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Home My WebLink About202-057 Imag< )roject Well History File Cover I-Jge XHYZE 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. !LQ .2 - f) Ii lWeI! History File Identifier Co-v.vJ'?~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ¿ Y'ES - NO BEVERLY ROBIN VINCENT SHERY~)WINDY DATE: 'Ö fJ.() e;,¡, vv\ P Organizing (dOlle) R;PCAN \ß ~ Color items: ~ Grayscale items; 0 Poor Quality Originals: 0 Two-Sided ?TA~S::t::, No. , 0 Other, NolType 0 Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERY~INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~INDY Scanning Preparation / x 30 =,30 BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: t/Rescan Needed OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner 0 OVERSIZED (Non-Scannable) 0 Logs of various kinds Other 0 , , DATE:~ I 6lþ Isl mf mtJ j 4 k &() . ~ ~t) ~ J- , , DATE:' I Ólf/SI , I + ;;2..ú = TOTAL PAGES " I DATE: to " O~ /SI S/ BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: DATE: ISI (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAl ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY . GRAYSCALE OR COLOR IMAGES) ReScanned (i¡¡¡filddl';'¡{ pJ('}"! !::.pacial Mr0lHion} ,<,c,}'Jni¡¡g wmplef0d) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: - YES - NO DATE: ISI Quality Checked (dnllc1 12/1 OI02Rev3NOTScanned. wpd v • • ,I1A11 GT ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kelli Wilmot 0 Engineering Technician DB&W aP ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C -04A Sundry Number: 311 -237 Dear Mr. Wilmot: _,A„, „frr 14 ti : Klf;) p Zt I Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 Daniel T. Seamount, Jr. Chair DATED this T day of August, 2011. Encl. i ` • Kelli Wilmot Engineering Technician. — ATO -1509 Drilling & Wells PO Box 196105 ConocoPh i I I i ps Anchorage, AK 99519 -6105 Phone: (907)265 -6309 July 25, 2011 Dan Seamount ; ,�. AOGCC Commissioner ?rw State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 ;.0A-3:N I . ul iornission Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3C -04A from Oil Production service to Water Injection service. The 3C -04A is a single CTD lateral well completed in the A -sands that has been recently shut -in due to low productivity caused by lack of injection support. Converting it to water injection service will allow it to support other producing wells in the area, namely 3C -03 and 3C -06. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3C -04A (PTD 202 -057). If you have any questions regarding this matter, please contact me at 265 -6309. Sincerely, `)/ (0A07 Kelli Willmot Engineering Technician Drilling & Wells ConocoPhillips Alaska, Inc. 700 G Street ATO -1509 907 - 265 -6309 Attachments: Sundry application Well schematic y STATE OF ALASKA (.j)* ALASKA" AND GAS CONSERVATION COMMISSIO. APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re-enter Susp. Well r Stimulate r Alter casing T Other:PROD to WINJ F. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 202 -057 3. A dd r ess : Stratigraphic r Service r 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50- 029 - 21416 -01 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No (7 3C -04A - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 025629 ' Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8591 , 6623 • 8557' 6621' Casing Length Size MD TVD Burst Collapse CONDUCTOR 65 16 100' 100' SURFACE 2410 10.75 2445' 2445' WINDOW 10 6 7213' 6537' PRODUCTION 7626 7 7658' 6663' LINER 1458 2.375 8591' 6623' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7203' - 8591' 6537' - 6623' 3.5 L -80 7014 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PBR - BAKER PBR MD= 7014 TVD= 6394 PACKER - BAKER 'FHL' PACKER MD= 7028 TVD= 6404 MD= 7006 TVD= 6388 12. Attachments: Description Su,n,rdry of Proposal 1 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/15/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kelli Wilmot Printed Name Kelli Wilmot Ail te/ Title: Engineering Technician D &W Signature / I Phone: 265 -6309 Date: 7/22/11 Commission Use Only � 0/ J Sundry Number: `� / Conditions of approval: Notify Commission so that a representative may witness ✓ ill///"' Plug Integrity r BOP Test r Mechanical Integrity Test ille Location Clearance r 'r- .> —k ' h 7 C, F „ 1 Other: 61 ( ki./si D I,Gr 01 N k 4iCC0 ■-.r .+7//41 U Z!✓ .. _ �,/ }� ic.;; `;.tic > ("Lill, c,itit�i. 1. ti,si €tioSlofl Subsequent Form Required: A — yt�y i� I4 ' Atic4 d ergo APPROVED BY /l /// Approved by: �� COMMISSIONER THE COMMISSION Date: RBDMS AUG 04 21)9 GINA'. � , , . i Z �, Form 10 -403 Revised 1/2010 O � r. Submit in Dupli 1 • 3C -04A DESCRIPTION SUMMARY OF PROPOSAL 3C -04A Proposal ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3C -04A from Oil Production service to Water Injection service. The 3C -04A is a single CTD lateral well completed in the A -sands that has been recently shut -in due to low productivity caused by lack of injection support. Converting it to water injection service will allow it to support other producing wells in the area, namely 3C -03 and 3C -06. Cement The 16" Conductor was cemented with 180 sx CS II (100' and / 100' tvd). The 10.75" Surface casing (2445' and / 2445' tvd) was cemented with 1050 sx PF 'E', 380 sx PF 'C'. The 7" Production casing (7213' and / 6537' tvd) was cemented with 380 sx PF 'E', 250 sx 'G', 250 sx PF 'C'. Formation Picks The top of the KuparukC was found at 7102' and / 6458' tvd. The top of the Kuparuk B was found at 7199' and / 6527' tvd. The top of the Kuparuk A was found at 7381' and / 6658' tvd. The large peroration interval here is due to this being a horizontal well that was completed open -hole with a pre - drilled liner in the interval noted. Testing 4/18/02 MITIA passed. Pressured up IA w/ diesel to 2500 psi. I CO 'iGV,. Well frkes 3 " 90 10 1/1 -ge VG and n e , y, id 6o Cv^ 7 A9 Awl/ Iv ;i s ec i k v n e e,,P eE 7 7 c 63 c- / • cast, f�► o o•P el- 5 •-6 t,? eel 4 ecrt_ L` L p4 4 t arc- c- j 4 t 7 S C O "i Y fi (Ad t�(.v ' 4111 KUP • 3C -04A ConocoPhillips Well Attributes M ax Angle & MD TTD Wel!bore API /UWI Field Name Well Status I Inc! (°) MD (ftKB) Act Btm (RKB) Alaska. !RC. 500292141601 KUPARUK RIVER UNIT PROD 97.47 7,677.66 8,591.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (R) Rig Release Date • Well COnf9: 3C - 04A, 9/13120094:08:08 PM SSSV: NIPPLE 160 7/1/2008 Last WO: 4/29/2002 36.31 8/28/1985 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag. RKB 7,234.0 1/10/2009 Rev Reason: TAG FILL Imosbor 1/22/2009 Casing Strings String OD . String ID Set Depth Set Depth (TVD) String Wt String hull nrivr'N iPat9 lid 1144 ,. ■ . - 1., Casing Description (In) (in) Top (RKB) (RKB) (RKB) (Ibs /R) Grade String Top Thrd CONDUCTOR 16 15.062 0.0 100.0 100.0 62.50 H - 40 CONDUCTOR, 100 SURFACE 103/4 9.794 0.0 2,445.0 2,444.7 45.50 K -55 PRODUCTION 7 6.151 0.0 7,213.0 6,537.3 26.00 J -55 BTC - WINDOW 6 3.000 7,203.0 7,213.0 6,537.3 26.00 J -55 BTC NIPPLE, 500 " LINER 23/8 1.999 7,132.0 8,591.0 6,622.5 4.43 L -80 STL Tubing Strings String OD String ID Sat Depth Set Depth (TVD) String Wt String Tubing Description (In) (In) T (8KB) (8KB) KB) (Ibs /R) Grade String Top Thrd 9.30 L -80 EUE8rdABMOD SURFACE, _ T U UBING BB B 3112 2.992 0.0 7,014.0 7 ,268.0 6,394.2 9.30 L -80 ABM -EUE TUBING 2 3. 5 7/ " 8" 33 1/2 2.992 7 ,253.0 014.0 7 (R 6,569.7 6,581.6 2 7/8 2.441 7, 6.50 J -55 EUE I z,4as T Bassi Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth (TV Top Intl Top (RKB) (RKB) (") Description Comment Run Dab ID (In) 500 500.0 0.32 NIPPLE CAMCO LANDING NO GO NIPPLE 4/29/2002 2.812 GAS LIFT, 2,992 2,991.6 1.08 GAS LIFT CAMCO /MMM/1.5/GLV /RK/.156/1290/ Comment: STA 1 5/4/2002 2.920 4,900 4,900 4,847.7 30.42 GAS LIFT CAMCO/MMM/1.5/GLV/RK/.188/1301/ Comment: STA 2 5/4/2002 2.920 6,208 5,815.6 44.55 GAS LIFT CAMCO /MMM/1.5/GLV/RK/.188/1288/ Comment: STA 3 ;5/42002 2.920 I 6,605 6,099.4 43.87 GAS LIFT CAMCO /MMM /1.5/DMY /RK/ // Comment: STA 4 5/4/2002 2.920 6,814 6,250.0 44.00 GAS LIFT CAMCO /MMM /1.5 /DMRK// /Comment: STA 5 12/22/1995 2.920 GAS LIFT, Y / 6,208 6,960 6,355.2 43.75 GAS LIFT CAMCO /MMM /1.5/OV/RK/.188// Comment: STA 6 5/4/2002 2.920 I 7,006 6,388.4 43.80 NIPPLE CAMCO LANDING NIPPLE - SELECTIVE 4/29/2002 2.812 7,014 6,394.2 43.82 PBR BAKER PBR 828/1985 3.000 7,028 6,404.3 43.85 PACKER BAKER 'FHL' PACKER 8/28/1985 3.000 GAS LIFT 7,072 6,436.1 43.96 PRODUCTION CAMCO/ MMM /1.5/DMY /RK/ / /Comment: STA7 8/28/1985 2.920 6,605 7,132 6,479.2 44.11 HANGER LINER TOP /HANGER 4/29/2002 4/29/2002 2.375 i - ' .. 41**to : Shot GAS LIFT, Top (ND) Btm (TVD) Dens 6,814 Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date (.h .. Type Comment 7,137 8,556 6,482.8 6,620.5 4/29/2002 4.0 IPERF PREDRILLED LINER - 4,0.375" SIZE HOLES PER FOOT GAS LIFT, 6960 . �...:: II } a } t NIPPLE, 7,006 1 I PBR, 7,014 - -- a 6 I. PACKER, 7,028 1 PRODUCTION, 7,072 HANGER, 7,132 4 ■ 1 PRODUCTION, - - 7,213 WINDOW, -- 7,213 I IPERF, 7,137 -8,556 - LINER, 8,591 TD ( 3C -04A 8,591 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, August 04, 2011 10:51 AM To: 'Wilmot, Kelli A' Subject: RE: 3C -04A cony. to WINJ (PTD 202 -057) I looked at the CET log from 1985. Cement coverage is very good so no issues with converting to an injector. Thanks for the AOR plot map. As you mention no wells are within % mile. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Wilmot, Kelli A [ mailto: Kelli .A.Wilmot @conocophillips.com] Sent: Tuesday, August 02, 2011 11:48 AM To: Schwartz, Guy L (DOA) Subject: RE: 3C -04A cony. to WINJ (PTD 202 -057) Guy 3C -04A is a single CTD lateral in the A -sand and there are no wells with a quarter mile of it within the reservoir. Attached are the CBL Log and a slide showing the AOR. If you need anything else please let me know. Kelli Wilmot Drilling & Wells Engineering Technician ConocoPhillips Alaska, Inc. 907.265.6309 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Thursday, July 28, 2011 4:09 PM To: Wilmot, Kelli A Subject: 3C -04A cony. to WINJ (PTD 202 -057) Kelli, An Area of Review is needed before the sundry can be approved. See attatched... The Drill site engineer can do it for you. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 8/4/2011 ,,, �- ConocoPhillips L 3C -04A /4 mile review Alaska 3i.. -05 1 3C-06 1 \ \ % mile buffer • 2900' 2150' 3 3C-04 3C. 3C -04A 3C -03 1850' t 3C -15A 3350' ID 33 ~ i . . ~ • • . . ~ . , . : . . ~ COf'1 ~ . . ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 3, 20Q9 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ,~„ ~~~~~..r' !~~j~ ~ ~ ~~1~ ~i:dy L' Dear Mr. Maunder: • ~~~1.~.~ V i....4./ .~UL 4 7 2009 ANa$ka ~il ~ Gas Cons, C~rnmissios~ An~kaora~a ~,aa"~~ ~ ~'` f ~ ~'~'~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of these wells was found to ha.ve a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from enteri.ng 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 June 16~' & 26~', 2009 and the corrosion inhibitor/sealant was pumped June 23rd & 30~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~`f~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ~ • ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-ofF Report of Sundry Operations (70-404) Kuparuk Field Date 7/3/09 3 C PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top oif date Corrosion inhibitor Corrbsion inhibitod sealant date ft bbls ft al 3C-01 500292141300 1851870 22' 2.3 28" 6/26/2009 5.9 6/30/2009 3C-02 500292141400 1851880 76' 10.0 22" 6/26/2009 5.1 6/30/2009 3C-03 500292141500 1851890 5' 1.0 21" 6/26/2009 5.1 6/30/2009 3C-04A 500292141601 2020570 4' 1.0 23" 6/26/2009 5.1 6/30/2009 3C-05 500292138900 1851540 24" n/a 24" n/a 4.25 6/23/2009 3C-06 500292109600 1840420 6" n/a 6" Na 7.65 6l23l2009 3C-07 500292139100 1851560 37' 5.00 25" 6/16/2009 5.52 6/23/2009 3C-08 500292139000 1851550 12' 2.00 22" 6/16/2009 3.4 6/23/2009 3C-09 500292135500 1851000 20" n/a 20" n/a 2.55 6/23/2009 3C-10 500292135600 1851010 30' 4.10 24" 6/16/2009 4.25 6/23/2009 3C-12 500292135400 1850990 45' 9.30 26" 6/26/2009 4.3 6/30/2009 3C-13 500292142400 1851980 20" n/a 20" Na 2.12 6/23/2009 3C-14A 500292142501 2071750 3' n/a 3' Na 8.07 6/23/2009 3C-15A 500292142601 2080810 31' 4.40 26" 6l16/2009 2.75 6/23/2009 3C-16 500292142700 1852010 20" n/a 20" n/a 2.12 6l23/2009 3C-17 500292338900 2080590 2'6" n/a 2'6" n/a 8.92 6/23/2009 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs _ Inserts\Microfilm _ Marl<:er.doc ~ '1 M~ À-ö ~ c{ DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 5f1~ ~ J- tfl.y M'ti '1 API No. 50-029-21416-01-00 Operator CONOCOPHILLlPS ALASKA INC Permit to Drill 2020570 Well Name/No. KUPARUK RIV UNIT 3C-04A / Completion Status 1-01L MD 8591 ¡/ REQUIRED INFORMATION TVD 6622'/ Completion Date 4/29/2002 DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Logl Data Digital Typy Med/Frmt ~ pD ~ C Tf i i Rpt ~D C Pdt i ' I~D !~ J iq.pg' C Pdf Electr Dataset Number Name Directional Survey Directional Survey LIS Verification l~2063 LIS Verification lj2063 Gamma Ray '12ó63 Gamma Ray Gamma Ray Gamma Ray Well Cores/Samples Information: Name Well Cored? ADDITIONAL INFORMATION yffû Chips Received? 'ÿ'7"N- Analysis Received? Comments: -..:t..J.Þ!- Current Status 1-01L UIC N Mud Log No Samples No Directional Survey Q~- (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No 1 Interval OHI ~ Start Stop CH Received Comments 7212 8591 Open 7/15/2002 7212 8591 Open 7/15/2002 7200 8591 Open 7/29/2003 Same info is also on Disk #12062 7200 8591 Open 7/29/2003 Same info is also on Disk #12062 7212 8591 Open 7/29/2003 MWD Gamma Ray - MD. Same info is also on Disk #12062 7212 8591 Open 7/29/2003 MWO Gamma Ray - TVO 7212 8591 Open 7/29/2003 MWD Gamma Ray - MD 7212 8591 Open 7/29/2003 MWD Gamma Ray - TVD 25 25 25 Blu 25 Blu Interval Start Stop Sample Set Number Comments -- Sent Received Daily History Received? 0N ~'1 L0N Formation Tops DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Permit to Drill 2020570 Well Name/No. KUPARUK RIV UNIT 3C-04A Operator CONOCOPHILLlPS ALASKA INC MD 8591 TVD 6622 Completion Date 4/29/2002 Completion Status 1-01L Current Status 1-01L Compliance Reviewed By: ~ Date: API No. 50-029-21416-01-00 UIC N j ~ \JIM- Jv\H-v( '-' ---- {) OéJ--6S '7 Transmittal Form INTEQ r&l. BAKER HUGHES Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 3C-04A IT----'" i! Contains the following: ,! 1 Revised LDWG Compact Disc j 9019 ~ (Includes Graphic Image files) , ¡ i 'I Original CD contained corrupt data TIF file. I Please replace original CD with this revised disc. CD t\. \)..(J Cr» ~~j~ \"4 \ j """'" :t.,-i I LAC Job#: 292896 IL I Date: Aug 7, 2003 Sent By: Glen Borel ~.., <::'.' Received BY~~~t~....(: ('(~\e.tV\. Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 ~~~N\l~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 RECEIVED AUG 0 7 2003 Alaska O;.¡ & Gas Com~. ÜJmmis8ion Anchorege [r:~~!p~- L~',~~"T ="~i , ""."."', ~¡, l':':..wo' f,.; : .,-.. ~¡': I , , :~:III IiWIU ...' lal~ -,l1li",' :" ','I" ....: .,..... I ¡,~~" .; ""'~I\ :~ ,~~~ ;:;:~'---~~~:';'-'-f---::;---:~~~- I''''''''''''''.' 'U"".''''.'''''' I I ::::~~"'. ¡ . i-----------§t~~~~,~,-~---------- -:~---~~~~:-;;;S:;~-~:;---~::~ r';'¡;;;,:,;;:;;~''-.'¡¡';'''ø;,;:'-''. .'¡ .. . .., j,. ~=----_:::~- .:: ;_à""'. .. .".,.,-,.". :~~,,~- -'~--_._. Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 3C-04A () C~d --C) 5 ':::¡- ) r&l. BAKER HUGHES Anchorage GEOScience Center Contains the following: o19~ 1 LDWG Compact Disc) (J (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional TVD Log LAC Job#: 292896 ""---~---~-------~~---_.""""""-'--~ Sent By: Glen Horel ~ '. ç- Received By: ~t JY\ b&<L' ~C.\N1 Date: July 25, 2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 Rb~vY\~ RECEIVED JUL 29 2003 Alaska O~1 & Gas Cons. Comm;seion ,Anchorage IT"~~~~;~~~~~~;~~f ",i..-',....-.,.',..,"'''; II,IWf '\If ....~t fII"r Iol~ ~"'N " ~ ',' .... -, , ',' "'- .... " .... ¡--~------------------------- :;p~~~.,_.".~.,_.__.._;,~. - :~.-.._.?=:~ ....n. 111.1 ""","""""" :~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ') !' 1. Status of Well ~ Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 420' SNL, 1402' WEL, SEC. 14, T12N, R09E, UM At top of productive interval 938' NSL, 1204' WEL, SEC. 11, T12N, R09E, UM At total depth 1482' NSL, 2267' WEL, SEC. 11, T12N, R09E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB = 85' ADL 025629 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 4/25/2002 4/28/2002 4/29/2002 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 8591 6622 FT 8557 6621 FT ~ Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES Classification of Service Well 1'" "1~' -"'~r'4i""'~'1 .i~I""\:,7iL''''~''''''~.''~'''''''~'.'''-.',-, ,","~. ìr.~~ ,'~~J&H\J:(;(lf': ',~ ~ .':' I. ¡r' "r" , ,. . "'" ~," . / d~!ji.:. ~ ".' .~,~". .. ","',1;'.'."i ".'"..L~?::qJ!::lr ~/~?,., ~"':,~ \lEm¡~) ~I..,.~ ,'~'~ ',~, AQ",,-.. ~\Wi#'.~~~~JI"" t.:"""'~~~~.1¥t.~'~ìr'7r.;~~;:':;!:~}~,.\, 7. Permit Number 202-057 8. API Number 50- 029-21416-01 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3C-04A 11. Field and Pool Kuparuk River Oil Pool 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost N/A MD 1380' (Approx.) 23. CASING SIZE 16" 10-3/4" 7" WT. PER FT. 60.5# 45.5# 26# 4.43# GRADE H-40 J-55 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 100' 24" 183 sx CS II Surface 2445' 13-1/2" 1050 sx PF 'E', 380 sx PF 'C' Surface 7213' 8-1/2" 380 sx PF 'E', 250 sx 'G', 250 sx PF IC' 7132' 8591' 3" Uncemented Slotted Liner AMOUNT PULLED 2-3/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-3/8" Slotted Liner MD TVD 7167' - 8557' 6504' - 6621' 25. TUBING RECORD DEPTH SET (MD) 7213' (Top of Window) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 22 Bbls of Diesel SIZE 3-1/2", 9.3#, L-80 PACKER SET (MD) 7028' & 7245' MD TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 5, 2002 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL 5/7/2002 6.8 TEST PERIOD 604 Flow Tubing Casing Pressure CALCULATED OIL-BBL Press. 24-HoUR RATE GAs-McF 0 GAs-McF WATER-BBL 1021 WATER-BBL CHOKE SIZE 124 OIL GRAVITY-API (CORR) GAS-OIL RATIO 611 28. CORE DATA D r r E I V [ D Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit c~ Ibi~ No core samples were taken. JUN î 3 2002 Alaska Oil & Gæ~ GwìS, t~olHimSSlor, Anchorage ".~ : /""\ ~ 1 , i ' :¡ . 11 'I I ~ j " I'ffHUMS BFL JUN I 4 2002Submit In Duplicate (g~ Form 10-407 Rev. 07-01-80 ) 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Top 85 v" 7202' 6529' Top 84 / 7242' 6561' Top 83 / 7270 6583' Top 82 / 7300' 6604' /' Top 81 7356' 6635' Top A6 7398' 6651' Top A5 7414' 6656' Top A4 7422' 6658' Top A3 7439' 6662' 31. List of Attachments: ) 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RECEIVED JUN 1 3 2002 Alaska OU & Gas Cons. CommtsG\m, Anchoratle Summary of Pre-Rig Work, Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ltAi-t ~ Title Technical Assistant 3C-04A 202-057 Well Number Permit No. / Approval No. INSTRUCTIONS Date 01.0 -l3 -D;;( Prepared By Name/Number: Terrie Hubble, 564-4628 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) PHILLIPS PETROLEUM CO. Operations Summary Report Page 1 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3C-04 3C-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/21/2002 Rig Release: 4/30/2002 Rig Number: Spud Date: 8/16/1985 End: 4/29/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 4/21/2002 00:00 - 03:30 3.50 MOB P PRE Continue move from 3H-16a. Move onto 3C Pad at 0220 hrs. Move over tree and set down. FLP 200, GL 200 03:30 - 07:30 4.00 BOPSURP DECOMP Accept rig at 0330 hrs 4/21/2002. Remove tree cap. NU BOPE. Meanwhile spot & berm flowback tanks, upright & slop tank. 07:30 - 08:30 1.00 BOPSURP DECOMP Held pre-spud/pre-operations start-up safety meeting with day crew. Discussed recent 3H-16A hi/lo-lights. Reviewed scope, objectives, critical issues, risks & contingencies of 3C-4A DOCTD operations. Stress adherence to procedures, HAlHM & good communication. 08:30 - 11 :00 2.50 BOPSUR P DECOMP PJSM. Install work platform around BOP stack. Open up & visually inspect lower 2-3/8" & 2" combi pipe/slip rams for wear/deformation. Rams in good condition. 11 :00 - 18:30 7.50 BOPSURP DECOMP PJSM. Pressure tested BOPE to 4500psi as per drilling permit. Witnessing of test waived by State Rep Chuck Scheve. 18:30 - 19:30 1.00 BOPSUR N SFAL DECOMP BOPE test completed, but noticed hydraulic fluid leaking from annular cap. Begin removal of same. Fill upright tank wI 220 bbls 12.6 ppg KWF 19:30 - 20:15 0.75 BOPSURP DECOMP Prespud mtg given by D. Venhaus to nite crew covering same topics above 20: 15 - 22:45 2.50 BOPSUR N SFAL DECOMP Continue removal of annular cap and repair same. Reinstall and retest wI test jt at 2500 psi for 30 min. Meanwhile investigate "noise" in power pack traction motor. Fin unload lowboys of misc tools. Unload KWF and send back to MI due to too high ph 22:45 - 23:00 0.25 CLEAN P DECOMP Safety mtg re: slack management procedure 23:00 - 00:00 1.00 CLEAN P DECOMP Fill CT wI 4 bbls mud to displace 2 bbls diesel from end of CT Cut off CTC 4/22/2002 00:00 - 04:30 4.50 CLEAN P DECOMP Stab injector on well. Rev 41 bbls mud 2.6/4000 and slack stopped moving at 7 bbls. Replace packoff Unstab. Cut off CT in +1-5' lengths and find e-line at 42'. Rehead. PT CTC and inner reel valve at 4000 psi 04:30 - 05:00 0.50 CLEAN P DECOMP Circ CT volume of mud the long way 2.2/3875 05:00 - 05:15 0.25 CLEAN P DECOMP Check well for pressure=O. MV=20, SW=20. PVT 200 05:15 - 06:10 0.92 CLEAN P DECOMP MU milling BHA. Test voltage, ok 06:10 - 06:50 0.67 CLEAN P DECOMP RIH wI BHA #1 to 2227'. 06:50 - 08:15 1.42 CLEAN N DFAL DECOMP SHT coiltrack & observe short somewhere in system. Open up eline bulkhead @ reel & check electrical connections - nothing amiss, could supply good voltage to bulkhead. Suspect e-line, UQC or downhole tool problem. Close up e-line bulkhead. 08:15 - 08:55 0.67 CLEAN N DFAL DECOMP POOH BHA#1 to check for short in e-line system. 08:55 - 1 0:00 1.08 CLEAN N DFAL DECOMP Tag up at surface. Break off UQC & RIB injector. Tested downhole tools & tools tested OK. Openned up UQC & found fluid ingress into e-line core (probably from reverse circ during slack management). 10:00-10:10 0.17 CLEAN N DFAL DECOMP Freeze protect exposed CT with 2 bbls diesel. Meanwhile rectified DS pump pressure transducer & installed new mother board for DS main computer. Looks like an "electronics' field day..... 10:10 -14:15 4.08 CLEAN N DFAL DECOMP Cut 60' of CT/e-line in 5' stages & still found fluid in e-line. Cut additional 15' before seeing dry e-line core. Carried out continuity tests on e-line from BHI unit - getting inconsistent readings. Retry from collector bulkhead - OK. M/U bulkhead & Printed: 4/30/2002 3: 18: 1 0 PM ) ) PHILLIPS PETROLEUM CO. O.perations Summary Report Page2 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3C-04 3C-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/21/2002 Rig Release: 4/30/2002 Rig Number: Spud Date: 8/16/1985 End: 4/29/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 4/22/2002 10:10 - 14:15 4.08 CLEAN N DFAL DECOMP meg-test from BHI unit - still getting inconsistent readings. Suspect electrical grounding or some sort of anomaly @ bulkhead after M/U. 14:15 - 18:30 4.25 CLEAN N DFAL DECOMP Cut 8' coil (83' total cut now). M/U BHI CTC. Pull test to 20k - OK. M/U UQC. Meanwhile re-open bulkehead, re-wired & retested. Finally got good condutivity tests from e-line to bulkhead to collector to BHI unit. 18:30 -19:15 0.75 CLEAN P DECOMP MU 2.3 BHI motor wI 2.74 DPI bit on BHI BHA. RIH wlo press deployment freely if bit below no-go ring. POOH and hangs up in stack, but can be worked thru MU 2.3 BHI motor wI 2.74 HYC D100 bicenter on BHI BHA. RIH/POH wlo press deployment, clean. PT BHI CTC @ 3000 psi 19:15 - 22:00 2.75 CLEAN P DECOMP Safety mtg (new Nordic crew) re: pressure deployment of BHA Practice pressure deployment wI Hycalog bit on 2.3 BHI motor wI 60 psi induced WHP. Notice BHI CTC has low pressure leak-retest and failed 22:00 - 23:30 1.50 CLEAN P DECOMP Safety mtg re: pressure undeployment of BHA Practice pressure undeployment wI same assylconditions 23:30 - 00:00 0.50 CLEAN N SFAL DECOMP Replace O-ring in CTC 4/23/2002 00:00 - 00:30 0.50 CLEAN N SFAL DECOMP Fin fix O-ring seal failure on BHI CTC. PT 20k, 3000 psi 00:30 - 01 :10 0.67 CLEAN N DFAL DECOMP MU milling BHA (2.80" D331, 1.0 deg motor) 01:10 - 01:40 0.50 CLEAN N DECOMP RIH wI BHA #2 (#1 RR). PVT 125. 10 ppg mud has mixed wI WB fluids so saved everything and calc 9.69 ppg system when blended 01 :40 - 02:30 0.83 CLEAN P DECOMP Continue RIH 02:30 - 03: 1 0 0.67 CLEAN P DECOMP Start pump at 7150'. Begin logging down at 150-300'/hr 1.5/3260/60L 03:10 - 04:10 1.00 CLEAN P DECOMP Tag and stall at PBD at 7232' CTD at 60L. Corr to 7222.0' PVT 151 Backream to 7200' while orient 90 deg to left. RIH 3'/min to 7222'. Repeat 3 times to catch 4 quadrants. Compare BHllog to SWS PPROF 10/23/01 and depths within a foot after correction (35.0' bit to gamma) 04:10 - 05:10 1.00 CLEAN P DECOMP POOH forWS MW=9.66 avg 05:10 - 05:40 0.50 CLEAN P DECOMP LD motor and mill. PVT 125 05:40 - 06: 15 0.58 STWHIP P WEXIT Crew change & PJSM on M/U whipstock assy. 06: 15 - 06:45 0.50 STWHIP P WEXIT M/U 3-1/2" TIW LSX whipstock to coiltrack & scribe tools. RA tag to TOWS is 5.2' 06:45 - 09:00 2.25 STWHIP P WEXIT Test coiltrack - OK. Open EDC & RIH whipstock BHA#3 @ 0.3bpm/750psi. Wt chk @ 5000' - 15.5k. Continue RIH to 6200'. 09:00 - 09:35 0.58 STWHIP P WEXIT Log CCL @ 16fpm from 6200' to 6750' - looks like we're @ 17' shallower (did not correct). 09:35 - 09:50 0.25 STWHIP P WEXIT Continue RIH. Wt chk @ 7000' - 21.5k. Continue RIH to 7020'. 09:50 - 11 :10 1.33 STWHIP P WEXIT Log GR tie-in @ 100fph from 7020' to 7160'. Correlated with CCL & made -3' correction to CTD. 11:10-11:25 0.25 STWHIP P WEXIT RIH slowly & tag cmt retainer @ 7222.'7 with 3001bs. PUH, orient TF to 165R & RBIH to 7221.4' (1.3' above retainer). 11 :25 - 11 :30 0.08 STWHIP P WEXIT Close EDC. Pump @ O.4bpm to 3400psi & set/release whipstock. TOWS @ 7212.7'. 11 :30 - 12:45 1.25 STWHIP P WEXIT Open EDC & POOH @ 1.1 bpm & 2000psi. 12:45 -13:10 0.42 STWHIP P WEXIT Tag up at surface. UD whipstock running BHA. Printed: 4/30/2002 3: 18: 1 0 PM ') ) PHILLIPS PETROLEUM CO. Operations Summary Report Page 3 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3C-04 3C-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/21/2002 Rig Release: 4/30/2002 Rig Number: Spud Date: 8/16/1985 End: 4/29/2002 Date From .~ To Hours Activity Code NPT Phase Description of Operations 4/23/2002 13:10 - 14:20 1.17 STWHIP P WEXIT MIU & scribe window milling BHA #4 with WI! 2.5deg fixed motor & 2.8" HCC DSM. 14:20 - 15:00 0.67 STWHIP P WEXIT RIH with window milling BHA#4. 15:00 - 15:05 0.08 STWHIP P WEXIT Tagged up on Gas Lift Mandrel at 2992'. Close EDC and bring pump on to try and work through. 15:05 - 15:25 0.33 STWHIP P WEXIT Continue RIH 15:25 - 16:15 0.83 STWHIP P WEXIT Tagged up on another Gas Lift Mandrel @ 6200'. Orient to High Side and work down. Tag another at 6814'. 16:15 - 17:15 1.00 STWHIP N SFAL WEXIT Dowell pump Trips shorted out by NC Mechanic Repairing Gen #2. WO Dowell ET to come out and fix Pump Trips. Dowell Standards will not allow them to pump without Pump Trips. 17:15 - 17:45 0.50 STWHIP P WEXIT Fin RIH. Dry tag TOW and corr -5.1'. Orient to desired TF 17:45 - 19:45 2.00 STWHIP P WEXIT Park at 7212.0', flag CT, and begin time milling the 3-1/2" tubing at 9 min/0.1' MW 9.69 'in' PVT 148 19:45 - 20:40 0.92 STWHIP P WEXIT 7213.3' 1.5/3360/165R 20:40 - 00:00 3.33 STWHIP P WEXIT 7214.0' 1.5/3370/170R Finally got a little wt loss and diff. Assume this is the 7". Pull stretch up l' to 7213.0' and start time milling 7" casing by schedule 7213.0' 1.5/3210/174R 16.7k 7214.2' 1.5/3350/160R 9.2k 4/24/2002 00:00 - 02:40 2.67 STWHIP P WEXIT Continue time milling window from 7214.2' 02:40 - 03:25 0.75 STWHIP P WEXIT 7216.3' 1.4/3330/170R 6.7k PVT 140 03:25 - 04:30 1.08 STWHIP P WEXIT Exit of 7" occurred at 7217.0' Drill 1 0' of formation at 10-20'/hr 1.4/3240/170R 8.5k PVT 138 MW 'in' 9.67 ppg. Official window is 7213-721 7' Probably the first window (definitely the first two string window) ever drilled without one stall! 04:30 - 04:40 0.17 STWHIP P WEXIT 7227.0' PUH backreaming 22k 1.4/3130 PVT 134 Afew bobbles at 7217' and 7214'. See flag on depth at 7212' mill depth 04:40 - 05:00 0.33 STWHIP P WEXIT Park at 7200', SD pump, SI @ choke and monitor for 10 min, no press Open choke and monitor for flow 10 min, none (good call Dan). BHI annular press correct for MW in hole 05:00 - 05:25 0.42 STWHIP P WEXIT Ream window area wI one pass, clean, wI TF at avg 175R 1.5/3325. Open EDC. PVT 133 (all losses have been over shaker-metal shavings plugging 21 O's) 05:25 - 06:30 1.08 STWHIP P WEXIT POOH. Kick while tripping drill. Overpull at 6960' (GLM) 06:30 - 07:15 0.75 STWHIP P WEXIT Tag up at surface, standby for no-flow test. No flow after 1/2 hour. Kick pumps on, well bore full. Took no fluid in 1/2 hour. 07: 15 - 07:40 0.42 STWHIP P WEXIT Safety meeting prior to clo BHA. 07:40 - 08:25 0.75 STWHIP P WEXIT Lay down motor from window milling BHA. Mill recovered in gauge, with some wear on gauge diamonds, and swirl pattern on face of mill. 08:25 - 09:50 1.42 STWHIP P WEXIT RIH with BHA #5 to dress window. 09:50 - 11 :00 1.17 STWHIP P WEXIT Tag up at flag, set depth to 7212', orient to 165R, close EDC, kick on pumps to 1.5 bpm, 1.5 out, pit vol 134 bbls. 3130 psi free spin at surface. Downhole free spin pressures, Annular Pressure=3764 psi, Inner Pressure = 4325 psi. 11 :00 - 11:40 0.67 STWHIP P WEXIT Update at 11 :00. On first down reaming pass thru window. At 7214.3'. Started seeing work right at 7212.0'. There was considerable work at 7214.1', and has been slow going since. 1.5/1.5/3120 psi, 134 bbls pit volume. Printed: 4/30/2002 3:18:10 PM ) ) PHILLIPS PETROLEUM CO. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3C-04 3C-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/21/2002 Rig Release: 4/30/2002 Rig Number: Spud Date: 8/16/1985 End: 4/29/2002 Hours...Açtivity Code NPT Phase Description of Operations 4/24/2002 11:40 - 12:50 1.17 STWHIP P WEXIT 12:50 - 13:30 0.67 STWHIP P WEXIT 13:30 - 14:15 0.75 STWHIP P WEXIT 14:15 - 15:00 0.75 STWHIP P WEXIT 15:00 - 15:20 0.33 STWHIP P WEXIT 15:20 - 16:35 1.25 STWHIP P WEXIT 16:35 - 16:40 0.08 STWHIP N DFAL WEXIT 16:40 - 18:15 1.58 STWHIP N DFAL WEXIT 18:15 - 20:00 1.75 STWHIP N DFAL WEXIT 20:00 - 21 :30 1.50 STWHIP N DFAL WEXIT 21 :30 - 00:00 2.50 STWHIP N DFAL WEXIT 4/25/2002 00:00 - 01:45 1.75 STWHIP N DFAL WEXIT 01 :45 - 02:00 0.25 STWHIP N DFAL WEXIT 02:00 - 04:00 2.00 DRILL N DFAL PROD1 04:00 - 04:20 0.33 DRILL N DFAL PROD1 04:20 - 05:40 1.33 DRILL P PROD1 05:40 - 06:15 0.58 DRILL P PROD1 06:15 - 06:30 0.25 DRILL P PROD1 06:30 - 07:10 0.67 DRILL N DFAL PROD1 Stopped seeing motor work at 7216..2', RIH tag up 7225', PU and back ream, still holding 165R tool face. Ream up and down at + and.; 30 degrees from 165R. Did not see any motor work on any reaming passes after first down pass. Dry drift window 2 times. Did not see any overpulls, or loss of weight. POOH for build section BHA. Pit vol = 134 bbls when trip OOH started. Stop at 3800' for chokeldriller practice. Practice technique for maintaining a constant BHP when drilling. (New choke operator). Continue POOH. Standby at surface for no flow check prior to doing BHA swap. No flow or loss observed. Tag up, lay down BHA #5. Mill gauged at 2.78". PU BHA #6. RIH with build section BHA. (BHA #6). Shallow hole test failed. Apparent short in e-line system. PU to check out. Troubleshoot system. Found short in upper quick connect. BHI suspects water leaking out of cable conductor, and will need to cut cable and reahead. SWS indicates that slack management is scheduled every 5 trips in the hole. Four trips have been made since last SM. Rig up to pump SM prior to building new cable head. Wait on SWS to bring new boots to location to attempt to keep wire dry while pumping slack management. Nordic gen #3 is sick due to hours/antifreeze in oil (supplies power to ops cab/BHI/Ml/camp). Will swap to rig generators tomorrow. Requires rig electrician to wire leads to BHI unit PJSM. Stab onto well. Reverse circ 2.2/4100 two CT volumes by procedure. E-line quit moving at 2.5 bbls. Cut CT and found end of wire after 13'. Cut additional 9' CT (22' total) after finding first 9' of wire wet. Test and still no continuity so assume bulkhead Position reel and tear down bulkhead connection. Pull 3' slack and reconnect jumper. Put it back together Rehead collector end. PT 20k, 4000 psi. Check well for press, none, hole full Safety mtg re: pressure deployment MU drilling BHA using pressure deployment on dead well with induced 100 psi. Found SL had jumped sheave and kinked. Cut off 70' and rehead. PT @ 1000# (max pull) RIH 100'. Open EDC. Circ CT volume to fin slack management. Test tool RIH wI BHA #7 (2.3 deg motor, Hycalog bi bit) Log down from 7150' 0.4/1050 PVT 134 Corr -8.0'. RIH thru window clean (and logging) at 165R. Close EDC. Tag at 7226.1' Try to start drilling at 60L and motor in a bind. Ream hole to get started 1.5/3220/90L. Start new mud down hole 7726', 1.5/1.513160 psi. Getting very weak stalls, and no ROP. Free spin; CTP=3160 psi, IP=4100 psi, AP=3773 psi. SI pumps, AP=3422, IP=3427, WHP=O. Try cycling the EDC open then closed. Kick pumps on Free spin CTP=3230 psi at 1.5 bpm. RIH, get 200 psi motor work, will not drill off. Open Printed: 4/30/2002 3:18:10 PM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4/25/2002 06:30 - 07:10 3C-04 3C-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours Activity Code' NPT Phase 0.67 DRILL N DFAL PROD1 07:10 - 07:30 0.33 DRILL N DFAL PROD1 07:30 - 08:30 1.00 DRILL N DFAL PROD1 08:30 - 08:45 0.25 DRILL N DFAL PROD1 08:45 - 11 :50 3.08 DRILL N DFAL PROD1 11 :50 - 12:10 12:10 -12:15 12:15 - 13:30 13:30 - 13:45 13:45 -16:15 0.33 DRILL N 0.08 DRILL N DFAL PROD1 DFAL PROD1 1.25 DRILL N 0.25 DRILL N DFAL PROD1 DFAL PROD1 2.50 DRILL N RREP PROD1 16:15 - 16:30 0.25 DRILL P PROD1 16:30 - 17:00 0.50 DRILL N DFAL PROD1 17:00 - 17:40 0.67 DRILL P PROD1 17:40 - 17:45 0.08 DRILL P PROD1 Start: 4/21/2002 Rig Release: 4/30/2002 Rig Number: Spud Date: 8/16/1985 End: 4/29/2002 Description of Operations EDC, establish circ pressure with EDC open. CTP=2873 psi, AP=3778 psi, IP=3808 psi. Shut EDC Free spin; CTP=3630 psi, IP=4364, AP=3808 psi. Tag bottom and put 200 psi extra CTP. Will not drill off. PU and free spin = 3750 psi. BHA not behaving normally. SI pumps, open EDC, continue mud swap. Will POOH after mud to bit and examine BHA for a washout. Note-Mud swap in progress, probably reason for changing free spins, but why won't it drill? Morning pre tour safety meeting. POOH Tag up at surface, stand by for no flow test. Confirm no flow, and well did not take any fluid. Troubleshoot BHA #7. PT CTC to 4000 psi, ok. Stack 500# weight on CTC, PT again to 4000 psi, all is ok. Lay down BHA, PT to 3000 psi, passed ok. Examine motor. The bit was in perfect shape, no obvious signs of washouts in BHA. Motor turned easily by hand??? BHI indicates that this is the normal condition with extreme motors. Change out motor and EDC. Check BHA electrically. Found orienter not working. Change out orienter. Last good functional orienter is now in BHA. Re check BHA electrically. All passed ok. RIH with BHA #8. Shallow hole test @ 725'. with EDC closed CTP=3437 free spin, AP=498 psi, IP=952 psi, all at 1.5 bpm. Shut down pumps, open EDC, CTP=2780 psi, AP=483 psi, IP=508 psi, rate=1.5 bpm. RIH with BHA #8. Discussion with BHI, SWS, BP about best way to proceed with drilling high dogleg interval just outside window while minimizing strain on orienter. (Last orienter available in Alaska at this time). Dry tag at 7229.5', make -4.5' correction to 7225', last tag on last run after tie in. Generator 3 (SWS-Nordic) just went down. Waiting on electrician to get power to BHI unit from rig generator. 7225', Start drilling. Free spin 3850 psi 1.5/1.5, AP=4154 psi, IP=4647 psi. ROP=25 fph, Pit vol=342 bbls. Attempt to orient off bottom. Can't orient. Pick up into casing, perform some BHI magic, and orienter apparently works. Attempt to return to drilling. Orient to 265 deg. Ease BHA down in open hole. Free spin CTP=3700 psi, AP=4120 psi, IP=4540 psi, 1.5/1.5. Run down from 2' outside window at 2 fpm. Tag up start drilling at 7225'. TF265 deg, orienter working properly in casing, but looking dodgey in window. 1.5/1.5 CTP=3800 psi, AP=4120 psi, IP=4603 psi. Pit vol=342 bbls. 7232', Drilling ahead. 1.5/1.5/4100 psi. Drilling with 300 psi back pressure on well now. Pump pressure 4700 psi. Trips set at 5000 psi. We are at the ragged edge with respect to pump pressure when drilling. There is room for only 300 psi additional motor work prior to hitting trips. Pick up to orient. Printed: 4/30/2002 3: 18: 1 0 PM ') ') Operations Sum maryReport Legal Well Name: 3C-04 Common Well Name: 3C-04 Spud Date: 8/16/1985 Event Name: REENTER+COMPLETE Start: 4/21/2002 End: 4/29/2002 Contractor Name: NORDIC CALISTA Rig Release: 4/30/2002 Rig Name: NORDIC 1 Rig Number: HOUrs .ActivityCödé 4/25/2002 17:40 - 17:45 0.08 DRILL P PROD1 Orienter acts up every time it runs thru the window. 17:45 - 18:15 0.50 DRILL P PROD1 Resume drilling to 7235' and orientor in a bind 18:15 - 19:00 0.75 DRILL P PROD1 Ream lowside hole in 10-20 deg increments to desired TF FS 1.5/4000 19:00 - 19:40 0.67 DRILL P PROD1 Drop WHP to 200 psi to get some room for motor work. Begin taking a bite at 7236' at 90L. Drill to 7241' where stall occurred while working TF to 20L 19:40 - 21 :00 1.33 DRILL P PROD1 Drilling 30'/hr 1.5/3800/1 OL Drop WHP to 100 psi PVT 344 21 :00 - 22:10 1.17 DRILL P PROD1 7285' Drilling 30'/hr 1.5/3700/5L PVT 345 AP 4218 psi Drill to 7300' 6590' TVD in 125 api shale. PUH, SD pump check forWHP. Still holding 100 psi induced. PVT 345. Resume drilling 1.5/3700/20L Drill to 7314'. Lost a bunch of angle wI low side KO-may land 5' deep, but okay wI geo since shale GR doesn't correlate to prior logs 22:10 - 23:20 1.17 DRILL P PROD1 Geo uncomfortable with GR counts and general plan. Wiper to window. Open EDC. PUH and relog down from 7150' 1.5/3250 180'/hr, thru window clean at 165R, and down to 7305' 23:20 - 00:00 0.67 DRILL P PROD1 No correction. Resume drilling at 20-40'/hr 1.5/3700/15L. Drill to 7330' 4/26/2002 00:00 - 00:40 0.67 DRILL P PROD1 Continue drilling 20-40'/hr from 7330' in 100+ api shale 1.5/3700/10L holding 100 psi whp building angle to land in A3 sand at 6555' TVD PVT 343. Drill to 7350' 00:40 - 02:30 1.83 DRILL N WAIT PROD1 PUH 20' and check well for press-none other than 100 psi induced. Wiper to window 1.5/3680 while geo confers wI town geo-may need to drop 35' TVD to hit A3. .. Open EDC at window. Log down from 7000-7226' while WOO. Park at 7226' 0.5/1480 PVT 342 02:30 - 03:10 0.67 DRILL N PROD1 Yup, town agrees and advises to proceed ahead to new target at 6590' TVD, but minimize exposure to A6. Plot a course, cuss and discuss. Close EDC, RBIH 03:10 - 05:20 2.17 DRILL P PROD1 Resume drilling from 7350' 15-35'/hr 1.5/3600/55L PVT 341. Drill to 7400' 05:20 - 06: 15 0.92 DRILL P PROD1 PUH 20' and check well for press-none other than 100 psi induced. Resume drilling from 7400' 1.5/3640/60L. Check IA and had 2000 psi. RU to bleed down 06:15 - 06:40 0.42 DRILL P PROD1 7430' (6570' TVD) Drilling 1.5/3650/45L 06:40 - 06:50 0.17 DRILL P PROD1 7440', short wiper trip to clean hole. ROP very slow. Gamma very hot. Drilling hard clays. PU weight 18klbs. RI weight=8500 Ibs. Free spin CTP=3800 psi. 06:50 - 07:00 0.17 DRILL P PROD1 Resume drilling. 1.5/1.5/4100 psi. ROP=20 fph, TF=300 deg, Pit Vol=342 bbls. 07:00 - 07:30 0.50 DRILL P PROD1 Bleed off OA and IA pressures. At start of day OA=650 psi, IA=2100 psi. After bleeding OA=580, IA=550 psi. 07:30 - 08:00 0.50 DRILL P PROD1 7475', ROP 50 fph, 1.5/1.5/3950 psi. TF315 deg. Pit Vol=341 bbls: Saw drilling break at 7440', gamma cleaned up. Appear to be in A sand. 08:00 - 08:15 0.25 DRILL P PROD1 Wiper trip to shoe. Observed a small amount of motor work at 7320' on trip up. 08: 15 - 08:30 0.25 DRILL P PROD1 SI pump, monitor WHP to observe where it stabalizes at. WHP=40 psi, Annular pressure=3495 psi. 08:30 - 09:00 0.50 DRILL P PROD1 RIH to finish wiper trip and resume drilling. Did not see Printed: 4/30/2002 3: 18: 1 0 PM ') ') Legal Well Name: 3C-04 Common Well Name: 3C-04 Spud Date: 8/16/1985 Event Name: REENTER+COMPLETE Start: 4/21/2002 End: 4/29/2002 Contractor Name: NORDIC CALISTA Rig Release: 4/30/2002 Rig Name: NORDIC 1 Rig Number: Date From...Tö Hours AêtivityCöde NPT Phase Descri ptiÖhof Operations 4/26/2002 08:30 - 09:00 0.50 DRILL P PROD1 anything while RIH at 7320'. Set down 2 times at 7402'. Had to ream back down from 7402'-7425'. Had to work up and down 4 times to get thru cleanly. Some stickyness on pickups at first. Finally got it cleaned up. Geo reports this is the A6 shale. 09:00 - 10:00 1.00 DRILL P PROD1 Resume drilling. 1.5/1.5/3950, ROP=47 fph, Pit vol=337 bbls. 10:00 -11:20 1.33 DRILL P PROD1 7554', update at 10:00 AM, 1.5/1.5/4200 psi. Pit volume=338 bbls, TF=270, ROP=58 fph, WHP=1 00 psi back pressure, 11 :20 - 11 :50 0.50 DRILL P PROD1 7600', Wiper trip to shoe, holding 400 psi on WHP as per proceedure on trip up. Did not see anything on trip up. Had to work in from 7412'-7422' to get thru it. Made 3 passes up and down to finally get it clean. 11:50 -15:50 4.00 DRILL P PROD1 Resume drilling. 1.5/1.5/4000 psi. AP=4340 psi, IP=4960 psi. TF=285 deg, ROP=60 fph. 15:50 - 16:05 0.25 DRILL P PROD1 7730' MD, 6576.6' TVD, Inc=92 deg at bit. Pit volume=332 bbls. Lost 10 bls of mud since starting tour at 06:00. PUH, wipe shale at 7402'-7425'. Didn't see anything on trip up. 16:05 - 16:50 0.75 DRILL P PROD1 Ream shales 7402'-7425', pulled up smooth through it on first pass. Tried to RIH on first down pass, and got packed off. Out rate dropped to 1.1 bpm (from 1.5) and CTP came up. Had to drill back down thru it at same tool face as originally drilled. (60L) Need to get this sorted out or we will have problems with liner. Notify MI on slope and BP/PAI in town. Mix 14#/bbl claygard pill. While mixing pill, ream up and down through shale. Each time down through shale it packs off and we stack out weight. Current AP=4286 psi. 16:50-17:10 0.33 DRILL P PROD1 Shale is as clean as we can get it, RIH. Set down one time at 7620', then fell thru? Haven't seen any problems at this depth before. Make it to TD easily. 17:10 -17:45 0.58 DRILL P PROD1 Pump 1 bbl of 14#/bbl pill past bit at TD. PU laying in mud at 60%, pumping at 0.5 bpm,. Kick pumps on to 1.5 bpm, open choke, pull thru shale interval, then RIH. Tagged up at 7398'. Worked back down thru. Current CTP=3930 psi, WHP=100 psi, AP=4550 psi, IP=4900 psi. Ream up and down while washing clay with claygard pill. PUH laying pill in remainder of open hole. 17:45 - 18:55 1.17 DRILL P PROD1 Stop at csg shoe, hold 1000 psi on whp, while pumps down. Open EDC, POOH following choke schedule in proceedure. 18:55 - 19:10 0.25 DRILL P PROD1 Close EDC at 200'. Tag up. PVT 300 Safety mtg: pressure undeployldeploy 19:10 - 22:00 2.83 DRILL P PROD1 Pressure undeploy and deploy with 1000 psi. Change motor 22:00 - 23: 15 1.25 DRILL P PROD1 Open back up to well and see 730 psi. RIH wI BHA #9 (1.1 deg motor, same bit) following Well Plan pressure schedule. Wind at 40 mph 23: 15 - 23:45 0.50 DRILL P PROD1 Log down while RIH thru window. Corr -8.4'. Close EDC 23:45 - 00:00 0.25 DRILL P PROD1 Precautionary ream to TD. Orient TF to 60L to RIH past 7400' shale. Set down at 7407' 4/27/2002 00:00 - 00:35 0.58 DRILL P PROD1 Ream A6 from 7400-25' at drilled TF taking 5' bites to 7415', then punch thru it to 7450'. Backream thru, clean. RIH, clean 1.5/3650/45L. Wind increasing to 50 mph 00:35 - 01 :35 1.00 DRILL P PROD1 Continue RIH to TD wI set down at 7618' (A3 shale). PUH and Printed: 4/30/2002 3:18:10 PM ) ) Legal Well Name: 3C-04 Common Well Name: 3C-04 Spud Date: 8/16/1985 Event Name: REENTER+COMPLETE Start: 4/21/2002 End: 4/29/2002 Contractor Name: NORDIC CALISTA Rig Release: 4/30/2002 Rig Name: NORDIC 1 Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 4/27/2002 00:35 - 01 :35 1.00 DRILL P PROD1 started losing ground. PUH from 7600-7536' 10k over. Acts like sticky clay on top of and covering BHA. Work to TD with noticable str wt loss at 7675'. Tag TD at 7734' 01 :35 - 02:40 1.08 DRILL P PROD1 Drilling 60'/hr 1.5/3730/85L in target A3 sand with -3k string wt holding 100 psi whp. PVT 328 Vac trucks delayed due to slick roads "(33 deg F) and high winds (Phz 1, gusts to 65 mph) 02:40 - 03:40 1.00 DRILL P PROD1 Found a hard spot at 7785' 1.5/3790/80L. Begin mud swap, empty pits. Phz 1 Drill to 7843' 03:40 - 04:30 0.83 DRILL P PROD1 New mud at bit. Wiper to window (test the waters). Clean trip to window. Set down at 7405' while RIH. Get thru first try. Same at 7620' 04:30 - 04:50 0.33 DRILL P PROD1 Drilling from 7843' 1.5/3440/90L New mud has lowered CTP by 350 psi and AP is 4167 psi. Shale in returns are up to 1/4" in dia. Increase drilling backpressure to 300 psi. Phz 2 04:50 - 06:15 1.42 DRILL P PROD1 Drill ahead wI -3k to -8k string wt at 1 0-30'/hr to right side 1.5/3650/80R Find out that no lubetex was added to mud. Drill in and out of sand to 7904' 06: 15 - 06:30 0.25 DRILL P PROD1 Drilling 50-80'/hr w/-1 k string wt in sand 06:30 - 07:00 0.50 DRILL P PROD1 7918' Drilling 10-50 fph, -5000 Ibs weight on bit. Free spin at 1.5 bpm=3550 psi, 1.5/1.5/CTP=3875 psi. PP=4500 psi, AP=4375 psi, IP=5121 psi. Pressures are about 300 psi lower with the new mud than with the old. Weight transfer is not very good however. Add 3 drums lubetex. 07:00 - 07:45 0.75 DRILL P PROD1 IA pressure up to 970 psi. Bleed to 550 psi. Continue drilling. Current Pit Vol=223 bbls. 07:45 - 08:00 0.25 DRILL P PROD1 Pre tour safety meeting. 08:00 - 08:10 0.17 DRILL P PROD1 Continue drilling ahead. Crossed fault #2 at 7970'. Need to start drilling down to get back into A3. 08:10 - 08:40 0.50 DRILL P PROD1 8000', wiper trip to shoe. Clean pickup at 18klbs. Clean on up trip. No overpulls or motor work anywhere. 08:40 - 09: 1 0 0.50 DRILL P PROD1 Log tie in pass over pip tag in whipstock. Make a +9' correction. Geo reports significant amount of cavings in samples. Getting sharp, hard pieces of shale about 1/4"-3/8" in size. Probably from a cave, probably the A6 that has been giving us troubles. 09:10 - 09:35 0.42 DRILL P PROD1 RIH to complete wiper trip and resume drilling. Pumped at 1 bpm, RIH at 40 fpm, and got thru 7402' interval with no bobbles! Tagged up at 7640', while pumping at 1.5 bpm. Picked up, dropped rate to 0.8 bpm, and ran thru it easily at 40 fpm. Tag 8007.7 ft. 09:35 - 11 :50 2.25 DRILL P PROD1 Resume drilling, Free spin 3700 psi at 1.5 bpm. 1.5/1.5/3800 WHP=320 psi, AP=4457 psi, IP=5326 psi, ROP=55 fpm, Weight=-3000 Ibs, Pit vol=218 bbls. Well appears be taking fluid slightly. Lossing at about 1 to 1.5 bbl/hr. 11 :50 - 12:50 1.00 DRILL P PROD1 8150', Wiper trip to shoe. Slick up, slick down thru 7402' shale. Bobbled thru 7620' shale. Set down at 7926', then fell thru. Had trouble the last 200 feet to bottom, looked like differential sticking. Backed choke pressure from 300 psi at surface to 0, and ran in the hole clean. 12:50 - 14:50 2.00 DRILL P PROD1 Resume drilling, back on left side. 1.5/1.5/3500/90L, 0 psi WHP, AP=4198, IP=4696 psi. 14:50 - 16:00 1.17 DRILL P PROD1 8345', Wiper trip to shoe. Clean pickup at 18klbs. Hung up at Printed: 4/30/2002 3: 18: 1 0 PM ') ) PHILLIPS PETROLEUM CO. Operations Summary Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3C-04 3C-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/21/2002 Rig Release: 4/30/2002 Rig Number: Spud Date: 8/16/1985 End: 4/29/2002 Date From-To HoürSActivityCode NPT Phäse DescriptionöfOþeratiöns 4/27/2002 14:50 - 16:00 1.17 DRILL P PROD1 7400' on way out of hole. Did not pull into it hard, but got stuck and could not go back down. Packed off around motor. Seeing weight changes on WOB sensor. Loosing returns Tried pumping, surging choke, finally held 1000 psi on well and were able to run in hole. Came back up gently, and got stuck again. Held 1000 psi, worked ourselves free. RIH to 7500', open EDC, Pump 1.7/3800 psi, got returns back. RIH slowly, getting grabby. Looks like drag on the coil from packoff shale up above, (Using Annular pressure sensor). Packof was below AP sensor at first go round, now above AP sensor. 16:00 - 17:15 1.25 DRILL P PROD1 Continue working pipe. Mix hi vis sweep. Pumping 1.4/1.2 back. Holding 500 psi while working pipe. Try PUH slowly to see if we can work thru. EDC open, watching APt we could see pulling into packoff at 7400' bit depth (30' bit to AP sensor puts packoff at 7370'). Note top of A6 shale is at 7400'. Used EDC to jet out packed off shale. (Thank goodness for the EDC). Managed to work thru it watching as we pulled into it on AP, then jetting debris free. Got free prior to hi vis sweep reaching EDC. Cleaned up by 7300', continue wiper trip to shoe. Chase cuttings up hole with sweep. 17:15 -18:00 0.75 DRILL P PROD1 Log tie in pass down. Pump hi vis sweep while logging to clean tubing. Make +10' correction. Space 20 bbls of mud, then pump another 10 bbl sweep to wash A6 shale. 18:00 - 19:00 1.00 DRILL P PROD1 RIH wI a few set downs in known bad spots 19:00 - 19:55 0.92 DRILL P PROD1 Tag TD at about 8349'. Drill ahead with neg wt 1.5/3680/90L holding 300 psi WHP wI AP 4450 psi. Drill with -8k wt/10'/hr where prior to wiper trip were making 70'/hr wI positive str wt 19:55 - 21 :40 1.75 DRILL P PROD1 8362' Finally got string wt back and making hole 1.5/3800/95L +2k string wt 50'/hr PVT 305. Drill to 8454'. PVT 300 21:40 - 23:10 1.50 DRILL P PROD1 Wiper to window (test the water) 17.2k. Minor motor work thru known spots on PUH. On RIH, clean thru 7400' and set down twice at 7625'. Need 4500-4600 psi AP to hold shales back 23:10 - 00:00 0.83 DRILL P PROD1 Stack wt at 8394', lose ground back to 8368', then back to 8350'. All sand in this interval. Acts like lockup may be occurring. Slow backream to 8340' while throw a drum a lubetex at it 4/28/2002 00:00 - 00:30 0.50 DRILL P PROD1 Slow ream to TD from 8340', poor wt transfer. Invent and put into effect the 'One hour rule' 00:30 - 03: 15 2.75 DRILL P PROD1 Resume drilling on right side from 8452' tag wI -3k string wt 1.5/3800/1 05R AP 4584 psi, PVT 290. Begin sli drop to prep for next fault. Digging good consistent sand at 40-60'/hr 03:15 - 04:05 0.83 DRILL P PROD1 Start stacking at 8585' which is probably interface at last fault. Wiper to window 1.5/3840 AP 4570 PVT 282 Had 3k constant overpull from 7650' to 7460' wI a few 12K overpulls. Then had the same from 7410-7370' where normal string wt returned 04:05 - 04:15 0.17 DRILL P PROD1 Tie-in from 7230', add 11' AP 4440 04:15 - 05:25 1.17 DRILL P PROD1 Tag up and work thru 7425' 3 times 1.0/3000/whp 550 AP 4640 Set down at 7738' (not bit, but top of BHA). Got thru on 5th try by reaming at 10'/min. Set down at 8000' and work various spots to 8330' 05:25 - 06: 15 0.83 DRILL P PROD1 Start 'one hour rule'. Dump a drum of lubetex and slow ream to TD from 8300' 06: 15 - 07:00 0.75 DRILL P PROD1 8500' Continue slow ream to TD and finally get there at 8591' Printed: 4/30/2002 3:18:10 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3C-04 3C-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/21/2002 Rig Release: 4/30/2002 Rig Number: Spud Date: 8/16/1985 End: 4/29/2002 Date Frorn - To Hours Activity COde NPT Phase Description of Operations 4/28/2002 06:15 - 07:00 0.75 DRILL P PROD1 tag. PVT 274 07:00 - 07:45 0.75 DRILL P PROD1 Hole deteriorating badly. Weight transfer is also much worse than predicted, and had trouble just getting back to bottom after last wiper trip. Probably due to higher drag than expected. Chances of getting remaining 300' are not good. Chances of getting liner in hole at this point are 50/50. Need to call this TD. Call and confer with town. Need to condition hole and clean up as much as possible. Start wiper trip up. Clean PU off bottom 18500 Ibs. Pump Hi vis pill to sweep hole. 07:45 - 08: 1 0 0.42 DRILL P PROD1 On wiper trip up, hung up at 7630', worked it free, hung up at 7610', packing off, lost returns, stuck. Had to pressure up WFP to 1000 psi while pumping 1 bpm to get free. Not ideal, hard on shales, but heck, we were stuck. Do what we have to do. Get up thru shale interval, will continue to shoe, and ream on next trip in the hole. Finish wiper trip to shoe. Held 1000 psi at 0.3 bpm thru shales at 7400-7430, and didn't see a bobble! 08:10 - 08:25 0.25 DRILL P PROD1 Log tie in pass down over RA tag. EDC open, holding 970 psi on WHP. Adjusting pump rate to hold AP=4780. Make +7' correction. 08:25 - 10:25 2.00 DRILL P PROD1 Wiper trip down, holding 4800 psi on AP, 565 on WHP, pumping at 1.3 bpm, RIH at 10-20 fpm, cleaning hole. Pumping sweeps of 1 OOklsrv mud to try to remove cuttings. Holding AP steady at a pressure that seems to keep shales under control. Made it back to bottom with small tag ups at 7400 shale and 7630'. Tag up at 8591'. 10:25 - 12:20 1.92 DRILL P PROD1 Wiper trip up to shoe. Number 3 for today. Holding 550 on WHP, AP=4764, pump rate = 1.2 bpm, CTP=3630 psi. PUH at 10-15 fph. Having to cycle choke at surface. Keep getting plugged off with shale cavings. Seem to be cleaning hole, that is a very good thing. Saw nothing at 7667', slight motor work at 7610', but no packing off, no overpulls. Pulled thru 7400' shale with no over pulls. Pumped final 1 0 bbl sweep as we came into the window. Pumped a total of 70 bbls in sweeps on last trip in and out of the hole. 12:20 - 13:50 1.50 DRILL P PROD1 Wiper trip RIH hole at 15 fph. Made it thru 7400' with no weight loss. Tagged up at 7620', packed off, and returns went to 80%. Picked up and then ran thru ok. Hole slick 7650'-7920'. Set down at 7920', then fell thru ok. Last 250' went very slow as weight transfer was not great. Had to hold 1000 psi on WHP and pump 0.3 bpm to get last 250'. 13:50 - 14:25 0.58 DRILL P PROD1 Made it to bottom ok. Start 10 bbl, 12.6 ppb, 14.5 #/bbl claygard, 6% lubtex pill. Will leave in open hole. Follow with 12.6 ppb, 2% lubetex formate KWF. 14:25 - 14:55 0.50 DRILL P PROD1 PUH at 25 fpm, pumping pill out bit at 0.25 bpm. Holding 1000 psi on whp, maintaining 4760 psi on AP. KWF density on MM=12.39 ppg, with mud check=12.48 ppg. Weight off bottom=21 klbs. Slick up thru bad shales at 7620', and 7400'. No bobbles on weight, no motor work anywhere. Entire open hole interval Printed: 4/30/2002 3: 18: 1 0 PM ') ) Legal Well Name: 3C-04 Common Well Name: 3C-04 Spud Date: 8/16/1985 Event Name: REENTER+COMPLETE Start: 4/21/2002 End: 4/29/2002 Contractor Name: NORDIC CALISTA Rig Release: 4/30/2002 Rig Name: NORDIC 1 Rig Number: From-To HoUrs AbtivitYCode NPT Phase 4/28/2002 14:25 - 14:55 0.50 DRILL P PROD1 looked good. 14:55 - 15:35 0.67 DRILL P PROD1 7224' Stop just outside window. SI pumping, holding 1000 psi on WHP, AP=4686 psi. Perform maintenance on hydraulic reel motor, and clean out under shaker screens. 15:35 - 16:45 1.17 DRILL P PROD1 POOH, pumping at 1 bpm, 100 fpm. Pulling at 100%. Laying in 12.45# KWF, displacing 10 #. Following modified pump schedule to maintain constant BHP. Holding 1000 psi at shoe, 300 psi at surface, with a linear interpolation in between. 16:45 -17:15 0.50 DRILL P PROD1 Tag up at surface, SI pumps, bleed WHP to 0, standby for no flow test. 17:15-17:25 0.17 DRILL P PROD1 Safety meeting prior to laying down BHA #9. 17:25 -18:00 0.58 DRILL P PROD1 Lay down BHA #9. 18:00-18:15 0.25 DRILL P PROD1 Tour crew change. 18:15 -18:45 0.50 CASE P COMP RU to run liner 18:45 -19:00 0.25 CASE P COMP Safety mtg re: liner/CSHIDC's/wellbore. Fill hole wI 2 bbls 19:00 - 20:45 1.75 CASE P COMP MU 45 jts 2-3/8" 4.43# L-80 STL slotted liner wI guide shoe and O-ring sub Kick drill wI safety jt 20:45 - 22:30 1.75 CASE P COMP MU 46 jts 1" CSH workstring w/1 O'stinger. MU BOT Deployment sleeve wI GS. MU 72-1/8" DC's 4.7#/ft 22:30 - 23:45 1.25 CASE P COMP MU Baker Coiltrak BHA wI EDC, press, GR, checks, disc) 23:45 - 00:00 0.25 CASE P COMP RIH wI liner assy on CT 6.2k 0.3 bpm/320 psi CTP thru open EDC 80'/min thru open choke. BHA OA 1716.5' 4/29/2002 00:00 - 00:55 0.92 CASE P COMP Continue RIH wI liner 00:55 - 04:00 3.08 CASE P COMP See flag at 7146.7' CTD and should be 7116'.did not correct (5428' mech counter) 13.6k @ 80'/min, PUH 24K 17'/min. EDC open 0.3/450 Check BHI AP 3400 and calc's equal to 12.6 MW at same TVD. RIH thru window 30'/min 14k. First set down at 7350'-too numerous to mention after that. PU at max 10k over, but clean most of the time. Incr rate thru EDC to 1.0/1750. Work to 8417' and progress stopped. Close EDC and circ 5 bbls 1.0/4000, no progress AP 4120. Switch back and forth and get to 8489' twice, but lose ground up to 150' at times 04:00 - 04:55 0.92 CASE P COMP With shoe at 8489' close EDC (pump thru workstring) 0.9/4000 and continue to gain and lose. Work liner to 8573' CTD twice and call this close enough-getting sticky and losing ground. Liner shoe may be up to 37' above TD or at actual TD since flags were off and drilling depths varied due to stacked weight. If shoe is at TD, then TOL is 7132', PBD is 8557'. PVT 145 04:55 - 06:00 1.08 CASE P COMP Release from liner wI GS 0.8/4000 21 k. PVT 145 POOH 06:00 - 06:30 0.50 CASE P COMP Tag up wI CSH. Monitor well stability during crew change out PVT 133 06:30 - 07:00 0.50 CASE P COMP Safety meeting prior to laying down CSH BHA. 07:00 - 08:50 1.83 CASE P COMP RD BHA, lay down drill collars, and BHI Coiltrak BHA. Stand back CSH. 08:50 - 09:30 0.67 CASE P COMP MU Cleanout run BHA. CTC-CHKS-STINGER-2.5" JSN 09:30 - 10:50 1.33 CASE P COMP RIH with BHA 10, 2.5" JSN-Stinger bars-CHKs-XO-CTC. 10:50 - 11 :25 0.58 CASE P COMP 7100', Kick on pumps, pumping with 12.45 # KWF. Pumping at 1.0 BPM, getting full returns. Pump 5 bbls OK. SD pumping. Standby for driller to complete gelling up system. 11 :25 - 12:40 1.25 CASE P COMP Circulate pumping very high vis 30 bbls sweep of seawater, Printed: 4/30/2002 3: 18: 1 0 PM ) ) Legal Well Name: 3C-04 Common Well Name: 3C-04 Spud Date: 8/16/1985 Event Name: REENTER+COMPLETE Start: 4/21/2002 End: 4/29/2002 Contractor Name: NORDIC CALISTA Rig Release: 4/30/2002 Rig Name: NORDIC 1 Rig Number: From'-To HotlrsActivity 4/29/2002 11 :25 - 12:40 1.25 CASE P COMP follwed by 2# biozan seawater. Pumping 1.0, returns 1.0 when gell out the nozzle at 7100'. Chased KWF OOH quite easily with only 2 bbllosses. System seemed to work very well, with only about 3 bbls of mixing. Note, no WHP observed with seawater in hole. 12:40 - 14:00 1.33 CASE P COMP POOH, laying in seawater. Pump 22 bbls of diesel for freeze protect. 14:00 - 14:20 0.33 CASE P CaMP Tag up at surface, SI pumping. Standby to obtain a steady WHP. WHP=533 psi. 14:20 - 15:20 1.00 CASE P CaMP Lay down Nozzle BHA, blow coil back. Stand back injector. 15:20 - 15:40 0.33 RIGD P COMP Safety meeting prior to HES setting downhole pump thru plug. 15:40 - 16:00 0.33 RIGD P COMP RU slickline eq. PT lubricator to 1000 psi. 16:00 - 16:50 0.83 RIGD P COMP RIH with slickline to nipple at 518'. Set 2.812" CS Lock with MCX Injection valve. POOH. Tag up at surface, bleed pressure, injection valve held. 16:50 - 17:45 0.92 RIGD P CaMP RD slickline. 17:45 - 18:45 1.00 RIGD P caMP Install BPV wI GPB DSM crew, VR plug wI KRU DSM crew 18:45 - 22:30 3.75 RIGD P COMP KRU DSM crew attempt to install 3 different VR plugs in GL IA wlo success. IA has 250 psi. Blow down rig lines and hardline to tanks with air. Vac pits/tanks. Close MV, SW, SSV. Winds to 40 mph. Phz 1-2 22:30 - 00:00 1.50 RIGD P COMP ND BOPE. NU tree cap and test RREL @ 2400 hrs 4/29/02 Printed: 4/30/2002 3: 18: 1 0 PM ) ~oa.05 7 '~ .~' Phillips Alaska, Inc. Pad 3C 4A slot #4 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref: PMSS <7212-8591'> Our ref: svy6748 License: Date pririted: 3-May-2002 Date created: 2-May-2002 Last revised: 2-May-2002 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 24 4.812,w149 45 33.625 Slot location is n70 24 0.680,w149 46 14.698 Slot Grid coordinates are N 5996010.380, E 528168.280 Slot local coordinates are 420.00 S 1402.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North f" ~.. r" ,... 5 tl !J r ['''''I ., ,'1 ~t... ~. Ìi.", ~ ~~"¡ ~... , ~ þ. * ' ~ ,j '" E 'I ~~. I"" ",,' ;i'=" " ,i.,~ "'\ ,'~. ,'""1 ,., " ("\ U d t.:UUt., Alaska o¡~ g¡ CCW..; ,-,;},i,i,\!;;';li)' AmJ~or:;-i:Y' ) ) Phillips Alaska, Inc. SURVEY LI STI NG Page 1 Pad 3C,4A Your ref: PMSS <7212-8591'> Kuparuk River Unit,North Slope, Alaska Last revised: 2-May-2002 Measured Inclin Azimuth True Vert R E C TAN G U L A R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 7212. 00 44.28 4.22 6536.53 1830.99N 238.61E 0.56 -45.91 528399.62 5997842.12 7230.28 31.04 0.71 6550.97 1842.12N 239.14E 73.37 -45.27 528400.11 5997853.25 7263.48 39.17 354.83 6578.12 1861.16N 238.30E 26.50 -42.45 528399.19 5997872.28 7290.03 46.36 350.66 6597.60 1879.01N 235.98E 29.09 -38.28 528396.80 5997890.13 7319.42 54.39 346.49 6616.33 1901.17N 231.46E 29.42 -31.46 528392.19 5997912.26 7351.12 62.37 342.39 6632.94 1927.13N 224.18E 27.47 - 21. 51 528384.81 5997938.19 7378.87 67.92 339.08 6644.61 1950.88N 215.86E 22.74 -10.76 528376.40 5997961.91 7409.19 73.29 335.67 6654.67 1977.26N 204.86E 20.64 2.95 528365.29 5997988.24 7436.91 77.95 332.71 6661.56 2001. 42N 193.16E 19.74 17.10 528353.50 5998012.35 7465. 75 82.43 325.01 6666.48 2025.71N 178.47E 30.55 34.25 528338.72 5998036.58 7497.80 86.31 316.14 6669.63 2050.31N 158.23E 30.08 56.95 528318.38 5998061.10 7527.53 90.43 308.54 6670.47 2070.31N 136.29E 29.06 80.87 528296.36 5998081.01 7557.81 90.86 299.46 6670.13 2087.22N 111. 21E 30.02 107.57 528271.22 5998097.82 7587.34 93.47 291.48 6669.02 2099.90N 84.59E 28.41 135.37 528244.56 5998110.39 7617.22 95.51 284.15 6666.67 2109.01N 56.26E 25.39 164.50 528216.19 5998119.39 7646. 75 95.73 275.97 6663.78 2114.14N 27.35E 27.58 193.79 528187.26 5998124.40 7677 .66 97.47 266.68 6660.22 2114.86N 3.32W 30.38 224.36 528156.60 5998125.00 7710.59 92.52 259.43 6657.35 2110. 89N 35.85W 26.58 256.30 528124.09 5998120.90 7741.20 91.10 251.97 6656.38 2103.33N 65.47W 24.80 284.97 528094.49 5998113.23 7774.62 91.96 246.09 6655.48 2091.38N 96.65W 17.78 314.73 528063.36 5998101.16 7807.38 94.49 242.53 6653.64 2077.21N 126.12W 13.32 342.56 528033.95 5998086.87 7839.43 94.83 238.56 6651.04 2061.50N 153.93W 12.39 368.57 528006.21 5998071. 05 7874.46 93.59 240.44 6648.46 2043.77N 184.03W 6.42 396.66 527976.18 5998053.21 7904.34 95.07 244.00 6646.21 2029.89N 210.39W 12.87 421.42 527949.88 5998039.22 7933 . 98 94.05 249.88 6643.85 2018.32N 237.56W 20.07 447.23 527922.76 5998027.55 7964. 11 92.83 252.37 6642.04 2008.59N 266.02W 9.19 474.51 527894.35 5998017.71 7996.98 93.10 257.14 6640.34 1999.96N 297.68W 14.52 505.10 527862.72 5998008.95 8032.61 92.40 263.84 6638.63 1994.09N 332.76W 18.89 539.37 527827.67 5998002.94 8062.24 91.29 268.88 6637.67 1992.21N 362.30W 17.41 568.56 527798.14 5998000.94 8092.32 93.56 273.79 6636.40 1992.91N 392.33W 17.97 598.50 527768.10 5998001.52 8122.05 93.90 280.23 6634.46 1996.53N 421.76W 21. 65 628.15 527738.66 5998005.02 8152. 53 91.75 282.80 6632.96 2002.60N 451.59W 10.98 658.45 527708.81 5998010.98 8182.35 91. 84 277 . 39 6632.03 2007.83N 480.92W 18.14 688.16 527679.46 5998016.09 8212.93 92.18 273.27 6630.95 2010.66N 511.35W 13.51 718. 72 527649.03 5998018.81 8242.95 91. 78 269.74 6629.92 2011.45N 541. 33W 11.83 748.62 527619.05 5998019.48 8273.20 91.26 267.24 6629 . 11 2010.66N 571.56W 8.44 778.60 527588.83 5998018.56 8303.28 90.43 262.27 6628.67 2007.91N 601. 50W 16.75 808.09 527558.90 5998015.69 8339.37 94.36 251. 86 6627.16 1999.85N 636.59W 30.80 842.14 527523.85 5998007.50 8369.59 94.70 247.90 6624.77 1989.49N 664.87W 13.11 869.19 527495.61 5997997.03 8400.36 94.27 244.37 6622.36 1977 . 08N 692.92W 11.52 895.79 527467.61 5997984.51 8429.56 91.63 241. 34 6620.86 1963.78N 718. 86W 13.75 920.20 527441.72 5997971.11 8459.58 92.18 240.56 6619.86 1949.21N 745. 09W 3.18 944.76 527415.56 5997956.44 8489.96 90.64 244.95 6619.12 1935.31N 772.09W 15.31 970.15 527388.62 5997942.43 8520.37 88.71 247.45 6619.29 1923.04N 799.91W 10.39 996.54 527360.85 5997930.05 8553.22 87.60 252.51 6620.35 1911.81N 830.74W 15.76 1026.03 527330.06 5997918.69 8591.00 86.00 257.00 6622.46 1901. 89N 867.13W 12.60 1061.18 527293.72 5997908.63 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #4 and TVD from wellhead (85.00 Ft above mean sea level). Bottom hole distance is 2090.24 on azimuth 335.49 degrees from wellhead. Vertical section is from wellhead on azimuth 276.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) Phillips Alaska, Inc. Pad 3C,4A Kuparuk River Unit,North Slope, Alaska MD TVD Rectangular Coords. ') SURVEY LISTING Page 2 Your ref: PMSS <7212-8591'> Last revised: 2-May-2002 Comments in wellpath Comment ....... -..-- -..- ---..........-... ----.. --..- ...--..... ---.. ----.................... -...... ..-....... ---.... ..........", ..-- ",..-........."",,,,,,,,,,,- -...... ----.... ----......-- 7212.00 7230.28 7263.48 7290 . 03 7319.42 7351.12 7378.87 7409.19 8591.00 6536.53 6550.97 6578.12 6597.60 6616.33 6632.94 6644.61 6654.67 6622.46 Top MD Top TVD 1830.99N 1842.12N 1861.16N 1879.01N 1901.17N 1927.13N 1950.88N 1977.26N 1901.89N 238.61E 239.14E 238.30E 235.98E 231.46E 224.18E 215.86E 204.86E 867.13W O.OON Rectangular Coords. O.OOE 8591.00 6622.46 1901. 89N Rectangular Coords. 867.13W 2-3/8" Sidetrack Point Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Projected Data-No Survey Casing positions in string 'A' Bot MD Bot TVD Casing -..--.........-.......--.....--..............-......--.........----....---.........--........-..........-..----.......--..----......----..........-..-..--...-------....--- Target name 0.00 0.00 Targets associated with this wellpath ---- T.V.D. Rectangular Coordinates Revised Geographic Location -.....-...-...... ....--........ "'......... ..-- .........-...... ....-..... .....",.... -... ----...... --........ ...---........- ........- --...........-..... ............ ........... .........-................ 3C-04A T3 Rsvd II-Fe 527300.000,5997899.000,-2.000 6645.00 3C-04A T2 Rsvd ll-Fe 527743.000,5998023.000,-2.000 6637.00 3C-04A Tl Rsvd 12-Fe 528206.000,5998138.000,0.0000 6628.00 3C-04A T4 Rvsd 12-Ap 527081.000,5997899.000,-2.000 6645.00 1892.23N 2014.49N 2127.67N 1893.10N 860.88W 12-Feb-2002 417.35W 12-Feb-2002 46.14E 12-Feb-2002 1079.90W 17-Apr-2002 ') ') II.. BAKD HUGIIIS INfEQ BP Baker Hughes INTEQ Survey Report Company: Phillips Alaska, Inc. Field: Kuparuk River Unit Site: KRU 3C Pad Well: 3C-04 Wellpath: 3C-04A Date: 7/10/2002 Time: 10:57:33 Co-ordinate(NE) Reference: Well: 3C-04, True North Vertical ((V D) Reference: 3C-0485.0 Section (VS) Reference: Well (0.00N,O.00E,263.90Azi) Survey Calculation Method: Minimum Curvature Db: Page: Sybase Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2000 Site: KRU 3C Pad UNITED STATES: North Slope Site Position: Northing: 5996435.88 ft Latitude: 70 24 4.812 N From: Map Easting: 529568.47 ft Longitude: 149 45 33.625 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 3C-04 Slot Name: Well Position: +N/-S -420.00 ft Northing: 5996010.38 ft Latitude: 70 24 0.680 N +E/-W -1402.00 ft Easting : 528168.28 ft Longitude: 149 46 14.698 W Position Uncertainty: 0.00 ft Well path: 3C-04A 500292141601 Current Datum: 3C-04 Magnetic Data: 4/17/2002 Field Strength: 57437 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 3C-04 7212.00 ft Mean Sea Level 25.83 deg 80.73 deg Direction deg 263.90 Height 85.00 ft Survey Program for Definitive Well path Date: 5/3/2002 Validated: Yes Actual From To Survey ft ft 100.00 7212.00 7212.00 8591.00 Version: Toolcode 3 Tool Name 3C-04 (0) MWD GCT -MS MWD Schlumberger GCT multishot MWD - Standard Annotation Mo TVD ft ft 7212.00 6536.55 KOP 8591.00 6621.94 TO Survey: MWD Start Date: 4/28/2002 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 7212.00 44.28 4.22 6536.55 6451.55 1831.01 238.75 5997842.09 528400.10 -431.97 0.00 7230.28 31.04 0.71 6550.99 6465.99 1842.14 239.28 5997853.22 528400.59 -433.68 73.36 7263.48 39.17 354.83 6578.13 6493.13 1861.17 238.44 5997872.26 528399.68 -434.86 26.50 7290.03 46.36 350.66 6597.61 6512.61 1879.03 236.12 5997890.10 528397.29 -434.46 29.09 7319.42 54.39 346.49 6616.35 6531.35 1901.18 231.59 5997912.24 528392.68 -432.31 29.42 7351.12 62.37 342.39 6632.96 6547.96 1927.15 224.32 5997938.17 528385.31 -427.84 27.4 7 7378.87 67.92 339.08 6644.62 6559.62 1950.90 216.00 5997961.89 528376.91 -422.09 22.74 7409.19 73.29 335.67 6654.69 6569.69 1977.28 204.99 5997988.22 528365.80 -413.95 20.64 7436.91 77.95 332.71 6661.57 6576.57 2001.44 193.30 5998012.33 528354.02 -404.89 19.74 7465.75 82.43 325.01 6666.49 6581.49 2025.73 178.61 5998036.57 528339.24 -392.86 30.55 7497.80 86.31 316.14 6669.64 6584.64 2050.33 158.37 5998061 .09 528318.91 -375.35 30.08 7527.53 90.43 308.54 6670.49 6585.49 2070.33 136.43 5998081.00 528296.89 -355.65 29.06 ) ) 1I¡¡8 BP BAKH HUGHlS Baker Hughes INTEQ Survey Report --_......._~~--,_.. [NT EQ Company: Phillips Alaska, Inc. Date: 7/10/2002 Time: .10:57:33 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3C-04, True North Site: KRU 3C Pad Vertical (TVD) Reference: 3C-04 85.0 Well: 3C-04 Section (VS) Reference: Well (0.00N,O.00E,263.90Azi) Wellpath: 3C-04A Survey Calculation Method: Minimum Curvature Db: Sybase Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/1000 7557.81 90.86 299.46 6670.15 6585.15 2087.24 111.35 5998097.82 528271.75 -332.52 30.02 7587.34 93.47 291.48 6669.03 6584.03 2099.92 84.73 5998110.40 528245.09 -307.40 28.41 7617.22 95.51 284.15 6666.69 6581.69 2109.03 56.40 5998119.40 528216.72 -280.19 25.39 7646.75 95.73 275.97 6663.79 6578.79 2114.16 27.48 5998124.42 528187.79 -251.99 27.58 7677.66 97.47 266.68 6660.23 6575.23 2114.87 -3.18 5998125.02 528157.13 -221.58 30.38 7710.59 92.52 259.43 6657.36 6572.36 2110.90 -35.71 5998120.92 528124.62 -188.81 26.58 7741.20 91.10 251.97 6656.39 6571.39 2103.35 -65.33 5998113.26 528095.03 -158.55 24.80 7774.62 91.96 246.09 6655.50 6570.50 2091.40 -96.51 5998101.19 528063.89 -126.27 17.78 7807.38 94.49 242.53 6653.66 6568.66 2077 .23 -125.98 5998086.91 528034.48 -95.47 13.32 7839.43 94.83 238.56 6651.05 6566.05 2061.52 -153.79 5998071.10 528006.73 -66.14 12.39 7874.46 93.59 240.44 6648.48 6563.48 2043.79 -183.89 5998053.26 527976.71 -34.33 6.42 7904.34 95.07 244.00 6646.22 6561.22 2029.91 -210.25 5998039.28 527950.40 -6.65 12.87 7933.98 94.05 249.88 6643.86 6558.86 2018.34 -237.42 5998027.61 527923.28 21.60 20.07 7964.11 92.83 252.37 6642.06 6557.06 2008.61 -265.88 5998017.78 527894.86 50.93 9.19 7996.98 93.10 257.14 6640.36 6555.36 1999.98 -297.54 5998009.03 527863.24 83.33 14.52 8032.61 92.40 263.84 6638.64 6553.64 1994.11 -332.62 5998003.02 527828.18 118.83 18.89 8062.24 91.29 268.88 6637.69 6552.69 1992.23 -362.16 5998001.03 527798.65 148.41 17.41 8092.32 93.56 273.79 6636.42 6551.42 1992.93 -392.20 5998001.62 527768.61 178.20 17.97 8122.05 93.90 280.23 6634.48 6549.48 1996.54 -421.63 5998005.12 527739.17 207.08 21.65 8152.53 91.75 282.80 6632.98 6547.98 2002.62 -451.45 5998011.09 527709.33 236.09 10.98 8182.35 91.84 277.39 6632.04 6547.04 2007.84 -480.78 5998016.20 527679.98 264.70 18.14 8212.93 92.18 273.27 6630.97 6545.97 2010.68 -511.21 5998018.92 527649.55 294.65 13.51 8242.95 91.78 269.74 6629.93 6544.93 2011.47 -541.19 5998019.60 527619.56 324.38 11.83 8273.20 91.26 267.24 6629.13 6544.13 2010.67 -571.42 5998018.69 527589.34 354.52 8.44 8303.28 90.43 262.27 6628.69 6543.69 2007.92 -601.36 5998015.82 527559.42 384.59 16.75 8339.37 94.36 251.86 6627.17 6542.17 1999.87 -636.45 5998007.64 527524.36 420.33 30.80 8369.59 94.70 247.90 6624.79 6539.79 1989.51 -664.73 5997997.17 527496.12 449.55 13.11 8400.36 94.27 244.37 6622.38 6537.38 1977.10 -692.78 5997984.66 527468.12 478.76 11.52 8429.56 91.63 241 .34 6620.88 6535.88 1963.80 -718.72 5997971.26 527442.23 505.97 13.75 8459.58 92.18 240.56 6619.88 6534.88 1949.23 -744.95 5997956.59 527416.06 533.60 3.18 8489.96 90.64 244.95 6619.13 6534.13 1935.33 -771.95 5997942.59 527389.12 561.92 15.31 8520.37 88.71 247.45 6619.30 6534.30 1923.06 -799.77 5997930.22 527361.35 590.89 10.39 8553.22 87.60 252.51 6620.36 6535.36 1911.82 -830.60 5997918.87 527330.56 622.74 15.76 8591.00 87.60 252.51 6621.94 6536.94 1900.48 -866.61 5997907.39 527294.60 659.75 0.00 Phillips Alaska, Inc. WELLPATH DETAILS 3C-04A 500292141601 Parent Wellpath: Tie on MD: 3C-04 7212.00 Rig: Nordic 1 Ref. Datum: 3C-04 85.00ft V.Sectlon Origin Origin Starting Angle +NJ.S +EI-W From TVD 283.90° 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (NJE~ Reference: Well Centre: 3C-Q4, True North Vertical (TVD Reference: System: Mean Sea Level Section (VS Reference: Slot - (O.ooN,O.OOE) Measured Depth Reference: 3C-Q4 85.00 Calculation Method: Minimum Curvature 6200 - C æ6250 ~63oo - =6350 ICL G.t 6400 Q ii6450 u :e 6500 G.t ~ 6550 ~ 6600 - ANNOTATIONS ofJ'H '- 3C.(oIA~ I 000 219710 18233 p~ ~3C~'!Tf3¡3 ¡ ~I ~~ :~g ~ - ~-~ ;mg .~;~-;: ::: TVO MD Annotation 6451.55 7212,00 KOP 6536,94 8591,00 m 6050 6100 6150 ~ ¡t~ 6650 6700 6750 i I 3G-04 (3c-04)~ 6800 ('PHliups') ... m BtIL. I I ~ INTEQ T ^M é Wenpath: (3C-04/3C-04A) LEGEND - 3C-04.3C-04A.Plan 016 - - 3C-04 (3C-04) - 3c-04A Azimuths to True North Magnetic North: 25.83° Magnetic Field Strength: 57437nT Dip Angle: 80.73° Date: 4/1712002 Model: BGGM2oo0 .M' ¡1;.~~,~ ~... Created By: Brij Potnis Date: 7/10/2002 Contact Information: Direct (907) 267-6613 E-mail: tJri!,-'Ütnis@inteQæm Baker Hughes INTEG: (907) 267-6600 2400";'- :_- - -~------------------- -- ---- -------- ------~-~------~-- - ------~---~- ------ -~----- 2350..:.:--~ . - ---- ----- ------- -"- ---- -- - -- - ---.- -- ------------~-- . ~--~ ------ ------ ----~-~-- 23OO-=-m.- - - ----- -- ----~- ----- ---------- ------- --------- - ---------~._-- 2250-=-~ . m . ----_._-~--~~ ------ -- -------~-- --~-------- --- - --------------- -.-" 2200":':- - C - æ215~~ - ~2100-=-' - - -----------------~ - ------ ---~- -------. +2050~ - ~~-- -~.~- .-- . . - --- I::L~~,,~J^-ro.jy~- ..... -~~- ...- ~ .- 0 1850-=--- en ::: ------- -~--_._. ~-----~-~-- ---~-------- - -------- - ------- - ----- - --------- -- -~ 1800----:-.:-- . --~-------- --------_._---~----~-- ----~--_. . ------------- - ------------- - -.-- ----- --- 1750--.:' ---~- - -- ---------- - - ---- ------- . 1700~- ----------- -- --- ----- --- ------ 1650-:::---- - -- - --------~---_._--_._-------- - -- -----~- ------- -- - -------- -- .-- 1600--= ._----~--- ------.---~-- - --- - ---- ~-- -1050-1000 -950 -900 -850 -800 -750 -700 -650 -600 -550 -500 -450 -400 -350 -300 -250 -200 -150 -100 -50 0 50 100 150 200 250 West(-)/East(+) [50ft/in] _/ - --- - -----~-- --- - -------- - ~----------------- -- . .... --V'=J. _.=-:¡~;:"<A';"- ... - ------ -- -- - -- ---- ------------ - ----.------- --- ------ ---- -------- ---~ - - ------ --- ---- --------------- ---- --- ---- --- .- -----.----~--- - -------- ---- ~---.----_. --- -------------- - -- -------------------- - '~-----:------"'-~--------'----:-------:---7-"'---:--~---:-- - . . --------..,.----.----,--~---~--,--------,------~,- --_.--.,.---------,-T---------'-- - ---.~----------,---------,---.-- - -----.. - - -- - --------- -700 -650 -600 -550 -500 -450 -400 -350 -300 -250 -200 -150 -100 -50 0 50 100 150 200 250 300 350 400 450 500 550 600 650 700 750 800 850 900 950 1000 1050 1100 1150 1200 Vertical Section at 263.900 [50ft/in] 7/10/2002 1:Jt 1 PM ) ~~fÆ~E : ~ fÆ~fÆ~~~fÆ ) ALASIiA. OIL AND GAS CONSERVAnONCO~SSION TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99510 Re: Kuparuk River Unit 3C-04A Phillips Alaska, Inc. Permit No: 202-057 Sur Loc: 420' SNL, 1402' WEL, Sec. 14, TI2N, R09E, UM Btmhole Loc. 1231' NSL, 2970' WEL, Sec. 11, TI2N, R09E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above referenced well. This permit is being redrilled by BP Exploration (Alaska), Inc. under the coiled tubing shared services agreement with Phillips Alaska, Inc. The operator of the Kuparuk River Unit is Phillips Alaska, Inc. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. , Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit 3C-04A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, CAA"'N-'{ ()L¿R\,!.--.ly.vJd Cammy tDechsli Taylor ð Chair BY ORDER OF THE COMMISSION DATED this.@1f day of March, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Phillips Alaska, Inc. wlencl. ALASI STATE OF ALASKA 'ÞIL AND GAS CONSERVATION cor PERMIT TO DRILL 20 AAC 25.005 )SSION 'KlGt 51 ~~lrr'- fr' 3/ n-o'}. Return Approved to BP CT Drilling 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator /IlL. I}¡ I /J J )1 -sp exploration (Alaska) Inc. liJt!s /f(q.$j(~.1 .L~, 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 420' SNL, 1402' WEL, SEC. 14, T12N, R09E, UM At top of productive interval 1334' NSL, 1168' WEL, SEC. 11, T12N, R09E, UM At total depth 12311 NSL, 2970' WEL, SEC. 11, T12N, R09E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 025634,1231' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 7220' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casino Weioht Grade Couplino Lenoth 2-3/8" 4.6# L-80 STL 2151' 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 85' Kuparuk River Oil Pool 6. Property Designation ADL 025629 7. Unit or Property Name Kuparuk River Unit 8. Well Number ,( 3C-04A 9. Approximate spud date 04/07/021 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9281' MD / 6676' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 93 0 Maximum surface 3563 ~Sig, At total depth (TVD) 6300' / 4193 psig Setting Depth Top Bottom Quantitv of Cement MD TVD MD TVD (include staQe data) 7130' 64741 9281'" 66761 Uncemented Slotted Liner 11. Type Bond (See 20 AAC 25.025) Þ.' .5''1 .52. Ifð Number3E 1 0030263Qo£77 Hole 3" RFC,FiVED 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical MAR 0 5 2002 Casing Structural Conductor Surface Intermediate Production Liner 7670' feet 6864 feet 7568 feet 6791 feet Length Plugs (measured) Junk (measured) Alaska Oil & Gas Cons. Commission Anchorage Size Cemented MD TVD 183 sx Coldset 1/ 100' 100' ,1050 sx PF 'E', 380 sx PF 'C' 2445' 2445' 380 sx PF 'E', 250 sx Class 'G', 250 sx PF 'C' 7650' 6850' 100' 2445' 16" 10-3/4" 7650' 7" true vertical 7175' -7201', 7400' -7424', 7435' - 7448' 6510' - 6529', 6671' - 6688', 6696' - 6705' Perforation depth: measured II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5666 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true nd orrect to the best of my knowledge Signed Mark Johnson ~~ CJ~ , , ..' Title. CT Drilling Engineer Commi~sion Use Only 20. Attachments Date 3/1/02- Permit Number API N r 2ow? - ð S 7 50- 02 -21416-01 Conditions of Approval: Samples Required 0 Yes .l2rNo Hydrogen Sulfide Measures ~Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: \,,\Ç()~~\ ~a\?~(fttJ'Wt Original Signed By Approved By Form 10-401 Rev. 12-01-85 Cennll~ Oacll~1i Approval Date See cover letter ?~ . I L\ .. 0 ~ for other requirements Mud Log Required 0 Yes Øo Directional Survey Required ßYes 0 No D4K D5K D10K D 15t<' 0 3.5K psi for CTU Commissioner ORIGINAl by order of the commission Date 0 " Y..02 Submit In Triplicàe ) KRU 3C-04A Sidetrack - Coiled TUb"'~ Drilling Summary of Operations: Coiled tubing drilling will sidetrack KRU 3C-04 using the dynamically overbalanced coiled tubing drilling (OOCTO) technique (see description below). This horizontal sidetrack (3C-048) will target Kuparuk A sand reserves for production. 3C-04A will be a producing well. Prior to CTO arrival, service coil will abandon the existing perforations in 3C-04 (sundry form 10-403 submitted) and set a whipstock. CTD Drill and Complete 3C-04A program: Planned for April 7. 2002 1) Mill two string window through 3 %" & 7" at 7220' and mill 1 0' of openhole. / 2) Orill2.7x3" bicenter hole horizontal sidetrack 3C-048 from window to ---9281' TO targeting Kuparuk A sand interval. / 3) Complete with 23/8" slotted liner from TO to .....7130' (.....90 above window). 4) Post CTO rig - Run GLVs. Bring on production. Mud Program: . Steps 1: 10 ppg KCUNaCI biozan brine . Steps 2-3: Flo-Pro (10 ppg) Disposal: I . No annular injection on this well. . Class II liquids to KRU 1 R Pad Class II disposal well . Class II drill solids to Grind & Inject at PBU Orillsite 4 . Class I wastes will go to Pad 3 for disposal. Casing Program: . 23/8",4.6#, L-80, STL slotted liner from 7130'-9281'. / Well Control: . BOP diagram is attached. ./ . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plans for 3C-04A / . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . A Gamma Ray log will be run over all of the open hole section. . Memory resistivity logging in sections of the openhole Hazards . Two faults are expected to be crossed, one in the B sand/shale and one in the ~sand, lost circulation risk is low. Res. pressure is 12.8 ppg. WeIl3C-Q4 has a H2S reading of 136 ppm. 3C-15 has the highest H2S on the pad at 190 ppm. 3C pad is a H2S pad. All H2S monitoring equipment will be operational. Reservoir Pressure . Res. pressure is app~~t 4193 psi @ 6300ss (12.8 ppg). Max. surface pressure with gas (0.1 psi/ft) to surface is 3563 psi. (continued) MOJ 564-5666 office, 240-8034 cell 1/3 ) KRU 3c-04A Sidetrack - Coiled TUb..,~ Drilling As done in the past at KRU by CTD, dynamically overbalanced coiled tubing drilling (DOCTD) techniques will be employed to address high reservoir pressure. Plans are to use 10 ppg drilling fluid in combination with I annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique with an underbalanced mud weight requires deployment of the BHA under trapped wellhead pressure. Deployment will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attache~ BOP configuration). The annular preventer will act as a secondary containment during deployment and not as stripper. At least two times hole volume of kill weight fluid will be on location as a contingency. Once drilling is complete, the slotted production liner will be deployed into the wellbore after killing the well with kill weight fluid. MOJ 564-5666 office, 240-8034 cell 2/3 ') KRU 3c..o4A Sidetrack - Coiled TUb"{¿ Drilling Kuparuk 3C-04A Potential Drilling Hazards POST ON RIG . Please perform pre-job Hazard I D and Safety meetings prior to every change in work scope during the operation. At any stage in the operation, if things don't look right shutdown the operation and discuss the situation before making the next move. SAFETY FIRST. . Well 3C-04 H2S level is 136 ppm. The 3C pad is a designated H2S area. H2S procedures musy be followed according to the AK Safety Handbook and BP Drilling H2S SOP. Ensure H2S monitoring equipment is functional. All personnel must be supplied with required PPE and H2S certified. Influxes of reservoir fluid could result in H2S in pit area, although KRU CTD sidetracks in the past have not seen this. . 3C-04 does not have a recent static bottom hole pressure surv~ Reservoir frac gradient is -0.8 psi/ft or 15.4 EMW, 5050 psi. This sidetrack will drill from 3C-04 into an adjacent fault block that is expected to be at a hiQty;r BHP of s12.8 PPQ EMW (4193 psi at 6300' TVD). 3C-05i is an injector in the targeted fault block. 3C-05i A-sand SBHP = 4586 psi @ 6300' TVD (14 ppg EMW) in February 2002. This injector has been recently shut in. Pressure in this target fault block is expected to fall to s12.8 ppg (4193 psi at 6300' TVD) by the time the sidetrack is drilled in April 2002. The Dynamically Overbalanced Coiled Tubing Drilling (DOCTD) technique will be used. Drilling wy be done with a less than kill-weight fluid (10.0 ppg Flo-Pro). While drilling and circulating at 1.5 BPM the 10 ppg mud, 930 psi of ann~lar friction, and 200 psi choked backpressure held on the return side will provide a 4400 psi BHP and overbalance the reservoir by -200 psi. However, when circulation is shut down, the reservoir could be underbalanced by -917 psi. Maintain at least 1100 psi WHP when not circulating to prevent reservoir in-flux and maintain formation stability close to / circulating pressures seen during drilling. Adjust SIWHP accordingly when BHP increases are seen on the downhole PWD sub. Increases will occur from higher-than-expected friction pressures and/or reservoir pressures. Refer to the PWD BHP vs Depth chart to determine if deviations occur. Monitor return-line flow rate and pit volume continuously. If crude enters the circulating system, divert those returns to an outside tank. . . Maximum anticipated WHP w/ full column of gas: -3563 psi assuming 0.1 psi/ft gas gradient. . No gas saturated intervals are expected. However, be prepared for the potential for gas influx since the target fault block has received MI injection in the past. Ensure all PVT equipment is fully operational and monitor return-line flow rate and pit volume continuously. MOJ 564-5666 office, 240-8034 cell 3/3 ) 11) Tally Length Depth ELM Baker FHL 7.15' 7046' Packer 1 jt 3-1/2" tbg 31.07' 7053' I 3 1/2" 9.3# tubing I Cameo GLM 20.1' 7084' wI pups 17" 26# Casing I 2 jts 3-1/2" 62.63' 7104' tbg 3-1/2" Blast 31.4' Joint 7029' X 7036' >< 3C-04 P&A Schematic detail & proposed 3C-04A Sidetrack > 7067' GLM J (t,',.:...,.:....:,.:..:,:,"...,.:..:,. _Target TOC near GLM at 7067' ELM . ;t--I:::,',..',.".:,.,.:..,.,.:',..."..,.,: Top of 2 3/8" sidetrack liner at -7130' . 0 ~~ 3112" tubing x 7" casing annulus 0:><: ' filled with 17 ppg cement from 0 ,,' ',: tubing tail plug to near GLM 0 at 7067' 0 7167' 7150' 3-1/2" Blast 30.7' Joint C sand perforations 7175' - 7201' ELM 7198' 7181' Whipstock at -7220' ELM / 3-1/2" Pup Jt 20.3' 7229' 7212' EZSV cement retainer at 7230' ELM Baker CMU 3.82' 7249' 7232' / ODD 3-1/2" Pup Jt 6.11 7253' 7236' / 3-1/2" x 2-7/8" XO 1.82' 7259' 724Z.~ Baker Locator sub 1.0' 7261' 7244' Baker 0 B Packer 3.65' 7262' 7245' Baker SBE 4.35' 7266' 7249' Baker XO 0.65' 7270' 7253' 2-7/8" Pup Jt 8.11' 7271' 7254' Otis XN Nipple 1.10' 7279' 7262' 2-7/8" Pup Jt 4.06' 7280' 7263' 2-7/8" Tail 7285' 7268' MOJ 2f27102 564-5666 office 240-8034 cell ~"'\ l ¡~ '...../ '" 0 <:::::~~ ~~. j~~ ~ ~ ~O~ 'ž Circulation holes 7238-7240' ELM Tubing tail plug set at 7262' ELM Proposed 3C-04A Sidetrack 2 3/8" 4.6# STL L-80 pre-drilled liner /' 00000 .. -' d t~ / :2: A-sand Perforations :S ~ 7400' - 7448' ELM 5 - .- -- - -- - - 00000 ~ ... 7" 26# Shoe @ 7670' 3" openhole TD at -9281' MD ~ PHILLIPS Ala~ka Inc. ~, A SUbsìdl~ry or PHILLIPS PETROLEUM COMPAN'Y ~ [ :: ' .:,::: ; f3C-Ð4 NIP 6~~~~~~cii ~I' I':,: :.':,::,'~.TJ:,:,¡:::'.:,',::',~:,:.':::,::,::, I"~ ~': . sssv T::' ~~~~'4~- 0;;9 c,;;,a~ ~~ --~---~: ;r~:- :: :: : ~~~~ ~ ; ~ Annular Fluid: Last W/O: 12/22/95 Rev Reason: Close Production .:¡¡1J.c;;~~g:'~~1JUNGS ~:::AJ: ~~".o~.'00 ~Upd~, ~~;~~'by'mo Description Size CONDUCTOR 16.000 SURFACE 10.750 PRODUCTION 7.000 Tubing $tring .. tOeiNG I Size I Top 3.500 0 , Perforations Summary Interval TVD Zone 7175 -7201 6510 - 6529 C-1,UNIT B 7400 - 7404 6671 - 6674 A-4 7404 - 7424 6674 - 6688 A-3 7435 -7448 6696 - 6705 A-2 'Gas UftMandrelslValves , : St MD TVD Man Man Mfr Type 1 2992 2992 Camco MMM 2 4900 4848 Camco MMM 3'- 6208 5816 Cameo MMM 4 6605 6100 Cameo MMM 5 6814 6250 Cameo MMM 6 6960 6355 Cameo MMM , Production MandrelsIValves I' St MD TVD Man Man Mfr Type î " ¡ ~h 7rf 6436 ¡ameo ) ~~~LRY r ".. ":~i ~ Dep~h p .;i;' ~~eetc. . Description ¡ ¡ 500 500 NIP Cameo 'OS' Landing NO GO 7014 6394 PBR Baker 7028 6404 PKR Baker 'FHL' ./ 7231 6550 SLEEVE Baker 'CMU' Sliding Sleeve; 10/15/00 - OPENED SLEEVE. 7245 6560 PKR Basker 'DB' 7262 6572 NIP Otis 'XN' Nipple 7267 6576 SOS Baker 7268 6577 TTL Gas Lift MandrelNalve 1 (2992-2993, 00:6.018) Gas Lift MandrelNalve 2 (4900-4901, 00:6.018) Gas Lift MandrelNalve 3 (6208-6209, OD:6,018) Gas Uft MandrelNalve 6 (6960-6961, 00:6.018) PBR (7014-7015, 00:3,500) PKR (7028-7029, 00:6,151) Perf (7175-7201) SLEEVE (7231-7232, OD:4,500) PKR (7245-7246, 00:6,151) NIP (7262-7263, OD:3,500) TUBING (0-7268, 00:3.500, ID:2.992) Perf (7400-7424) Perf (7404-7424) Perf (7435-7448) j!i ~ ! ::::~ f ~Jrj;firn , , ( ~ ~ ~ ~ ¡ ~ ... ¡ ~ ~ ~ ~ ~ j 1 t-I ~ ¡ i c ~ ~ r . ¡ ~ t== ~ ! LL! =f i= -do: :t= ::l J:: ~ += ---t -r- 4 t~~ =t t kRU 3C-04 Bottom 7268 Top Bottom TVD Wt Grade Thread 0 100 100 62.50 H-40 /' 0 2445 2445 45.50 K-55 0 7650 6850 26.00 J-5S TVD Wt I Grade I Thread / 6577 9.30 L-80 EUE 8RD MOD Status Ft SPF Date Type Comment 26 12 10/3/85 IPERF 5" Csg gun; 120 deg ph 4 4 10/3/85 IPERF 4" Csg gun; 90 deg ph 20 8 8/6/96 RPERF 2-1/8" EJ; 180 deg ph +/- 90 deg f/lowside 13 4 10/3/85 IPERF :4:' (;sg ~ul'1, V Mfr V Type V OD Latch Port TRO Date Run 1303 8/28/96 1295 12/27/96 1336 8/28/96 0 12/22/95 0 12/22/95 0 12/27/96 Vlv Cmnt GLV 1.0 RK 0.188 GLV 1.0 RK 0.188 GLV 1.0 RK 0.188 DMY 1.0 RK 0.000 DMY 1.0 RK 0.000 OV 1.0 RK 0.188 V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt ...1.á.__-B.K 0.000 -~ 12/22/95 Closed DMY ID 2.812 3.000 3.000 2.750 3.250 2.250 2.992 2.992 ~ +- a.> a.> - '-/ ..r:: +- 0.. a.> 0 0 () 6600 - +- L- a.> > a.> ::J L- l- I v /PHilliPS ~ rÐ Phillips Inc. Alaska, Structure: Pad 3C Field: Kuparuk River Unit Well: 4 Location: North Slope, Alaska <- West (feet) 1800 1500 1300 1100 500 200 400 300 1000 900 800 700 600 1700 1600 1400 1200 3C-D4A T1 ~ ---------- 0 3C-04A T2 Rsvd 11-Feb-02 6300 - T.O. & End of Turn - 6676.05 Tvd. 1652.36 N, 1569.92 W r&íí8 BAKER HUGHES INTEQ ~,-I' 100 0 100 200 300 400 2300 \ - 2200 ~ - 2100 '-'" - 2000 ^ - 1900 I Z - 1800 0 , -+ :r r--o.. - 1700 --h <D <t> -+ '-/ - 1 600 -1500 -1400 '~ Kick Off Point Tie on - 6456.20 Tvd, 1753.20 N, 232.37 E 3C-04A 13 Rsvd 11 -Feb-02 6400 - Tie on - 44.03 Inc, 7100.00 Md, 6456.20 Tvd, -417.35 Vs 6500 - Kick Off Point 3C-04A T1 Rsvd 12-Feb-02 3C-04A T2 Rsvd 11-Feb-02 6700 - 8 -1300 3C-04A 13 Rsvd 11-Feb-02 T.O. & End of Turn - 93.00 Inc, 9280.78 Md, 6676.05 Tvd, 1385.45 Vs 6800 - 6900 600 300 400 500 600 700 800 900 1000 100 0 100 200 300 200 500 400 Vertical Section (feet) -> Azimuth 263.90 with reference 0.00 N, 0.00 E from slot #4 1100 1200 1300 1400 1500 1600 ) ) Phillips Alaska, Inc. Pad 3C 4 slot #4 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 3C-04A Version #2 Lowside Our ref: prop5113 License: Date printed: 26-Feb-2002 Date created: 21-Feb.2002 Last revised: 21-Feb.2002 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 24 4.812,w149 45 33.625 Slot location is n70 24 0.680,w149 46 14.698 Slot Grid coordinates are N 5996010.380, E 528168.280 Slot local coordinates are 420.00 S 1402.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North » Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad3C.4 Your ref: 3C-04A Version #2 Lowside Kuparuk River Unit. North Slope. Alaska Last revised: 21-Feb-2002 Measured Inclin Azimuth True Vert R E C TAN G U L A R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect Easting Northing 7100 .00 44.03 4.93 6456.20 1753.20N 232.37E 0.00 -417.35 528393.69 5997764.31 7125.00 44.09 4.78 6474.16 1770.52N 233.84E 0.49 -420.66 528395.09 5997781.64 7150 .00 44.16 41.63 6492.11 1787.87N 235.27E 0.49 -423.92 528396.45 5997798.99 7175.00 44.22 4.47 6510.03 1805.24N 236.65E 0.49 -427.14 528397.76 5997816.36 7200.00 44.28 4.32 6527.94 1822.63N 237.99E 0.49 -430.32 528399.03 5997833.76 7225.00 44.29 4.12 6545.84 1840.04N 239.27E 0.56 - 433.45 528400.24 5997851.17 7237.00 44.29 4.02 6554.43 1848.40N 239.87E 0 . 56 /" 434 . 93 528400.81 5997859.53 7242.00 41. 83 3.37 6558.08 1851.81N 240.09E 50.00 -435.51 528401. 01 5997862.94 7250.00 41. 83 3.37 6564.04 1857.13N 240.40E 0.00 -436.38 528401.31 5997868.26 7252.00 41. 83 3.37 6565.53 1858.46N 240.48E 0.00 .436.60 528401.38 5997869.60 7275.00 42.18 354.78 6582.64 1873.82N 240.23E 25.04 -437.99 528401. 07 5997884.95 7300.00 43.28 345.69 6601. 02 1890.50N 237.34E .£5.04 -436.89 528398. 11 5997901.62 7325.00 45.06 337.07 6618.97 1906.97N 231.77E 25.04 -433.10 528392.48 5997918.06 7350.00 47.44 329.05 6636.27 1923.03N 223.58E 25.04 -426.66 528384.22 5997934.09 7375.00 50.35 321.68 6652.72 1938.49N 212.86E 25.04 -417.65 528373.45 5997949.51 7400.00 53.67 314.95 6668 . 11 1953.17N 199.76E 25.04 -406.18 528360.29 5997964. 13 7425.00 57.34 308.79 6682.28 1966.90N 184.41E 25.04 -392.38 528344.89 5997977.79 7450.00 61.29 303.14 6695.04 1979.49N 167.01E 25.04 -376.41 528327.44 5997990.32 7475.00 65.46 297.91 6706.25 1990.82N 147.76E 25.04 - 358.48 528308.15 5998001.57 7500.00 69.79 293.02 6715.76 2000.74N 126.90E 25.04 -338.79 528287.25 5998011.41 7525.00 74.26 288.41 6723.48 2009.14N 104.66E 25.04 -317.57 528264.98 5998019.72 7550.00 78.81 283.99 6729.30 2015.91N 81.33E 25.04 -295.08 528241.62 5998026.39 7575.00 83.43 279.71 6733.16 2020.97N 57.16E 25.04 -271:60 528217.44 5998031.36 7600.00 88.08 275.51 6735.02 2024.27N 32.46E 25.04 -247.39 528192.73 5998034.56 7621.00 92.00 272.00 6735.00 2025.64N 11. 52E 25.04 .226.70 528171.78 5998035.85 7625.00 91.99 271.60 6734.86 2025.77N 7.52E 10.00 -222.74 528167.78 5998035.96 7650.00 91.93 269.10 6734.01 2025.92N 17 .46W 10.00 -197.92 528142.80 5998036.02 7675.00 91.87 266.60 6733.18 2024.98N 42.43W 10.00 -172.99 528117.84 5998034.98 7700.00 91. 80 264.10 6732.38 2022.96N 67.33W 10.00 -148.02 528092.95 5998032.85 7725.00 91.73 261.60 6731. 61 2019.85N 92.12W 10.00 -123.03 528068.17 5998029.65 7750.00 91.66 259.10 6730.87 2015.66N 116. 76W 10.00 -98.10 528043.56 5998025.36 7775.00 91.58 256.60 6730.16 2010.40N 141.19W 10.00 -73.25 528019.15 5998020.00 7800.00 91.50 254.10 6729.49 2004.08N 165.36W 10.00 -48.54 527995.01 5998013.59 7825.00 91.42 251.60 6728.85 1996.71N 189.24W 10.00 -24.01 527971.16 5998006.12 7850.00 91.33 249.10 6728.25 1988.30N 212.78W 10.00 0.29 527947.66 5997997.63 7875.00 91.24 246.60 6727.69 1978.88N 235.92W 10.00 24.30 527924.55 5997988.11 7900.00 91.15 244.10 6727.17 1968.46N 258.64W 10.00 48.00 527901.88 5997977 . 6'0 7925.00 91.06 241.60 6726.69 1957.05N 280.88W 10.00 71.32 527879.69 5997966.11 7941.04 91.00 240.00 6726.40 1949.23N 294.88W 10.00 86.07 527865.72 5997958.23 7950.00 90.98 240.90 6726.24 1944.81N 302.67W 10.00 94.29 527857.95 5997953.78 7975.00 90.91 243.40 6725.83 1933.13N 324.77W 10.00 117.51 527835.90 5997942.02 8000.00 90.85 245.89 6725.45 1922.43N 347.36W 10.00 141.11 527813.35 5997931.23 8025.00 90.78 248.39 6725.09 1912.72N 370.39W 10.00 165.04 527790.36 5997921.43 8050.00 90.71 250.89 6724.76 1904.03N 393.82W 10.00 189.27 527766.96 5997912.64 8075.00 90.64 253.39 6724.47 1896.36N 417.62W 10.00 213.74 527743.20 5997904.89 8100.00 90.57 255.89 6724.20 1889.74N 441.72W 10.00 238.41 527719.13 5997898.17 8125.00 90.50 258.39 6723.97 1884.18N 466.09W 10.00 263.23 527694.78 5997892.51 8150.00 90.43 260.89 6723.77 1879.68N 490.68W 10.00 288.16 527670.21 5997887.92 8175.00 90.35 263.39 6723.60 1876.26N 515.44W 10.00 313.15 527645.47 5997884.40 8200.00 90.28 265.89 6723.46 1873.93N 540.33W 10.00 338.14 527620.59 5997881.97 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #4 and TVD from wellhead (85.00 Ft above mean sea level). Bottom hole distance is 2279.24 on azimuth 316.47 degrees from wellhead. Total Dogleg for wellpath is 261.58 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 263.90 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid ) Presented by Baker Hughes INTEQ :~ Phillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 3C,4 Your ref: 3C-04A Version #2 Lowside Kuparuk River Unit, North Slope, Alaska Last revised: 21-Feb-2002 Measured Inclin Azimuth True Vert R E C TAN G U L A R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect Easting Northing 8225.00 90.20 268.39 6723.36 1872.68N 565.30W 10.00 363.10 527595.63 5997880.62 8250.00 90.13 270.89 6723.29 1872.52N 590.30W 10.00 387.97 527570.64 5997880.36 8275.00 90.05 273.38 6723.25 1873.45N 615.28W 10.00 412.71 527545.66 5997881.20 8291.16 90.00 275.00 6723.24 1874.63N 631.40W 10.00 428.62 527529.53 5997882.31 8300.00 90.11 274.12 6723.24 1875.34N 640.20W 10.00 437.30 527520.72 5997882.98 8325.00 90.42 271.64 6723.12 1876.59N 665.17W 10.00 461.99 527495.76 5997884.14 8350.00 90.72 269.16 6722.87 1876. 77N 690.17W 10.00 486.83 527470.76 5997884.22 8375.00 91.03 266.68 6722.49 1875.86N 715.15W 10.00 511.76 527445.79 5997883.21 8400.00 91.33 264.20 6721. 98 1873.87N 740.06W 10.00 536.74 527420.89 5997881.12 8425.00 91.63 261.71 6721.33 1870.81N 764.86W 10.00 561.73 527396.10 5997877.96 8450.00 91.93 259.23 6720.55 1866.67N 789.50W 10.00 586.67 527371.48 5997873.73 8475.00 92.22 256.75 6719.65 1861.47N 813.94W 10.00 611.52 527347.07 5997868.44 8500.00 92.51 254.26 6718.61 1855.22N 838.12W 10.00 636.23 527322.91 5997862.09 8525.00 92.80 251.78 6717.45 1847.93N 862.00W 10.00 660.75 527299.06 5997854.70 8542.84 93.00 250.00 6716.55 1842. ION 878.84W 10.00 678.11 527282.25 5997848.80 8550.00 93.01 250.72 6716.17 1839.69N 885.57W 10.00 685.06 527275.53 5997846.37 8575.00 93.03 253.22 6714.86 1831.97N 909.31W 10.00 709.49 527251.82 5997838.55 8600.00 93.05 255.72 6713.53 1825.28N 933.36W 10.00 734. 11 527227.80 5997831.77 8625.00 93.06 258.23 6712.20 1819.66N 957.68W 10.00 758.89 527203.51 5997826.05 8650.00 93.07 260.73 6710.86 1815.10N 982.22W 10.00 783.78 527178.98 5997821.40 8675.00 93.07 263.23 6709.52 1811.62N 1006.94W 10.00 808.73 527154.28 5997817.82 8700.00 93.07 265.74 6708.18 1809.22N 1031.78W 10.00 833.69 527129.45 5997815.32 8725.00 93.06 268.24 6706.84 1807.91N 1056.71W 10.00 858.61 527104.53 5997813.91 8750.00 93.04 270.74 6705.51 1807.69N 1081.67W 10.00 883.46 527079.57 5997813.59 8775. 00 93.02 273.25 6704.19 1808.56N 1106. 62W 10.00 908.17 527054.62 5997814.36 8792.49 93.00 275.00 6703.27 1809.81N 1124. 05W 10.00 925.36 527037.19 5997815.55 8800.00 93.02 274.25 6702.88 1810.42N 1131.52W 10.00 932.73 527029.72 5997816.13 8825.00 93.07 271.75 6701. 55 1811. 72N 1156. 45W 10.00 957.38 527004.79 5997817.33 8850.00 93.12 269.24 6700.20 1811.94N 1181.41W 10.00 982.17 526979.83 5997817.45 8875.00 93.16 266.74 6698.83 1811.06N 1206.35W 10.00 1007.07 526954.89 5997816.48 8900.00 93.20 264.24 6697.44 1809.10N 1231.23W 10.00 1032.02 526930.02 5997814.41 8925.00 93.23 261.73 6696.04 1806.05N 1256.00W 10.00 1056.98 526905.26 5997811.27 8950.00 93.26 259.23 6694.62 1801.92N 1280.62W 10.00 1081.89 526880.67 5997807.04 8975.00 93.28 256.72 6693.20 1796.72N 1305.03W 10.00 1106.71 526856.28 5997801.75 9000~00 93.29 254.22 6691.77 1790.46N 1329.19W 10.00 1131. 40 526832.15 5997795.39 9025.00 93.29 251.72 6690.33 1783.15N 1353.05W 10.00 1155.90 526808.32 5997787.99 9050.00 93.29 249.21 6688.89 1774.81N 1376.57W 10.00 1180 . 18 526784.83 5997779.55 9075.00 93.29 246 . 71 6687.46 1765.44N 1399.70W 10.00 1204.17 526761.74 5997770.09 9100.00 93.27 244.20 6686.03 1755.07N 1422.40W 10.00 1227.85 526739.08 5997759.64 9125.00 93.26 241.70 6684.60 1743.72N 1444.63W 10.00 1251.16 526716.90 5997748.20 9150.00 93.23 239.20 6683.19 1731.41N 1466.34W 10.00 1274.05 526695.24 5997735.81 9175.00 93.20 236.69 6681.79 1718.17N 1487.50W 10.00 1296.49 526674.14 5997722.48 9200.00 93.16 234.19 6680.40 1704.01N 1508.05W 10.00 1318.44 526653.65 5997708.24 9225.00 93.12 231.68 6679.03 1688.97N 1527.97W 10.00 1339.84 526633.79 5997693.12 9250.00 93.07 229.18 6677.68 1673.07N 1547.21W 10.00 1360.66 526614.61 5997677.14 9275.00 93.01 226.68 6676.35 1656.34N 1565.74W 10.00 1380.87 526596.15 5997660.35 9280. 78 93.00 226.10 6676.05 1652.36N 1569.92W 10.00 1385.45 526591.99 5997656.35 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #4 and TVD from wellhead C85.00 Ft above mean sea level). Bottom hole distance is 2279.24 on azimuth 316.47 degrees from wellhead. Total Dogleg for wellpath is 261.58 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 263.90 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 3C,4 Kuparuk River Unit,North Slope, Alaska Comments in well path -------------------- -------------------- MD TVD Rectangular Coords. Comment ..........-..-........ --.... ---...... --........ --............ .....---................ ......oo -..- ...... -- ---...... -- -.............. --- ............... --- ----...............-........... 7237.00 6554.43 1848.40N 239.87E Kick Off Point :~ PROPOSAL LISTING Page 3 Your ref: 3C-04A Version #2 Lowside Last revised: 21-Feb-2002 Target name Geographic Location T.V.D. Targets associated with this wellpath ---------- Rectangular Coordinates Revised -------- ..-..oo..- -............... -- ........... ..-- --....-..............- .............. ---................ --- -- --...... ......--..-.. ..-.... --.. -........ ---.... ..-........-.... ---- ........ 3C-04A Tl Rsvd 12-Fe 527816.000,5997971.000,-2.000 6710.00 3C-04A T2 Rsvd II-Fe 527399.000,5997849.000,2.0000 6709.00 3C-04A T3 Rsvd II-Fe 526592.000,5997660.000,0.0000 6666.00 1962.19N 1841.83N 1656.01N 344.55W 12-Feb-2002 762.07W 12-Feb-2002 1569.90W 12-Feb-2002 Vrt Ref: wellhead Hrz Ref: slot #4 North on true Units: feet M+D+ [f] Inc+ Dir+ TVD [f] N/S [f] E/W [f] Polar crd+[f] Curv+ Tf DLS I 100 Ft ~ [5113] 3C-04A Version #2 Lowsi ~ [2034] PGMS <0-7670F) . . 1:fjG1:IP..DJ ~ ~ ------------- ----- -60 .. : J . 6527+94 N 1822+63 E 237+99 ------------- 0+49 -87 . . J 6554+43 N 1848+40 E 239+87 ------------- 0+56 II J . t 41 + 83 3 + 370 6558 + 08 N 1851 + 81 E 240 + 09 ------------- II. t' 41+83 3+370 6565+53 N 1858+46 E 240+48 ------------- -89 7621+00 ~ .. ~ N 2025+64 E 11+52 ------------- 25+0 -91 7941+04 . . ... 6726+40 N 1949+23 W 294+88 ------------- 91 8291+16 . .. 6723+24 N 1874+63 W 631+40 ------------- . -82 8542+84 .. . .. 6716+55 N 1842+10 W 878+84 ------------- .. 89 8792+49 ~.. ... 6703+27 N 1809+81 W 1124+05 ------------- . -88 9280+78 . . .. 6676+05 N 1652+36 W 1569+92 ------------- . ---- ~ ----- ------- -------- ---------- ---------- ------------- ----- ---- -------- ----- ------- -------- ---------- ---------- ------------- ----- ---- iDR Plan Options i!R Delete field i§g Insert station ;mg Delete station 10: t -417+35 Tie -430+32 EoB/EoLT -434+93 EoB/EoLT -435+51 EoD/EoLT -436+60 EoIH/EoDH -226+70 EoB/EoLT 86+07 EoD/EoLT 428+62 EoD/EoRT 678+11. EoB/EoLT 925+36 EoIH/EoRT 1385+45 EoIH/EoLT _.' -------- --------------------- -------- --------------------- () f t!~(. ,,'q,.A@ I ---~ --- I 0 llF ~ a ) ,- j,t~! J-#~~ SQ( þ¿,S 5 o~ /1 D crt~ß-~- t.T }-v~f ~ ¡oj lJ "Y\ß';'!DL5. ð\ F'.~ n ~£~.~ ~ ..-í1° rr e. t~ ~ p¿;; t-'~~ -~~_? ') ') Nordic CrD BOP Detail /u I~I I I ~ Methanol Injection ~ Otis 7" WLA Quick II Connect - I ~ '-..1 I~ I 1 t==C ~' II ~ I Blind/Shear I / rc= tQ\ I 2" Combi Pipe/Slip I Flanged Fire Resistant '\~) Kelly Hose to Dual HeR fnì I ' I Fire resistant Kelly Hose Choke Manifold [0JJill. ~IT~:aJve / 7-1/16" 10, 5000 psi working pressure I 2"Side l =:I I Ram Type Dual Gate I I~ ~ O~utlets F 2 3/8" Combi Pipe/Slip BOPE TOT ~ = I Manual over Hydraulic c:: I @ I 2" Combi Pipe/Slip 11 xo Spool as necessary \ / 2 fl d t ange ga e valves I I Tree or Double ~ Manual Master Valves \~ , I @) I I II THA I L ~-?(y--- ~ 7" Annulus Tubing ~J. í Spool =, I I - @- ~ 9 518" Annulus 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic TOT MOJ 01/23/01 o~ -- CT Injector '\> I Head Stuttlng Box (Pack-Off), 10,000 psi Working Pressure -- ~ - 7" Riser ,'I I , Annular BOP (Hydril),7-1/16" ID / 5000 psi working pressure 1/ 1/ ) ) 205535 DATE 02/1~/O2 CHECK NO. OO¿O5~35 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS 100. 00 VENDOR DISCOUNT ALASKADILA NET 00 21302 CK021302D PYMT COMMENTS: HANDLING INST: Pernit to Drill 7ee S/H - Sandra Stellman X4750 100. 00 H RECE\\fED flf¡ f\ r. 0, r, 2()nÎ \1 IH ro{ / .'.; ,,' './.. ~e,o.'-tA Alaska Oil & Gas Coos commission Ällchoraqe ,TTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL .... 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H2O 5 5 3 5 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 4J2 00205535 AY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 02/15/02 AMOUNT $100_00 0 The RDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 \2.~J {!;/1,ft\U~ II. 2 0 5 5 j 5 II. I: 0 L. ~ 2 0 j 8 g 5 I: 0 0 8 L. L. ~ g II. ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 ST ANDARD LETTER DEVELOPMENT ~ DEVELOPMENT REDRILL 0 EXPLORATION INJECTION WELL INJECTION WELL RED RILL WELL NAME /{f,q CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) PILOT HOLE (PH) ANNUL¿~POSAL NO ANNULAR DISPOSAL <.--> YES ANNULAR DISPOSAL THIS WELL' 3C -0 Gj,A "CLUE" The permit is for a Dew wellbore segment of existing well -----.3 Permit No, ,API No. . " Production should conÌinue to be reported as a function of the original API number stated above. ' In accordance with 20 AAC 25.005(t), aU records, data and logs acquired for' the pilot hole mu'st be clearly , differentiated in both name (name on permit plus PH) and API number (SO -70/80) from records, data and logs acquired for well (n~me on permit). , Annular disposal bas ~ot been requested. . . Annular Disposal, of drilling wastes will not be approved. .. Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated. '. . ANNULUS L-J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is tbe approved application for permit to drill the above referenced well. The permit is approved. sùbJect to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY /j//lt);..s WELL NAME ¡(It¡ 3C-07'A FIELD & POOL </70 / cJc-J INIT CLASS IJ€.V J-ð'l ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ,ý).N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . V N 6. Well located proper distance from other wells.. . . . . . . . . V N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . V N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . V N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . V N 11. Permit can be issued without conservation order. . . . . . . . V I N 12. Permit ca~ be issued without administrativ~ approval.. . . . . I V N 13. Can permit be approved before 15-day walt.. . . . . . . . . . 'V N 14. Conductor string provided.. . . . . . . . . . . . . . . . . . -¥---W-- ~ 15. Surface casing protects all known USDWs. . . . . . . . . . . ¥---N-> N fA- 16. CMT vol adequate to circulate on conductor & surf csg. . . . . -¥-N- 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . .-V--N -, .L; 18. CMT will cover all known productive horizons. . . . . . . . . . ¥:-N- Sf pn:-<J í ¡ ~v 19. Casing designs adequate for C, T, B & porm3froot: . . . . . . 6¡) N . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ~ N '-T þu . 21. Ifare-drill, has a 10-403 for abandonment been approved. . .N ApPW\(Rd "S/ì.P107.... 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . ~ Ai/A- 24. Drilling fluid program schematic & equip list adequate. . . . . ~ N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . iN 26. Bo.PE press rating appropriate; test to 4S00 psig. ., N M> P -=.~"3 p <.-t \ . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N 30. Permit can be issued w/o hydrogen sulfide measures. . . . . XV N 31. Da~a ~resented. on potential overpressure zones. . . . . . . Y /I) L) 32. Seismic analysIs of shallow gas zones. . . . . . . . . . . . . N / L/, '7 oJ A~R ~~~7 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N /Vê.. -1/ ;PðZ 34. Contact name/phone for weekly progress reports [exploratory y] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will npt contaminate freshwater; or cause drilling waste. ., to surface; (C) will not impair mechanical integrity of the well used for disposal; V N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. V N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~ TEM M-~3/tr'D-:>- COT SFD- WGA vJGPr DTSð3j J2-!ð L JMH .Jrv\H- 3fr2./Ó2- A~RR D~J~ 1(/'/ 1/1"°J ENGINEERING APPR. DATE ~61t- ;1111ot.. /f17n?~AtO~ GEOLOGY APPR DATE PROGRAM: Exp - Dev X Redrll2( Serv - Wellbore seg - Ann. disposal para req - GEOL AREA ?<j/'} UNIT# ///? d ON/OFF SHORE o.,() ¿)e'JP/rtfA-V! /I Je/ r--,-).,-/ 4i!f r,.,J/o1 ,.",,} _-v ~) /----/ ( ,( ~ ~ f\k Cw.-I-L,^-lcv ~ SfD~J reOuo!.bJ. Comments/Instructions: G:\geology\templates\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. . To improve the readabiHty of the Well History file and to simplify finding information, infonnation of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. &C)~.-'C6T ,) **** REEL HEADER **** MWD 03/03/29 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/04/28 292896 01 2 3/8" CoilTrak *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 7200.0000: STOP.FT 8591.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- Remark File Version 1.000 Extract File: ldwg.las 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value Phillips Alaska, INC 3C-04A Kuparuk River Unit 70 deg 24' 0.626"N 149 deg 46' 14.649"W North Slope Alaska Baker Hughes INTEQ 2.375 Coil Trak 28-April-02 500292141601 ------------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . -Remarks \::< ~ ",~ \"vi\ ,'~ 14 12N 09E MSL 0 KB 85.0 KB 85.0 N/A N/A N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services LiRECEIVED JUL 29 2003 Alaska o¡.¡ 8. Gas CCHS. Commission AI1chor8ge ) ) (1) (2 ) (3 ) ( 4) (5 ) All depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data presented is realtime data. Well 3C-04A was kicked off at 7212' MD (6451' SSTVD) and was drilled to TD at 8591' MD ( 6537' SSTVD) on Run 9. Baker Hughes Inteq utilized CoilTrak downhole tools and the Advantage surface system. The data presented here is final. Per PAI Geoscience standing order, no depth shifting has been done as this MWD GR is the depth reference for this well. Gamma ray detector type is a scintillator. The interval from 8567' MD (6536' SSTVD) to 8591' MD (6537' SSTVD) was not logged due to sensor to bit offset. (6 ) (7 ) (8 ) MNEMONICS: GRCX -> Gamma Ray MWD-API [MWD] (MWÐ-API units) ROPS -> Rate of Penetration, feet/hour TVD -> True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASUR N/A, N/A Tape Subfile: 1 DISPLACEMENT N/A 61 records... Minimum record length: Maximum record length: 14 bytes 132 bytes MWÐ **** FILE HEADER **** .001 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT md.xtf 150 Phillips Alaska, Inc. 3C-04A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !! !!!!!! !!!!! !! !!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has not been depth shifted to a PDC as ,per instructions from PAI Geoscience standing order. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR ROP ---------------------------------------------------- GR ROP GR1CX GROPA 0.0 0.0 ) * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 API F/HR 4 4 4 4 ------- 8 Total Data Records: 66 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 7200.000000 8591.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 2 75 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT md.xtf 150 Phillips Alaska, Inc. 3C-04A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** ) ) !!!! !!!!!! !!! !!! !!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRCX ROPS GRCX ROPS GRICX GROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRCX MWD ROPS MWD 68 68 1 1 API F/HR 4 4 4 4 ------- 8 Total Data Records: 66 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 7200.000000 8591.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 3 75 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/04/28 292896 01 ) **** REEL TRAILER **** MWD 03/03/29 BHI 01 Tape Subtile: 4 Minimum record length: Maximum record length: Tape Subtile 1 is type: LIS ) 2 records... 132 bytes 132 bytes ) Tape Subfile 2 is type: LIS DEPTH 7212.7500 7213.0000 7250.0000 7300.0000 7350.0000 7400.0000 7450.0000 7500.0000 7550.0000 7600.0000 7650.0000 7700.0000 7750.0000 7800.0000 7850.0000 7900.0000 7950.0000 8000.0000 8050.0000 8100.0000 8150.0000 8200.0000 8250.0000 8300.0000 8350.0000 8400.0000 8450.0000 8500.0000 8550.0000 8590.0000 GR 42.4848 53.8197 79.6102 81.3158 96.7426 114.8146 39.7770 34.8272 87.5511 84.6811 89.5899 60.0880 92.4431 34.3950 43.2858 79.3644 37.2949 49.8008 48.4834 36.7795 50.3159 41.7209 69.2708 74.8332 35.9565 56.5407 62.2027 58.3828 61. 7540 -999.2500 ,) ROP -999.2500 -999.2500 32.4200 29.2400 4.8000 7.8286 73.1400 5.9913 52.6800 8.6583 25.1600 83.7200 47.8000 45.5284 26.4000 53.9800 45.4400 51. 0000 68.5000 106.8000 12.8896 170.6500 77.3000 73.3800 7.4700 50.2800 53.7600 56.1800 39.4400 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 7212.750000 8590.000000 0.250000 ) Tape Subfile 3 is type: LIS DEPTH 7212.7500 7213.0000 7250.0000 7300.0000 7350.0000 7400.0000 7450.0000 7500.0000 7550.0000 7600.0000 7650.0000 7700.0000 7750.0000 7800.0000 7850.0000 7900.0000 7950.0000 8000.0000 8050.0000 8100.0000 8150.0000 8200.0000 8250.0000 8300.0000 8350.0000 8400.0000 8450.0000 8500.0000 8550.0000 8590.0000 GRCX 42.4848 53.8197 79.6102 81.3158 96.7426 114.8146 39.7770 34.8272 87.5511 84.6811 89.5899 60.0880 92.4431 34.3950 43.2858 79.3644 37.2949 49.8008 48.4834 36.7795 50.3159 41. 7209 69.2708 74.8332 35.9565 56.5407 62.2027 58.3828 61. 7540 -999.2500 ) ROPS -999.2500 -999.2500 32.4200 29.2400 4.8000 7.8286 73.1400 5.9913 52.6800 8.6583 25.1600 83.7200 47.8000 45.5284 26.4000 53.9800 45.4400 51.0000 68.5000 106.8000 12.8896 170.6500 77.3000 73.3800 7.4700 50.2800 53.7600 56.1800 39.4400 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 7212.750000 8590.000000 0.250000 ) ) Tape Subfile 4 is type: LIS