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Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincere Roger Winter ConocoPhillips Well Integrity Field Supervisor I • • 4110 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 6/29/2016 2T&2Z Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2T-39 50103203920000 2011830 9" NA 9" NA 3.8 6/23/2016 2Z-02 50029209600000 1830800 12" NA 12" NA 6 6/22/2016 2Z-03 50029209640000 1830850 10" NA 10" NA 3.5 6/22/2016 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing P Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well , Other:conductor extend (rr 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r 201-183 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20392-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025568 KRU 2T-39 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 11685 feet Plugs(measured) None true vertical 6050 feet Junk(measured) None Effective Depth measured 11584 feet Packer(measured) 11021 true vertical 5996 feet (true vertical) 5685 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121 16 156 156' SURFACE 5978 9 5/8 6012 3107' PRODUCTION 11212 7 11244 5819' LINER 671 3 1/2 11683 6049' RECEIVED ._ Perforation depth: Measured depth: 11358-11370, 11392-11406, 11454-11470, 11500-11510 True Vertical Depth: 5880-5886, 5897-5904, 5929-5939, 5952-5958 MAY 3 12016 AOGCC Tubing(size,grade,MD,and ND) 3.5, L-80, 11021 MD,5685 TVD Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO DS NIPPLE NO GO @ 525 MD and 524 TVD SEAL ASSY @ 11021 MD and 5685 TVD 12.Stimulation or cement squeeze summary: 3 Intervals treated(measured): NA %ANNE) JAN 2 r LG i Treatment descriptions including volumes used and final pressure: 1� 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-205 Contact MJ Loveland Email: N1878conocophillips.com Printed Name MJ Loveland Title: NSK Well Integrity Supervisor Signature "I 7 Phone:659-7043 Date /‘ V1 L- q /Z // ,� '1 -41 RBDMS LL JUN 0 2 2016 Form 10-404 Revised 5/2015 Submit Original Only • • ConocoPhillips RECEIVED Alaska MAY 3 1 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360AOGC C May 26, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 2T-39, PTD 201-183 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, 7/j7 rA MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • I 2T-39 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/23/16 Welded a 9" conductor Extension onto conductor to stablize wellhead. O L� •� , ui...: ..140-7,-.--..E. rte o .. . ...',.-,..iir,.., „: U, . U 0 N � � 0c � � � o caaC O ` ..r L � 0, L__ Off. 00 Q O — 4. � � �� . � .o_ . ZiE" O O O C\1 = Q (� C2.- .40 - ' ....,;(-_,t-, . . L. :-:-..:, - .. ,..'...., „,'. . . Asrutmn,,..,,-•-----...---,i.agi a c �2 �� r .fir "MI -.040now -4110 int, *11481111111010 IMIIIIIIIIIII • • 1 , „ 1`4 `NN, (iit, \-., . 1', a i' IF 1 i IL, k ..,, t TAT> kit k 4. reel • fi ` ,J• r1 � ey ,` rte r ( 4 At j f �� r t+r � t � t � r rY rr t 1 i t r t f ' \ ' '* ' h.-- \...,. IN 'llie:"F' 4" #7 , ' ... '',,.'- s .4%1/4 • At c� � � lift?;, L +� 0 C — (5 -o ._ / , . ,--, - A, _cp (D-. _ Jr: _ . ,40, , ,40. ,,. — : 1\0. �• s cn Q 0 >r i j` - if : ,. I,t4iiip" x � 4 Q 1 / ' - O - UO c 4 4 Q / '' 4 ./V • • SOF Ty • g 1" �//7; ••A THE STATE Alaska Oil and Gas Of TLAS Conservation Commission A 333 West Seventh Avenue ,_\7417- hGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS*P' Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland NSK Well Integrity Project Supervisor same ADP 0 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-39 Permit to Drill Number: 201-183 Sundry Number: 316-205 Dear Ms. Loveland: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, /a9k-e-t,b4- Cathy . Foerster � Chair DATED this `1,day of April, 2016. RBDMS 01 APR 0 5 2016 RECEIVED ' • STATE OF ALASKA • MAR 2 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION �FJe 1./¢//i,,;,, • APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well f Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing F Other:conductor extend 1.7- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development p - 201-183 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20392-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA- Will kWill planned perforations require spacing exception? Yes r No F/ KRU 2T-39 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025568 - Kuparuk River Field/Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): AlDepth TVD(ft):, Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11685 �J 6 5 4050 11584' • 5996' 3000 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 120 16 155' 155' SURFACE 5978 9 5/8 6012' 3107' PRODUCTION 11212 7 11244' 5819' LINER 671 3 1/2 11683' 6049' Perforation Depth MD(ft): 04 Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11358-11370, 11392-11406, 11454- 11470, 11500-13.'t'S0 1/610 5880-5886,5897-5904,5929-5939,5952-5958 3.5 L-80 11021 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) No SSSV CAMCO DS NIPPLE NO GO ° MD=525 TVD=524 SEAL ASSY , MD=11021 TVD=5685 12.Attachments: Proposal Summary F WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development . r Service r 14.Estimated Date for 15. Well Status after proposed work: 04/15/16 Commencing Operations: OIL WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: MJ Loveland Printed Name MJ Loveland Phone:659-7043 Email: N1878conocophillips.com Title: NSK Well Integrity Supervisor Signature 1 7 jCA---YDate: 77/(„76/ //‘ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 l4 -2vS Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Post Initial Injection MIT Req'd? Yes r No J Spacing Exception Required? Yes r No 1✓ Subsequent Form Required: /'�.—4 G if ----. 14,...(...,14,...._ APPROVED BY Approved by: �1 COMMISSIONER THE COMMISSION // Date: 4,-4—! co L 4 l4 /li0 YKd 314/$- /'/!/ 3` 70! 7/ Submit Form and Form 10-403 Revised 11/2015 opRieittAktfor 12 months from the date of approval. Attachments in Duplicate RBDMS 1,t/ APR 0 5 2016 • • ConocoPhillipsAEGEIVED Alaska MAR 2 9 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC March 26, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2T-39, PTD 201-183 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, je.:} MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 2T-39 (PTD 201-183) SUNDRY NOTICE 10-403 APPROVAL REQUEST 03-26-16 This application for Sundry approval for Kuparuk well 2T-39 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 10". With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage if it is exposed. 3. Extend the conductor to starter head. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor v., ima KUP PROD • 2T-39 ConocoPhillips �� Well Attributes Max Angle&MD TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status Inc](°) MD(ftKB) Act Btm IftKB) • r rhueps 501032039200 KUPARUK RIVER UNIT PROD 7243 2,150.00 11,685.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2T-39.622/20142:00:31 PM SSSV:NIPPLE Last WO: 36.60 11/12/2001 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,___ Last Tag:SLM 11,539.0 6/13/2013 Rev Reason:PLUG CORRECTION lehallf 6/22/2014 HANGER 28.6 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 155.0 155.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 34.4 6,012.3 3,090.6 40.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread I PRODUCTION 7 6.276 31.6 11,243.8 5,805.7 26.00 L-80 BTC-MOD .e, MIL Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I LINER 31/2 2.992 11,012.4 11,683.0 6,033.9 9.30 0-80 SENT Liner Details Nominal ID CONDUCTOR;35.0-155.0 • Top(ftKB) Top(TVD)(ftKB) Top Incl V) Item Des Com (in) 11,012.4 5,680.5 56.66 SLEEVE LINER TIE BACK SLEEVE 5250 NIPPLE;524.7 11,023.7 5,686.7 56.64 PACKER BAKER ZXP LINER TOP PACKER w/5"TKC 4.370 COUPLING 11,030.5 5,690.4 56.66 HANGER BAKER FLEX-LOCK LINER HANGER w/RS NIPPLE 4.410 II &TKC COUPLING 11,043.2 5,697.4 56.70 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 Tubing Strings GAS LIFT;3,960.3 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 28.6 11,058.8 5,706.0 9.30 L-80 EUE8RDMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 28.6 28.6 0.00 HANGER FMC GEN V TUBING HANGER 3.500 524.7 523.9 6.66 NIPPLE CAMCO DS NIPPLE NO GO 2.812 SURFACE;34.4b,012.3---_- 10,981.7 5,663.7 56.80 NIPPLE CAMCO D NIPPLE NO GO 2.750 11,020.8 5,685.1 56.63 LOCATOR BAKER LOCATOR 3.000 11,021.2 5,685.3 56.63 SEAL ASSY SEAL ASSEMBLY ABOVE 8 BELOW MULE SHOE-4" 2.875 GAS LIFT;7,013.3 - OD SEALS Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f GAS LIFT;8,745.5 - Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 11,358.0 11,370.0 5,865.0 5,871.1 C-4,2T-39 12/6/2001 6.0 IPERF 2.5"HSD,BHPJ,60 deg pH 11,392.0- 11,406.0 5,882.3 5,889.4 A-3,2T-39 - 12/4/2001 6.0 IPERF 2.5"HSD,BHPJ,60 deg pH GAS LIFT;10,011.8 - 11,454.0 11,470.0 5,913.9 5,922.1 A-2,2T-39 12/4/2001 6.0 IPERF 2.5"HSD,BHPJ,60 deg pH 11,500.0 11,510.0 5,937.6 5,942.8 A-2,2T-39 11/15/2008 6.0 APERF 2.5"HSD,PJ2506-HMX, 60 deg pH Stimulations&Treatments GAS LIFT;10,935.8 = Min Top Max Btm Depth Depth Top(TVD) Btm(WD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com I11,358.0 11,470.0 5,865.0 5,922.1 FRAC 12/10/2001 INITIALA&C SAND FRAC,279,600#16/20 CARBOLITE,12 PPA ON PERFS NIPPLE;10,981.7 a Mandrel Inserts St ati , on Top(WD) Valve Latch Port Size TRO Run 11 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date CO. f 3,90.3 2,33.4 CAMCO KBUG- 1 GAS LIFT GLV BK 0.156 8/23/2005 0.0 LOCATOR:11,020.9 .. 2 7,013.3 3,548.9 CAMCO KBUG- 1 GAS LIFT GLV BK 0.188 1,318.0 8/23/2005 • , M 3 8,745.5 4,462.3 CAMCO KBUG- 1 GAS LIFT GLV BK 0.188 1,300.0 8/23/2005 M SEAL ASSY;11,021.2 4 10,011.8 5,127.7 CAMCO KBUG- 1 GAS LIFT GLV BK 0.188 1,285.0 8/22/2005 • M IL 5 10,935.8 5,638.6 CAMCO MMG 11/2 GAS LIFT OV RK 0.188 0.0 8/21/2005 Notes:General&Safety End Date Annotation 10/26/2003 NOTE:WAIVERED WELL: IA x OA COMMUNICATION PRODUCTION;31.6-11243.8 IPERF;11,358.0-11,370.0 IPERF;11,392.0-11,406.0 FRAC;11,358.0 IPERF;11,454.0-11,470.0 - APERF;11,500.9-11,510.0 LINER;11,012.4-11,683.0 • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 1, 2010 .~ ~~~;} Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ao~-~83 a~=39 ~~~~Q F m '~°° ~at~t--issian Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement .was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30th, 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8101/10 2B_ 2K_ 2T PAD Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 2T-39 50103202280000 50103203920000. 1951020 2011830 SF 30" 0.40 0.54 12" 14" 7/21/2010 7/21/2010 2.6 4.3 7/30/2010 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION r REPORT OF SUNDRY WELL OPERATIONS ' 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development 0 Exploratory ^ 201-183 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20392-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 34' ~ 2T-39 ' 8. Property Designation: 10. Field/Pool(s): ADL 25568, 25569 Kuparuk River Field /Kuparuk River Pool 11. Present Well Condition Summary: Total Depth measured 11685' ~ feet true vertical 6050' • feet Plugs (measured) Effective Depth measured 11584' feet Junk (measured) true vertical 5996' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 120' 16" 154' 154' SURFACE 5978' 9-5/8" 6012' 3107' PRODUCTION 11210' 7" 11244' 5819' LINER 671' 3-1/2" 11683' 6049' Perforation depth: Measured depth: 11356'-11370', 11392'-11406', 11454'-11470', 11500'-11510' Y1 true vertical depth: 5880'-5886', 5897-5904', 5929'-5937, 5952'-5958' ,y~~~f" :.J~ ~.~s it ~~~t~ Tubing (size, grade, and measured depth) 3.5", L-80, 11012' MD. Packers & SSSV (type 8~ measured depth) no packer Camco'DS" nipple @ 525' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 562 975 153 ~ - 252 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil Gas^ WAG[] GINJ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: none Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer r• Signature ,1 r Phone: 265-6471 .t t C~ Date 12~.L~.'~dG7 r1`~ _ (~/ P ared b Shar n Allsu -D k 263-4612 Form 10-404 Revised 04/2006 ~y""`~.~~'+~ ~~ ~ lQatt Submit Ori mal Only /2//S~d1S` 2T-39 Well Work Summary DATE SUMMARY 11/4/08 PERFORM FCO DOWN TO H D TAG @ 11610' CTMD, LEAVING 140' ~T OF RATHOLE BELOW LOWER SET OF PERF.POON @ 80% WASHING TUBING, GLM AND JEWELRY.JOB COMPLETE 11/7/08 DRIFTED TUBING WITH 2.65" CENT & 10' OF 2.5" DD BAILER. TAGGED @ 11586' SLM. PROPOSED NEW PERFS: 11500' - 11510'. READY FOR E/L. 11/15/08 PERFORATED A2 INTERVAL FROM 11500'-11510' USING 2.5" HSD 2506 POWERJET HMX GUN, 6 SPF, 60 DEG PHASING. DID NOT TAG. ~" ~ KUP ~ 2T-39 ~4~I1{KC?Pfl~J~j~"JS Well Attributes Max Angel & MD TD I ~ Wallbore APIIU W I FnYd Nanm Well Slelus GruUllni Type lnci () MU ((tK6) Acl dm1((lKD) ~ I 501032039200 KUPARUK RIVER UNIT PROD i 72.32 2,139.30 71,685.0 Comment H2S (ppm) Date Annotation Entl Date KB-Grd (R) Rig Release Dat1 "°. . -T ;' ~ - - a sa FM - ~ >e m SSSV: NIPPLE 110 7!1/2008 Last WO: 36.60 11/12/2001 . ~ ,.. , ~ , g _-, ~,., ~...-, a. ~ ,al--_- -"' 4nnotation Depth (RKB) End Dah Annotation End Date L,~st Tag: SLM 11.586.0 11/7/2008 Rev Reason: ADD PERF. UPDATE_ SEAL OD81D 11!16/2008 Casing Strings ~ I I coNDUCro~ '.; NIPPLE, SURFACE, 8,013 GqS LIFT ],013 E~ GAS LIFT, e.]as 1 GAS LIFT, 10,012 E GAS LIFT, C~ 10,936 NIPPL E, 10,982 TUBING, 10,983 SEAL 11 021 , , PRODUCTION, 11,242 (PERF, ~, 1 11,358-11,370 4j (PERF, 11,392-11,406 FRAC, 11,358 1 (PERF, ii S 11,454-11,470 APERF, 11,50411,510 LINER, 11,683 ~ iD, 11,685 ~ Perforations shot rop IrvD) ~ Btm IrvD> ( Dana Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date (sh... Type Comment 11,358.0 11,370.0 5,879.8 5,885.8 C-4, 2T-39 1216/2001 6.0 (PERF 2.5" HSD, BHPJ, 60 deg pH 11,392.0 11,406.0 5,897.0 5,904.7 A-3, 2T-39 1214!2001 6.0 (PERF 2.5" HSD, BHPJ, 60 deg pH 60 deg pH Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth ~, Depth Depth (rvD) ITVD) (RKB) (RKB) (RKB) (RKB) Type Date Comment 11,358.0 11,470.0. 5,879.8 5,936.9 FRAC 12/10/2001 INITIAL A$C SAND FRAC, 279,600k 16/20 CARBOLITE. 12 PPA ON PERFS ~ Notes: General & Safety Entl Dato ~ AnoeWlion Tubing Strings SUIny OD Stilny lD Sel Dnpui Sal Depth ITV D) I Sbing YYt Smog Tubing Deudptlon Iin) On) Top (RKB) (RKB) (RKB) (Ibs/R) Grade String Top Thrd (TUBING 31/2 2.992 0.0 11,012.0 5,695.0 9.30 L-80 EUE8rdMOD ipther In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) ~ lop Depth ITVD) Top Inc! ToP (RKB) (RKB) (°) ~ Deacrlption Comment Run Date ID lin) 525.0 524.0 7.30~NIPPLE CAMCO'DS' NIPPLE w12.821 NO GO PROFILE 11/12/2001 2.8121 10/13/06 Scblunlbepgep OCT 1 6 2006 ,1~()iI&(;æ (ì~~~W7 C), ., Ç) ..:::..0 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth .""\\' , ..... \I \:',J\1- ~)! ~(-'v,'v r.\~\0)\.:\'Q.~'- '(j~If'" .. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 8Öl - lLß Field: Kuparuk Well Job# Date Color CD Log Description BL " 1J-127 11404957 PROD PROFILE W/DEFT 09/14/06 1 2W-10 11404958 INJECTION PROFILE 09/15/06 1 2W-14 11404960 INJECTION PROFILE 09/17/06 1 2U-01 11404964 PROD PROFILE W/DEFT 09/20/06 1 2A-19A 11415618 PROD PROFILE W/DEFT 09/03/06 1 1 E-04 11421627 INJECTION PROFILE 09/13/06 1 2W-02 11296718 INJECTION PROFILE 09/14/06 1 3H-10B 11296723 PATCH/STATIC SURVEY 09/19/06 1 2T -39 11296724 PROD PROFILE W/DEFT 09/20/06 1 1L-04 11415626 SBHP SURVEY 09/24/06 1 2V-04 11415628 INJECTION PROFILE 09/26/06 1 1A-17 11415622 PROD PROFILE W/DEFT 09/21/06 1 1 L-06 11415625 SBHP SURVEY 09/24/06 1 1F-07 11415629 LDL 09/27/06 1 2F-06 11434750 FLOWING BHP SURVEY 10/03/06 1 2A-17 11434751 PROD PROFILE W/DEFT 10/04/06 1 2P-447 11404966 INJECTION PROFILE 10/06/06 1 2V-08A 11216327 USIT 09/21/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor, Chair DATE: October 23,2001 THRU: Tom Maunder, ~t~~~~iE'-, r P. I. Supervisor FROM: Jeff Jones, Petroleum Inspector SUBJECT: Remedial Cementing PAl 2T -39 ~ PTD 201-183 KRU/KRF October 23. 2001: I traveled to Nabors Rig 16E in the Kuparuk River Field to witness a remedial surface casing cementing operation on Phillips Alaska Inc.'s well 2T -39. On my arrival I met with Mike Thornton (PAl rep.) and Truman Knutsen (Nabors Rep.) to discuss the procedure. A 95/8" TAM port collar set at 722' MD in the casing string was tested to 1000 psi, then opened and the remedial cementing proceeded with approx. 8 BBLS of 9.6 PPG drilling mud circulated with contaminated mud returns taken in the cellar. Dowell I Schlumberger then pumped 20 BBLS of fresh water followed by 147 BBLS of 10.7 PPG Arcticset Lite cement at a rate of approx. 4.7 BBLS/min. and 475 PSI. At approximately 95 BBLS of cement away I witnessed good returns of 10.7 PPG "green" cement to the surface around the circumference of the 9 5/8" surface pipe. The remainder of the 147 BBLS of cement was pumped and then displaced with 4 BBLS of water. SUMMARY: I witnessed a remedial surface casing cementing operation on PAl's well 2T-39 in the Kuparuk River Field. Attachments: PAl cement job reports (6 pages) Schlu mberger cement job reports (1 0 pages) cc: NON-CONFIDENTIAL 011023-Remedial Surface Cement P AI 2T-39 JJ.doc .'. þ' Hole Size: 12.250 (in) TMD Set: 6,012 (ft) Date Set: 10/23/2001 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Type: Cement Casing Volume Excess %: 150.00 Meas. From: Time Circ Prior To Cementing: 1.00 Mud Circ Rate: 210 (gpm) Mud Circ Press: 325 (psi) e (ft) Cmtd. Csg: e Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Cementer: Steve Doughten Pipe Movement: No movement Description: ASLite Cmt Vol: 147.0 (bbl) Slurry Vol:185 (sk) Temperature: (OF) Temperature: ("F) Temperature: (OF) Disp Avg Rate: Disp Max Rate: Bump Plug: ! Press Prior: Press Bumped: Press Held: Float Held: Returns: Full Total Mud Lost: I Cmt Vol to Surf: (bbl) 52.00 (bbl) Start Mix Cmt: 21 :25 Start Slurry Displ: 21 :53 Start Displ: 21 :53 End Pumping: 21 :55 I End Pump Date: 10/23/2001 Top Plug: N Bottom Plug: N 4.70 (bbl/min) 4.70 (bbl/min) N (psi) (psi) (min) N Ann Flow After: N Mixing Method: Tub Density Meas By: Densometer Slurry Data Fluid Type: LEAD Slurry Interval: 722.00 (ft) To: (ft) Water Source: Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Class: G Density: 10.70 (ppg) Yield: 4.45 (ft3/sk) Water Vol: 91.2 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Temp ("F) (OF) Pressure (psi) (psi) Printed: 10/24/2001 4:12:22 PM , , e e Slurry Data Fluid Type: LEAD Slurry Interval: 3,000.00 (ft)To: (ft) Water Source: Description: ASLite Cmt Vol: 474.4 (bbl) Slurry Vol:600 (sk) Density: 10.70 (ppg) Water Vol: (bbl) Class: G Yield: 4.45 (ft3/sk) Other Vol: 0 Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (" F) Temperature: (OF) Temperature: (OF) Temperature: ("F) Time Compressive Strength 1: Compressive Strength 2: Temp ("F) ("F) Pressure (psi) (psi) D124 D53 D79 S1 D46 D65 D44 50.00 % 30.00 % 1.50 % 1.50 % 0.60% 0.50% 9.00% Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pas Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: ~._~--,--,--- Printed: 10/24/2001 4:12:22 PM e e With 9-5/8" Tam Port Collar @ 722', RIH wI Tam Combo tool to 722', Test tool to 1000 psi, Open Tam Port Collar, Circ Btm's up @ rate of 5 bpm @ 325 psi & circ out 8 bbls cmt. contaminated mud, Rig Dowell, Pump 20 bbls fresh water, Followed by 185 sxs (147 bbls) Lead cmt. @ 10.7 ppg wI 50%D124, 30%D53, 1.5%D79, 1.5%S1, 0.6%D46, 0.5%D65, 9.0%D44, Mixed & pumped entire job @ 4.7 bpm @ 475 psi, Had good cmt to surface after pumping 95 bbls, Had 52 bbls cmt to surface, CIP @ 2155 hrs 10/23/01, Close Tam Port Collar & test to 1000 psi, Circ out 4 bbls cmt from drill pipe, Job witnessed by AOGCC Jeff Jones Printed: 10/24/2001 4:12:22 PM e e Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 6,012 (ft) SQ TMD: (ft) TMD Set: Top Set: (ft) Date Set: 10/23/2001 SQ Date: Date Set: BTM set: (ft) Csg Type: Surface Casing SQ Type: Csg Type: Plug Date: Csg Size: 9.625 (in.) SQ TMD: Plug Type: SQ Date: Drilled Out: Cmtd. Csg: Surface Casing Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Steve Doughten Pipe Movement: Reciprocating Type: Cement Casing Volume Excess %: Meas. From: Time Circ Prior To Cementing: 6.50 Mud Circ Rate: 252 (gpm) Mud Circ Press: 400 (psi) Start Mix Cmt: 11 :59 Start Slurry Displ: 11 :59 Start Displ: 14:20 End Pumping: 15:45 End Pump Date: 10/23/2001 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 4.00 (bbl/min) 6.00 (bbl/min) N 1,000 (psi) (psi) (min) Y Returns: Good Total Mud Lost: Cmt Vol to Surf: 120.00 (bbl) (bbl) I Ann Flow After: N Mixing Method: Density Meas By: Densometer Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (" F) Temperature: ("F) Temperature: (OF) Density: 8.40 (ppg) Water Vol: 20.0 (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Purpose: SPACER Mix Water: (bbl) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 10/24/2001 5:58:28 AM " e e Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: 50.0 (bbl) Other Vol: 0 Temperature: (OF) Temperature: ("F) Temperature: ("F) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: SPACER Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: LEAD Slurry Interval: 3,000.00 (ft)To: (ft) Water Source: Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: ASLite Cmt Vol: 474.4 (bbl) Slurry Vol:600 (sk) Class: G Density: 10.70 (ppg) Yield: 4.45 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) D124 D53 D79 S1 D46 D65 D44 Temperature: ("F) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) ("F) 9.00% Slurry Data Fluid Type: TAIL Slurry Interval: 6,012.00 (ft)To: Water Source: Test Data Thickening Time: 5.17 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) 50.00 % 30.00 % 1.50 % 1.50 % 0.60% 0.50% Description: LiteCRETE 3,000.00 (ft) Cmt Vol: 281.7 (bbl) Slurry Vol:659 (sk) Density: 12.00 (ppg) Water Vol: (bbl) Class: Yield: 2.40 (ft3/sk) Other Vol: 0 Temperature: ("F) Temperature: ("F) Temperature: ("F) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: TAIL Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) Printed: 10/24/2001 5:58:28 AM e e Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: 9-5/8",40#, L-80, BTCM Shoe @ 6012', Float Collar @ 5929' & 9-5/8" Tam Port Collar @ 722', Mixed & Pumped 5 bbls CW100, Test lines to 3500 psi, Mixed & Pumped 15 bbls CW100, Shut down drop bottom plug, Mixed & Pumped 50 bbls MudPUSH XL @ 10.5 ppg wIRed Dye @ rate of 4.5 bpm @ 400 psi, Followed by 600 sxs (474.4 bbls) Lead cmt. @ 10.7 ppg w/50%D124, 30%D53, 1.5%D79, 1.5%S1, 0.6%D46, 0.5%D65, 9.0%D44 @ Rate of 6 bpm @ 600 psi, Followed by 659 sxs (281.7 bbls) Tail cmt @ 12.0 ppg w/1.0%D65, 1.0%D79, 0.2%D46 @ Rate of 4-6 bpm @ 600 psi, Drop Top Plug, Displaced Cmt wI 3 bbls cmt., 7 bbls Wash water & 442.5 bbls 9.9 ppg mud @ Rate of 6-4.2 bpm @ 1000 psi, Did not bump plug, Had good returns thru out job but noticed a mud loss of .5 bpm loss - Total est. loss thru out job was 120 bbls, Did not see any CW1 00, MudPush or Cement returns to surface, CIP @ 1545 hrs 10/23/01 Printed: 10/24/2001 5:58:28 AM SCltIlmbIt'IIP e e Cementing Service Report I Well ~ I ¡ County J Beechey Point Deviation I Prudhoe Bay, AK 2001-0ct-23' ) Bit Size ) Welt MD Welt TVD 1 o I 9.88 in I 6,025 ft I 3,118 ft 'I I BHST I) BHCT I Pore Pre$$. Gradient 1 85 OF j psilft J 2T 39 TABASCO StatelProvince BHP DOYON 141 Oil Land Weight, Iblft AK 40 Rig Name Drilled For Service Via Other 41 cp Weight, Ibltt Service Line Cementing Cem Surface Casing Max. Allowed Ann. Pressure WellHead Connection I Max. Allowed Tubing Pressure I 3500 psi ~ instructions i I J Double cement hea Packer Type Diameter . ) m Packer Depth ) ft1 OpenHole Vol ¡ psi Top, ft Bottom, ft spf I No. of Shots T otallnterval I ft PhiUips Allocation = $ 68110.00 Field Estimate = $76,374.06 Total = $144,484.06 TN# - 15077 bbl) I ~bJ ¡ 2.1 bbU 455.6 bbJ j 336 Casing/Tubing Secured J;f) 1 Hole Volume Circulated prior to Cementing~ Casing Tools Squeeze Job Lift Pressure: psi Shoe Type: Float Squeeze Type I Pipe Rotated D Pipe Reciprocated~ Shoe Depth: 6010.58 ft Tool Type: No. Centralizers: 27 Top Flugs: 1 ¡Bottom Plugs: 1 Stage Tool Type: Tam Port Tool Depth: ft Cement Head Type: Double Stage Tool Depth: 7i9.1ft I Tail Pipe Size: in ) Job Scheduled For: ) Arrived on Location: ) Leave Location: I Collar Type: Float I Tail Pipe Depth: ft ··iI¡.¡¡¡.i¡rii. 'U' In > 20ü1-0ct-23 11:24 O. 8.33 O.85? 315.'3 O. O. 0 Safely Meeting 11:00 2001-0ct-23 11 :37 O. 8.33 13.87 18.32 O. 0. 0 2001-0d-23 11 :37 O. 8.33 13.87 18.32 J O. O. 0 Start CN1 00 2001-Gct-23 11 :37 0.2% , 8.33 14.29 59.52 0.296 1.38 0 1 I 2001-0ct-23 11 :38 1.25 8.33 14.71 242.7 1.25 3.31 0 J 2001-0ct-23 11:38 2.78 8.33 , 15.13 283.9 I 2.78 3.75 0 J 2001-0ct-23 11 :39 4.36 I 8.33 15.55 256.4 J 4.36 3.79 0 ! 2001-0ct-23 11:39 j 5.6 8.33 15.97 59.52 5.6 I O. 0 2001-0ct-23 11 :40 5.6 8.33 16.39 45.79 5.6 I O. 0 2001-0ct-23 11 :40 5.6 8.33 I 16.81 41.21 5.6 O. , 0 2001-0ct-23 11 :40 5.6 8.33 17.23 41.21 5.6 O. 0 2001-0ct-23 11 :41 5.66 8.33 17.65 1355 I 5.66 O. 0 2001-0ct-23 11 :41 5.66 8.33 18.07 1255 5.66 O. Ü 2001-0ct-23 11:42 I 5.66 8.33 18.49 1236 I 5.66 I Ü. Ü I 2001-0ct-23 11:42 5.68 8.33 18.91 3036 5.68 0.039 0 2üD1-0ct-23 11:42 5.68 8.33 I 18.91 I 31136 5.6B 11.1139 11 Pressure Test Lines 20D1-0ct-23 11 :42 I 5.68 8.33 19.33 3723 5.68 Ü. 0 2001-0ct-23 11 :43 5.68 8.33 19.75 728 I 568 O. 0 2001-Gct-23 11 :43 5.68 8.33 20.17 50.37 J 5.68 J O. 0 j I I I 2001-0ct-23 11 :44 5.68 8.33 20.59 41.21 5.68 I O. 0 20D1-0ct-23 11 :44 6.16 833 21.01 219.8 6.16 3.07 I 0 j 2001-0ct-23 11 :44 6.16 8.33 21.01 219.8 6.16 3.07 0 Resume CvV100 Casing Tubing Vol 449.4 bbl Casing Vol Annular Vol Oct 23,2001 WRS3 v3.2-SR Page 1 of 5 ¡ Well I Field Service Date Customer ) I 2T #39 I TABASCO 01296-0cl-23 PHILLIPS ALASKA INC N0 lili 'T'i .i" ,'.·,.,.i...<...>·'....' 'ii ""i'iiii ii· 2001-0ct-23 11 :45 7.79 8.33 21.43 389.2 7.79 4.34 I 0 2001-0ct-23 11:45 I 9.68 8.33 21.85 444.1 I 9.68 4.75 0 I 200l-0ct-23 11:45 11.8 I 8.33 22.27 430.4 11.8 I 5.13 0 2001-0ct-23 11:46 13.94 8.33 22.69 402.9 13.94 5.13 0 2001-0ct-23 11 :46 I 16.09 E.33 23.11 4945 I 16.09 5.1 , 0 2001-0ct.-23 11:471 18.24 8.33 23.53 467. I 18.24 5.B Ü J I I 2001-0ct-23 11:47 20.13 8.34 23.95 96.15 20.13 0.034 0 Drop Bottom Plug 2001-Dct-23 11 :47 ¡ 20.13 8.34 I 23.95 96.15 20.13 0.034 0 2001-0ct-23 11 :47 20.13 8.34 23.95 96.15 20.13 0.034 0 Reset Volume 2001-0ct-23 11 :47 20.13 8.34 23.95 96.15 20.13 0.034 0 [Stage Vo!ume]=20.13 bb1 200l-0ct-23 11 :47 20.13 8.28 24.37 , 59.52 0.001 O. 0 2001-0ct-23 11 :48 20.13 9.26 24.79 j 54.95 0.001 O. 0 2001-0ct-23 11 :48 20.13 10.95 25.21 50.37 0.001 O. 0 I 1 2001-0ct-23 11:49 20.13 I 10.99 25.63 50.37 I 0.001 O. 0 2001-0ct-23 11 :49 20.13 11. 26.05 50.37 0.001 O. 0 2001-0ct-23 11 :50 I 20.22 10.94 26.47 100.7 0.097 1.41 0 J 2001-0ct-23 11 :50 21.52 10.69 26.89 265.6 I 1.39 I 3.2 0 2001-0ct-23 11:50 21.52 10.69 26.89 265.6 1.39 ! 3.2 I 0 Start MudPUSH XL ! 2001-0ct-23 11:50 22.87 10.83 27.31 348. 2.74 3.17 0 2001-0ct-23 11 :51 24.32 I 10.77 27.73 348 4.2 3.65 , \] J I 20Dl-Oct-23 11 :51 25.89 10.42 28.15 274.7 5.76 3.75 0 ¡ 2001-0ct-23 11:52 27.56 10.26 I 28.57 325.1 J 743 4.03 0 I I 2001-0ct-23 11:52 29.38 10.46 28.99 I, 279.3 9.26 4.48 J 0 ¡ I 2001-Dct-23 11 :53 31.27 10.81 29.41 325.1 11.14 I 4.48 0 20ü1-0ct-23 11 :53 J 33.13 I 11.14 29.83 325.1 13.ü1 4.41 0 2001-0ct-23 11 :53 34.98 10.99 30.25 357.1 14.85 4.37 , 0 200l-0ct-23 11 :54 36.82 10.52 30.67 I 361.7 16.69 4.37 0 2001-0ct-23 11 :541 38.68 10.78 31.09 398.4 18.56 4.44 0 2001-0ct-23 11 :55 j 40.54 , 10.95 31.51 462.5 20.41 437 0 2001-0ct-23 11:55 42.38 I 10.65 1 31.93 439.6 1 22.26 4.44 0 2001-0ct-23 11:55· 44.25 10.33 32.35 320.5 24.12 4.44 0 2001-0ct-23 11 :56 46.12 10.71 32.77 375.5 25.99 4.44 0 200l-0ct-23 11 :56 47.97 10.84 33.19 I 3342 27.85 4.41 I 0 2001-0ct-23 11:57 49.84 10.67 33.61 416.7 29.71 4.48 0 I 2001-0ct-23 11:57 51.71 10.43 34.03 393.8 I 31.58 4.41 I 0 zOOl-0ct-23 11:58 53.58 10.42 34.45 348. i 33.45 4.48 0 20Dl-Oct-23 11 :58 55.44 10.83 34.87 297.6 35.31 4.41 0 I 2001-0ct-23 11:58 I 57.3 10.87 35.29 302.2 I 37.18 4.44 0 200l-0ct-23 11:59 J 59.16 10.65 35.71 430.4 I 39.03 I 4.44 0 20m-Dct-23 11 :59 61.03 10.57 36.13 439.6 40.91 4.44 0 20ü1-0ct-23 12:00 62.9 10.43 36.55 288.5 4278 4.48 0 200l-0ct-23 12:00 64.77 10.43 36.97 329] 44.65 4.44 , 0 J 200l-0ct-23 12:01 66.74 10.62 37.39 J 517.4 46.62 4.92 0 2001-0ct-23 12:01 66.74 10.62 37.39 517.4 46.62 4.92 0 Start Lead Slurl)/ 2001-0ct-23 12:01 66.74 10.62 37.39 517.4 46.62 4.92 0 Reset Volume 2001-0ct-23 12:01 66.74 10.62 37.39 517.4 46.62 4.92 0 [Stage Volume]=47.83 bbl 2001-0ct-23 12:01 69.33 10.84 37.81 709.7 127 6.3 0 2001-0ct-23 12:01 71.99 10.87 38.23 732.6 3.93 I 6.34 0 2001-0ct-23 12:02 I 74.64 10.71 38.65 7143 I 6.58 I 6.34 0 2001-0ct-23 12:07 106.5 I 10.7 43.69 599.8 38.4 6.27 0 2001-0ct-23 12:07 109.1 10.71 44.11 I 599.8 41.03 6.23 0 2001-0ct-23 12:0B 111.7 10.6B 44.53 5B6.1 43.65 , 6.27 0 2001-0ct-23 12:08 114.3 I 10.68 44.95 I 544.9 46.29 6.27 0 2001-0ct-23 12:08 117. 10.78 45.37 535.7 j 48.91 6.23 0 e e Oct 23,2001 WRS3 v3.2-SR Page 2 of 5 I Well I Field Service Date Customer 2T #39 I TABASCO 01296-Oct-23 PHILLIPS ALASKA INC iy " "" " 2001-0ct-23 12:09 119.6 I 10.79 45.79 531.1 51.53 6.23 0 2001-0ct-23 12:09 122.2 10.78 46.21 522. 54.14 6.23 0 2001-0ct-23 12:10 124.8 10.79 46.63 595.2 56.74 6.16 0 2001-0ct-23 1210 127.4 10.69 I 47.05 503.7 I 59.34 6.16 \) 2001-0ct-23 12:11 130. 10.73 47.47 590.7 61.94 6.2 0 I 2001-0ct-23 12:11 132.6 10.8 4789 586.1 64.54 6.16 0 2001-0ct-23 12:11 135.2 10.87 48.31 599.8 67.13 I 6.16 0 2001-Dct-23 12:121 137.8 10.87 I 48.73 618.1 69.72 6.16 0 I 200l-0ct-23 12:121 140.4 10.82 ¡ 49.15 609. I 72.3 6.1 0 2001-0ct-23 12:13 142.9 10.81 J 49.57 576.9 j 74.87 , 6.13 J 0 I 200l-0ct-23 12:13 J 145.5 10.84 ! 49.99 544.9 j 77.44 613 0 2001-0ct-23 12:14 148.1 1 10.87 50.41 595.2 80.02 6.1 0 J 200l-0ct-23 12:14 150.7 I 10.87 50.83 526.6 82.59 6.13 , 0 200l-0ct-23 12:141 153.2 1 10.86 51.25 558.6 85.16 6.1 1 0 , 2001-0ct-23 12:15 155.8 10.81 51.67 5357 87.73 6.1 0 2001-0ct-23 12:15 158.3 10.82 52.09 489.9 90.29 6.06 0 200l-0ct-23 12:16 160.9 10.83 52.51 494.5 92.84 6.1 0 2001-0ct-23 12:16 163.4 I 10.84 52.93 572.3 95.38 6.06 i 0 I J 2001-oct-23 12:16 166. 10.81 I 53.35 512.8 97.94 6.1 0 2001-0ct-23 12:17) 168.5 10.81 53.77 540.3 I 100.5 , 6.1 0 2001-0ct-23 12:17 ' 171.1 10.78 54.19 512.8 1 103. 6.06 I 0 I 2001-0ct-23 12:18 173.6 10.77 54.61 563.2 105.6 6.06 0 , I 2001-0ct-23 12:18 176.2 10.72 I 55.D3 I 531.1 108.1 6.06 i 0 \ 2001-Dct-23 12:19 I 1 78.7 10.79 55.45 ! 508.2 110.7 6.03 I 0 200l-0ct-23 12:19 181.2 10.85 55.87 494.5 I 113.2 5.96 0 -j 2001-0ct-23 12:19 183.7 10.89 56.29 535.7 115.7 5.99 0 200l-0ct-23 12:20 186.3 10.91 56.71 540.3 118.2 5.99 0 I 2001-0ct-23 12:20 188.8 10.94 57.13 526.6 120.7 5.99 0 ! 2001-0ct-23 13:10 495.7 10.94 107.1 604.4 427.6 6.16 0 2001-0ct-23 13:11 498.3 10.84 107.5 586.1 430.2 6.16 0 , 200l-0ct-23 13:11 500.9 10.83 107.9 503.7 432.8 6.2 0 2001-0ct-23 13:11 503.5 10.87 108.3 576.9 435.4 6.16 0 2001-0ct-23 13:12 506.1 10.82 108.8 549.5 I 438. 6.2 0 2001-0ct-23 13:12 508.7 10.88 I 109.2 576.9 I 440.6 6.2 0 2001-0ct-23 13:13 511.3 10.87 109.6 544.9 443.2 6.16 i 0 20D1-uct-23 13:13 513.8 10.78 110. 549.5 445.8 6.2 0 , 20m-Oct-23 13:14 I 516.4 10.71 11 0.4 595.2 I 448.4 6.2 I 0 20ü1-0ct-23 13:14 519. 10.78 I 110.9 508.2 I 451. 6.2 0 2001-0ct-23 13:14 i 521.6 10.87 111.3 , 581.5 453.6 6.16 0 2!J!Jl-Dct-23 13:15 524.2 10.9 111.7 558.6 456.2 6.16 0 ¡ 200l-0ct-23 13:15 I 526.8 I 10.79 112.1 549.5 , 458.7 6.13 0 J I I I I 2001-0ct-23 13:16 529.4 10.86 112,5 599,8 461.3 6.13 0 200l-0ct-23 13:161 531.9 I 10.9 113. 567.8 I 463.9 6.13 0 2001-0ct-23 13:17) 534.5 10.78 113.4 531.1 I 466.5 6.13 0 2001-0ct-23 13:17 537.1 10.85 113.8 567.8 469. I 6.13 , 0 J 200l-0ct-23 13:17 537.1 10.85 113.8 567.8 469. 6.13 0 Start Tail Slurry 2001-0ct-23 13:17 539.7 10.77 1142 522. 471.6 613 0 2001-0ct-23 13:18 542.2 10.97 114.6 549.5 2.25 6.1 ¡ 0 2001-0ct-23 13:18 542.2 10.97 114.6 549.5 2.25 6.1 0 ResetVolume 2001-0ct-23 13:18 542.2 10.97 114.6 I 549.5 2.25 61 I 0 [Stage Volume]=471.8 bbl 2001-0ct-23 13:18 544.8 11.49 115.1 i 682.2 4.78 6.03 0 20D1-0ct-23 13:19 547.3 11.26 115.5 627.3 7.32 6.06 0 2001-0ct-23 13:24 577.9 11.84 I 120.5 1168 37.89 6.1 0 2001-0ct-23 13:29 i 606.4 12.13 125.6 I 920.3 66.44 6.06 0 e e Oct 23,2001 WRS3 v3.2-SR Page 3 of 5 Well I Field ¡service Date Customer 2T #39 T ABASCO 01296-Oct-23 PHILLIPS ALASKA INC « " , 2001-0ct-23 13:29 609. 12.03 126. 888.3 68.98 6.06 I 0 2001-0ct-23 13:30 611.5 12.1 126.4 1016 71.5 5.96 0 2001-0ct-23 13:30 6l4. 12.08 126.8 1030 I 74.02 5.99 I 0 I 2001-0ct-23 13:30 616.5 12.17 127.2 1218 76.52 5.96 0 20D1-0ct-23 14:04 760.3 12.05 160.4 I 544.9 220.3 3.97 0 ¡ 20üí-Oct-23 14:04 761.9 12.07 160.8 540.3 2219 3.97 0 2001-0ct-23 14:04 763.6 12.07 161.3 416.7 223.6 I 4. 0 2001-0ct-23 14:05 765.3 12.02 161.7 499.1 225.3 3.99 1 0 2001-0ct-23 14:05 766.9 12.01 162.1 540.3 227. 4. I 0 1 2001-0ct-23 14:06 768.6 12.08 162.5 544.9 228.6 3.99 0 I I 2001-0ct-23 14:06 770.3 1217 162.9 , 590.7 230.3 I 3.99 I 0 J 2001-0ct-23 14:06 772. 12.19 163.4 613.6 232. 3.99 0 2001-0ct-23 14:07 773.6 12.19 163.8 636.4 233. 7 3.99 0 2001-0ct-23 14:07 775.3 12.14 1642 572.3 235.3 I 3.99 I 0 J 2001-0ct-23 14:08 777. 12.08 1646 540.3 237. 3.97 0 2001-0ct-23 14:08 778.6 11.96 165. 522. 238.7 4. I 0 2001-0ct-23 14:09 780.3 12.1 165.5 526.6 240.3 I 4. I 0 I 2001-0ct-23 14:09 782. 12.23 165.9 641. 242. 3.97 0 2001-0ct-23 14:09 783.7 12.22 166.3 691.4 243.7 3.97 0 2001-0ct-23 14:10 785.3 12.22 166.7 659.3 I 245.3 3.97 I 0 20û1-0ct-23 14:10 787. 12.11 167.1 I 595.2 247. 3.99 I 0 I 2001-0ct-23 14:11 788.7 12.01 167.6 540.3 248.7 3.97 0 2001-0ct-23 14:11 790.3 11.95 168. 540.3 250.4 4. 0 j 200l-oct-23 14:12 792. 12.02 168.4 563.2 252. 3.99 J 0 ¡ I 2001-0ct-23 14:12 793.7 I 12.1 168.8 558.6 253.7 3.99 0 2001-0ct-23 14:12 795.4 12.12 169.2 558.6 , 255.4 3.99 0 2001-0ct-23 14:13 797. 12.13 169.7 586.1 257.1 3.99 0 200i-Oct-23 14:13 798.7 12.13 170.1 590.7 258.7 3.99 , 0 , 2001-0ct-23 14:14 800.4 12.09 170.5 554. , 260.4 3.99 0 2001-0ct-23 14:14 802. 12.09 170.9 599.8 j 262.1 3.99 0 2001-0ct-23 14:14 803.7 12.08 171.3 576.9 2637 3.97 0 2001-0ct-23 14:15 805.4 12.05 I 171.8 586.1 I 265.4 1 3.97 0 J 2001-0ct-23 14:15 807.1 1199 172.2 522. 2671 3.99 0 2001-0ct-23 14:16 808.7 I 11.95 172.6 544.9 268.7 3.99 0 I J 2001-oct-23 14:16 810.4 12.16 173. 540.3 270.4 4. 0 I 2Dû1-0ct-23 14:17 812.1 , 12.19 173.4 691 .4 I 272.1 3.97 D 2DOi-Oc\-23 14:17 813.7 12.16 173.9 700.5 273.8 I 3.97 0 2001-0ct-23 14:17 815.4 12.19 I 174.3 746.3 275.4 3.95 Ü 2001-od-23 14:18 I 817.1 12.16 174.7 604.4 , 277.1 3.99 " I u 2001-oct-23 14:18 818.7 12.2 175.1 636.4 278.8 3.97 0 I I J 2001-0ct-23 14:19 820.4 1222 175.5 6136 280.4 3.97 0 2001-0ct-23 14:19 821.7 12.4 176. 114.5 281.7 0.467 0 I 2001-0ct-23 14:20 821.7 , 12.46 176.4 50.37 I 281.7 , O. 0 I 2001-0ct-23 14:20 821.7 12.48 176.8 36.63 281.7 j O. I 0 2001-0ct-23 14:20 ) 821.7 12.48 177.2 36.63 281.7 O. 0 2001-0ct-23 14:21 821.7 12.5 177.6 36.63 281.7 O. 0 2001-0ct-23 14:21 821.7 12.5 178.1 32.05 281.7 O. 0 2001-0ct-23 14:22 821.7 I 12.51 178.5 3205 281.7 O. I 0 2001-0ct-23 14:221 821.7 12.51 I 178.5 32.05 281.7 O. I 0 Drop Top Plug 2001-0ct-23 14:22 821.7 12.51 1785 32.05 I 281.7 0 0 Reset Volume 2001-0ct-23 14:22 821.7 I 12.51 178.5 32.05 281.7 O. 0 {Stage Volume}=281.7 bbl I 20tn-Oc\-23 14:22 821.7 12.5 178.9 32.05 O. O. 0 2001-0ct-23 14:22 821.7 12.5 178.9 32.05 O. O. 0 Start 3 bbl Cement 2001-0ct-23 14:22 822.5 12.57 1793 412.1 I 0.767 i 22 0 e - Oct 23,2001 WRS3 v3.2-SR Page 4 of 5 j Well I Field 2T #39 " 2001-0ct-23 14:23 823.4 12.51 2001-0ct-23 14:23 824.3 12.5 2001-Qct-23 14:23 i 824.3 12.5 2001-0ct-23 14:24 'I 824.3 12.5 2ûOl-0ct-23 14:24 1 824.3 12.5 I 2üú1-0ct-23 14:24 825.3 12.49 2001-0ct-23 14:24 '827. 11.2£ I 2001-0ct-23 14:25 829.2 I 12.48 I 2001-0ct-23 14:25' 831.3 I 12.48 I 2001-0ct-23 14:25 832.5 I 12.49 2001-0ct-23 14:26 832.5 1249 2001-0ct-23 14:26 832.5 12.48 2001-0ct-23 14:27 832.5 9.37 2001-0ct-23 15:44 832.5 I O. 2001-0ct-23 15:44 832.5 -0.008 2001-0ct-23 15:44 832.5 -0.008 2001-0ct-23 15:45 832.5 O. 2001-0ct-23 15:45 832.5 O. 2001-0ct-23 15:45: 832.5 -0008 2001-0ct-23 15:45 832.5 i -0.008 2001-0ct-23 15:45 832.5 -0.008 i:'::'i:' Tiii'T.: :.....,:..,:.,: :: : 5.2 I I Treating Maximum Final Average 1630 I 503 j 800 J Avg. N2 Percent j Designed Slurry Volume ) % ) 741 bbl ¡ Customer or Authorized Representative I Thomton, Mike Oct 23,2001 WRS3 v3.2-SR e TABASCO 179.7 180.2 180.2 180.2 180.2 180.6 181. 181.4 181.8 182.3 182.3 182.7 182.7 182.9 183.3 183.3 183.7 183.7 184.2 184.2 i 184.£ bpm I 6.3 n.,õ Bump Plug to Breakdown o ¡ Displacement J 453 bbl ¡ Dowell Supervisor 389.2 402.9 402.9 402.9 402.9 563.2 489.9 499.1 503.7 87. 87. 50.37 41.21 -4.58 -4.58 -4.58 -4.58 -4.58 -4.58 -4.58 O. Service Date 01296-Oct-23 754 Type Customer e PHILLIPS AlASKA INC I 1.69 2.62 2.62 2.62 2.£2 0.485 2.2£ 4.39 6.52 7.73 7.73 7.73 7.73 7.73 7.73 7.73 7.73 7.73 7.73 7.73 7.73 2.2 2.2 : 2.2 : 2.2 1 2.2 3.36 'I J 5.02 5.05 I 5.07 D. D. O. J O. O. O. o. O. O. I O. o. i O. "1" o o o o o o o o (I o o o o o o o o o o o o . .u.u 'n¡A~f""" bbl ! Volume St",rt H20 Behind Reset Volume [StageVolume)=3.059 bb1 1 ¡ Shutdown/Rig to Displ",C8 Shutdown Top job required End Job ¡ . I I 50 Density j bbl ¡ Mix Water Temp ¡ D ~t Circulated to Surface?VOlUme 75 of D Washed Thru Perfs To ft Doughten, Steven j D 0 Ib/gal o bbl - Pane 5015 . -.,- - -. - W Mark of $chJumoorf;1eT 11:00 ~Start 0\1\1100 "'Shutdown SCltI.It'IIP e Cementing Service Report e Rig Name Drilled For Formation NamelType De"iation Well 2T 39 Field TABASCO County StatelProvince SHP I I ·1 psi' Beechey Point AK Service Via NABORS 16 Oil Well Class Land Depth, ft Grade Thread Offshore Zone Well Type 6010 L-80 BUTT Drilling Fluid Type New Exploration Max. Density Plastic Viscosity Service line 9.8 Ib/gal 40 cp ¡ I Treat Down f" . Displacement I 6 bb! j j I Packer Type Total Interval I ft) I Diameter . ¡ ~ Packer Dep: ) Cementing Max. Allowed Tubing Pressure WellHead Connection 3500 psi Service Instructions psi WECO 2" Phillips Allocation = $ 12,110.00 Materials = $8799.60 Total = $20,909.60 TN# - 15087 I 'I vaslng I '\ I I j I Tubing Vol. , Casing Vol. I Annular Vol. I OpenHole Vol! , I I Obbl) bbl j o bbJ 40 bbJ I CasinglTubing Secured ~ 1 Hole Volume Circulated prior to Cementing~ I Casing Tools Squeeze Job Lift Pressure: psi j Shoe Type: Float Squeeze Type Pipe Rotated 0 Pipe ReciprocatedD Shoe Depth: 6010 ft Tool Type: J No. Centralizers: 27 Top rlugs: 1 ¡Bottom Plugs: 1 j Stage Tool Type: Tam Collar Tool Depth: ft Cement Head Type: Double I Stage Toot Depth: 719 ft Tail Pipe Size: in ) Job Scheduled For: ) Arrived on Location: Leave Location: I Collar Type: Float I Tail Pipe Depth: ft I ) I 10/18/01 17:00 I 2001-0ct-23 17:00 2001-0ct-23 23:30 Collar Depth: 5929 ft Sqz Total Vol: bbl I F iT" I¡/< 1/ ¡......C·............. 1 IiI .i..>: . 20Qí -Oct-23 21 :15 O. I -6.26 O. -3306 O. I O. 0 2001-0ct-23 21:15 O. j 8.33 0.168 77.84 I O. , O. 0 2001-0ct-23 21 :16 O. 8.33 0.336 77.84 O. O. 0 2001-Qct-23 21 :16 O. I 8.33 0.336 77.84 O. O. 0 Safely Meeting 21 :00 I 2001-0ct-23 21:161 O. I 8.33 , 0.504 17.84 O. O. J 0 J I 2001-0ct-23 21:16 ) O. 833 0.672 , 8242 O. O. 0 I 2001-0ct-23 21:16 O. I 8.33 0.84 77.84 O. O. 0 1 : 2001-0ct-23 21:16, O. I 8.33 I 1.01 77.84 O. O. j 0 2001-0ct-23 21 :16 O. 8.33 1.18 82.42 O. O. 0 j 2001-0ct-23 21 :17 O. 8.33 1.34 77.84 O. O. 0 J 2001-0ct-23 21 :17 I O. 8.33 I 1.51 77.84 O. O. 0 2001-0ct-23 21:171 O. 833 I 1.68 77.84 O. O. 0 I I 2001-0ct-23 21:17 O. 833 1.85 77.84 O. O. 0 \ 2001-0ct-23 21 :17 O. I 8.33 2.02 77.84 O. O. (\ 2001-0ct-23 21:17 O. 8.33 2.18 , 77.84 O. I O. I 0 2DD1 -Oct-23 21:18 D. 8.33 2.35 , 77.84 D. D. D I 20û1-0ct-23 21:18 0.001 8.33 2.52 4.58 O.Oû1 O. 0 ) , 20m-Oct-23 21 :18 0.042 833 2.6'3 458 0.042 0.861 0 , 2001-0ct-23 21:18 I 0.042 8.33 2.69 4.58 0.042 0.861 I 0 Start 20 bbj H20 Ahead I I I I 2001-0ct-23 21:18 0.234 8.33 I 2.86 13.74 0.234 1.38 I 0 2001-0ct-23 21:18 J 0.462 8.33 3.02 64.1 0.462 1.34 I 0 I 2001-0ct-23 21:18 0.776 8.33 3.19 109.9 0.776 2.03 0 Oct 23,2001 WRS3 v3.2-SR Page 1 of 3 e e I Well Field Service Date Customer 2T #39 TABASCO 01296-Qct-23 PHilLIPS ALASKA INC !i :: :::: i'" ," it!! 2001-0ct-23 21 :25 20.18 9.79 9.58 45.79 20.18 ! O. 0 2001-0ct-23 21:25 20.18 9.84 9.74 50.37 20.18 O. 0 2001-0ct-23 21:25 20.18 9.84 I 9.91 50.37 20.18 O. 0 I 2001-0ct-23 21:25 20.18 9.86 10.08 , 50.37 20.18 O. 0 20û1-0ct-23 21:25 2û.lí3 99 1û.25 50.37 'I 20.1 í3 Û. , Û 2001-0ct.-23 21:26 I 20.18 99 10.42 \ 50.37 20.18 I O. 0 2001-0ct-23 21:26 ¡ 20.21 9.9 I 10.58 45.79 I 20.21 0.827 0 2001-0ct-23 21:26 20.21 I 9.9 10.58 J 45.79 20.21 0.827 0 Start Cement Sturry I 2001-0ct-23 21:26 20.21 , 9.9 10.58 45.79 20.21 0.827 J 0 {Stage Volume]=20.24 bbl 2001-0ct-23 21:26 20.21 9.9 10.58 45.79 20.21 I 0.827 0 Reset Volume 2001-0ct-23 21:26 20.41 9.91 10.75 I 87. 0.149 1.48 0 2001-0ct-23 21:26 20.78 I 9.91 I 10.92 169.4 0.521 2.82 0 I 2001-0ct-23 21 :26 21.49 I 10.01 11.09 325.1 1.24 I 4.61 , 0 2001-0ct-23 21:26 22.27 , 10.24 11.26 I 366.3 2.02 , 4.65 0 2001-0ct-23 21 :27 2106 1 0.51 11 .42 393.8 2.8 4.65 0 2001-0ct-23 21:27 23.84 10.78 11.59 352.6 158 4.65 0 2001-0ct-23 21:27 24.61 10.98 11.76 389.2 I 4.35 4.61 I 0 I 2001-0ct-23 21:27 25.38 11.05 11.93 384.6 5.12 I 4.58 0 i 2001-oct-23 21 :27 26.15 11.03 12.1 407.5 5.69 I 4.61 0 I 2001-0ct-2::J 21:27 26.93 10.97 12.26 375.5 I 667 4.65 0 I 2ûD1-0ct-23 21:28 27 .71 1û.92 12.43 39M 7.46 4.68 û I 20ü1-0ct-23 21:28 28.5 10.89 12.6 352.6 8.25 4.68 1) I 2001-0ct-23 21 :43 I 100.1 10.78 27.72 430.4 79.64 I 4.75 0 2001-oct-23 21:43 100.9 10.78 , 27.89 453.3 80.63 4.75 0 I 2001-0ct-23 21 :46 114.4 10.78 3û.74 444.1 94.14 4.75 0 2001-0ct-23 21 :46 115.2 I 10.75 30.91 430.4 I 94.93 4.75 0 2001-0ct-23 21:46 I 116. 10.74 31.08 4579 I 95.73 4.75 J 0 J 2001-0ct-23 2146 116.6 10.73 3125 412.1 96.53 4.75 0 I 2001-0ct-23 21:47 117.6 10.71 I 31.41 439.6 97.33 I 4.79 0 2001-0ct-23 21 :47 118.4 10.72 31.58 439.6 98.13 4.75 0 ) 2001-0ct-23 21 :47 I 119.2 10.74 31.75 425.8 98.93 4.75 0 2001-0ct-23 21:47 120. 10.74 31.92 I 425.8 99.73 4.75 0 2001-0ct-23 21:47 120.8 10.75 32.09 457.9 100.5 I 4.75 0 2001-0ct-23 21:47 121.6 10.77 32.25 453.3 101.3 4.75 0 2001-0ct-23 21:48 122.4 10.79 32.42 453.3 102.1 4.72 I 0 20Dl-Oct-23 21 :4B 123.2 10.B1 32.59 444.1 102.9 4.72 0 2ûûl-0ct-23 21 :48 124. 1û.84 32.76 448.7 103.7 4.75 Û 2001-0ct-23 21A8 124.8 10.86 32.93 435 I 104.5 4.75 1) 2001-0ct-23 21:48 125.6 10.89 , 33.09 , 457.9 105.3 4.72 0 I I 2001-0ct-23 21:48 126.3 10.9 33.26 435. J 106.1 4.72 0 2001-0ct-23 21 :49 I 127.1 10.9 33.43 448.7 106.9 472 0 2D01-0ct-23 2L49 127.9 10.88 316 416.7 107.7 4.72 J 0 2001-0ct-23 21:49 128.7 10.87 33.77 448.7 108.5 I 4.72 0 2001-0ct-23 21 :49 129.5 J 10.86 33.93 444.1 109.3 4.72 0 2001-0ct-23 21:49 130.3 10.84 34.1 I 439.6 110. 4.75 0 2001-0ct-23 21 :491 131.1 I 10.82 34.27 407.5 110.8 4.75 0 2001-0ct-23 21 :50 131.9 10.79 34.44 425.8 111.6 4.72 0 2001-0ct-23 21:50 132.7 10.74 34.61 457.9 112.4 I 4.72 0 , I 2001-0ct-23 21:53 146.2 10.92 I 37.47 435. I 125.9 4.68 0 2001-oct-23 21:56 159.7 10.84 40.33 421.2 139.4 4.68 i 0 2001-0ct-23 21:56 160.4 10.84 40.49 I 448.7 140.2 4.72 0 I 20Dl-Oct-23 21:56 161.2 10.84 40.66 430.4 , 141. 4.68 j 0 20û1-0ct-23 21:56 162. 10.83 40.83 444.1 141.8 4.68 0 2001-0ct-23 21:56 I 162.8 10.9 41. I 444.1 142.6 472 0 i Oct 23,2001 WRS3 v3.2-SR Page 2 of 3 e e I Well Field Service Date Customer I 2T #39 TABASCO 01296-Oct-23 PHILLIPS ALASKA INC H" " " 2001-0ct-23 21:56 163.6 10.96 41.17 439.6 I 143.3 4.68 0 2001-0ct-23 21:57 I 1644 11.02 41.33 I 453.3 I 144.1 4.65 I 0 2001-0ct-23 21:57 165.2 11.02 41.5 I 444.1 144.9 4.65 I 0 I 2001-0ct-23 21:57 166. 10.85 41.67 485.3 145.7 4.68 0 2ûû1-0ct-23 21:57 166.7 1û.84 41.84 4945 1465 I 4.68 Û 20m-Oct-23 21:57 167.5 I 10.B9 42.01 , 44B.7 147.3 4.6B Û I 2001-0ct-23 21:57 167.5 10.89 42.01 448.7 147.3 J 4.£8 0 Start 3 bbt H2O I 200l-Gct-23 21 :57 I 167.5 10.89 I 42.01 448.7 147.3 4.68 0 (Stage Volumel=147.4 bbt 2001-0ct-23 21:57 167.5 10.89 42.01 448.7 147.3 4.68 0 ResetVclume I 2001-0ct-23 21:57 168.3 10.91 42.17 393.8 0.548 4.72 0 I 2001-0ct-23 21:58 169.1 , 10.92 , 42.34 357.1 1.35 4.79 0 2001-0ct-23 21:58 169.9 10.94 42.51 348. 2.15 4.79 I 0 2001-0ct-23 21:58 i 170.7 10.94 42.68 352.6 2.95 4.75 0 2001-0ct-23 21:58 171.1 I 10.94 42.85 8242 I 13 I O. 0 2001-0ct-23 21 :58 171.1 10.94 4101 54.95 3.3 O. 0 2001-0ct-23 21:58 171.1 10.94 43.18 50.37 3.3 O. 0 2001-0ct-23 21:59 171.1 10.94 43.35 45.79 ! 13 O. 0 I 2001-0ct-23 21:59 171.1 10.94 43.35 45.79 I 3.3 O. I 0 Shutdown/Rig to DisplEtc-e 2001-0ct-23 21:59 171.1 8.85 43.52 45.79 3.3 O. 0 I 2001-0ct-23 21:59 171.1 8.72 43.69 45.79 3.3 \l 0 I 20û1-0ct-23 21:59 171.1 j 8.75 43.85 45.79 3.3 O. I Û ·!i"'i.., .....,........"................... · ',...,·..·.i,·..i.i..i...... ·i." ii'· // ."",i"'ii 'Ci'ii.,· I. ) Slurry Average Pump Rates, N2 Mud bpm Volume of Fluid Injected, bbl Maximum Rate Total Slurry Mud Spacer N2 o o 147 20 Maximum Treating Pressure Summary, psi Final Average Bump Plug to Breakdown Type Breakdown Fluid Volume Density Avg. N2 Percent Designed Slurry Volume Displacement I bbl I ~ ~t Circulated to Suñace?v;;ume of 0 Washed Thru Peñs To ft J Ib/gal 30 bbl I I I I 476 352 400 o % 40 bbl o bbl Customer or Authorized Representative Dowell Supervisor TM,orntpn, ~ike DO~QN~f1, §teYen 0 çirl!lll\~q!1,.~t ~ "ftb cOlTlr"~ Oct 23.2001 WRS3 v3.2-SR Page 3 of 3 Client SIR No. Job Date 9:15:40 PM 05:18:48 05:19:40 05:22:33 05:25:26 05:28:19 05:31:12 05:34:04 05:36:57 05:39:50 05:42:43 05:45:38 05:48:28 05:51 :21 '" 0 OJ "' 05:54: 14 ~ "' ~ 05:57:07 ;" (0 N N 0 0 '" ¡;¡ t:J ;:> ~, Mark of Sch!umberger - "Safety Me~ting 21 :00 'Start 20 bbl H20 Ahead PRISM'" V2,23 M6ssagøs bb bb e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFichc\CvrPgs _lnserts\Microfihn _ Marker. doc 3, J ~ Àò t\ i DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011830 Well Name/No. KUPARUK RIV UNIT 2T-39 Operator CONOCOPHILLIPS ALASKA INC MD Completion Date 12/3/2001 ~ Completion Status 11685 -- TVD 6050 - 1-01L Current Status 1-01L 5p OvJ. f cl ß ~ Pt ~Ú l API No. 50-103-20392-00-00 UIC N - --- - --~--~ ------ ---- ~- REQUIRED INFORMATION Mud Log No Samples No Directional Survey ..-nõ Ý J..4l . - -----~ --- - -- - - -- - - ~ - - ~~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Electr Digital Dataset Med/Frmt Number Name - J!ír~c:tLJÞtiPIT' Log/ Data Type tõi I YED I ! .- J,tii g I I +1Ö9 i t:bg .-t:Og i t.og I>Ðg I !.L-og ItEÓ C I i Log Log Run Scale Media No OTH BS 1 1 OTH BS 1 OTH BS 1 5 Blu 1 5 Blu 1 5 Blu 1 5 Blu 1 5 Blu 1 1 D 'f6729 LIS\!enfiêâHQr) ,. .... . ... $pjtir'l~r ... <......." '.csrØd.ië>(Y'I$!~(' . ~ . . ~ .. . . . ~ ~ v8r~BipM~f~~i' ~~Þ9~è~18ry .' 1p¡ð?~t'i L ";'" ~..... . ,.. .' '.'~ ."" --l?tê$~Úre.~....................... ~mþ~r~t4f~...~'.'. ...(1259s~eNÓt~$."~" (data taken from Logs Portion of Master Well Data Maint) --~ Interval OH / Start Stop CH Received Comments ------- - ------ 0 11462 Case 5/17/2002 1 5 scale 5967 11630 Open 3/13/2002 0 11462 Case 5/17/2002 0 11462 Case 5/17/2002 11 080 11450 Case 10/1/2002 11 080 11450 Case 10/1/2002 11080 11450 Case 10/1/2002 11080 11450 Case 10/1/2002 11 080 11450 Case 10/1/2002 5967 11685 Open 11/1/2002 1,5 scale 1, 5 scale Digital Data: Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity. , - - --_! -. Well Cores/Samples Information: Name Interval Start Stop Sent' ADDITIONAL INFORMATION Well Cored? yfÐ ~ ~ Formation Tops Daily History Received? Ø,N ~N Chips Received? Analysis Received? Received Sample Set Number Comments ~---- - --~- DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011830 Well Name/No. KUPARUK RIV UNIT 2T-39 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20392-00-00 MD 11685 TVD 6050 Completion Date 12/3/2001 Completion Status 1-01L Current Status 1-01L UIC N Comments: Compliance Reviewed By: k\.-c Date: ~ J;:':' ~~.~=:~. -'- "-. f ( y ConocoPh ill ips. Alaska P.O, BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 30, 2003 r"" 'I, 'O"',."" ""," "", ,"'" " ~',,!:_"~)-.~: "... ';' \ > Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ("-:') n (~, ')r~I'1') oJ ¡ , ¡ \,: /J (.)1 lì ¡.. ", 1, ", I' ,/!i,' ;. " r' , . I"~ ',',.'1,',',' ','" . I', , 'I", ,\ \ :,,' \ " , .., \" "¡ Dear Mr. Maunder: Enclosed please find 10-404 Sundry Notices for ConocoPhillips Alaska, Inc., weBs 3F-17 (PTD 1961130), 3K-32 (PTD 1970760), and 2T-39 (PTD 2011830). The Sundry Notices regard cement shoes that were pumped on the surface casing. Please call Nina Woods, or me at 907-659-7224 if you have any questions. } Sincerely, MJ oveland Problem Well Supervisor ConocoPhillips Alaska, Inc. Attachments \ " OH\G\N~L Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 114' 1. Operations Performed: Abandon r ~ ~I STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 0 Suspend D Operation Shutdown D D Repair Well 0 Plug Perforations D D Pull Tubing D Perforate New Pool D 4. Current Well Status: Development - B Stratigraphic D Perforate D Variance 0 Annular Disp. D Stimulate D Time Extension D Other 0 Re-enter Suspended Well D 5. Permit to Drill Number: 201-183/ 6. API Number: 50-103-20392-00 Exploratory D Service D 9. Well Name and Number: 2T -39 8. Property Designation: Kuparuk River Field 11. Present Well Condition Summary: 10. FieldlPool(s): Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: measured 11685' feet true vertical 6050' feet measured 11584 feet true vertical 5996 feet Length Size MD 155' 16" 155' 5899' 9-5/8" 6013' 11128' 7" 11242' 671' 3-1/2" 11683' Plugs (measured) Junk (measured) TVD Burst Collapse 155' 31 07' 5819' 6049' I, " Measured depth: 11358-11370, 11392-11406, 11454-11470' 1:;' ;) ¡r), Ú) 'ì (, ~ 1,1 r) '-' ¡J \; J~'; (Ji, ,J true vertical depth: 5880-5886,5897-5904,5929-5937' Tubing (size, grade. and measured depth) 3-1/2" , L-80, 11012' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 525' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 2900 2900 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: Oil0 GasDWAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA it C,O. Exempt: 303-202 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations _X Contact Printed Name Oil-Bbl 750 750 Casin Pressure 700 700 Tubin Pressure 300 300 WDSPLD Signature Problem Well Supervisor 659- 7224 Date 4/3P/ ~ Pre ared b Sharon AI/su -Drake 263.4612 I', '\: .'1, ,,1 , ' I' ( 1,_r:'~l~:~LU\~IJ¡li\'-): (QIÎ, . 'i) 1 \Q)1t:\r - SUBMIT IN DUPLICATE 2T -39 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 8/21/2003 Pumped 40 bbls of 15.8 ppg cement w/ 148.6 bbls diesel freeze protect down the OA (10-5/811 annulus) Cement top is @ 5433' MD RKB for a 580' Cement column 8/24/2003 MITOA post OA cement shoe downsqueeze - passed w/1800 psi, T/I/O = 200/1000/500 Pressure up OA with diesel to 1800 psi, start MITOA T/I/O= 200/1000/1800, 15 minute reading T/I/O= 200/1000/1750, 30 minute reading T/I/O= 200/1000/1720 ,«." ," .'1 ( ( ~ ConocoPh ill ips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 20, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih A venue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Sundry Notices for ConocoPhilIips Alaska, Inc., wells 2T-39 (PTD 2011830) and 3K-32 (PTD 1970760). The Sundry Notices regard pumping a cement shoe on the surface casing. Please call Nina Woods, MJ Loveland, or me at 907-659-7224 or 7043 if you have any questions. Sincerely, ;J~eI~C~ JeITY Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. Attachments E.#E:~'L.I' E,,~,-....'r)'1 ,,' ,""~,, 1\ 1\ """''.' ,I;\" JUL 2 )1 2003 A~aska Oil 8~ Gmt: Com; r:,rh'rr¡¡-tlilç:(';.~1"1)1 . -Ui""",,",,"";H~,,I,.¡ !htdmw~~g€'. ORiG\NAl ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 .. 1. Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Suspend D Repair well D Pull Tubing D P. O. Box 100360 7. KB Elevation (ft): RKB 114' 8. Property Designation: Kuparuk River Field 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 11685' 6050' 11584 Casing Length Size CONDUCTOR SURFACE 155' 5899' 16" 9-5/8" PRODUCTION LINER 11128' 671' 7" 3-1/2" Perforation Depth MD (ft): 11358-11370, 11392-11406, 11454-11470' Packers and SSSV Type: no packer SSSV= NIP 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Perforate D Variance D Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Nyrlíber: 201-183 V 6. API Number: / 50-103-20392-00 9. Well Name and Number: 2T -39 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5996 MD Operation Shutdown Plug Perforations D D 0 Perforate New Pool 4. Current Well Class: Development - 0 Stratigraphic 0 Exploratory 0 Service D TVD 155' 6013' 155 11242' 11683' 3107 5819 6049 Perforation Depth TVD (ft): Tubing Size: 5880-5886,5897-5904,5929-5937' 3-1/211 Packers and SSSV MD (ft) August 1, 2003 Date: SSSV= 525' 13, Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG D GINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~ry Dethlefs Signature C / ~ ~q c. ~ / ,. Sundry NU'J'Ø, ..1-.1 Ff'~e~'~ I~III-'~'"", Location I r.anlÏe¿. 0. IJ :~..iii ~"~." ~I \, ,l M"",.., ,I,¡.""",,p Otl1er: ~~ 5\-ì r", "1'e ~ o~ ~P~~' \¡k ~ ~ \~"~J ~ ~ 2 " 200,3 . . " 'U¡",;:o:" Subsequent Form Requ' red '. ~ i f\ L\ t~tiI1:r¡:'ï';"~¡I~"'" ',I ~ \J "\ '-~c,c C;¡~jb Approved by: ~ ~ ~COMMISSIONER ~~~~g~~~~ION Form 1 ~;;;::d 2ho03 . "'-..~ Contact: Title: Phone 659-7043 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test 0 ORIGIN;~f RBDMS SF l Annular Disp. D Other 0 Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 11012' Service D Plugged 0 WINJ D Abandoned D WDSPL D Jerry Dethlefs @ 659-7043 Problem Well Supervisor Date ?'; ~~t'...s Date: "7.2Z{) S SUBMIT IN DUPLICATE JUl 2 ~ 2003 (' ( ConocoPhillips Alaska, Inc. Kuparuk Well 2T -39 (PTD 2011830) SUNDRY NOTICE 10-403 REQUEST 7/20/03 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Kuparuk producing well 2T -39. 2T-39 was drilled in November 2001 and has been in production since that time. A surface casing cement shoe was not pumped at the time of original completion. In March 2002 Operations personnel reported signs of IA x OA communication due to the number of bleeds on the GA. The OA and IA appear to track in pressure. As part of the diagnostic process an MIT -OA was attempted to test the integrity of the surface casing. Since there is not a cement shoe, fluid can readily be pumped into the OA and the pressure will leak off. The casing packoffs appear to have integrity so the IA x OA communication may be downhole. A cement shoe is desired for both diagnostic testing and to prevent potential gas migration out the bottom of the casing. The proposed plan includes pumping a cement shoe and performing an MIT -OA to test the surface casing integrity. . , NSK Problem Well Supervisor 07/20/03 (' ~PHILLIPS Alaska, Inc. ~ A.Subsidiary of PHILLIPS PETROLEUM COMPANY ( KRU 2T-39 TUBING 2T-39 (G-11012, API: 501032039200 Well Tvpe: PROD Angle @ TS: 59 deQ @ 11356 00:3.500, SSSV Type: Nipple Orig 11/12/2001 Angle @ TO: 58 deg @ 11685 10:2.992) Completion: Annular Fluid: Last W/O: Rev Reason: Taa by ImO I Reference Loa: Ref Loa Date: Last Update: 4/27/2002 Last Taa: 11462 TO: 11685 ftKB Last Taa Date: 4/23/2002 Max Hole AnQle: 72 deQ @ 2139 CasinaStrina - ALL STRINGS Description Size TOD Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 155 155 62.50 H-40 WELD SURFACE 9.625 0 6013 3107 40.00 L-BO BTC SURFACE D PRODUCTION 7.000 0 11242 5819 26.00 L-80 BTC-M (~13, LINER 3.500 11012 11683 6049 9.30 L-80 SLHT 00:9.625, Tubina StrinG - TUBING Wt40.oo) Size I Top I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 I 11012 I 5695 I 9.30 I L-80 I EUE8rdMOD , Periorations Summary ~ Interval TVD Zone Status Ft SPF Date TvDe Comment ." 11358 - 11370 5880 - 5886 C-4 12 6 12/6/2001 IPERF 2.5" HSD BHPJ 60 deg ph ~OOUCTION f~ 11392-11406 5897 - 5904 A-3 14 6 12/4/2001 IPERF 2.5" HSD, BHPJ 60 dea ph (G-11242, :,', 11454 - 11470 5929 - 5937 A-2 16 6 12/4/2001 IPERF 2.5" HSD, BHPJ 60 dea ph ,,: ,,'!, ' .: 00:7.000, i "~. ~, Stimulations '& ",T reatmel1ts .,'., ,', ,' ~,' .,....'~ ".,.', , .,.,' ,.",'.. ,',' .,.'."",,'," '," ..'.", ',' ,'" " Wt26,00) "',,', Interval Date Type Comment , " : I '," 11358 - 11470 12/10/2001 FRAC INITIAL A&C SAND FRAC, 279,600# 16/20 CARBOLlTE, 12 PPA ON PERFS , Gas Lift MandrelsNalyes . St MD TVD Man Man V Mfr V Type VOD Latch Port TRO Date Vly Gas Lift Mfr Type Run Cmnt lAandrelNalve 1 3960 2346 CAMCO KBUG-M GLV 1.0 BK 0.156 1249 2/18/200 3 (8745-8746, : 2 7013 3556 CAMCO KBUG-M GLV 1.0 BK 0.188 1281 2/18/2001 00:5.390) ' . 3 8745 4476 CAMCO KBUG-M GLV 1.0 BK 0.188 1275 2/18/2001 " .." 4 10012 5142 CAMCO KBUG-M GLV 1.0 BK 0.188 1266 2/18/2001 , : 5 10936 5653 CAMCO I\.tv1G OV 1.5 RK 0.188 0 2/17/2001 Other, ( :)luas.eauiD..etc; ,-JEWELRY , " , DeDth TVD Type Description ID '--7 525 524 NIP CAMCO 'OS' NIPPLE w/2.821 NO GO PROFILE 2.812 i," " 10982 5679 NIP CAMCO '0' NIPPLE WITH2.75" NO GO PROFILE 2.750 10983 5679 JOINT 2.992 "", 11021 5700 SEAL SEAL ASSEMBLY ABOVE & BELOW MULESHOE 0.000 " '. n "'"" : NIP (10982-10983, 61' 00:4.520) JOINT - (10983-11021, 00:3.500) ïI LINER (11012-11683, 00:3.500, Wt:9.30) Perf .f-"¡L (11358-11370) + I-r f- r+ Perf + ~ (11392-11406) +- K- Perf * ~ r+ (11454-11470) ¡(- , ( ,f :1 aOJ-1 f53 11~51 WELL LOG TRANSMr I'T AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn,: Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage,Alaska 99501 October 31, 2002 RE: MWD Formation Evaluation Logs 2T -39, AK-MM-11168 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Speny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2T -39: Digital Log Images 50-103-20392-00 1 CD Rom ~~ RECEIVED NO V 01 :~,'1"1:,1 . ... "" <";.. A1~DLQ 0'/ f) ,""..,r, c",r,... tl ~ 1...:..,,',' ,: /"',"', ,-,c, "".. . 1.:, ...'.. 'J ~.", , '. '1",' '" . ~ """""""'¡'::::!'!'J!1 J'tilê"""'h"""" .. J .'1 ¡"'I:;..:'_;' :: 09/23/02 Schlumbel'gep NO. 2433 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ---~. Well Job# Log Description Date BL Sepia CD Color 2H-09 (S?:,,;~ ~q PRODUCTION PROFILE 08/29/02 1 10-09 IVLI-JQ!L INJECTION PROFILE 09/04/02 1 1C-125 ,:;}C {- J crq ~ INJECTION PROFILE ~ 09/11/02 1 2H-12 I5tFi--dbc:¿ PRODUCTION PROFILE 09/07/02 1 2T -39 ~ ()j. {~~!l... PRODUCTION PROFILE 09/09102 1 1B-04 1< ~l-n (II S INJECTION PROFILE 09/04102 1 3A-12 J ~...~3 q STATIC PRESSURE SURVEY 08/31/02 1 3A-13 I C:;.... ~ ~ I STATIC PRESSURE SURVEY 08/31/02 1 2K-02 f 'c - I ~ 1 PRODUCTION PROFILE 09/08/02 1 3N-07 / t'J ' O~ %'" LEAK DETECTION LOG 08/30/02 1 2M-01 I ..:J- 1 O~ PRODUCTION PROFILE 09/13/02 1 1C-119 ~DJ - f: 9 INJECTION PROFILE 09/05/02 1 -~ 5IGN~ ~- DATE: RECE'VED OCT 0 1 200l AI... Oil' Gal Coni. ConII8IiJn AndøID8 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 05/16/02 Scblum~erger NO. 2082 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Company: Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk "--" Well Job # Log Description Date BL Sepia CD Color ~-" 1 C-119 ~ ~n' -,~q DRIFT & TAG 04/14/02 1 1 1 C-133 ~ û/-O 7 1 PRESSURE/TEMP LOG 04/14/02 1 1 1 C-133 ..v INJECTION PROFILE 04/14/02 1 1 1 D- 1 09 IQ 7-::J;<C; STATIC BOTTOM HOLE PRESSURE 04/11/02 1 1 1 D- 119 C;>DI-I~ q STATIC BOTTOM HOLE PRESSURE 04/11/02 1 1 1 D-132 Iq~ )-1;:),) TEMPERATURE WARMBACKS 04/18/02 1 1 1 D- 132 ,v INJECTION PROFILE 04/18/02 1 1 1 R-35 :::::::I D)-~IO PRESSURE TEMPERATURE 04/21/02 1 1 2D-02 1< >ll/ - 15;> PRESSURE-TEMP STATIONS 04/16/02 1 1 2P-431 ;::. Dd -o5? PERF RECORD/STATIC SURVEY 04/19/02 1 1 2T-39 ... nl-JR'L~ PRODUCTION PROFILE 04/23/02 1 1 ,.., 3B-14 J'lJ 'S-oac.l PRESSURE/TEMP LOG 04/15/02 1 1 3C- 15 Ctr~..~(')1"\ PRESSURE/TEMP 04/13/02 1 1 f3; ,1\11 . .1 ".- D SIGN~ (t ~pr;) DATE: t..1.~Ý 1 7 2002 AI asks au & Gas Cons. Commis8tO n Ancbor8ge Please sign and return one copy of this transmittal to Sherrie at the åbove address or fax to (907) 561-8317. Thank you. cSJo J-ß .3 ~ ( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 12, 2002 RE: MWD Fonnation Evaluation Logs 2T -39, AK-MM-11168 1 LDWG fonnatted Disc with verification listing. API#: 50-103-20392-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COpy OF mE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 -1:m lh pJ Signeu . (Á. ¡ / Date: RECEIVED r" .~ R "-I "7 "00 :i-i ~ ....,' L 2 Alaska Oil & Gas Cons. Commision Anchorage (' ("'" II PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 February 12, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2T-39 (201-183) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk we1l2T-39. If you have any questions regarding this matter, please contact Scott Lowry at 265-6869. Sincerely, ~~ Drilling Engineering Supervisor PAl Drilling CMlskad RECE \\1 EO f£B 1 3 2007- commission I'\å' o.GaSC~s. A'æ'f.a V"~ or. ~,,~ ORIGINAL ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. location of well at surface ,"-" "..., -. 265' FSL, 556' FWL, Sec. 1, T11N, R8E, UM :_'~".:. '.. '~"'(ASP: 498945, 5970245) At Top Producing Interval ~ ;'~' ',', , 1015' FSL, 1991' FWL, Sec. 3, T11 N, R8E, UM ,~.-tz..~;r-r2L' (ASP: 489820, 5971002) . '\;;"'" - "'. At Total Depth i. "~:(j'J...,~'-" , 1040' FSL, 1711' FWL, Sec. 3, T11N, R8E, UM "'~~-:'.~~" (ASP: 489540, 5971024) 5. Elevation in feet (indicate KB, DF, etc.) 6. lease Designation and Serial No. RKB 34' feet ADL 25568 & 25569 I ALK 2666 12. Date Spudded October 14, 2001 17. Total Depth (MD + TVD) 11685' MD 1 6050' TVD 22. Type Electric or Other logs Run GR/Res/Neu Dens 23. CASING SIZE WT. PER FT. 151.5# 40# 26# 9.3# 16" 9.625" 7" 3.5" Suspended D Service D Abandoned D 7. Pennit Number -~i"'"'ì""T'\ ' "" "',l!ÍIIoi\ ~'~', i.~:':',. "~: 8. ' ,.,}I:)j,~j':u\,"ii"" .'" "'"';"'-'-"- " - ....... ..- .'" 50-103-20392-00 9. Unit or lease Name ~ ~\ l1 . "11. ~ -" . Kuparuk River Unit 10. Well Number 2T -39 11. Field and Pool Kuparuk River Field Kuparuk River Pool 13. Da~:~~~R::;~~~001 14'~~~~:J6~b~~ 15'N~:ter Depth, ::;ff;;:re 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 11584' MD 1 5996' TVD YES 0 No D N/A feet MD 16. No. of Completions 1 21. Thickness of Pennafrost 1573' (approx) GRADE X-65 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 154' Surface 6012' Surface 11244' 11012' 11683' AMOUNT PUllED HOLE SIZE CEMENTING RECORD 5 cu yds High Early 600 sx AS Lite & 659 sx LiteCrete 166 sx Class G wlGasBlok 24" 12.25" 8.5" 6.125" 154 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 11392' - 11406' MD 11454' - 11470' MD 11358' - 11370' MD 27. Date First Production December 25, 2001 Date of Test Hours Tested 1/1/2002 18 hours Flow Tubing Casing Pressure press. 285 psi 1232 28. 25. SIZE TUBING RECORD DEPTH SET (MD) 11024' PACKER SET (MD) 11024' 3.5" 5897' - 5904' TVD 5929' - 5937' TVD 5880' - 5886' TVD 6 spf 6 spf 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Squeeze 11043' to 11243' 97 sx Class G PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing Oll-BBl GAS-MCF 993 1809 Oll-BBl GAS-MCF 1204 2528 CORE DATA Production for Test Period> Calculated 24-Hour Rate> WATER-BBl 16 WATER-BBl 21 CHOKE SIZE GAS-Oil RATIO 124 1451 Oil GRAVITY - API (corr) no available Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 RECEIVED rES 1 3 2002 Alaska Oil & Gas Cons. Commission Anchorage - CONTINUED ON REVERSE SIDE Submit in duplicate lJ' r~ i G. ,'",; ~ N:J fj L '.. r 1\ ¡ ,." ~ ¡ j l ~ R B D M 5 B F l ~(V FEB I 9 2002 ."" 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A 11356' 11370' 11370' 11597' 5879' 5886' 5886' 6003' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Scott Lowry 265-6869 Signed (! Title Drillina Enaineerina Supervisor Date /;L Ed uo 1...... Prepared by Sharon Allsup-Drake I NSTR UCTIONS 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 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 (OF, 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. RECE IVED Item 28: If no cores taken, indicate "none". Form 10-407 FEB 1 ,3 2002 ~¡l r""~ ~ ~i"""'\ ~ ~ ~ ~' ~ I 11)j I :' "¡ (\,.it'!"<'~.,",":¡ir¡\"i,.~,"i """'¡;~' "",.tl~I,1J~- Alaska Oil & Gas Coos. Commission Anchorage (' ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 10/9/2001 00:00 - 03:30 3.50 MOVE DMOB MOBMIR 03:30 - 12:00 8.50 MOVE DMOB MOBMIR 12:00 - 00:00 12.00 MOVE DMOB MOBMIR 10/10/2001 00:00 - 00:30 0.50 MOVE DMOB MOBMIR 00:30 - 09:30 9.00 MOVE MOVE MOBMIR 09:30 - 10:00 0.50 MOVE OTHR MOBMIR 10:00 - 00:00 14.00 MOVE MOVE MOBMIR 1 0/11/2001 00:00 - 02:00 2.00 MOVE MOVE MOVE 02:00 - 12:00 10.00 MOVE OTHR MOVE 12:00 - 13:30 1.50 MOVE OTHR MOVE 13:30 - 22:00 8.50 MOVE OTHR MOVE Page 1 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 1 0/1 0/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations Prep to skid floor. Disconnected service lin es under rig floor & in stair tower, PJSM. Skid floor in , installed skid rail clamps, pr ep to separate modules. Separated modules & moved sub module away from power modu Ie & work on ball mill maintenance. Moved rig camp to 2T pad (from 12:00 hrs to 14:45 hrs). Layed down BOP in moving cra die. POsition sub module for Booster Tire i nstallation. Install booster wheel assy on r ear of Sub Module. Remove off drillers side rear tires & install on front Booster. Move d Ball Mill to 2T pad. Load trucks out, post ioned Power Module & removed mats. Prep to move Sub & Power modules to 2T. PJSM, checked air pressure in tires = 120 P s i. Moved Sub & Power Modules 7.5 miles from 2N pad to pull off. Wait on traffic + check air pressure on tires = 140 psi. Moved Sub & Power Modules from 7.5 - 10.2 miles from 2N pad (to 2M pad). Wait on traf fic & moving mats around rig (1 hr). Moved modules to 2A pad and waited for mats to be laid on low spot (2 hrs). Continued moving rig (roughly 1 mile to 2T pad). Finished moving Sub & Power Modules to 2T pad. Total Distance of Rig Move 16.1 mile s. (Cost of move added in yesterday). Unload pipe shed. Install both wind wall bu bbles on sub module & install spreader links on power module. Remove rear booster wh eel assy from sub. Put BOP stack in cellar. Install annular diverter spool + adapter fla nge. Set BOP stack on stump. Put surface annular preventer in cellar & hang from brid ge cranes. Hang cellar scaffold ladde'rs, po sit ion power module near sub module. Position sub module to move over 2T-39 con ductor. Attempt to back onto 2T-39 and una ble to position over well because of Thermo Syphon on driller's side. Contacted proper personnel and mobilized cr ane to remove thermo syphon. Once crane a rrived decided to remove "red iron supports" on power module and attempted to back in to well... still not clear of syphon. Attempt ed to pull inner tube on thermo syphon, froz en and would not pull. Obtained permissio n from Nabor's Anchorage to remove part of walkway on power module. Removed lower s ection of beaver slide with crane in order to Printed: 1/16/2002 2:22:01 PM (' (" PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 10/11/2001 13:30 - 22:00 8.50 MOVE OTHR MOVE 22:00 - 00:00 2.00 MOVE POSN MOVE 10/12/2001 00:00 - 01 :30 1.50 MOVE POSN MOBMIR 01 :30 - 04:00 2.50 DRILL RIRD MOBMIR 04:00 - 05:00 1.00 DRILL RIRD MOBMIR 05:00 - 09:30 4.50 MOVE OTHR MOBMIR 09:30 - 11 :00 1.50 DRILL RIRD MOBMIR 11 :00 - 17:00 6.00 DRILL RIRD MOBMIR 17:00 - 00:00 7.00 DRILL MOBMIR RIRD 10/13/2001 00:00 - 01 :00 1.00 DRILL RIRD MOBMIR 01 :00 - 02:00 1.00 DRILL PULD MOBMIR 02:00 - 03:00 1.00 RIGMNT OTHR MOBMIR 03:00 - 05:00 2.00 DRILL PULD MOBMIR 05:00 - 05:30 0.50 WELCT BOPE MOBMIR 05:30 - 13:30 8.00 DRILL PULD MOBMIR 13:30 - 15:00 1.50 DRILL PULD MOBMIR 15:00 -19:30 4.50 RIGMNT RGRP MOBMI R 19:30 - 20:00 20:00 - 20:30 0.50 DRILL CIRC MOBMIR 0.50 RIGMNT RGRP MOBMIR 20:30 - 21 :00 0.50 DRILL CIRC MOBMIR 21 :00 - 22:00 1.00 DRILL DRLG MOBMIR Page 2 0118 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description 01 Operations clear 2nd well house on driller's side. Position rig 'close' to over hole & slide rig mats under rig. Spot sub module over 2T-39. Due to 15 mph wind limit on removing well h ouses, decided to face diverter line to Sout h rather than North as originally planned. T his was to enable us to continue operations while waiting on wind. Spot power module. Skid floor over hole & installed hand rails & attached power module to sub module. Skid floor off of hole to make room for cran e to remove well houses. Hooked up service line between modules & R/U cellar berm. PJSM. Used crane and assisted production dept to remove 2 well houses from wells 201 & 9. Safely done. Placed houses on Sout h end of pad. Skid floor back over hole & hooked up servi ce lines & installed cattle shoot using PEAK crane. R/U diverter + diverter line towards south. Spot ball mill & R/U same. Installed necess ary spill prevention berms & drip pans. Continued R/U saver sub + bails + elevators + slips for 8" BHA. R/U mud lines & koome y Ii n es. Finished N/U diverter line. Load drillpipe in shed. PRe-Spud checklist & walkaround. PJSM, topdrive safety inspection. Turn on g Iycol pumps & check for leaks. P/U 5" drillpipe. Test diverter & accumulator test. P/U 5" drillpipe. P/U BHA as per directional driller. Turned on auger and sheared flight. Change r out flight. (Auger turned on while frozen i n spots). Filled stack & blew pop-off, OK. Repaired topdrive ISBOP. (During summer maintenance, reassembled backwards). Rep aired ISBOP. Filled hole & flowlines with mud and checke d for leaks, OK. Ran UBHO sub above bit without motor & RI H to +1- 143', tagged fill. Cleaned out con ductor to 155' RKB and new formation from 155 - 190'. (Cleaning out like this was a pr ecaution in order to check angle of conducto r due to close proximity of two producing we lis). Gyro @ 173' md = 1deg @ 355 azimut h. In addition, prior to spudding production Printed: 1/16/2002 2:22:01 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/13/2001 10/14/2001 10/15/2001 10/16/2001 ( (' PHilliPS ALASKA INC. Operations Summary Report 2T -39 2T -39 ROT - DRILLING Nabors Nabors 16E Sub From - To Hours Code Code Phase 21:00 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 01 :30 01 :30 - 03:30 03:30 - 05:00 05:00 - 05:30 05:30 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 12:00 12:00 - 13:00 13:00 - 13:30 13:30 - 14:00 14:00 - 00:00 00:00 - 00:00 00:00 - 08:30 08:30 - 09:30 09:30 - 1 0:45 10:45 -11:00 11 :00 - 14:00 14:00 - 15:15 15:15 - 15:45 1.00 DRILL 0.50 DRILL 1.50 DRILL 1.50 DRILL 2.00 DRILL 1.50 DRILL 0.50 DRILL 3.50 DRILL 0.50 DRILL 0.50 DRILL 2.00 DRILL 1.00 DRILL 0.50 DRILL 0.50 DRILL 10.00 DRILL 24.00 DRILL 8.50 DRILL 1.00 DRILL 1.25 DRILL 0.25 DRILL 3.00 DRILL 1.25 DRILL 0.50 DRILL DRLG MOBMIR TRIP MOBMIR PULD MOBMIR PULD SURFAC DRLG SURFAC CIRC SURFAC TRIP SURFAC CIRC SURFAC CIRC SURFAC TRIP SURFAC CIRC SURFAC TRIP SURFAC CIRC SURFAC SURV SURFAC DRLG SURFAC DRLG SURFAC DRLG SURFAC CIRC SURFAC DRLG SURFAC CIRC SURFAC CIRC SURFAC WIPR SURFAC WIPR SURFAC Page 3 of18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations wells 7 & 8 were shut down from gas lift & a nnulus pressures bled down. Once we clear these wells, we will immediately notify prod uction so they can be brought back on line. POOH to pick up motor. . Change out BHA. « Please note that RIG A CCEPTED 23:00 hrs on 11 Oct 01 after discu ssions between co. man and lead tool pusher over problems getting onto well, etc.) Handled BHA. Drld 12-1/4" hole fl 190 - 326' md. AST= O. 75 hrs & ART= 0.50 hrs. Flow line plugged off with clay. Try to clea r line and possum bellies. Ran gyro survey. POOH to conductor shoe @ 154.4'. Cleaned flow line + possum bellies of clay. Circulated @ 150'. TIH. Circ'd 5 min & flow line plugged off again. Ran gyro survey and gyro not seating proper Iy. The gyro has a lead tattle tail that help s to identify if it has seated properly in the UBHO sub and it does not show it has. Tool face does not look correct. Decided to P OOH to check UBHO sub. POOH. Found a red rag in the UBHO sub. Cleaned flow line & possum belly. Ran gyro survey. Directionally drld 12-1/4" hole fl 326 - 750'. AST= 2.25 hrs & ART= 2.25 hrs. Product ion informed it was OK to bring wells 7 & 8 back onto production @ 21 :00 hrs. Directionally drilled 12-1/4" hole f/ 750 - 26 54' md 11842' tvd. ART=6.0 hrs & AST=8 hrs. Drld 12-1/4" hole fl 2654 - 3501' md. ART= 4.5 hrs & AST=1 hr. Made connection & went to drilling and lost 35 bbls of mud in 10 min. Fluid level static with pumps off. Added barofibre fine & cir culated downhole. Drld 12-1/4" hole f/ 3501 - 3595'. Losses g one as best we can tell. This is the plann ed wiper trip depth. Cleaned mud pump suction screens due to L CM. Circulated 4 bttms up + two hi-density swee ps. Shakers clean. Flow checked well, no flow. POOH to 2937'. Hole taking fluid properly. Had a spot at 2845' that we needed to pump & rotate thru to clean up. Decided to go ah Printed: 1/16/2002 2:22:01 PM ( (" Page 4 of18 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 10/16/2001 15:15 - 15:45 0.50 DRILL WIPR SURFAC 15:45 - 16:00 0.25 DRILL WIPR SURFAC 16:00 - 00:00 8.00 DRILL WIPR SURFAC 10/17/2001 00:00 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 10:00 10:00 -13:30 13:30 - 14:30 14:30 - 16:00 16:00 - 16:30 1.50 DRILL WIPR SURFAC 0.50 DRILL WIPR SURFAC 1.00 DRILL PULD SURFAC 1.00 RIGMNT RSRV SURFAC 1.00 DRILL WIPR SURFAC 5.00 DRILL WIPR SURFAC 3.50 DRILL 1.00 DRILL DRLG SURFAC CIRC SURFAC 1.50 DRILL 0.50 DRILL DRLG SURFAC CIRC SURFAC Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations ead and pump the slug. POOH to 2749' md. POOH to 2729' and had a tight spot. Unable to ream thru and had to pump and rotate. Decided to go ahead and keep pumping out of the hole until we had the slug out of the annulus... this put us around 2185'. Tried to POOH but had to pump out to 635'. At 635', while pulling & rotating with pumps @ 40 spm... lost returns. Stopped pumping. Torque irratic 3-10,000 ft-Ibs. Pumped at 20 spm and no returns. Continued POOH wit h annulus swabbing and pumping the swabbe d volume down the dp. Had to stop rotating due to torque, POOH OK. As a precautio n, adding barofibre fine into active system. Finished POOH f/ 60S'. At 60S', unable to rotate and only pumping at 15-17 spm the vo lume of mud swabbed on each stand. Fortun ately, no problem going down on connection s, when pulling up, swabbing & when going down, push mud away... a complete piston. This occurred from 605' and until in conduct or shoe. Formation acts plastic in this inte rval. Handled BHA. Top stabilizer + 4' above it t otally balled up with clay & wall cake. Low er stabilizer & bit balled completely as well with same. Took some time to clean them up. Changed motor setting from 1.83 deg to 1.15 deg. Changed bits as well. Serviced topdrive & drawworks. TIH and pushing mud away from conductor s hoe until below 60S', kept annulus full with trip tank.. On that last stand, actually lost some down weight (once again, acts like pi astic clay). Once below this, hole displacin g proper fluid. Continued in hole & had to idle one pump at 50 spm & rotate at 50 rpm at 700' & 1359'- 1800'. Continued in hole to +/- 2200' and c irculated bottoms up. Got a lot of wipings across the shakers. Continued to bottom. Drld 12-1/4" hole f/ 3595 - 3827'md. Cleaned mud pump suction screens. Since b eing back on bottom, we have been adding 3 - 6 bags/hr of Barofibre Fine. Drld 12-1/4" hole f/ 3827 - 3938' md. Cleaned mud pump suction screens again. Stopped adding Barofibre into active system as PVT has looked good for some time now. Printed: 1/16/2002 2:22:01 PM t: ( Page 5 of 18 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 10/17/2001 16:30 - 23:00 6.50 DRILL DRLG SURFAC 23:00 - 00:00 1.00 DRILL CIRC SURFAC 10/18/2001 00:00 - 00:30 0.50 DRILL CIRC SURFAC 00:30 - 09:00 8.50 DRILL DRLG SURFAC 09:00 - 14:30 5.50 DRILL CIRC SURFAC 14:30 - 17:00 2.50 DRILL WIPR SURFAC 17:00 - 17:30 0.50 DRILL WIPR SURFAC 17:30 - 23:30 6.00 DRILL WIPR SURFAC Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations Drld 12-1/4" hole fI 3938 - 4442'. Total for day ART=5.75 hrs & AST=1.75 hrs. After a connection @ 4438' +1-... we slid 4' and pit watcher called to say we were loosin g mud (drlr did not note as we had just start ed dumping mud as well). Drlr stopped pum ps & went to pick up, overpull. Stopped pu mp & +1- 250-300 psi trapped on standpipe, bled oft. Pulled up with some overpull & br oke out new stand (no room to work). Made up single to have room to work. Picked pipe up and rotated and staged pumps up to 150 spm over 30 minutes or so. Watched PVT at each staging of the pump. Hole giving fl uid back to us, estimate we lost +1- 40 bbls of mud (during this staging up of pumps, go t back 35 bbls). Preparing to drill ahead. Finished observing well and staging flowrate back up to full drilling rate... no losses no w. Hole giving mud back. Drld 12-1/4" hole fI 4442 - 5003' md. Wiper trip depth. (At 02:45 a.m., had another 30 bbls of mud loss downhole... this while drl g and no changes in pump press, etc. After shutting down to check, well back flowing, brought pumps back up to full speed and no losses). ART=4.5 hrs & AST=1.25 hrs. Increased flow rate to 639 gpm, no losses. Circulated bottoms up, pumped 30 hi-dense sweep & circulated it out. Pumped another 30 bbl hi-dense sweep. Total circulation 0 ver 4 bttms up. Racked 1 stand in derrick e very hour, to avoid washing out hole in one spot. Flow checked well, no flow. POOH to 4444', hole not swabbing. Had spo t @ 4409' that we had to work. Had to use pumps & rotation to clear it out... due to 10 osing string wt going down without pumps. Cleaned up OK. POOH to 4225' and had to do the same as above. POOH to 3972' and t hen had to circ & rotate to clean it up... sa me as above. Due to the time consumed g oing back and forth from trip tank or to mud pits... decided to go ahead and PUMP OUT to point of last trip. POOH fI 3595 - 3399'. Had to pumplrotate on next stand. POOH to 3219'. One next stand, had to pump & rotate again. Decide d to go ahead and pump out of the hole due to time factor. Pumped out of the hole to surface. So no s pots or increase in torque. Hole looked fin e. Printed: 1/16/2002 2:22:01 PM ( ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 10/18/2001 23:30 - 23:45 0.25 DRILL WIPR SURFAC 10/19/2001 10/20/2001 23:45 - 00:00 00:00 - 01 :00 01 :00 - 04:00 04:00 - 05:00 0.25 RIGMNT RSRV SURFAC 1.00 RIGMNT RSRV SURFAC 3.00 DRILL WIPR SURFAC 1.00 DRILL CIRC SURFAC 05:00 - 07:00 2.00 DRILL WIPR SURFAC 07:00 - 08:00 1.00 DRILL CIRC SURFAC 08:00 - 23:15 15.25 DRILL DRLG SURFAC 23:15 - 00:00 00:00 - 04:30 04:30 - 04:45 04:45 - 05:00 05:00 - 10:00 10:00 - 14:15 0.75 DRILL 4.50 DRILL CIRC SURFAC CIRC SURFAC 0.25 DRILL 0.25 DRILL OBSV SURFAC OTHR SURFAC 5.00 DRILL TRIP SURFAC 4.25 DRILL TRIP SURFAC Page 6 of18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations Cleaned stabs & bit, very very little amount of clay on top or bttm stab... small amount on bit. Bit in good shape. Serviced topdrive & dwwks brakes. Finished servicing topdrive + brakes + dwwk s. TIH & had to wash down thru 1254' - 1534'. Washed/reamed down at 50-70 rpm & 30-50 spm on pumps. Continued TIH to 2560'. Circulated hole clean at 2560'... precaution ary to make sure we don't have too much wi pings sturred up in annulus when we get to bttm and have circ'g problems. Cleaned qu ite a bit of wipings across the shakers. TIH no problems. Took check shot MWD sur vey @ 4061' (new probe & pulsar). Circulated and cleaned hole up & raised YP to 41-44, prior to drlg. Drld 12-1/4" hole fI 5003 - 6025' md /3111 tvd. ART= 8.5 hrs & AST= 2.25 hrs. ROP s lowed down the last couple hundred of feet t 0 50-70 ftlhr. Torque OK, just seems like f orm hardened up. At the start of a new st and & preparing to slide @ 5755'... lost 30 bbls of mud. Pump pressure did not show p acking off and torque was OK. Stopped pum ps, giving mud back. Continued drlg and no more losses. As a precaution, we added Barofibre fine @ 6 bags/hr from 5700' to TD (in case we saw the Tobasco sands). Circ'd & swept hole prior to wiper trip. Circulated 5 bttms up @ 653 gpm & pumped 2 hi-dense sweeps. Shakers clean. Racke d 1 std of dp per hour. Flow checked well, no flow. Blew down topdrive & lines. Prep flowline & trip tank for POOH. POOH and saw each tooljoint go thru a keys eat in the new hole section. 50-60k extra d rag pulling thru each one. Cleared all of t hem up by wiping except @ 5040'. Had to p ump & rotate to clean it up going down. We had pulled up thru it but going down to che ck it, stacked out the dp. Cleaned up OK. Decided to try and pull some more in old ho Ie and no longer seeing each tool joint. P OOH to +/- 3000' and unable to work thru. Had to pump & rotate to clear spot @ 3000'. Had to work some more spots & taking too much time so we decided to pump out with 604 gpm to 1158' and 497 gpm up to 700'. Continued POOH from 700' to surface with Printed: 1/16/2002 2:22:01 PM ~ ..... ~ (PHILUPS) lUi ,.". Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/20/2001 10/21/2001 ( ( PHilliPS ALASKA INC. Operations Summary Report 2T -39 2T -39 ROT - DRILLING Nabors Nabors 16E From - To Hours Code Sub Phase Code 10:00 - 14:15 14:15 - 15:30 15:30 - 16:30 16:30 - 17:00 17:00 - 21 :30 21 :30 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 05:00 05:00 - 06:00 06:00 - 08:00 08:00 - 13:30 13:30 - 00:00 4.25 DRILL 1.25 DRILL TRIP SURFAC PULD SURFAC 0.50 DRILL 1.00 RIGMNT RGRP SURFAC PULD SURFAC 4.50 DRILL 1.00 DRILL 1.00 DRILL TRIP SURFAC TRIP SURFAC PULD SURFAC 0.50 WELCTL BOPE SURFAC 2.00 DRILL 1.00 RIGMNT RSRV SURFAC PULD SURFAC 2.00 DRILL 1.00 DRILL 2.00 DRILL 5.50 DRILL 10.50 DRILL TRIP SURFAC CIRC SURFAC TRIP SURFAC CIRC SURFAC TRIP SURFAC Page 7 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations out pumps & no problems & no swabbing. Cleaned stabs (top one balled a fair amount and bttm stab & bit marginally). LID top s tab. Removed pulsar & probe. Reset motor angle to zero. Flushed motor. L/D mtr. Adjusted ISBOP and worked on link tilt actu ator to topdrive. P/U hole opener & placed stabilizer 60' up a bove between flex collars. Ran hole opener & had to wash/ream spots @ 1345-50' & 1434' & 1548' & 1648'. Conti nued in hole to 1957' (thru curve). Decide d to POOH to 1200' above first spot & check curve again prior to RIH to bottom. Had t 0 work spot @ 1482' when POOH to 1200'. Ran back in the hole thru the curve & had t 0 wash/ream spot @ 1360' & 1434'. Unable to work down without pumps or with pumps or rotating with pumps. After working for 1 0-15' decided to stop before we washed this area out too badly. Spot @ 1434' is solid & made no progress at all, hole clear comin g up. POOH to surface, no swabbing. Changed out BHA & prep to re-run the motor Spoke with AOGCC due to changes in what w as mentioned to them to get BOP test exten sion. Decided to go ahead and do diverter test. PJSM. Serviced topdrive & drawworks. Cle an strip-omatic. Make up motor BHA & MWD again. Re-ran la st bit. Shallow test motor & MWD. Tripped in hole and washed/reamed thru spo ts @ 1343' & 1434'. Continued in the hole to 2845'. Circulated bottoms up until shakers cleaned up. Blew down topdrive & mud lines. TIH f/ 2845 - 6025', no fill. Circulated 4 bttms up while pumping two 30 bbls hi-dense sweeps. Once hole clean, rai sed mud wt from 9.6+ to 9.9 ppg and raised vis up to +1- 150... gave us 51 VP. Flow ch ecked well, no flow. POOH to 4917' and hole not taking proper fil I. The keys eats we had seen on last trip fro m TO to 5000' are much much better now. Barely see them. Pumping out of the hole at 604 gpm & 50 rpm. At +/- 1200 slow gp m down to 497 gpm & at 700' slowed it down to 426 gpm. While pumping out from +/- 80 0'-605' we had a lot of running sand coming Printed: 1/16/2002 2:22:01 PM ( (' PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 10/21/2001 13:30 - 00:00 10.50 DRILL TRIP SURFAC 10/22/2001 00:00 - 02:00 2.00 DRILL PULD SURFAC 10/23/2001 02:00 - 04:00 04:00 - 07:30 07:30 - 11 :30 11 :30 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 04:15 04:15 - 05:00 05:00 - 05:30 05:30 -11:45 2.00 CASE RURD SURFAC 3.50 CASE RUNC SURFAC 4.00 CASE OTHR SURFAC 12.50 CASE RUNC SURFAC 1.50 CASE RUNC SURFAC 1.00 CASE CIRC SURFAC 0.50 CASE RUNC SURFAC 1.00 CASE CIRC SURFAC 0.25 CASE RUNC SURFAC 0.75 CEMEN CIRC SURFAC 0.50 CEMEN PULD SURFAC 6.25 CEMEN CIRC SURFAC Page 8 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations across the derrick shakers. Finished L/D MWD & cleaning and laying do wn mud motor after adjusting motor setting f rom 1.5 deg to 0 deg. PJSM. Clean and clear rig floor. Changed out bails to long bails. Picked up fillup too I with push plate. Changed out elevators to spider/elevator and picked up 9-5/8" spider Rigged up power tongs and platform for tong operator. Ran 9-5/8" casing to 625'. This jt did not gi ve mud back. Broke circ & circ bttms up an d getting a lot of sand on derrick shakers. RIH with csg to 898' with good returns on fl ow show. This put us below running sand i nterval.. planned to CBU here but not able t 0 get returns. L/D 5 jts of 9-5/8" csg, getting us back to w here we had last good circulation. Messed up one jt of casing... pin end. Established circulation and CBU. Washed each jt down t 0 898' while circulation 1/2 to 1 full bttms u p on each jt... The derrick shakers are flo oded with running sand. Not cleaning up m uch at all. Continued running 9-5/8" casing to 4879'. Currently running 15 jts & then circulating 2 500 strokes. Still getting some sand on sh akers, but a lot better than before. Original Iy circ'g bttms up every 3 jts and then sprea d it out slowly to 5 then 10 and then 15 jts. Ran 134 jts of casing. Picked up TAM port collar. Ran 10 more joints of casing and ve ry sticky. Decided to circulate bottoms up. Circulated bottoms up. P/U wt came down fr om 300K to 230K. Slack off wt 120K. Ran 9-5/8" casing to 5976' after picking up I ast joint. Decided to circulate 2500 stroke s prior to picking up hanger & landing joint, as hole sticky. Circuited bottoms up and no mud losses @ 6 5 spm 5.5 bpm. M/U 9-5/8" casing hanger + landing j'oint an d RIH 34.40 ft. Landed exactly on the mark Continue to work casing w/ pumps going and full returns. Plan to circulate 4000 stro kes prior to rigging up cementing head, as i t takes time. Circ & condo mud Lay down fill up tool, Pick up Gmt. head Circ & condo mud fl cmt job @ rate of 5.5 bp m @ 400 psi- No noticeable mud loss, Held Printed: 1/16/2002 2:22:01 PM ~ -A. ~ <PHILLlPS~. ~ 'V Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1 0/23/2001 10/24/2001 10/25/2001 ( (" PHilliPS ALASKA INC. Operations Summary Report 2T -39 2T -39 ROT - DRILLING Nabors Nabors 16E Sub From - To Hours Code Code Phase 05:30 - 11 :45 6.25 CEMENl CIRC SURFAC 11:45 -16:00 4.25 CEMENl PUMP SURFAC 16:00 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 22:00 22:00 - 00:00 00:00 - 01 :30 01 :30 - 03:30 03:30 - 04:30 04:30 - 12:30 12:30 - 00:00 00:00 - 05:30 1.00 CEMEN' PULD SURFAC 1.00 CEMEN' PCLR SURFAC 1.00 CEMEN' CIRC SURFAC 3.00 CEMEN' TOPJ SURFAC 2.00 CEMEN"I PULD SURFAC 1.50 CEMEN' PULD SURFAC 2.00 WELCTL NUND INTRM1 1.00 WELCTL NUND INTRM1 8.00 WELCTL NUND INTRM1 11.50 WELCTL NUND INTRM1 5.50 WELCTL BOPE INTRM1 Page 9 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations PJSM flcmt job Mix & Pump 5 bbls CW100, Test lines to 350 0 psi, Mix & Pump 15 bbls CW100, Shut dow n drop bottom plug, Mix & Pump 50 bbls Mud PUSH XL @ 10.5 ppg wi Red Dye, @ rate of 4.5 bpm @ 400 psi, Followed by 600 sxs (47 4.4 bbls) Lead cmt @ 10.7 ppg wi 50%D 124, 30%D53, 1.5%D79, 1.5%S1, 0.6%D46, 0.5%D 65, 9.0%D44 @ rate of 6 bpm @ 600 psi, Fol lowed by 659 sxs (281.7 bbls) Tail cmt @ 12 .0 ppg wi 1.0%D65, 1.0%D79, 0.2%D46 @ ra te of 4-6 bpm @ 600 psi, Drop top plug, Dis place cmt wI 3 bbls cmt, 7 bbls wash water & 442.5 bbls 9.9 ppg mud @ rate of 6-4.2 bp m @ 1000 psi, Did not bump plug, Had good returns thru out job but noticed a mud loss of .5 bpm - Total est. mud loss was 120 bbls , Did not see any CW100, MudPUSH, or cmt returns to surface, CIP @ 1545 hrs 10/23/01 Rig down cmt head & landing joint Make upTam Port collar tool & RIH to 722' Test tool, Open Port collar, Circ btm's up - Had 8 bbls cmt contaminated mud on btm's u p Pump 20 bbls fresh water, Mix & pump 185 s xs (147 bbls) Lead cmt @ 10.7 ppg w/50%D1 24, 30%D53, 1.5%D79, 1.5%S1, 0.6%D46, O. 5%D65, 9.0%D44, Displace wi 3 bbls fresh w ater, Had good cmt to surface after pumpin g 95 bbls cmt, 52 bbls cmt to surface, CIP @ 2155 hrs 10/23/01, Close & test Tam port collar to 1000 psi, Circ out 4 bbls cmt., Wit nesed by AOGCC Jeff Jones Lay down 5" HWDP Finish laying down 5" HWDP & Port Collar T 00 I Nipple down all Diverter stack equip. & hang off same Install FMC starter head, Orient same & test to 5000 psi- OK Install & Nipple up BOP & all equip. (Note; 1 hr turning stack at mud cross due to direc tion of speed head different than last well) Rig down time- Time over contract alloted 8 hrs for nipple up & testing of BOP, Trouble making up newly installed gray lock clamps, Choke line & inspecting all rams Rig down time- Time over alloted 8 hr nipple up & test time in contract, Test all BOP e quip. to 250 psi low & 5000 high- Hydril to 2 50 psi low & 3500 psi high, Had leaks on Gr ay lock clamps, Choke valve, Btm pipe rams Printed: 1/16/2002 2:22:01 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/25/2001 10/26/2001 10/27/2001 10/28/2001 (" (' Page 10 of 18 PHilliPS ALASKA INC. Operations Summary Report 2T -39 2T -39 ROT - DRILLING Nabors Nabors 16E Sub From - To Hours Code Code Phase 00:00 - 05:30 05:30 - 06:30 06:30 - 10:30 10:30 - 11 :30 11 :30 - 12:30 12:30 - 14:30 14:30 - 18:00 18:00 - 18:30 18:30 - 21:30 21 :30 - 22:00 22:00 - 22:30 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 05:00 05:00 - 07:30 07:30 - 12:00 12:00 - 14:30 14:30 - 16:00 16:00 - 20:30 20:30 - 21 :30 21 :30 - 22:30 22:30 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 03:30 03:30 - 04:00 04:00 - 14:00 14:00 - 15:00 15:00 - 00:00 00:00 - 16:30 16:30 -19:00 5.50 WELCT BOPE INTRM1 1.00 DRILL RIRD 4.00 DRILL PULD 1.00 RIGMNT RSRV 1.00 DRILL TRIP 2.00 RIGMNT RURD 3.50 DRILL TRIP 0.50 DRILL PULD 3.00 DRILL TRIP 0.50 DRILL CIRC 0.50 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 5.00 DRILL 2.50 DRILL 4.50 DRILL 2.50 DRILL 1.50 DRILL 4.50 DRILL 1.00 DRILL 1.00 DRILL 1.50 DRILL 1.50 DRILL 1.00 DRILL 1.00 DRILL 0.50 DRILL 10.00 DRILL 1.00 DRILL 9.00 DRILL 16.50 DRILL 2.50 DRILL INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 DEQT INTRM1 CIRC INTRM1 DEQT INTRM1 TRIP TRIP TRIP TRIP TRIP TRIP TRIP INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 CIRC INTRM1 DEQT INTRM1 OTHR INTRM1 DRLG INTRM1 CIRC INTRM1 FIT INTRM1 DEQT INTRM1 DRLG INTRM1 CIRC INTRM1 DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations (Changed out same) Test witnessed by AOG CC Jeff Jones Rig down test equip., Install wear bushing Pick up BHA, Orient motor, Program LWD Service top drive & drawworks Pick up 5" DP & RIH PJSM, Cut drilling line 75' Pick up 5" DP & RIH PJSM, Install kelly hose Pick up 5" DP & RIH Tag cmt on top of float collar @ 5899', Circ. btm's up Rig & attempt to test 9-5/8" csg- No good, ( Pumped 2 bbls- pressure built to 400 psi ver y slowly), Tam port collar possibly leaking Circ, Check surface equip. Attempt to retest csg- No good, (Only able t 0 pressure up to 175 psi- pumped total of 2 b b Is) Mix & Pump dry job Dry pipe, POOH, Down load & lay Make up port collar shifting tool, e port collar @ 722', POOH, Test 0 psi- OK Make up & program BHA, RIH to 1158' (Bit s et down 10K on port collar @ 722'), Close ra ms & attempt to test csg- No good POOH, Down load & set back BHA Make up port collar shifting tool, RIH & clos e port collar @ 722', POOH, Test csg to 250 0 psi- OK Change bits, Make up & program BHA, RIH t 0 1012', Close rams test csg- OK, RIH to 58 99' Circ. btm's up Rig & test 9-5/8" csg. to 2500 psi f/ 30 min. -OK Drill cmt & Float collar @ 5929' Finish drilling out cmt & float equip., Drill 2 5' of new hole ART= .25 hrs Change over to new 8.4 ppg mud Rig & perform FIT to 16.0 EMW w/ 1235 psi, 8.4 ppg mud @ 3121' TVD Perform PWD base line test Drill fl 6050' to 7000' Cric. slow & work pipe while changeing shak er screens Drill fI 7000' to 8025' Drill fI 8025' to 9882' ART= 11.25 hrs AS T= 1.25 hrs Note; Clocks back 1 hr. fl dayli ght savings time Circ. btm's up, Pump sweep & circ. hole cle an, Monitor well, Dry pipe down BHA RIH & clos csg to 250 Printed: 1/16/2002 2:22:01 PM ( (' " PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 10/28/2001 19:00 - 21:00 2.00 DRILL WIPR INTRM1 21 :00 - 22:00 1.00 RIGMNT RSRV INTRM1 22:00 - 00:00 2.00 DRILL WIPR INTRM1 10/29/2001 00:00 - 00:30 0.50 DRILL WIPR INTRM1 00:30 - 07:00 6.50 DRILL DRLG INTRM1 07:00 - 07:30 0.50 RIGMNT RGRP INTRM1 07:30 - 19:30 12.00 DRILL DRLG INTRM1 19:30 - 23:00 3.50 DRILL CIRC INTRM1 23:00 - 00:00 1.00 DRILL WIPR INTRM1 10/30/2001 00:00 - 01 :30 1.50 DRILL WIPR INTRM1 01 :30 - 05:00 3.50 DRILL CIRC INTRM1 05:00 - 09:30 4.50 DRILL WIPR INTRM1 09:30 - 10:30 10:30 - 13:00 1.00 RIGMNT RSRV INTRM1 2.50 DRILL WIPR INTRM1 13:00 - 16:30 3.50 DRILL REAM INTRM1 16:30 - 18:00 1.50 DRILL REAM INTRM1 18:00 - 20:00 2.00 DRILL CIRC INTRM1 20:00 - 22:30 2.50 DRILL REAM INTRM1 22:30 - 00:00 1.50 DRILL CIRC INTRM1 10/31/2001 00:00 - 03:00 3.00 DRILL WIPR INTRM1 03:00 - 06:30 3.50 DRILL CIRC INTRM1 06:30 - 10:00 10:00 - 12:30 3.50 DRILL 2.50 DRILL CIRC INTRM1 WIPR INTRM1 12:30 - 14:30 2.00 DRILL INTRM1 CIRC Page 11 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations Wipe hole to shoe @ 6012' - no tight hole, Hole in good shape Service top drive, Drawworks, Blocks RIH, Take check shot surveys @ 8942', 9037 ',9131', RIH, Hole in good shape RIH fI 9131' to 9882' hole in good shape Drill fl 9882' to 10445' ART= 3.5 hrs AST = 1.5 hrs (Trip gas 300 units) Repair bleeder valve on standpipe Drill f/ 10445' to 11255' ART= 5.75 hrs A ST= 2.25 hrs (Back ground gas 0- 50 units) , Weighted up mud to 9.6 ppg @ 10500' Circ 1 btm's up, Pump sweep, Circ 2 btm's u p & hole clean Note; Had 5000 units gas w hen sweep return to surface according to bo th availible gas detectors- Gas did not cut mud weight Monitor well- OK, Dry pipe, Begin 20 stand wiper trip Wipe hole to 9417', 45K drag @ 10100', No other problems Circ btm's up (Trip gas 5000 units), Pump s weep & Raise mud weight to 9.8 ppg Monitor well, Wipe hole to 9-5/8" shoe, 50K drag fl 10700' to 10450', Pump out to 10355 " No other problems to shoe Service top drive, Drawworks, Blocks RIH to 10261', Precautionary ream fI 10261' to 10729'. No problems, RIH to 11197'- Bre ak circ. Circ. & work pipe, Hole ght- 80K Drag, Circ out s, Attempt to raise mud e very unstable Back ream & pump out to 10261' (Tight & pa cking off), Raise mud weight 10.2 ppg Circ & finish raiseing mud weight to 10.2 pp g Wash & ream f/ 10261' to 11255' No problem s Pump sweep & circ hole clean (Btm's up gas +-25 units) Monitor well-OK, Dry pipe, Wipe hole to 950 0' No problems Pump sweep & circ hole clean (Trip gas +-2 5 units), Spot baranex pill on btm, After shu ting pump off unable tò go down, Mild packi ng off washing back to btm. Circ & raise mud weight fI 10.2 to 10.6 ppg Monitor well-OK, Dry pipe, Wipe hole to 972 3' No problems Pump sweep & circ hole clean (Trip gas +- 2 5 units) packing off & very ti trip gas of 5200 unit wt. 10.2 ppg but hol Printed: 1/16/2002 2:22:01 PM ( (' PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 10/31/2001 14:30 - 15:30 1.00 DRILL OBSV INTRM1 15:30 - 17:00 1.50 DRILL TRIP INTRM1 17:00 - 17:30 0.50 DRILL CIRC INTRM1 17:30 - 00:00 6.50 DRILL TRIP INTRM1 11/1/2001 00:00 - 01 :00 1.00 DRILL TRIP INTRM1 01 :00 - 03:30 2.50 DRILL PULD INTRM1 03:30 - 05:30 2.00 WELCT EaRP INTRM1 05:30 - 07:30 2.00 CASE RURD INTRM1 07:30 - 15:00 7.50 CASE RUNC INTRM1 15:00 - 16:00 1.00 CASE CIRC INTRM1 16:00 - 22:30 6.50 CASE RUNC INTRM1 22:30 - 23:30 1.00 CASE RURD INTRM1 23:30 - 00:00 0.50 CEMEN CIRC INTRM1 11/2/2001 00:00 - 02:30 2.50 CEMEN crRC INTRM1 02:30 - 05:30 3.00 CEMEN PUMP INTRM1 05:30 - 06:30 , 1.00 CEMEN PULD INTRM1 06:30 - 08:00 1.50 CASE DEaT INTRM1 08:00 - 10:30 2.50 WELCT 10:30 - 21 :00 10.50 DRILL PULD PROD 21 :00 - 23:00 2.00 DRILL PULD PROD 23:00 - 00:00 1.00 WELCT BOPE PROD 11/3/2001 00:00 - 03:30 3.50 WELCT BOPE PROD 03:30 - 07:30 4.00 DRILL PULD PROD 07:30 - 18:30 18:30 - 20:30 11.00 DRILL PULD PROD 2.00 RIGMNT RURD PROD 20:30 - 21 :00 21 :00 - 22:00 22:00 - 00:00 0.50 DRILL CIRC PROD 1.00 DRILL OTHR PROD 2.00 CEMEN DSHO PROD Page 12 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description. of Operations Monitor well, Check hole for fill- OK, Spot b aranex pill on btm. POOH to 9886' (Slow) Pump dry job POOH to run 7" csg. No problems POOH to BHA, No problems Down load LWD tools & Lay down BHA Pull wear bushing, Change btm pipe rams to 7" & test door seals to 3500 psi Rig to run 7" csg. Run 7", 26#, L-80, BTCM to 5969' Circ btm's up @ 5969' Run 7",26#, L-80, BTCM to 12243' Rig down fill up tool, Rig up Dowell cmt hea d Circ & condition mud fl cmt job Circ & cond mud f/ cmt job, Work Pipe for 2 btm's up & pipe began to get sticky- Land s ame Batch mix 30.0 bbls MudPUSH @ 12.0 ppg & 166 sxs (35.5 bbls) of Class G GASBLOK cm t w/ 3.0%D53, .5%D65, .1%D800, .2%D47, 2. 0%D600G mixed @ 15.8 ppg, Pump 5 bbls fr esh water, Test lines to 3500 psi, Drop btm plug. Pump 30 bbls MudPUSH @ rate of 5 bp m @ 900 psi Followed by 35.5 bbls cmt @ ra te of 5 bpm @ 1300-1100 psi, Drop top plug, Displace cmt w/ 1 bbl cmt, 9 bbls fresh wat er & 416.6 bbls 10.6 ppg mud @ rate of 6 bp m @ 600-800 psi, Bump plug w/ 500 psi over disp. pressure, CIP @ 0520 hrs 11/2/01, H ad good circ thur out job, Had no mud loss, Floats held good. Lay down cmt head & landing jt. Set & test FMC csg pack-off to 5000 psi- OK Change btm pipe rams to 4", Change top dri ve saver sub to 4" HT-38 Rig & lay down 5" DP f/ Derrick Clear floor of 5" equip., Rig to run 4" DP Install test plug, Rig to test BOP Rig & test all BOP equip. to 250 psi low & 5 000 high, Hydril to 250 psi low & 5000 psi h igh, Test waived by AOGCC John Crist, Set wear bushing Pick up 6-1/8" BHA, Program tools, Surface test tools, Load R/A soruces Pick up 4" DP & RIH to 11156' Install Kelly hose, Cut & slip drilling line 11 9', Service rig Tag top of cmt @ 11158', Circ btm's up Rig & test 7" csg to 3500 psi- OK Drill out float equip. & cmt. Printed: 1/16/2002 2:22:01 PM ( (' PHilliPS ALASKA INC. Operations Summary Report 11 :00 - 19:00 8.00 DRILL TRIP PROD 19:00 - 21 :00 2.00 DRILL PULD PROD 21 :00 - 00:00 3.00 DRILL TRIP PROD 11/5/2001 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 06:30 4.50 DRILL CIRC PROD Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 11/4/2001 00:00 - 01 :00 1.00 CEMEN DSHO PROD 01 :00 - 04:00 3.00 DRILL CIRC PROD 04:00 - 04:30 0.50 DRILL DRLG PROD 04:30 - 06:00 1.50 DRILL CIRC PROD 06:00 - 07:00 1.00 DRILL LOT PROD 07:00 -11:00 4.00 DRILL OTHR PROD 11/6/2001 06:30 - 07:00 0.50 WELCT OBSV PROD 07:00 - 12:00 5.00 DRILL CIRC PROD 12:00 - 13:30 1.50 WELCT OBSV PROD 13:30 - 19:00 5.50 DRILL CIRC PROD 19:00 - 00:00 00:00 - 00:30 00:30 - 02:00 5.00 DRILL 0.50 DRILL 1.50 DRILL TRIP PROD TRIP PROD PULD PROD 02:00 - 10:00 8.00 CEMEN TRIP PROD 10:00 - 10:30 0.50 CEMEN CIRC PROD 10:30 - 11 :00 0.50 CASE DEOT PROD 11 :00 - 14:30 3.50 CEMEN OTHR PROD Page 13 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations Drill out 7" float equip. & Soft cmt to 11255' Pump sweep & Drill f/ 11255' Pump sweep & ph) Monitor well- Static, Perform LOT of 12.9 pp g w/ 12.0 ppg mud, 275 psi @ 5837' TVD Monitor well, Observe 7"x 9-5/8" ann. press ure of 280 psi, Close rams, pressure 7" csg to 320 psi & 7"x 9-5/8" ann. pressure built t 0 320 psi, Rig & check U-tube between 7" & 9-5/8"- Open 9-5/8" & 7" dropped l' in 5 min °, Close 9-5/8" & 7" dropped 3" in 5 min. POOH & Remove R/A source, Down load MW D tools, Stand back BHA Rig & pick up 805' 2-7/8" DP RIH slow wI cmt stinger RIH w/ 2-7/8" OEDP, Tag btm @ 11275', Pull up to shoe @ 11243' Circ slow at rate of 3 bpm @ 850 psi (Loss r ate of 45 bph) & lower mud wt. f/ 12.0 ppg t 0 11.0 ppg & add LCM of 1 ppb (Stopped los es), Total lost 165 bbls, No gas Monitor well- Light flow, Close in well (No d rill pipe pressure, 10 psi csg pressure- susp ect well breathing), Open well Raise mud wt. f/ 11.0 ppg to 11.3 ppg & mai ntain 1 ppb Barofibre, No gas or mud loss Monitor well- Light flow, Close in well (No d rill pipe pressure, 20 psi csg pressure- susp ect well breathing), Open well, Blow down c hoke lines Displace well w/ 12.0 ppg mud & maintain 1 ppb Barofibre, Losing +- 45 bph (lost total 9 0 bbls), No gas, Monitor well- Static, Build mud vol. in pits for trip, Pump dry job POOH w/ 2-7/8" OEDP Finished POOH. PJSM. R/U to lay down 2-7/8" dp. Laid dow n 2-7/8" dp & RID GBR power tongs, etc. TIH with Baker right hand set 7" Retrievama tic packer to 11850'. Rigged up to pump down cement line. Pump ed 10 bbls of mud. Set packer. Opened cir culating sleeve. Pumped to establish losse s. Closed circulating sleeve & closed pipe ram s. Tested 7" x 4" annulus to 3000 psi, OK. R/U for injectivity test. Test lines to 3000 psi, OK. Performed injection test and estab Ii shed 0.56 bpm @ 760 psi (using cementing unit). Change over to 12.0 ppg mud to 11275' circ btm's up (Losing 40-45 b Printed: 1/16/2002 2:22:01 PM 11/7/2001 16:00 - 20:00 20:00 - 22:30 22:30 - 00:00 , 00:00 - 05:30 05:30 - 06:30 06:30 - 11 :00 11 :00 - 16:00 16:00 - 18:30 18:30 - 19:00 19:00 - 22:00 (" PHilliPS ALASKA INC. Operations Summary Report 4.00 CEMEN OTHR PROD 2.50 CEMEN CI RC PROD Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 11/6/2001 14:30 - 16:00 1.50 CEMEN SOEZ PROD 1.50 CEMEN TRIP PROD 5.50 CEMEN TRIP PROD 1.00 CASE DEOT PROD 4.50 DRILL TRIP PROD 5.00 DRILL TRIP PROD 2.50 CEMEN DSHO PROD 0.50 DRILL CIRC PROD 3.00 DRILL DRLG PROD 22:00 - 23:00 1.00 DRILL CIRC PROD 23:00 - 00:00 1.00 CEMEN FIT PROD 11/8/2001 00:00 - 01 :00 1.00 CEMEN FIT PROD Page 14 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations Mixed & pumped Class G cement @ 15.8 ppg with 3hr-8min thickening time. Due to low injection rate the volume of cement mixed was reduce to 20 bbls and the cement was s potted down the 4" dp to near the packer by pumping thru the circulating sleeve and hold ing 500 psi back pressure on the choke line. Closed sleeve & squeezed 12.5 bbls un de r the shoe. Leaving 7.5 bbls inside the cas ing (+/- 196'). Sqeezed @ 1 bpm @ 760 psi. Estimated TOC @ +1- 11047'. Kept 500 p si on 7" x 4" annulus + 200 psi on 4" dp + 3 00 psi on 9-5/8" x 7" annulus. Wait on cement. At end of 4 hrs, pressures still the same as above. Bled pressures off, opened Hydril & monitor ed well. Opened bypass on packer & unseat ed the packer. Blew down choke & kill lines Circulated 2 bottoms up @ 4 bpm & 1250 psi. Flow check well, no flow. Pumped slug. PO OH. Finished POOH with Baker 7" retrievamatic compression set packer. Packer OK, no ru bbers washed off. RIU to test 7" casing. Tested 7" casing aga inst cement sqz to 760 psi for 15 minutes, g ood test. Bled pressure off slowly & RID pu mp-in sub, circulating hose with safety val v e & chart recorder. PJSM. R/U to P/U BHA. PIU BHA & rerun 6 -1/8" bit. Load LWD source. Test LWD & mud motor, OK. TIH to 10,973' md. d s. Broke circ & with slow pump rate washed do wn to top of cmt @ +/- 11,155'. Brought pu mps up to drlg gpm & cleaned out cmt in 7" & rathole to 11,275' md. Circulated at 230 gpm & observed PVT, no m ud losses. Shut pumps down, no static los ses either... all looks good. Continued drilling to drill 20' of new formati on for F.I.T. Had a very hard streak... me ssed with parameters & pumped nut plug do wn. Broke thru hard streak prior to nut plug hitting the bit. Circulated bttms up & conditioned mud for F .I.T. No mud losses. R/U to peform F.I.T., pumping down kill line and drillpipe simultaneously. Finished performing F.I.T. Could not get ei ther mud pump to pump @ 6 spm. Closed kil Filling pipe every 40 st Printed: 1/16/2002 2:22:01 PM ~ ~ ~ <PHILLlPS~~ 1m¡ 'V' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/8/2001 11/9/2001 ( (' PHilliPS ALASKA INC. Operations Summary Report 2T -39 2T -39 ROT - DRILLING Nabors Nabors 16E Page 15 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations Sub From - To Hours Code Code Phase 00:00 - 01 :00 01:00 - 01:30 01 :30 - 14:30 14:30 - 19:00 19:00 - 20:00 20:00 - 21 :00 21:00 - 21:30 21 :30 - 00:00 00:00 - 01 :30 01 :30 - 09:00 09:00 - 13:00 13:00- 14:00 14:00 - 16:30 1.00 CEMEN" FIT 0.50 DRILL 13.00 DRILL 4.50 DRILL 1.00 DRILL TRIP PROD DRLG PROD PROD CIRC TRIP PROD PROD 1.00 RIGMNT RSRV PROD 0.50 DRILL TRIP PROD 2.50 DRILL CIRC PROD 1.50 DRILL 7.50 DRILL 4.00 DRILL 1.00 CASE 2.50 CASE TRIP TRIP PROD PULD PROD PROD RURD PROD RUNC PROD I & dp valve and could not get them to press ure up using either pump @ 6 spm. Tried 8 spm & pressured up just fine. Evidently th e rheology increase due to cmt contaminatio n & air entrainment made it necessary to pu mp a little faster before the pumps would pr ¡me. Performed F.I.T. at 11 ,295'md I 5847'tv d to 750 psi with 12.0 ppg mud in the well. EMW= 14.47 ppg. RID from F.I.T. and screwed in to topdrive & TIH. Drld 6-1/8" hole fl 11,295' - 11 ,685'md I 604 9.55' tvd. ART= 10.75 hrs. Lowered rheol ogy from 25-26 YP to +1- 20 in order to get t he PWD down some. PWD down from 14.2+ ppg to 13.8-13.9 ppg at 230 gpm. Had two hard streaks.. one above C4 sand & the othe r the last 30' or so on bttm. Drld to 200' b elow bttm perforation, est. to be at 11,485' md. CBU & flow checked well. Pumped hi-dense sweep & no gas on bttms up. Swab checked well. Pumped 2nd hi-dense sweep. No gas on bttms up. Finished circulating 4 bttms up & racking 1 std/hr. Raised mud rheolog y back up to 25+ YP. Flow checked well, no flow. TIH with 2 stds POOH to inside 7" shoe to 11,166'. Hole looked very good, no abnormal drag. When below the C4 sand, the dp differentially sti cks to some small degree, takes +1- 20k dra g to break free. Serviced topdrive, dwwks & blocks. TIH to bttm, no fill. Broke circ slowly, check for losses, none. Pumped hi-dense sweep & circ'd it out. Ch ecked mud for barite sagging indications, no ne. Added some mud lube. No indications of any mud losses, dynamic or static. Flow checked well, no flow. Blew down topd rive & lines. POOH to 7" shoe. Flow checked well at shoe, no flow, no loss. Pumped 14 ppg slug. POOH to BHA. Down loaded data from LWD tools. LID drill collars, MWD + LWD tools + mud motor + bi t. R/U to run 3-1/2" liner. Held PJSM, reviewed all aspects of liner job Made up float eqpt & landing collar and Ba ker locked same & joints between. Centrali zed as per program. Checked floats, OK. Finished PIU 19 jts of 3-1/2" SLHT liner + Ii ner hanger + liner top packer & running tool Printed: 1/16/2002 2:22:01 PM 11/10/2001 ( (' PHilliPS ALASKA INC. Operations Summary Report 00:00 - 03:00 3.00 CASE CIRC PROD Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 11/912001 14:00 - 16:30 2.50 CASE RUNC PROD 16:30 - 00:00 7.50 CASE RUNL PROD 03:00 - 06:30 3.50 CASE RUNL PROD 06:30 - 08:00 08:00 - 09:00 1.50 CASE 1.00 CASE CIRC PROD RUNL PROD 09:00 - 12:00 3.00 CEMEN CIRC PROD 12:00 - 12:30 0.50 CEMEN RURD PROD 12:30 - 13:00 0.50 CEMEN CIRC PROD 13:00 - 14:15 1.25 CEMEN PUMP PROD 14:15 - 14:45 0.50 CEMEN DISP PROD 14:45 - 15:15 0.50 CASE OTHR PROD Page 16 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations Ran liner on 4" HT-38 dp to 4521'. Circulat ed bttms up. no barite sagging..variance .1 ppg. Ran liner to 7976'. Circulated bttms up and 0.9 ppg variance in mud wt. Had to circulate 2 bttms up to get mud leveled out @ 48 spm & 1100 psi.. Running speed is 2. 5-3 min/stand. Initially started at 1.5 minI std but appeared to be loosing some mud, s 0 slowed down the running speed. Circ'd and conditioned mud. Had some bari te sagging. Only able to pump at 45 spm so a bttms up takes awhile. Ran 3-1/2. liner on 4. HT-38 dp from 7976' - 11,239' md. Circ'd bttms up... minor barite sagging. PJSM concerning topdrive plug launching he ad. Ran 3-1/2. liner to TD. Washed, no ro tation last stand to bttm... no indication of any fill. Circ'd & conditioned mud rheology... lowere d vis and VP. Reciprocated & rotated liner throughout the circulating. No irregular tor que. PJSM & picked up topdrive cement headlplu g launching head. Hooked up torque arm & torque line (tugger line) to plug launching h ead swivel. Continued circulating while DS batch mixed cement. NO INDICATIONS OF ANY DOWNH OLE LOSSES during any of the circulating. When pumps are off, absolutely no backflo w. Mixed and pumped the following. Pumped 1 0 bbls CW-100 @ 8.34 ppg. Pressure tested lines to 5000 psi, OK. Pumped 10 bbls of CW-100 + 20 bbls of MudPUSH @ 13.0 ppg. Pumped 154 sxs (33 bbls) of Class G cmt @ 15.8 ppg with Gas Check additive. Full returns throughout. Continued rotating and reciprocating casing. P/U torque= 7-9k-ft-lbs. SIO torque=3-5k- ft-Ibs. Released wiper plug, plug indicator positive. Displaced with DS cmt unit @ 4.2 - 4.7 bpm. Saw wiper plug enter liner (+ 1 00-200 psi). Slowed displacement rate to 2. 5 bpm. Bumped plug. Had to stop rotatin g liner +1- 4 bbls prior to bumping the plug. Pressured liner on up to 2900 psi. Slacked off & liner set +1- 2' off bttm. Pressured on up to 3500 psi to release RS setting too I, held 1minute & bled off. Floats holding good. P/U & tool did not release. Pressur Printed: 1/16/2002 2:22:01 PM (' f PHilliPS ALASKA INC. Operations Summary Report 15:15 - 18:45 3.50 CEMEN CIRC PROD Legal Well Name: 2T -39 Common Well Name: 2T -39 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 11/10/2001 14:45 - 15:15 0.50 CASE OTHR PROD 18:45 - 19:00 0.25 DRILL OBSV PROD 19:00 -19:30 0.50 CEMEN RURD PROD 19:30 - 00:00 4.50 DRILL PULD PROD 11/11/2001 00:00 - 06:00 6.00 CMPL TN TRIP PROD 06:00 - 06:30 0.50 CMPL TN TRIP PROD 06:30 - 07:30 1.00 CMPL TN TRIP PROD 07:30 - 09:00 1.50 CMPL TN TRIP PROD 09:00 - 10:30 1.50 CMPL TN RUNT PROD 10:30 - 12:30 2.00 RIGMNT RGRP PROD 12:30 - 20:00 7.50 CMPLTN RUNT PROD 20:00 - 22:00 2.00 CMPLTN CIRC PROD 11/12/2001 22:00 - 23:00 1.00 RIGMNT RGRP PROD 23:00 - 00:00 1.00 CASE DEOT PROD 00:00 - 01 :00 1.00 CASE DEOT PROD 01 :00 - 03:00 2.00 CMPL TN CI RC PROD Page 17 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations ed back up to 4000 psi for 1 min... bled off. PIU & did not release. Pressured up to 45 00 psi for 1 min & bled down to 3000 psi & h eld pressure. P/U & tool released. Bled pr essure off & floats holding good. PIU to ex pose dogs. Slacked off without rotation and set 40,000 Ibs onto liner top packer. Repe ated same. Slacked off with pipe rotation and set 45,000 Ibs onto liner top pkr. Pumped the long way (discussed with town fi rst). Pumped 4 bttms up. 1st two bttms u p @ 97 spm @ 3200 psi. Recovered space r & mud PUSH + (+1-) 8 bbls of cmt contamin ated mud. Displaced hole to higher rheolo gy mud, to avoid barite sagging. YP now in the upper 30's. Took 2 circulations with t he higher rheology mud... circulated at 45 s pm to keep pressure off of liner. Flow checked well, no flow. RID topdrive plug launching head. RIU to lay down 4" dp. POOH laying down 4" HT-38 dp. Finished laying down 4" HT-38 drillpipe. Layed down Baker rotating liner hanger setti ng tool. RIH with 4 stands of 4" dp in derrick. POO H laying down same. Pulled wear bushing. RIU to run 3-1/2" L-80 EUE 8rd Modified tubing. PJSM. Ran 3-1/2" completion string - 39 jts. Repaired pick up lay down machine. Broke n chain. Ran 3-1/2" tubing, joints 40 - 346. RIU to circulate at 7" & 3-1/2" liner test poi nt... Circulated bottoms up. Closed BOP & pumped thru kill line to get air out of syste m. Brought pressure up to 2750 psi and valve i n standpipe manifold leaking. Bled pressur e off. Repaired valve and tested manifold t 0 4000 psi, OK. R/U chart recorder, etc. for 7" & 3-1/2" liner pressure test. Pressure tested to 3550 ps i for 30 minutes, no bleed off at all. Bled pressure off and recovered exact amount of fluid pumped. Finished testing the 7" casing & 3-1/2" liner and liner lap to 3550 psi. Bled pressure 0 ff slowly RID testing lines & chart recorder Open pipe ram. Arranged for 3 truckloads of seawater. Maxi mum pump rate to avoid damaging seal assy was 5 bpm. Displaced 12.0 ppg LSND mud Printed: 1/16/2002 2:22:01 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/12/2001 ( (' PHilliPS ALASKA INC. Operations Summary Report 2T -39 2T -39 ROT - DRILLING Nabors Nabors 16E Page 18 of 18 Spud Date: 10/12/2001 End: 11/12/2001 Group: Start: 10/10/2001 Rig Release: 11/12/2001 Rig Number: 16E Description of Operations Sub From - To Hours Code Code Phase 01 :00 - 03:00 03:00 - 04:00 04:00 - 04:30 04:30 - 06:00 06:00 - 06:30 06:30 - 07:30 07:30 - 09:00 09:00 - 10:30 10:30 - 11 :00 11:00 -12:00 12:00 - 16:00 16:00 - 20:00 2.00 CMPL TN CIRC PROD 1.00 CMPL TN PULD PROD 0.50 CMPL TN crRC PROD 1.50 CMPL TN SOHO PROD 0.50 CMPL TN RURD PROD 1.00 CMPL TN DEOT PROD 1.50 CMPL TN FRZP PROD 1.50 CMPL TN FRZP PROD 0.50 CMPL TN FRZP PROD 1.00 CMPL TN PULD PROD 4.00 WELCT NUND PROD 4.00 CMPL TN NUND PROD with 8.5 seawater. Finished running tubing, idling pump @ 12 s pm & watching for first seals to hit polish b ore. Had 150 psi increase, stopped pump, bled off & marked pipe. Slacked off 17.5' p rior to seal assy locator bottoming out. Pi cked up to just above seal bore & pumped 2 00 strokes of seawater. Picked tubing up fu rther to above liner top. (( IN ADDITION - P erformed L.O.T. on 7" x 9-5/8" annulus. Est ablished injection rates as follows: 1 bpm @ 710 psi & 2 bpm @ 840-825 psi & 3 bpm @ 1000 - 950 psi. Flushed 200 bfw and the n 105 bbls of diesel @ 3 bpm @ 1000-1250 P s i.» Now that we are above liner top, finished di splacing the well with 8.5 ppg seawater (3rd truck). PIU and LID tubing joints 350 & 349, for spa cing out. Had to use 4 pup joints in order t 0 get a 2.54' space out of the locator above the seat. P/U tubing hanger & landing joint Landed hanger and screwed in all hold do wn bolts against hanger. RID tubing power tongs & type C back ups, etc. Pressured 3-1/2" tbg to 3500 psi fo 15 minut es, OK. Bled to 1500 psi. Pressured 3-1/2" tbg x 7" csg annulus to 3500 psi for 15 min utes, OK. Bled pressure down on tubing. RP shear valve sheared, communicating. Freeze protected the well by pumping 109 b bls of diesel down the annulus. Allowed to equalize 1 hr. Cleared rig floor RID lines and valves used for freeze protect in g. LID landing joint. Set BPV in hanger. Clear ed floor. NID BOP stack, etc. (Changed bttm rams to 4-1/2" x 7" VBR). Nippled up tree & re-arranged valve orientat ion to suit production. Ttested packoff to 5 000 psi. OK. Pulled BPV & set 2 way check Tested tree to 250 psi and then 5000 psi, OK. Pulled 2 way check and installed BPV. . RIG RELEASED TO MOVE TO OLIKTOK ST AGING AREA.... Printed: 1/16/2002 2:22:01 PM Date 11/29/01 11/30101 12/01/01 12/02/01 12/03/01 12/04/01 12/05/01 12/10101 12/12/01 12/16/01 12/17101 12/18/01 01/04/02 01/05/02 ( (" ,( 2T -39 Event H ¡story Comment PERFORMED A FCO TO 11573.1' CTMD. RETURNS 1-1 ALL DAY. SMALL TRACE OF FINE SAND + MUD IN RETURNS. WASHED MANDRELLS ON WAY TO SURFACE. FREEZE PROTECTED WELL TO 4000'. [FCO] TAGGED @ 11,576' WLM, IN PROGRESS [TAG] SET 2.75" CAT SV @ 10,982' RKB, EMPTY POCKET @ 10,936' RKB, IN PROGRESS [GLV] SET 1.5" DV @ 10,936' RKB, PTTBG TO 3500#, PT CASING & LINER TO 3000# HELD, PULLED CAT SV @ 10,982' RKB, DRIFTED & TAGGED @ 11,584' RKB WI 23' OF 2.60" DUMMY GUN'S [GLV, PT TBG-CSG, TAG] PERFORATED: 11392' - 11406' & 11454' - 11470', 6 SPF WITH 2 1/2" HSD GUNS, 60 DEG PHASE, RANDOM ORIENT,POWERJET CHARGES, PENT= 25.2", EH= 0.32" OBTAINED INITIAL A SAND SBHP @ 11431'= 2939.7 PSIA, TEMP= 155.8 DEGF & SBHP AT 11331'= 2907.7 PSIA, TEMP= 154.3 DEGF PERFORATED C SAND INTERVAL: 11358' - 11370', 6 SPF POWERJET, OBTAINED A & C SAND SBHP OF 2868 PSIA @ 11364' WI BHT OF 156.4 DEG, ALSO 2839 PSIA @ 11264' WI BHT OF 153.5 DEG. [PERF] FRACTURED A & C SANDS AT 20 BPM. PLACED 279M# 16/20 CARBOLITE (105% OF DESIGN) IN PERFS WI 12 PPA MAX. FLUSHED WI 96 BBLS AND LEFT 1200# PROPPANT IN WELLBORE. TAGGED FRAC WI ANTIMONY IN PAD FLUID, SCANDIUM IN 2-4 PPA STAGES AND IRIDIUM IN 4-12 PPA STAGES. CUT TRACER 50 BBLS EARLY. RECOVERED 100% TREESA VER RUBBERS. CLEANED FILL TO TD AT 11,560' CTM WI 2.25" JET-SWIRL NOZZLE USING 1-1/2# BIO, SLICK SEAWATER & SLICK DIESEL. WASH PASSES MADE ACROSS GLM'S. WELL FREEZE PROTECTED WI DIESEL TO 2500'+. [FCO] TAGGED FILL @ 11384' WLM. EST -86' FILL. ~ SET OV @ 10396' RKB. PULLED DV @ 10012' RKB, ATTEMPT SET GLV. IN PROGRESS. [GLV] INSTALLED NEW GAS LIFT DESIGN [GLV] TAG @ 11480' RKB.EST 10' OF RAT HOLE. [TAG] LOG 10900' SLM TO 11474' SLM (11480' RKB) WITH SPECTRA IMAGE TOOL. Page 1 of 1 2/12/2002 ( (: 19-Nov-0 1 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Survey Re: Distribution of Survey Data for Well 2T-39 Gyro qDJ-j 83 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Su rvey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 0.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED '. NOV 2 9 2001 Àli=fSi<8. OJ¡ & ñ. ~ ,'~ uas~n$ C . Anchorag~ ommlSSior¡ ~ --.. I ""'- ~ "..' 0 1) DEFINITIVE ...... "'-"--- Kuparuk River Unit North Slope, Alaska Kuparuk 2T, Slot 2T-39 2T-39 Gyro Job No. AKMM11168, Surveyed: 9 November, 2001 SURVEY REPORT 20 November, 2001 Your Ref: API 501032039200 Surface Coordinates: 5970245.06 N, 498944.71 E (70019' 47.7776" N, 150000' 30.8129" W) Kelly Bushing: 113. 70ft above Mean Sea Level "<-- t . .tI " speI'I'Y-su" DRILLING SERVices A Halliburton Company Survey Ref: svy9659 Kuparuk River Unit Measured Depth (ft) .~ 0.00 173.00 262.00 353.00 443.00 ..-- 535.00 624.00 Incl. Azim. Sperry-Sun Drilling Services Survey Report for 2T-39 Gyro Your Ref: API 501032039200 Job No. AKMM11168, Surveyed: ,9 November, 2001 . D EFI N'T\VE 0.000 0.000 1.000 355.000 2.600 210.000 3.900 252.000 5.250 263.000 7.500 267.000 9.250 283.000 North Slope, Alaska Kuparuk 2T Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Depth . Northings Eastings Northings Eastings Rate Section Comment (ft) . (ft) (ft) (ft) (ft) (ft) (°/1 OOft) -113.70 0.00 0.00 N O.DOE 5970245.06 N 498944.71 E 0.00 Tolerable Gyro 59.29 172.99 1.50 N 0.13W 5970246.56 N 498944.58 E 0.578 0.26 148.27 261.97 0.53 N 1.21 W 5970245.59 N 498943.50 E 3.895 1.25 239.13 352.83 2.22 S 5.18W 5970242.85 N 498939.52 E 2.885 4.98 328.84 442.54 3.66 S 12.18W 5970241.40 N 498932.53 E 1.782 11.84 420.27 533.97 4.49 S 22.36 W 5970240.57 N 498922.35 E 2.491 21.91 508.33 622.03 3.18 S 35.13 W 5970241.88 N 498909.58 E 3.257 34.75 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 113. T MSL. Northings and Eastings are relative to 265' FSL & 556' FWL. Magnetic Declination at Surface is 25.817° (12-0ct-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 265' FSL & 556' FWL and calculated along an Azimuth of 274.762° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 624.000., The Bottom Hole Displacement is 35.28ft., in the Direction of 264.820° (True). .""".,,/ Survey tool program for 2T-39 Gyro : I ~ From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 20 November, 2001 - 9:06 uO. To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 624.00 622.03 Tolerable Gyro Page 2 of 2 Dr;¡¡Quest 2.00.08.005 ( ( 19-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Survey Re: Distribution of Survey Data for Well 2T-39 aOI- J?;3 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 624.00' MD Window / Kickoff Survey , MD Projected Survey: 11,685.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED NOV 2 9 2001 Alaska Oil & Gas Cons, Commission ;I\nr.,oorage DEF\N\1\'E \ \..........- Kuparuk River Unit North Slope; Alaska Kuparuk 2T, Slot 2T-39 2T-39 Job No. AKMM11168, Surveyed: 9 November, 2001 ~ v SURVEY REPORT 20 November, 2001 Your Ref: API 501032039200 Surface Coordinates: 5970245.06 N, 498944.71 E (70° 19' 47.7776" N, 150000' 30.8129" W) Kelly Bushing: 113.70ft above Mean Sea Level ~,~ -J I ~ ' spar'r'Y-5UI! DRILLING 5~l::E5 A Halliburton Company Survey Ref: svy9705 Sperry-Sun Drilling Services Survey Report for 2T-39 DEF\N\1\'I Your Ref: API 501032039200 Job No. AKMM11168, Surveyed:.9 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2T Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. - Depth Depth' Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 624.00 9.250 283.000 508.33 622.03 3.18 S 35.13 W 5970241.88 N 498909.58 E 34.75 ~ 736.93 14.080 283.880 618.89 732.59 2.16 N 57.32 W 5970247.22 N 498887.39 E 4.280 57.30 MWD Magnetic ~ ',-- 828.59 18.100 285.660 706.94 820.64 8.68N 81.87 W 5970253.75 N 498862.84 E 4.418 82.30 924.11 21.800 278.950 796.73 910.43 15.44 N 113.69 W 5970260.52 N 498831.02 E 4.549 114.58 1014.50 24.920 276.770 879.70 993.40 20.30 N 149.19 W 5970265.38 N 498795.52 E 3.581 150.36 1108.82 28.140 273.590 964.08 1077.78 24.04 N 191.13 W 5970269.12 N 498753.58 E 3.730 192.47 1204.95 32.780 272.970 1046.92 1160.62 26.81 N 239.77 W 5970271.90 N 498704.94 E 4.838 241.17 1298.41 40.230 273.650 1121.99 1235.69 30.04 N 295.24 W 5970275.15 N 498649.48 E 7.983 296.71 1391.78 44.060 273.910 1191.21 1304.91 34.18 N 357.74 W 5970279.29 N 498586.97 E 4.106 359.34 1485.27 47.470 274.710 1256.42 1370.12 39.23 N 424.52 W 5970284.34 N 498520.19 E 3.699 426.31 1580.34 53.170 276.360 1317.10 1430.80 46.32 N 497.31 W 5970291.45 N 498447.41 E 6.142 499.44 1674.17 60.000 276.320 1368.74 1482.44 54.96 N 575.11 W 5970300.11 N 498369.61 E 7.279 577.68 1761.88 68.460 275.070 1406.84 1520.54 62.77 N 653.63 W 5970307.92 N 498291.09 E 9.730 656.59 1858.40 68.440 275.400 1442.29 1555.99 70.96 N 743.03 W 5970316.12 N 498201.69 E 0.319 746.36 1952.28 70.970 272.330 1474.86 1588.56 76.87 N 830.86 W 5970322.05 N 498113.86 E 4.083 834.38 2046.45 71.700 272.730 1505.00 1618.70 80.81 N 919.99 W 5970326.00 N 498024.73 E 0.873 923.53 2139.31 72.320 271.920 1533.68 1647.38 84.39 N 1008.24 W 5970329.59 N 497936.48 E 1.065 1011.77 2235.46 70.500 271.770 1564.33 1678.03 87.33 N 1099.32 W 5970332.54 N 497845.40 E 1.899 1102.78 ~ 2332.53 70.640 273.330 1596.62 1710.32 91.40 N 1190.77W 5970336.63 N 497753.95 E 1.522 1194.25 2425.62 68.500 275.190 1629.12 1742.82 97.87 N 1277.75 W 5970343.11 N 497666.97 E 2.965 1281.47 -J I I 2517.69 68.430 276.780 1662.91 1776.61 106.80 N 1362.93 W 5970352.05 N 497581.8ð E 1.608 1367.09 2611.08 68.700 275.860 1697.04 1810.74 116.37 N 1449.33 W 5970361.63 N 497495.40 E 0.961 1453.99 2702.91 66.990 277.540 1731.67 1845.37 126.28 N 1533.79 W 5970371.56 N 497410.94 E 2.518 1538.98 2797.56 67.130 275.840 1768.57 1882.27 136.43 N 1620.36 W 5970381.72 N 497324.37 E 1.661 1626.09 2891.69 67.920 275.040 1804.55 1918.25 144.68 N 1706.95 W 5970389.98 N 497237.79 E 1.149 1713.06 2986.67 67.380 272.630 1840.67 1954.37 150.56 N 1794.58 W 5970395.87 N 497150.15 E 2.415 1800.89 3078.69 65.860 270.390 1877.19 1990.89 152.79 N 1879.01 W 5970398.12 N 497065.72 E 2.779 1885.21 3176.84 66.070 275.690 1917.19 2030.89 157.55 N 1968.48 W 5970402.88 N 496976.25 E 4.936 1974.77 3268.23 66.080 274.840 1954.26 2067.96 165.21 N 2051.67W 5970410.56 N 496893.07 E 0.850 2058.30 3363.89 65.930 274.240 1993.16 2106.86 172.13N 2138.78 W 5970417.49 N 496805.95 E 0.594 2145.69 ------ ------- -- - ---------------------- 20 November, 2001 - 9:08 Page 2 of 6 DrillQuest 2.00.08.005 . Sperry-Sun Drilling Services Survey Report for2T-39 Your Ref: AP/501032039200 Job No. AKMM11168, Surveyed:.9 November, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2T Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3456.18 67.680 271.690 2029.51 2143.21 176.50 N 2223.49 W 5970421.88 N 496721.25 E 3.169 2230.47 ..-. ; 3550.52 67.130 274.720 2065.76 2179.46 181.37 N 2310.44 W 5970426.75 N 496634.30 E 3.022 2317.52 ~ '.....- 3642.35 65.040 275.820 2102.99 2216.69 189.07 N 2394.02 W 5970434.47 N 496550.71 E 2.526 2401.46 3737.80 66.220 274.430 2142.37 2256.07 196.83 N 2480.62 W 5970442.24 N 496464.12 E 1.813 2488.40 3831.45 64.590 275.490 2181.35 2295.05 204.19 N 2565.45 W 5970449.61 N 496379.29 E 2.022 2573.54 3923.53 67.410 275.480 2218.80 2332.50 212.23 N 2649.17 W 5970457.66 N 496295.57 E 3.063 2657.65 4020.37 68.650 278.370 2255.04 2368.74 223.07 N 2738.31 W 5970468.51 N 496206.43 E 3.049 2747.38 4107.87 66.770 278.460 2288.22 2401.92 234.91 N 2818.40 W 5970480.37 N 496126.35 E 2.151 2828.17 4205.14 67.760 276.910 2325.82 2439.52 246.91 N 2907.30 W 5970492.37 N 496037.45 E 1.788 2917.76 4300.69 66.910 277.690 2362.64 2476.34 258.11 N 2994.75 W 5970503.59 N 495949.99 E 1.166 3005.84 4393.60 67.680 277.260 2398.50 2512.20 269.26 N 3079.74 W 5970514.75 N 495865.01 E 0.932 3091.46 4488.57 67.820 276.820 2434.46 2548.16 280.03 N 3166.97 W 5970525.53 N 495777.78 E 0.453 3179.29 4583.25 68.150 276.140 2469.95 2583.65 289.93 N 3254.19 W 5970535.45 N 495690.57 E 0.752 3267.02 4678.47 69.130 273.760 2504.63 2618.33 297.58 N 3342.53 W 5970543.11 N 495602.23 E 2.545 3355.69 4774.70 68.570 273.860 2539.36 2653.06 303.54 N 3432.07 W 5970549.09 N 495512.68 E 0.590 3445.43 4865.35 68.400 275.440 2572.60 2686.30 310.38 N 3516.13 W 5970555.93 N 495428.63 E 1.632 3529.76 4961.22 68.790 272.290 2607.60 2721.30 316.39 N 3605.17 W 5970561.96 N 495339.59 E 3.086 3618.99 5052.23 68.380 271.100 2640.83 2754.53 318.90 N 3689.86 W 5970564.48 N 495254.90 E 1.298 3703.59 ..-. 5144.84 68.290 270.500 2675.02 2788.72 320.10 N 3775.91 W 5970565.69 N 495168.84 E 0.610 3789.45 -..J 5240.25 68.530 274.370 2710.14 2823.84 323.87 N 3864.53 W 5970569.47 N 495080.23 E 3.780 3878.08 I, 5334.62 68.250 275.090 2744.89 2858.59 331.11 N 3951.97 W 5970576.72 N 494992.7~ E 0.769 3965.81 5427.07 68.100 278.210 2779.27 2892.97 341.04 N 4037.20 W 5970586.67 N 494907.56 E 3.137 4051.57 5522.10 68.520 275.130 2814.40 2928.10 351.29 N 4124.89 W 5970596.93 N 494819.87 E 3.044 4139.81 5616.05 69.500 273.690 2848.05 2961.75 358.03 N 4212.34 W 5970603.69 N 494732.42 E 1.771 4227.52 5710.89 69.050 274.830 2881.62 2995.32 364.62 N 4300.80 W 5970610.29 N 494643.96 E 1.220 4316.22 5803.84 68.570 274.390 2915.22 3028.92 371.59 N 4387.18 W 5970617.26 N 494557.58 E 0.679 4402.89 5896.17 67.740 273.060 2949.57 3063.27 377.16 N 4472.70 W 5970622.85 N 494472.07 E 1.611 4488.57 5981.06 68.120 272.540 2981.47 3095.17 381.00 N 4551.27 W 5970626.70 N 494393.49 E 0.723 4567.19 6041.47 68.290 271.260 3003.90 3117.60 382.86 N 4607.33 W 5970628.57 N 494337.43 E 1.987 4623.21 6134.55 65.710 272.410 3040.27 3153.97 385.59 N 4692.96 W 5970631.31 N 494251.80 E 2.996 4708.77 ----.--------- -0_0___0 20 November, 2001 - 9:08 Page 3 of 6 DrillQlIest 2.00.08.005 . Sperry-Sun Drilling Services Survey Report for 2T-39 Your Ref: API 501032039200 . Job No. AKMM11168, Surveyed:_9 November, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2T Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6225.89 63.500 274.250 3079.44 3193.14 390.37 N 4775.33 W 5970636.11 N 494169.44 E 3.027 4791.25 -... 6320.50 62.620 276.940 3122.31 3236.01 398.59 N 4859.26 W 5970644.33 N 494085.51 E 2.700 4875.57 \wi 6413.32 63.200 276.790 3164.58 3278.28 408.47 N 4941.30 W 5970654.22 N 494003.47 E 0.641 4958.15 6508.70 63.500 277.160 3207.36 3321.06 418.82 N 5025.92 W 5970664.59 N 493918.85 E 0.468 5043.34 6600.91 63.060 276.880 3248.82 3362.52 428.88 N 5107.66 W 5970674.66 N 493837.11 E 0.549 5125.64 6696.18 62.660 276.290 3292.28 3405.98 438.61 N 5191.88 W 5970684.40 N 493752.89 E 0.693 5210.37 6790.44 62.110 276.400 3335.97 3449.67 447.84 N 5274.89 W 5970693.64 N 493669.88 E 0.593 5293.86 6883.72 61.540 276.820 3380.01 3493.71 457.30 N 5356.57 W 5970703.12 N 493588.20 E 0.729 5376.05 6977.42 61.250 275.450 3424.88 3538.58 466.10 N 5438.36 W 5970711.92 N 493506.41 E 1.320 5458.28 7069.20 60.870 273.940 3469.29 3582.99 472.67 N 5518.41 W 5970718.51 N 493426.37 E 1.498 5538.60 7163.40 60.270 274.240 3515.58 3629.28 478.52 N 5600.24 W 5970724.37 N 493344.54 E 0.695 5620.64 7255.95 59.710 273.210 3561.87 3675.57 483.73 N 5680.21 W 5970729.59 N 493264.57 E 1.138 5700.76 7350.73 59.320 273.140 3609.95 3723.65 488.25 N 5761.77 W 5970734.12 N 493183.01 E 0.416 5782.41 7446.43 58.760 273.220 3659.18 3772.88 492.81 N 5843.70 W 5970738.69 N 493101.08 E 0.590 5864.44 7538.34 58.230 272.100 3707.21 3820.91 496.45 N 5921.98 W 5970742.34 N 493022.80 E 1.188 5942.75 7633.54 57.760 271.990 3757.67 3871.37 499.33 N 6002.66 W 5970745.23 N 492942.12 E 0.503 6023.39 7729.17 57.150 273.090 3809.11 3922.81 502.90 N 6083.19 W 5970748.81 N 492861.59 E 1.161 6103.94 7822.25 56.840 274.310 3859.82 3973.52 507.93 N 6161.08 W 5970753.86 N 492783.70 E 1.149 6181.98 ~- 7917.81 56.280 273.720 3912.48 4026.18 513.52 N 6240.63 W 5970759.45 N 492704.15 E 0.780 6261.72 J 8012.88 56.560 274.480 3965.06 4078.76 519.18 N 6319.63 W 5970765.13 N 492625.16 E 0.728 6340.91 \ , 8106.D6 56.500 275.120 4016.45 4130.15 525.68 N 6397.08 W 5970771.64 N 492547.76 E 0.577 6418.64 8201.53 55.940 274.960 4069.53 4183.23 532.66 N 6476.13 W 5970778.63 N 492468.66 E 0.603 6497.99 8291.51 56.970 273.130 4119.25 4232.95 537.94 N 6550.93 W 5970783.92 N 492393.86 E 2.045 6572.98 8386.44 58.070 274.850 4170.23 4283.93 543.52 N 6630.81 W 5970789.51 N 492313.98 E 1.918 6653.04 8478.56 57.820 273.910 4219.13 4332.83 549.48 N 6708.66 W 5970795.48 N 492236.13 E 0.906 6731.12 8574.73 57.540 275.090 4270.54 4384.24 555.86 N 6789.67 W 5970801.87 N 492155.11 E 1.077 6812.38 8667.98 57.320 276.200 4320.74 4434.44 563.58 N 6867.88 W 5970809.61 N 492076.91 E 1.031 6890.96 8761.17 58.160 275.600 4370.49 4484.19 571.68 N 6946.26 W 5970817.72 N 491998.53 E 1.053 6969.74 8860.48 58.080 276.290 4422.94 4536.64 580.42 N 7030.14 W 5970826.47 N 491914.65 E 0.595 7054.06 8957.26 57.980 276.270 4474.18 4587.88 589.40 N 7111.75W 5970835.46 N 491833.05 E 0.105 7136.13 ..__.- -------. _u- -. - .-----.-. - .--------.---- 20 November, 2001 - 9:08 Page 4 of 6 Dri/lQuest 2.00.08.005 - Sperry-Sun Drilling Services Survey Report for 2T-39 Your Ref: API 501032039200 Job No. AKMM11168, Surveyed:.9 November, 2001 . . North Slope, Alaska Kuparuk River Unit Kuparuk 2T Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth . Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9046.61 58.610 277.460 4521.14 4634.84 598.49 N 7187.21 W 5970844.56 N 491757.58 E --- 1.335 7212.09 \ 9140.71 59.310 278.480 4569.66 4683.36 609.67 N 7267.06 W 5970855.75 N 491677.74 E 1.190 7292.59 ~ '--.. 9235.74 59.290 277.100 4618.18 4731.88 620.74 N 7348.01 W 5970866.84 N 491596.78 E 1.249 7374.18 9327.52 58.950 276.410 4665.28 4778.98 630.01 N 7426.24 W 5970876.11 N 491518.56 E 0.744 7452.90 9422.39 58.600 276.740 4714.46 4828.16 639.30 N 7506.83 W 5970885.41 N 491437.97 E 0.474 7533.99 9514.36 58.180 277.050 4762.67 4876.37 648.70 N 7584.59 W 5970894.83 N 491360.22 E 0.539 7612.26 9608.22 58.130 277.360 4812.19 4925.89 658.70 N 7663.69 W 5970904.84 N 491281.11 E 0.286 7691.92 9703.37 58.300 276.970 4862.31 4976.01 668.79 N 7743.94 W 5970914.94 N 491200.87 E 0.392 7772.73 9798.97 58.210 277.060 4912.61 5026.31 678.72 N 7824.63 W 5970924.88 N 491120.18 E 0.124 7853.96 9891.01 57.450 274.210 4961.62 5075.32 686.37 N 7902.15 W 5970932.55 N 491042.66 E 2.748 7931.85 9984.53 56.020 271.100 5012.93 5126.63 690.01 N 7980.24 W 5970936.19 N 490964.57 E 3.173 8009.97 10079.38 55.690 272.070 5066.16 5179.86 692.18 N 8058.71 W 5970938.38 N 490886.10 E 0.915 8088.35 10173.66 55.550 270.510 5119.41 5233.11 693.93 N 8136.49 W 5970940.14 N 490808.31 E 1.374 8166.02 10265.36 55.500 269.220 5171.31 5285.01 693.76 N 8212.09 W 5970939.97 N 490732.72 E 1.161 8241.33 10361.17 56.110 272.540 5225.17 5338.87 694.98 N 8291.31 W 5970941.21 N 490653.50 E 2.936 8320.38 10454.75 55.730 271.890 5277.61 5391.31 697.98 N 8368.76 W 5970944.22 N 490576.05 E 0.704 8397.81 10548.51 56.710 273.970 5329.74 5443.44 701.97 N 8446.58 W 5970948.22 N 490498.23 E 2.119 8475.70 10640.13 57.230 274.550 5379.68 5493.38 707.68 N 8523.18 W 5970953.94 N 490421.63 E 0.777 8552.50 ~ 10734.87 57.090 274.060 5431.06 5544.76 713.65 N 8602.55 W 5970959.92 N 490342.26 E 0.459 8632.10 J 10828.14 57.520 274.550 5481.44 5595.14 719.54 N 8680.82 W 5970965.83 N 490263.99 E 0.639 8710.59 ! I 10920.56 57.160 274.000 5531.32 5645.02 725.35 N 8758.41 W 5970971.64 N 490186.40 E 0.635 8788.39 11014.56 56.610 274.710 5582.67 5696.37 731.32 N 8836.91 W 5970977.63 N 490107.90 E 0.862 8867.12 11107.30 56.890 274.700 5633.52 5747.22 737.68 N 8914.21 W 5970984.00 N 490030.60 E 0.302 8944.68 11173.45 57.560 275.360 5669.33 5783.03 742.56 N 8969.61 W 5970988.88 N 489975.20 E 1.315 9000.30 11284.91 58.590 274.910 5728.27 5841.97 751.03 N 9063.83 W 5970997.36 N 489880.98 E 0.986 9094.89 11380.62 59.480 274.810 5777.51 5891.21 757.98 N 9145.61 W 5971004.33 N 489799.21 E 0.934 9176.96 11477.54 59.080 273.880 5827.02 5940.72 764.29 N 9228.69 W 5971010.65 N 489716.13 E 0.922 9260.28 11572.94 58.240 274.080 5876.64 5990.34 769.95 N 9309.97 W 5971016.32 N 489634.85 E 0.899 9341.75 11615.98 58.010 274.730 5899.37 6013.07 772.75 N 9346.41 W 5971019.13 N 489598.41 E 1.389 9378.30 11,85.00 58.010 274.730 5935.94 6049.64 777.58 N 9404.75 W 5971023.96 N 489540.07 E 0.000 9436.84 Projected Survey ..--.--.___n_m__-__' ----'.'-----------------"'- n- --.----- 20 November, 2001 - 9:08 Page 5 of 6 DrillQuest 2.00.08.005 .. Sperry-Sun Drilling Services Survey Report for 2T-39 Your Ref: API 501032039200 Job No. AKMM11168, Surveyed:.9 November, 2001 . - Kuparuk River Unit North Slope, Alaska Kuparuk 2T All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 113. T MSL. Northings and Eastings are relative to" 265' FSL & 556' FWL. Magnetic Declination at Surface is 25.789° (12-Nov-01) -~ ~ ~ The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 265' FSL & 556' FWL and calculated along an Azimuth of 274.760° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11685.00ft., The Bottom Hole Displacement is 9436.84ft., in the Direction of 274.726° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11685.00 6049.64 777.58 N 9404.75 W Projected Survey Survey tool program for 2T-39 ~) From r.,easured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) I ~ Survey Tool Description 0.00 736.93 0.00 732.59 736.93 11685.00 732.59 Tolerable Gyro (2T -39 Gyro) 6049.64 MWD Magnetic (2T -39) - ------_u- ._------- 20 November, 2001 - 9:08 Page 6 of 6 DrillQuest 2.00.08.005 '@1f&1f~ @~ &r1Æ@~ DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS December 26, 2001 Phillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Attention: Paul K. Wharton Senior Landman Subject: Tract Operation Extension- ADL 25568 Kuparuk 2T-39 Dear Mr. Wharton: ... , II \. TONY KNOWLES, GOVERNOR ,':?() H~ 3601 C STREET. SUITE 1380 ANCHORAGE, ALASKA 99503-5948 PHONE: (907) 269-8800 FAX: (907) 562-3852 Reference is made to the Division of Oil and Gas' approval to drill Kuparuk 2T-39 (Well) and conduct a plan of testing, evaluation and pilot production of the Well using Kuparuk River Unit (KRU) Kuparuk Participating Area (KPA) facilities, dated October 15, 2001, and Jack Walker's e- mail request of December 17, 2001 to extend the date to submit a Kuparuk Participating Area application associated with the Well. Based on the information provided in the e-mail, I approve the request to extend the date of submittal of the KP A application from December 31, 2001 to March 4, 2002. Except for the new KP A application submittal date, the October 15, 2001 approval letter remains unchanged. Sincerely, ~/?--- Q /"'- '- / ~.ø' Mark D. Myers Director cc: AOGCC Jack Walker - PAl (Fax #263-4035) KRU .Kuparuk 2T -39- TractOps_Extension.doc RECEIVED DEC 2 8 2001 Alaska Oil & Gas Cons. Commission Anchorage "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." 12/13/01 Scbllnbepger NO. 1692 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Alln: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~ Well Job # Log Description Date BL Sepia CD Color .;} ol-;l ott ;\. 08 - I B3 ;l O' -Iqq ~O, ..~ ';>01- ~¥ 1 F-16A SBHP SURVEY 11/30/01 1 1 2T-39 SBHP SURVEY 12/04/01 1 1 1C-125 21501 SCMT 11/05/01 1 1 F-16A 21502 USIT 11/12/01 1 2K-28 21503 SCMT 11120/01 1 . - -{i=( :t=IVt-J ) SIGNED:~ {Åa~~ DATE: DEe 2 1-20-01- -- Alaska Oil & Gas Cons. CommiSSIO! Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you'Anchorage t ~V&\VŒ (ill~ &\~&\~[[&\ ."" \ ALAS IiA. 0 IL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. -¡TH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. . PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit 2T -39 Phillips Alaska, Inc. Pennit No: 201-183 Sur Loc: 264' FSL, 556, FWL, Sec. 1, T11N, R8E, UM Btmhole Loc. 1042' FSL, 1705' FWL, Sec. 3, T11N, R8E, UM Dear Mr. Mallary: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confinned by a valid Fonnation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on fonn 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on 2T must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pennit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 baITels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. 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. aniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this13th day of September, 2001 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 2T-39 Permit to drill application I( Subject: 21-39 Permit to drill application Date: Wed, 12 Sap 2001 13:00:47 -0800 From: "Scott L Lowry" <sUowry@ppco.com> To: tom_maunder@admin.state.ak.us Tom, Please note the following changes to the 2T-39 application: Surface casing will be 9 5/8" 40# L-80 BTC (see step 4 in proposed drilling program). 7" Intermediate casing will be tested to 3500 psi prior to drill out (see step 11 in proposed drilling program). Thanks, Scott Lowry Drilling Engineer Phillips Alaska Inc. 907 -265-6869 1 of 1 ( 9/12/011:35 PM ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ~, Post Office Box 100360 Anchorage, Alaska 99510-0360 Chuck Mallary Phone (907) 265-6434 Fax: (907) 265-1535 Email: crmalla@ppco.com September 5,2001 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, producer 2T -39 Dear Ms. Taylor: j' J,~ t~::; ,~ Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore~ce well, KRU 2T-39, a development well. ' Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. ~e:2 I Chuck Mallary Drilling Engineering Supervis r R'" ~'I"'a",", ,"""\' !11",' "",,", ~I, \" I/' 'I?',WH ~ ..,'~, " (" '. 1'1 fw I, f~ '1 " , ~""" . iw""" ~ "[....,, ¡~ ~ , ~. J 1>0.,.., ~ / W......., ",-,Þ SEP 11 2001 ,Alaska Oil & Gas Cons. Commission /\nchorage t J1A~ C\iI¡}lJl ~ ~< ~ r (' ~J \) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25 005 / 1a. Type of work: Drill ø Redrill 0 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil ß ft- Re-entry 0 Deepen 0 Service r~ Development Gas 0 Single Zone 0 Multiple Zone ~ 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation J,.. 6z9;1ðì f1.) Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 2556B ALK 2666 " Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) 264' FSL, 556' FWL, Sec. 1, T11 N, RBE, UM Kuparuk River Unit Statewide At top of productive Interval 8. Well number Number 1017' FSL, 2015' FWL, Sec. 3, T11 N, RBE, UM 2T-39 # 59-52-1 BO At total depth 9. Approximate spud date Amount 1042' FSL, 1705' FWL, Sec. 3, T11 N, RBE, UM October 5, 2001 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres In property 15. Proposed depth (MD and TVO) 2015' @ Target feet 2T-OB 13' @ 400' feet 2560 11641 ' M D I 6045 . TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2» Kickoff depth: 300' MD Maximum hole angle 67.Bo Maximum surface 2B39 psig At total depth (TVD) 3476 psig 18. Casing program Settlna Depth size Specifications Top Bottom Quantitv of Cement Hole Casing Weight Grade CoupllnQ LenÇJth MD TVD MD TVD (Include stage data) 24" 16" 62.5# H-40 Weld 120' 35' 35' 155' 155' 260 sx AS I 12.25" 9.625" 36# J-55 BTC 5975' 35' 35' 6010' 311B' 540 sx AS Lite & 600 sx LiteCRETE 8.5" 7" 26# L-80 BTC 11107' 35' 35' 11142' 5775' 170 sx Class G 6.125" 3.5" 9.3# L-BO EUE 8rd M 649' 10992' 5694' 11641' 6045' 150 sx Gasblok 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production [~r'~ cg:"m '~\\¡rE 0 " ,.{ t:" "'"'" ~ IV '~",.. , !~ . ii-. . , SEP 11 2001 Perforation depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee ø Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program ø Time vs depth plot DRefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21, I hereby 7!l'l:. :!(;;ct ': the best 01 ~ ~owh¡dge Questions? Scott Lowry 265-686~ Da~ 7 ~ø ~~v, Signed J , ---.., ..,. TItle: Drilling Engineering Supervisor C. Ma a I J Commission Use Onh Permit Number. / I ð' 3 API nu~'er 3 2c. '*?92Có Approval date v}.1.3,0 See cover letter '20 -- ~ 50- /0 .- . ) ~ - for other requirements Conditions of approval Samples required 0 Yes IlJ No Mud log required 0 Yes 1&1 No Hydrogen sulfide measures I&] Yes 0 No Directional survey required RI Yes 0 No Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M;D ~ ?)SOa '\'>~\ M\~'t'\A...~\,"" '3sj?~~ Other: .JRIGINAL SIGNED BY Q, /9 r () I 0 Tavlor Seamount by order of ~ .. r" ~ J\ f . ApDroved bv Commissioner the commission D~e j' I ~ i j '~ll 1 1\,1 ",.rj. Form 10-401 Rev. 12/11B5. Submit in triplicate ( t AJplication for Permit to Drill, Well 2T-39 Saved: 5-Sep-O1 Permit It - Kuparuk Well 2T-39 Application for Permit to Drill Document MoximizE Well Vg I '-I E; Table of Contents 1. Well Name................................................................................. .... ....... ........ ............. 2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Sum mary ................................................................................................... 2 Requirements of 20 AAC 25. 005( c)(2) ................................................................................................... 2 Requirements of 20 AAC 25. 050(b)........................................................................................................ 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ...................................................................................................3 4. Dri II i ng Hazards Information....................................................... ............................ 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casi ng and Cementing Program ......... ........................ ............................. ......... ......3 Requirements of 20 AAC 25. 005(c)(6) ................................................................................................... 3 7. Diverter System Information................................................................................... 4 Requirements of 20 AAC 25. 005( c)(7) ................................................................................................... 4 8. Dri II i ng FI u id Program............................................................ .... .............................4 Requirements of 20 AAC 25. 005(c)(B) ................................................................................................... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis...................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................5 12. Evidence of Bond i ng............................... ..................... ........... ............ ..................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Dri Iii ng Prog ram....... ............................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................5 2T-39 PERMIT IT DOC 0 R1GTÑ~ L (, ,i ,,' \1, Application for Permit to Drill, Well 2T-39 Saved: 5-Sep-O1 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................6 15. Attachments.............. ..... .................. ........................................................................ 6 Attachment 1 Directional Plan................................................................................................................6 Attachment 2 Drilling Hazards.............................................................................................6 Attachment 3 Well Schematic.............................................................................................. 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25:040(b). For a well with multiple well branche:,~ each branch must similady be identified by a unique name and API number by adding a suffix to the name d~}signated for the well by tl7e operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2T-39. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An applk::"JtlÒn for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commi.%ìÒn and kJentified in the application: (2) a plat idenbfying tile property and the property's owners and showing (A)the coordinates of the proposed location of the well at the s'UrfôCf!/ at the top of each objective formation, and at total depth rel'erenc:yxl to governmental section lines: (B) the coordinates o(the proposed location of the well at the surfÚCt'/ referenCé:!d to the state plane cvordinate system for this state as maintained by the National Geodetic Swvey in the National Oceanic and Atmosphenc Admlr7i..'itrtJtion' (C) the propo::,-ed depth of'the well at the top of each objective formation and at total depth; Location at Surface I 264' FSL, 556' FWL, Sec 1, TllN, R8E, UM NGS Coordinates RKB Elevation 115.1' AMSL Northings: 5,970,245 Eastings: 498,945 Pad Elevation 80.5' AMSL Location at Top of Productive Interval Ku aruk "C4" Sand NGS Coordinates Northings: 5,971,004 1017' FSL, 2015' FWL, Sec 3, TllN, R8E, UM Eastings: 489,844 11 324' 5873' 5758' Location at Total De th 1042' FSL 1705' FWL NGS Coordinates Northings: 5,971,026 Eastings: 489,578 11 641' 6045' 5930' and (0) otherinformatio/7 required by 20 AAC 25:050(b); Requirements of 20 AAC 25. 050 (b) if a well is to be intentionally deviatec¿ the application for a Permit to Drill (Form .1 O~401) must (1) include a plat~ drawn to a suitable scale/ showing the path of the proposed wellbore/ including all adjacent wellbores within ,ZO() ft'et of any portion or the propO!ied wel¿' Please see Attachment 1: Directional Plan and (2) lor all wells within 2{)(} feet of the proposed wellbore 2T~39 PERMIT IT. DOC OlffSfN A L ( (' Application for Permit to Drill, Well 2T-39 Saved: 5-Sep-O1 (A) list the names ot the operators of t/70se wells¡ to the extent that t/70se names are known or discoverable Ii] public record~ and shm'v that each named operator has been furnished a copy of the application by ærtifìed mai¿' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a PermIt to Drill must be accompanied by t3ach of tht3 f..í)llmv!i79 Items¡ except for an Item already on file with the commission and identified 1f7 tht3 application: (3) a diagram and desCliption of the blowout prevention equipmt3nt (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25. 03~ as applicable/ Please reference BOP schematics on file for Nabors 16E. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Dr/II must be accompanied by each of the following ¡fem5~ except for an item already on file with the commission and identified in the application: (4) information on drilling hazards¡ ineiuding (A) the maximum downhole pressure that may be encounterert CrIteria used to determlÌ7e it;, and maximum potenti(JI surface pressure based on a methane gradient; Based on offset well data, the expected reservoir pressure in the A2 Kuparuk sand for the 2T-39 well is -3500 psi at 5800' tvd, 0.60 psi/ft or 11.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling 2T-39 is calculated using above reservoir pressure, a gas gradient of 0.11 psi/ft, and top of the Kuparuk A2 sand target at 5793' tvd: MPSP =(5793 ft)*(0.60 - 0.11 psi/ft) = 2839 psi (8) data on potential gas 20nes~' The well bore is not expected to penetrate any gas zones. and (C) data concerning potential cau.';es of 110119 problems sl.lch as abnormally geo.pressured stratal lost circulation ZOf7es~ and zones that flave a propenslLy for differential stic*ing; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application fÓr a Permit to Drill must be accompanied by each of the f'ollowing item:.,~ except f'or an item already on file with the commi:;,:;¡on and Identified in the applk:t'1tion: (5) a descriptk)f7 of tl7e procedure !br conductJi79 formation integrity te.<;t:'i¡ as required under 20 AAC 2.¡;;.O30(f); Drill out surface and intermediate casing shoe and perform LOT test or FIT (maximum of 16 ppg EMW) in accordance with the Kuparuk LOT / FIT procedure, that Phillips Alaska has on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of'the f'ollowing items~ except for an item already on file witt) the commi:;,:;lon and Identified In the appllc:(')tion: (6) a complete proposed casing and cementing program as required by 20 AAC 25. 03~ and a desCliption of any slotted liner., pre... perforated liner; or screen to be installed; 2T-39 PERMIT IT. DOC 0 Rffitf(~ L .~ " (}o\I-'Plication for Permit to Drill, Well 2T-39 Saved: 5-Sep-O1 Casing and Cementing Program I Hole Top Btm CsglTbg Size Weight Length MO/TVO MO/TVO 00 (in) (in) (/b/ft) Grade Connection (ft) (ft) u(ttL Cement Program 16 24 62.5 H-40 Welded 120' 35'/35' 155'/155' 260 sx 15.8 ppg ASl 9-5/8 12-1/4 36.0 J-55 BTC 5975' 35'/35' 6010'/3118' Lead: 540 sx 10.7 ppg AS Lite Tail: 600 sx 12.0 ppg LiteCRETE Planned TOC=Surface 7 8-1/2 26.0 L-80 BTC 11107' 35'/35' 11,142'/5775' 170 sx 15.8 ppg 'G' wI add. Planned TOC=10,343' 3-1/2 6-1/8 9.3 L-80 EUE 8rd 649' 10,992' / 11,641'/6045' 150 sx 15.8 ppg Mod 5694' GASBLOK w/ add. Planned TOC=10,793' 3-1/2 9.3 L-80 EUE 8rd 10957' 35'/35' 10,992'/5694' Mod 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill mlJ.'st be accompanied by each of the following Items, except for an item already £1/7 file with the commission and identified i/7 the application: (7) a diagram and description of the diverter system as requin,;d by 20 MC 25: 035~ unless thi,; requirement is wFJived by the commiS~ìon under 20 AAC 25JJ35(h)(Z); Please reference diverter schematic on file for Nabors 16E. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following item;,~ except for an item already on file with the c£1mmission and Identified in the application: (8) a drilling flUId prograrn including a diagram and descfliJtiol7 of the dn/ling fluid system, as required by 20 AA C 25, 033; Drilling will be done using mud systems having the following properties: Surface Inte/Va/ S ud Mud 8.5-9.6 60-250* 20- 70 20-60 10-30 6-15 9.5-10 +10 Intermediate Inte/Va/ LSND 8.6-9.6 40-55 8-25 5-25 3-10 5-15 9.5-10 < 6% Production Interval LSND 12.0 45-55 15-25 20-25 3-7 8-10 HTHP 9-10 LGS < 40/0 *Spud mud should be adjusted to a FV between 150-250 sec/qt to drill gravel beds Diagram of Nabors 16E Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 2T-39 PERMIT IT. DOC onf ¥(VAL (' it l"'\¡Jplication for Permit to Drill, Well 2T-39 Saved: 5-Sep-O1 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the folloWJf¡g item~ except for an item already on file with the commission and Identified in the application: (9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25. 033(f); NI A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the t'ollowing items/ except for an item already 0/7 file wIth tllr:? commission and Identified i/7 the application: (10) for an exploratory or stratigraphic test wel¿ a seismic refraction or reflectio/7 analysis as required by 20 AAC 25. 061 (a); NI A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application tor a Permit to Drill must be accompanied by each of the following items¡ except for an item already on tìle wlNI the commission and identified in the application: (0) tor a well drilled from an ort!ihore platfOl7rJ, mobile bottom-founded structure, jaä-up riÇJ, or floating drilling ve5:'C'ie¿ an analysis of seabed conditions as required by 20 AAC 25. 061 (b); NI A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a PermIt to Olill must be accompanied by each of the following Items, except fÓr an item already 017 tHe with the commission and identified In the application: (12) evIdence showing that the (('~ql1irements of.?O AAC 25:025 {Bonding}have been met~. Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An applícation for a Penni! to Onll must be accompanied by each of" the following Items~ except 1'01' an Item already on tHe with tile evmmissio/7 and idenNìed in tile application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor to +1- 155' RKB. Weld landing ring on conductor. 2. Move in I rig up Nabors Rig 16E Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+1 6010 MD') according to directional plan. Run MWD I LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 36.0# J-55 BTCM casing to surface using lightweight permafrost cement lead slurry and LiteCRETE tail slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job or stage job if needed. Note: 9 5/8" port collar to be installed at +1- 1000'. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 2T-39 PERMIT IT DOC 0 RtdJW~ L i '~ ~. A¡;plication for Permit to Drill, Well 2T-39 Saved: 5-Sep-O1 7. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 8. Directionally drill 8-1/2" hole to 11,142' MD according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 9. Run 7" 26.0# L-80 BTCM casing and cement. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030 10. Nipple up BOPE and test to 5000 psi. Record results. 11. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 12. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 13. Drill 6-1/8" hole to well total depth (+/- 11,641' MD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 14. Run open hole e-line or drill pipe conveyed logs as needed. 15. Run and cement 3-1/2" 9.3# L-80 EUE 8RD MOD liner and Baker ZXP hanger/packer assembly. Set packer +/- 150' above intermediate casing shoe to provide appropriate liner lap. 16. Run and land 3-1/2" completion tubing string. 17. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 18. Freeze protect well. Set BPV. Release rig and turn well over to production. 19. Clean location and RDMO. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mlJ..,tc be accompanied by each of the fOllowing item~ except fòr an item already 017 file wIth the cornrnif.;:.c;¡on and Identified in the applic,.-1tion: (14) a general description of how the operatorplans tv dispose of drilling mud and cuttings and a statement of whether tl7e operator ti7tends to request authorization under 20 AAC 25.080 fof' an annular dl'.>f)osal operation in the well.,' Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2T pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 2T pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 2T-39 for annular pumping of fluids occurring as a result of future drilling operations on 2T pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 2T-39 PERMIT IT. DOC 0 RtBrN~ L <::) ::x:. - - ~ - - ~ ........ Kuparuk River North Slope, II, Kuparuk 2T, Slot Ilia Plan: 2T-~fA¡¡¡lc,~T-31;it(""pO1) RevisedS?iliSe¡5tgmber, 2001.. r~~. OSAL REPORT 5 September, 2001 Your Ref: Per Scott Lowry wI Phillips Surface Coordinates: 5970244.61 N, 498945.11 E (70019' 47.7732" N, 1500 DO' 30.8012" W) Surface Coordinates relative to Project H Reference: 970244.61 N, 1054.89 W (Grid) Surface Coordinates relative to Structure: 137.825, 0.20 E (True) Kelly Bushing: 122.00ft above Mean Sea Level -., &i"'E~' #J sun ~ït:~~~ AHdí~Þ'~11 Làdfi'$1f Proposal Ref: pro960B Sperry-Sun Drilling Services . ~" Proposal Report for Plan: 2T-39 - 2T-39 (wp01) Your Ref: Per Scott Lowry wi Phillips Revised: 4 September, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2T Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings ,~asliQgs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 0.00 0.000 0.000 -122.00 0.00 0.00 N 0.00 E 5970244,611\1 498945.11 E 0.00 SHL: X = 498,945.107' E & Y = 5970244.609' N (264' FSL & 556' FW Sec 1-T11 N-R8E) ,..--- 100.00 0.000 0.000 -22.00 100.00 0.00 N 0.00 E 5970244,61 N 498945.11 E 0.000 0.00 200.00 0.000 0.000 78.00 200.00 0.00 N ,0:00 E '5970244.61 N 498945.11 E 0.000 0.00 300.00 0.000 0.000 178.00 300.00 0.00 N ,O.OOE 5970244.61 N 498945.11 E 0.000 0.00 Begin Dir @ 3.00/100ft : 300.00ft MD, 300.00ft TVD 400.00 3.000 274.760 277.95 399.95 5970244.83 N 498942.50 E 3.000 2.62 500.00 6.000 274.760 377.63 ' 10.43 W 5970245.48 N 498934.68 E 3.000 10.46 600.00 9.000 274.760 476.77 23.43 W 5970246.56 N 498921 .68 E 3.000 23.51 633.33 10.000 274.760 509.64 28.91 W 5970247.02 N 498916.20 E 3.000 29.02 Increase in Dir Rate @ 4.00/100ft : 633.33ft MD, 631.64ft TVD 700.00 12.667 274.760 575.00 3.49 N 41.97 W 5970248.11 N 498903.14 E 4.000 42.11 800.00 16.667 274.760 671,,73 5.60 N 67.20 W 5970250.21 N 498877.91 E 4.000 67.43 883.33 20.000 ' 872.82 7.77 N 93.31 W 5970252.39 N 498851.80 E 4.000 93.64 Increase in Dir Rate @ 5.00/100ft : 883.33ft MD, 872.82ft TVD 900.00 20.833 274.76å> '",766.44 888.44 8.25 N 99.11 W 5970252.88 N 498846.00 E 5.000 99.45 1000.00 25.833 2+4.760 " 858.23 980.23 11.54 N 138.57 W 5970256.17 N 498806.54 E 5.000 139.05 1100.00 30.833 274~'Zq1 " 946.22 1068.22 15.48 N 185.85 W 5970260.11 N 498759.26 E 5.000 186.49 1200.00 35.833 274\'761 1029.75 1151.75 20.04 N 240.59 W 5970264.68 N 498704.52 E 5.000 241.43 1300.00 40.833 274.761 1108.16 1230.16 25.18 N 302.38 W 5970269.83 N 498642.73 E 5.000 303.43 -'" 1400.00 45.833 274.761 1180.88 1302.88 30.88 N 370.75 W 5970275.54 N 498574.37 E 5.000 372.03 1500.00 50.833 274.761 1247.33 1369.33 37.07 N 445.17 W 5970281.75 N 498499.95 E 5.000 446.71 1587.58 55.212 274.761 1300.00 1422.00 42.88 N 514.88 W 5970287.56 N 498430.24 E 5.000 516.66 Base Permafrost (?) 1600.00 55.833 274.761 1307.03 1429.03 43.73 N 525.08 W 5970288.41 N 498420.04 E 5.000 526.90 1700.00 60.833 274.762 1359.51 1481.51 50.79 N 609.87 W 5970295.49 N 498335.25 E 5.000 611.98 1800.00 65.833 274.762 1404.38 1526.38 58.21 N 698.90 W 5970302.92 N 498246.22 E 5.000 701.32 1839.33 67.800 274.762 1419.86 1541.86 61.21 N 734.93 W 5970305.92 N 498210.19 E 5.000 737.47 End Dir, Start Sail @ 67.80° : 1839.33 C MD, 1541.86ft TVD 1900.00 67.800 274.762 1442.78 1 564.78 65.87 N 790.90 W 5970310.59 N 498154.22 E 0.000 793.64 ::t::J 2000.00 67.800 274.762 1480.57 1602.57 73.56 N 883.17 W 5970318.29 N 498061.95 E 0.000 886.23 - ~ ~ - -- ~ 5 September, 2001 - 7:56 Page 2 of 9 DrillQuest 2.00.09.003 .......... Sperry-Sun Drilling Services Proposal Report for Plan: 2T-39 - 2T-39 (wp01) Your Ref: Per Scott Lowry wI Phillips Revised: 4 September, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2T Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2100.00 67.800 274.762 1518.35 1640.35 81.24 N 975.44 W 5970325.99N 497969.68 E 0.000 978.82 2200.00 67.800 274.762 1556.14 1678.14 88.93 N 1067.71 W . .. 5910333:69.N. .497877.42 E 0.000 1071.40 2300.00 67.800 274.762 1593.92 1715.92 96.62 N 1159.97W ..5970341Ù39N. 497785.15 E 0.000 1163.99 ....-=. . 2400.00 67.800 274.762 1631.70 1753.70 104.30 N 1252.24 W . 5970349109 N 497692.88 E 0.000 1256.58 . .. 497600.62 E 1349.16 2500.00 67.800 274.762 1669.49 1791.49 111 .99 N 1 5970356.79 N 0.000 2600.00 67.800 274.762 1707.27 1829.27 5970364.49 N 497508.35 E 0.000 1441.75 2700.00 67.800 274.762 1745.06 1867.06 5970372.18 N 497416.08 E 0.000 1534.34 2800.00 67.800 274.762 1782.84 1904.84 5970379.88 N 497323.82 E 0.000 1626.93 2900.00 67.800 274.762 1820.63 1942.63 5970387.58 N 497231 .55 E 0.000 1719.51 3000.00 67.800 274.762 1858.41 1980.41 5970395.28 N 497139.29 E 0.000 1812.10 3100.00 67.800 274.762 1896.19 58.10 N 1898.11 W 5970402.98 N 497047.02 E 0.000 1904.69 3200.00 67.800 274.762 1933.98 165.79 N 1990.38 W 5970410.68 N 496954.75 E 0.000 1997.27 3300.00 67.800 274.762 1 173.47 N 2082.65 W 5970418.38 N 496862.49 E 0.000 2089.86 3400.00 67.800 274.762 29 181.16N 2174.92 W 5970426.08 N 496770.22 E 0.000 2182.45 3500.00 67.800 ..204 188.85 N 2267.18 W 5970433.77 N 496677.95 E 0.000 2275.03 3600.00 67.800 2î)85.1 2207.11 196.53 N 2359.45 W 5970441.47 N 496585.69 E 0.000 2367.62 3700.00 67.800 2122.90 2244.90 204.22 N 2451.72 W 5970449.17 N 496493.42 E 0.000 2460.21 3800.00 67.800 2160.68 2282.68 211.90 N 2543.99 W 5970456.87 N 496401.15 E 0.000 2552.80 3900.00 67.800 2198.47 2320.47 219.59 N 2636.25 W 5970464.57 N 496308.89 E 0.000 2645.38 4000.00 67.800 274.762 2236.25 2358.25 227.27 N 2728.52 W 5970472.27 N 496216.62 E 0.000 2737.97 _. 4100.00 67.800 274.762 2274.03 2396.03 234.96 N 2820.79 W 5970479.97 N 496124.35 E 0.000 2830.56 4200.00 67.800 274.762 2311.82 2433.82 242.65 N 2913.06 W 5970487.67 N 496032.09 E 0.000 2923.14 4300.00 67.800 274.762 2349.60 2471.60 250.33 N 3005.32 W 5970495.36 N 495939.82 E 0.000 3015.73 4400.00 67.800 274.762 2387.39 2509.39 258.02 N 3097.59 W 5970503.06 N 495847.56 E 0.000 3108.32 4500.00 67.800 274.762 2425.17 2547.17 265.70 N 3189.86W 5970510.76 N 495755.29 E 0.000 3200.91 4600.00 67.800 274.762 2462.95 2584.95 273.39 N 3282.13 W 5970518.46 N 495663.02 E 0.000 3293.49 C 4700.00 67.800 274.762 2500.74 2622.74 281.07 N 3374.39 W 5970526.16 N 495570.76 E 0.000 3386.08 4800.00 67.800 274.762 2538.52 2660.52 288.76 N 3466.66 W 5970533.86 N 495478.49 E 0.000 3478.67 ::0 4830.38 67.800 274.762 2550.00 2672.00 291 .09 N 3494.69 W 5970536.20 N 495450.46 E 0.000 3506.79 Base West Sak 4900.00 67.800 274.762 2576.31 2698.31 296.45 N 3558.93 W 5970541 .56 N 495386.22 E 0.000 3571.25 - - ~ - - ==== ::t:. 5 September, 2001 - 7:56 Page 3 of 9 DriJ/Quest 2.00.09.003 r--- Sperry-Sun Drilling Services . Proposal Report for Plan: 2T-39 - 2T-39 (wp01) Your Ref: Per Scott Lowry wI Phillips Revised: 4 September, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2T Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastil'lgs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) .. (ft) (°/1 OOft) 5000.00 67.800 274.762 2614.09 2736.09 304.13 N 3651.20 W . 5970549,26?N 495293.96 E 0.000 3663.84 5100.00 67.800 274.762 2651.87 2773.87 311.82 N 3743.46 W .. 5970556;95 N 495201 .69 E 0.000 3756.43 5200.00 67.800 274.762 2689.66 2811.66 319.50 N 3835.73 W . 597Ö564!65N. 495109.42 E 0.000 3849.01 .--. 5300.00 67.800 274.762 2727.44 2849.44 327.19 N 3928.00 W .. 5970572;35 N 495017.16 E 0.000 3941 .60 5400.00 67.800 274.762 2765.23 2887.23 334.87 N 5970580.05 N 494924.89 E 0.000 4034.19 5500.00 67.800 274.762 2803.01 2925.01 5970587.75 N 494832.62 E 0.000 4126.78 5600.00 67.800 274.762 2840.80 2962.80 5970595.45 N 494740.36 E 0.000 4219.36 5700.00 67.800 274.762 2878.58 3000.58 5970603.15 N 494648.09 E 0.000 4311.95 5800.00 67.800 274.762 2916.36 3038.36 5970610.85 N 494555.83 E 0.000 4404.54 5809.62 67.800 274.762 2920.00 3042.00 5970611.59 N 494546.94 E 0.000 4413.45 Tabasco 5900.00 67.800 N 4481.60 W 5970618.54 N 494463.56 E 0.000 4497.12 6000.00 67.800 380.99 N 4573.87 W 5970626.24 N 494371.29 E 0.000 4589.71 6010.00 67.800 381.76 N 4583.10 W 5970627.01 N 494362.07 E 0.000 4598.97 9-5/8" Casing 6100.00 67.800 388.68 N 4666.14 W 5970633.94 N 494279.03 E 0.000 4682.30 6200.00 67.800 396.36 N 4758.41 W 5970641.64 N 494186.76 E 0.000 4774.89 6227.79 67.800 3200.00 398.50 N 4784.05 W 5970643.78 N 494161.12 E 0.000 4800.62 Begin Dir @ 1.00/1O0ft : 6227.79ft M[ 3200.00ft TVD 6300.00 67.078 27~¡Z62... 3105.70 3227.70 404.03 N 4850.50 W 5970649.32 N 494094.67 E 1.000 4867.30 6400.00 66.078 274;762 3145.45 3267.45 411.65 N 4941.94 W 5970656.95 N 494003.23 E 1.000 4959.06 6500.00 65.078 274.762 3186.80 3308.80 419.21 N 5032.68 W 5970664.53 N 493912.49 E 1.000 5050.11 6600.00 64.078 274.762 3229.73 3351.73 426.70 N 5122.68 W 5970672.03 N 493822.49 E 1.000 5140.42 -~ 6700.00 63.078 274.762 3274.22 3396.22 434.14 N 5211.93 W 5970679.48 N 493733.24 E 1.000 5229.98 6800.00 62.078 274.762 3320.28 3442.28 441.51 N 5300.38 W 5970686.86 N 493644.79 E 1.000 5318.74 6900.00 61.078 274.762 3367.87 3489.87 448.81 N 5388.03 W 5970694.17 N 493557.15 E 1.000 5406.69 7000.00 60.078 274.762 3417.00 3539.00 456.04 N 5474.83 W 5970701.42 N 493470.35 E 1.000 5493.79 7100.00 59.078 274.762 3467.63 3589.63 463.20 N 5560.76 W 5970708.59 N 493384.42 E 1.000 5580.02 7200.00 58.078 274.762 3519.77 3641.77 470.28 N 5645.80 W 5970715.68 N 493299.38 E 1.000 5665.35 C 7284.76 57.230 274.762 3565.11 3687.11 476.22 N 5717.16 W 5970721.64 N 493228.02 E 1.000 5736.96 End Dir, Start Sail @ 57.23° : 7284.76 MD, 3687.11ft TVD ::0 7300.00 57.230 274.762 3573.36 3695.36 477.29 N 5729.93 W 5970722.70 N 493215.25 E 0.000 5749.77 - 7400.00 57.230 274.762 3627.49 3749.49 484.27 N 5813.73 W 5970729.69 N 493131.45 E 0.000 5833.86 - 7500.00 57.230 274.762 3681.62 3803.62 491 .25 N 5897.52 W 5970736.69 N 493047.66 E 0.000 5917.94 ~ - - §: 5 September, 2001 - 7:56 Page 4 of 9 DrillQuest 2.00.09.003 .......... Sperry-Sun Drilling Services Proposal Report for Plan: 2T-39 - 2T-39 (wp01) Your Ref: Per Scott Lowry wi Phillips Revised: 4 September, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2T Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings J;astiogs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) . (ft) (°/1 0 Oft) 7600.00 57.230 274.762 3735.74 3857.74 498.23 N 5981.32 W 5970743.68N 492963.86 E 0.000 6002.03 7700.00 57.230 274.762 3789.87 3911.87 505.21 N 6065.11 W ..597075():67N 492880.07 E 0.000 6086.12 7800.00 57.230 274.762 3844.00 3966.00 512.19 N 6148.91 W .597075p:66N 492796.28 E 0.000 6170.20 ---- . . 7900.00 57.230 274.762 3898.12 4020.12 519.17 N 6232.70 W 5970764,65 N 492712.48 E 0.000 6254.29 8000.00 57.230 274.762 3952.25 4074.25 526.15 N 63 16¡SO.W 5970771 .65 N 492628.69 E 0.000 6338.37 8100.00 57.230 274.762 4006.37 4128.37 53:3,13 N ..6400.29Vil 5970778.64 N 492544.89 E 0.000 6422.46 8200.00 57.230 274.762 4060.50 4182.50 54aBU N . . 648ft.t09 W 5970785.63 N 492461.10 E 0.000 6506.54 . ... 8300.00 57.230 274.762 4114.63 4236.63 nO9.N. .6567.88 W 5970792.62 N 492377.31 E 0.000 6590.63 8400.00 57.230 274.762 4168.75 4290.75 ,.OEN ... .6651.68 W 5970799.61 N 492293.51 E 0.000 6674.71 8500.00 57.230 274.762 4222.88 4344.88 1.05N 6735.47 W 5970806.60 N 492209.72 E 0.000 6758.80 8600.00 57.230 N 6819.27 W 5970813.60 N 492125.92 E 0.000 6842.88 8700.00 57.230 575.01 N 6903.06 W 5970820.59 N 492042.13 E 0.000 6926.97 8800.00 57.230 581.99 N 6986.86 W 5970827.58 N 491958.34 E 0.000 7011 .05 8900.00 57.230 588.97 N 7070.65 W 5970834.57 N 491874.54 E 0.000 7095.14 9000.00 57.230 595.95 N 7154.45 W 5970841 .56 N 491790.75 E 0.000 7179.22 9100.00 57.230 4669.64 602.93 N 7238.24 W 5970848.56 N 491706.95 E 0.000 7263.31 9200.00 57.230 4723.76 609.91 N 7322.04 W 5970855.55 N 491623.16 E 0.000 7347.40 9300.00 57.230 4777.89 616.89 N 7405.83 W 5970862.54 N 491539.36 E 0.000 7431.48 9400.00 57.230 4832.02 623.87 N 7489.63 W 5970869.53 N 491455.57 E 0.000 7515.57 9500.00 57.230 274.762 4886.14 630.85 N 7573.42 W 5970876.52 N 491371.78 E 0.000 7599.65 -~ 9600.00 57.230 274.762 4818.27 4940.27 637.83 N 7657.22 W 5970883.51 N 491287.98 E 0.000 7683.74 9700.00 57.230 274.762 4872.40 4994.40 644.81 N 7741.01 W 5970890.51 N 491204.19 E 0.000 7767.82 9800.00 57.230 274.762 4926.52 5048.52 651.79 N 7824.81 W 5970897.50 N 491120.39 E 0.000 7851.91 9900.00 57.230 274.762 4980.65 5102.65 658.77 N 7908.60 W 5970904.49 N 491036.60 E 0.000 7935.99 10000.00 57.230 274.762 5034.77 5156.77 665.75 N 7992.40 W 5970911.48 N 490952.81 E 0.000 8020.08 10100.00 57.230 274.762 5088.90 5210.90 672.73 N 8076.19 W 5970918.47 N 490869.01 E 0.000 8104.16 10200.00 57.230 274.762 5143.03 5265.03 679.71 N 8159.99 W 5970925.46 N 490785.22 E 0.000 8188.25 C 10300.00 57.230 274.762 5197.15 5319.15 686.69 N 8243.78 W 5970932.46 N 490701 .42 E 0.000 8272.33 10400.00 57.230 274.762 5251.28 5373.28 693.67 N 8327.58 W 5970939.45 N 490617.63 E 0.000 8356.42 ::t::J 10500.00 57.230 274.762 5305.41 5427.41 700.65 N 8411 .37 W 5970946.44 N 490533.83 E 0.000 8440.50 - - c-> - - <: 5 September, 2001 - 7:56 Page 5 of 9 DrillQuest 2.00.09.003 ~ r--- Sperry-Sun Drilling Services Proposal Report for Plan: 2T-39 - 2T-39 (wp01) Your Ref: Per Scott Lowry wI Phillips Revised: 4 September, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2T Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastil)gs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10600.00 57.230 274.762 5359.53 5481.53 707.63 N 8495.17 W 5970953A3N .490450.04 E 0.000 8524.59 10700.00 57.230 274.762 5413.66 5535.66 714.61 N 8578.96 W ... 597096Œ42N 490366.25 E 0.000 8608.68 10800.00 57.230 274.762 5467.78 5589.78 721.59 N 8662.76 W . . 597D967Æ42JN 490282.45 E 0.000 8692.76 -- 10900.00 57.230 274.762 5521.91 5643.91 728.57 N 8746.55 W ..5970974141 N 490198.66 E 0.000 8776.85 11000.00 57.230 274.762 5576.04 5698.04 735.55 N 883Q;35W 5970981.40 N 490114.86 E 0.000 8860.93 11100.00 57.230 274.762 5630.16 5752.16 5970988.39 N 490031.07 E 0.000 8945.02 11142.19 57.230 274.762 5653.00 5775.00 5970991 .34 N 489995.72 E 0.000 8980.49 7" Casing Lower Kalubik (K-1 Marker) 11200.00 57.230 274.762 5684.29 5806.29 ....'8997.94 W 5970995.38 N 489947.28 E 0.000 9029.10 11300.00 57.230 274.762 5738.42 5860.42 9081.73 W 5971002.37 N 489863.48 E 0.000 9113.19 11323.25 57.230 274.762 5751.00 .,58%3.00 9101 .22 W 5971004.00 N 489844.00 E 0.000 9132.74 TARGET: 11323.25ft MD, 5873.00ft TVD (1017' FSL & 2015' FWL, Sec. 3 T11 N-R8E) Kuparuk C4 Target - 2T-39 (Top C4), 100.00 Radius., Geological 11339.88 57.230 . ~L4.762m;~5~,~0.00 5882.00 759.27 N 9115.15W 5971005.16 N 489830.07 E 0.000 9146.72 Kuparuk A3 11400.00 57.230 2£4.762 5792.54 5914.54 763.47 N 9165.53 W 5971009.37 N 489779.69 E 0.000 9197.27 11400.85 57.230 27?f.gZt)~.' 5793.00 5915.00 763.53 N 9166.24 W 5971009.43 N 489778.98 E 0.000 9197.98 Kuparuk A2 11456.27 57.230 2741762 5823.00 5945.00 767.40 N 9212.68 W 5971013.30 N 489732.54 E 0.000 9244.59 Kuparuk A2 (Base Net Pay) 11495.07 57.230 274.762 5844.00 5966.00 770.10 N 9245.19 W 5971016.01 N 489700.02 E 0.000 9277.21 Kuparuk A 1 -, 11500.00 57.230 274.762 5846.67 5968.67 770.45 N 9249.33 W 5971016.36 N 489695.89 E 0.000 9281 .36 11539.41 57.230 274.762 5868.00 5990.00 773.20 N 9282.35 W 5971019.11 N 489662.87 E 0.000 9314.50 Miluveach 11600.00 57.230 274.762 5900.79 6022.79 777.43 N 9333.12 W 5971023.35 N 489612.10 E 0.000 9365.44 11641.02 57.230 274.762 5923.00 6045.00 780.29 N 9367.50 W 5971026.22 N 489577.72 E 0.000 9399.94 Total Depth: 11641.02ft MD, 6045.00 TVD (1042' FSL & 1705' FWL, Sec. 3. T11 N-R8E) 3-1/2" Casing C :::x:J - - c-:> - - :c:: 5 September, 2001 - 7:56 Page 6 of 9 DrillQuest 2.00.09.003 :J:::=.. r-- C ::0 - - ~ - - <= ):::::.. r--- Kuparuk River Unit Sperry-Sun Drilling Services Proposal Report for Plan: 2T-39 - 2T-39 (wp01) Your Ref: Per Scott Lowry wI Phillips Revised: 4 September, 2001 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.862° (21-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from SHL to Target and calculated along an Azimuth of 274.762° (True). Based upon Minimum CuNature type calculations, at a Measured Depth of 11641.02ft., The Bottom Hole Displacement is 9399.94ft., in the Direction of 274.762° (True). Comments Measured Depth (ft) 0.00 300.00 633.33 883.33 1839.33 6227.79 7284.76 11323.25 11641.02 Station Coordin TVD Northings. . (ft) (ft) 0.00 E 0.00 E 28.91 W 93.31 W 734.92 W SHL: X = 498,945.107' E & Y = 5970244.609' N (264' FSL & 556' FWL, Sec 1-T11 N-R8E) Begin Dir @ 3.0°/1000 : 300.000 MD, 300.000 TVD Increase in Dir Rate @ 4.00/1O0ft: 633.33ft MD, 631.64ft TVD Increase in Dir Rate @ 5.00/100ft : 883.33ft MD, 872.82ft TVD End Dir, StartSail @ 67.80°: 1839.33ft MD, 1541.86ftTVD 3200.0 3687.11 5873.00 6045.00 398.50 N 476.22 N 758.11 N 780.29 N 4784.05 W 5717.16 W 9101.22W 9367.50 W Begin Dir @ 1.00/1O0ft : 6227.79ft MD, 3200.00ft TVD End Dir, Start Sail @ 57.230 : 7284.76ft M D I 3687.11 ft TVD TARGET: 11323.25ft MD. 5873.0Oft TVD (1017' FSL & 2015' FWL, Sec. 3-T11 N-R8E) Total Depth: 11641.02ft MD, 6045.000 TVD (1042' FSL & 1705' FWL, Sec. 3-T11 N-R8E) North Slope, Alaska Kuparuk 2T --. -" 5 September, 2001 - 7:56 Page 7 of 9 DrillQuest 2.00.09.003 c ::x:. - - ~ - - ==== ::t:=.. r-- Sperry-Sun Drilling Services Proposal Report for Plan: 2T-39 - 2T-39 (wp01) Your Ref: Per Scott Lowry wI Phillips Revised: 4 September, 2001 Kuparuk River Unit Formation Tops Formati on Plane (Below Well Origin) Sub-Sea DJp Dip Dir. eft) Deg. Deg. Penetration Point Sub-Sea Depth Northings (ft) (ft) North Slope, Alaska Kuparuk 2T -~ Base Permafrost (?) Base West Sak Tabasco Lower Kalubik (K-1 Marker) Kuparuk C4 Kuparuk A3 Kuparuk A2 Kuparuk A2 (Base Net Pay) Kuparuk A 1 Miluveach -~~ Profile Measured Vertical Depth Depth (ft) (ft) 1300.00 0.000 359.992 1587.58 1422.00 1300.00 2550.00 0.000 359.992 4830.38 2672.00 2550.00 2920.00 0.000 359.992 5809.62 3042.00 2920.00 5653.00 0.000 359.992 11142.19 5775.00 5653.00 5751.00 0.000 359.992 11323.25 5873.00 5751:00 5760.00 0.000 359.992 11339.88 5882.00 5760.00 759.27 N 5793.00 0.000 359.992 11400.85 5793.00 763.53 N 5823.00 0.000 359.992 11456.27 5823~00 767.40 N 5844.00 0.000 359.992 11495.07 5844.00 770.10 N 5868.00 0.000 359.992 11 5868.00 773.20 N Casing details Fro m To Measured Verti asured Vertical Depth Depth Depth Depth Casing Detail (ft) (ft) (ft) eft) <Surface> <Surface> 6010.00 3117.71 9-5/8" Casing <Surface> <Surface> 11142.19 5775.00 7" Casing <Surface> <Surface> 11641.02 6045.00 3-1/2" Casing .4:.88 3494;B9W 4398.22W 8949.50 W 9101.22 W 9115.15 W 9166.24 W 9212.68 W 9245.19 W 9282.35 W 5 September, 2001 - 7:56 Page 8 of 9 DrillOuest 2.00.09.003 0 :::x:J - - ~ - - :c:: þ r-- Kuparuk River Unit Targets associated with this wellpath Target Name 2T-39 (Top C4) Sperry-Sun Drilling Services Proposal Report for Plan: 2T-39 - 2T-39 (wp01) Your Ref: Per Scott Lowry wI Phillips Revised: 4 September, 2001 Mean Sea LeveVGlobal Coordinates: Geographical <èÞ:9fdint!t~s: Radius: Coo r din ate s Eastings (ft) 758.11 N 9101.22 W 5971004.00 N 489844.00 E 70019' 55.1755" N 150004' 56.5696" W North Slope, Alaska Kuparuk 2T Target Shape Target Type -~ Circle Geological ~"- 5 September, 2001 - 7:56 Page 9 of 9 DrillQuest 2.00.09.003 ã) ~ 2600 a: ..c: +-' Q.. Q) 0 cu () t Q) > 3900 r---£riliQUest 2.00.09.003 1300 n lJ 1300 5200 -9100 -7800 -6500 TotalOepth: 11641.0211 MO, 6045.000 TVO (1042' FSL& 1705' FWL, Sec. 3-T11N-R8E) TA~GET: ~ ~~~23.2~,H MD. 537:"t()OH P¡D (1(),," FSL & 20,S' FWl. S,~. 3.T,,¡'H;¡;;::) / <fj . -r:¡')it:.. ,... ',-", ,... 3-112' Casing 11641.02fI MD 6045.00ft TVD 7' Casing 11142.1911 MD 5775.0Oft TVD Scale: 1 inch = 1300ft -9100 -7800 -6500 SHL x' ."""."",; ",," E ¿ \'", ~:'~?<'44 i,.:"" 'j ()V'F"3Lf,:""""PNl.. ~,",.;~ .T~~:';.hT, 0 Begin Dir @ 3.0o/1O0ft : 300.00ft MD, 300.00ft TVD -5200 -3900 -2600 End Oir, Start Sail @ 57.23" : 7284.76ft MO, 3687.11ft TVD B~in Oir @ 1.0°/1 DOft : 6227.700 MO, 3200.0OftTVD <;f) ~ ,... 9-518' Casing 6010.0011 MD ...31J7.11ft.I'lD . tþ<ß.<ß Increase in Dir Rate @ 4,oo1100ft: 633.33ft MD, 631 ,64ft TVD !:1<fj.oO .Increase in Dir Rate @ 5.0o/1O0ft : 883.33ft MD, 872.82ft TVD -5200 End Dir, Start Sail @ 67.80° : 1839.33ft MD, 1541.86ft TVD . Arfr'.rfJ ~.rfJ -~ ... 9-5/8' Casing 6010.00ft MD 3117.71ftTVD .~,s> -3900 Reference is TRUE North -2600 Begin Dir @ 1.0o/1O0ft: 6227.79ft MD, 3200.00ft TVD End Dir, Start Sail @ 57.23° : 7284.76ft MD, 3687.11ft TVD 0 1300 Scale: 1 inch = 130Oft 2600 3900 -1300 0 1300 End Oiro Start Sail @ 67.80": 1839.3311 MD, 1541.86ft TVO .o<P.<ß Begin Dir Þ 3.0°/10011: 300.00ft MD, 300.0011 TVD 0 '.;Ht .,:,-.n:~'1.F,~iji'E",Y',(;",;,<:,/."...",,¡,,' (;;'«;=~',..SCU:';=,"i<. "H.C' .,j'~"-:""¡:' -1300 0 Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 2T-39 (wpO1) r-'- Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: Plan: 2T-39 RKB Elevation: North Reference: Units: 5970244.61 N, 498945.11 E 137.82 S. 0.20 E 70° 19' 47.7732' N, 150000' 30.8012" W (264' FSL & 556' FW L. Sec 1 - T11 N - R8E) 122.00ft above Mean Sea Level True North Feet (US) .-. sper-"",;-sull ~]!Hb- bIN .J~ ~_. .~. !:!. (!t~ ~ \[1 ~-I!;~ ~ /I H""~"n ç(lmp',ny <?Ì':,J B (¡þ~ 9\OOØJ ',Dol) T AHGET:I 00' Ré\cjius Circle , @ 11323.25ft MD, ~:¡(r73.00ft TVD : ¡101-I'r:c.L&~O1r,'r::\!..I'L (~c)c :i-'1'11~,J-f')g[::i ¡' <" -~'.v,~,.- .n~,- / / / 7' Casing 11142.191tMD 5775.0011 TVD ...,/ r:fJ ,.,...--..-- 't' \,~O':.-,---,-"- ~.u: """0/ 3.112" Casing 11641.(>211 MD - 6045.0011 TVD Total Depth: 11641.02ft MD, 6045.0Oft TVD (1042' FSL& 1705' FWL, Sec, 3-T11N-R8E) 5200 6500 7800 9100 C) ::::0 - - ~ - =æ: ~ r- Phillips Alaska, Inc. 2T-39 (wpO1) MD Inc Azim. SSTVD TVD N/S EIW Y X DLS V.S. Comment . -- (tt) (Oeg) (Oeg) (ft) (tt) (tt) (ft) (ft) (tt) (0/100tt) (ft) 0.00 0.00 0.00 -122.00 0.00 0.00 N 0.00 E 5970244.61 N 498945.11 E 0.00 0.00 SHL 300.00 0.00 0.00 178.00 300.00 0.00 N 0.00 E 5970244.61 N 498945.11 E 0.00 0.00 Begin Oir 633.33 10.00 274.76 509.64 631 .64 2.41 N 28.92 W 5970247.02 N 498916.20 E 3.00 29.02 Increase in DLS 883.33 20.00 274.76 750.82 872.82 7.77 N 93.32 W 5970252.39 N 498851.80 E 4.00 93.64 Increase in OLS 1839.33 67.80 274.76 1419.86 1541.86 61.21 N 734.93 W 5970305.92 N 498210.19 E 5,00 737.47 End Oir 4830.38 67-EO 274.76 2550.00 2672.00 291.10 1\J 3494J39 \¡V 5fr70536.20 N 495450.46 E 0.00 350ß.79 E3DSC Vv cst Sak 5BO9.ß3 67.80 274.76 2920.00 3042.00 36ß.3ß 1\1 439ß.22 VV 5970611.59 N 494546.95 E 0.00 4413J1S Tabasco 6010.00 67.80 274.76 2995.71 3117.71 381.76 N 4583.10 W 5970627.01 N 494362.07 E 0.00 4598.97 9-5/8" Casing 6227.79 67.80 274.76 3078.00 3200.00 398.50 N 4784.05 W 5970643.78 N 494161.12 E 0,00 4800,62 Begin Dir 7284.76 57.23 274.76 3565.11 3687.11 476.22 N 5717,16 W 5970721.64 N 493228.02 E 1.00 5736.96 End Dir 11142.19 57.23 274.76 5653.00 5775.00 745.47 N 8949.50 W 5970991.34 N 489995.72 E 0.00 8980.49 7" Csg - (K-1 Marker) 11323.25 57.23 274.76 5751.00 5873.00 758.11 N 9101.22 \¡V 5971004.00 N 489844.00 E 0.00 9132.74 TARGET i 1339):18 '-7 'Y' 2'Tit.76 5760.00 58B2.00 759.2l N 9 'j '1 5.1 5 Vv' 5971005. .; 6 N 489830.07 E 0.00 9146.72 Kuparuk 1\3 ::J < . c._~j 11400.85 57-23 274.76 5793.00 5915.00 7133.53 N 916624 \N 59710Œ143 N 489778.98 E 0.00 91D7.98 Kupmuf'\ /\2 'j 1456.27 r"7 ,\n 2l4.7ß SH23.00 5g45.00 767040 N 9212.6B VV SEi7H)13.30N 489732.S4 E 0.00 9244,~)9 t<tn A") (B(,1""" ~!~~ o,'\'} ~J< .¿>,oj ,.~. /:..CJ~-;.,¡\.;l¡(;!j:I -- 11495.07 '-7 ')" 274."76 5ß44.00 5H6G,OO T1Ü.10 N 924Ei 19 VV 5971016.01 N 4[:59700.03 E 0.00 9~:T7.21 !/lJ'-'~n'< ~'\' ~f ".:..5 r\ "" ¡IC! U. t i .¡ -¡ 53DA'l 57.23 2l4. 7ß SH6B. 00 5EiGn. 00 7"73.20 N 9282035 \N 597H}19.11 N 4896ß2.B7 E 0.00 9314.50 iVliluvcach 11641 .03 57.23 274.76 5923.00 6045.00 780.29 N 9367.50 W 5971026.22 N 489577.72 E 0.00 9399.94 T ctal Depth ( f Sperry-Sun Anticollision Report CompanJ': Field: Reference Site: Reference Well: Reference Wellpath: Phillips Alaska Inc. Kuparuk River Unit Kuparuk 2T Pad Plan: 2T -39 2T-39 Date: 9/4/2001 Time: 16: 19:53 Page: I GLOBAL SCAN APPLIED: An wellpaths \\ithin 200'+ 100/1000 of reference Interpolation Method: MD Inten'al: 50.00 ft Depth Range: 122.00 to 11641.86 ft 1\'1 aximum Radius: 1351 .99 ft Reference: Error Model: Scan Method: Error Surface: Well: Plan: 2T-39, True North N16E (RKB est @ 122') 122.0 Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Co-ordinate(NE) Reference: Vertical (TVD) Reference: Sun'ey Program for Definitive Well path Date: 8/30/2001 Validated: No Planned From To Survey ft ft 122.00 900.00 900.00 11641.86 Version: Toolcode 3 Tool Name Planned: 2T-39 (wp01) V1 Planned: 2T-39 (wp01) V1 CB-GYRO-SS MWD Camera based gyro single shots MW D - Standard Casing Point" MD TVD Diameter Hole Size ft ft in in 6010.00 3117.71 9.625 12.250 11143.18 5775.00 7.000 8.500 11641.86 6044.85 3.500 6.125 Summary Name 9-5/8" 7" 3-1/2" <---------------------- Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft -. -- - Kuparuk 2T Pad 2T -02 2T -02 VO 400.58 400.00 138.84 5.70 133.16 Pass: Major Risk Kuparuk 2T Pad 2T -03 2T -03 VO 599.03 600.00 113.23 8.71 104.66 Pass: Major Risk Kuparuk 2T Pad 2T -04 2T -04 VO 549.53 550.00 89.08 8.11 81.01 Pass: Major Risk Kuparuk 2T Pad 2T -05 2T-05 VO 499.80 500.00 64.32 7.17 57.26 Pass: Major Risk Kuparuk 2T Pad 2T -06 2T-06 VO 350.01 350.00 39.94 5.25 34.70 Pass: Major Risk Kuparuk 2T Pad 2T -07 2T -07 VO 399.85 400.00 13.41 6.02 7.41 Pass: Major Risk Kuparuk 2T Pad 2T -08 2T -08 VO 399.77 400.00 12.68 5.89 6.82 Pass: Major Risk Kuparuk 2T Pad 2T -09 2T -09 VO 449.38 450.00 38.29 6.52 31.82 Pass: Major Risk Kuparuk 2T Pad 2T-10 2T-10 VO 595.59 600.00 116.27 8.78 107.59 Pass: Major Risk Kuparuk 2T Pad 2T -11 2T-11 VO 448.81 450.00 137.51 6.42 131.16 Pass: Major Risk Kuparuk 2T Pad 2T -12 2T-12 VO 595.29 600.00 161.70 9.37 152.34 Pass: Major Risk Kuparuk 2T Pad 2T -12A 2T-12A VO 546.83 550.00 160.83 8.00 152.92 Pass: Major Risk Kuparuk 2T Pad 2T -13 2T-13 VO 546.50 550.00 189.09 8.14 180.99 Pass: Major Risk Kuparuk 2T Pad 2T -14 2T-14 VO 546.41 550.00 211.40 7.82 203.79 Pass: Major Risk Kuparuk 2T Pad 2T -15 2T-15 VO 545.75 550.00 238.22 7.92 230.40 Pass: Major Risk Kuparuk 2T Pad 2T -202 2T-202 V1 300.00 300.00 182.82 4.21 178.61 Pass: Major Risk Kuparuk 2T Pad 2T-207 2T -207 V1 1908.28 1900.00 89.68 79.01 26.46 Pass: Major Risk Kuparuk 2T Pad 2T -22 2T-22 VO 550.36 550.00 150.66 8.06 142.65 Pass: Major Risk Kuparuk 2T Pad 2T-23 2T-23 VO 550.20 550.00 166.95 8.11 158.91 Pass: Major Risk Kuparuk 2T Pad 2T -26 2T -26 VO 600.00 600.00 213.37 9.30 204.07 Pass: Major Risk Kuparuk 2T Pad 2T-27 2T-27 VO 600.36 600.00 230.25 9.10 221.15 Pass: Major Risk Kuparuk 2T Pad 2T-28 2T -28 VO 451 .19 450.00 243.96 6.83 237.17 Pass: Major Risk Kuparuk 2T Pad 2T-29 2T-29 VO 649.66 650.00 256.08 9.54 246.59 Pass: Major Risk Kuparuk 2T Pad 2T -36 2T -36 VO 448.09 450.00 251.15 6.55 244.65 Pass: Major Risk Kuparuk 2T Pad 2T -38 2T -38 VO 448.42 450.00 200.87 6.69 194.21 Pass: Major Risk Kuparuk 2T Pad 2T-TAB-01 2T - T AB-01 VO 299.97 300.00 25.68 4.33 21.36 Pass: Major Risk L..... ORIGINAL I I I I 1-'-200 i I I I , I i I I I ~ ê WBL DErAILS l'arœ +NI.S Interpolation Method:MD Depth Range From: 122,00 Maximum Range: 1351.99 M'TI-COLLISION SETTINGS RiO' Ref. fb'uñ. +EI.W l'pJthj;¡g &,ti;g Lati.L'<le Longitude Slot Plan: H.W .137.S} 0.20 5970244.61 49_5.11 7Ing47.773N 150'OO30.801W N/A Plan: 2T.39 (\\1'°1.1 (plan: H.39,2T.391 tOO By: 1M... EguJahJ eckt-J: ~-- Dale: 9/412001 IJa"':~ IJa"':~ ~",\\,.j: WP",vcd: lM'e: 388 !) --"., - ,- - - "i .. i i "'1'-702 C2.1"-202ì ;,."'- 300 --200 100 0 100 300 .. '/ ¡~,:; 1,- . ¡, " ':¡ "', ,/'¡- .', 'r., " 388 , '-., ..-..--- -- : -<-:1\-" -,- ' ,..--..---- I'ij Interval: 25,00 To: 1]641.86 Reference: Plan: 2T-39 (wpO]) V.S",,',-'n "." 274.76' From 0 200 300 400 500 600 700 800 Colour ':;:., '/' <., , - ';.. "I,'/,../~" '. " LEGEND - 2T. ',' ¡or Risk 2T.'--. '" .or Risk - 2T.', '.'" :ocRi,k 2T.' , '., \':or Ri,k - IT.'' ',' (>f Risk - IT.'. ',' ør Risk - 2T.' "' ,', ", orRisk --2T-.-'I,-."orRisk - IT.:.' "orRi,k IT. I ',' Dr Risk "._.'".~ IT. I ',' '" Risk - 2T.' '" I ' \. MaiorRi,k 2T.:' I "" o,Risk 2T-: " " .or Ri,k ~ IT.: ,-,' oc Ri,k - IT. .. '.fajùrRisk ~ 2T.. ; . ','lajoT Risk ~2T,';'I' ~'orRi,k - 2T." - I "or Ri,k "z",.". IT. ." I -,' or Ri,k 2T. I ',' c-r Risk - 2T.' I . \' orRisk ~ 2T. " , ., \~ or Risk -- 2T..' ,., ,. or Ri,k - 2T..- , , \; ,or Ri,k Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [200ft/in] WELLP A TH DEr All.S IT-39 SHI. Pad ele & RKD ",¡'J COMPi\J'<ì' DI'T'\I1-~ SURVEY I'RI)(;R,\M l)ol"hl'm I"'I"IIT" SUI'qn'lm Pllilli¡" Au',", 1"<. EngineclÍ"~ Kuparuk 122m XXJ.!O) <¡(X) IX) I'UM<-.: 1T W"'l"") VI 1I"~1."', 1'1",",,1 H..1'J",J'i)) VI Nol'Ofe l"E NIIiE(RKB",'... 122'1 121 00fi Ca\;Ubl'" Melo.,J: Min"'..m Cu,",'U'" EIwr S¡;!em: IS[WSA Snn Mclh,d: Tea,. C\"inJ,~ ;-';"nll r. ,', rl'" . """,,-, ".' Wami;g ~klh.J: Rule' ß-a<ro Origi-t Origin Stan;,g +N/.S ~FJ-W FmmTVn 0.00 0.00 0.00 34 0 From 0 20() 300 40() SOO (iO() 700 HOO 1)00 1000 120() 1400 I(iOO IHOO 2UOO 2S00 300() 3S00 00 "'30-'--"-""""""""""""'" 30 ..----------'----" //~' // -20 / / I I / í / Í I ! i i ¡ 10 a 27 10 20 SECTION IJET/\ll.$ 1"" MD Inc Azi 1VD +NI,S +EI-W Ju:~ 1'1'a,," VS,'c 1"~~d 122.00 0.00 0.00 122.IH) (1.00 O.IH) 0.00 (I.IK) OIK) 300.00 0.00 0.00 .101).011 11.011 O.tHJ 11.1)0 IIIK) OIK) 63.u3 !O.OO 274.76 631.64 2.41 -28.~1 3.00 27-1.7(-> 2'1.U2 883.33 201K) 274.76 Sn82 7.77 -93-' I H)lJ O.IK) '13.M ] 839.33 67.SI) 274.76 1541.86 1>1.211 .734.~.1 500 (UH) 7.\7,41 6227.79 67.80 274.76 3201l.lHI 3'18.37 -4784.1)6 0011 O.IHI 48IH).!>2 7281.74 57.24 274.76 3685.65 475.~1I -571455 1.00 ISO.IK) 57.U..!.\ ] 1324.00 57.24 274.76 5873.00 758.J~ -9!112.12 lUll) O.tK) 'JI.1.U..I 2T-.II) ITargc'li 11641.86 57.24 274.76 61)45.00 780.3S -93(.8.50 11.110 tUH) 'J4I"'.'J,~ Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [20n/in T",,! ("(HõYRo.SS MWlJ Colour To MIJ 200 300 400 SOO (}OO 70C) HOO I)O[) IO()O 1200 140() ¡(}(JO IHOO 2000 2500 3()OO 350() 4S()O SOO() ----. 2T-O1; (2T-01;) --. 1 'I ( 2T-39 Drillinq Hazards Summar'l 12-1/4" Hole /9-5/8" Casin~ Interval Event Conductor Broach Well Collision G ravel and sand slou hin Shoe Fracture/Lost Returns during cement 'ob Risk Level Low Low Low Low 8-1/2" Hole /7" CasinQ Interval Event Shale stability in HRl High ECD and swabbing if higher MW is re uired Hole cleaning in long, hi h an Ie tan ent Shale stability across K- 1 interval Hole instability or lost circulation in Tabasco Risk Level Moderate Moderate Moderate Moderate Low 6-1/8" Hole /3 1/2" Liner Interval Event High ECD and swabbing if higher MW is re uired Hole cleaning in long, hi h an Ie tan ent Shale stability across Mil uveach Risk Level Moderate Moderate High Miti ation Strate Monitor cellar continuousl durin interval. Careful well planning and surveying, adherence to anti-collision olic Elevated mud viscosity from spud; Hi dens swee s. Reduced pump rates, and lightweight tail cement Miti ation Strate Control with higher MW and proper drilling ractices. Pumping and rotating out on all trips to reduce swab and barite sag potential. Good drilling practices. Control with higher MW and proper drilling ractices. Directional path planned to avoid Tabasco. Miti ation Strate Pumping and rotating out on all trips to reduce swab and barite sag potential. Good drilling practices. Control with higher MW and proper drilling ractices. 2T-39 Drilling Hazards Summary. doc prepared by Scott Lowry 8/10/01 ORI(111v~L (' KRU 2T-39 Producer Proposed Completion Schematic T opset Base Case 16" 62.6# @ +1-120' MD Depths are based on Nabors 16E AKB Surface csg. 9-5/8" 36.0# J-55 BTCM (+1- 6010' MD /3118' TVD) Intermediate csg. 7" 26.0# L-80 BTCM (+1- 11,142' MD I 5775' TVD) Future Perforations Production Liner 3-1/2" 9.3# L-80 EUE8RD (+1- 11,641' MD I 6045' TVD) t PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple wI 2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above and below, EUE8RD set at +1- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" X 1" Cameo 'KBUG' Mandrels wI DV's and RK latch's (Max. OD 5.390", ID 2.867"), 6' L-80 handling pups installed above and below on GLM. Spaced out wI 3-1/2" 9.3# L-80 EUE8RD tubing as follows: GLM 1 2 3 4 5 TVD (RKB) 2350' 3550' 4475' 5150' 5662' (As noted below) 3-1/2" X 1" Cameo 'MMG' mandrel wi shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Cameo 'DS' nipple wI 2.813" No-Go profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 5.125" x 3" Baker locator sub 4-1/2" Baker GBH-22 casing seal assembly wI 15' stroke, 3-1/2" L-80 EUE8RD box up Liner Assemblv (run on drillpipe). set @ +1- 11.004' MD Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock' Liner Hanger Baker 17' Seal Bore Extension XO Sub, 5" Stub Acme box x 3';1/2" EUE8RD pin 1 jt 3-1/2" 9.3# L-80 L-80 EUE8RD tubing 3-1/2" Halliburton 'XN' nipple wI 2.75" No-Go Profile, 3-1/2" EUE8RD box x pin 3-1/2" 9.3# L-80 EUE8RD liner as needed 3-1/2" Baker Landing Collar 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker Float Collar 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker Float Shoe ORJoGlN A L \ ( ,. \ ¡ \ . -"---... ".. -"'.-- American Expressœ Cash Advance Draft 163 DATE L 0 >~PÁ-b.v 2ðt)J, m , ( fl~('c- r I Slæ9. ()O ~ ~. /) ~ If ..... ..t-¿::f' 0" 0 .- DOLL A R 5 PAY TO THE ORDER OF -=---- Issued by Integrated Payment System, (nc. E.,Iewood. Cola""'" N~_ID- _FOR AMOUNT 0 E~R $1000 ,- Payable at Norwest Bank of Grand junction - Downtown, NA ;' SHARON UP-D ~ / , Grand junction. Colorado (: Ii .I~ ~ ~J2 ') 1: 14~ PER'OD ENDING d" ,- .. ¿;q - ". - I - u. ~ I: ~ 0 2 ~ 0 0 ... 0 0 I: :l 5 III 0 ~ 7 5 0 0 0 5 :l b III 0 ~ b ~ .. ..--.-.---.-..--" . .. ( " ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARA GRAPH S TO BE INCLUDED IN TRANSNDTTAL LETTER J:R{,[ 2!- 31 CHECK 1 STANDARD LETTER DEVELOPMENT ¡ DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL L-)NO ANNULAR DISPOSAL L-) YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) , and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not 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 that an disposal of fluids generated. . . ANNULUS / ' ~ YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The, permit is approved subject 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. ,eLl... WELL PERMIT CHECKLIST COMPANY . ,'. 1!5 WELL NAME -;2:.í.- 3~ PROGRAM: exp - dev - redrll serv wellbore seg _ann. disposal para req - FIELD & POOL'" INIT CLAS '::;;¡;;E L/ J () / L - GEOL AREA UNIT# () ! / (~ 0 ON/OFF SHORE C' J1 ADMINISTRATION 1. Permit fee attached. . . '-.;..? ¿n:.: '-' f f. '/'" . 'J" . .." . -~!N . / -'-' -L ~ 2. Lease number appropriate~ ~ .~~..,,~} ~~-: ~ /. ! N .~ 5úA~ Iccdrf,~ ~ ADL o?-t;;S-t",.:¡' +f' ~l>d~ Q+:,t.-<.. ~",",-*,,\r-cJ: 3. Uniquewellnameandnumber... . . . . . . . . . . . . . . . . N ~ T- Do.':~ /l-"DL c..."2..çç"}f. ~ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . ) N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . I N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . . ' N. 8. If deviated, is wellbore plat included.. . . . . . . . . . . .'. . - I N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . ' N 11. Permit can be issued without conservation order. . . . . . . . N 12. Permit can.be issued without administrative approval.. . . . . VI N 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . . . . . .. . . . . . . . . . 15. Surface casing protects all known USDWs. . .. . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to .tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . '. . . . . 19. Casing'designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate weilbore separation proposed.. . . . . . ; . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . ~ . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . Q.~TE 26. BOPE press rating appropriate; test to ~~:JO psig. \d-. . 27. Choke manifold complies w/API Rp.53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . " 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . .'. . ~ ( '^ APP..R DATE. 33. Seabed condition survey (if off-shore). . . . . . . . . . ., ~1'" Y '.l b e'f, ,.2 . ð/ 34. Contact name/phone for weekly progress reports [explo 01'}' only] Y ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface: " " (C) will not impair mechanical integrity ~f the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING:,. UIC/Annular COMMISSION: ~Þ8 WM, 8~s JM (' ~fC DATE { 9 I (2 .0 ENGINEERING GEOLOGY t APPR DATE i~ ~! "-....... '" "".. ~ ';. " "" "-"'- \ -.::> \.\- '\ ...... ~ "\ \' "".J:J y ~ ~~"""':,~~ ~ ~<L~j.\ . , ~ !.-\o;:,.<-.Cè. c-, ,\,\,=",~\-",~(",~i,.~s;; , N ' ~\-\~<:>\'~:>~s~~~\ ~6-CS:~~\~çç~~~~, .'~~ \~~\"t~~;;."\~~: N ~~ I~,<~\~ 'Cè~\"k~ $ ~ 2C:dJ . Y Y@ Y . N N ' N ' ~~~"os-~~~\. ~\\-\\"'~'f ~\Q."~. ~'- ~c..\o-~ tCc~~,~\~ Y N ' Y N Com ments/lnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z 0 -I :E ::u - -I' m - z -I J: - en )- ::0 l\. m » ~ (' Well History File APPENDIX Information of detaHed nature that is not particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically . . organize this category of information. '" ( (' ~OJ-/~3 JO7¿) c¡ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Sat Mar 02 16:24:09 2002 Reel Header Service name.............LISTPE Date.....................02/03/02 Origin...................STS Reel Name. - - - - - - - . . . . . - - . UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Tape Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/03/02 Origin...................STS Tape Name................ UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 AK-MM.-11 1 68 P. SMITH M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 12.250 8.500 # REMARKS: Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 2T-39 501032039200 PHILLIPS Alaska, Inc. Sperry Sun 02-MAR-02 MWD RUN 7 AK-MM-11168 P. SMITH M. THORNTON MWD RUN 8 AK-MM-11168 T. MCGUIRE R.ROSS 1 11N R8E 264 556 .00 113.50 79.10 CASING SIZE (IN) 16.000 9.625 7.000 DRILLERS DEPTH (FT) 155.0 6012.0 11243.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 - 4 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. ( ( 3. MWD RUN 5 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). NO FOOTAGE DRILLED DUE TO A FAILED CASING TEST AND IS NOT PRESENTED. 4. MWD RUNS 6 AND 7 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) - 5. MWD RUN 8 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 6. GAMMA RAY LOGGED BEHIND CASING TO 6012' MD, 3107' TVD. 7. GAMM..A. RAY LOGGED BEHIND CASING FROM 11203' MD, 5799' TVD TO 12243' MD, 5820' TVD. ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 LOGGED BEHIND CASING FROM 11196' MD, 5795' TVD TO 11243' MD, 5820' TVD. 8. MWD DATA IS CONSIDERED PDC PER THE E-MAIL FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. DATED 01/04/02. AUTHORIZED BY GKA GEOSIENCE GROU ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 9. MWD RUNS 6 - 8 REPRESENT WELL 2T-39 WITH API # 50-103-20392-00. THIS WELL REACHED A TOTAL DEPTH OF 11685' MD, 6050' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED SBD2 = SMOOTHED SCO2 = SMOOTHED BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-C TNPS= SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SI CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE FORMATION EXPOSURE TIME BULK DENSITY (LOW-COUNT BIN) STANDOFF CORRECTION (LOW-COUNT ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 6.125" MUD WEIGHT: PPG MUD FILTRATE CHLORIDES 12.0 SALINITY: 500 -900 PPM $ ( (' FORMATION WATER SALINITY: FLUID DENSITY: GICC MATRIX DENSITY: 25000 PPM CHLORIDES 1. 00 2.65 GICC LITHOLOGY: SANDSTONE File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/03/02 Maximum Physical Record..65535 Fil e Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUIvIMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NPHI FCNT NCNT DRHO RHOB PEF $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 5967.0 6002.0 6002.0 6002.0 6002.0 6002.0 6025.0 11233.0 11233.0 11233.0 11242.5 11242.5 11242.5 STOP DEPTH 11630.0 11637.0 11637.0 11637.0 11637.0 11637.0 11684.5 11593.0 11593.0 11593.0 11608.5 11608..5 11608.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -..,.------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 6 7 8 MERGE TOP 5967.0 11255.5 11275.0 MERGE BASE 11255.0 11274.5 11684.5 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block. Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..... ..... .,... ... ...... . . -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FTIH 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 (' ( RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5967 11684.5 8825.75 11436 5967 11684.5 ROP MWD FT!H 0.13 898.36 159.689 11320 6025 11684.5 GR MWD API 22.54 445.27 127.624 11327 5967 11630 RPX MWD OHMM 0.11 92.02 4.32916 11271 6002 11637 RPS MWD OHMM 1.18 825.63 4.47077 11271 6002 11637 RPM MWD OHMM 1.24 2000 19.1056 11271 6002 11637 RPD MWD OHMM 1.25 2000 16.7894 11271 6002 11637 FET MWD HR 0.2 220.95 3.49499 11271 6002 11637 NPHI MWD PU-S 23.13 71.73 34.9517 721 11233 11593 FCNT MWD CP30 93.01 580.39 342.17 721 11233 11593 NCNT MWD CP30 13529.4 31058.1 22638.9 721 11233 11593 RHOB MWD G/CM 1. 99 3.17 2.42434 733 11242.5 11608.5 DRHO MWD G/CM -0.25 0.32 0.0412278 733 11242.5 11608.5 PEF MWD B/E 3.17 19.18 5.97314 733 11242.5 11608.5 First Reading For Entire File......--..5967 Last Reading For Entire File._.........11684.5 File Trailer Service name.............STSLIB.OOI Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......02/03/02 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Serv~ce name.............STSLIB.002 Service Sub Level Name... Version Number......... ..1. 0.0 Date of Generation.......02/03/02 Maximum Physical R~cord..65535 File Type............... .LO Previous File Name.......STSLIB.OOI Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPX RPD FET ROP $ 2 header data for each bit run in separate files. 6 .5000 START DEPTH 5967.0 6002.0 6002.0 6002.0 6002.0 6002.0 6025.0 STOP DEPTH 11203.5 11196.0 11196.0 11196.0 11196.0 11196.0 11255.0 # .. (' LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOfF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value........ '.. . . ... . . . . . . . -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 29-0CT-Ol Insite 4.05.5 66.16 Memory 11255.0 55.5 68.3 TOOL NUMBER PM02237HWRG6 PM02237HWRG6 8.500 11243.0 LSND LT 9.60 44.0 9.0 350 4.8 2.400 1.483 1.900 3.300 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HR 4 1 68 28 8 Name Service Unit DEPT FT Min 5967 Max 11255 Mean Nsam 8611 10577 (" 75.0 125.6 75.0 75.0 First Reading 5967 Last Reading 11255 . (. ( ROP MWD060 FT/H 0.13 898.36 167.516 10461 6025 11255 GR MWD060 API 22.54 445.27 129.926 10474 5967 11203.5 RPX MWD060 OHMM 0.11 42.88 3.91602 10389 6002 11196 RPS MWD060 OHMM 1.18 41. 59 3.96434 10389 6002 11196 RPM MWD060 OHMM 1.24 2000 5.03116 10389 6002 11196 RPD MWD060 OHMM 1.25 2000 8.27626 10389 6002 11196 FET MWD060 HR 0.2 173.57 1.50927 10389 6002 11196 First Reading For Entire File..........5967 Last Reading For Entire File...........11255 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/03/02 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.OO3 Physical EOF File Header Service name.............STSLIB.OO3 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/03/02 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 header data for each bit run in separate files. 7 .5000 START DEPTH 11196.5 11196.5 11196.5 11196.5 11196.5 11204.0 11255.5 STOP DEPTH 11235.0 11235.0 11235.0 11235.0 11235.0 11228.0 11274.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM. ANGLE: 04-NOV-Ol Insite 4.05.5 66.16 Memory 11275.0 57.6 57.6 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02261FGR4 PBO2261FGR4 # BOREHOLE AND CASING DATA , ; ( ( OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND LT 12.00 56.0 8.0 450 3.8 2.300 1. 259 1.800 3.200 70.0 133.5 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .,-999 Depth Units.... .... . .. .. .. .. . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWDO70 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11196.5 11274.5 11235.5 157 11196.5 11274.5 ROP MWD070 FT/H 11.1 44.41 29.0703 39 11255.5 11274.5 GR MWD070 API 67.5 82.15 74.0718 49 11204 11228 RPX MWD070 OHMM 2.73 4.89 3.56949 78 11196.5 11235 RPS MWDO 70 OHMM 3.63 9.26 5.78231 78 11196.5 11235 RPM MWD070 OHMM 574.57 2000 1813.15 78 11196.5 11235 RPD MWD070 OHMM 24.28 1930.33 1092.71 78 11196.5 11235 FET MWD070 HR 123.86 128.03 125.994 78 11196.5 11235 First Reading For Entire File..........11196.5 Last Reading For Entire File...........11274.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......O2/03/02 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.004 ( Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/03/02 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR NPHI FCNT NCNT RPM RPS RPD FET RPX PEF RHOB DRHO ROP $ 4 ("" header data for each bit run in separate files. 8 .5000 START DEPTH 11228.5 11233.0 11233.0 11233.0 11235.5 11235.5 11235.5 11235.5 11235.5 11242.5 11242.5 11242.5 11275.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER .( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ STOP DEPTH 11630.0 11593.0 11593.0 11593.0 11637.0 11637.0 11637.0 11637.0 11637.0 11608.5 11608.5 11608.5 11684.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 08-NOV-01 Insite 4.05.5 66.16 Memory 11685.0 58.1 59.1 TOOL NUMBER PB02261FGR4 PBO2261FGR4 PBO2055NL4 PB02055NL4 6.125 LSND 12.00 57.0 8.8 800 4.0 1. 800 20.412 70.0 138.0 '. (" ( MUD FILTRATE AT MT: MUD CAKE AT MT: 1.500 1. 700 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWDO80 API 4 1 68 8 3 RPX MWDO80 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWDO80 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWDO80 HR 4 1 68 28 8 NPHI MWD080 PU-S 4 1 68 32 9 FCNT MWD080 CP30 4 1 68 36 10 NCNT MWD080 CP30 4 1 68 40 11 RHOB MWD080 G/CM 4 1 68 44 12 SC02 MWDO80 G/CM 4 1 68 48 13 PEF MWD080 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11228.5 11684.5 11456.5 913 11228.5 11684.5 ROP MWD080 FT/H 3.74 288.68 66.0469 820 11275 11684.5 GR MWDO80 API 43.98 156.08 100.888 804 11228.5 11630 RPX MWD080 OHMM 1.88 92.02 9.74138 804 11235.5 11637 RPS MWD080 OHMM 2.04 825.63 10.8874 804 11235.5 11637 RPM MWDO80 OHMM 2.33 2000 26.9216 804 11235..5 11637 RPD MWD080 OHMM 2.31 1537.18 22.413 804 11235.5 11637 FET MWD080 HR 0.57 220.95 17.2694 804 11235.5 11637 NPHI MWD080 PU-S 23.13 71. 73 34.9517 721 11233 11593 FCNT MWDO80 CP30 93.01 580.39 342.17 721 11233 11593 NCNT MWD080 CP30 13529.4 31058.1 22638.9 721 11233 11593 RHOB MWD080 G/CM 1.99 3.17 2.42434 733 11242.5 11608.5 SC02 MWD080 G/CM -0.25 0.32 0.0412278 733 11242.5 11608.5 PEF MWD080 B/E 3.17 19.18 5.97314 733 11242.5 11608.5 First Reading For Entire File..........11228.5 Last Reading For Entire File...........11684.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Nurnber...........l.0.0 Date of Generation.......02/03/02 Maximum Physical Record..65535 Fil e Type................ LO Next File Name...........STSLIB.OO5 (: Physical EOF Tape Trailer Service name.............LISTPE Date.. ............ ...... .02/03/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.................STS LIS Reel Trailer Service name.............LISTPE Date..... .............. ..02/03/02 Origin...................STS Reel Name................ UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Writing Library. ( Scientific Technical Services Scientific Technical Services