass -Major Risk Plan 1J-122 -Plan 1J-122 - 1J-122 (wp02) 9,364.92 9,450.00 268.25 226.50 92.69 Pass -Major Risk Plan 1J-124 -Plan 1J-124 - 1J-124 (wp01) BHI 10,593.68 9,699.96 221.36 172.17 50.92 Pass -Major Risk Plan 1J-129 (Q13 Phase 2) -Plan 1J-129 - 1J-129 ( 550.99 550.00 402.72 12.01 390.71 Pass -Major Risk Plan 1J-132 (Q12 Phase 2) -Plan 1J-132 - 1J-132 ( 400.65 400.00 461.08 8:59 452.48 Pass -Major Risk Plan 1J-141 (L14 Phase 2) - 1J-141 (L14) A Lateral 10,901.66 9,599.96 448.36 174.2$ 274.34 Pass -Major Risk Plan 1J-142 (L15 Phase 2) - 1J-142 (L15) (Phase 2 11,182.61 9,699.96 629.47 162.17 467.27 Pass -Major Risk Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDisposal 309.84 300.00 232.35 6.01 226.34 Pass -Major Risk Plan 1J-152 - 1J-152 - 1J-152 (wp05) 308.93 300.00 202.61 6.58 196.03 Pass -Major Risk Plan 1J-152 - 1J-152 - 1J-152 Rig Surveys 40.00 28.00 202.23 1.22 201.01 Pass -Major Risk Plan 1J-152 - 1J-152 L1 - 1J-152 L1 (wp05) 308.93 300.00 202.61 6:5$ 196.03 Pass -Major Risk Plan 1J-152 - 1J-152 L2 - 1J-152 L2 (wp05) 308.93 300.00 202.61 6:5$ 196.03 Pass -Major Risk Plan 1J-156 - 1J-156 - 1J-156 w 02 308.97 300.00 152.18 6:58 145.60 Pass -Major Risk GC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/15/2006 3;34;52PM Page 4 of 6 COMPASS 2003.11 Suild 50 GRI~IfJAL l-' ~ Halliburton Energy Services Cai'loCOPh~llips Anticollision Report Alaska Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Project: Kuparuk River Unit.. ND Reference: Reference Site: Kuparuk 1J Pad. MD Reference: Site Error: O.OOft North Reference: Reference Well: Plan 1 J-109 Survey Calculation Method: Well Error. O.OOft Output errors are at Reference Wellbore Plan 1J-109 Database: Reference Design: 1 J-109 (wp05) Offset ND Reference: HALLtBURTON Sperry Drilling Services Well Plan 1J-109-Slot 1J-109 Plan RKB @ 121_CJOfi (Doyon 15 (40+81)) Plan RKB @ 121.OCTft (Doyon 15 (40+81)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Offset Datum Summary Reference Offset Centre to Measured Measured Centre Site Name Depth Depth Distance Offset Well - Wellbore -Design (ft) (ft) (ft) Kuparuk 1 J Pad. Plan 1J-156 - 1J-156 L1 - 1J-156 L1 {wp02) 308.97 300.00 152.18 Plan 1J-156 - 1J-156 L2 - 1J-156 L2 (wp02) 308.97 300.00 152.18 Plan 1J-158 - 1J-158 - 1J-158 (wp03) 262.00 250.00 146.28 Plan 1J-160- Plan 1J-160- 1J-160 {wp01) BHI 262.00 250.00 151.70 Plan 1J-162 - 1J-162 - 1J-162 (wp03.1-North Heel) 309.96 300.00 178.24 Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) 309.96 300.00 178.24 Plan 1 J-162 - 1 J-162 L2 - 1 J-162 L2 (wp3.1) 309.96 300.00 178.24 WSP-02 -WSP-02 -WSP-02 656.27 650.00 23.01 WSP-03 -WSP-03 -WSP-03 717.29 700.00 81.36 WSP-04 -WSP-04 -WSP-04 704.79 700.00 140.10 WSP-05 -WSP-OS -WSP-05 797.56 800.00 203.77 WSP-06 -WSP-06 -WSP-06 800.00 800.00 263.05 WSP-15 -WSP-15 -WSP-15 700.40 700.00 41.71 WSP-1 S -WSP-1 S -WSP-1 S 752.86 750.00 105.08 WSP-20 -WSP-20 -WSP-20 358.26 350.00 235.70 No-Go Allowable Distance Deviation Warning (ft) from Plan (ft) 6.58 145.60 Pass -Major Risk 6.5$ 145.60 Pass -Major Risk 5.39 140.89 Pass -Major Risk 5.65' 146.05 Pass -Major Risk 6.44 171.80 Pass -Major Risk 6:34 171.90 Pass -Major Risk 6:34 171.90 Pass -Major Risk 13.79 9.22 Pass -Major Risk 19.14 62.22 Pass -Major Risk 14.89 125.22 Pass -Major Risk 21.75. 182.03 Pass -Major Risk 21.67 241.38 Pass -Major Risk 16.93 24.79 Pass -Major Risk 28.14 78.06 Pass -Major Risk 8.37 227.34 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/15/2006 3:34:52PM Page 5 of 6 COMPASS 2003.11 Build 50 ~,~` • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-109 -Slot 1J-109 1J-109 ~J Plan: 1J-109 (wpO5) 1/4 Mile Scan -Closest Well In Pool 15 March, 2006 0".IGINAL Closest in POOL • ~1 ~~! a„..~... Closes t A roach: Reference Well : 1J-109 w 05 Offset Weft: 1J -03 cool- Cood- ASP ASP 3-D ctr-ctr Meas Sba N(j/5(-) View VS Meas S6a N(j/S(-) View VS Min. Dist. De h I A TH Az . ND E 180 ommeh De h I A TH Az . ND E 180 ommeh BMirDil3e BMirDihe (4337.6 f ir0 (4337.6 (irB (3500 - 3650 St3a (3500 - 3650 S6a TVD) b 1J-109 4337.6 10025 78.5 149.63 3501.813 5946535 566953.4 -569.3395 ND) b 1J-03 6550 64.2 61.99 3639.261 5948185 562944.2 -2250.564 (wp05) Closes t A roach: Reference Well : 1J-109 w 05 Offset WeII: tJ -14 Cood- Cood- ASP ASP 3-D ctr-ctr Meas S6a N(jIS(-) View VS Meas S6a N(j/S(-) View VS Min. Dist. Deph I A THAz . ND E 180 ommeta Deph I A THAz . ND E 180 ommeh i i a BMirDitae (4371.92 ~ irB (4371.92 3 irB (3500 - 3650 Spa (3500 - 3650 S6a TVD) b 1J-109 4371.92. 14550 85.13 180.21 3631.386 5942060 567164.8 3907.081 ND) b 1J-14 7000 69.48 125.99 3646.312 5942040 562793 3892.569 (wp05) I ~~ BSmmaq 3/15/2006 434 M Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-109 Wellbore: Plan 1J-109 Plan: 1 J-109 (wo051 1250 625 0 -625 1250 „'~ c ~8 0 N ~s t L 1: O Z L O 3750 CASING D ETAILS 4375 No TVD NID' Name. Size 1 2297.00 4373:43. 13 3/$" 13-3/8 2 3753.0010893.82 9 5/8" 9-5/8 5000 3 3728.0016821.84 4 1 /2" 4-1 /2 5625 6250 Ccana~c~Ph~I~pS Af~ska MALLIBURTC7IV 9yeery Drlliirtg Services '1 OJ 3 0 0 _~ , !1J- 901 l`~'i_p0 )1 '~--%' ~1 by _.__ j ,~50° 175° f 9 5/8" 1so° 160° 160° 180° 180° 1': !' 180° 180° ~ r 41/2" ~ • • -1250 -625 0 625 1250 1875 2500 3125 3750 4375 5000 5625 6250 6875 7500 8125 8750 9375 10000 10625 1111--~/ \Ir.-~/.\ /~~\rll 4/'.\ CASING DETAILS No TVD MD Name Size 1 2297.00 4373.43 13 3/8" 13-3/8 2 3753.00 10893.82 9 5/8" 9-5/8 3 3728.00 16821.84 4 1 /2" 4-1 /2 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-109 Wellbore: Plan 1J-109 Plan: 1J-109 (wp05) n Z ~n r'j s ~0 oOC --~ -109 ~illina Hazards ~mm (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 16" Open Hole / 13-3/8" Casino Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate ~ Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei ht Abnormal Reservoir Low ~ BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates mud rheolo LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low .~ Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole. cleaning, PWD tools, hole o ever runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin 1J-109 Drilling Hazards Summary prepared by Mike Greener r ~~ ~ ~ ~ ~ 3/16/2006 6:37 AM ~~ ~~ ~ ' ' ~~I~r~ CemCADE Preliminary Job Design 13 3/8" Surface Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 3/20/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,678' MD (1,524' TVD) Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 3,573' MD. Lead Slurry Minimum pump time: 300 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1678' - 80') x 3.50 (250% excess) = 2352.4 ft3 0.4206 ft3/ft x (3573' - 1678' x 1.35 (35% excess) = 1076 ft3 81.5 ft3 + 2352.4 ft3+ 1076 ft = 3509.9 ft3 3509.9 ft3 / 4.45 ft3/sk = 788.7 sks Round up to 790 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 190 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x (4373' - 3573') x 1.35 (35% excess) = 454.2 ft3 0.8407 ft3/ft x 80' (Shoe Joint) = 67.3 ft3 454.2 ft3 + 67.3 ft3 = 521.5 ft3 521.5 ft3/ 2.47 ft3/sk = 211.1 sks Round up to 220 sks BHST = 50°F, Estimated BHCT = 65°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) < Top of Tail at 3,573' MD < 13 3/8", 68.0# casing in 16" OH TD at 4,373' MD (2,297' TVD) Mark of Schlumberger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 AS 7.0 625.1 89.3 122.6 DeepCRETE 6.0 92.9 15.5 138.1 Drop top plug 0.0 0.0 5.0 143.1 Water 5.0 20.0 4.0 147.1 Switch to rig 0.0 0.0 5.0 152.1 Mud 7.0 613.8 87.7 239.8 Slow & bump plug 3.0 9.0 3.0 242.8 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 2 per joint throughout tail slurry column oRi~~n~n~ ' ' ~l~~r~ CemCADE Preliminary Job Design 9-5/8" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 3/20/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com Previous Csg. < 13 3/8", 68.0# casing at 4,373' MD < Top of Tail at 6,850' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 10,894' MD (3,753' TVD) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 4044' MD annular length Tail Slurry Minimum thickening timer 290 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 4044' x 1.25 (25% excess) = 1583.2 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1583.2 ft3 + 34.1 ft3 = 1617.3 ft3 1617.3 ft3/ 2.25 ft3/sk = 718.8 sks Round up to 720 sks BHST = 88°F, Estimated BHCT = 75°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbll (mini CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 75.0 15.0 40.0 DeepCRETE 5.0 288.0 57.6 97.6 Drop top plug 0.0 0.0 5.0 102.6 Wate 5.0 20.0 4.0 106.6 Switch to rig 0.0 0.0 5.0 111.6 Mud 6.0 791.0 131.8 243.4 Mud 3.0 9.0 3.0 246.4 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend ?? 2 per joint on shoe track ?? 1 'h per joint until 500' and above West Sak ?? 1 per joint across all Ugnu ~~~ n ~~ N ~~ Wellhead /Tubing Head /Tree, 10-3/4" x 4-%", 5,000 ksi Insulated Conductor Casing, 20", 94#, K55 x 34", 0.3 I Z" WT Li? +/- 80' MD 13-3/8", 68#, L-80, BTC, R3 @ 4,200' MD / 2,278' TVD ~~ @ 77 degrees TD 16" hole Top of Ugnu C @, 7,253' MD / 2,976' TVD ~ (( ~~ ~....1 ~~ ? F ~~ ~ s~ ~ /~J ~'"~ .~,~ ~ .. u, ~ c o S o C y ., y ~ c ' j.' ~+~~ L G ~"~" c c C Tubing String: 4-I/2", 12.6 #, L-80, IBTM (1) Gas Lift Mandrel, CAMCO 4-1/2" x I" Model KBG-2, one (p set @ ~XXX' MD, X,XXX' TVD. (I) Gas Lift Mandrel, CAMCO 4-1/2" x l" Model KBG-2, X,XXX' MD, X,XXX' TVD. Electric Submersible Pump, Centrilift 418 HP motor, with EC6W0 wireline deployed pump. Bottom at X,XXX' ;1I D, X,XXX' TVD Top of West Sak D @ 10,708' MD / 3,741' TVD ~~ e~ a'~ b ~ C "'mn~ °a C i ~ Seal bore and ZXP packer for D liner @ 10,500' 9-5/8", 40#, L-80, BTCM, It3 Csg ~ a. IQ708' MD / 3,741' TVD @ 84 degrees TD 12-1/4" hole D Sand Liner, 4-1/T', 11 6#, L80, BTC, R3 IJ-I09: 6-3/4" D sand lateral TD IG~3(f'MD/3,7J1i-TVD Mgle 92 degrees 37Zt3~ Tr' 9d' _ • ConocoPhillips Alaska, Inc. 700 G St Anchorage, AK 99501 September 8, 2004 Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 Dear Commissioners: • ConocoPhillips Alaska requests an amendment to Area Injection Order 2B {A1O2B) to include additional acreage for disposal into the Upper Ugnu Sand {Ugnu C). ConocoPhillips Alaska plans to drill a Class II disposal well to dispose of mud and cuttings and other non-hazardous fluffs resulting from drilling and produaion operations. This well is covered under the Kupanak River Unit {KRU) A1O26, which allows the injection of disposal waste into the Ugnu A and Ugnu B sands. ConocoPhillips Alaska would like to request an amendment to Rule 2, °Authorized Injection Strata for Disposal", of the existing KRU A1O2B. We request that A1O2B be amended to include sections 26, 27, 34, and 35 of T11 N, R10E, Umiat Meridian for disposal injection into non-hydrocarbon bearing zones of the Ugnu C (Attachment 1), in addition to the existing authorized zones. This zone correlates to the strata found in ARCO West Sak River State Well No. 1 between the measured depths of 3145 feet and 3390 feet {Attachment 2). It is believed that confined, non-hydrocarbon bearing zones to inject into exist within the Ugnu A, B and C intervals between the approximate subsea depths of 2700 feet and 3200 feet of the proposed injection area (Attachment 2}. Additionally, all the proposed injection strata fall within the KRU boundary within which the aquifers are exempt from the definition of freshwater. The selection of the disposal interval will be based on the log data gathered when the well is drilled. Inclusion of the Ugnu C interval allows greater flexibility to identify the best injection zone and avoid any hydrocarbons, which may be encountered in the Ugnu. Two previous amendment requests have been made for Rule 2, requesting the Ugnu C for class II disposal. These requests were made for Drillsites 1B and 3R. The 16 request was approved in July 1988 and the 3R request was approved in December 1991. We are requesting approval to use the Ugnu C for class II disposal at 1J pad. Attached to this letter is across-section showing West Sak 1 and the nearest 1 J weld (Attachment 1), and a top Ugnu structure map (Attachment 2). Should you have any questions regarding this request, please contact Steve McKeever at (907) 265- 6826. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader • • 1J 109 Surface Injection Pressures with gauge at disposal wellhead and using annulus friction of 50 MW ~ P) Injection Pressure ~ si MW ~ Pg) Injection Pressure ~ si MW ~P } Injection Pressure t si) 6.8 1,093 8.8 853 10.8 614 6.9 1,081 8.9 841 10.9 602 7.0 1,069 9.0 829 11.0 590 7.1 1,057 9.1 817 11.1 578 7.2 1,045 9.2 805 11.2 566 7.3 1,033 9.3 793 11.3 554 7.4 1,021 9.4 781 11.4 542 7.5 1,009 9.5 769 11.5 530 7.6 997 9.6 757 11..6 518 7.7 985 9.7 745 11.7 506 7.8 973 9.8 733 11.8 494 7.9 961 9.9 722 11.9 482 8.0 949 10.0 710 12.0 470 8.1 937 10.1 698 12.1 458 8.2 925 10.2 686 12.2 446 8.3 913 10.3 674 12.3 434 8.4 .901 10.4 662 12.4 422 8.5 889 10.5 650 12.5 410 8.6 877 10.6 638 12.6 398 8.7 865 10.7 626 12.7 386 C~ r u ~ e 4C c-~. ~,1 ~ l.~ ~' S~ Annular Injection -Operating Conditions s G ~, This chart included the Annular Friction that is input in cell Z17 (not calculated in this spreadsheet). Well # 1J-109 Surface Shoe Depth 2,306 ft LOT/FIT @ Surface Shoe 15.5 ppg Annulus EMW I 12.4 Pressure @ Shoe 1,859 Pump distance 350 Line Diameter 1.75 Velocity@ 2 BPM 11.28 ft/s friction factor 0.02 Annular Friction Loss 50 psi • • ~, °' 0 o 3 ~ ~ ~' >° M ~ a ~ o ~ ~ ~ O Y '~ y J N ~ d U ~ ~ ~ C O) d d O N O C • U Y ~ •X 10 -U /0 v ~ a` ~ i ~ ~ °. ~ I N ' 0 ~ ' . ~. a L O ~ O O N r r r N N L ~ O ~ ~L r m d a.+ C L L a 0 0 0 _ o 0 0 0 0 o 321f1SS3?~d Pressure Integrity Test 1J-109 C Yra ~ c~`~c.~, 1500 ~ ~~Casing Test - - -Theoretical Minimum Volume ~ icipated Leak-off Pressure ~ ~-Leak-off Test / - - - - - -Theoretical Maximum Volume O FIT Point 1000 -Maximum Pressure W ~ W ~ ~ a ~ 500 0 0.0 2.0 4.0 6.0 8.0 1 0.0 1 2.0 1 4.0 Barrels • • • DELTA BROWN ~~ ~ ~~~ 1051 CONOCOPHILLIPS _ J AT01534 ~ `Z CJ~ 700 G ST. DATE 56-1551/441 ANCHORAGE AK 99501 PAY TO THE ~/_ ~~/ a ORDER OF ~ ~ ` ~" C~'I/~~U (ti ~ jU~,i 6~ P 'v ~ C ~ w DOttA ~ ,~~ s.~ J PMorgainChase ~ j valid up To 5ot)o ~ouars JPMorgan Chase Bank, N.A. }/ `mot"! '"tG / ~ / ,1'~~ Colu us, O~r,~- /_ J ~/ Vu~~llC,_ ~ ~" ~(~~J ~ ~- ~ MEMO T - ----- --- ----- -- -- ----- ----- -- x:044 L L55 L L!:528743B98B6 L9n~105 L j ~ • TRANSMITTAL LETTER CHECKLIST WELL NAME ~/eL~. ~~ ~~ PTD# ZO~o - bS~ ~! Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/25/06 C: \j ody\transmittal_checkl ist r WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOIL-490150 Well Name: ~ARUK RIV U WSAK 1J-109 Program DEV Well bore seg ^ PTD#:2060500 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_feeattached______ ___-_________________._____ ___,-_. Yes- __-___-__-_--___--__. -- -- - - - 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - Yes Made-correction to 401_ form: Top Prod Interval in ADL 28248, TD in ADL 390705.-Lease_318602 expired in_'03. - 3 U-n(quewell-name and numbe[_________________________---- --------Yes- ---------_----___---- ----------------------------------------------------- 4 Well locatedin_a_definedpo4l_______________________________ ________Yes_ _____KRUWest_SakOilPool,goyemed-by Conservation_OrderNo:4Q6B-__-___---_------__-._.____ 5 Well located proper distance from drilling unit_boundery . . . . . ... . . . . . . . . . .. .... Yes - - - - - . - C9 4066, Rule 3; no restrictions as-tQ wQll spacing except that rlo_pay shall be openQd in a well closer - _ _ _ _ _ _ 6 Well located proper distance from other wells_ .. Yes than 50.0 feet to.an external_property line where ownershipor landownership changes- - - - - - - - - - - - - - - - 7 Sufficientacreageayailablein_drillinqunit______--_-------------- --------Yes_ -___-_--_-.___-_---__----_-___--____ ------------------------------------ 8 If deviated, is-wellboreplat_included_______________ __-_-__--_ _.------Yes_ --_-----___--_-_--__--- --____ ------------------------------------------ 9 Ope[atotontyaffectedparty_-._______________ ___________ ________Yes_ -_,_, 10 Operator has.appropriate-bond in force----------- ------- -- -- - ---- -Yes- ----------- --- -------...---------- -- -- --------- -- --------- -- - 11 Pe[mit_cah be issued without conservation order. - _ _ , - Yes Appr Date 12 Pe[mitcan be issued without administ[ative_approval - - - - - - - - - - - - - - - - - - - - _ _ _ Yes _ _ - _ - - _ _ - _ _ - - _ _ - - _ . - SFD 4!6!2006 13 Can permit be approved before 15-day wait Yes 14 WelllocafedwithinareaandstrataauthorizedkylnjectionOrder#(put1O#in_comments)-(FOr_ NA__ _________________--_---_---_-__--_ -_-.__---____--__--- _---_-___- -_- _ 15 All wells within 1/4_mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ - _ - _ _ _ _ _ _ _ - - _ _ _ - --------------------------------------------------------- 16 Pre-produced injector: duration_ofore-production 1_ess than_ 3 months-(For service well only) - - NA- - - - - - - - - - - - - - - - - - - - - - - - AC_M_P_FindingofConsistency_hasbeepissued_fo[this project-..-.__._-, _„-___ NA-- ------------------------------------ -------------------------------------- Engineering 18 Conductorstring_p_rovided_________________________________ ________Yes_ __-__.__----.--__---.-_-----__-__- - - 19 Surface casing_protectsallknown_USDWs ....................... ........ NA_- ____--All aquifers exempted, 40 CFR-147.102_(b)(3)._____________-_______________- __-- 20 _C_MT_vol_adequate-to ci[culate on conductor & surf.csg _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ 21 CMT_vol. adeguate_to tie-in long string to surf csg_ No- - - All_ hydrocarbons will be covered, Annular disposal may be proposed .. .. ..... . . .. . . . . . . . . . . . . 22 CMT.willcoverallknownproductivehorizons---------------------- --------No__ _____-Slottedliner completion planned._-______-_-_-___--__-__- ------------------------- 23 Casing designs adequate forC,T,B&_permafrost_____.--------- - Yes- ------------------------- ----------------------------------------.--- 24 Adequate tankage_o_r reserve pit - - - - - - - - - - -- - - - - - - - - - -- - -- - - - - - --- - - -Yes - - - - - - -Rig is-equipped with steel_pits.. No reserve_pitplanned, All waste to approved annulus or disposal wel_Is. 25 Ifa_re-drill,has-a10-403 for abandonment been aRP-roved______________ ___.__ NA.- _____--_--__--__--__--__--_-_- ---------------------------------------- 26 Adequate wellbore_ separatjonproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - - - - _ .Proximity analysis performed, Traveling cylinder path calculated, Gyros planned in_su_rfaee hole._ _ - _ _ _ - _ 27 If diverterrequired,doesitmeetregulations______________________ ___._--Yes_ __-__-__--_-.--_--__-----__--_.-_--_-.----___-_ ------------------------ Appr Date 28 Drilling fluid_ program schematic-& equip listadequate- - - - - - - - - - - - - - - - - -- - - --- -Yes - - - - - - -Maximum expected fo[malion pressure 8,7_ EMW._ MW planned 8.6 or as_needed, - _ TEM 4!6!2006 29 BOPEs,dotheymeetregulation-_-________________________ ____ ___Yes_ ______-__-_.--_---__.-_-__--__--__--_--__-- 30 BOPS-press rating appropriate; test ko-(put psig in comments), - Yes - - - - _ _ - MASP calculated at 1276psi, 3K stack arrangement and test pressureplanned_ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ 31 Choke-man'rfoldcomplieswlAPI-RP-53(May84)____________________ ________Yes_ __.____-_..__.__-___--._-__-__-___-__--__.----.---_---- _ 32 Warkwilloccu[wi#houtoperationshutdown_-_--__-_--,.,-_.___ ______.Yes- -------------------------------------------------- --------------------- 33 Js presence of H2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - No- . . _ . - - - H2S is not expected in_this underveloped_area. Rig has sensors and alarms. - 34 Mechanical condition of wells within AOR verified (For service well only) NA_ Geology 35 Pe[mitean be issued wlo hydrogen_sulfide measures Yes - - _ - . -None anticipated in-this new area of West $ak development-- - - - - - - - - - - - - - - - - - - - - 36 Data-presented on potential overpressure zones Yes - _ - - _ Expected reservoirpressure is 8.7-ppg EMW; will be drilled with 8.6 ppg oil-based_mud, Mitigation _ . - - - - , - Appr Date 37 Seismic analysis of shallow gas zones- _ _ - _ _ _ _ .. -- - - - - .. - _ - NA_ - _ _ - _ _ _ measures discussed in Drilling Hazards section. - SFD 4!6!2006 38 Seabed condition survey-(ifoff-shore) - _ _ - - _ _ _ -Gas hydrates may be encountered at base of permafrost. -Mitigation-measures noted in Drilling_Hazards Summary 39 Contact namelphone for weekly-progress reports [exploratory only) NA_ Mud program calls for 9.6-ppg mud if hydrates_are encountered_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Geologic Engineering Public Date: Date Date West Sak D sand develo ment well. p Commissioner: mmissioner: C Co r o ,/ _ • C • Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dri~ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Aug 14 15:05:20 2006 • DECEIVED AUG 3 0 2006 Reel Header Service name .............LISTPE Date .....................06/08/14 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/08/14 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF gla$IcaOil & Gas Cons. Commission Anchorage Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1J-109 PB1 API NUMBER: 500292330770 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 14-AUG-06 JOB DATA MWD RUN 3 MWD RUN 4 JOB NUMBER: W-0004474893 W-0004474893 LOGGING ENGINEER: R. FRENCH R. FRENCH OPERATOR WITNESS: F. HERBERT F. HERBERT SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2089 FEL: 2408 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 121.83 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.625 4151.0 2ND STRING 3RD STRING PRODUCTION STRING c~C~-OSC~ ~' ~`~>C~ r t REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUNS 1,2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 3,4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL). MWD RUN 3 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 1J-109 PBl WITH API#: 50-029-23307-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11004'MD/3782'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 (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, ACAL-DERIVED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (12.25" BIT) MUD WEIGHT: 9.0-9.1 PPG MUD SALINITY: 350-450 PPM CHLORIDES FORMATION WATER SALINITY: 6000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE c+. ~ ., v..., a.. ,.. ~ • Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4118.0 10952.5 NPHI 4140.0 10898.5 NCNT 4140.0 10898.5 RPS 4140.0 10945.0 FCNT 4140.0 10898.5 RPD 4140.0 10945.0 FET 4140.0 10945.0 RPM 4140.0 10945.0 RPX 4140.0 10945.0 DRHO 4144.0 10915.5 PEF 4144.0 10915.5 RHOB 4148.0 10915.5 ROP 4153.5 11004.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 4118.0 7917.0 MWD 4 7917.0 11004.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .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 CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 ~ RPS MWD OHMM 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 4118 11004 7561 13773 4118 11004 FONT MWD CNTS 579.1 4722.9 1141.13 13518 4140 10898.5 NCNT MWD CNTS 138765 241516 177682 13518 4140 10898.5 RHOB MWD G/CM 1.19 3.479 2.14081 13536 4148 10915.5 DRHO MWD G/CM -4.758 1.125 0.0587437 13544 4144 10915.5 RPD MWD OHMM 4.06 2000 20.9029 13611 4140 10945 RPM MWD OHMM 5.64 2000 18.2135 13611 4140 10945 RPS MWD OHMM 4.96 2000 14.8866 13611 4140 10945 RPX MWD OHMM 4.62 90.94 11.6506 13611 4140 10945 FET MWD HOUR 0.05 106.87 1.61982 13611 4140 10945 GR MWD API 20.62 130.49 68.587 13670 4118 10952.5 PEF MWD BARN 0.54 11.14 2.07657 13544 4144 10915.5 ROP MWD FT/H 0.8 2168.58 312.066 13702 4153.5 11004 NPHI MWD PU-S 2.65 113.19 35.7575 13518 4140 10898.5 First. Reading For Entire File..........4118 Last Reading For Entire File...........11004 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 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.......06/08/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4118.0 RPS 4140.0 FET 4140.0 RPX 4140.0 STOP DEPTH 7881.5 7874.0 7874.0 7874.0 . NPHI 4140 7822.5 FONT 4140.0 7822.5 RPM 4140.0 7874.0 RPD 4140.0 7874.0 NCNT 4140.0 7822.5 PEF 4144.0 7840.0 DRHO 4144.0 7840.0 RHOB 4148.0 7840.0 ROP 4153.5 7917.0 LOG HEADER DATA DATE LOGGED: 19-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7917.0 TOP LOG INTERVAL (FT) 4153.0 BOTTOM LOG INTERVAL (FT) 7917.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 75.6 MAXIMUM ANGLE: 78.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBE R DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 78633 CTN COMP THERMAL NEUTRON 158416 ALD Azimuth. Litho-Den 10718128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 4151.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 49.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 450 FLUID LOSS (C3) 5.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.400 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.860 94.6 MUD FILTRATE AT MT: 2.400 72.0 MUD CAKE AT MT: 2.600 72.0 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 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4118 7917 6017.5 7599 4118 7917 FCNT MWD030 CNTS 579.1 1997.19 1157.39 7366 4140 7822.5 NCNT MWD030 CNTS 138765 207040 180825 7366 4140 7822.5 RHOB MWD030 G/CM 1.277 2.896 2.08364 7385 4148 7840 DRHO MWD030 G/CM -4.758 0.369 0.035928 7393 4144 7840 RPD MWD030 OHMM 4.06 2000 14.8129 7469 4140 7874 RPM MWD030 OHMM 5.74 2000 13.1623 7469 4140 7874 RPS MWD030 OHMM 4.96 2000 12.1485 7469 4140 7874 RPX MWD030 OHMM 4.62 26.85 10.4872 7469 4140 7874 FET MWD030 HOUR 0.05 106.87 0.850691 7469 4140 7874 GR MWD030 API 21.03 130.49 65.2802 7528 4118 7881.5 PEF MWD030 BARN 0.54 11.14 2.02972 7393 4144 7840 ROP MWD030 FT/H 2.24 1341.96 397.957 7528 4153.5 7917 NPHI MWD030 PU-S 13.48 113.19 38.7321 7366 4140 7822.5 First Reading For Entire File..........4118 Last Reading For Entire File...........7917 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 7823.0 10898.5 NCNT 7823.0 10898.5 FONT 7823.0 10898.5 RHOB 7840.5 10915.5 DRHO 7840.5 10915.5 PEF 7840.5 10915.5 RPM 7874.5 10945.0 RPX 7874.5 10945.0 RPD 7874.5 10945.0 FET 7874.5 10945.0 RP5 7874.5 10945.0 GR 7882.0 10952.5 ROP 7917.5 11004.0 LOG HEADER DATA DATE LOGGED: 24-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11004.0 TOP LOG INTERVAL (FT) 7917.0 BOTTOM LOG INTERVAL (FT) 11004.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 74.8 MAXIMUM ANGLE: 78.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 116184 CTN COMP THERMAL NEUTRON 2809199881343015 ALD Azimuth. Litho-Den 10718130 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 4151.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.05 MUD VISCOSITY (S): 66.0 MUD PH: 9.0 MUD CHLORIDES (PPM) 300 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.200 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.830 91.4 MUD FILTRATE AT MT: 2.050 75.0 MUD CAKE AT MT: 2.400 75.0 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 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOB MWD040 G/CM 4 1 68 12 4 DRHO MWD040 G/CM 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MWD040 FT/H 4 1 68 48 13 NPHI MWD040 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7823 11004 9413.5 6363 7823 11004 FONT MWD040 CNTS 633.05 4722.9 1121.67 6152 7823 10898.5 NCNT MWD040 CNTS 145920 241516 173919 6152 7823 10898.5 RHOB MWD040 G/CM 1.19 3.479 2.20945 6151 7840.5 10915.5 DRHO MWD040 G/CM -0.095 1.125 0.0861663 6151 7840.5 10915.5 RPD MWD040 OHMM 5.82 837.32 28.3086 6142 7874.5 10945 RPM MWD040 OHMM 5.64 985.27 24.356 6142 7874.5 10945 RPS MWD040 OHMM 5.22 169.49 18.2163 6142 7874.5 10945 RPX MWD040 OHMM 4.7 90.94 13.0654 6142 7874.5 10945 FET MWD040 HOUR 0.17 52.59 2.55513 6142 7874.5 10945 GR MWD040 API 20.62 120.71 72.6401 6142 7882 10952.5 PEF MWD040 BARN 0.62 4.66 2.13289 6151 7840.5 10915.5 ROP MWD040 FT/H 0.8 2168.58 207.339 6174 7917.5 11004 NPHI MWD040 PU-S 2.65 73.21 32.1959 6152 7823 10898.5 First Reading For Entire File..........7823 Last Reading For Entire File...........11004 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 • • Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/14 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/08/14 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Aug 14 15:56:37 2006 Reel Header Service name .............LISTPE Date .....................06/08/14 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/08/14 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. FZECEIVED AUG 3 0 2006 Alaska 01~ & Gas COf1S. Cpn11TNSSIO[1 AnChOtage Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1J-109 API NUMBER: 500292330700 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drlling Services TAPE CREATION DATE: 14-AUG-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: W-0004474893 W-0004474893 W-0004474893 LOGGING ENGINEER: R. FRENCH R. FRENCH HENNINGSEN OPERATOR WITNESS: F. HERBERT F. HERBERT F. HERBERT MWD RUN 6 JOB NUMBER: W-0004474893 LOGGING ENGINEER: HENNINGSEN OPERATOR WITNESS: G. RIZEK SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2089 FEL: 2408 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 121.83 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS ~'~ >~105 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT S~ (IN) 12.250 6.750 SIZE (IN) DEPTH (FT) • 13.625 4151.0 9.625 10856.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-109 PB1 WELLBORE AT 10882'MD/3761'TVD, WITHIN THE MWD RUN 4 INTERVAL. 4. MWD RUNS 1,2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3,4, ALSO INCLUDED COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL) MWD RUNS 3,6 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) MWD RUN 5 ALSO INCLUDED AT-BIT INCLINATION (ABI). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-6 REPRESENT WELL 1J-109 WITH API#: 50-029-23307-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15160'MD/3782'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 (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, ACAL-DERIVED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. • • PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (12.25" BIT) MUD WEIGHT: 9.0-9.1 PPG MUD SALINITY: 350-450 PPM CHLORIDES FORMATION WATER SALINITY: 6000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4118.0 15103.0 NPHI 4140.0 10882.0 RPD 4140.0 15110.0 RPM 4140.0 15110.0 FET 4140.0 15110.0 RPX 4140.0 15110.0 NCNT 4140.0 10882.0 FCNT 4140.0 10882.0 RPS 4140.0 15110.0 PEF 4148.0 10882.0 DRHO 4148.0 10882.0 RHOB 4148.0 10882.0 ROP 4153.5 15160.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 4118.0 7917.0 4 7917.0 10882.0 5 10882.5 12383.5 6 12383.5 15160.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing...........~......60 .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 CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 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 HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4118 15160 9639 22085 4118 15160 FCNT MWD CNTS 579.1 4722.9 1140.59 13485 4140 10882 NCNT MWD CNTS 138765 241516 177666 13485 4140 10882 RHOB MWD G/CM 1.19 3.479 2.14048 13469 4148 10882 DRHO MWD G/CM -0.202 1.125 0.0608212 13469 4148 10882 RPD MWD OHMM 4.06 2000 25.4092 21941 4140 15110 RPM MWD OHMM 5.64 2000 22.6563 21941 4140 15110 RPS MWD OHMM 4.96 2000 20.4329 21941 4140 15110 RPX MWD OHMM 4.62 2000 17.9489 21941 4140 15110 FET MWD HOUR 0.05 157.53 1.4927 21941 4140 15110 GR MWD API 20.62 130.49 69.1321 21971 4118 15103 PEF MWD BARN 0.54 7.63 2.07431 13469 4148 10882 ROP MWD FT/H 0.52 6123.13 251.803 22014 4153.5 15160 NPHI MWD PU-S 2.65 113.19 35.7742 13485 4140 10882 First Reading For Entire File..........4118 Last Reading For Entire File...........15160 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 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.......06/08/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 • Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4118.0 7881.5 FET 4140.0 7874.0 NCNT 4140.0 7822.5 FONT 4140.0 7822.5 NPHI 4140.0 7822.5 RPS 4140.0 7874.0 RPD 4140.0 7874.0 RPX 4140.0 7874.0 RPM 4140.0 7874.0 PEF 4148.0 7840.0 RHOB 4148.0 7840.0 DRHO 4148.0 7840.0 ROP 4153.5 7917.0 LOG HEADER DATA DATE LOGGED: 19-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7917.0 TOP LOG INTERVAL (FT) 4153.0 BOTTOM LOG INTERVAL (FT) 7917.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 75.6 MAXIMUM ANGLE: 78.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 78633 CTN COMP THERMAL NEUTRON 158416 ALD Azimuth. Litho-Den 10718128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 4151.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 49.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 450 FLUID LOSS (C3) 5.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.400 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.860 94.6 MUD FILTRATE AT MT: 2.400 72.0 MUD CAKE AT MT: 2.600 72.0 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 MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4118 7917 6017.5 7599 4118 7917 FCNT MWD030 CNTS 579.1 1997.19 1157.39 7366 4140 7822.5 NCNT MWD030 CNTS 138765 207040 180825 7366 4140 7822.5 RHOB MWD030 G/CM 1.277 2.896 2.08364 7385 4148 7840 DRHO MWD030 G/CM -0.202 0.369 0.0396574 7385 4148 7840 RPD MWD030 OHMM 4.06 2000 14.8129 7469 4140 7874 RPM MWD030 OHMM 5.74 2000 13.1623 7469 4140 7874 RPS MWD030 OHMM 4.96 2000 12.1485 7469 4140 7874 RPX MWD030 OHMM 4.62 26.85 10.4872 7469 4140 7874 FET MWD030 HOUR 0.05 106.87 0.850691 7469 4140 7874 GR MWD030 API 21.03 130.49 65.2802 7528 4118 7881.5 PEF MWD030 BARN 0.54 7.63 2.0227 7385 4148 7840 ROP MWD030 FT/H 2.24 1341.96 397.957 7528 4153.5 7917 NPHI MWD030 PU-S 13.48 113.19 38.7321 7366 4140 7822.5 First Reading For Entire File..........4118 Last Reading For Entire File...........7917 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 • Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 7823.0 NPHI 7823.0 FCNT 7823.0 PEF 7840.5 RHOB 7840.5 DRHO 7840.5 RPD 7874.5 RPX 7874.5 RPS 7874.5 FET 7874.5 RPM 7874.5 GR 7882.0 ROP 7917.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD STOP DEPTH 10882.0 10882.0 10882.0 10882.0 10882.0 10882.0 10882.0 10882.0 10882.0 10882.0 10882.0 10882.0 10882.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuth. Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 24-JUL-06 Insite 66.37 Memory 10882.0 7917.0 10882.0 74.8 78.5 TOOL NUMBER 216261 116184 2809199881343015 10718130 12.250 4151.0 Other 9.05 66.0 MUD PH: • 9.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.200 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.830 91.4 MUD FILTRATE AT MT: 2.050 75.0 MUD CAKE AT MT: 2.400 75.0 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 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOB MWD040 G/CM 4 1 68 12 4 DRHO MWD040 G/CM 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MWD040 FT/H 4 1 68 48 13 NPHI MWD040 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7823 10882 9352.5 6119 7823 10882 FCNT MWD040 CNTS 633.05 4722.9 1120.38 6119 7823 10882 NCNT MWD040 CNTS 145920 241516 173863 6119 7823 10882 RHOB MWD040 G/CM 1.19 3.479 2.20947 6084 7840.5 10882 DRHO MWD040 G/CM -0.095 1.125 0.0865107 6084 7840.5 10882 RPD MWD040 OHMM 5.82 837.32 28.2226 6016 7874.5 10882 RPM MWD040 OHMM 5.64 985.27 24.2288 6016 7874.5 10882 RPS MWD040 OHMM 5.22 169.49 18.0404 6016 7874.5 10882 RPX MWD040 OHMM 4.7 90.94 12.9329 6016 7874.5 10882 FET MWD040 HOUR 0.17 52.59 2.56748 6016 7874.5 10882 GR MWD040 API 20.62 120.71 72.7933 6001 7882 10882 PEF MWD040 BARN 0.62 4.66 2.13695 6084 7840.5 10882 ROP MWD040 FT/H 0.8 2168.58 198.067 5930 7917.5 10882 NPHI MWD040 PU-S 2.65 73.21 32.2136 6119 7823 10882 First Reading For Entire Fi~.........7823 Last Reading For Entire File...........10882 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 10882.5 12383.5 GR 10882.5 12325.0 FET 10882.5 12332.5 RPX 10882.5 12332.5 RPS 10882.5 12332.5 RPM 10882.5 12332.5 RPD 10882.5 12332.5 LOG HEADER DATA DATE LOGGED: 01-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12383.0 TOP LOG INTERVAL (FT) 10882.0 BOTTOM LOG INTERVAL (FT) 12383.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.6 MAXIMUM ANGLE: 94.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 17851 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 10856.0 • BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Mineral Oil Base 8.80 75.0 .0 23000 3.0 .000 .0 .000 107.4 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10882.5 12383.5 11633 3003 10882.5 12383.5 RPD MWD050 OHMM 14.88 64.06 31.6637 2901 10882.5 12332.5 RPM MWD050 OHMM 13.51 64.05 29.8627 2901 10882.5 12332.5 RPS MWD050 OHMM 12.35 67.32 29.2755 2901 10882.5 12332.5 RPX MWD050 OHMM 11.27 59.55 27.8795 2901 10882.5 12332.5 FET MWD050 HOUR 0.23 157.53 0.905233 2901 10882.5 12332.5 GR MWD050 API 43.69 92.2 63.565 2886 10882.5 12325 ROP MWD050 FT/H 0.52 654.84 168.678 3003 10882.5 12383.5 First Reading For Entire File..........10882.5 Last Reading For Entire File...........12383.5 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number..........~0.0 • Date of Generation.......06/08/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12325.5 15103.0 RPS 12333.0 15110.0 FET 12333.0 15110.0 RPX 12333.0 15110.0 RPM 12333.0 15110.0 RPD 12333.0 15110.0 ROP 12384.0 15160.0 LOG HEADER DATA DATE LOGGED: 04-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15160.0 TOP LOG INTERVAL (FT) 12383.0 BOTTOM LOG INTERVAL (FT) 15160.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.4 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 17851 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 10856.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 71.0 MUD PH: .0 MUD CHLORIDES (PPM): 19000 ~ • FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 115.1 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .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 MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12325.5 15160 13742.8 5670 12325.5 15160 RPD MWD060 OHMM 7.59 105.35 33.3432 5555 12333 15110 RPM MWD060 OHMM 7.09 128.66 29.955 5555 12333 15110 RPS MWD060 OHMM 6.71 2000 29.5449 5555 12333 15110 RPX MWD060 OHMM 6.37 2000 28.2275 5555 12333 15110 FET MWD060 HOUR 0.21 42.53 1.49873 5555 12333 15110 GR MWD060 API 43.57 123.26 73.2884 5556 12325.5 15103 ROP MWD060 FT/H 1.21 6123.13 156.005 5553 12384 15160 First Reading For Entire File..........12325.5 Last Reading For Entire File...........15160 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 • Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/14 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/08/14 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................ST5 LIS Writing Library Physical EOF Physical EOF • Scientific Technical Services Scientific Technical Services End Of LIS File
