Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
207-131
Image Project llllell History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~ - ~ .~ ~ Well History File Identifier Organizing (done) o..o=aee uiiumiuiiiiiii a.~,~~.a uiumi~iuiiiu RE CAN DIG TAL DATA OVERSIZED (Scannable) olor Items: Diskettes, No. ~ ^ Maps: l G ~ ~~`~ reysca e Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ 0 /s/ Project Proofing ~~~~~~~~~~~~~~ ~~~~~ BY: Maria Date: 1 ~ /s/ i P S ti ~ ~ ~ =TOTAL PAGES U + ng cann repara on x 30 = 1 ~ ~ (Count does not include cover sheet) ~ BY: Maria Date: ~ ~ ~~ /s/ ~ Production Scanning Stage 1 Page Count from Scanned File: -~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: E~ YES NO BY: _ Maria Date:' ~/C./ ~ /s/ ~/ I Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'I II I II II I (III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III'l) III III 10/6/2005 Well History File Cover Page.doc '~ "~~ ` ~;~~.' ,, .'" w ~ t ~~~ ~... ~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ' C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc # i 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: 3A-03B May 27, 2009 AK-MW-5373121 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 3A-03B 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 50-029-21432-02 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 50-029-21432-02 Digital Log Images 1 CD Rom 50-029-21432-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 ?~ liburton.com ~~, ~~~~~~ ~, Date: i9 ~ s. C,or~riission Anore ~,, ~; ~i Signed: ~' 1 ~ ~~ • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • ~~ `~II4 ~car«~ 4 ~ ~~ t April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~, +r n ~ ~+ ~~~~ v ~ ~ I ~f (~-~~ 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 March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry K~1~einr ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off ..~. s Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-03B 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 ~ 185-237 16' 2.50 25" 3/27/2009 5.95 4/6/2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 3A-03B Plan Forward • Maunder, Thomas E (DOA} Page 1 of 2 From: Gober, Howard [Howard.Gober~conocophillips.com] Sent: Friday, December 14, 2007 3:51 PM To: Maunder, Thomas E (DOA) Cc: Martin, Michael W(Schlumberger Oilfield Services); NSK WeU Integrity Proj; Allsup-Drake, Sharon K; Schwartz, Guy L; CPA Wells Supt; Senden, R. Tyler Subject: 3A-036 Plan Forward a~ `~ - ~~ ~ Tom, I just wanted to recap the discussion with you, Perry Klein, and myself today regarding 3A-036. Here is our plan forward: o Perforate the Kuparuk A sand o Fracture stimulate the A sand. The liner top packer leaks intermittently, but we should be able to maintain backside pressure during the frac. o Perform apost-frac CTU FCO o Produce the well for 2-3 weeks to clean up. This wiN be done without gas lift. o MIRU Nordic 3 to pull the tubing, set the existing liner hanger and liner top packer, and stack a hanger and packer on top. We will then run 2-718" production tubing to complete the well. o Put well on production o All operations will be reported on the 10-407 for 3A-036. Since we will report the operations under the 10-407, I will not submit a 10-403 for the workover. I believe this reflects what we discussed. If you see any problems, please let me know. Otherwise, we will proceed as planned. I appreciate your help today. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard. Gober@conocoph fillips. com From: Gober, Howard Sent: Friday, December 14, 2007 11:24 AM To: Thomas Maunder' Subject: 3A-036 071004 Window 7 ind~ tongstring Schematic.pdf « File: 3A-03B 071004 Window 7 inch Longstring Schematic.pdf» Tom, 4/21 /2009 3A-03B Plan Forward • Page 2 of 2 I was calling about this well when I called earlier. I just wanted you to have this schematic handy when we speak. Also to answer the question about 1 C-06. I messed up. This should be a WAG well not a water injector. The purpose of the workover was to get it back in shape for MI injection. Do we need to resubmit the 10-404? Thanks, Howard 4/21 /2009 3A-03B 071004 Window 7 ine~ngstring Schematic.pdf Page 1 of 1 Maunder, Thomas E (DOA) From: Gober, Howard [Howard.Gober@conocophillips.com] Sent: Friday, December 14, 2007 11:24 AM To: Maunder, Thomas E (DOA) Subject: 3A-038 071004 Window 7 inch Longstring Schematic.pdf Attachments: 3A-038 071004 Window 7 inch Longstring Schematic.pdf «3A-03B 071004 Window 7 inch Longstring Schematic.pdf» Tom, I was calling about this well when I called earlier. I just wanted you to have this schematic handy when we speak. Also to answer the question about 1 C-06. I messed up. This should be a WAG well not a water injector. The purpose of the warkover was to get it back in shape for MI injection. Do we need to resubmit the 10-404? Thanks, Howard 4/21/2009 • 3A-036 070924 Window 7 inch Longstring Schematic 3A-03B SIDETRACK / Longstring COMPLETION wp03 ConocoPhillips Circulate corrosion inhibitor before landing Original completion RKB 73' from mean sea tubing hanger. Inhibit corrosion up to bottom level (PAD 42'. 31' RIG AIR GAP) GLM. 3'/z" FMC Gen 4(converted in 511999 workover) Tubing Hanger, 3 Yz" L-80 IBT Mod 9-5/8" x 7" annulus pin down arctic packed 9/22/ 3'/z" 9.3# L-80 IBT Mod Spaceout Pups as Required 1985 w/ 47 bbls cmt 3'/z" 9.3# L-80 IBT Mod Tubing & 65 bbls diesel. sssv 3'/z" Camco SCSSSV TRMAXX-5E with 2.812 `X' Profile Nipple Bore set at +/- 2246' MD/ 2000' TVD 3'/z" x 6' L-80 handling pups installed above and below, IBT Mod 3'/z" 9.3# L-80 IBT Mod tubing 3'/z" x 1" Camco'KBG-2- 9' mandrels 9-5/8" 36# J-55 3'/z" x 6' L-80 handling pups installed above and below, IBT Mod BTC casing 3'/z" x 1" Camco'KBG-2- 9' mandrel w/ shear valve, pinned for 2000 psi shear Set @ 3888' MD / casin to tubin differential 3'/z" x 6' L-80 handlin 3098' TVD ( 9 9 ), g pups installed above and tor~ymai toT iz s vv9 eraw~ below, IBT Mod GLM # TVD-RKB MD-RKB 1 2450 2910 2 3700 4729 3 4600 5932 4 5300 6868 5.5" X 7" Liner Top 5 5847 -7589 (2 its above ao ckerl TOBE@ - 3884' MD / 3094' TVD Sidetrack KOP w/ window in 7" @ 4084' MD / 3226' TVD -~> Whipstock F~S~u Orientation to be 45 ~s2~ .. degrees from high side .; 3'/z" nipple w/ 2.75" "X" profile 1 full joint below packer assembly. '~ 1 joint 3'/z" L-80 EUE 8rd Mod installed above, 3'/z" x 10' handling pup installed below `x::x~s '~' Baker "K-1" CIBP y ~, :<< 3, below set point for 5 '/z" oacker assembly (a7 7649' whipstock @ MD / 5897' TVD (200' b A ' +/- 4109' MD a o ve 111D T~ D Formations sandl: it ft SABL-3 packer O.CO base Permafrost 1 jt tubing 0.00 Top Ugnu 2.75" X profile 0.00 Top'JVest Sak 3-1 i2" tbg cut and ~. 10' pup 0.00 Base ~,mest Sak pulled from +/- xxxx' WLEG 724250 5579.60 Top HRZ \ 7435.80 5724.60 Top Kalubik above the packer. Top 7567.40 5828.60 Top lower Kalubik (K1) of cmt P&A plug cr ~ °' ~ 7640.Oe 5888.60 TOR KUDaruk D xxxx ~ 7672.04 5415.60 Top Kuparuk C ~~ 7732.77 5467.60 Kuparuk B " 7849.39 6068.60 Kuparuk .A3 CT Liner top PKR 7882.88 6097.fi0 Kuparuk A2 7105' MD 5'/z" liner Assembly: 7479.88 6181.60 Miluveach 5-1/2" 15.5# Hydril 511 Liner shoe @ 8138' MD / 6318' TVD LWD Loaaina: 6- 1/8" hole: GR/RES/ NEU /DEN/ PWD PKR 7680' MD 5'/z" Centrilization: 5-19/32" x 6-1/8" rigid stand off Ooen Hole Loaaina: band between stop collars NONE Original Wellbore 1 perjoint BHP Est.: 7.0" csg 26.0# J-55 BTC @ C sand: 9.1 - 11.1 ppg EMW 8371' MD ~ A sand: 10.1 - 10.8 ppg EMW 8138' MD / 6318' TVD 10.6 ppg likely top EMW for C & A TOC est. 6900' MD JAB 8123/07 DATA SUBMITTAL COMPLIANCE REPORT 12/3/2008 Permit to Drill 2071310 Well Name/No. KUPARUK RIV UNIT 3A-03B MD 8285 TVD 6444 Completion Date 11/16/2007 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR / RES Well Log Information: Log/ Electr Data Digital Dataset Tae Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH I Scale Media No Start Stop CH Received Comments YED D Asc Directional Survey pt Directional Survey ~g Cement Evaluation /1'D C Las 15839/Leak W"N~ LIS Verification D C Lis 15970 eduction/Resistivity I'I D C Las 16088 Leak 28 8285 Open 12/18/2007 28 8285 Open 12/18/2007 5 Col 7594 8146 Case 12/21/2007 CBL, SCMT-CB, Temp, ~ Pres 1-Dec-2007 3759 4001 Case 1/16/2008 LAS, LDL, Temp, CCL w/PDF and TIF graphics 4085 8285 Case 2/29/2008 Lis Veri, FCNT, NCNT, RHOS, DRHO, RPD, RPM, RPS, RPX, FET, GR, ROP, NPHI 4085 8285 Case 2/29/2008 LIS Veri, FCNT, NCNT, RHOS, DRHO, RPD, RPM, RPS, RPX, FET, GR, ROP, NPHI 11 7714 Case 4/9/2008 LDL, Temp, CCL w/PDF graphics Well Cores/Samples Information: Interval Name Start Stop ADDITIONAL INFOR~ION Well Cored? Y Chips Received? ~, Analysis 4~!-Fl~ Received? Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21432-02-00 Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Survey Sample Set Sent Received Number Comments Daily History Received? l./N Formation Tops DATA SUBMITTAL COMPLIANCE REPORT 12/3/2008 Permit to Drill 2071310 Well Name/No. KUPARUK RIV UNIT 3A-03B Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21432-02-00 MD 8285 TVD 6444 Completion Date 11/16/2007 Completion Status 1-OIL Current Status 1-OIL UIC N Comments: Compliance Reviewed By: ._. Date: 6 0~ ~~ • ~jUR ? c STATE OF ALASKA ~ LG~~ ALASKA OIL AND GAS CONSERVATION COMMISSIO ,,,,, ~~~ ~IJ'1~ ~0~~1e~8j00 REPORT OF SUNDRY WELL OPERA~~C ~r~rr:,.,r~P4.., 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate Q Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhlllips Alaska, InC. Development ^~ Exploratory ^ 207-131 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21432-02 7. KB Elevation (ft): 9. Well Name and Number: RKB 69'; 41' AMSL 3A-036 8. Property Designation: 10. Field/Pool(s): ADL 2563', 25632 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8285' ' feet true vertical 6444' feet Plugs (measured) Effective Depth measured 8047' feet Junk (measured) 7800' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 106' 16" 106' 106' SURFACE 3888' 9-5/8" 3888' 3098' INTERMEDIATE 4104' 7" 4104' 3240' LINER 4372' 5.5" 8285' 6444' Perforation depth: Measured depth: 7930'-7995' true vertical depth: 6132'-6189' Tubing (size, grade, and measured depth) 3.5", L-80, 7723' MD. Packers &SSSV (type & measured depth) Baker SABL-3 pkr @ 7661' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 260 652 422 135 Subsequent to operation 236 357 336 - 112 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Group Engineer / Signature Phone: 265-6471 ~ ~~~ Date / ~ ~~ Pre ared b Sharon Allsu Drake 263-4612 Form 10-404 Revised 04/2006 ~ ~,~ ~ ~ ~ S~~ ~ ~ Submit Origin I Only • 3A-03B Well Events Summary .DATE , SUMMARY 5/21/08 PERFORATED 7930'-7974' (A3/A4 SANDS) WITH 2-1/2" POWERJET, 6-SPF, 60-DEG PHASING. 5/24/08 TAGGED @ 8047' SLM; BOTTOM PERF @ 7995' RKB. COMPLETE. SEL'6 (Eo-vE) 01 awn s's v MOONIM NOIlONO e MOONIM If8'f'OX aZa'E LZB'£ 'N30NVN »Haed iaeueN +a~n ~wws ELe'E 'N3NOtld 689'f 'N3NOVd yuawWOO ayep leWl W4S auoZ aanl ~ (AL) uu48 IOAU dol l9)1N1 u4818%41 Doll ~ ~... ~ ' ~- 30vdans eS0'f ldn sv~ sszz 'nsss W181 08-1I0E~6 CZS6'S O'S4Z'£ O'SOL'4 0'660'4 OOS'4 Z/L S 8 MOONIM ~ y LIS IPP~FI 08-l OS'Sl 6'£46'9 O'S8Z'8 £'8L9'£ OS6'a Z/LS ~au!~.S'S ~:'' az N30NVH iaiped Z'OZL'E O'ZZ6'E 6'L68'£ 008'4 ZL'9 raBuea~aw~~aipeLS 018 SS-f 00'9Z L'4L0'9 O'46L'L 0'0 LSL'9 L NOLLOf100ad 018 SS-f 00'9£ 9'960'£ 0'888'£ 0'0 59L'B 8/S6 30tldaflS PaPIaM 04-H OS'Z9 O'90L O'90l 0'0 Z90'SL 9L aOlOf10N00 Pew4l dol apufl (4/x911 iN11eN4110N14yda0 NS ISN4141da0laS ISN41 dol lull Ol (u1100 uo!ydP~OBulasO _..... __.. ^qi..''. 800Z/6L/9 ~) _ -_-- -Otll'Sda3d OOtl:uoseaa naa 800U4Z/S O'L40'8 :Bel ise~ aiep Pu3 uolysyouutl ase0 Pu3 le>+ul 4P1a0 ucPewuW_ S861/9L/6 6Z'SE 800Z/4LIZ ~OMysel wda. k..-^= s~,~: ~" _ crisp asealaa e!8 141 Wfl'8N au0 Pu3 uaRiouW aK0 Iwddl SZH Waluu+o:1 _ 0 S£L 6 8E'4S Goad 11N(1 a3nla NflaVdflN ZOZ£4LZ6ZOOS (8N4141daO leiol~ IJ u i u4aul wnwneW ar4eyg IIaM au+eN PPId IMMd1/ aio411aM 'f ! x:, ._ "` - ~ 5t~fi(~IL~tI~UI~ 1 ~ ~' so-dE dn~~ ~ ,. _.~-; ~V~~ ~ _ T°R~4/USi~/I/7`J`AL ProActive Diagnostic Services, Inc. To: AOGCC Chiristine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1 j Leak Detection - WLD 02 Apr-08 3A-03B EDE 50-029-21432-02 2) Signed Print Name: lo.'~ r~~~ o ~/ !/ !~./~ ~O~ ~--~ 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 : -bra _~~ .~?:++I3e, .~''^a ,,~.: t'~,.a....~ WEBSITE PPJ'?f. ?i`i ~=1.~'~~;'1 C'\Documents and Settings\Owner\Desktop\Tmnsmit_Conoco.doc 3A-03B (PTD 2071310) Report of TxIA communication • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, March 15, 2008 2:09 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA} ~ ~~ ~~~~~~' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 3A-03B (PTD 2071310) Report of TxIA communication Attachments: 3A-03B schematic.pdf; 3A-03B 90 day TIO plot.jpg Tom & Jim, Gas lifted producer 3A-03B (PTD 20713T0) failed a diagnostic TIFL on 03/12/08 and has been added to the weekly SCP report. The TIO was 170/1220/150 prior to the well being shut-in. A leakin~c GLV is suspected since the MITIA passed to / 2500 psi prior to the well coming on line after the RWO. Slickline will troubleshoot the leak and repair if possible. Attached is a 90 day TIO plot and schematic. «3A-03B schematic.pdf» «3A-03B 90 day T~ plot.jpg» Please let me know if you have any questions. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 3/18/2008 ~v~-13 I KRU 3A-03B PTD 207-131 T/I/~ Plot - 3A-0~~3 1200 1000 $00 a- 600 400 X00 t ............................................................~.....~.. ..............................................,......................... ~ 0 ~ ~~ 15-arc-07 L$-aec-0? 10-Jan-08 23-J~r~-0$ 05-Fed-08 ~-~te 18-Feb-08 OZ-Maur-Q8 200 150 a E as 100 ~ ac 0 s 50 0 T.~ ,~. Z Cc+nac©Phllips Aiaska, tn~. 3A-038 '.:-------- TUBING C (o-7s5a, ~' OD:3.500, ID:2.992) t ¢~~ ~~ '~, t `~ ~ ,~ ;~ KRU 3A-03B Hf'I: 50U2y2 i4.i20z Well T e: PROD An le ~u l S: 3i de ~ 7747 SSSV Type: TRDP Orig Com letion: i 1/16/2007 Angle @ TD: 28 deg @ 8285 Annular Fluid: Last W/O: 2/14/2008 Rev Reason: GLV C/O, FISH, PULL PLUG Reference L 24' RKB Ref L Date: Last U date: 2/25/2008 Last Ta TD: 8285 ftK6 I act Tai Date' Max HnIP AnnlP• 54 dw1 x14161 ¢`~ ~~ Casing String -ALL STRINGS I' :3 Desch tlon Size To Bottom TVD Wt Grade Thread :~~~~;i . n'~ . ' „ WINDOW 5.500 4104 4105 3241 0.00 'RODUCTION TOP (OA200, OD:7.000, Wt26.00) k; ,:.~ ,` " - - . ~ 'i~ rE,' - E I ~ ANCHOR ~ (7660-7661, _ OD:4.500) E' TUBING _ (765&7723, OD:3.500, r... ' i ID:2.992) I --- LINER • - - -..- (3913-8285, _ .. __ ~ WL 15.50) CONDUCTOR 16.000 0 106 106 62.50 H-40 WELDED SURFACE 9.625 0 3888 3097 36.00 J-55 BTC PRODUCTION TOP 7.000 0 4200 3300 26.00 J-55 BTC LINER 5.500 3913 8285 8285 15.50 L-80 HYD 511 Tubtrtg String -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 7658 5898 9.30 L-80 IBTM 3.500 7658 7723 5953 9.30 L-80 IBTM Perforations Summary Int?rvaf TVt1 ~ Zone ~ Status ~ Ft ~ SPF Date ~ T/pe Comment ~y5 ~~171 r,I~t1 -~ 'U r, l.'-l ~i,ii- II'~P,F ~ ~ H.I 6n d ~ r-x~~lrm~ Stimulations $ Treatments _ Interval Date Type Comment i)5 1_ ~I'I~w i; i~ : ~ ~ PJD FP,AS PUP/1PEC~ ~ _ '~, ~ )F 1F~~ I r ,RBU LITE -~/~r1D Gas Lift Mandrels/Valves SI MU I VU M8n MTr Man I ype V MTr v I ype V UU LatCh Ndrt IRO Date RUn VIV Cmnt 1 3056 2546 CAMCO KBG-2-9 GLV 1.0 BTM 0.125 1280 2/23/2008 2 4818 3694 CAMCO KBG-2-9 GLV 1.0 BTM 0.250 1310 2/22/2008 3 6122 4699 CAMCO KBG-2-9 GLV 1.0 BTM 0.188 1335 2/21/2008 4 7112 5465 CAMCO KBG-2-9 OV 1.0 BTM 0.250 0 2/21/2008 5 7596 5846 CAMCn KRG-7-9 DMY 1.0 RTM n Ono 0 7/9r1/9nnR Other (plugs, equip., etc.) -COMPLETION De th TVD T e Descri Lon IG 24 24 HANGER FMC GEN IV TUBING HANGER set 2/14/2008 2.992 2265 2013 SSSV CAMCO TRMAXX-5E SSSV set 2/14/2008 2.812 3898 3103 PACKER LINER TOP PACKER CPH C-2 PROFILE set 2/14/2008 TO REPAIR LINER PACKER LEAK 3913' 4.826 3913 3113 PACKER LINER CPH C-2 PROFILE LINER TOP PACKER 5.500 3922 3119 HANGER LINER HMC HANGER set 2/4/2008 4.826 3924 3120 HANGER LINER HMC HANGER 4.960 3931 3125 XO LINER CROSSOVER PUP 4.800 7646 5888 PBR BAKER OIL TOOL 80-40 PBR 3.000 7660 5899 ANCHOR BAKER OIL TOOL KBH-22 40FA36 ANCHOR 2.970 7661 5900 PACKER BAKER OIL TOOL SABL-3 PACKER 2.760 750 Fish -FISH LJ GUIDE Comment ConocoPhillips Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 March 3, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 REDEI\/'ED MAR 0 4 2008 /i~k~t 0~ ~ Gals Cons. Commission ~,.~ ~ Subject: Well Completion Report for 3A-03B Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 3A-03B. If you have any questions regarding this matter, please contact me at 265-6830 or Jason Brink at 265-6419. Sincerely, ~ \ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad 3~ ,~.\ ~~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEI~/EC~ MAR 0 4 2008 WELL COMPLETION OR RECOMPLETION REPO~~~Q1,~Q~,~~ 1a. Well Status: Oil ^/ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: ~~p Development ' "L~lcploPatory ^ Service ^ Stratigrephic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: November 16, 2007 ~ 12. Permit to Drill Number: 207-131 / ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: November 4, 2007 13. API Number: 50-029-21432-02 4a. Location of Well (Governmental Section): Surface: 52T FSL, 749' FEL, Sec. 7, T12N, R9E, UM 7. Date TD Reached: November 12, 2007 14. Well Name and Number: 3A-036 Top of Productive Horizon: 1273' FSL, 652' FEL, Sec. 18, T12N, R9E, UM 8. KB (ft above MSl_): 68.6' RKB - Ground (ft MSL): ~`` 41' AMSL ~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 1015' FSL, 679' FEL, Sec. 18, T12N, R9E, UM 9. Plug Back Depth (MD + ND): 8164' MD / 6337' TVD Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 507699 y- 5996908 ~ Zone- 4 10. Total Depth (MD + ND): ~ 8285' MD /6444' TVD ' 16. Property Designation: ALK 25631,•25632 TPI: x- 507818 y- 5992375 Zone- 4 Total Depth: x- 507791 - 5992117 Zone- 4 11. SSSV Depth (MD + ND): SSSV @ 2263' MD / 2012' TVD 17. Land Use Permit: 2564, 2565 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1900' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @ 4104' AVM $ L O GR/RES ~ .~. 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE T AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMEN ING RECORD PULLED 16" 62.5# H-40 41' 106' 41' 106' 24" 187 sx AS II 9-5/8" 36# J-55 41' 3888' 41' 3098' 12.25" 1200 sx AS III & 320 sx Class G 7" 26# J-55 41' 4104' 41' 3240' 8.5" 425 sx Class G & 25o sx Class G 5.5" 15.5# L-80 3913' 8285' 3111' 6444' 7" 79 sx LiteCRETE, 125 sx Class G w/GASBLOK 23. Open to production or injection? Yes ~ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 7723' 3898', 7661' 7975'-7995' MD 6171'-6189' ND 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7975'-7995' pumped 292767# of 16/20 carbolite 26. PRODUCTION TEST Date First Production January 23, 2008 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil Date of Test 1/23/2008 Hours Tested 44 hours Production for Test Period -> OIL-BBL 25 GAS-MCF 62 WATER-BBL 1674 CHOKE SIZE 136 Bean GAS-OIL RATIO 2740 Flow Tubing press. 118 psi Casing Pressure 1376 Calculated 24-Hour Rate -> OIL-BBL 13 GAS-MCF 34 WATER-BBL 898 OIL GRAVITY -API (corr) 22.5 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ~ Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ,~ ~ ~( j~ Cfi"s"Ir b NONE ~~' ' ~Ii'~I Form 10-407 Revised 2/2007 ~ ~O~INUED N RE SE 3 • $~•(Df~ 28. GEOLOGIC MARKERS (List all formations and ers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 2100' 1900' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 7747' 5973' Kuparuk A 7919' 6122' N/A Formation at total depth: Kuparuk C 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: JaSOn Brink @ 265-6419 Printed Nam Rand Thomas Title: Drillino Team Leader 2' f~(~? '~ Signature Phone -~S G.~ 3 ~ Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2!2007 .`-~ ~ KRU 3A-03B GvnoCt~Phl~lipS At~l~tea, Inc. - ~3A-03S ` --- -- -- - - API: - - 500292143202 Well T e: -- - PROD An le TS: 31 de 7747 TUBING SSSV Type: TRDP Orig 11/16/2007 Angle @ TD: 28 deg @ 8285 (a765e, oD:3.soo, ~ Com letion: 1o:2.ss2) Annu)ar Fluid: Last W/O: 2/14/2008 Rev Reason: WORKOVER-FIX PRODUCTION TOP (0-4200, OD:7.000, Wt:26.00) ANCHOR (766a7661, OD:4.500) TUBING (7658-7723, OD:3.500, ID:2.992) LINER (3913285, OD:5.500, Wt:15.50) LINER PKR LEAK Reference Lo : 24' RKB Ref Lo Date: Last U date: 2/18/2008 Last Ta TD: 8285 ftKB Last Tag C>ate• Max Hol? An~la: 54 dPg (a~ 4161 Casing String -ALL STRINGS ~~ Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 106 106 62.50 H-40 WELDED SURFACE 9.625 0 3888 3097 36.00 J-55 BTC PRODUCTION TOP 7.000 0 4200 3300 26.00 J-55 BTC LINER 5.500 3913 8285 8285 15.50 L-80 HYD 511 WINDOW 5.500 4104 4105 32_41 0.00 _ TubinQString -TUBING __ Size To Bottom TVD Wt Grade Thread 3.500 0 7658 5898 9.30 L-80 IBTM 3-500 _7658 7723_ _ _ 5953 9.30 L-8.0 IBTM Perforations Summary _ Imerval TVD Zone Status Ft ' SPF Date Type " Commem 7975- 7995 6171 - E,189 A 2 -__ 20 6 1224/2 - 007 IPEP,F 2-5 H J. 60 ~ieg random Stimulations 8 Treatments Interval Date Type Comment 7975- 7995 7228/2007 A- SAND FRAC PUMPED 292,767# OF 16/20 CARBOLI TE SAND __ ___ Gas Lift MandrPlsNalves i St MD TVD Man Mir Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3056 2546 CAMCO KBG-2-9 DMY 1.0 BK-5 0.000 0 2/14/2008 2 4818 3694 CAMCO KBG-2-9 DMY 1.0 BTM 0.000 0 2/14/2008 3 6122 4699 CAMCO KBG-2-9 DMY 1.0 BTM 0.000 0 2/14/20D8 4 7112 5465 CAMCO KBG-2-9 DMY 1.0 BTM 0.000 0 2/14/2008 5 7596 5846 CAMCO KBG-2-9 SOV 1.0 BTM 0.000 0 2/15/2008 Other plugs @ Ui etC.) - GOMPLETIQN ' De th TVD T e _ Descri lion ID 24 24 HANGER FMC GEN IV TUBING HANGER set 2/14/2008 2.992 2265 2013 SSSV CAMCO TRMAXX-5E SSSV set 2/14/2008 2.812 3898 3103 PACKER LINER TOP PACKER CPH C-2 PROFILE set 2/14/2008 TO REPAIR LINER 4.826 PACKER LEAK 3913' 3913 3113 PACKER LINER CPH C-2 PROFILE LINER TOP PACKER 5.500 3922 3119 HANGER LINER HMC HANGER set 2/4/2008 4.826 (,` r €~' 7711 5943 PLUG PXX PLUG w/PX PRONG set 2/2/2008 0.000 7723 5953 WLEG WIRELINE GUIDE 2.750 8165 6338 COLLAR BAKER LANDING COLLAR w/PLUG 0.000 8245 6408 COLLAR DAVIS LYNCH AUTO-FILL LINER FLOAT COLLAR 4.800 8283 6442 SHOE DAVIS LYNCH TYPE 601 LINER GUIDE SHOE 4.800 COLLAR (8245-8246, OD:5.500) ~~ Time Logs __ __ Date From To Dur S. De th E. De th Phase Code Subcode T COM ~ 11/03/2007 04:15 11:15 7.00 MIRU _ RPCOh RCST P _ Monitor well -static. PJSM with crews - install stripping rubber catcher. Pull 3-1 /2" completion out of hole - LD 198 Jts, 2 pup jts, 3 GLM's, DB Npl, and 1 cut jt = 6.73' long. (6,287.89' total) NORM tree & tubing & ck'd ok. ** Tested new 4" Dart valve to 250 psi low and 3500 si hi h. ** 11:15 12:00 0.75 MIRU RPCOh RURD P RD Csg equip. Clean and clear rig floor 12:00 13:00 1.00 MIRU RPCOh RURD P Continue cleaning rig floor and unload the ulled 3-1/2" tb out of i eshed. 13:00 14:00 1.00 MIRU CASIN( OTHR P Install wear ring -Spot GeoSpan on rig floor -Monitor well -Static. 14:00 19:15 5.25 MIRU CASIN OTHR P PJSM - MU tri cone bit and 7" casing scraper. Single in hole PU 4" DP from shed (Fill DP @ 2,820' MD). Break circ @ 5,720' MD. Picked up a total of 183 jts. PU Wt 105k, SO Wt 80k, Rot Wt 92k, Tr 3k. 19:15 19:45 0.50 MIRU CASIN( CIRC P CBU at 5,720' MD. Pumped at 320 GPM, 850 si. Monitor well -static. 19:45 21:30 1.75 MIRU CASIN OTHR P POOH from 5,720' MD and LD Bit and scraper. Monitor well -static. Calculated tri dis lacement correct. 21:30 22:00 0.50 MIRU CASIN RURD P Pull wear ring -clear floor. 22:00 22:15 0.25 MIRU EVAL SFTY P PJSM with Baker, SLB wireline, and crew. Discuss RU procedure and hazards. 22:15 23:00 0.75 MIRU EVAL1l~ RURD P RU SLB equipment on rig floor. 23:00 00:00 1.00 MIRU EVAL11~ ELOG P RIH with Baker CIBP on SLB wireline - Monitorwell on tri tank. 11/04/2007 00:00 01:15 1.25 0 MIRU EVALW ELOG P Continue RIH with CIBP on SLB Eline -Monitor well on Trip Tank. Coorelated log with GR and CCL -Set CIBP 5' above collar at 4,116' MD. (40' Jt). POOH RD Eline. 01:15 02:00 0.75 MIRU EVAL1Ib DHEO P RU Test Csg and CIBP to 3000 psi for 15 min. Had to repeat test due to sensor failure. *Daylight savings time - Actual duration was 1.75 hrs* 02:00 04:00 2.00 MIRU WELCT NUND P PJSM - ND BOPE & FMC Tbg Head. Depressurized and removed old ackoffs. 04:00 05:00 1.00 MIRU WELC OTHR P MU Baker spear assembly -Pull 7" Csg up ~ 2" to a height of 5.5" -Max Wt 150k, Held 145k. Reset slips. RD S ear. 05:00 08:00 3.00 MIRU WELCT NUND P Installed new 7" packoffs. NU New FMC Tbg head and tested PO void to 3000 si for 10 min. 08:00 09:45 1.75 MIRU WELCT NUND P NU BOPE ~'~~e 3 of 16 J Time Logs ~ - -- - -~ Date From To Dur S De th E. Depth Ph e Code Subcode T COM ~ r 11/07/2007 18:00 00:00 6.00 5,605 5,854 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 5605' - 5854' MD. TVD = 4491'. ADT = 4.65 HRS. ECD = 11.09 PPG. Bit Hrs = 35.12. Max gas observed = 106 Units. Obtain Slow pump rates @ 5740' MD. OA pressure recorded @ 250 PSI. Crew Chan e 11/08/2007 00:00 06:00 6.00 5,854 6,138 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 5854' - 6138' MD. TVD = 4711'. ADT = 5.69 HRS. ECD = 11.17 PPG. Bit Hrs = 40.8. Max gas observed = 105 Units. Obtain Slow pump rates @ 6115' MD. 06:00 12:00 6.00 6,138 6,397 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 6138' - 6397' MD. TVD = 4912'. ADT = 4.93 HRS. ECD = 11.13 PPG. Bit Hrs = 45.74. Max gas observed = 115 Units. Obtain Slow pump rates @ 6115' MD. OA pressure recorded @ 250 PSI. 12:00 18:00 6.00 6,397 6,655 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 6397' - 6655' MD. TVD = 5110'. ADT = 5:19 HRS. ECD = 11.08 PPG. Bit Hrs = 50.93. Max gas observed = 94 Units. 18:00 00:00 6.00 6,655 6,943 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 6655' - 6943' MD. TVD = 5333'. ADT = 4.58 HRS. ECD = 11.46 PPG. Bit Hrs = 55.51. Max gas observed = 88 Units. Obtain Slow pump rates @ 6930' MD. OA pressure recorded @ 450 PSI. 11/09/2007 00:00 06:00 6.00 6,943 7,207 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 6943' - 7207' MD. TVD = 5539'. ADT = 5.83 HRS. ECD = 12.05 PPG. Bit Hrs = 61.34. Max gas observed = 90 Units. Begin weight up system to 10.8 PPG at 6870' MD as er well Ian. 06:00 06:30 0.50 7,207 7,217 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 7207' - 7217' MD. TVD = 5546'. ADT _ .2 HRS. ECD = 12.05 PPG. Bit Hrs = 61.54. Continue weight up mud s stem. Lost enerator. 06:30 07:00 0.50 7,217 7,217 INTRM1 DRILL OTHR T Trouble shoot generator. Observed failed bearing. Work Drill string while trouble shooting. Generator will be re laced out of the critical ath. 07:00 12:00 5.00 7,217 7,379 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 7217' - 7379' MD. TVD = 5673'. ADT = 3.73 HRS. ECD = 12.42 PPG. Bit Hrs = 65.27. Max Gas observed = 90 Units. Continue weight up mud system. Obtained SPR's @ 7335' MD, TVD 5638'. Recorded 500 PSI on the OA. Crew Chan e ~~~~ l~~s~e ? of 1b Time Logs Date From To Dur_ S D~th E_Depth Phase Code_ Subcode T COM 11/09/2007 12:00 18:00 6.00 7,379 7,555 INTRMI DRILL DDRL P Directional drill 6 1/8" x 7" hole from 7379' - 7555' MD. TVD = 5811'. ADT = 5.93 HRS. ECD = 12.05 PPG. Bit Hrs = 71.20. Max Gas observed = 258 Units. 18:00 19:45 1.75 7,555 7,602 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 7555' - 7602' MD. ND = 5849'. TD as per GEO & DD. ADT = 1.62 HRS. ECD = 12.82 PPG. Bit Hrs = 72.82. Max Gas observed = 81 Units. Obtained SPR's @ 7602' MD, ND 5849'. Observed OA pressure to 780 PSI. Bled off uickl to tank. No Gas. 19:45 20:15 0.50 7,602 7,602 INTRM1 DRILL OWFF P Continue criculate 10 minutes. Obtain slow pump rates. Monitor well -static. re ri floor for BROOH. 20:15 00:00 3.75 7,602 6,000 INTRM1 DRILL REAM P BROOH performing MAD PASS from 7602' - 7325', at 3-5 ft/minute with pumps at 330 GPM's - 3200 PSI. Continue BROOH increasing string speed to 40-45 ft/min with same pump rates. Crew Change. Observed loss circulation at 6000' MD, at 2330 HRS. Fluid loss = 50 BBLS. 11/10/2007 00:00 01:00 1.00 6,000 6,000 INTRM1 DRILL CIRC P Monitor well, observing slight flow with 11.1 PPG out, 10.8 PPG in. Total fluid loss = 90 BBLS. Work drill string, while gaining circulation with full returns in increments, at 275 GPM's. Observed well taking fluid at 275 GPM's, slow pumps to 250 GPM's - stable. Monitor losses, with none observed. Continue CBU for a total of 2500 strokes observing hole cleaning up, and 10.8 PPG in/out. No fluid losses. Monitor well -fluid slightly movin in stack. Pit volume static. 01:00 07:15 6.25 6,000 4,338 INTRM1 DRILL REAM P Continue BROOH at rates of 10 ft/minute. Attempt to pull at 30 fUmin, observing loss of circulation. Pump rates at 250 GPM's - 1900 PSI. Slow rates to 200 GPM's no losses. We could not observe a "packoff', or overpull, just a sudden loss of circulation. When we stopped pulling, and slacked off, we were able to gain full circulation, indicating packed off, and continued BROOH. Mud weights in/out - 10.8+ PPG. First 5 stands indicated 11 BBL Loss, with 200 GPM's - no fluid loss. Pull to bit depth of 4338' MD. Total fluid loss = 118 BBLS. P~c~ef~oil6 ~~ ~~ i Time Logs __ ~ Date From To Dur _S. De th E. De ttt Phase Code Subcode T COM ' 11/11/2007 04:45 06:00 1.25 7,744 7,784 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 7744' - 7784' MD. TVD = 6006'. ADT = 1.04 HRS. ECD = 12.32 PPG. Bit Hrs = 80.11. Max Gas observed = 227 Units. 06:00 12:00 6.00 7,784 7,925 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 7784' - 7925' MD. TVD = 6127. ADT = 4.84 HRS. ECD = 12.43 PPG. Bit Hrs = 84.95. Max Gas observed = 277 Units. Obtained SPR's @ 7895' MD, TVD 6102'. CRew Chan e 12:00 18:00 6.00 7,925 8,090 INTRM1 DRILL DDRL P Directional drill 6 1/8" x 7" hole from 7925' - 8090' MD. TVD = 6272'. ADT = 5.74 HRS. ECD = 12.40 PPG. Bit Hrs = 90.69. Max Gas observed = 460 Units. 18:00 00:00 6.00 8,090 8,200 INTRMI DRILL DDRL P Directional drill 6 1/8" x 7" hole from 8090' - 8200 MD. TVD = 6368'. ADT = 4.93 HRS. ECD = 12.42 PPG. Bit Hrs = 95.62. Max Gas observed = 233 Units. Crew Chan e 11/12/2007 00:00 06:00 6.00 8,200 8,285 INTRMI DRILL DDRL P Directional drill 6 1/8" x 7" hole from 8200' - 8285' MD. TVD = 6444'. ADT = 6.16 HRS. ECD = 12.36 PPG. Bit Hrs = 101.78. Max Gas observed = 148 Units. This TD picked at 220' below top of Miluveach as per GEO. Obtained SPR's on bottom. 06:00 06:15 0.25 8,285 8,285 INTRM1 DRILL OWFF P Monitor well -Observed well slightly flowing. Breakout & lay down single 'oint. 06:15 11:00 4.75 8,285 7,056 INTRMI DRILL REAM P BROOH from 8285' @ 3-5 fUmin, for caliper logs. Pumps @ 300 GPM's - 2900 PSI for 3 stands. Continue BROOH staging rate to 15 ft/min. Observed packing off @ 7755' - 7725' & 7700'-7648', slowing back ream rates to 3 ft/min from 7524'-7056'. Continue @ 20 ft/min with no packoff issues and no fluid loss. Stop BROOH 7056' MD. 11:00 12:00 1.00 7,056 7,056 INTRM1 DRILL CIRC P Circulate bottoms up while reciprocate & rotate drill string with pumps @ 330 GPM's - 3350 PSI. No fluid loss observed. Crew Chan e 12:00 12:15 0.25 7,056 6,864 INTRM1 DRILL TRIP P POOH on elevators from 7056' - 6864'. Observed no swabbing issues and fluid fallin .Monitor well -static. 12:15 13:15 1.00 6,864 8,285 INTRMI DRILL TRIP P Trip in hole from 6864' - 8285' with no issues, and ro er dis lacement. 13:15 15:00 1.75 8,285 8,285 INTRM1 DRILL CIRC P Circulate bottoms up x 2, with pumps at 330 GPM's -3475 PSI. ECD = 12.53 PPG. No fluid losses observed. Reci rotate & rotate drill strip . 15:00 15:15 0.25 8,285 8,285 INTRM1 DRILL OWFF P Monitor well. Observed slight flow in stack as observed reviousl . ~8x~y £''~t#r7~ 2=~ Time Logs I Date From To Dur S. De th E. D~th Phase Code SubCOde T COM 11/12/2007 15:15 17:30 .2.25 8,285 8,285 INTRM1 DRILL CIRC P Circulate to weight up mud system to 11.2 PPG. Continue reciprocate & rotate drill string. Obtained 3 btms up while weighting up, with ECD's @ 12.55 PPG. UP WT = 157K, SO WT = 107K. Observed no fluid loss. 17:30. 18:00 0.50 8,285 8,285 INTRM1 DRILL CIRC P Monitor well -static. Pump & spot 35 BBLS of Lube pill as planned for liner run. Spot pill 100' out of bit depth at 8285'. 18:00 20:00 2.00 8,285 5,460 INTRM1 DRILL TRIP P POOH on elevators with a wet string from 8285' - 5460' as planned. Observed proper hole fill with no hole issues. 20:00 20:15 0.25 5,460 5,460 INTRM1 DRILL CIRC P Pump 25 BBL dry job. Drop 2 1/4"drift with wire in DP. 20:15 21:15 1.00 5,460 4,050 INTRM1 DRILL TRIP P Continue POOH on elevators from 5460' - 4050'. Observed no issues with assembly going through window area. Observed ro er hole fill. 21:15 21:30 0.25 4,050 4,050 INTRM1 DRILL OWFF P Monitor well -static. 21:30 22:45 1.25 4,050 680 INTRM1 DRILL TRIP P Continue POOH on elevators from 4050' - 680'. BHA.Observed proper hole fill. 22:45 00:00 1.25 680 150 INTRM1 DRILL PULD P Monitor well -static. Breakout & lay down 2 joints of HWDP & drilling jars. lay down 2 drill collars and stabilizer. Crew Chan e 11/13/2007 00:00 01:00 1.00 150 100 INTRM1 DRILL PULD P Continue POOH, breakout & lay down BHA. Held PJSM with crew & Sperry reps. Discuss safety & hazard recognition issues. Discuss safe removal of nuclear sources in tools. Pull nukes. Lay down & inspect Smith Rhino Reamer. Gauged to a 1/1. All cutters in ood sha e. 01:00 02:30 1.50 100 100 INTRM1 DRILL PULD P Plug in and download MWD assembly. SIMOPS:. Pull tools & e ui ment to ri floor for Liner run. 02:30 03:30 1.00 100 0 INTRM1 DRILL PULD P Continue POOH, breakout & lay down remaining BHA. Inspect & grade bit to 4/1 /LT/C/X/I/CT/TD. 03:30 04:00 0.50 0 0 COMPZ CASIN RURD P Clean & clear rig floor. BOLDS. Rig up and ull wear bushin . 04:00 05:00 1.00 0 0 COMPZ CASINC RURD P Held PJSM. Discuss safety & hazard recognition issues. Rig up casing equipment to run 51/2" liner. Make up cement head with ball catcher assembly & crossover with 15' DP pup 'oint, and la down same. 0 ~ t E~~ge 1't of 1fi • C~ Time Logs e T COM Date From To Dur S De th E. De th Ph se Code Suhcod 11/13/2007 05:00 12:00 7.00 0 4,351 COMPZ CASIN( _ RNCS P Held PJSM. Make up 5 1/2" Shoe track assembly with Davis LynchType 601 Guide Shoe & Auto-Fill Float collar. Make up Joint with Insert landing collar baker locking all shoe track joints. Continue TIH with 105 jnts of 5 1/2" liner assembly as planned to 4351'. MAke up Baker liner hange assembly as per BOT rep. Obtain parameters with UP WT = 82K, SO WT = 68K. Observed proper dis lacement on TIH. Crew Chan e 12:00 12:15 0.25 4,351 4,916 COMPZ CASIN RUNL P RIH with Liner on Drill pipe to 4916'. UP WT = 85K, SO WT = 73K. Ran 3 stands to s ace out for H o valve. 12:15 14:00 1.75 4,916 4,916 COMPZ CASINC CIRC P Make up Hyflo valve with crossovers as per BOT rep. Circulate liner volume @ 2 BPM - 325 PSI. Observed packed off and um ed awa 42 BBLS. 14:00 17:30 3.50 4,916 8,285 COMPZ CASIN( RUNL P Continue run 5 1/2" liner asembly from 4916' - 8285' MD, Tagging bottom on depth. Obtain T&D parameters for rig engineer evry 5 stands. PU WT - 152K, SO Wf = 92K. 17:30 18:00 0.50 8,285 8,285 COMPZ CASIN RURD P Make up cement head, with ball dro in sub. Ri u cement lines. 18:00 18:30 0.50 8,285 8,285 COMPZ CASINC CIRC P Circulate bottoms up @ 3 BPM - 375 PSI. Observed no fluid loss. Reci rocate strip in 20 'increments. 18:30 18:45 0.25 8,285 8,285 COMPZ CASINC CIRC P Drop 1 3/8" ball from ball dropper, pump down @ 2 BPM until observed seated in 233 strokes, and sheared at 2700 PSI. Observed pumped down to landing collar and shifted with 600 PSI increase in pressure. Continue reci rocate casin strip . 18:45 22:00 3.25 8,285 8,285 COMPZ CEME~ CIRC P Circulate staging pumps slowly to 46 SPM (3.9 BBLS), observing minimal fluid loss. Decision to lower mud weight from 11.2 PPG - 11.0 PPG. Continue reciprocate casing string. Rig up Dowell cementers, and spot vac trucks. -oad truck with dis lacement mud - 11.0 PPG. 22:00 00:00 2.00 8,285 8,285 COMPZ CEMEt` CIRC P Continue circulating for a total of 5 bottoms up, and dropping mud weight to 11.0 PPG. Continue staging pumps up to 4.6 BPM - 1000 PSI with minimal fluid loss until observed 11.0 PPG all the way around. Continue reciprocate casing string. Crew Chan e ~ __.~_e~_ -- - ~a€~~r 1 Y ~~ 13 ~ • Time Logs __ ___ Date From To Dur 5 De th E. De th Phase Code Subcode T COM 11/14/2007 07:00 08:00 1.00 0 0 COMPZ CASINC OTHR P Clean & clear rig floor. Send tools out. Blow down Geo-S an unit 08:00 12:00 4.00 0 0 COMPZ CASINC OTHR P Install mousehole in rotary table. Held PJSM. Discuss safety & hazard recognition issues. Breakout & lay down 67 stands of drill pipe. Crew Chan e 12:00 13:30 1.50 0 0 COMPZ CASINC OTHR P Held PJSM. Discuss safety & hazard recognition issues. Breakout & lay down 21 stands of drill i e. 13:30 14:00 0.50 0 0 COMPZ CASIN OTHR P Clean & clear rig floor. 14:00 16:45 2.75 0 0 COMPZ RPCO OTHR P Make up tubing hanger as per FMC rep for dummy run. Attempt to land hanger. Observed mud /clay build up. Rig up and flush BOP stack and well head with stack washer. Make up tbg hanger again, RIH ,land & RILDS. Test hanger to 2500 PSI for 15 minutes on chart. 16:45 18:00 1.25 0 0 COMPZ RIGMN SVRG P Held PJSM. Discuss safety & hazard recognition issues. Rig up and slip & cut 62' of drilling line. Inspect draw works brakes. Note: observd ID versus OD tolerances of the production PKR and the XO on the Liner hanger both = 4.80" .Sent Production PKR to machine shop to turn down to 4.790" as er BOT recommendations. 18:00 18:30 0.50 0 0 COMPZ RPCOh RURD P Rig up to run 3 1/Z" production tbg. Ri u ower ton s. 18:30 20:00 1.50 0 0 COMPZ RPCOti RCST NP Observed all equipment to be made up under the packer was not Baker -locked as per the well plan. Breakout wireline entry guide assembly, and all connections, pups to the packer. Apply Baker lock to each connection and re- make up the assembly. Pull assembly out of hole & hange in blocks. 20:00 21:00 1.00 0 0 COMPZ RPCOti DHEO P Rig up to pump down kill line. Close blind rams. Apply a 2500 PSI casing test, to ensure integrity of liner lap before RIH with tbg.Good test- recorded on chart. 21:00 00:00 3.00 0 1,350 COMPZ RPCO RCST P Held PJSM with crew, casing hand & BOT rep. Discuss safety & hazard recognition issues. RIH with wireline entry guid assembly, and Baker SABL-3 production packer assembly. Ran a total of 40 'nts to 1350'. ~ ~ ~ ~~~~ i~ ~~ ~b ! i 3A-03B Sidetrack Summary DATE Summary 11/24/07 ELINE UNIT 2196 -PREP FOR SLIM CASED HOLE RESISTIVITY JOB. 11/25/07 GAUGED TBG TO 2.75" TO 7661' RKB. PULLED BALL & ROD @ 7710' RKB. PULLED SOV @ 7565' RKB. REPLACED WITH DMY VLV. JOB IN PROGRESS. 11/26/07 ATTEMPTED MITIA TO 2500#. LOST 500# IN 15 MIN. UNABLE TO MAINTAIN SPECIFIED PRESSURE AFTER NUMEROUS ATTEMPTS. ***FAILED***. (*''*APPEAR TO LOOSE PRESSURE FASTER AFTER EACH ATTEMPT TO BUMP IA UP. TTL OF 3 BBLS AWAY. DO NOT SUSPECT GAS COMPRESSION***). TBG HOLDING @ 1500# WITH NO LOSS. PASS. 11/27/07 PERFORMED MITT TO 2500# -PASS. ATTEMPT TO MITIA 2500#- FAILED. ESTABLISHED INJECTION RATE OF 1/2 BPM @ 1500# DOWN IA. PULLED 2.75" RHC PLUG BODY @ 7710' RKB. DRIFTED TBG WITH 22' X 2.65" DMY DRIFT & TAG BTM @ 8143' SLM. JOB COMPLETE. 12/1/07 RAN A SCMT CEMENT BOND LOG FROM 8146' TO 7594'. LOGGED WITH TBG PRESS= 1200 PSI TO ELEMINATE MICRO ANNULUS EFFECTS. CEMENT QUALITY WAS FAIR FROM 8146' TO THE TBG TAIL. ATTEMPTED TO DO TEMP WARM BACK PASSES TO IDENTIFY CASING LEAKS. IA LOCKED UP AFTER PUMPING 22 BBLS OF DIESEL. TAGGED BOTTOM AT 8159'. AFTER SLB RIG OFF, MITIA PASSES, BUT ABLE TO BLEED BACK AND REPRODUCE LEAK. 12/2/07 Initial T/I/0= 100/600/50. Rig up LRS, pump .5 bpm @ 1000 psi, pressured up to 2500 psi with 4 bbls diesel, stopped pumping, pressure dropped 100 psi immediately, slowed rate down to .3 bpm. Pumped .5 bbls @ .3 bpm, pressure climbed to 2500. Shut in pump, start MIT IA. 15 min T/I/0= 100/2100/50. Pressured back to 2500 with .5 bbls @ .25 bpm. 15 min: 1900 psi, pressure back to 2500 with .5 bbls @ .25 bpm. LLR of 1.4 gpm. Bleed IA down to FTP of 250 psi. Pressure back up to 2500 psi with 2.5 bbls diesel @ .25 bpm, 10 min reading 1000 psi. Pressure back to 2500 psi with 1.5 bbls diesel @ .25 bpm, 15 min reading. 2125 psi. Pressured back to 2500 psi with .5 bbls diesel @ .25 bpm. 15 min: 2475 psi, 30 min T/I/0= 100/2465/50. For a total 9.5 bbls diesel to IA. Bled IA to 250 psi. Final T/I/0= 100/250/50. MITIA -passed. 12/7/07 ATTEMPTED TO RUN SFRT (CASED HOLE RESISTIVITY). UNABLE TO GET TOOLS TO FALL PAST 3100'. WILL TRY AGAIN WITH ADDITIONAL WEIGHT BARS AND ROLLERS. 12/8/07 PLANNED SFRT (CASED HOLE RESISTIVITY) JOB WAS PUSHED FOR ONE DAY DUE TO DELAYS CAUSED BY TOOL PROBLEMS. UNABLE TO CLOSE ARRAY SECTION OF THE SFRT TOOLSTRING. TOOL PROBLEM WAS IDENTIFIED TO BE IN THE ARRAY SECTION HYDRAULICS AND TOOL WAS REPLACED. 12/9/07 ATTEMPTED TO RUN SFRT TOOL DID NOT FUNCTION PROPERLY, SPENT TIME TROUBLE SHOOTING DOWNHOLE, BUT DID NOT GET TOOL WORKING, NOT FIELD REPAIRABLE TOOLS SENT TO SWS PRUDHOE BAY SHOP FOR REPAIR 12/10/07 MITIA -FAILED , IA-LLR - 7.7 GPM @ 1300 PSI. 12/10/07 PRUDHOE BAY SHOP UNABLE TO REPAIR SFRT. SWAP UNIT BACK TO SMALL CABLE. TEST BOP/WIRELINE-VALVES. 12/12/07 TECWELL LEAK DETECT LOCATED LEAK AT LINER TOP 3913', UNABLE TO ESTABLISH CONSISTENT LEAK -KEPT IA PRESSURE BETWEEN 2200 - 2500 PSI, PUMPED AT TOTAL OF 14.6 BBLS DIESEL DOWN IA TO FORMATION 12/24/07 Shot 2.5" 6 spf HyperJet, 60 deg phasing gun from 7975'-7995'. Perforated overbalanced with surface WHP = 2500 psi prior to shooting. a ~ 3A-03B Sidetrack Summary 12/25/07 SET 2.85" FRAC SLEEVE @ 2263' RKB (2.30" ID). DRIFT TREE W/ 2.9" GAUGE RING TO 20' SLM. JOB COMPLETE. 12/28/07 COMPLETED A SAND FRACTURE STIMULATION. PUMPED A TOTAL OF 230220# OF 16/20 CARBOLITE WITH 229767# BEHIND PIPE, 102% OF DESIGN. COMPLETED FRAC WITH 12 PPA ON FORMATION. PUMPED A TOTAL OF 1985 BBLS OF SW @ AN AVERAGE TREATING PRESSURE OF 3758 PSI. FRAC PUMPED TO COMPLETION AND FLUSHED WITH 37 BBLS OF SW FOLLOWED BY 31 BBLS OF DIESEL. FREEZE PROTECT. FINAL ISIP=2853#, FG=.91 PSI/FT AND 15 MIN WHP = 2100 PSI. 12/30/07 PULLED 2.85" FRAC SLEEVE @ 2263' RKB. JOB COMPLETE. 1/5/08 PERFORM POST FRAC FCO DOWN TO HARD BOTTOM @ 8164' CTMD.HAD 1 FOR 1 RETURN USING MI SKID WITH GOOD AMOUNT OF FORMATION AND FRAC SAND.LEFT WELL SHUT IN AND FREEZE PROTECTED WITH SLICK DIESEL FOR DSO TO PERFORM FLOW BACK.JOB COMPLETE • Cc~nocoPhillips Time Log Summary weltvJew Web Reparbng Well Name: 3A-03 Job Type: RECOMPLETION Time Loys __ Da e From To Dur S. D~th E De th Phase Cade SufJCCxie T C©tvt _ _ 02/12/2008 04:00 08:00 4.00 MIRU MOVE MOB P Move Rig from 3H-16 Well (2 miles). Spot over well, prepare for well work. Ri acts ted this da at 0400 hrs. 08:00 09:00 1.00 MIRU RPCOh OTHR P Check pressure, 450 psi tbg, 120 psi IA, 30 psi OA. Pull BPV. Spot Rock-washer, rig up lines for circulatin t/ Kill Tank. 09:00 11:30 2.50 MIRU WELCT KLWL P RU to kill well, press test hardlines to 2500 psi. Drop tarps on rig. spot Equipment around rig. Load 9.6# brine in its. 11:30 13:00 1.50 MIRU WELCT KLWL P Circulate 233 bbls 9.6 # brine displacing diesel freeze protect and seawater to kill tank. Shut down monitor well, ress 0. 13:00 16:00 3.00 MIRU WELC NUND P Set BPV, ND tree. Inspect lifting threads on hanger. Install blanking lu . 16:00 19:30 3.50 MIRU WELCT NUND P NU 11" BOP w/ 2 sets of 3 1/2" pipe rams. 19:30 04:00 8.50 MIRU WELL ROPE P Pressure test BOPE including the annular to 250/3500 psi. Witnessing of test waived by Bob Noble w/AOGCC. Could not get annular to test. Pre ared to re lace annular ba . 02/13/2008 00:00 06:00 6.00 MIRU WELC EQRP T Could not get the annular to test. Notified State Rep.(Lou Gramaldi) Replaced the element in the annular. Good test at 250/3500 psi. State witness test had been waived by Bob Noble @ 13:45 on 2/12/08 per phone conversation. 06:00 07:30 1.50 MIRU RPCO PULD P Pull blanking plug. Pull BPV. MU landing jt in tubing hanger. Pull hanger to rig floor pulling seal assembly out of PBR with no roblems. U wt 95K. Monitor well. 07:30 09:30 2.00 MIRU RPCOh PULD P LD landing jt and hanger. Pull 1 jt to get enough slack in control line to add fittings and pressure up to lock open SSSV. 09:30 19:00 9.50 MIRU RPCO PULD P Rig up Spooling Unit .POOH spooling up control line and retrieving all 64 bands, standing back 3 1/2" IBTM tubing and laying down pups and tom letion 'ewel Page 1 t~f :~ l J Time Logs _ _ _ Date From To Dur 5 De th E. De th Phase Code Subcode T COM 02/13/2008 19:00 20:00 1.00 COMPZ RPCOti PULD P _ Clear rig floor and prepare to run drill pipe. PU BHA (Liner hanger setting assembl 20:00 00:00 4.00 COMPZ RPCOti PACK P RIH with BHA #1 to re-energize the upper packer element. U wt. 78K, Down wt. 70K 02/14/2008 00:00 02:00 2.00 COMPZ RPCOh PACK P Located top of liner hanger at 3922', dropped the ball and pumped down w/ 30 bbls. of 9.6# brine. Set down into the liner hanger at 3944' and pressured up to 4000 psi ,had good comfimation of ball seat shearing out. Set 35K down to attepmt to reset liner hanger. Bled off press. Picked up out of hanger.. U wt. 78K and down wt. 70K. 02:00 03:00 1.00 COMPZ RPCOh CIRC P Circulate bottoms up to clean up top of liner han er. 03:00 06:00 3.00 COMPZ RPCOh TRIP P POOH w/ BHA #1 (Liner hanger setting assembly) . OOH, lay down BHA. 06:00 07:00 1.00 COMPZ RPCOti DHEQ P Pressure test casing to 2500 psi.30 min. 07:00 11:30 4.50 COMPZ RPCOh TRIP P RD test equip. MU BHA #2 ("CPH" Liner Top Packer) and RIH on 3 1/2" drill i e. 11:30 13:30 2.00 COMPZ RPCOh OTHR P Locate Tie back seals @ 3928'. Pressure up to 200 psi to make sure seals are in. PU break jt and drop ball, make jt backup. Pump 2 BPM @ 160 psi to get ball on seat. Lowered down stacked 10K down. PU to up wt. Press up to 1600 psi to set Liner Hanger. Slacked off, put 35K wt on Liner Hanger. Bled off press. Slacked off wt back to 35K. Pressure up to 2600 psi to set liner top packer. Sheared @ 1750 psi. Held for 5 min. Pressured up to 3200 psi to blow ball seat. No indication of shear. Bled off to 0 and repeated this to 3200 psi and still no indication of shear. Bled off pressure, right hand released w/15 turns. PU 90K up wt. 6' to expose dog sub. Slacked off on liner top, setting max available wt of 35K on liner top. Repeat slack one more time. PU 10' circulated 3 BPM @ 180 psi. PU at 19' out of liner hanger, took 25 to 30K overpull. Worked down and up several times and pulled packer cups free of liner top. LD 2jts. and RU to test. 13:30 14:00 0.50 COMPZ RPCOh DHEO P Pressure tested to 2500 psi for 30 min on chart. Page 2 of 3 • Time Logs _ Date From To Dur S De th E. De th Pha e Code bcode T COM Su 02/14/2008 14:00 19:00 5.00 COMPZ _ RPCOh _ TRIP P ND test equipment. POOH laying down drill pipe and liner packer runnin tool. 19:00 20:00 1.00 COMPZ RPCOh PULD P OOH, Prepare rig floor to run com letion strip . 20:00 00:00 4.00 COMPZ RPCOh RCST P PU and RIH w/ 3.5" completion string. 02/15/2008 00:00 08:30 8.50 COMPZ RPCOh RCST P Continue to RIH with completion. 08:30 10:00 1.50 COMPZ RPCOti HOSO P Up wt 95K Dwn wt 70K. Space out 2' off fully located on seal assembly @ 7658'. Bled off control line pressure on SSSV. MU hanger and reconnect control line and pressure back up to o en SSSV. 10:00 12:30 2.50 COMPZ RPCO CIRC P Pumped 150 bbls seawater containing 1 % CRW-132 corrosion inhibitor, followed b 50 bbls seawater. 12:30 15:00 2.50 COMPZ RPCO HOSO P Landed hanger, RILDS. NU test lines. Pressured up tubing to 25,000 psi held for 15 min. Bled pressure down to 1750 psi. Pressured up on IA to 25,000 psi held and charted for 30 min. Bled pressure on tubing to 0 and sheared SOV in GLM #5. Bled all ressure off. ND test a ui ment 15:00 16:30 1.50 COMPZ RPCOh HOSO P Pull landing jt. Set BPV. 16:30 22:00 5.50 COMPZ RPCO NUND P ND BOP stack, change out HCR Valve. 22:00 00:00 2.00 COMPZ RPCOh NUND P NU Tree, Install new master valve. Changed out IC test ports checks. Test tbg hanger void to 250/5,000 psi for 15 min. 02/16/2008 00:00 02:00 2.00 COMPZ RPCO DHEO P PJSM, Continue to Test tree and Pack off @ 250/ 5,000 psi. Pull test plug and BPV. 02:00 03:00 1.00 COMPZ RPCO OTHR P RU Circ line to Tiger tank. Check line for flow. 03:00 07:00 4.00 COMPZ RPCOti FRZP P PJSM, RU LRS and PT lines to 2,000 psi. Pump 105 bbls diesel down the IA taking returns to the TT form the TBG. Blow down lines to TT. Allow tbg x IA to equalize. RD hoses, clean wellhead and cellar. Release rig @ 07:00 2/16/2008. Page 3 saf ~ • • Halliburton Company Survey Report C umpany: ConocoPhillips Alaska Inc. Date: 11/28/2007 I in,c: 10.41:26 Pa~c: I Gild: KuparukRiver Unit Co-ordinate(~'1:) Refcrrncc: Well: 3A-03, Tru e North Jite: Kuparuk 3A Pad 1'crtical (TVll) Re ference: 3A-03°: G3.6 ~~ell: 3A-03 tiec tion (VS) lefer ence: Well (O.DON,fJ.00E,178.96Azi) ~~ellpa[6: 3A-03B Su n~ey ('alculatio n Method: Minimum Curva __ ture nn: Oracle ~ 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 Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 WeII: 3A-03 Slot Name: Well Position: +N/-S 48.29 ft Northing: 5996908.32 ft Latitude: 70 24 9.995 N +E/-W -12.90 ft Easting : 507699.06 ft Longitude: 149 56 14.397 W Position Uncertainty: 0.00 ft Wellpath: 3A-03B Drilled From: 3A-03 API 50-029-21432-02 Tie-on Depth: 3996.60 ft Current Datum: 3A-03B: Height 68.60 ft Above System Datum: Mean Sea Level Magnetic Data: 11/1/2007 Declination: 22.95 deg Field Strength: 57616 nT Mag Dip Angl e: 80.85 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 178.96 Survey Program for Definitive Wellpath Date: 11/12/2007 Validated: Yes Version: 3 Actual From To Survey To olcode Tool Name ft ft 96.60 3996.60 3A-03 (96.60-8386.60) (0) GCT-MS Schlumberger GCT mu ltishot 4104.00 8235.75 3A-03B IIFR+MS+SAG (4104.00-82 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey X11) Intl Azim TVl) ti}s ~TVI) \/S Gr~1 VapS 11tapE l~nul ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -40.60 0.00 0.00 5996908.32 ~ 507699.06 • TIE LINE 96.60 0.43 27.07 96.60 28.00 0.23 0.12 5996908.55 507699.18 GCT-MS 196.60 0.43 75.25 196.60 128.00 0.66 0.65 5996908.98 507699.71 GCT-MS 296.60 0.27 108.22 296.60 228.00 0.68 1.24 5996909.00 507700.30 GCT-MS I 396.60 0.27 232.97 396.59 327.99 0.47 1.27 5996908.79 507700.33 GCT-MS 496.60 0.50 236.18 496.59 427.99 0.08 0.72 5996908.40 507699.78 GCT-MS i 596.60 3.48 178.18 596.52 527.92 -3.20 0.46 5996905.12 507699.52 GCT-MS 696.60 7.13 181.55 696.08 627.48 -12.44 0.38 5996895.88 507699.46 GCT-MS ~ I 796.60 9.75 179.95 794.99 726.39 -27.11 0.22 5996881.21 507699.31 GCT-MS j 896.60 13.35 182.30 892.95 824.35 -47.12 -0.23 5996861.20 507698.88 GCT-MS ~ 996.60 16.13 183.32 989.65 921.05 -72.53 -1.50 5996835.80 507697.64 GCT-MS I 1096.60 20.08 183.13 1084.68 1196.60 23.72 182.67 1177.45 ' 1016.08 1108.85 -103.55 -140.79 -3.24 -5.12 5996804.78 507695.92 5996767.53 507694.09 GCT-MS GCT-MS ~ 1296.60 27.02 183.88 1267.79 1199.19 -183.56 -7.59 5996724.77 507691.66 GCT-MS 1396.60 28.65 183.83 1356.22 1287.62 -230.15 -10.73 5996678.18 507688.57 GCT-MS ~ 1496.60 32.08 182.53 1442.49 1373.89 -280.61 -13.50 5996627.72 507685.85 GCT-MS 1596.60 34.55 181.52 1526.05 1457.45 -335.50 -15.43 5996572.84 507683.98 GCT-MS 1696.60 38.13 181.75 1606.59 1537.99 -394.72 -17.12 5996513.62 507682.34 GCT-MS 1796.60 41.27 181.88 1683.52 1614.92 -458.56 -19.15 5996449.79 507680.38 GCT-MS ' 1896.60 44.32 181.85 1756.89 1688.29 -526.45 -21.36 5996381.90 507678.24 GCT-MS ~ 1996.60 45.47 181.38 1827.73 1759.13 -597.00 -23.35 5996311.35 507676.33 GCT-MS i 2096.60 46.05 180.95 1897.49 1828.89 -668.63 -24.80 5996239.73 507674.95 GCT-MS 2196.60 46.78 180.83 1966.43 1897.83 -741.05 -25.93 5996167.31 507673.90 GCT-MS I 2296.60 46.92 181.00 2034.83 1966.23 -814.00 -27.09 5996094.37 507672.81 GCT-MS 2396.60 46.78 181.42 2103.22 2034.62 -886.94 -28.63 5996021.44 507671.34 GCT-MS 2496.60 46.97 181.83 2171.58 2102.98 -959.90 -30.70 5995948.49 507669.35 GCT-MS ; 2596.60 47.08 182.15 2239.74 2171.14 -1033.02 -33.24 5995875.37 507666.88 GCT-MS 2696.60 47.78 182.37 2307.39 2238.79 -1106.61 -36.15 5995801.79 507664.06 GCT-MS 2796.60 48.50 182.50 2374.12 2305.52 -1181.02 -39.31 5995727.38 507660.97 GCT-MS • Halliburton Company Survey Report ('omp»ny: ConocoPhillips Alaska Inc. Datc_ 1 U28/2007 l imr. 10'41:26 Pagc_ I~icl~i: Kuparuk River Unit Co-ordinate(~F.I Reference Well: 3A,-03, True North tiitc Kuparuk 3A Pad Vertical CID) Reference 3A-03B: 68.6 ~~ell: 3A-03 Section (~Sj Reference: Well (O.OON,O.OOE,~72.96Azi) ~~ell~io-rth: 3A-03B Sur~c~ t'silc~rlarion Method: Minimum Curvature 11b: Oracle __ --- tiurcc~ iii) Intl lzim f~'ll S~SI'~`D N/S F.~~ MapN ~TapE Tool ft deg deg ft ft ft ft ft ft _ -- _____ 2896.60 48.52 182.67 2440.37 2371.77 -1255.85 -42.69 5995652.56 507657.67 GCT-MS 2996.60 48.50 182.62 2506.62 2438.02 -1330.67 -46.15 5995577.73 507654.29 GCT-MS 3096.60 48.48 182.68 2572.90 2504.30 -1405.48 -49.61 5995502.93 507650.90 GCT-MS 3196.60 48.57 182.78 2639.13 2570.53 -1480.32 -53.18 5995428.10 507647.41 GCT-MS 3296.60 48.63 182.80 2705.26 2636.66 -1555.24 -56.83 5995353.18 507643.84 GCT-MS 3396.60 48.58 182.90 2771.38 2702.78 -1630.16 -60.56 5995278.26 507640.19 GCT-MS 3496.60 48.62 183.07 2837.51 2768.91 -1705.07 -64.47 5995203.35 507636.36 GCT-MS 3596.60 48.60 183.10 2903.63 2835.03 -1779.99 -68.50 5995128.44 507632.40 GCT-MS 3696.60 48.53 183.22 2969.81 2901.21 -1854.84 -72.64 5995053.59 507628.34 GCT-MS 3796.60 48.47 183.42 3036.07 2967.47 -1929.61 -76.97 5994978.82 507624.08 GCT-MS 3896.60 48.65 183.17 3102.25 3033.65 -2004.45 -81.28 5994903.98 507619.85 GCT-MS 3996.60 48.70 182.35 3168.29 3099.69 -2079.46 -84.90 5994828.98 507616.31 GCT-MS 4104.00 46.95 184.50 3240.40 ~ 3171.80 -2158.90 -89.63 5994749.54 507611.66 MWD+IFR-AK-CAZ-SC 4161.12 54.38 183.38 3276.58 3207.98 -2202.95 -92.64 5994705.50 507608.70 MWD+IFR-AK-CAZ-SC 4204.32 53.33 182.60 3302.06 3233.46 -2237.79 -94.46 5994670.66 507606.91 MWD+IFR-AK-CAZ-SC 4300.16 52.98 180.95 3359.53 3290.93 -2314.44 -96.84 5994594.01 507604.61 MWD+IFR-AK.CAZ-SC 4394.15 52.05 179.29 3416.73 3348.13 -2389.02 -97.00 5994519.44 507604.53 MWD+IFR-AK-CAZ-SC 4490.71 51.09 177.43 3476.75 3408.15 -2464.62 -94.85 5994443.85 507606.76 MWD+IFR-AK-CAZ-SC 4583.65 49.83 178.57 3535.92 3467.32 -2536.25 -92.34 5994372.23 507609.34 MWD+IFR-AK-CAZ-SC 4676.56 48.90 176.12 3596.43 3527.83 -2606.67 -89.09 5994301.82 507612.67 MWD+IFR-AK-CAZ-SC 4770.72 45.87 175.38 3660.18 3591.58 -2675.77 -83.96 5994232.74 507617.86 MWD+IFR-AK-CAZ-SC 4864.40 42.15 172.95 3727.55 3658.95 -2740.50 -77.39 5994168.02 507624.50 MWD+IFR-AK-CAZ-SC 4956.27 39.33 172.47 3797.15 3728.55 -2799.97 -69.79 5994108.56 507632.16 MWD+IFR-AK-CAZ-SC 5050.71 37.99 173.38 3870.89 3802.29 -2858.51 -62.52 5994050.03 507639.49 MWD+IFR-AK-CAZ-SC 5143.10 38.65 177.51 3943.39 3874.79 -2915.59 -57.99 5993992.96 507644.08 MWD+IFR-AK-CAZ-SC 5234.93 39.56 181.34 4014.66 3946.06 -2973.48 -57.43 5993935.08 507644.70 MWD+IFR-AK-CAZ-SC 5330.91 39.71 181.05 4088.57 4019.97 -3034.69 -58.70 5993873.87 507643.49 MWD+IFR-AK-CAZ-SC 5425.46 40.33 177.42 4160.99 4092.39 -3095.47 -57.88 5993813.10 507644.38 MWD+IFR-AK-CAZ-SC 5519.39 38.92 172.40 4233.36 4164.76 -3155.10 -52.61 5993753.49 507649.71 MWD+IFR-AK-CAZ-SC 5613.00 40.04 170.95 4305.61 4237.01 -3213.98 -43.98 5993694.62 507658.40 MWD+IFR-AK-CAZ-SC 5705.43 39.23 169.90 4376.79 4308:19 -3272.12 -34.18 5993636.49 507668.26 MWD+IFR-AK-CAZ-SC 5799.28 39.63 171.02 4449.28 4380.68 -3330.90 -24.30 5993577.73 507678.19 MWD+IFR-AK-CAZ-SC 5892.28 39.35 172.79 4521.06 4452.46 -3389.45 -15.97 5993519.20 507686.58 MWD+IFR-AK-CAZ-SC j 5985.43 39.68 173.57 4592.92 4524.32 -3448.30 -8.93 5993460.36 .507693.68 MWD+IFR-AK-CAZ-SC 6079.36 39.48 173.79 4665.31 4596.71 -3507.78 -2.35 5993400.89, 507700.33 MWD+IFR-AK-CAZ-SC 6174.12 38.04 174.57 4739.20 4670.60 -3566.80 3.68 5993341.88 507706.41 MWD+IFR-AK-CAZ-SC I 6267.29 39.02 175.19 4812.09 4743.49 -3624.60 8.85 5993284.09 507711.65 MWD+IFR-AK-CAZ-SC ~ 6360.98 40.09 173.02 4884.33 4815.73 -3683.94 14.99 5993224.76 507717.85 MWD+IFR-AK-CAZ-SC 6456.19 39.05 170.34 4957.72 4889.12 -3743.94 23.75 5993164.78 507726.67 MWD+IFR-AK-CAZ-SC I 6549.95 39.86 170.80 5030.12 4961.52 -3802.72 33.51 5993106.02 507736.48 MWD+IFR-AK-CAZ-SC 6644.58 39.36 172.76 5103.02 5034.42 -3862.42 42.14 5993046.33 507745.18 MWD+IFR-AK-CAZ-SC ~ 6738.06 39.06 174.75 5175.46 5106.86 -3921.16 48.57 5992987.60 507751.67 MWD+IFR-AK-CAZ-SC 6831.78 39.64 174.85 5247.93 5179.33 -3980.34 53.96 5992928.44 507757.11 MWD+IFR-AK-CAZ-SC 6923.28 38.98 174.35 5318.73 5250.13 -4038.05 59.41 5992870.74 507762.62 MWD+IFR-AK-CAZ-SC 7017.59 39.57 172.91 5391.73 5323.13 -4097.38 66.04 5992811.42 507769.31 MWD+IFR-AK-CAZ-SC 7111.12 38.85 173.92 5464.20 5395.60 -4156.11 72.82 5992752.70 507776.16 MWD+IFR-AK-CAZ-SC 7204.66 39.47 172.08 5536.74 5468.14 -4214.73 80.03 5992694.09 507783.42 MWD+IFR-AK-CAZ-SC 7299.50 38.59 171.68 5610.41 5541.81 -4273.86 88.46 5992634.98 507791.91 MWD+IFR-AK-CAZ-SC 7393.61 39.48 172.14 5683.51 5614.91 -4332.54 96.80 5992576.32 507800.31 MWD+IFR-AK-CAZ-SC 7487.00 37.36 173.33 5756.67 5688.07 -4390.10 104.15 5992518.77 507807.72 MWD+IFR-AK-CAZ-SC 7579.66 33.90 174.91 5831.98 5763.38 -4443.78 109.71 5992465.10 507813.34 MWD+IFR-AK-CAZ-SC 7673.54 32.25 177.81 5910.65 5842.05 -4494.89 112.99 5992414.00 507816.67 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. Date 1 1 /2 81200 7 Time: 10.4126 P.wc 3 Field: Kuparuk River Unit Co-o rdin;rte(vE)}tcfcrencc Well: 3A-03, True North Site:. Kuparuk 3A Pad Ferlical (f~ I)) Reference: 3A 03B'. 68.6 WeH: 3N-03 Section ~~5) Reference Well (O.OON.O.OOE,17°.96Azi) ty'cllp;~lh: 3A-03B __ Suncg Calculalion~Vletlwd: _ __ Minimum Curvature Ub: Oracle tiur~c~ ~~tll 1nc1 ~iim f~D C~sl~y'D \%S is/y~ ~1ap~ ~1apt: fool ft deg deg ft ft ft ft ft ft 7766.19 30.69 178.99 5989.67 5921.07 -4543.24 114.35 5992365.66 507818.08 MWD+IFR-AK-CAZ-SC 7859.76 29.80 181.20 6070.50 6001.90 -4590.36 114.29 5992318.54 507818.06 MWD+IFR-AK-CAZ-SC 7954.36 28.24 185.47 6153.23 6084.63 -4636.15 111.66 5992272.75 507815.49 MWD+IFR-AK-CAZ-SC 8048.58 28.58 188.99 6236.11 6167.51 -4680.60 106.01 5992228.30 507809.89 MWD+IFR-AK-CAZ-SC 8142.44 29.36 189.17 6318.23 6249.63 -4725.49 98.84 5992183.40 507802.76 MWD+IFR-AK-CAZ-SC 8235.75 27.54 190.27 6400.27 6331.67 -4769.31 91.35 5992139.59 507795.31 MWD+IFR-AK-CAZ-SC . 8285.00 27.54 190.27 6443.93 ~ 6375.33 -4791.71 87.29 5992117.18 . 507791.27 ~ PROJECTED to TD • WELL LOG TRANSMITTAL To: State of Alaska February 12, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 3A-03B AK-MW-5373121 1 LDWG formatted CD Rom with verification listing. API# : 5 0-029-2143 2-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~_ -~ ;~ ~~ Date ~- ~ ~ ~~~~ Signed: l~ ~O~' l 3~ ~` lS9~d i ~ ALL L TR~4/1f~'lVI/7r74L ProActive Diagnostic Services, Inc. To: AOGCC Chiristine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 793-1225 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 following BP Exploration (Alaslcaj, Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive.Diagnostic Services lnc. Attn:.: Robert.A. Richgt;. 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 ~o~-f3 ~ ~h ~ ~5 ~ J~ 1 J Leak Detection - WLD 12-Dec-07 3A-03B 2J Signed Print Name: ~ ~f~~ f -),_~i~ a_Gr k % ~ ~- EDE 50-029-21432-02 ,~, - >i ~ ~ ~ ~ ~_,~.~ ., Date ~'~.? ~ .~ ~ )~~'~ t ~~, PROACTNE DIAGNOSTIC $ERdICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~dsanchorageCa~memorylog.com WEBSITE : www.memorvlog.com D:Vvlaster_Copy_00_PDSANC-2(ha\Z_Woid\DislributionlTiansmitW_Sheets\Transmit_Original_New.doc 12/20/07 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO.4532 a ~ ~Lsit --, -- Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken i~~~, ~ ~ ~? ~~ ~~ ~~~~~~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 1J-105 11837540 INJECTION PROFILE c''a'1'~-(~'~- 11/20107 1 1A-06 11837542 RST WFL ~'~ ~. ~/ ~ r 11/22/07 1 1Q-05 11837537. _ LDL G - ( 11/17/07 1 16-12 11970607 INJECTION PROFILE 'T - 12/04107 1 2N-327 11996582 OILPHASE SAMPLER Q~- ~ 12115/07 1 1D-132 11994588 SBHP SURVEY ~'~ ^ ~ 12/17/07 1 3H-10B 11996580 PATCH EVALUATION 12/13107 1 3N-02A 11970609 LDL '$ - 12105/07 1 1C-125 11964553 INJECTION PROFILE - 12/01107 1 2M-15 N/A PRODUCTION PROFILE ( ~ " 12110/07 1 2M-11 N/A PRODUCTION PROFILE ~q ~ I 12/08/07 1 3A-036 11970604 SCMT '~- / 12101/07 1 2T-217A 11978431 SCMT 12/15/07 1 2L-330 11837544 FULLBORE MICRO SCANNER 11/27107 1 2L-330 11837544 SONIC SCANNER 11/27/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • 10-Dec-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3A-03B Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 3,996.60' MD Window /Kickoff Survey 4,104.00' MD (if applicable) Projected Survey: 8,285.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 jj ~ Date 1 ~ ~c. ~T~ Signed .~ ~ .. Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~~~-f3r ~ • o Q ~ Q a. SARAH PALIN, GOVERNOR ~iK>•-7~~ OTTj ~~ ~ 333 W. 7th AVENUE, SUITE 100 C011TSERQA~`I011T COMI~'IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kupaurk River Field, Kuparuk River Oil Pool, 3A-03B ConocoPhillips Alaska, Inc. Permit No: 207-131 Surface Location: 527' FSL, 749' FEL, SEC. 7, T12N, R9E, UM Bottomhole Location: 1065' FSL, 649' FEL, SEC. 18, T12N, R9E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Dan T. Seamount Commissioner DATED this Z day of October, 2007 cc: Department of Fish 8s Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ConocoPhillips ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.I.thomas@conocophillips.com September 20, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907)279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Producer 3A-03B Dear Commissioner: 2007 ~;;~:;. Comm~ssiar~ _, ;, ConocoPhillips Alaska, Inc. hereby applies for a Permit to DrilUSidetrack an onshore Producer well, KRU 3A-03B, a development well. It is planned to abandon the original wellbore with a CIPB and place a permanent whipstock on top of the CIBP. Sidetrack operations will then cut and mill a window in the existing 7" production casing with a planned KOP point from the 7" casing +/- 4084' MD. The existing 7.0" casing cement job from the original wellbore did not bring the top of cement up as high as the window. The current plan is to mill the window and perform aFIT /LOT. If the LOT is low, a squeeze cement job will be performed ~! placing cement on top of the whipstock and in the milled window and a second FIT/LOT will be performed. After a successful FIT/LOT test, the intermediate section will be drilled with a 6" bi-center bit, opening up to 7", to intermediate 5- 1/2" casing point above the Kuparuk C sand. The 5-1/2" casing shoe will be drilled out using 2-7/8" DP and a 4-3/4".bit to TD. A 3-1/2" liner will be run and cemented across the Kuparuk C and A sands. The spud date is expected to be approximately October 16th, 2007. If you have any questions or require any further information, please contact Jason Brink at 265-6419. Sincerely, l Randy Thoma GKA Drilling Team Leader STATE OF ALASKA ~ `~~-~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~IV`~I~ SEP 2 ~ 2007 PERMIT TO DRILL Alaska Oil & I;~S ~I~~IS. C~rrrmissioft 20 AAC 25.005 n^lCf3t31"8~°3 1a. Type of Work: Drill ^ Re-drill ^/ Re-entry ^ 1b. Current Well Class: Exploratory ^ Development Oil ^/ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 3A-036 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 8138' ND: 6318' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 527' FSL, 749' FEL, Sec. 7, T12N, R9E, UM 7. Property Designation: ADL 25631, 25632 ~ Kuparuk Oil Pool Top of Productive Horizon: 1299' FSL, 649' FEL, Sec. 18, T12N, R9E, UM 8. Land Use Permit: ALK 2564, 2565 13. Approximate Spud Date: 10/16/2007 Total Depth: 1065' FSL, 649' FEL, Sec. 18, T12N, R9E, UM 9. Acres in Property: 2560 14. Distance to '3ae~ ~ eS Nearest Property: 649' k'ei`-d° 4b. Location of Well (State Base Plane Coordinates): Surface: x- 507699 ~ y- 5996908 ~ Zone- 4 10. KB Elevation (Height above GL): X8.6' AMSL ~ feet 15. Distance to Nearest fj. yt• Well within Pool: 3F-19A , 1345' 16. Deviated wells: Kickoff depth: 4084' ~ ft. Maximum Hole Angle: 4g° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3431' psig ~ Surface: 2780 psig ~ 18. Casing Program if ti S Setting Depth Quantity of Cement Size ica ons pec Top Bottom c. t. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 7" 5.5" 15.5# L-80 Hydril 511 3688' 3884' 3094' 7572' 5832' - 70 sx LiteCRETE, 80 sx GasBLOK 4.75" 3.5" 9.3# L-80 Hydril 511 766 7372' 5677 8138' - 6318' - 80 sx GasBLOK 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 9735' Total Depth ND (ft): 6164' Plugs (measured) Effective Depth MD (ft): 9698' Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural 106' 16" 187 sx AS II 106' 106' Surface 3816' 9-5/8" 1200 sx AS III, 320 sx CI G 3888' 3098' Intermediate Production 7722' 7" 425 sx Class G, 250 sx AS I 7794' 5921' Liner 2612' 2-3/8" 25 bbls Class G 9730' 6164' Perforation Depth MD (ft): 8775'-9235', 9275'-9675' Perforation Depth ND {ft): 6133'-6147', 6156'-6162' 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program Q Time v. Depth Plot ^ Shallow Hazard Analysis ^/ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jason Brink @ 265-6419 Printed Name Randy Thomas Title Drilling Team Leader Signature ~ ` Phone '~~ ~ ~ 3o Date "C ~~~®7 h n All D k Commission Use nlyd•3•® Permit to Drill '"7 / Number: ~ p '- / ~ ~ API Number: Q ermit Approval 50- ~ ~~ ~~.,,i~.~~ Date: (~ , ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed me ane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No Mud log req'd: Yes ^ No [y]am Other: ~~~~\ ~~Zy~t v`~~3~. ~~ ~~ H2S measures: Yes [.~No ^ Directional svy req'd: Yes ~ No ^ /~ APPROVED BY THE COMMISSION / DATE: ,COMMISSIONER i Form 10-401 Revised 12!2005 ~ ~ (~ ! ~ ~ ~ /~~~~,/~ ,~ ~ Submit in Duplicate tf it 7/~(/ ~ Y• ~~, d7 • ~ Application for Permit to Drill, We113A-03B Revision No.O Saved:21-Sep-07 Permit It - Kuparuk We113A-03B Application for Permit to Drill Document Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 2S. 005 (fl ............................................................................................................. 2 2. Location Summary ...............:...........................:.:...........................::...........................2 Requirements of 20 AAC 25.005(c)(2) .........................................................................................................2 Requirements of 20 AAC 2S. 050(b) ............................................................................................................. 2 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 2S.OOS(c)(3) ......................................................................................................... 3 4. Drilling Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ......................................................................................................... 3 5. Procedure for Conducting Formation Integrity Tests ................................................... 3 Requirements of 20 AAC 25.005 (c)(S) ......................................................................................................... 3 6. Casing and Cementing Program .................................................................................. 3 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 3 7. Diverter System Information ....................................................................................... 4 Requirements of 20 AAC 25.OOS(c) (7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 q f ()() ....................................................................................... Re uirementso 20AAC2S.OOSc 8 ••.••••••••••••••• 4 9. Abnormally Pressured Formation Information ............................................................ 4 Requirements of 20 AAC 25.005 (c)(9) ......................................................................................................... 4 10. Seismic Analysis .......................................................................................................... 5 ........................................................................ Requirements of 20AAC25.005 (c)(10) ....................~. ` ••••••••• 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ....................................................................................................... 5 12. Evidence of Bonding ................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ....................................................................................................... 5 13. Proposed Drilling Program ......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ..........:............................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7 ~~ ~ ~ ~ R ~ ~ ~ 3A-038 PERMIT IT ~ t ~A~~l Page 1 of 6 • • Application for Permit to Drill, Well 3A-036 Revision No.0 Saved:21-Sep-07 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 Well Schematic .....................................................................................................................7 Attachment4 Cement Summary ..................................................................................................................7 1. Well Name Requirements of 20 AAC 25.005 (~ Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be ident~ed by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 3A-03B. 2. Location Summary Requirements of 20.4AC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on ftle with the commission and identified in the application: (2) a plat ident~ng the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 527' FSL, 749' FEL, Sec. 7, T12N, R9E, UM NGSCoordinates ' RKB Elevation 68.6' AMSL Northings: 5,996,908 Eastings: 507,699 Pad Elevation 40.6' AMSL Location at Top of 1299' FSL, 649' FEL, Sec. 18, T12N, R9E, UM Productive Interval Ku aruk C Sand) NGSCoordtnates Measured De th, RKB: 7,672' Northings: S, 992, 401 Eastings.• 507, 820 Total Vertical De th, RKB: 5,916' Total Vertical De th, SS: 5,847' Location at Total De th 1065' FSL, 649' FEL, Sec. 18, T12N, R9E, UM NGSCoordinates Measured De th, RKB: 8,138' ~ Northings: 5, 992,167 Eastings: 507, 821 Totad Vertical De th, RKB: 6,318' Total Vertical Depth, SS: 6,250' and (D) other information required by 20 AAC 25.050(6); Requirements of 20.4AC 25.050(b~ If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (I) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (BJ state that the applicant is the only affected owner. The Applicant is the only affected owner. .i,JGINAL 3A-038 PERMIT /T Page 2 of 6 • • Application for Permit to Drill, Well 3A-03B Revision No.O Saved: 21-Sep-07 3. BIowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) Ari application for a Permit to Drill must be accompanied by each of the following items, except for an .item already on file with the commission and identtfied in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c) (4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and ident~ed 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; Expected reservoir pressure for 3A-03B is 3400 psi at 5915' TVD. Equivalent Mud Weight @TD = 3400 psi =11.1 ppg ~ 5915'TVD x 0.052 The maximum potential surface pressure (MPSP) while drilling 3A-03B is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5915' TVD. MPSP = (GradientMud - Gradient~as )TVD GradientMud = l l.lppg x 0.052 = 0.58 f l t Gradientcas = 0.11 f l1 t TVD=5915 ft MPSP = 0.58 psl - 0.11 psl 5915 ft = 2780psi ~ ft ft (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 -Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. The procedure will be followed after milling the window in 7" casing and drilling 20'-50' of new formation. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: _ _. (6) a complete proposed casing and cementing program as reguired by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed ORIGINAL 3A-038 PERMIT IT Page 3 of 6 • Application for Permit to Drill, Well 3A-03B Revision No.O Saved: 21-Sep-07 Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) in) (lb/ft) Grade Conn. (ft) ) (ft) Cement Pro am Ori final Wellbore 9-5/8" 12-1/4 36 J-55 BTC 3,888' surface 3,888' / 3,098' 1200 sx ASIII & 320 sx Class G 7" 8-1/2 26 J-55 BTC 8,371' surface 8,371' / 6,363' 425 sx Class G & 250 sx AS I Est TOC 6,900' MD 3-1/2" 9.3 J-55 EUE 7,715' surface 7,715' / 5,861' Tubing 8rd AB Mod Sidetrack Plan 7" window 26 J-55 BTC 4,084' surface 4,084' ! 3,226' 70 sx 11.Oppg LiteCRETE, 3.30 5.5" flush jt 7" 15.5 L-80 HSldlll 3,688' 3,884' / 3,094' 7,572'/ 5,832' g0 sx 15.8 GasBLOK w/ Class G, 1.17 ft3/sk Hydril ' ' '" 1 ' ' 80 sx 15.8 GasBLOCK w/ Class „ 3-1/2 flush jt 4.75 9.3 L-80 511 766' / 5,677 7,372 / 6,3 8 8,138 G, 1.17 ft3/sk 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identifted in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC r This rotary sidetrack will exit pre-existing casing at +/- 4,084' MD. BOPE will be installed prior to exiting the casing; therefore, no diverter is required. , 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on f 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 using a LSND mud systems having the following properties: Sidetrack Hole mud bronerties Intermediate Interval Production Interval Depth NID 4084' - 7572' 7572' - 8138' Density (ppg) 9.0 -10.3 ! 11.1 ~ Yield Point (cp) 20 - 25 20 - 25 pH 9.0 - 9.5 9.0 - 9.5 API Filtrate(cc) 4 - 5 4-5 Diagram of Doyon 141 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identtfied in the application: A ~ ~ ~ ~ 3A-036 PERMIT IT (v= Page 4 of 6 Application for Permit to Drill, Well 3A-03B Revision No.O Saved: 21-Sep-07 (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths ofpredicted abnormally geo pressured strata as required by 20 AAC 25.03310; N/A -Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c) (10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.Oti1(a); N/A -Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(6); N/A -Application is not for an offshore well. 12.1Jvide~ace of Bondang Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item. already on fide with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bondingjhave been met; Evidence of bonding for ConocoPhillips Alaska, Inc, is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by, each of the following items, except for an item already on file, with the commission and iden(~ed in the application: ~ ~ ~, Pre-Rig Well Work: Wells Group will Supervise Pre-Rig P&A and will submit a separate Sundry and procedure for P&A. Current Wellhead: FMC Gen lV, 11"x 3IC, 7-1/16" x 5K Rig Work: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MI and RU Doyon 141. 2. With BPV installed, remove tree and tubing head adaptor. 3. Install BOP blanking plug and NU BOP on 7-1/16" SK flange. Test BOP to 3500 psi. 4. Ensure well is dead. Pull blanking plug and BPV. 5.. Pu113-1/2" tubing. 6. Insta117" storm packer. ND BOP. 7. Break tubing head from casing head flange. Replace leaking packoffs. 8. Install tubing head and NU BOP on 7-1/16" SK flange. Test BOP to 3500 psi. 9. PU mill, casing scraper, and 4" DP and RIH to top of tubing stub. POOH. 10. RU wireline set a CIBP inside the 7" casing at +/- 4084' MD based on casing collar depth. (Note: CIBP must be >_ 2.0' above a casing collar and >_ 20' below a casing collar) POOH, RD SWS. Test 7" casing and CIBP to 3000 psi and hold for 15 min. 1 ~ ~ ~ ~ ~ ~ ~ 3A-038 PERMIT IT Page 5 of 6 Application for Permit to Drill, Well 3A-036 Revision No.O Saved: 21-Sep-07 11. PU and RIH with Baker's "WindowMaster" whipstock system & window mill, bottom trip anchor, MWD, and UBHO on drill pipe from the derrick. Whipstock to be set on top of CIBP set at 4084' MD. 3c~~ ~-~~ 12. Orient whipstock, shear off, and POOH. 13. Displace Brine from hole with 9.6 ppg LSND new mud to mill window. Mill window and dri1120' new formation. Dress window. Pump super sweep pill. 14. Perform FIT/LOT. POOH and LD window mill etc. 15. PU bi-center bit & BHA, 4.0" DP, and RIH. ~~ ~~~ 16. Drill to casing point (7572' MD / 5832' TVD). MW expected to be 10.3 ppg. r 17. PU 5.5" flush joint liner and R1H. Liner overlap into 7" casing needs to be +/- 200'. 18. Reciprocate the liner while circulating and cementing. R/U Dowell and cement the liner. 19. Release from liner. Set packer. 20. Pull and lay down 4" DP. Pick up 2-7/8" DP. Change out BOP rams and test to 3500 psi. 21. Weight up to 11.1 ppg LSND. 22. Pick up and run 4-3/4" bit, 3-1/8" BHA, and 2-7/8" DP. 23. Tag cement. Drill out and perform an FIT/I,OT. 24. Dri114-3/4" Production hole to TD @ 8138' MD / 6318' TVD. 25. RU and run 3-1/2" hydri1511 liner. Reciprocate the liner while circulating and cementing. lt/LI Dowell and cement 3-1/2" hydri1511 liner. 26. Release from liner. Set packer. ' 27. Displace the well above the liner top with seawater until the returns are clean. Check for flow. POOH. LD/DP. 28. RU and RIH with 3-1/2" production tubing. Space out and land. RILD's. 29. Test tubing, PBR and liner to 2500 psi with the IA open for 15 minutes. Bleed the tubing down to 1500 psi. Test the IA, PBR and liner top to 2500 psi for 30 minutes (chart test). Bleed tubing pressure to zero psi. With tubing open; annulus pressure should shear dump kill valve (2000 psi casing to tubing shear). Bleed pressures to zero 30. Install BPV and blanking plug. ND BOPE. NU and test the 3-1/8" SK tree to 5000 psi. 31. Pull the blanking plug and BPV. ~ ` 32. Displace the well with diesel freeze protect fluid. 33. Install BPV. RD and MO Doyon Rig 141. Post-Rig Well Work: 1. Pull BPV. 2. RU SL. Drift and tag to PBTD. 3. .Dummy-off GLM. RD SL. 4. RU E-Line. 5. Perforate the Kuparuk "A" sand as directed. RD E-Line. o ~ i ~ ~ (\ j /fj f 3A-038 PERMIT IT 1 1 \YI !~-.]1 L Page 6 of 6 6. Install new "S" riser. 7. Frac and flowback "A" sand producer. 8. Turn over to Production. Application for Permit to Drill, Well 3A-03B Revision No.O Saved: 21-Sep-07 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal ~' well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary '?RIGINAL 3A-038 PERMIT lT Page 7 of 6 ~onocoPhillips Alaska, In~ CPAI Plan Report Company: ConocoPhillips Alaska Inc. llate: 8/20/2007 Time: 11:30:56 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3A-03, True North Site: Kuparuk 3A Pad Vertical (TVD) Reference: 3A-03Bwp02 68.6 Well: 3A-03 Section (VS) Reference: Well (O.OON,O.OOE,180AOAzi) Wellpath: Plan: 3A-036 Survey Calculation Method: Minimum Curvature ~ Db: Oracle Plan Section Information - - - - MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO 'Cargo ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg -- -- _ _ 4084.00 47.24 184.14 3226.81 -2144.41 -88.63 0.00 0.00 0.00 0.00 4377.78 41.58 174.45 3436.82 -2349.41 -86.98 3.00 -1.92 -3.30 -133.24 7389.37 41.58 174.45 5689.45 -4338.89 106.21 0.00 0.00 0.00 0.00 7732.77 30.00 180.00 5967.60 -4538.90 117.27 3.50 -3.37 1.62 166.58 3A-03Bwp02 T5 7849.39 30.00 180.00 6068.60 -4597.21 117.27 0.00 0.00 0.00 0.00 3A-036wp03 T6 8138.07 30.00 180.00 6318.60 -4741.55 117.27 0.00 0.00 0.00 0.00 Plan: 3A-036wp03 Date Composed: 7/30/2007 Version: 3 Principal: Yes Tied-to: From: Definitive Path Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: Kuparuk 3A Pad Site Position: Northing: 5996860.05 ft Latitude: 70 24 9.520 N From: Map Easting: 507712.01 ft Longitude: 149 56 14.019 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.06 deg Well: 3A-03 Slot Name: Well Position: +N/-S 48.29 ft Northing: 5996908.32 ft Latitude: 70 24 9.995 N +E/-W -12.90 ft Easting : 507699.06 ft Longitude: 149 56 14.397 W Position Uncertainty: 0.00 ft Wellpath: Plan: 3A-03B Drilled From: 3A-03 Tie-on Depth: 4084.00 ft Current Datum: 3A-03Bwp02 Height 68.60 ft Above System Datum: Mean Sea Level Magnetic Data: 5/3/2007 Declination: .23.22 deg , Field Strength: 57603 nT Mag Dip Angle: 80.84 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 7/30/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft ORIGINAL I°1/000OZI (+)y1i°!.!/(-)4r^OS O ~n z d 3 a` °J1 M O ~ a ~ 7 z 3 ~ rn rn is ~ -~ o c 0 O J Q on ~ E, c o W N a Q WJ .~ ~ W O 3 OpA M .f,. W 0 `o ~ z 3 ° W N N z ~° + 7 y M, e z a ~N ~ 0700 pN Moo 00 M ~ O O N N yN V~~~ ,~. t ~ '~ u ~ 0~0 f•" O ~~ C .p. ~ °z ~~¢R~ t_`-' ~~o-Q~o~rr 7 C ~ Q G CCb9 Q G F (] ~ ~ ~ ~ ~ O ~ O 0 fn LL N ~ ,-1 [¢- l] C] M ~ Oi 07 N 031 7 ~ GO pO 1 ~3 0 W ~ + [-+ 4 M ~ M 7 CC~ "~ a p Q M C rn O 00~ 0 0 Z 3 O a~ ~,g ~~ o ~_ ° ~¢ 3.v ~F ~ > a U N U v. c~ 3 ~ ~ U O M ~ O M a .o T N ~n a. O ~- o L ~ a ~ ~ w oO s ~. o ° 3 3 Cil °O + °O v~ v z N N W ~3 . ~ ~ pp.. I"" N Q M v ~ M z O N M t~ J ¢ >c~ ~ M 0. N Q 7 00 .C-i N r 7 ~ O O ~~ •- a •~ 0 /V V r 0 Q p M7M C W _ J :_._ i I ~ __- i ` i I ___.__-1 _... '. ~ 1. ~ .-..1.._... I o~ ........-... I~!MOOOZI Nda4 lea!uap avl 0 7 0 C 7 s r 0 2 F `~ o~o`O ~ O Mao Z [-. N z N 7 Q rOOOU ~ ~0 ~ ~ U~~~ E ~ ~ ~ ~ C z °~Q?Q' 3MtnM~ w U di di di di ti z cccct ~ ~~.. ~ ~ y u, va~av cC o: cL cG o s z~j u~ vcQ u C U v ~U ~~~p O ; ~ U ~ 0 0000000000000000000000 • oooo~no~nooooo0000000000000 ~ viO v~ O N vi l~ O ~ O v'i O OO OOO Nit ~O 000 ~n ~ ~ U I I I ( I I - --- --- Q ` F" ~ \ ~ ~ooooo sa"ooooo00 00ooooot~ o ~~ v,o~n o~,ooooo0 00000000 a ~ 4Y o N~l1[~ ~nt~o~nov-io~n 000000000. p( a 5m LJ. ~.~:.--+ •-• .-• N N M M_sS-7- -+fl-r GO O~ O N d' ~O 00 t~ 'w F L ~ ~ o ~ ~ ~ v~ .~ O ~ 3 ea~~rr I ~ ~ ~~ off. > ~ + ''~~_-_ ~ ~~ ~ ~\\ 1 U ~ m ~ Z $ T _ O c~i fN ~, / b P ~ ~ a o y._ e I ~ I '" h 7477 I u ~ '~ ~ '~ ~ ~ ~ ~ ~. ~ a ~~ A '~ ~" ~ OA / ~., t •, ., .. e ., i H ~ . Q 00 r V 8 ~ ~Fm, M N x a ~ ~ ~ ~ ~ g ~x w _ c ~ \~ __-____ - F: e -.V r,e... ,~ ~\..~-\ ~ 0 0 0 0 0 0 0 - ~ ~ ~ O O O O O O O O O O O O O O O O O O O O O O l~ ~ O O O O ~A O~ O O O O O O O O O O O O O O O O O O N ~ ~~ O V) O N 1n l~ O H O V'i O H O 00 O O O N~ ~D 00 O~ M E"N~h~-+~~~--~NNMM~~7 V'i ~O l~00 Q~~~"~^'~NN O O O O O O O C3-y O dct M N i ~ N M dV ~ ~ ~ V1 O M :: V I ( I I I ~ ~ I I I I I ~ N I I M ~~. ~ p p. ` r~ 'qj 0 0~ O~ O V'i O M O O O O O O O O O OQ'O O O O O ~ .. u L N V~I~ON~l~0~0~0 000¢000000 W > .• ~ •••.•~•r ••NNMM 7V'I~ 'Op 0~0~7~0-0 e u ^" ~ ~ ~ ~ W e z _o= O o = :- ,~ ., -~ o- ;- v ~ ~a; ' i ~ ~ Y O ~ - U y '2 ~ d ,y p Y U W OD ~ O LCyi O ~ =~ ~% ~ e c ~ , ~ ; ~ ` ~~'~ )`~ ~ '~ ~ % 9 K,},, C / ~ ~/ ,' / rl V M N c / > g ~ F ~~g~i 3 ~ ~g°mi .. Zn ° -aN$~ M N ~ -~ EtJa~ - 3.4 .Ss x M O ~ O O O Vi O M ~ a~ ~~~ ,~'~ wc~o~ N N •~ O ~ N N '~+ o ~s~NS =~zb o g sr'~ E ~ `~ '~~~C ~Ef ~ J 3~ ~~ cp'Sy ~3 3j~F~ ~1 3 u' :4J',~ M III II ~onocoPhillips Alaska, In~ Anticollision Report Company: C onocoPhillips Alaska Inc. ll ate: 8!2 0/2007 Tim e: 11:28 :00 Page: i Field: K uparuk River Unit Reference Si te: Kuparuk 3A Pad C o-ordinate (NF.) Reference: Well: 3A-03, True No rth Reference W ell: 3A-03 Vertical (TV D) Reference: 3A-036wp02 68.6 Reference Wellpath: Plan: 3A-03B Db: Oracle GLOBAL SCAN APP LIED: All wellpaths w ithin 200'+ 100/1000 of reference Reference: Plan : 3A-03Bwp03 & NOT PLANNED PR Interpolation Method: MD Inte rval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.00 to 8138.07 ft Scan Method: Trav Cylinder North Maximum Radius: 1011.01 ft Error Surface: Ellipse + Casing Casing Points _ MD TVD Diameter Hole Size Name ft ft in in 3884.60 3094.32 9.625 12.250 9 5/8" x 12 1 /4" 7640.06 5888.60 7.000 8.750 7"x 8 3/4" 8138.07 6318.60 4.500 6.125 4 1 /2" x 6 1 /8" Plan: 3A-03Bwp03 Date Composed: 7/30/2007 Version : 3 Principal: Yes Tied-to: From: Definitive Path Summary < _ __________________ Offset ~'1'cllpath ---------- ------------> Reference Offset Ctr-Ctr No-Go Allowable Site Wcll Wellpath _~lll MD Distance :1rea Deviation Warning ft ft ft ft ft Kuparuk 3A Pad 3A-03 3A-03 V1 4146.67 4150.00 1.41 131.85 -130.43 FAIL: Major Risk Kuparuk 3A Pad 3A-03 3A-03A VO 4146.67 4150.00 1.41 131.85 -130.43 FAIL: Major Risk Kuparuk 3F Pad 3F-13 Plan 3F-13B V1 Plan: 3 7612.73 9525.00 826.33 182.84 643.48 Pass: Major Risk Site: Kuparuk 3A Pad Well: 3A-03 Rule Assigned: Major Risk Wellpath: , 3A-03 V1 Inter-Site Error: 0.00 ft , Refe rence Offset Semi-]LiajorAsis Ctr-Ctr No-Go ;111owable ~1D TVD !~1D TVD Ref Offset TFO+A 7.I TFO-HS Casing/Il~istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 68.60 68.60 72.00 72 00 0.09 0.00 27.07 0.00 0.09 1.55 -1.46 FAIL 71.60 71.60 75.00 75.00 0.10 0.01 207.07 180.00 0.10 1.62 -1.51 FAIL 96.60 96.60 100.00 100.00 0.15 0.06 207.07 180.00 0.15 2.16 -2.00 FAIL 121.60 121.60 125.00 125.00 0.21 0.12 207.07 168.51 0.15 2.69 -2.54 FAIL 146.60 146.60 150.00 150.00 0.26 0.18 207.07 155.91 0.15 3.23 -3.07 FAIL 171.60 171.60 175.00 175.00 0.31 0.24 207.07 143.31 0.15 3.76 -3.61 FAIL 196.60 196.60 200.00 200.00 0.36 0.29 207.07 131.82 0.15 4.30 -4.14 FAIL 221.60 221.60 225.00 225.00 0.37 0.32 207.07 126.29 0.15 4.65 -4.50 FAIL 246.60 246.60 250.00 250.00 0.39 0.35 108.22 0.00 0.10 5.00 -4.90 FAIL 271.60 271.60 275.00 275.00 0.40 0.38 207.07 110.15 0.15 5.36 -5.21 FAIL 296.60 296.60 300.00 300.00 0.41 0.41 207.07 98.85 0.15 5.71 -5.56 FAIL 321.60 321.60 325.00 325.00 0.41 0.44 207.07 80.17 0.15 6.04 -5.89 FAIL 346.60 346.60 350.00 350.00 0.42 0.46 207.07 36.47 0.15 6.37 -6.22 FAIL 371.60 371.60 375.00 375.00 0.43 0.48 207.07 352.78 0.15 6.70 -6.54 FAIL 396.60 396.60 400.00 399.99 0.43 0.51 207.07 334.10 0.15 7.03 -6.87 FAIL 421.60 421.60 425.00 424.99 0.50 0.58 207.07 332.87 0.15 7.64 -7.48 FAIL 446.60 446.59 450.00 449.99 0.57 0.65 207.07 332.01 0.15 8.25 -8.09 FAIL 471.60 471.59 475.00 474.99 - 0.64 0.72 207.07 331.38 0.15 8.86 -8.70 FAIL 496.60 496.59 500.00 499.99 0.71 0.79 207.07 330.89 0.15 9.47 -9.31 FAIL 521.60 521.59 525.00 524.99 0.79 0.88 207.07 12.32 0.15 10.17 -10.02 FAIL 546.61 546.59 550.00 549.98 0.88 0.97 207.08 22.44 0.15 10.87 -10.72 FAIL 571.61 571.57 575.00 574.96 0.97 1.06 207.10 26.65 0.15 11.57 -11.42 FAIL 596.61 596.53 600.00 599.93 1.06 1.14 207.12 28.94 0.15 12.27 -12.12 FAIL 621.61 621.48 625.00 624.87 1.15 1.24 207.14 27.60 0.15 13.01 -12.85 FAIL 646.61 646.39 650.00 649.78 1.25 1.33 207.17 26.73 0.15 13.74 -13.59 FAIL 671.62 671.26 675.00 674.65 1.34 1.43 207.21 26.13 0.15 14.47 -14.32 FAIL 696.62 696.10 700.00 699.48 1.43 1.52 207.25 25.70 0.15 15.20 -15.05 FAIL 721.62 720.89 725.00 724.27 1.54 1.63 207.29 26.24 0.15 15.99 -15.84 FAIL 746.62 745.64 750.00 749.02 1.64 1.73 207.33 26.70 0.15 16.77 -16.62 FAIL 771.62 770.35 775.00 773.73 1.75 1.84 207.37 27.11 0.15 17.55 -17.40 FAIL SRAM ORIGINAL ~onocoPhillips Alaska, In~ CPAI Plan Report Company: ConocoPhillips Alaska Inc. llate: 8/20/2007 Time: 11 :30:56 Page: 2 Fietd: Kuparuk River Unit Co-ordi nate(NE) Referenc e: Well: 3A-03, Tru e Nor th Site: Kuparuk 3A Pad Vertical (TVD) Reference: 3A-03Bwp02 68 .6 Nell: 3A- 03 Sect ion (VS) Reference: Well ( D.OON,O.OOE,18 0.OOAzi) ~~'ellpath: Pla n: 3A-03 B Sun~ey Calculation method: Mi nimum Curvature Db: Oracle Surve~• - _ _ MD Incl Azim TVD Sys TV D N/S E/V1' VlapA b1apE DLS TFO Comment ft deg deg ft ft ft ft ft ft deg/100ft __- deg 3884. 60 48. 63 183.20 3094.32 3025. 72 -1995. 46 -80. 78 5994912.98 507620. 34 0.00 0. 00 9 5/8" x 12 1/4" 4084. 00 47. 24 184.14 3226.81 3158. 21 -2144. 41 -88. 63 5994764.04 507612. 65 0.78 153. 76 KOP 4100. 00 46. 91 183.66 3237.70 3169. 10 -2156. 10 -89. 42 5994752.35 507611. 87 3.00 226. 76 4200. 00 44. 91 180.54 3307.29 3238. 69 -2227. 85 -92. 09 5994680.60 507609. 28 3.00 227. 09 4300. 00 43. 00 177.21 3379.28 3310. 68 -2297. 22 -90. 76 5994611.23 507610. 67 3.00 229. 26 4377. 78 41. 58 174.45 3436.82 3368. 22 -2349.41 -86. 98 5994559.06 507614. 51 3.00 231. 66 4400. 00 41. 58 174.45 3453.44 3384. 84 -2364. 09 -85. 55 5994544.38 507615. 95 0.00 180. 00 4500. 00 41. 58 174.45 3528.24 3459. 64 -2430. 15 -79. 14 5994478.33 507622. 43 0.00 180. 00 4600. 00 41. 58 174.45 3603.04 3534. 44 -2496. 21 -72. 72 5994412.28 507628. 92 0.00 180. 00 4700. 00 41. 58 174.45 3677.84 3609. 24 -2562. 27 -66. 31 5994346.24 507635.40 0.00 180. 00 4800. 00 41. 58 174.45 3752.64 3684. 04 -2628. 33 -59. 89 5994280.19 507641. 88 0.00 180. 00 4900. 00 41. 58 174.45 3827.44 3758. 84 -2694. 39 -53. 48 5994214.14 507648. 36 0.00 180. 00 5000. 00 41. 58 174.45 3902.24 3833. 64 -2760. 46 -47. 06 5994148.09 507654. 84 0.00 180. 00 5100. 00 41. 58 174.45 3977.03 3908. 43 -2826. 52 -40. 65 5994082.05 507661. 33 0.00 180. 00 5200. 00 41. 58 174.45 4051.83 3983. 23 -2892. 58 -34. 23 5994016.00 507667. 81 0.00 180. 00 5300. 00 41 .58 174.45 4126.63 4058. 03 -2958. 64 -27. 82 5993949.95 507674. 29 0.00 180. 00 5400. 00 41 .58 174.45 4201.43 4132. 83 -3024. 70 -21. 40 5993883.90 507680. 77 0.00 180. 00 5500. 00 41 .58 174.45 4276.23 4207. 63 -3090. 76 -14. 99 5993817.86 507687. 26 0.00 180. 00 5600. 00 41 .58 174.45 4351.03 4282. 43 -3156. 82 -8. 57 5993751.81 507693. 74 0.00 180. 00 5700. 00 41 .58 174.45 4425.83 4357. 23 -3222. 88 -2. 16 5993685.76 507700. 22 0.00 180. 00 5800. 00 41 .58 174.45 4500.62 4432. 02 -3288. 94 4. 26 5993619.72 507706. 70 0.00 180. 00 5900. 00 41 .58 174.45 4575.42 4506. 82 -3355. 00 10. 67 5993553.67 507713. 19 0.00 180. 00 6000. 00 41 .58 174.45 4650.22 4581. 62 -3421. 06 17. 09 5993487.62 507719. 67 0.00 180. 00 6100. 00 41 .58 174.45 4725.02 4656. 42 -3487. 12 23. 50 5993421.57 507726. 15 0.00 180. 00 6200. 00 41 .58 174.45 4799.82 4731. 22 -3553. 18 ` 29. 92 5993355.53 507732. 63 0.00 180. 00 ' 6300. 00 41 .58 174.45 4874.62 4806. 02 -3619. 24 36. 33 5993289.48 507739. 12 0.00 180. 00 6400. 00 41 .58 174.45 4949.42 4880. 82 -3685. 30 42. 75 5993223.43 507745. 60 0.00 180. 00 6500. 00 41 .58 174.45 5024.22 4955. 62 -3751. 36 49. 16 5993157.38 507752. 08 0.00 180. 00 6600. 00 41 .58 174.45 5099.01 5030. 41 -3817. 42 55. 57 5993091.34 507758. 56 0.00 180. 00 6700. 00 41 .58 174.45 5173.81 5105. 21 -3883. 48 61. 99 5993025.29 507765. 04 0.00 180. 00 6800. 00 41 .58 174.45 5248.61 5180. 01 -3949. 55 68. 40 5992959.24 507771. 53 0.00 180. 00 6900. 00 41 .58 174.45 5323.41 5254. 81 -4015. 61 74. 82 5992893.19 507778. 01 0.00 180. 00 7000. 00 41 .58 174.45 5398.21 5329. 61 -4081. 67 81. 23 5992827.15 507784. 49 0.00 180. 00 7100. 00 41 .58 174.45 5473.01 5404. 41 -4147. 73 87. 65 5992761.10 507790. 97 0.00 180. 00 7200. 00 41 .58 174.45 5547.81 5479. 21 -4213. 79 94. 06 5992695.05 507797. 46 0.00 180. 00 7242. 50 41 .58 174.45 5579.60 5511. 00 -4241. 87 96. 79 5992666.98 507800. 21 0.00 180. 00 Top HRZ 7300. 00 41 .58 174.45 5622.61 5554. 01 -4279 .85 100. 48 5992629.01 507803. 94 0.00 180. 00 7389 .37 41 .58 174.45 5689.45 5620. 85 -4338 .89 106 .21 5992569.98 507809. 73 0.00 180. 00 7400 .00 41 .22 174.58 5697.43 5628. 83 -4345 .88 106 .88 5992562.98 507810. 41 3.50 166. 58 7435 .80 40 .00 175.04 5724.60 5656. 00 -4369 .09 108 .99 5992539.78 507812. 54 3.50 166. 48 3A-036wp02 T1 7500 .00 37 .83 175.92 5774.55 5705. 95 -4409 .29 112 .18 5992499.59 507815 .77 3.50 166. 14 7567 .40 35 .55 176.94 5828.60 5760. 00 -4449 .48 114 .70 5992459.41 507818 .33 3.50 165. 45 Top lower Kalubik 7568 .63 35 .51 176.96 5829.60 5761. 00 -4450 .19 114 .73 5992458.69 507818 .37 3.50 164. 64 3A-03Bwp02 T2 7600 .00 34 .45 177.47 5855.30 5786. 70 -4468 .15 115 .61 5992440.74 507819 .26 3.50 164. 62 7640 .06 33.10 178.17 5888.60 5820. 00 -4490 .40 116 .46 5992418.49 507820 .13 3.50 164. 20 3A-036wp02 T3 7672 .09 32 .03 178.77 5915.60 5847. 00 -4507 .64 116 .92 5992401.25 507820 .61 3.50 163. 62 Top Kuparuk C 7673 .27 31 .99 178.79 5916.60 5848 .00 -4508 .26 116 .93 5992400.63 507820 .63 3.50 163. 11 3A-036wp02 T4 7700 .00 31 .09 179.32 5939.38 5870 .78 -4522 .24 117 .17 5992386.65 507820 .87 3.50 163 .10 7732 .77 30 .00 180.00 5967.60 5899 .00 -4538 .90 117 .27 5992370.00 507820 .99 3.50 162 .65 3A-03Bwp02 T5 7800 .00 30 .00 180.00 6025.82 5957 .22 -4572 .51 117 .27 5992336.39 507821 .03 0.00 0 .00 7849 .39 30 .00 180.00 6068.60 6000 .00 -4597 .21 117 .27 5992311.69 507821 .05 0.00 0 .00 3A-03Bwp03 T6 7882 .88 30 .00 180.00 6097.60 6029 .00 -4613 .95 117 .27 5992294.95 507821 .07 0.00 0 .00 Kuparuk A2 7900 .00 30 .00 180.00 6112.43 6043 .83 -4622 .51 117 .27 5992286.39 507821 .08 0.00 0 .00 i ORIGINAL ~onocoPhillips Alaska, In~ CPAI Plan Report Company: ConocoPhillips Alaska Inc. hate: 8/20/2007 Timc: 11:30:56 Page: 3 Field: Kuparuk River Unit Co-ord inatc(NE) Reference: Well: 3A-03, True North Site: Kuparuk 3A Pad Vertical (TVD) Reference: 3A-036wp02 68.6 Well: 3A-03 Section (VS) Reference: Well (D.OON,O.OOE,180.DOAzi) ~Vellpath: Plan: 3A-03B Survey Calculation Method: Minimum Curvature Db: Oracle Survc~ ` -- D Incl Azim TVD Svs TVD M N/S E/W MapN MapE DLS TFO Comment I ff deg deg ft ~ ft ft ft ft ft deg/100ft deg __ _ _ - --- 7979.88 30.00 180.00 6181.60 6113.00 -4662.45 117.27 5992246.46 507821.12 0.00 0.00 Miluveach 7981.03 30.00 180.00 6182.60 6114.00 -4663.03 117.27 5992245.88 507821.12 0.00 0.00 3A-036wp02 T7 8000.00 30.00 180.00 6199.03 6130.43 -4672.51 117.27 5992236.40 507821.13 0.00 0.00 8100.00 30.00 180.00 6285.63 6217.03 -4722.51 117.27 5992186.40 507821.18 0.00 0.00 - 8138.07 30.00 180.00 6318.60 .6250.00 -4741.55 117.27 5992167.37 507821.20 0.00 0.00 4 1/2" x 6 1/8" Targets flap Map <--- - Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg M11in Sec Dip. Dir. ft ft ft ft ft 3A-03Bwp02 T1 5724.60 -4326.86 99.48 5992582.00 507802.99 70 23 27.441 N 149 56 11.484 W -Plan out by 43.29 at 5724.60 -4369.09 108.99 5992539.78 507812.54 70 23 27.026 N 149 56 11.206 W 3A-03Bwp02 T2 5829.60 -4418.87 107.39 5992490.00 507810.99 70 23 26.536 N 149 56 11.253 W -Plan out by 32.17 at 5829.60 -4450.19 114.73 5992458.69 507818.37 70 23 26.228 N 149 56 11.037 W 3A-036wp02 T3 5888.60 -4469.88 111.34 5992439.00 507814.99 70 23 26.035 N 149 56 11.137 W -Plan out by 21.15 at 5888.60 -4490.40 116.46 5992418.49 507820.13 70 23 25.833 N 149 56 10.987 W 3A-036wp02 T4 5916.60 -4494.89 113.31 5992414.00 507816.99 70 23 25.789 N 149 56 11.079 W -Plan out by 13.86 at 5916.60 -4508.26 116.93 5992400.63 507820.63 70 23 25.657 N 149 56 10.973 W 3A-036wp02 T5 5967.60 -4538.90 117.27 5992370.00 507820.99 70 23 25.356 N 149 56 10.963 W -Plan hit target 3A-036wp03 T6 6068.60 -4622.91 117.18 5992286.00 507820.99 70 23 24.530 N 149 56 10.966 W -Circle (Radius: 100) -Plan out by 25.70 at 6068.60 -4597.21 117.27 5992311.69 507821.05 70 23 24.782 N 149 56 10.963 W 3A-03Bwp02 T7 6182.60 -4721.92 122.08 5992187.00 507825.99 70 23 23.556 N 149 56 10.823 W -Plan out by 59.09 at 6182.60 -4663.03 117.27 5992245.88 507821.12 70 23 24.135 N 149 56 10.963 W Annotation MD I'Vll ft ft 4084.00 3226.81 KOP Casing Points _ MD TVD Diameter Hole Size Name _ ft ft in in 3884.60 3094.32 9.625 12.250 9 5/8" x 12 1 /4" 7640.06 5888.60 7.000 8.750 7"x 8 3/4" 8138.07 6318.60 4.500 6.125 4 1 /2" x 6 1 /8" Formations _ _ MD TVD Formations Lithology Dip Angle Dip llirection ft ft deg deg 0.00 Base Permafrost 0.00 0.00 0.00 Top Ugnu 0.00 0.00 0.00 Top West Sak 0.00 0.00 0.00 Base West Sak 0.00 0.00 7242.50 5579.60 Top HRZ 0.00 0.00 7435.80 5724.60 Top Kalubik 0.00 0.00 7567.40 5828.60 Top lower Kalubik (K1) 0.00 0.00 7640.06 5888.60 Top Kuparuk D 0.00 0.00 7672.09 5915.60 Top Kuparuk C 0.00 0.00 7732.77 5967.60 Kuparuk B 0.00 0.00 7849.39 6068.60 Kuparuk A3 0.00 0.00 7882.88 6097.60 Kuparuk A2 0.00 0.00 7979.88 6181.60 Miluveach 0.00 0.00 ORIGINAL Drilling Hazards 6-1/8" Hole Event Risk Level Miti ation Strate High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD tool. Pump hi her MW's re wired and rotate out on trips as a last resort. Barite Sag Low Use Good drilling practices as documented in well plan and keep track of mud ro erties in line with mud ro am. Differential Sticking High Do not leave pipe static for extended period of time. Proper drilling practices and keep connection time to minimum. Hole instability while drilling High Use enough MW to stabilize HRZ / Kalubik without sustaining losses HRZ / Kalubik Shale section Lost Circulation Moderate Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree as needed. 4-3/4" Hole Event Risk Level Miti ation Strate High ECD and swabbing with High Condition mud prior to trips. Monitor ECD's with PWD tool while close tolerance and higher drilling across pay interval. Pump and rotate out on trips as a last MW's re wired resort. Abnormal Reservoir Pressure Moderate / Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed., Ensure adequate kick tolerance prior to drilling pay interval. Have spike fluid available. Differential Sticking Moderate Wiper trips as needed. Do not leave pipe static for extended period of time. Lost Circulation Moderate Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology. Use LC decision tree. ORIGINAL ,.. ~a~o~a~n~ii~ps Alaska ~~ t_.._ ConocoPhillips Alaska, Inc. • Kuparuk River Unit Kuparuk 1J Pad _~ 1/4 Mile Pool Scan ~.~ er rilli , S~r~rices August 27, 2007 • L tlT ~' " ~°s ' °<r ~ ~ - ° ~ ~ ~ ~ '~'~'~~ Drllling and Formation r.~.~.m Evaluation r ~M~ Plan: 3:~-p3B (w~03) (3A-U3IP1an 3A-03B) Closest in POOL ~~ ~~ }~ i Closest A roach: Reference Well: 3A-03 6w 03 Plan ¢~~~a ell: -7" CooMs. _ Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)!S(-) View VS Distance. De th Ind. An le TRUE Azi. ND E + /W - 180° Comments De th Ind. An le TRUE Azi. ND E + ply _ 180° Comments in is nce (1344.71 ft) in POOL (6150 - 6250.96 POOL Min Distance (1344.71 ft) in j TVDss) to 3F-19A POOL (6150 - 6250.96 TVDss) to (6096 - 6196.72 3FW3Bwp03 Plan (6096 - 6196.72 :13&4.71 8138 30 180 6250.956 5992167.5 507824 4740.948 TVDss) 8254 38.99 338.95 6796.716 5990834 507659.4 6074,255 NDss) Closest A roach: Reference Well: 3A-03 Bw 03 Plan Offset Welh -~t~ Coords. - Coords. - ASP ASP 3-D ctrttr Meas. Subsea N(+)/S(-) vew VS Meas. Subsea N(+)/S(-) Yew VS Distance. De th Ind. An le TRUE Azi. ND E + my _ 180° Comments De th Ind. An le TRUE Azi. TVD E + /W _ 160° Comments in istance (1447.32 ft) in POOL (6150 - 6250.96 POOL Min Distance (1447.32 ft) in NDss) to 3F-13A POOL (6150 - 6250.96 TVDss) to (6016 - 6116.46 3A-036wp03 Plan (6016 - 6116.46 1447;:4G 8138 30 180 6250.956 5992167.5 507824 4740.948 TVDss) 9350 64.1 351.78 6116.458 5991681.8 506467.3 5225.055 TVDss) ..~ POOL Summary.~ds 8/27/2007 10:54 AM 3A-036 070823 Window 7 inch Topset Plan Schematic 3A-03B SIDETRACK / TOPSET COMPLETION wp0~ ~ConocoPh~ll~ps Circulate corrosion inhibitor before landing Original completion RKB 73' from mean sea tubing hanger. Inhibit corrosion up to bottom level (PAD 42', 31' RIG AIR GAP) GLM. 3'/z' FMC Gen 4(converted in 5/1999 workover) Tubing Hanger, 3'/2' L-80 IBT Mod 9-5/8" x 7" annulus pin down arctic packed 9/22/ 3'/2' 9.3# L-80 IBT Mod Spaceout Pups as Required 1985 w/ 47 bbls cmt & 65 bbls diesel. sssv 3'/i' 9.3# L-80 IBT Mod Tubing 3 Yz' Camco SCSSSV TRMAXX-5E with 2.812 Profile Nipple Bore set at +/- 2000' MD/ 2000' TVD 3'/2' x 6' L-80 handling pups installed above and below, IBT Mod 9-5/8" 36# J-55 BTC casing Set @ 3888' MD / 3098' TVD (Original LOT 12.5 ppg EMVh 5.5" X 7" Liner Top TOBE@ 3884' MD / 3094' TVI Sidetrack KOP w/ window in 7" @ 4084' MD / 3226' TVD Whipstock Orientation to be XX degrees from high side Baker "K-1" CIBP below set point for whipstock @ +/- 4109' MD 3-1/2" tbg cut and pulled from +/- xxxx' above the packer. Top of cmt P&A plug @ xxxx'. CT Liner top PKR 7105' MD PKR 7680' MD Original Wellbore 7.0" csg 26.0# J-55 BTC @ 8371' MD TOC est. 6900' MD 3'/z" 9.3# L-80 IBT Mod tubing 3'/z" x 1"Camco 'KBG-2- 9' mandrels 3'/i' x 6' L-80 handling pups installed above and below, IBT Mod 3'/z" x 1" Camco 'KBG-2- 9' mandrel w/ shear valve, pinned for 2000 psi shear (casing to tubing differential), 3'/2' x 6' L-80 handling pups installed above and below, IBT Mod GLM # TVD-RKB MD-RKB 1 x x 2 X X 3 X X 4 x x 5 2 joints above nipple profile 3'/2' Camco 'D' nipple w/ 2.75" No-Go profile TWO joints above seal assembly. 3'/z" x 6' L-80 IBT Mod spaceout pup installed above, 3'/z" x 6' handling pup installed below 5'/~" liner asse~r~bl~~: 5-1/2" 15.5# Hydril 511 Liner shoe @ 7572' MD / 5832' TVD 3-'/z" ,.n,r r`-.~ °~~mbly top Ccil 7372' MD / 5677' TVD: 3-1/2" 9.3# Hydril 511 Liner shoe @8138'MD/6318'TVD Topset Point: 5-1/2" 15.5# Hydril 511 Liner 7572' MD / 5832' TVD 5-'/z" Centrilization: 5-19/32" x 6-1 /8" rigid stand off band between stop collars 1 perjoint TD: 3-1/2" 9.3# Hydril 511 Liner @ 8138' MD / 6318' TVD 3'/z" Centrilization: ~°fD ~f~"D Foraeatinss ft ft 0.00 Base Perr=iafrost 0.00 Top tlgnu 0.00 Top'ti"r'est Sak 0.00 Base'~a'est Sak 7242.50 5579.60 Top FiRZ 7438.30 5724.60 Tvp Kal~lhik 7567.40 5828.60 Top lower Kalubik (K1 } 7640.06 5888.60 Top Kuparuk D 7672.09 5915.fi0 Top Kuparuk C 7732.77 5967.60 Kuparuk B 7849.39 .60ti8.60 Kuparuk A3 7882.88 6097.80 Kuparuk A2 7979.33 6181.60 FAiluveach LWD Loaaina: 6- 1/8" hole: GR/RES/ NEU /DEN 4- 314" hole: GR/RES Ogen Hole Loaaina: NONE BHP Est.: C sand: 9.1 - 11.1 ppg EMW A sand: 10.1 - 10.8 ppg EMW 10.6 ppg likely top EMW for C & A JAB 8/23107 ~~r~~~.~ ~: CemCADE Preliminary Job. Design 5.5" Intermediate Casin Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska, Inc. Revision Date: 9/21/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com ~' Previous Csg. < 7", 26.0# casing at 4,084' MD < Top of Tail at 7,072' MD < 5 1/2", 15.5# casing in 7" OH ' TD at 7,572' MD ~s,8s2' TvD) Volume Calculations and Cement Systems Volumes are based on 50% excess. LEad slurry is designed for 1500' MD and tail is designed for 500' MD above the intermediate casing shoe. Lead Slurry Minimum thickening time: 180 min. (Pump time plus 120 min.) LiteCRE 3E @ 11.0 ppg - 3.30 ft3/sk 3 / 0.1023 ft /ft x 1500' x 1.50 {50 /° excess) = 230.2 ft 230.2 ft3/ 3.3 ft3/sk = / 69.8 sks Round up to 70.0 sks Tail Slurry Minimum thickening time: 180 min. (Pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % 6155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk 0.1023 ft3/ft x 500' x 1.50 (50% excess) = 76.7 ft3 0.1336 ft3/ft x 80' (Shoe Joint) = 10.7ft3 10.7 ft3+76.7 ft3= 87.4 ft3 87.4 ft3/ 1.17 ft3/sk = 74.7 sks Round up to 80 sks /` BHST = 120, Estimated BHCT = 97`F. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage (bpm} (bbl) (min) . (min) ,Comments Drop Bottom Plug 10.0 10.0 MudPUSH II 5 25 5.0 15.0 Start Pumping Spacer Lead Slurry. 6 41 6.8 21.8 Mix and Pump Tail Slurry Tail Slurry 6 17 2.8 24.6 Mix and Pump Tail Slurry Drop Top Plug 5.0 29.6 Pump Water 4 20 5.0 34.6 Switch to Rig Pump 5.0 39.6 . Displacement 5 108 21.6 61.2 Start Displacement Slow Rate 3 50 16.7 77.9 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH* I I, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint across zones of interest for proper cement placement. CemCADE Preliminary Job Design 3 1/2" Liner Preliminary Job Design based on limited input data. For esfimate~purposes only. Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska Revision Date: 9/21/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Top of Tail at µ:;,_ < 7,172' MD ,~, ~`~` z, < Liner Top at 7,372' MD Previous Csg. 5 1/2", 15.5# casing at 7,572' MD < 3 1/2", 9.3# casing in 4 3/4" OH ~. TD at 8,138' MD (6,318' TVD) Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 50% excess. Displacement is calculated with a 2.9"- 10.4# drill string. Cementjob is designed to seal off liner top by bringing cement 200' above liner top, with 15.8 ppg G cement (cement type as per client's request). Tail Slurry Minimum thickening time: 130 min. (pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % 8155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk Liner Cap: 0.0886 ft3/ft x 200' x 1.00 (no excess) = 17.7 ft3 Liner Lap: 0.0668 ft3/ft x (7572' - 7372') x 1.00 (no excess) = 13.4 ft3 Annular Volume: 0.0562 ft31ft x (8138' - 7572') x 1.50 (5070 excess) = 47.7 ft3 Shoe Volume: 0.0488 ft3/ft x 80' x 1.00 (no excess) = 4.4 ft3 Totals: 17.7 ft3+13.4ft3+47.7ft3+4.4ft3= 83.2 ft3 83.2 ft3/ 1.17 ft3/sk = 71.1 sks Round up to 80 sks BHST = 131 ~, Estimated BHCT = 117. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Volume Time Stage (bpm) (bbl) (min) (min) Comments MudPUSH II 5 15 3.0 3.0 Start Pumping Spacer Tail Slurry 5 17 3.4 6.4 Mix and Pump Tail Slurry Drop Wiper Dart 3.0 9.4 Displacement 6 29 4.8 14.2 Start Displacement Displacement 3 10 3.3 17.5 Slow to Bump MUD REMOVAL Recommended Mud Properties: 11.1 ppg, Pv < 15, TY < 22; As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH* II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint from Previous Casing to TD. ORIGINAL TRANSMITTAL LETTER2CHECKLIST WELL NAME ~~~ ~~ '~~ PTD# Z~ ~~ Development Service Non-Conventional Well Exploratory Stratigraphic Test 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 AAG 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 / infect 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 ~Compan~Name) has designed and implemented a water well testing program td provide baseline ,data on water quality and quantity. ~Compan~Name) must contact the. Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 ~ • ^^ N , , rn n y N , a~ o , , $ ~ ~: , I ~ ~ N: p > i t , C, : V, o p w ~ ~ ' ~ >: a, ' a ~ ' ~ N >' : c , ~ a ~: m ' a ' ~ ca ~ a N ~ r ~ a: - M, ami: m a m o - ~~ O ~ g; u~ ~ o~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ o~ ~ Q , m~ ~ ~ c, ~ a ~ : ~ ~~ ~ : : , o` r i ° : ° ~ O m ~ ~~ ~ N: ~, N: N ~ N ~': •° - o ~: L: y ~: ~ ~ , ~ _ ~ ~ 3; a o' c U. 3 0 c o c m: ~ -a a~: N ,~, a o, ~: aD ~ ~: Z N: ~ ~ >, ~ v , ~, v ~: ~ ~ ~: m, 3. ~: ~: : ~ a i: ~: o : ~ ~ a: °- in v> °-T ~ ~ ~~ ~ rn i co N: ~: ~ v m ~, - Q, a, ~, ~ ~~ c: o~ J: N in m Ol N ~ ~•_, ~: m: C: O: ~ ~ O' t/~ m VI C : O: - O 2 22 Q ~ m' N' ~ ~~ c N~ Q ~ ~: , ~ N r ~ m ~ N w M G , J, C •C: •~, ~ ~: : . ~ ~: O: : y, , y, N: : N: ~ 6 O) 4 Z o~ ~ • ~' ' 3' ~ , ~ m: ~ ~: ° : ~: ~ y ,~ ~ o ~ o ~ Y: ~ N. ~ N. ~ ~ O ~ w N ~ ~: ~: N: N: ~ N: N, L ~ ~ ~, LL U M U ~ Q "O: N p• .~ g: ~ a ~ : ~ Y ~ ~: N: : M: M, Q, V, 'V. M: V 3 : O: O O O: .O ~ N _ m Or O a O: C: ~ O ~~ ~: p. p, : p. : c: . ~., M: ~: M: O. c N: N: ,~, ~ ~ o. ~: Q. ~ ~: a rn Q Y: Z: Z. Z: _, o: ~: c: : ~ m: a N: Q' ~: a Y a' a' a' ~ , ~ g. > O, O. O. o i c: ~: ~, ~ ' v: ' N, ~, ' ~: ~, ' ~ : ~: ~: ~ : Q ai o m' ~, C: C: g, o, c. o, py ~ ~ ~ x N. p: m : m '~ ~ -: o o pQ a ~ - c 3: , , a x m, io ~ ~ m ~ N~ ~, m m m: E m O o: Y ~~ Z~ Z~ ~~ ~ ~ ~ ~ ~ ~: ~' ~ ~~ _ ~ ~ ~ ~ Y m te m' ~~ ~ ~ v ~ ~~ i a ~~ ~ Z m: Q' ~: ~' ~ , : , . a : : ~' . : , : _ N ~ > Z m 't: p: ti ui ~: c: c. ~: O: O: vi c' O: N• C. a a ~ m: O. -: m ,C: p: 3, p: v_i ~ ~ r> ~, X• 0.: O. O: ~X: m: ~: Q. ~: N: d, Q: N: ~ '0: ~, w ~: ~[: U: (~, U: m: V: Q: N: Z: ~: M. a, m: g: ~: _: M: W: ~, a , j , w : ~ , I I Q p N~ N N N O M: N N: N (//: N: N: N N N N, N N N ( Q 7 Q Q Q Q Q Q Q N: N N: N U/: N N: O N: N Q (/1: O N: N, N: O O O N: N: O O I Q ~ O N: d Q ¢ a N , Q : . Z } , , : . } } ~- ~- , } , } , , , } } ~ , } } , , , Z Z Z Z' j , . Z Z . Z' , Z , ~ , } . } : } , : } Z : ~- : : : ~- } } : : ~ } , Z ; - Z, : } , : Z Z , Z ,, A , II ~ V, T : ~I '' c0 ~ I O , ~. p0: I ~ C, - N, ~ E: 3: I , - E: m. ~ ~ II ~: U: , I ~ ~ ~: ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ o c , ~ `~ o ~: ~ ~ ~ .~ ~ , ~, o ~: ~ -: ~: „ o U a~; ~, ~. a 3:I o, ? M• : O: v' y: ~: U: I : ~ c o. Z, ~: O. ~: a~: ~: ~: : o ~: ~ ~ ~ ~: N: N. N: N: ~ Q N, O: O O. N: ~ ~i Q :, 3. ~, v C: ~ N: m: O ~, ~: ~ ~: ~, O. ~ a: O: a, , ~: t~ 0: C: d~j: a N tn, N m N Q' 7. N, C: >: ~` .N. G a: O 'i y: O: 7, O: C: y: m C >, N• N W ~ OD 3= C •~~ Q . ~ 3 p: ~, ~ M O O om ~: U: 0 O, ~ ,N: ~, C N O: a - fl pQ ~ 0: ~'. i a: ~ ~: O, (~ : ~, _: t: O: ~ f6' ~, ~: ' :y: T m : r ..' 3: ?r, N. O: m d Q' ~: 0' - C, ' Ql O' L oif.. C, : ~: N• ~: . . ~ M: ~: t(}: a: ~: ~: j Q• i ~: 3: ~: ~: ~. .. Y Z~ -a: ~: p: a p p: p: a : N. ~: o: c: N: m: O o, OD p: d t: c: N: c, ~ a ~ - ~ , Q E E, ' = ~ a, C C : E~ .o: r N O M~ ~: m: C' 3: ~ : ~ ~: ~ r.: C : O otf' w~ ~~ c, C' a~. ~~ N' Q : N t N: O: C C o ~ Y o o „ ~ ~ ' o a: U: m, ~ ~ Q, ' o: o rn ~ ~j~ 'o. m ~~ Q a~, ~ • o: : a. o .n: 3~ o m y N ' ~ ~~n a d ' ~, o; Q m' m' ._ , ~ c, O in o. ~°- c. ~. c ' a " m: m: c m ' m: ~ Q. (6 io, m w. a o. ~ , rn o ~ ~ a~ ,w ~ ~ o~ o: ~: E' a m, >, O 3 -C s' o' 7 o' m a m (6~ ~ c' ~' m. Y - m ~ O o 0; Z' o' O ~ .. m E• (6 ~' 3' ~ a~' a ~' >. •c' m ~: 3' a~: C E c Y ~ Q ~ m m a ' ~ ~ ~ m, t_, ~_. ~ m: ~ ~: a~ m~ ~ S: . m: a>~ . •-, a~, o a ar a a 3' o' _ °' ~' E ~ . , c , a: ~: u~; ui •~: o, a. ~, 3, ~ 3. aai ami, ~ ~: o, ; ~ ~' '~, .°-~, 3:: ~: ~ Q fl. ~ y: ~ 4 ~ ~' ~': o ~ 3, ~ ~, ~ o w U g ~ Q O: c: ~: `a, >: o ~ a. m, a: 'o m: '~ `o: c ` o aoi o: o, ~: a o, ~ y -°o. ' a~ ~ a : o: rn c, ''~ a: a ~, ~: m: a ~ a, Q m, ai ' N' N' m ~: O, a> ~: • m : d s , TJ: O, , • ' Y' o o ' E ' a> E ' ' r (/j: o; a> : : ~ : N, c : V J N : N a fl O N 7 4 C ~. C ~ O O: O` ~ N a N N ~ ` m D) O ~ U C N ~ '~ ] C O O p~ = t ~ U: ~ l : ~: O. O, ~ m: ~. ~: N: ~: m: ~ ~: Q m L' r ' ' N, j C, O7 0- : m : c6 , (6 m: p: Q7 m: m' p' ~: : 01 O. : : 7, a: 3: : Z: _' ~, C,~ N, .~. O: : N: C,. ~ : O: L. Q pl ~°: ~: ~, .5. n a ~: N: >, N m: o: a~ m 3. ~, a rn ~I C '" c O a > ~ ~: ~ ~: m ~ ~ ~ o: ~, m: o: ~: o o: ', m a m: O >, :6 u~ ii C.h m: ~. E -, a~ a~ a~ a> a~ U. m ~ . c: m: .o: c .a: -p a: ~ a>: i v ~ a> ;~: •~: a~: a m: a >: o ~ m: .c, m: 3' v' ti: o ~ ~~ o: m' ~ ~ c: m m c: ~ ~ a Oi - ar 3 : ~, ar ..~ 3 m m m , a : o: s. m c: m E : 3' ~' m ~ m m: o' o m' m' o: ar m' _ - ~ m: a' a~' o: ~: - c : o , c: m : m m ~: ~: ~ Z ~: : C . . : : U U U ~. m: m , O O U U~ N : U V1~ 0' C~ fJ N O O~ - _ a~ (6 'O~ v m O~ O" ~' _ -: . ~ p > ~~ ~ I U~ ~ U a fn O .J a~, ' ~ 0 0 0 .~ m; m a o' ~ o , ~ ~ U ~ ~ > > ' 3' m ~ ~ ~ ~' ~ w w. m '' ~' Y ~ m' ~ ~~ °- , ~ m ~ ~: ~i J U ~ . ~: .~ a~ a> a> ~, a a a~ a~ ~ Q ~ c ~~ 3 ~ ~ c , 'C, I-, F- ' 1- ' 'y: a~i a~i~ > = ~ d, o o a ~ : , ~ :.° : .~ m c: m U ~ m: a~: a ~ c ~ ~' ~ ~ ~ cn ° -; n a~ O a O' m a m U o ¢ ~; z' ! ~' o, ~, U cn ~, U ~ U' ~ U' m U' a. ¢ m: ~ a, a Q ~; o O, O. L: m m v ~' ti m: ~ a~: a m, q a> a>. U cn o: U ~ W a , , , , , , , _ , O , N M , C 47 (D I~ ~~ M 61 , O _ , N , M V : t0 , (O f~ , 00 : , _ 61 O N M : I V I : LL) M ~ M d) O ~ N M V ~O (O f~ 00 O ~_ ~ ~ ~ ~ ~ ~ ~ N N N N N N N N N N M M M M Mi M M - M M M U , _ __ _ , _ _ _ _. I _ - __ _. -_ V F- O O ° .. O C •~'' N •p+ O "p" N U p o O_ ~'' ~ N ~ 01 ~ ~ N ° ~ W a ~ y °~ ! .~ o °~ - aoi E J o N y ! ~ I ~ O E E E a ~ ~ Q. ~ ~ o a o U W ~a a a ~ ~ ~ a ~ ~ ~ C7 an w Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Penrritting Process but is part of the history file. To improve the readability of the Well History file and to simplify Minding infom~ation, information of this nature is accumulated at the end of the fife under APPENDIX. No special effort has been made to chronologically organize this category of information. • r 3a-03b.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Feb 13 08:34:29 2008 Reel Header Service name .............LISTPE Date . ...................08/02/13 Ori9in ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/02/13 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 W-0005373121 P . ORTH P. WILSON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services 3A-036 500292143202 ConocoPhillips Alaska, Inc Sperry Drilling Services 13-FEB-08 MWD RUN 3 MAD RUN 3 W-0005373121 W-0005373121 P. ORTH P. ORTH P. WILSON P. WILSON 7 12N 9E 527 749 68.60 40.60 Page 1 ~o~--~ 3 ~ ~ ~ 5~ ~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 3a-03b.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 4104.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 3A-03 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 4104'MD/3240'TVD. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 1, PRIOR TO PICKING UP LWD TOOLS. NO DATA ARE PRESENTED FOR RUN 1. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 3 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND GEOPILOT ROTARY STEERABLE BHA (GP). MAD DATA WERE ACQUIRED OVER TWO INTERVALS (8267'MD-7990'MD & 7600'MD-7333'MD BIT DEPTHS) WHILE POOH AFTER REACHING FINAL TD. 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM PAT PERFETTA (CPAI) TO ROB KALISH (SDS), DATED 2/8/2008. 6. MWD RUNS 1-3 REPRESENT WELL 3A-03B WITH API# 50-029-21432-02. THIS WELL REACHED A TOTAL DEPTH OF 8285'MD/6444' 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 RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX,FIXED 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 Page 2 3a-03b.tapx BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125~~ BIT MUD WEIGHT: 9.0-11.0 PPG MUD SALINITY: 250-700 PPM CHLORIDES FORMATION WATER SALINITY: 14545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH SGRC 4085.5 8227.5 SESP 4100.0 8234.5 SEXP 4100.0 8234.5 SFXE 4100.0 8234.5 SEDP 4100.0 8234.5 SEMP 4100.0 8234.5 SROP 4142.5 8285.0 TNPS 4181.5 8198.5 CTNA 4181.5 8198.5 CTFA 4181.5 8198.5 SBD2 4195.5 8213.5 SNP2 4195.5 8213.5 SCO2 4195.5 8213.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 2 4085.5 4267.0 $wD 3 4267.0 8285.0 Page 3 ~ • 3a-03b.tapx 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 Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 4085.5 8285 6185.25 8400 4085.5 8285 FCNT MWD CNTS 147 1450 281.371 8035 4181.5 8198.5 NCNT MWD CNTS 16105 42491 21575.6 8035 4181.5 8198.5 RHOB MwD G/CM 2.134 3.164 2.36748 8037 4195.5 8213.5 DRHO MWD G/CM -0.141 0.406 0.0624969 8037 4195.5 8213.5 RPD MWD OHMM 0.21 2000 4.61028 8270 4100 8234.5 RPM MWD OHMM 0.21 418.54 3.5883 8270 4100 8234.5 RPS MWD OHMM 0.23 1052.01 3.57506 8269 4100 8234.5 RPX MWD OHMM 0.25 1196.44 3.61308 8270 4100 8234.5 FET MWD HOUR 0.54 25.49 2.10784 8270 4100 8234.5 GR MwD API 42.09 569.28 130.166 8285 4085.5 8227.5 PEF MWD BARN 1.83 9.72 3.38577 8037 4195.5 8213.5 ROP MWD FT/H 5.22 178.59 53.3978 8286 4142.5 8285 NPHI MwD Pu-s 14.4 52.76 38.3672 8035 4181.5 8198.5 First Reading For Entire File..........4085.5 Last Reading For Entire File...........8285 File Trailer Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/13 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Page 4 3a-03b.tapx Physical EoF File Header Service name... .......STSLI6.002 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/02/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE NPHI FCNT NCNT RHOB DRHO PEF GR RPS RPD RPM FET RPX RAT MERGED DATA SOURCE PBU TOOL CODE MWD START DEPTH STOP DEPTH 7247.0 8180.5 7247.0 8180.5 7247.0 8180.5 7261.5 8199.5 7261.5 8199.5 7261.5 8199.5 7275.5 8213.0 7282.5 8220.5 7282.5 8220.5 7282.5 8220.5 7282.5 8220.5 7282.5 8220.5 7333.5 8267.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 3 1 4181.5 8285.0 REMARKS: MERGED MAD PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD CNTS 4 1 68 4 2 NCNT MAD CNTS 4 1 68 8 3 RHOB MAD G/CM 4 1 68 12 4 Page 5 3a-03 b.tapx DRHO MAD G/CM 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HOUR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD BARN 4 1 68 44 12 RAT MAD FT/H 4 1 68 48 13 NPHI MAD PU-s 4 1 68 52 14 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 7247 8267 7757 2041 7247 8267 FCNT MAD CNTS 140 623 257.726 1089 7247 8180.5 NCNT MAD CNTS 16701 30473 20021.6 1089 7247 8180.5 RHOB MAD G/CM 2.005 2.797 2.38395 1100 7261.5 8199.5 DRHO MAD G/CM 0.004 0.239 0.0909773 1100 7261.5 8199.5 RPD MAD OHMM 1.06 41.88 4.44721 1100 7282.5 8220.5 RPM MAD OHMM 0.93 42.31 4.25046 1100 7282.5 8220.5 RPS MAD OHMM 0.89 47.27 4.30738 1100 7282.5 8220.5 RPX MAD OHMM 0.86 43.87 4.17589 1100 7282.5 8220.5 FET MAD HOUR 2.19 19.98 10.5922 1100 7282.5 8220.5 GR MAD API 55.21 558.6 156.866 1100 7275.5 8213 PEF MAD BARN 2.54 11.65 5.51807 1100 7261.5 8199.5 RAT MAD FT/H 0.42 313.01 212.707 1090 7333.5 8267 NPHI MAD PU-S 25.34 56.84 39.4725 1089 7247 8180.5 First Reading For Entire File..........7247 Last Reading For Entire File...........8267 File Trailer Service name... .......sTSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/13 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......sTSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 Page 6 ~ ~ 3a-03b.tapx DE PTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4085.5 4210.0 RPM 4100.0 4217.0 RPD 4100.0 4217.0 RPX 4100.0 4217.0 FET 4100.0 4217.0 RPS 4100.0 4217.0 ROP 4142.5 4267.0 LOG HEADER DATA DATE LOGGED: 05-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4267.0 TOP LOG INTERVAL (FT): 4142.0 BOTTOM LOG INTERVAL (FT): 4267.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 47.0 MAXIMUM ANGLE: 54.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 WR4 Electromag Resis. 4 228501 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 4104.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 45.0 MUD PH: 10.2 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 7.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): 3.100 70.0 MUD AT MAX CIRCULATING TER MPERATURE: 2.620 84.0 MUD FILTRATE AT MT: 3.000 70.0 MUD CAKE AT MT: 3.600 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type ................ ..0 Page 7 3a-03b.tapx 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 MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4085.5 4267 4176.25 364 4085.5 4267 RPD MWD020 OHMM 2.75 2000 38.3223 235 4100 4217 RPM MWD020 OHMM 1.52 362.05 7.94847 235 4100 4217 RPS MWD020 OHMM 2.52 1052.01 10.1551 235 4100 4217 RPX MWD020 OHMM 2.45 1196.44 13.1083 235 4100 4217 FET MWD020 HOUR 0.79 19.17 6.97774 235 4100 4217 GR MWD020 API 57.4 131.17 99.4396 250 4085.5 4210 ROP MWD020 FT/H 7.37 113.87 68.3368 250 4142.5 4267 First Reading For Entire File..........4085.5 Last Reading For Entire File...........4267 File Trailer Service name... .......STSL2B.003 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/02/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... ......STSLI6.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/02/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 Page 8 3a-03b.tapx 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 FCNT 4181.5 8198.5 NPHI 4181.5 8198.5 NCNT 4181.5 8198.5 RHOB 4195.5 8213.5 PEF 4195.5 8213.5 DRHO 4195.5 8213.5 GR 4210.5 8227.5 RPS 4217.5 8234.5 FET 4217.5 8234.5 RPX 4217.5 8234.5 RPD 4217.5 8234.5 RPM 4217.5 8234.5 ROP 4267.5 8285.0 LOG HEADER DATA DATE LOGGED: 12-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8285.0 TOP LOG INTERVAL (FT): 4267.0 BOTTOM LOG INTERVAL (FT): 8285.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 27.5 MAXIMUM ANGLE: 53.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 CTN COMP THERMAL NEUTRON 113413 EWR4 Electromag Resis. 4 228501 ALD Azimuthal L itho-Dens 183652 S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 4104.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 44.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3): 2.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.600 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.160 154.0 MUD FILTRATE AT MT: 2.700 65.0 MUD CAKE AT MT: 2.500 65.0 NEUTRON TOOL MATRIX: Page 9 • 3a-03b.tapx 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 4181.5 8285 6233.25 8208 4181.5 8285 FCNT MWD030 CNTS 147 1450 281.371 8035 4181.5 8198.5 NCNT MwD030 CNTS 16105 42491 21575.6 8035 4181.5 8198.5 RHOB MWD030 G/CM 2.134 3.164 2.36748 8037 4195.5 8213.5 DRHO MWD030 G/CM -0.141 0.406 0.0624969 8037 4195.5 8213.5 RPD MWD030 OHMM 0.21 418.54 3.6243 8035 4217.5 8234.5 RPM MWD030 OHMM 0.21 418.54 3.46078 8035 4217.5 8234.5 RPS MWD030 OHMM 0.23 44.22 3.38259 8034 4217.5 8234.5 RPX MWD030 OHMM 0.25 50.8 3.33538 8035 4217.5 8234.5 FET MWD030 HOUR 0.54 25.49 1.96541 8035 4217.5 8234.5 GR MWD030 API 42.09 569.28 131.122 8035 4210.5 8227.5 PEF MWD030 BARN 1.83 9.72 3.38577 8037 4195.5 8213.5 ROP MWD030 FT/H 5.22 178.59 52.933 8036 4267.5 8285 NPHI MWD030 PU-S 14.4 52.76 38.3672 8035 4181.5 8198.5 First Reading For Entire File..........4181.5 Last Reading For Entire File...........8285 File Trailer Service name .............STSLIB.004 Page 10 • 3a-03b.tapx service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/13 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/13 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 3 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI 7247.0 FCNT 7247.0 NCNT 7247.0 PEF 7261.5 DRHO 7261.5 RHOB 7261.5 GR 7275.5 FET 7282.5 RPS 7282.5 RPM 7282.5 RPD 7282.5 RPx 7282.5 RAT 7333.5 for each pass of each run in separate files. 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 8180.5 8180.5 8180.5 8199.5 8199.5 8199.5 8213.0 8220.5 8220.5 8220.5 8220.5 8220.5 8267.0 12-NOV-07 Insite 74.11 Memory 8267.0 7333.0 8267.0 27.5 53.0 TOOL NUMBER 64004 Page 11 • 3a-03b.tapx CTN COMP THERMAL NEUTRON EwR4 Electromag Resis. 4 ALD Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum Specification Block sub-type...0 113413 228501 183652 6.125 4104.0 Polymer 10.80 44.0 9.5 250 2.4 2.600 65.0 1.160 154.0 2.700 65.0 2.500 65.0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MAD031 CNTS 4 1 68 4 2 NCNT MAD031 CNTS 4 1 68 8 3 RHOB MAD031 G/CM 4 1 68 12 4 DRHO MAD031 G/CM 4 1 68 16 5 RPD MAD031 OHMM 4 1 68 20 6 RPM MAD031 OHMM 4 1 68 24 7 RPS MAD031 OHMM 4 1 68 28 8 RPX MAD031 OHMM 4 1 68 32 9 FET MAD031 HOUR 4 1 68 36 10 GR MAD031 API 4 1 68 40 11 PEF MAD031 BARN 4 1 68 44 12 RAT MAD031 FT/H 4 1 68 48 13 NPHI MAD031 PU-S 4 1 68 52 14 Page 12 • • 3a-03b.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7247 8267 7757 2041 7247 8267 FCNT MAD031 CNTS 140 623 257.726 1089 7247 8180.5 NCNT MAD031 CNTS 16701 30473 20021.6 1089 7247 8180.5 RHOB MAD031 G/CM 2.005 2.797 2.38395 1100 7261.5 8199.5 DRHO MAD031 G/CM 0.004 0.239 0.0909773 1100 7261.5 8199.5 RPD MAD031 OHMM 1.06 41.88 4.44721 1100 7282.5 8220.5 RPM MAD031 OHMM 0.93 42.31 4.25046 1100 7282.5 8220.5 RPS MAD031 OHMM 0.89 47.27 4.30738 1100 7282.5 8220.5 RPX MAD031 OHMM 0.86 43.87 4.17589 1100 7282.5 8220.5 FET MAD031 HOUR 2.19 19.98 10.5922 1100 7282.5 8220.5 GR MAD031 API 55.21 558.6 156.866 1100 7275.5 8213 PEF MAD031 BARN 2.54 11.65 5.51807 1100 7261.5 8199.5 RAT MAD031 FT/H 0.42 313.01 212.707 1090 7333.5 8267 NPHI MAD031 PU-S 25.34 56.84 39.4725 1089 7247 8180.5 First Reading For Entire File..........7247 Last Reading For Entire File...........8267 File Trailer Service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/13 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/02/13 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next. Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/02/13 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF writing Library. Scientific Technical services writing Library. Scientific Technical services Page 13 ~ ` ! End Of LIS File 3a-03b.tapx Page 14
