The URL can be used to link to this page

Home My WebLink About203-007MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, September 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3S-16 KUPARUK RIV UNIT 3S-16 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2022 3S-16 50-103-20445-00-00 203-007-0 G SPT 5669 2030070 1500 2050 2050 2050 2050 610 830 830 820 4YRTST P Sully Sullivan 9/11/2022 Test was due 8/31/2022; well was offline during last test cycle. Baker seal assembly at 5669 ft, all gauges had good cert. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3S-16 Inspection Date: Tubing OA Packer Depth 945 2900 2810 2800IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS220912144928 BBL Pumped:1.3 BBL Returned:1.2 Thursday, September 15, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.09.15 12:21:16 -08'00' DECEIVED 203-Ob�- W,' NOV 15 2019 3 I y y `i ConocoPhillips TRANSMITTAL AOGCC FROM: Sandra D. Lemke, ATO -704 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 222 W. 71h Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Core Photo well list DATE: 11/15/2019 Transmitted: please promptly sign, scan, and e-mail to CC: Receipt: V r V Date: t l (I l Alaska/IT-GGRE IC ocoPhil s Alaska I Office: 90,7.265.6947; Mobile 907.440.4512 11= -me p¢0 Y9 2P-417 Care photos 3 1 4 4 5 2�'3- 04- 3S-16 Core Photos 31444, )01- q !atlas 1 Core photos 3 1 4 4 3 61-0'15 CD2 -24 Core Photos 3 1 4 4 2 Ot-2 Atl Cirque 3 Core photos --50*97- !Ob- j 12 Meltwater North 1 UV WL photos—T2-5 C9400 t1`1(0 Shark Tooth 1 Core photos —Ti 2LiiN9 ,co -c 12Z lDD4025935_Meltwater-N-1,pdf-1-2.5 D 1004278632_3S-16.pdf 3 1 4 4 4 :f)_0 y5:1 1064282603 Rendenous-A.pdf 3 1 4 4 6 please promptly sign, scan, and e-mail to CC: Receipt: V r V Date: t l (I l Alaska/IT-GGRE IC ocoPhil s Alaska I Office: 90,7.265.6947; Mobile 907.440.4512 r� • • 8 T _ ^J 6- ' '_\ > y 0 ro v c0 Q > Wrw � � � >, _r h C7 N Z „�, Y O v cC>3 v 0 w C C O u N +' C > <�m 0 a °- o C - > 0 <N m CO 4-, H 0 2 - C v a - c ' 0 C E o m p 0 n N N N r N -- J ' .0 C u J Q „ C C C C C C 4' L -O 0 N C@2 -Il6 R f6 10 f6 10 -O N ? _) _) -7 ") -, 47 C .0 v, C N F 00 N 1n Oci C @ Y .0 Cu QN Z `. Q N N N M Ou -o CO O u Z d' E > v O C O -O u 0 0 0 cl 0 0c aJ L J J J J J J CDC y. 0 } W W W W W W v, U - F- LL LL LL LL LL LL O L �-✓ Q J J J J J J 9 d G � a Q Q Q Q Q Q C ro v o Z Z Z Z Z Z v v a) LL LL LL LL LL LL CC ^--, . > ea - IJ N C, C } O co O .a N v 0 ro' Z CO •,„„cu u > • �. U 0 m •• c a a H > U II3 Q o 0 u z J Q a, a 0 C a Cr) mO o \+Um a a a L II- omi = E" 0 4,, ce U U d N MQ1 � U 5al az w U W \1 C oN (ZS a - ozs . 9 G x0 , e /E .X z LU W eao (a 0 co - v d J J J J J J / z a z 2 u,c.,I � 3 L z In vi, cuW ,111.--1,1 if.. ...-d"PfP en a) w w w www = li ceLL' 2' LL' LL' tx N Y Y Y Y Y Y C ® > > > > > > wreLL' xd' d' a+Q Q Q Q Q Q >'W a a a a a a uU Y Y Y Y Y Y �'co N 2'' to X n'- U WQM 0 O 0 M ett0 (p WV� � � 0000 E ` C Oo 0 o c o o v CO O v Y Y ii �i t, �i C i �r U C7 0 0 0 0 C W �,. ,. 0 lL 0 0 0 0 C � (_) 0000 CC M 14- roN E \ O o O O O O C o 0 0 0 0 o po N cr (C) co ti-) N N- r) E 0 0 0 0 0 rNi 0 0 IN N N N N N N L. .L7 n M ) o) r) o) o) v �, EO O N 0 N N 01 O O O 0 i O O O OO O z 4 C In In u) in a U c @ O Cm a7 V a q Y i a ii ja I- aJ y' .-1 Q co N v o0 r- QJ 3 N d Z 1.+ 4a Z N Cl ate+ y H . < 0 '+ W M M N N m , ro Z C cc Y 0 y Q H a a Q Comments about this file Quality Checked I I 11111 I 151 II I BY: Helen Maria I I Date: 111111 1 1111 ReScanned I I II 151 11111 I I Scanning is complete at this point unless rescanning is required. BY: Stage 1 BY: Stage 1 Helen Maria Page Count Matches Number HelenCMaria) NO in stage If 1 page(s) discrepancies were found Date: YEt Date:4-171()~ YES NO NO 151 lA1P 1 in Scanning Preparation include cover sheet) ~ Page Count from Scanned File: /{o (Count does Production Scanning BY: Helen ('Maria) 1D + ~ = ~TAL PAGES (Count ý~e r;i1. lude cover Date: t -110S-/sl 1IIIIII11 I ~ fl!ó If) sheet) m~ II Scanning Preparation BY: Project Proofing BY: Helen Helen (Maria ~aria ~ ) ) ~ x 30 = Date: Date: if /7/ O-S- Isl W1/~I~~~ mP 111111 fVtJ NOTES: o Other: o Logs of various kinds o Other: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other Items Scannable by a Large Scanner R;SCAN ~ Color Items o Greyscale Items: DIGITAL DATA ~iskettes. No. I o Other, NolType: o Maps This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J03- Df)!:J Well Organizing (done) History File Identifier ~wo-sided 11/1111 II III 1111 OVERSIZED (Scannable) ~escan Needed I I I I 'I I III XHVZE Image Project Well History File Cover Page MEMORANDUM ~ State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday, August ] 0, 20] 0 Jim Regg P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 35-16 F1tONlc Bob Noble KUPARUK RIV UNIT 3S-16 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv _ NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3S-16 Insp Num: mitRCN100809151457 Rel Insp Num: API Well Number: 50-103-20445-00-00 Permit Number: 203-007-0 Inspector Name: Bob Noble Inspection Date: 8/x/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 3s-16 ` Type Inj. ~' TVD 5669 IA 160 1840 ~ 1760 1740 - P.T.D 2030070 iTypeTCSt SPT Test psi 1840 QA 475 600 600 600 InteYVa14YRTST p~F P ~ Tubing 3000 3000 3000 3000 a Notes: ~li,,'l, ~ ~ ~~-~~'~' ~S, ~ ~' ~ ~- Tuesday, August 10, 2010 Page 1 of 1 • ,. --m.~ .,.-a.-~-_-~,, MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~, ~, , . ,~ F:\LaserFiche\C~rPgs_Inserts\Microfilm_Marker.doc . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 3S-16, 3S-17, 3S-17A, 3S-18. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3S-16: u::rc... 903-0ö-:f. ~ 1~/3?fd- Digital Log Images: 50-103-20445-00 1 CD Rom 3S-17: UJ:.~ ';;>03 -blS- :Sf 1'-(31)3 Digital Log Images: 50-103-20448-00 1 CD Rom U:I.c. 3S-17A: 190"3-D150 ¡ILI3~/ crANNEDFEB 012007 Digital Log Images: ~ 50-103-20448-01 1 CD Rom 3S-18: QÖd -dÓG:, ~ \L(õ-?50 Digital Log Images: 50-103-20433-00 1 CD Rom ,--' v MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor "RGi'/I'; ß/3<:¡1~ ~t{ ! DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3S-16 KUPARUK RIV UNIT 3S-16 'J!i!j' Ð 0 7 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv CfP;;?- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3S-16 API Well Number 50-103-20445-00-00 Inspector Name: Jeff Jones Insp Num: miúJ060829 123346 Permit Number: 203-007-0 Inspection Date: 8/22/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3S-16 Type Inj. w TVD 5653 IA 1920 1800 1750 1750 P.T. 2030070 TypeTest SPT Test psi 1500 OA 530 560 560 550 Interval 4YRTST P/F P Tubing 2450 2450 2450 2450 Notes 0.7 BBLS diesel pumped. 1 well house inspected; no exceptions noted. SCANNED S E P 0 8 2005 Wednesday,1\ugust30,2006 Page I of I . ~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 Jt ,;,. Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 a03-007 ~~rt(P Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, 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 top-fill operation was completed on November 18, 2003 and was previously reported to the Commission as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 4 -5, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043, if you have any questions. Sincerely, J ~f~ ConocoPhillips Well Integrity Supervisor Attachment e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmIll. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 10, 2004 ) '3li,1 ~l RE: MWD Fonnation Evaluation Logs 3S-16, AK-MW-2260898 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 3S-16: Digital Log Images 50-103-20445-00 903 -co~( 1 CD Rom G~ 2'/90'/00 Ä~ ~ ~~;- DATA SUBMITTAL COMPLIANCE REPORT 3/7/2005 Permit to Drill 2030070 Well Name/No. KUPARUK RIV UNIT 35-16 Operator CONOCOPHILLlP5 ALASKA INC 5pl-vl )~J~~~?J API No. 50-103-20445-00-00 MD 6150./ TVD 6079 /' Completion Date 2/23/2003-- Completion Status WAGIN REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRea/Dens/Neut, CBL w/SCMT Well Log Information: <- Log/ Electr Data Digital Dataset ~ Med/Fnnt Number ;:f Rpt Rpt Name Cement Evaluation LIS Verification Directional Survey Directional Survey LIS Verification Log Log Scale Media 5 Col Run No 1 ~642 -~ ~g ...I::'6g oÆg " E;~as ~~/ 5 Blu 5 5 5 Blu Blu Blu ~8 Injection Profile Spinner Temperature Injection Profile Injection Profile Well Cores/Samples Infonnation: Current Status WAG IN " ~éc Y.--J Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received Comments 5600 6040 Case 317/2003 2538 6106 Open 4/29/2003 0 6150 Open 2/26/2003 0 6150 Open 2/26/2003 2538 6106 Open 4/29/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Moduie on: 1/14/2003. 5600 6040 Case 4/14/2003 PSP/PILS/SPIN 5600 6040 Case 4/14/2003 PSP/PILS/SPIN 5600 6040 Case 4/14/2003 PSPiPILS/SPIN 5890 5929 Case 5/4/2004 CGfv1 PDF TIF GRAPHICS 5890 5929 Case 5/4/2004 DSN 12558 Name Core Chips Inte/Val Start Stop 5912 5971 Sent Sample Set Received Number Comments 2/11/2003 1121 '-"'/. ~.-- _/ -" DATA SUBMITTAL COMPLIANCE REPORT 3n /2005 Permit to Drill 2030070 Well Name/No. KUPARUK RIV UNIT 3S-16 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20445-00-00 ADDITIONAL INFO~ATION Well Cored? U, N f?::..... N Chips Received? \...:JA GYN MD 6150 Analysis Received? --~- Comments: ~~ TVD 6079 Completion Date 2/23/2003 Completion Status WAGIN Daily History Received? Formation Tops Compliance Reviewed By: ~ -==- Current Status WAGIN UIC Y ~ """""' C!JN Date: ) ¥~ ¡- _/ _0" Phone:(281) 565-9085 Print Name: Signed PRoACTivE Fax:(281) 565-1369 '1/ ~ A I J ~... ()Lfi- H- C,j ~'J u,\fð- a k l Q '- J DiAGNOSTic SERvicES, INC., E-mail: PO Box 1 }69 STAffoRd IX 77477 pds@memorylog.com Website: Date IL~J0 ~ 2 d \J f...1 www.memorylog.com Caliper Survey 1 Rpt or 2 Color ~';..- \lJ L\- 2,5 -DL\ Res. Eva!. CH J ^ J- ~- ~ Mech. CH 1 1 °'6\\0:·\ ~l'~ 1 WELL DATE LOG TYPE Open Hole DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 1 BLUE LINE PRINT(S) BLUE LINE REPORT OR Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 The technical data listed below is being submitted herewith this transmittal letter to the attention of : Please acknowledge receipt by returning a signed copy of RE Distribution - Final Print(s) State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 To: ÖS GO) ProActive Diagnostic Services, Inc. (I WELL LOG TRANSMJIIAL ) } ¡ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation D or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 1 st 2003 I 2nd 2003 I 3rd 2003 14th Total Ending Volume (bbls): o o 31006 100 o o o o 31006 100 Pressure vs. Time D 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ~"^ì \~ '\"<. c'\ "..,( ì '\'L- 0 '"- -- ) Signature: Printed Name: Form 10-423 Rev. 9/2003 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG0 GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 303-085 (h)(3) Other Commission approved substances (include descriptions in block 12) 3/20/2003 Volume (bbls): Number of days disposal occurred 357* 357 0 0 0 31106 0 0 0 0 31 357 31463 31 Step Rate Test D Date: Title: ~ í t ~ '\ E- ~;-. L....c-~cÂ INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-007 38-16 50-103-20445-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ o 4/14/2003 5/17/2003 38-23, 38-17, 38-06 o o ~j Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 1-111 &( O~-f Phone Number: 2..6 S- ~ 8 S 0 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. f \ ~ \~_ ~ -..J 7 ~Q ---.Cõo ~ 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 2nd 31006 100 2003 / 3rd 2003 / 4th 20041 1st Total Ending Volume (bbls): 31006 100 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D Signature: Printed Name: Form 10-423 Rev. 9/2003 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: 303-085 (h)(3) Other Commission approved substances (include descriptions in block 12) 3/20/2003 Volume (bbls): Number of days disposal occurred 357* 357 o 31106 31 357 31 31463 Step Rate Test D Date: Title: ~c-S~L~ INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-007 38-16 50-103-20445-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ---/ 4/14/2003 5/17/2003 38-23, 38-17, 38-06 "~~ Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \ 11...6 {or Phone Number: 2..&'>-6.g~o Submit in Duplicate ) STATE OF ALASKA ') ALA,. OIL AND GAS CONSERVATION COMMISSI / ~ REPORT OF SUNDRY WELL OPERATIONS {V;üJJ f-o wA C? )ermit to Drill Number: ConocoPhillips Alaska, Inc. 203-007 I 3. Address: 6. API Number: P. O. Box 100360 50-103-20445-00 7. KB Elevation (tt): 9. Well Name and Number: RKB 57' 3S-16 8. Property Designation: 10. FieldlPool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6150' feet true vertical 6079' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 281 1611 1081 108' SURFACE 2530' 9-5/8" 2558' 2558' PRODUCTION 5881' 7" 5907' 58391 LINER 427' 3-1/2" 6145' 6074' Perforation depth: Measured depth: 5915-5934 true vertical depth: 5847-5866 NOV 0 7 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5771' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 530' 'reby certify that the foregoing ¡, Ire Form 10-404 Revised 2/2003 · NOV 1 ~~ 200t1 SUBMIT IN DUPLICATE fØDMS Bfl Date 10/28/03 Event Summary ) 3S-16 ) . DESCRIPTION OF WORK COMPLETEl, SUMMARY } Alaska 0 OCT 1 6 2003 Commission & Gas Cons. Anchorage RECEIVED RT Iskad CPAI Drilling R. Thomas Kuparuk Drilling Team Leader ~ \ \ Sincerely, If you have any questions Scott Lowry at 265-6869 \ ~ regarding this matter, ConocoPhillips Alaska, Inc. submits the attached core analysis report to supplement the Well Completion Report for the Kuparuk weIl3S-16. please contact me at 265-6830 or Dear Subject: Commissioner: Well Completion Report for 3S-16 (APD # 203-007 1303-034) Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 October 15. 2003 ConocóP'hiIIi ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ) ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells A [ore Lab PETROLEUM SERVICES ) ') CORE ANAL YSIS RESULTS PHILLIPS ALASKA, INC. "KUPARUK" 3S-16 KUPARUK FIELD UMIAT MERIDIAN, ALASKA CL FILE #57111-03010 Performed by: Core Laboratories 3430 Unicorn Road Bakersfield, CA 93308 (661) 392-8600 Final Report Presented March 31, 2003 Petroleum Services 3430 Unicorn Road Bakersfield, California 93308 Tel: 805-392-8600 Fax: 805-392-0824 www.corelab.com CLB . "CUll'. NYSE ) TABLE OF CONTENTS DESCRIPTION OF SERVICES CORE ANALYSIS DATA - TABULATED RE5UL T5 HYDRAULIC UNIT ANAL Y515 RESUL T5 CORE GAMMA ) 4 3 2 1 SECTION ) ) INTRODUCTION Core Laboratories was selected by ConocoPhillips to perform a core analysis study upon samples recovered from the Kuparuk Field, Umiat Meridian, Alaska. Conventional aluminum inner barrel cores were submitted. Presented herein are the results of analysis. This report is divided into five sections. The first section provides a description of services. The second section contains tabulated results of standard PKS analysis. Hydraulic unit classifications in tabular presentation are included in the third section, and the core gamma surface log comprises the final section. ) ) Core Processing Core Laboratories personnel from our Anchorage office performed all field handling as well as all subsequent core processing. Core Gamma Surface Log Each core was scanned for natural gamma radiation utilizing Core Lab's gamma spectrometer. Total gamma radiation is reported in API units. Core Sampling and Slabbing After the gamma measurement the core was slabbed parallel to the core axis using liquid nitrogen as the blade coolant. Due to the small core diameter, a one/fourth - three/fourths cut rather than the normal one/third - two/thirds cut was used. For photography, viewing, description and additional sample selection by ConocoPhillips' representatives the onelfourth sections were placed into slab boxes with Styrofoam inserts. Sample Preparation Both horizontally and vertically oriented one-inch diameter plugs were drilled from each foot of core. Isopar mineral oil was used as the bit coolant and lubricant. Each plug was weighed, wrapped with Saran wrap and aluminum foil, and sealed in a sample jar as drilling was completed. In addition to the routine core plugs, several one and one·half inch diameter plugs were drilled for advanced rock property testing. After all of the samples were taken, the plugs were packaged and shipped to our Bakersfield California facility. ') ) Permeability and Porosity Determinations at Stress Core Laboratories' automated core measurement equipment (CMS-300) was used for pore volume and permeability determinations at elevated confining pressures. The CMS-300 makes direct pore volume measurements by Boyle's Law methods using helium. Pore volume and permeability values were determined at aOO-psi net stress on each sample and at 2400-psi net stress on every fifth sample. Fluid Saturation Calculations Oil and water saturations were calculated using the pore volumes measured by the CMS-300 at aOO-psig net stress. Equations 2 and 3 were used for oil and water saturation calculations. -( ) ( ~- So = Mf-Md-Mw _ J.- -lOa (2) _ 8Q \. Vp ) _ - - Sw = Vw -100 (3) _Vp_ Where: So = Oil saturation (%) Sw = Water saturation (%) Mf = Fresh sample mass (g) Md = Extracted and dried sample mass (g) Mw = Extracted water mass (g) Vw = Extracted water volume (cc) 00 = Density of oil (14 APlo) Vp = Pore volume (co) Permeability to Air CMS-300 permeabilities are determined by unsteady-state methods using a transient "blow down" technique. A tank of known volume filled with nitrogen gas is discharged through the core sample to atmosphere. The decaying tank pressure is monitored versus time, which allows determination of gas ) ) flow rate and pressure drop across the sample at any given time. The automated recording of flow rate versus pressure differential provides the data necessary for calculation of a gas-slippage corrected or Klinkenberg permeability as well as the permeability to air. Both permeability to air and Klinkenberg- corrected permeability are reported. Hydraulic Unit Analysis After rock property measurements had been completed, a hydraulic unit analysis was performed. Reservoir quality index (average pore throat size) and pore ratio values were calculated for each of the horizontal samples using Equations 4 and 5. ROI ~ (4) = 0.0314· <Þ PR <Þ (5) = [1- <Þ ] Where: ROI = Reservoir quality index Ka = Permeability to air (md) cþ = Fractional porosity PR = Pore ratio RQI and PR values were used to group the samples into hydraulic units. Each hydraulic unit represents a unique pore geometry relationship and provides the foundation for the integration of core and electric log data. The results are presented sorted by sample depth, and by hydraulic unit; to facilitate selection of representative samples for any additional testing. Core Photography Photographs of the slabbed core were taken under both white light and ultra-violet lighting at our Anchorage facility. Results of the photography will be presented in hardcopy as well as digitally under separate cover. ¿~. Conoco-Phillips ~, "Kuparuk" 38-16 Core LaI:Ì Kuparuk Field CL File No. : 57111-03010 Core Analysis Results ( 800 psi 08, 2400 psi 08) Sample Depth Permeability PorositY Saturations· Gtain ' Description Notes No. Horizontal Vétficaf 'Oil Water Total 'OIW Dè'l)sity: Kalr I Kkllnk Kalr I Kidlnk tt md met met rTtd .% % % % Ratfo alec·. * Too short for CMS . Steady-state penn. & helium porosity @ 400 psi confining ** Too tight to measure· estimated penn., ambient porosity (bulk volume· grain volume) 1 5912.5 226. 213. 28.5 41.4 35.6 77.0 1.16 2.89 Sst dk bm vf-fgr sslty dk s10 dgld flu - 1V 5913.1 1004. 982. 30.5 2 5913.3 686. 666. 29.9 46.0 34.5 80.5 1.33 2.84 Sst dk bm vf-fgr sstty dk stn dgld flu 3 5913.9 1713. 1'547. 33.5 55.0 23.7 78.7 2.32 2.70 Sst dk bm vf-fgr ssfty dk stn dgld flu 4 5914.5 580. 510. 23.7 50.7 25.6 76.3 1.98 2.91 Sst dk bm vf-fgr sslty dk stn dgld flu 5 5915.5 40.3 37.3 18.1 51.4 22.9 74.3 2.24 2.92 Sst dk bm vfgr ssIty dk 8tn dgfd flu 5 5915.5 38.1 35.2 17.5 2.92 Sst dk bm vfgr ssIty dk stn dgld flu 2V 5916.1 158. 151. 21.9 6 5916.4 1714. 1342. 27.9 62.2 15.9 78.1 3.91 2.78 Sst dk bm vf-fgr sslty dk stn dgld flu 7 5916.9 1727. 1496. 30.8 64.6 15.9 80.5 4.06 2.73 Sst dk brn vf-fgr sslty dk stn dgld flu 8 5917.4 344. 336. 22.1 52.1 25.5 77.6 2.04 2.88 Sst dk bm vfgr sslty dk stn dgld flu 9 5918.5 2.92 NA 5.7 35.2 5.8 41.0 6.07 3.10 Sst It bm vfgr vslty m stn dgld flu 10 5919.3 1850. 1646. 30.4 54.9 21.1 76.0 2.60 2.70 Sst dk bm vf-fgr sslty dk stn dgld flu 10 5919.3 1482. 1414. 29.1 2.70 Sst dk bm vf-fgr sslty dk 8tn dgld flu 11 5919.9 136. 128. 20.7 52.3 20.6 72.9 2.54 2.91 Sst dk bm vfgr sslty dk 8tn dgld flu 3V 5920.0 < 0.0001 < 0.0001 12 5920.5 < 0.0001 < 0.0001 3.9 62.7 3.2 65.9 19.59 3.02 Sst It bm vfgr vs/ty m stn dgld flu 13 5921.5 2513. 2180. 28.0 71.1 8.7 79.8 8.17 2.70 Sst dk bm vf-fgr sslty dk stn dgld flu ~ 14 5922.2 2970. 2404. 30.9 62.3 13.7 76.0 4.55 2.73 S8t dk bm vf-fgr sslty dk stn dgld flu 15 5922.9 2121. 1955. 27.6 57.0 21.3 78.3 2.68 2.72 Sst dk bm vf-fgr sslty dk 8tn dgld flu 15 5922.9 1804. 1764. 26.7 2.72 Sst dk brn vf-fgr sstty dk 8tn dgld flu 4V 5923.1 3501. 3230. 27.0 Sst dk bm vf-mgr sslty dk 8tn dgld flu 16 5923.5 332. 318. 19.6 57.1 16.2 73.3 3.52 2.85 Sst dk bm vf-fgr sslty dk stn dgld flu 17 5924.1 2606. 2418. 26.8 64.8 16.2 81.0 4.00 2.70 Sst dk bm vf-fgr sslty dk stn dgld flu 18 5924.5 2726. 2436. 26.6 70.8 10.0 80.8 7.08 2.70 Sst dk bm vf-fgr sslty dk stn dgfd flu 19 5925.2 449. 439. 19.7 65.0 12.9 77.9 5.04 2.78 Sst dk bm vf-fgr sslty dk stn dgld flu 20 5925.8 2781. 2636. 25.9 . 55.7 24.4 80.1 2.28 2.67 Sst dk bm vf-fgr sslty dk stn dgld flu 20 5925.8 2321. 2301. 25.1 2.67 Sst dk bm vf-fgr ssIty dk 8tn dgld flu ~C\\j .' ~ b / Ub ~ b'.? ~~\ / \ /,-t ?\ . ;'l,.. ~\G / ) "\'"\ ' ~v f\ II ') :\ LJv "-110" \~'iL ~ ~\ 0 -..A \) <~~ ì ;.~ Conoco-Philllps ~, "Kuparuk" 38-16 Core I.fII:i Kuparuk Field CL File No. : 57111-03010 Core Analysis Results ( 800 psi 08, 2400 psi 08) Sample Depth Permeability . Saturations ~ .Gtain . · Oêscription Notes No. Horizontal Oil ·.··Water Total om 'Density- Kalr 1 Kkllnk ft md md '/. 'I.. % 'ÁI ~Ratlau. glee · Too short for CMS . Steady-state penn. & helium porosity @ 400 psi confining ** Too tight to measure· estimated penn., ambient porosity (bulk volume - grain volume) 21 5926.4 98.8 94.2 15.3 48.6 20.0 68.6 2.43 2.71 Sst dk bm vt-fgr sslty dk stn dgld flu 22 5927.4 6.96 6.12 15.5 43.0 37.6 80.6 1.14 2.70 Sst bm vt-fgr slty dk stn dgld flu 23 5928.0 404. 318. 21.3 52.6 26.3 78.9 2.00 2.66 Sst dk bm vt-fgr sslty dk stn dgld flu 5V 5928.0 74.7 70.4 16.7 5V 5928.0 70.3 66.4 16.2 24 5928.5 0.249 0.170 14.0 13.0 81.0 94.0 0.16 2.69 Sh It bm stty m stn vdull or flu 25 5930.4 0.052 0.041 10.0 9.0 90.9 99.9 0.10 2.63 Sh It bm slty m stn vdull or flu 25 5930.4 0.005 0.004 8.6 2.63 Sh It bm sIty m stn vdull or flu ~ ;". .. Conoco-Phllllps ., "Kuparuk" 38-16 Core Lab Kuparuk Field Dépth (ft) . 5912.5 5913.3 5913.9 5914.5 5915.5 5916.4 5916.9 5917.4 5918.5 5919.3 5919.9 5920.5 5921.5 5922.2 5922.9 5923.5 5924.1 5924.5 5925.2 5925.8 5926.4 5927.4 5928.0 5928.5 5930.4 Hydraulic Unit Classification S§ª~ª,tþyI~~mPt~l,ª~Rt,t:ï .' .. Fh5w'.; ,.?RiíiêÍ'Voìf~cftyCt~Ülrcf Z~~~·. ... ·'.~Q~~li~....Uñif Indicator.lndex . " 2.2179 3.5252 4.4576 4.9997 2.1202 6.3593 5.2828 4.3662 3.7206 5.6082 3.0850 0.0124 7.6496 6.8837 7.2205 5.2984 8.4566 8.7715 6.1083 9.3090 4.4169 1.1467 5.0537 0.2571 0.2042 0.884 1.504 2.246 1.553 0.469 2.461 2.351 1.239 0.225 2.450 0.805 0.001 2.975 3.078 2.753 1.292 3.096 3.179 1.499 3.254 0.798 0.210 1.368 0.042 0.023 CL File No. : 57111 - 03010 ·.·'$ê~ª~~x~~ª~I1~.t;J~~. ·~pt"'r . ··.·rf'j~Vl··':".\Rt~,~.t\1ojr··< ·.HYdtåûlìc -/;-~f~~~"''- <R~~~fj~1 Unit .i',(ft)/ . ,Indicator' -. .... ·lnCfex· 12 13 14 14 12 14 14 14 13 14 13 2 15 14 14 14 15 15 14 15 14 11 14 8 7 5920.5 5930.4 5928.5 5927.4 5912.5 5915.5 5913.3 5918.5 5919.9 5913.9 5914.5 5916.4 5916.9 5917.4 5919.3 5922.2 5922.9 5923.5 5925.2 5926.4 5928.0 5921.5 5924.1 5924.5 5925.8 0.0124 0.2042 0.2571 1.1467 2.2179 2.1202 3.5252 3.7206 3.0850 4.4576 4.9997 6.3593 5.2828 4.3662 5.6082 6.8837 7.2205 5.2984 6.1083 4.4169 5.0537 7.6496 8.4566 8.7715 9.3090 0.001 0.023 0.042 0.210 0.884 0.469 1.504 0.225 0.805 2.246 1.553 2.461 2.351 1.239 2.450 3.078 2.753 1.292 1.499 0.798 1.368 2.975 3.096 3.179 3.254 2 7 8 11 12 12 13 13 13 14 14 14 14 14 14 14 14 14 14 14 14 15 15 15 15 ~ ~ 5911.00 5911.50 5912.00 5912.50 5913.00 5913.50 5914.00 5914.50 5915.00 5915.50 5916.00 5916.50 5917.00 5917.50 5918.00 5918.50 5919.00 5919.50 5920.00 5920.50 5921.00 5921.50 5922.00 5922.50 5923.00 5923.50 5924.00 5924.50 5925.00 5925.50 5926.00 5926.50 5927.00 5927.50 5928.00 5928.50 5929.00 5929.50 5930.00 5930.50 5931.00 -999.3 40.2 37.3 21.8 32.2 34.2 24.2 26.6 36.6 34.9 43.7 27.6 32.7 22.0 22.1 36.4 22.5 26.7 23.7 36.5 22.4 25.6 23.5 14.4 33.1 39.0 26.4 13.9 28.8 31.1 23.3 31.2 43.1 34.4 25.7 45.4 41.4 38.9 50.6 60.7 42.0 De'tli ,.p fl:. tptQrt$~roijía· ARI .. [ore Lati Conoco..Phillips II Kuparuk" 35..16 Kuparuk Field CORE GAMMA SURFACE LOG ') ) CL File: 57111-03010 5931.50 5932.00 5932.50 5933.00 5933.50 5934.00 5934.50 5935.00 5935.50 5936.00 5936.50 5937.00 5937.50 5938.00 5938.50 5939.00 5939.50 5940.00 5940.50 5941.00 5941.50 5942.00 5942.50 5943.00 5943.50 5944.00 5944.50 5945.00 5945.50 5946.00 5946.50 5947.00 5947.50 5948.00 5948.50 5949.00 5949.50 5950.00 5950.50 5951.00 5951.50 45.6 48.3 41.1 58.9 48.4- 37.9 27.4 41.8 38.1 57.5 47.3 37.1 26.8 58.8 42.5 44.5 38.3 29.9 46.2 53.3 43.1 32.9 51.4 67.5 53.4 39.3 30.4 54.8 51.6 35.9 35.0 39.5 23.9 47.8 49.9 35.2 37.3 47.6 34.8 22.1 23.1 Dê~îh .ft "'øtil)Cåmmâ .' .. .' L :: ' :, " ,'i,: ': ," ":'" : :¡.')', :;', "";' " ~ :" " .·API ) ) .. Conoco-Phillips CL File: 57111-03010 . ... "Kuparuk" 3S~16 CoreLab Kuparuk Field CORE GAMMA SURFACE LOG ') ) .. Conoco-Phillips CL File: 57111-03010 "Kuparuk" 38-16 ÜJn! LaI:Ì Kuparuk Field CORE GAMMA SURFACE LOG Oê"'tfl· ......>&.... 5952.00 5952.50 5953.00 5953.50 5954.00 5954.50 5955.00 5955.50 5956.00 5956.50 5957.00 5957.50 5958.00 5958.50 5959.00 5959.50 5960.00 5960.50 5961.00 5961.50 5962.00 5962.50 5963.00 5963.50 5964.00 5964.50 5965.00 5965.50 5966.00 5966.50 5967.00 5967.50 5968.00 5968.50 5969.00 5969.50 5970.00 37.3 31.4 55.6 38.2 58.4 33.0 46.6 43.9 38.6 33.4 50.0 48.4 59.3 38.3 37.5 58.5 43.3 26.0 24.1 40.9 39.8 23.3 43.2 35.3 38.7 51.0 41.1 53.3 37.7 40.3 68.9 55.3 38.2 30.7 46.5 33.2 18.3 ~. .. .~...' .. , .. ".. h···. . tø~~~,m~ "API' CD2-50 ID-II IC-IS 31530 32102 32251 100 100 100 o o o 370 235 373 32000 32437 32724 Open, Freeze Protected Open, Freeze Protected Open, Freeze Protected July 2002 May 2002 June 2002 5ept2002 June 2002 July 2002 CD2-19, 23 CD2-41 D-I03 C-I04 CD2-38 CD2-32 Well Name CD2-17 31337 Total h(l) Volume 17709 100 Total h(2) Volume 100 o Total h(3) Volume o 379 Authorization Expired during the second quarter 2003: Freeze Protect Total Volume Fluids Injected Volume 372 31816 18181 Open, Freeze Protected Status of Annulus Open, Freeze Protected June 2002 May 2002 July 2002 Feb 2003 CD2-08, CD2-48, CD2- 46 CD2-41, CD2- Start Date End Date Volumes into Annuli for which Disposal Source Wells Total IC-19 38-08B CD2-19 CD2-41 38-17 A 31325 31610 30860 3900 4559 100 100 100 100 100 o o o o o 31425 31710 30960 4000 4659 o 290 377 377 361 o o o o 5020 31425 32000 31337 4377 5020 May 2003 May 2003 May 2003 June 2003 June 2003 Hansen 1 47382 100 o 47482 o 67796 115278 3S-16 31006 100 o 31106 357 o 31463 J CD2-46 31393 100 o 31493 371 o 31864 Puviaq #1 5063 100 o 5163 o 4731 9894 IC-22 21553 100 o 21653 o 27044 48697 March 2003 March 2003 March 2003 April 2003 April 2003 J an uary 2002 June 2003 June 2003 June 2003 June 2003 June 2003 CD2-20 35-19 IC-184, lC-170, IC-172 35-24,35-03,35-19 CD2-58, CD2-52 June 2003 Hansen, Hansen IA May 2003 April 2003 May 2003 April 2003 May 2003 35-23,35-17,35-06,35- 6 CD2-51 CD2-12 Puviaq IC-190, IC-174, 1 C-178 1 C-19 3S-10 Annular Disposal during the second quarter of 2003: h(3) Total for Volume Quarter Well Name 9972 h(l) Volume 100 h(2) Volume o 10072 Freeze Protect Volumes 388 21204 Previous Total 31664 New Total Start Date End Date 35-21 Source Wells 35-08, 35-23 dO 3é)C) 1- of 2 4/30/2003 8:02 AM > > > > > > Subject: 3S-16 Water Injection > Date: Tue, 29 Apr 2003 16:53:44 -0800 > From: "Daniel E Hensley" <Dan.E.Hensley@conocophillips.com> > To: Winton Aubert <Winton_Aubert@admin.state.ak.us> > CC: "CPF3 Prod Engrs" <n1223@conocophillips.com>, > "Daniel E Hensley" <Dan.E.Hensley@conocophillips.com>, > "Scott L Lowry" <Scott.L.Lowry@conocophillips.com>, > "Christopher J. Alonzo" <Chris.Alonzo@conocophillips.com> > > Winton > > Attached below you will find documentation for '~pplication for Sundry for > 38-16" (for reference) and the E-line log from the 3S-16IPROF & > Temperature Survey (PDS file) completed on 03/15/03. A baseline > temperature survey was conducted while injecting water into weIl3S-16, > then the well was shut-in and warm-back temperature passes were conducted > 15, 30, 60, and 120 minutes after shut-in. Based on the results of the > warm-back temperature passes, there is NO indication of out of zone > injection on well 3S-16. > > In addition, the well 3S-16 injection conditions (injection pressure, > injection temperature, injection rate, inner annulus pressure, and outer > annulus pressure) have NOT been unusual or anomalous. > > Also, on 03/25/03, we1l3S-16 PASSED the state witnessed MIT on the inner > annulus. > > Please give me a call if you'd like to discuss. > > Thanks > Dan Hensley > Palm Surveillance Engineer > ConocoPhillips Alaska > 907-265-1606 > Dan. E. Hensley@conocophillips.com > > (See attached file: 3S-16 COP Letterhead.doc)(See attached file: > Combined_I_PROF.PDS) Name: 3S-16 COP Letterhead. doc Dan, et ai, I have examined the information submitted on 3S-16 and agree that the information demonstrates that the water is being confined to the intended zone. The only question I have is that there appears to be a diameter restriction at about 5770' near the top of the 3-1/2" liner. A "spike" appears on most of the presented log curves and the caliper response is somewhat similar to the GLM at 5650'. I would be interested to hear what the logs might be showing at 5770' Please call me at 793-1250 if you have any questions. Tom Maunder, PE AOGCC Subject: Re: [Fwd: 3S-16 Water Injection]--PTD 203-007 Date: Wed, 30 Apr 2003 08:01 :50 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Daniel E Hensley <Dan.E.Hensley@conocophillips.com>, "Christopher J. Alonzo" <Chris.Alonzo@conocophillips.com>, CPF3 Prod Engrs <n1223@conocophillips.com>, Scott Lowry <sllowry@ppco.com> Re: [Fwd" 38-16 Water Injection]--PTD 203-007 '\ ') ) Re: [\~d: 38-16 Water Injection]--PTD 203-007 ) } > 3S-16 COP Letterhead. doc Type: WINWORD File (application/msword) > Encoding: base64 > > Name: Combined_'-PROF.PDS > Combined_'-PROF.PDS Type: PDSView Document (application/x -unknown-content-type-PDSView. Document) > Encoding: base64 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2of2 4/30/2003 8:02 AM File Edit Display Annotate View Help -~-~----~-- JJ ~ · Id I ~ I ,.~~I a11 Tl jJ~-" ~ ~ .. I ..' - '-.. .. -~,- ~.' .r .... --,-J -- " .'" ~ rP'~, ~ -~ .~ ~ ...,/ ? 'L, "1 ~ I~ ~ ( i { -- :> $(I] ~ J ~ Z r 5 J . è... :> r- <; C < ./ J. ., f ,.=;. ....... 1 { -, I / . Annotations not succorted at this X-Coordinate ... -..~~",---'=-"""--~=-- ,- - D A ~ I ¿ · ~ · 4. · - a I 'rJ. ~ I Helvetica 1 I I , -; .... : I : ~ : I .-: INJtC1"1N ~\T-:Mrt:R^TURC :: I : . ! . 'I~ I r-c 1,:::e~::::F ~: ::,:HJT IN I I r ' ~-- Tè'\l1F'CRATURC AF"'CR 00 tllIN. '!' t , ·"'w------=-~ '" 1" I ¥---I'rMI:'FRAI U h- AnI-to: 110 rujN. . [ i r . ~ ./ /~.<.'.-'~ ,/" (.>:' .-.y. : I I [ ". _:...J\ \. .... , " "\ ,\.. ....4 -. .~.. -. ~ ~, ',\. ... '. '- ~ ~~-: ~.::. ~~ "', ~~, . ''''''''iii. ¡o.~ _"&.. ':~~::~""~.. ~ -..... \!- ~·""'V~ -\~\.'-.~ --. ~ ~. . '~~~\. -...\_~ \~~ fw a ,25 --~~~--- ¡ ..... 10..... I . '..".-- ---l"'T~_-'~_"~_'~'_~_'~____. _.__~___. __....._ ..~_..__~_~ ~~ -, ~ - r ~ J -- \ '-..0 d-O'S-Da~ !File COfficlete r -r Date: si4~ ~y:». ') RECEIVED APR 2 9 2003 Alaska Oü & Gas Cons. Commission Anchorage Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 PLEASE ACKNOWLEDGE RECEJPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: 1 LDWG formatted Disc with verification API#: 50-103-20445-00 listing. RE: MWD Formation Evaluation Logs State of Alaska Alaska Oil and Gas Conservation Corom.. Attn.: Lisa Weepie 333 West ib Avenue, Suite 100 Anchorage, Alaska 3S-16, AI(-MW-2260898 To: WELL LOG TRANSMITTAL April 18.2003 \) / ) <:908-007 II t.oL/ ;) APR ì 4 200.3 Alaska Oi1 & Gss Cons. C{}mm~n Anchor!!fJe Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. RECEIVED 1 :9.0ßd-. I CD Color Field: Kuparuk Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 NO. 2731 04/03/03 BL DATE: 1 1 1 SIGNE;Y--".fA~ i\!"\.~ ,,0 -.ÔL."ì-,. A:>./V\ 03/15/03 03/16/03 01/16/02 INJECTION PROFILE LEAK DETECTION LOG RST Date Log Description ,- 35-16 f9D3--(Y.rT~ 1A-13 \ <;., J -\ '1,5 "/ 1C-102f1,{)} -) lo (/22067 Job# Well ,.....~ Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Scblußlbepger MIT report form 5/12/00 L. G M.I.T.'s performed Attachments Test's The wells were ready to begin testing upon my arrival completed without to much difficulty ~ none mit kru 3s 2-25-03 js.xls Number of Failures: Q Tota cc: Time during none tests: 4hrs 5/12/2003 Details (fluid packed) Although the ambient temp. was -42 the tests were Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test W= Test during Workover 0= Other (describe in notes) Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance Type Inj. Type test T.V.D. Test psi Tubing Casing nterval P/F Type Inj. Type test T.V.D. Test psi Tubing Casing nterval P/F Type Inj. Type test T.V.D. Test psi Tubing Casing nterval P/F 35-22 2030110 Type Inj. Type test 5 P= T.V.D. Test psi 5626 1407 Tubing Casing 2150 1075 2150 1950 2150 1950 2150 1900 nterval P/F 4 E 35-16 2030070 Type Inj. Type test 5 P= Packer T.V.D. Test psi Depth 5718 1430 Tubing Casing Pretest 2360 1060 nitial 2360 950 15 Min 2360 920 30 Mm. 2360 1920 nterval P/F 4 E John H. Spauldmg Petroleum Inspector NON- CONFIDENTIAL 16,22 Kuparuk River Field Kuparuk River Unit FROM '7\ Jim Regg ~;(\ P.I. Supervisor \. THRU Mechanical I ConocoPhillips 3S - \ 'ò?7 \'U\ SUBJECT: ntegrity Tests ~ TO: Randy Ruedric Chair MEMORANDUM 42fJ/) Jlaska Oi h ) DATE: March 25, 2003 State of Alaska. and Gas Conservation Commission I) Alaska Œ1 ~, Gas Cons. Ccmm~n Anch0f'!ge cc 3S-16 Well File Randy Thomas Sharon Allsup-Drake ATO-1576 ATO-1530 MAR RECEIVED Î L~. 2003 Sincerely, ~ ~~ Drilling Engineer If you have any questions or require further information, please contact Randy Thomas at 265-6830. 2. 3. 4. 5. 6. 7. 8. 9. O. Annular Disposal Transmittal Form Pressure Calculations for Annular Disposal Surface Casing Description Surface Casing Cementing Report & Daily Drilling Report during celnent job Casing and Formation Test Integrity Report (LOT at surface casing shoe). Intermediate Casing Description Intennediate Casing Celnenting Report & Daily Drilling Report Formation LOT on 9-5/8" x 7" casing annulus Plan View of Adjacent Wells Details on all wells within·V4 mile of3S-16 at the surface casing Scott (3S-1 :.iowry at 265-6869, or 4, 3S-07, 3S-26) shoe 8, 3.~)- during cem.ent ob Please Phillips Alaska, Inc. hereby requests that 38-16 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on 3S-16 approxilnately April 5. 2002. find attached form 10-403 and other pertinent nfonnation as follows Dear Sir or Madam: Re Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Application for Sundry Approval for Annular Disposal of Drilling Waste m well 3S-16 March 12, 2003 Post Office Box 1 00360 Anchorage, Alaska 99510-0360 Scott Lowry Phone (907) 265-6869 Fax: (907) 265-1535 Email: scott.I.lowry@conocophillips.com y ConocoPh illips ) ) Form 0-403 Rev 06/15/88 RBDMS 8Fl ß-/; Commissioner 'vit\f~ ') SUBMIT IN TRIPLICATE Approved by order of the Commission FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance_ Mechanical Integrity Test Subsequent form required 1 0- t~,\! \r\ct ,\....( /lJ~ Date Approval Signed \ R. Thomas - ~~'~ Date Prepared by Sharon Allsup-Drake Name of approver 7. I hereby certify that the foregoing is rue and correct \~ Title: Kuparuk Drilling Team Leader Date approved Service _XX to the best of my knowledge. Questions? Call Scott Lowry 265-6869 5 J 17 ('ö'5 16. 3. Attachments 14. Estimated date for If commencing operation April 5, 2003 proposal was verbally approved Oil Detailed operations program _XX 5. Status of well classification as: Gas Suspended Baker 7" x 5" ZXP Liner Top Land Nipple @ 530' Description summary of proposal _XX BOP sketch Packers & SSSV type & measured depth) Isolation Packer @ 5718' .s~ C:;t~s ;..~<:( fJ '" f"'·~;""·ii<>;"\\~ III' '~<I'U i It ':.J~ ',... ,~j ~," Tubing (size, grade, and measured depth PJa3~a C\i .:...~ '1.J':.. m¡;~~~n 3.5".9.3#, L-80 @ 5735' MAli "1 4 '" ("\ f"1, ·:v ~..:,.)'(,it) true vertical 5847' 5866' Perforation depth measured 5915' - 5934' RECEI\fEl1 Production Liner Surface 5879' 428' 2531 measured true vertical L~rîgth 108' Size 16" 9.625" 7" 3.5" 85 sx Class G 21 sx Class G 440 sx AS ILite, 240 sx LiteCrete Measured Depth 108' 2559' 5907' 6145' 5839' 6075' True vertical Depth 108' 2559' Casing Conductor Cemented 30 sx Arctic Crete Effective depth: 567' FEL, Sec. 18, condition summary measured true vertical 6049 5980 6150 6079 feet feet feet feet Junk (measured) At total depth 2377' FSL, 12. Present well Total depth: Plugs (measured) API number 50-103-20445 11. Field / Pool Kuparuk River Field/Kuparuk River Oil Pool T1 2N, R8E, UM (475693,5993514) 2528' FNL, 1110' FEL, Sec. At top of productive interval 2402' FSL, 1541'FEL,Sec. 18, effective depth At O. T12N, R8E, UM (475719, 5993540) 9. Permit number I approval number 203-007 18, T12N. R8E, UM (asp's: 476149, 5993887) 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3. Address P. O. Box 2. Name of Operator ConocoPhillips Alaska, Inc. Type of request: Abandon _ Alter casing _ Change approved program _ Perforate (DF or KB feet) APPLICATION FOR SUNDRY APPROVALS Re-enter suspended well Time extension Suspend _ Repair well Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development Exploratory Stratigraphic. Service _XX Kuparuk River Unit 8. Well number 3S-16 Variance 6. Datum elevation RKB 28 Property name 7. Unit or Stimulate _ Other _XX Annular Disposal STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) I nO'3iJ3_C1<5 ~t'~~ ~"C\"~~\o.~êJ\~~' 711/03 ) 4: () /T'r 3["1<4 ~ J j> ¡:- , FO -:q~? Any additional to confirm data required by the Commission containment of drilling wastes. 1 h. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. NA See attached casing summary page. g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. sheet and calculation See attached cementing reports, and casing reports. operation value was An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal and calculations showing how this determined. LOT IFIT reports, Maximum anticipated diff~ê:rçntial pressure at casing shoe during disposaJ operations is 1939 psi. See attached calculation page f. e. Identify the types and maximum volume of Types of waste can be drilling mud, drilling waste to be disposed of and the estimated density cuttings, cement-contamÌJlated drilling mud, of the waste slurry. completion fluids, diesel, tt)tnlation fluids associated with the act of drilling a well, domestic waste water, and any added '\),/ater needed to facilitate pumping of drilHng :lnud or drilling cuttings. Maximum volurne to be pumped is 35,000 bbls. / d. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. See attached map indicating\~¡ells within There are no water wells \;v'Ìlthin 1 mile. I 1/4 mile. c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater From open IS with occasional sands. the 9 5/8" shoe to the cement top.Jll that is interbedded claystoÒ{(, siltstone and shale minor nOlI1··]11ydrocarbon bearing b. The depth to the base of freshwater aquifers and permafrost, if present. / No aquifers 1 Base Permaj}ost RKB a. Designation of the well or wells to receive drilling wastes. / = +1- 1546' TVD Annular Disposal ) 3S-16 Transmittal Form ) Maximum Fluid Density to Collapse 7" Casing: Pcollapse85% = PHydrostatic + P Applied - PGasGradient - PHeader 4598 = MWmax (0.052) (5052) + 1500 - (0.11) (5052) - 1350 MWmax = 19.0 ppg Maximum fluid density to burst 9-5/8" casing: Pburst85% = PHydrostatic + P Applied - PFonnation 4888 = MWmax (0.052) (2559) + 1500 - 0.4525 MWmax = 34.2 ppg (2559) Maximum pressure at 9-5/8" shoe: Pmax = PHydrostatic + P Applied - PFonl1ation Pmax = 12.0 (0.052) (2559)+ 1500 - 0.4525 (2559) Pmax = 1939 psi ~ () c :.::¡ t:! ~ M L ~ CALCULA TIONS: ASSUMPTIONS: · Maximum injection pressure, P Applied = 1500 ps · Maximum density of injection fluid is 12.0 ppg. · Pore pressure at 9-5/8" casing shoe is 0.4525 ])si/ft · Injection gas pressure is 0.11 psi/ft + 1350 psi header pressure 0'> c: :.a ::J I- ~ ~ ~W L ~ <;=7" 26 lb/ft, L-80, BTC casing @ 5907 ft MD Pcollapse = 5410 psi, @ 85%: Pcollapse85% (5839 ft TVD) = 4598 psi Toe <;=3-1/2" 9.3 lb/ft L-80 tubing to 5735 ft Estimated Top of Cement @ 5107 ft (7" csg x 8-1/2" Open hole annulus) MD (plan :n cd) 0'> c: ëi5 co Ü Cx:> ì:õ ~ \.... () "'0 co () ..c: "00 0- o I.() ('I') ~ + ~ ·00 0- ~ ~ o (f) co (.9 \.... () "'0 ~ ..c: '00 0- o I.() ('I') ~ + ~ '00 0- ~ ~ o (f) co (.9 ~ MD <;=9-5/8" 40 lb/ft, L-80 BTC casing @ 2559 ft Pburst = 5750 psi, @ 85%: Pburst85% = 4888 psi (5052 ft M)) 'V'D) 2559 ft TVD) DETAILS: 38-16 Pressure Calculations for Annular Dispo~~ul ) ) TUBING (24-5771 , 00:3.500, 10:2.992) SURFACE (28-2558, 00:9.625, Wt40.00) ~OOUCTION (26-5907, 00:7.000. Wt26.00) NIP (5695-5696, 00:5.390) PACKER (5718-5719, 00:5.960) LOCATOR (5733-5734, 00:5.000) SEAL (5735-5736, 00:3.980) LINER (5718-6145, 00:3.500, Wt:9.30) e I u Date Note 2/10/2003 TREE: FMC I GEN 5/5M TREE CAP CONNECTION: 53/4" ACME W/3.5" EUE 8RD THREAD I -......"'..'..',.......,.'..,,'......,..'...,,'.'.........'.,..... .'....,....,......... .,.....".,......".'.....".".... ·,···,······',··I··"i········,..,.. '. '.... '.. .. .. .. ',... .. .'. ... ..,......,..,...,.... ,,,"" 24 530 5695 5733 Man Mfr 1 5651 5651 CAMCO Øthe...(;JIUgs¡:èqÜÎø;~:êt¿;~ Depth TVD Type 5718 5718 PACKER 5749 5749 SBE 6143 6143 SHOE Man VMfr V Type VOD Latch Port TRO Date Vlv Type Run Cmnt rvTv1G SOV 1.5 RKP 0.000 0 2/10/2003 IlINER.JEVVEIlRY Description ID ZXP LINER PACKER WIHR PROFILE 4.420 BAKER 20' SEAL BORE EXTENSION 4.000 BAKER 2.5" 'V" FLOAT SHOE 2.992 WUEWEI2RV: Description FMC 3.5" GEN 5 TBG HANGER CAMCO 'OS' NIPPLE WINO GO PROFILE CAMCO 'OS' NIPPLE WINO GO PROFILE BAKER G-22 LOCATOR SUB BAKER SEAL ASSEMBLY St MD Size 3.500 TVD Description PRODUCTION SURFACE CONDUCTOR Size 7.000 9.625 16.000 Top 26 28 28 Bottom 5907 2558 108 TVD 5907 2558 108 Wt 26.00 40.00 62.50 Grade L-80 L-80 H-40 Thread BTCM BTCM WELD Annular Fluid: Reference Log: Last Tag: Date: Last Well Type: SVC Orig Completion: Last W/O: Ref Log Date: TD: 6145 ftKB o 24.33' RKB Rev Reason: NEW WELL Last Update: 2/13/2003 API: 501032044500 SSSV Type: NIPPLE Angle (â>. TS: deg (â>. Angle @ TD: deg @ ConocoPbilUps, Alaska,~.lnc" ') ) KRU 35-16 Supervisor: Dave Burley Mike Thornton / Granville Rizek Drifted all casing to 8.679" Up Wt - On Wt - 25k 125k Block Wt - 30k Remarks: Use Jet Lube "Run-N-Seal" pipe dope MU torque 9,00 ft/lb Last Joint in shed stays out 5 jts. Outside not on tally (Including extra float equip.) Total of 70 Jts. On location Total of 65 Jts. On tally (All 65 Run 64 Joints jts in shed) RUN TOTAL 14 BOWSPRING CENTRALIZERS 2 on jt.#1 (31 to 51 above Shoe on stop ring and over collar) 1 on Jt. #2 (On stop ring 5' below Float Collar) 1 per jt on Jt #3 - #13 (Total of 14 centralizers & 2 Stops) 9-5/8" Shoe @ 2,5581 MD 2,558' TVD 12-1/4" T.D. @ 2,570' MD 2,570' TVD 2570.00 TO 12 1/4" Surface Hole Jts Jts 3 to 64 to 2 2 Jts 62 Jts 9-5/8" 40# L-80 BTC Csg Weatherford Model 303 Float Shoe (00 Nabors 7ES RT to Lnd Ring LID groove center(Load shoulder= 29.6C FMC Gen V Hanger (Pup = 1.39') (00 of hngr 15.25") 9-5/8" 40# L-80 BTC Csg Weatherford Model 402 Float Collar (00 10.64". 10 8.865") 0.64" 10 8.865") 29.60 1.70 2438.06 1.44 86.37 .73 29.60 31.30 2469.36 2470.80 2557.17 2558.90 Jt _PHILLIPS Alaska, Inc. .~. A Subsidiary of PHILLIPS PETROLEUM COMPANY ) Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Casing Detail 9 5/8" Surface Casinq ) LENGTH Well Date: DEPTH TOPS 35-16 1/28/2003 Legal Well Name: 38-16 Spud Date: 1/26/2003 Common Well Name: 38-16 Report #: 1 Report Date: 1/28/2003 Event Name: ROT - DRILLING 8tart: 1/25/2003 End: 2/10/2003 ~ênèrånl'l String Type: Surface Casing Permanent Datum: Hole Size: Hole TMD: 2,570.0 (ft) Hole TVD: 2,569.0 (tt) KB-Datum: 0.00 (tt) Water TMD: (ft) Str Wt on Slips: 95,000 (Ibs) Ground Level: (tt) CF Elevation: (tt) Liner Overlap: (tt) Max Hole Angle: 1.93 (0) Circ Hours: 2.50 (hr) Mud Lost: (bbl) KB to Cutoff: 29.60 (tt) Days From Spud: 2.75 (days) - Manufacturer: Hanger Model: FMC P118997-0001 Model: Gen V Packoff Model: Top Hub/Flange: (in) I 5,000 (psi) BTM Hub/Flange: (in) 15,000 (psi) Actual TMD Set: 2,558.90 (tt) Item Size Weight (in.) (I bitt) Casing Hanger 9.625 40.00 L-80 8.679 BTC 1.70 29.60 N FMC P118997 -0001 'JEW 9.625 8.835 Casing Hanger Casing 9.625 40.00 L-80 8.679 BTC 62 2,438.06 31.30 N \JEW 9.625 8.835 95/8" 40# L-80 Float Collar 9.625 40.00 L-80 8.679 BTC 1.44 2,469.36 y WEATHERFORD 402 'JEW 9.625 8.835 Float Collar Casing 9.625 40.00 L-80 8.679 BTC 2 86.37 2,470.80 Y \JEW 9.625 8.835 95/8" 40# L-80 Float Shoe 9.625 40.00 L-80 8.679 BTC 1.73 2,557.17 Y WEATHERFORD 303 \JEW 9.625 8.835 Float Shoe 2,558.90 .--- Accessory Bowspring Centralizer Bowspring Centralizer Bowspring Centralizer WEATHERFORD WEATHERFORD WEATHERFORD 2 1 11 2,514.9 2,563.8 2,041.9 2,552.0 Stop Ring 2,565.8 Stop Ring 2,426.9 OverCollar Remarf(s Average MU torque first 10 joints = 9000 tt-Ibs Thread locked shoe track [3 jts] Printed: 3/11/2003 4;08;25 PM Legal Well Name: 3S-16 Common Well Name: 3S-16 Event Name: ROT - DRILLING Report #: Start: 1 1/25/2003 Spud Date: 1/26/2003 Report Date: 1/28/2003 End: 2/10/2003 Used Jet Lube Run -N- Seal pipe dope Ian Curphey & O'Neal FMC Tec Rep Hanger part# P118997 -0001 [fluted mandrel hanger] Warehouse material # 10619945 - J -- Operational Detail: RU GBR Csg Tools and GBR Fill-up Tool. Held PJSM on Running of 9 5/8" Csg MU 9 5/8" Float Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 62 Jts of 9 5/8" Csg, (Total of 64 Jts Ran 2558.90') TIH with No Problems, Landed Csg in Head - RD Fill Up Tool & MU Cmt Head on Landing Jt & Landed Csg wi FS @ 2558.90', FC @ 2469.36'. Ran 14 Bow Spring Centralizers Per Well Program, Ran 2 stop rings. ~ Printed: 3/11/2003 4:08:25 PM Printed: 3/11/2003 4:09:43 PM Test Data Thickening Time: Free Water: Fluid Loss: Fluid Loss Pressure: (%) (cc) OF) Temperature: Temperature: Temperature: OF) OF) OF) Compressive Strength Compressive Strength 2: Temp OF) OF) Pressure (psi) (psi) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: Cmt Vol: Slurry Vol: CW 100 (bbl) (sk) Time Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Purpose: Mix Water: (gal) Foam Job: N Type: Spud Mud Density: 9.2 (ppg) Vise: 54 (s/qt) Bottom Hole Circulating Temperature:65 (OF) Displacement Fluid Type: Mud Density: 9.2 19 (cp)/16 Gels 10 sec: 8 (lb/100ft2) Bottom Hole Static Temperature: 51 ( Volume: 187.00 (bbl) (ppg) PVNP: Ib/100ft2) Gels OF) Omin: 11 Ib/100ft2) Meas. From: 203 Time Circ Prior To Cementing: Mud Circ Rate: Mud Circ Press: 3.50 337 (gpm) 515 (psi) Start Displ: End Pumping: End Pump Date: Top Plug: Bottom Plug: 8:23 18:24 19:49 20:25 1/28/2003 Y Y Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 3 Y Ann Flow After: N Mixing Method: recirculat Density Meas By: Densometer ,000 (psi) (min) Y 500 (psi) Returns: 100 Total Mud Lost: Cmt Vol to Surf: (bbl) 203.00 (bbl) Type: Volume Excess %: Cement Casing 90.00 Start Mix Cmt: Start Slurry Displ: Disp Avg Rate: Disp Max Rate: 6.00 (bbl/min) 7.00 (bbl/min) Rot Time Start: Ree Time Start:14:20 Time End: Time End: 20:24 RPM: SPM: Init Torque: Stroke Length: ,ft-Ibf) 20.0 (ft) Avg Torque: Drag Up: ,ft-Ibf) 125 (lbs) Max Torque: (ft-Ibf) Drag Down: 125 (Ibs) Cement Co: Dowell Schlumberger Cementer: Randy Jost Pipe Movement: Reciprocating Cmtd. Csg: OPEN HOLE Cmtd. Csg: Csg Type: sa TMD: sa Date: Cmtd. Csg: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Csg Type: Csg Size: Hole Size: TMD Set: Date Set: Surface Casing 9.625 (in.) 12.250 (in) 2,559 (ft) 1/28/2003 Hole Size: sa TMD: sa Date: sa Type: Hole Size: TMD Set: Date Set: Hole Size: Top Set: BTM set: t t ft Legal Well Name: 38-16 Common Well Name: 38-16 Event Name: ROT DRILLING Report #: 8tart: 1 1/25/2003 Spud Date: 1/26/2003 Report Date: 1/29/2003 End: 2/10/2003 ') I' ) psi, 25 bbls @ 5 bpm Reciprocated pipe untill surface, CI P @ 2030 hrs. Printed: 3/11/2003 4:09:43 PM switched to 570 psi, last 27 bbls @ 4 bpm 450-500 psi last 27 bbls of displacement PUW 11 OK rig pumps and displaced with (167 bbls total SOW 95K, had mud) bumped plugs to floats held. full returns with 203 bbls of 10.7 ppg cement returns to 115 bbls of mud @ 7.0 bpm 000 psi, Line up to cementers, pumped 5 bbls of CW 100, tested lines to 3500 psi. Pumped additional 45 bbls of CW 100 Pumped 45 bbls of 10.5 ppg Mud PUSH XL with die marker - 336 bbls of 10.7 ppg AS Lite lead cement followed with 96 bbls of 12.0 ppg LiteCRETE tail slurry. Drop top plug -Cementers pumped 20 bbls of of FW 400 600 @ 1.75 bpm wi 321 Gels 60/110 to 8/11 Reciprocated pipe wi full returns throughout. psi. Stage pumps up to 8 bpm wi 563 psi and condition mud. Maintain MW @ 9.2 ppg. Total volume pumped Final 515 psi. PUW rate 8 bpml 320 bbls, 25K SOW 125K. dropped bottom plug. Reduced FV fl 240 to 54. PV fl 38 to last 100 bbls wi nutplug marker. PJSM. Establish circ YP f/ 64 to 16. 19. CBL Run: Under Pressure: Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: N Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N N Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful N N (psi) (ft) Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Found between Shoe and Collar: Y Pressure: Tool: Open Hole: 30 (ft) Hrs Before Test: Test Press: For: Cement Tool: Tool: N N 2,500 (psi) 30 (min) 8.00 N (ppge) D79 D46 D124 D65 D164 BWOC BWOC 29.54 %BWOC BWOC BWOC .00% 16.63 % 0.50% 0.60% Legal Well Name: 3S-16 Common Well Name: 3S-16 Event Name ROT DRILLING Report #: Start: 1 1/25/2003 Spud Date: Report Date: End: 1/26/2003 1/29/2003 2/1 0/2003 ') ) Printed: 3/11/2003 4:03:26 PM running 9 5/8" casing wi Float Shoe, 2 Jts of 9 5/8· Float Float Equip, Thread Locked Btm 3 Conn, Ran 62 Jts of 9 5/8· 64 Jts Ran 2558.90') TIH with No Problems, Circ 50 bbls @ 670'. Continue RIH, Landed Csg in Head - Landed Csg Collar, Tested Csg, (Total of @ 3bpm I 240 psi wi FS @ 2558.90' 08:00 08:30 02:30 05:00 08:30 3:30 05:00 08:00 0.50 5.00 2.50 3.00 CASE P CASE P DRILL P CASE P SFTY RUNC TRIP RURD SURFAC PJSM on SURFAC MU 95/8· loor. SURFAC RU to run 95/8·, 40#/ft, L-80 BTC surf casing. RU casing equip, change bales to long bales, RU Frank's fillup tool. Rig up stabbing board stabbing board. 40# L-80 BTC Csg, rig crew and casing crew. drag data. SURFAC Reset bend on motor, UD stab, clear rig 00:00 02:30 2.50 DRILL P TRIP SURFAC Monitor well. POOH f/1200' to 0'. Slight overpull @ 1112',1042', and 1027' work through, OK. Continue POOH. SLM (no correction). Record torque and Drill Pipe Hyd Jars Drill Pipe Bit Mud Motor Float Sub Stabilizer Drill Collar - MWD HOS UBHO Stabilizer Crossover Flex Collar - Heavy Wgt Non Mag Heavy Wgt Hang Off Jt 1 1 3 9 1 14 1 1 1 1 1 .00 29.44 2.48 5.08 30.83 5.76 2.90 5.66 2.77 89.88 272.23 30.14 422.20 2.250 8.000 7.875 8.125 7.750 8.125 8.060 8.000 7.750 6.437 5.000 6.375 5.000 4.000 5.250 2.813 2.875 2.813 3.313 2.813 3.000 2.750 2.813 3.000 2.250 3.000 LAST CASING 6.000 (in) 108.0 (ft) NEXT CASING 9.625 (in) @ 2,566.0 (ft) LAST SURVEY: DATE 1/27/2003 24 HR FORECAST N/D diverter, NU LITHOLOGY TMD 2,502.92 135/8" BOP stack, test, PU BHA # 2, RIH, I JAR HRS OF SERVICE I BHA HRS SINCE INSP INC 0.780 AZIM 14.500 @ DAILY INT WIO MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 1/28/2003 342,424 LEAKOFF AFE 0027968 RU to test 13 5/8" BOPE 3S-16 SUPERVISOR I RIG NAME & NO. Dave Burley/Granville Riz n1268@conocop CURRENT STATUS Nabors 7ES JOB NUMBER I EVENT CODE 124 HRS PROG ODR FIELD NAME I OCS NO. Kuparuk River ACCIDENTS LAST 24 HRS.? TMD 2,570.0 AUTH MD TVD 2,569.0 DAILY TANG 0.00 LAST BOP PRES TEST CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 626,373 AUTH. WELL NAME ) ) DFS 2.75 REPT NO. 4 DATE 1/28/2003 ) ) WELL NAME 3S-16 I I 2,569.0 2.75 4 1/28/2003 ~~ 08:30 13:30 5.00 CASE P RUNC SURFAC FC @ 2469.36'. Ran 14 Bow Spring Centralizers Per Well Program 13:30 14:15 0.75 CEMENT P PULD SURFAC Remove fillup tool. Blow down mud line. MU Dowell cement head. 14:15 17:45 3.50 CEMENT P CIRC SURFAC Establish circ @ 1.75 bpm wi 321 psi. Stage pumps up to 8 bpm wi 563 psi and condition mud. Reduced FV f/240 to 54. PV f/38 to 19. YP fl 64 to 16. Gels 60/110 to 8/11. Maintain MW @ 9.2 ppg. Total volume pumped 1320 bbls, last 100 bbls wI nutplug marker. Reciprocated pipe wi full returns throughout. Final rate 8 bpm/515 psi. PUW 125K SOW 125K. PJSM. 17:45 20:00 2.25 CEMENT P PUMP SURFAC Line up to cementers, pumped 5 bbls of CW 100, tested lines to 3500 psi. Pumped additional 45 bbls of CW 100 - dropped bottom plug. Pumped 45 bbls of 10.5 ppg Mud PUSH XL with die marker - 336 bbls of 10.7 ppg AS Lite lead cement followed with 96 bbls of 12.0 ppg LiteCRETE tail slurry. 20:00 20:45 0.75 CEMENT P DISP SURFAC Drop top plug -Cementers pumped 20 bbls of of FW - switched to rig pumps and displaced with 115 bbls of mud @ 7.0 bpm 1400 - 600 psi, 25 bbls @ 5 bpm 1570 psi, last 27 bbls @ 4 bpm 450-500 psi (167 bbls total mud) bumped plugs to 1000 psi, floats held. Reciprocated pipe untilllast 27 bbls of displacement PUW 110K SOW 95K, had full returns with 203 bbls of 10.7 ppg cement returns to surface, CIP @ 2030 hrs. 20:45 22:00 1.25 CASE P RURD SURFAC LD cement head - flush surface stack and flowline. Flutes on hanger were partially plugged. Blow down cement line. 22:00 23:30 1.50 CASE P RURD SURFAC LD landing jnt. LD casing elevators and long bails - remove tools from rig floor. Hang short (drilling) bails on Top Drive. Rig down stabbing board. 23:30 00:00 0.50 WELCTL P NUND SURFAC Remove riser, then drop 20" extension to set riser off to side. 24 HR SUMMARY: Con't POOH f/1200' to 200' (SLM-no corr), UD BHA, RU to run csg, Run 64 jts 9 5/8" 40#/ft L-80 BTC, MU cmt head, circ & cond prior to cement, cement csg, bump plugs to 1000 psi, check floats, flush stack, N/D diverter system. ConocoPhillips 2 Sperry Sun 3 Nabors 37 Baroid 2 Doyon Universal 5 APC 2 MATERIALSICONSUMPTION JNITS USAGE ON HAND ITEM JNI'n gals 1,651 Fuel gals gals 4,580 15,390 Water, Drilling bbls RESERVOIR AND INTERVAL DATA RESERVOIR NAME ZONE TOP BASE COMMENTS 3S-18 3S-15 310 3 775 G&I 38-15 0 0 R-18 38-15 295 0 Printed: 3/11/2003 4:03:26 PM PRESSURE INTEGRITY TEST PHilLIPS Alaska, Inc. Nabors 7ES Date: 1/29/2003 I VOlume,lnput Volume/Stroke I Pump used: I #2 Mud Pump ... St k i ~ 0 0698! Bbl/S k I, ~ I - - - ro es i.... . I S tr ; .... ... Pumping down I annulus and DP. II'" i Cas'lng Test i Pressure Integrity Test I Hole Depth -. Pumping Shut-in Pumping Shut-in 2,590 Ft-MD 2,589 Ft-TVD Strks psi Min psi Strks psi Min psi ...\ 0 0 0 2535 0 0 0 1185 2 120 1 2535 1 ('~\ 86 0.25 1165 4 250 2 2535 2\(f~183 0.5 1145 6 390 3 2535 3 'h~ 286 1 1085 8 540 4 2535 4 ~370 1.5 985 10 700 5 2530 5~~ 485 2 875 12 860 6 2530 6d-¿ 579 2.5 800 14 1000 7 2530 7 r}-J 664 3 725 'Þ ,;' 16 1135 8 2525 8 c~752 3.5 675 18 1280 9 2525 9 -r~ 805 4 640 20 1425 10 2520 1 0 ~-:; 858 4.5 620 22 1560 15 2510 11Š-~ 911 5 600 24 1720 20 2510 12 C;; 965 5.5 580 26 1875 25 2505 13'rill014 6 550 28 2050 30 2495 14 t~1071 6.5 530 30 2220 15;..,1135 7 520 32 2380 16,;,..0'1192 7.5 510 34 2535 8 510 8.5 505 9 500 9.5 495 10 490 Well Name: 3S-16 I Rig: Drilling Supervisor: Burley 1 Rizek Type of T est: I Casing Shoe Test LOTI FIT Hole Size: 8-1/2" ... RKB-CHF: 26.6 Ft Casinç¡ Size and Description: Casina Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: Blocksrrop Drive Weight: Estimates for Test: Casing Shoe Depth 2,559 Ft-MD 2,558 Ft-TVD 9-5/8" 40#/Ft L-80 BTC Pressure Inteç¡ritvTest Mud Weight: 9.2 ppg Mud 10 min Gel: 7.0 Lb/100 Ft2 Rotating Weight: 100,000 Lbs Blocksrrop Drive Weight: 26 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 1171 psi 9.2 ppg 35.0 Lb/100 Ft2 2,500 psi 97,000 Lbs 26 Lbs 1.5 bbls 0.7 bbls r~1 ...1 EMW = Leak-off Pressure + Mud Weight = 1192 0.052 x TVD 0.052 x 2558 + 9.2 EMW at 2559 Ft-MD (2558 Ft- TVD) = 18.2 ppg PIT 15 Second Shut-in Pressure, psi 1165 3000· - Lost 40 psi during test, held ::: 98.4% of test pressure. 2500 - ",....w.. .~ L.1J et:: :::> en en L.1J et:: a.. o 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point 500 Barrels ~CASING TEST __LEAK-OFF TEST Comments: Changed well over to 9.2 ppg new LSND mud prior to FIT. Volume Bled Back _~bIS Pump Rate: 8.0 Strk/min !.... I -~ ~ Vo ume Bled Back ~bls Sup ervis or: Dave Burley / Granville Rizek Remarks: Up Wt = 150K MU Torque 7,200 ft/lb On Wt = 135K Block Wt= 30K Use "Run-N-Seal" pipe dope Drifted to 6.151 Total of 160 jts.on location Total of 151 jts in pipe shed Jts 141-151 stay out (last 11 jts Total CentralizHrs 1- 1" Bow cent.! stop rings 15' above FS Jt Bowspring centralizer over collar on jointH 7" x 8-3/8" Centering guide on jts.#81 thru #85 7" x 8-3/8" Centering guide on Jt. #'s 129, 132, Totals: 19 Bowspring, 9 centering guides, 135,138. (Total of 4) 2 Stop collars # & 8' below FC on #3 thru #19 ~T otal of 5) t #2 Casing Landed on Emergency Slips 7" Shoe @ 5907' MD 5839' TVD TD of 8-1/2 hole @ 5907' M D 58391 TVD Jts Jts 140 to 140 Jts 3 to 139 to 2 2 Jts Jts 37 Jts 7" 26# L-80 BTCM Csg 7" Weatherford Sure-Seal Model 303 Float Shoe NABORS 7ES RKB 7" 26# L-80 BTCM Csg 7" 26# L-80 BTCM Csg 7" Weatherford Sure-Seal to LDS Oa=42.991 Model 402 Float (cut off 35.01') Collar 26.56 7.98 5788.86 1.30 80.82 .48 26.56 34.54 5823.40 5824.70 5905.52 5907.00 Jt ConocoPhillips Alaska Nu mber Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN ì ) Casing Detai 7" Intermediate Casina Top Set running order ) LENGTH Wel Date: DEPTH TOPS 38-16 02/02/03 Legal Well Name: 38-16 Common Well Name: 38-16 Event Name: ROT - DRILLING Report #: 8tart: 2 1/25/2003 Spud Date: 1/26/2003 Report Date: 2/2/2003 End: 2/10/2003 String Type: Intermediate Casing/Liner Permanent Datum: Hole Size: Hole TMD: 5,907.0 (ft) Hole TVD: 5,839.0 (ft) KB-Datum: 0.00 (ft) Water TMD: (ft) Str Wt on Slips: 190 (Ibs) Ground Level: (ft) CF Elevation: (ft) Liner Overlap: (ft) Max Hole Angle: 16.19 (0) Circ Hours: 7.50 (hr) Mud Lost: (bbl) KB to Cutoff: 26.56 (ft) Days From Spud: 7.75 (days) -/ Manufacturer: Hanger Model: FMC Set on slips Model: Gen V Packoff Model: A-75 Top Hub/Flange: (in) 15,000 (psi) BTM Hub/Flange: (in) I 5,000 (psi) Actual TMD Set: 5,907.00 (ft) Item Size (in.) Casing 7.000 26.00 L-80 6.151 BTC-MOD 1 7.98 26.56 N FMC \lEW 7.000 6.276 7" 26# L-80 Cas Casing 7.000 26.00 L-80 6.151 BTC-MOD 137 5,788.86 34.54 Y \lEW 7.000 6.276 7" 26# L-80 Cas Float Collar 7.000 26.00 L-80 6.150 BTC-MOD 1.30 5,823.40 Y Weatherford 402 'JEW 7.000 6.276 Float Collar Casing 7.000 26.00 L-80 6.151 BTC-MOD 2 80.82 5,824.70 Y \JEW 7.000 6.276 7" 26# L-80 Cas Float Shoe 7.000 26.00 L-80 6.151 BTC-MOD 1.48 5,905.52 Y Weatherford 303 \lEW 7.000 6.276 Float Shoe 5,907.00 ~ Accessory Bowspring Centralizer Bowspring Centralizer Bowspring Centralizer Centering Guides Centering Guides WEATHERFORD WEATHERFORD WEATHERFORD RAY OIL TOOLS RAY OIL TOOLS 1 1 17 5 4 5,888.2 5,814.7 5,150.8 2,356.5 115.1 5,890.2 Stop Ring 5,816.7 Stop Ring 5,823.4 OverCollar 2,525.8 Slid On 492.1 Slid On Printed: 3/11/2003 4:09: 14 PM Legal Well Name: 3S-16 Common Well Name: 3S-16 Event Name: ROT - DRILLING Report #: Start: 2 1/25/2003 Spud Date: 1/26/2003 Report Date: 2/2/2003 End: 2/10/2003 Average MU torque first 10 joints = 7200 ft-Ibs Thread locked shoe track [3 jts] Used Jet Lube Run -N- Seal pipe dope Ion Curphey FMC Tec Rep ~-~ Operational Detail: RU GBR Casers and Fill-up Tool. Held Safety Mtg on Running of 7· Csg Run Weatherford 7· model 303 float shoe, 2 joints 7· 26 #/ft L-80 BTC-mod casing, Weatherford model 402 float collar on Jnt #3, Circ to check floats, ok. Run 7· 26 ppf L-80 BTC-mod casing to 2529'. Circulate and condition mud and hole @ 2529'. Continue to run 7" 26 ppf L-80 BTC-mod casing to 4655' (110 joints in hole) Circulate and condition mud and hole @ 4655'. Stage up f/ 1.3 bpm @ 635 psi, final press 612 psi wi 5.7 bpm, volume pumped 176 bbls. SO weight increased f/107k to 120k. PU wt stayed the same. Continue to run 7· 26 ppf L-80 BTC-mod casing to 5872' (139 joints in hole) PU joint 140. Break circ and stage up to 5.0 bpm wi 750 psi. Wash to TO (5907') no problems. _/ Printed: 3/11/2003 4:09:14 PM Printed: 3/11/2003 4:10:02 PM Test Data Thickening Time: Free Water: Fluid Loss: Fluid Loss Pressure: (%) (cc) OF) Temperature: Temperature: Temperature: OF) OF) OF) Compressive Strength Compressive Strength 2: Temp OF) OF) Pressure (psi) (psi) Interval: Water Source: Slurry FLUSH 3,834.00 (ftJfo: Description: 3,242.00 (ft) Cmt Vol: Slurry Vol: CW 100 (bbl) (sk) Time Density: 8.30 (ppg) Water Vol: 20.0 (bbl) Class: Yield: (ft3/sk) Other Vol:20 l) Purpose: SPACER Mix Water: Foam Job: (gal) N Slurry Data Fluid Type: Type: 11.8 Bottom Hole Circulating Temperature: Displacement Fluid Type:Mud PVNP: 21 Density: 11 (cp)/24 (lb/100ft2) Gels 10 sec: 11 (lb/100ft2) Bottom Hole Static Temperature: (OF) Volume: 223.00 (bbl) .8 (ppg) Non-Disp. LS Density: (ppg) Visc: 48 (s/qt) OF) Gels Omin: 16 Ib/100ft2) To Cementing: 3.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 850 (psi) Top Plug: Bottom Plug: Meas. From: 0 Time Circ Prior End Pumping: End Pump Date: Start Mix Cmt: Start Slurry Displ: Start Displ: 12:15 13:05 13:16 14:10 2/2/2003 Y Y Press Held: Float Held: Y 630 (psi) 1,120 (psi) 3 (min) Y Ann Flow After: N Mixing Method: Batch Density Meas By: Press scal Press Bumped: Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Returns: 100 Total Mud Lost: Cmt Vol to Surf: (bbl) (bbl) Type: Cement Casing Volume Excess %: 75.00 6.50 (bbl/min) 7.00 (bbl/min) Rot Time Start: Rec Time Start:09:30 Time End: Time End: 14:05 RPM: SPM: Init Torque: Stroke Length: ,ft-Ibf) 20.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 500bs) Max Torque: (ft-Ibf) Drag Down: 135 (Ibs) Cement Co: Dowell Schlumberger Cementer: Rick Gallegos Pipe Movement: Reciprocating Cmtd. Csg: OPEN HOLE Cmtd. Csg: Csg Type: sa TMD: sa Date: Cmtd. Csg: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Csg Type: Intermediate Casing/Li Csg Size: 7.000 (in.) Hole Size: TMD Set: Date Set: 8.500 (in) 5,907 (ft) 2/2/2003 Hole Size: sa TMD: sa Date: sa Type: Hole Size: TMD Set: Date Set: Hole Size: Top Set: BTM set: ft ft (ft) Legal Well Name: 3S-16 Common Well Name: 3S-16 Event Name: ROT DRILLING Report #: Start: 2 1/25/2003 Spud Date: Report Date: End: 1/26/2003 2/3/2003 2/10/2003 ) ) 2.00 G P S 0.02 G P S Printed: 3/11/2003 4:10:02 PM D65 B155 D600 D47 0.30 %BWOC 0.02 %BWOC %m jj ji!!1! ......... Test Data Thickening Time: Free Water: Fluid Loss: Fluid Loss Pressure: (%) (cc) OF) Temperature: Temperature: Temperature: OF) OF) OF) Compressive Strength Compressive Strength 2: Temp (OF) (OF) TAIL Slurry nterval: 5,907.00 (ft}To: Water Source: 5,017.00 f Description: Cmt Vol: 38.4 (bbl) Slurry Vol:186 (sk) Time Class: G Density: 15.80 (ppg) Yield: 1.16 (ft31sk) Water Vol: 22.6 (bbl) Other Vol: 0 Slurry Data Fluid Type: Test Data Thickening Time: Free Water: Loss: Loss Pressure: Fluid Fluid (%) (cc) OF) Temperature: Temperature: Temperature: OF) OF) OF) Compressive Strength Compressive Strength 2: Temp (OF) (OF) FLUSH Slurry Interval: 5,017.00 Water Source: ft}To: Description: 3,834.00 (ft) Cmt Vol: Slurry Vol: MUDPUSH XL (bbl) (sk) Density: Water Vol: Time 2.80 (ppg) (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 5.10 (gal) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: Legal Well Name: 38-16 Common Well Name: 38-16 Event Name: ROT DRILLING Report #: Start: 2 1/25/2003 Spud Date: 1/26/2003 Report Date: 2/3/2003 End: 2/10/2003 ) ) Pumped 40 bbls of 12.8 ppg MudPush XL, dropped 2nd btm plug- displaced 20 bbls of FW - switched to rig pumps and displaced with last last 8 bbls pumped final pressure 630 psi, bumped plugs to 1160 psi pumped 38.4 bbls of 15.8 ppg G wi adds 82.5 of 11.8 ppg mud @ 7.0 bpm 1588 - floats held - full returns throughout - Printed: drop top plug - cementers 805 psi slowed to 4 bpm CIP @ 1410 hrs. 3/11/2003 4:10:02 PM Line up to cementers - pumped 5 bbls of FW and tested lines to 3500 psi. Pumped 20 bbls of CW head wI 2nd btm & top plugs. Established circ @ 3.0 bpm confirm bottom. Circ & cond mud maintained 11.8 ppg mud wt in. 100, dropped btm plug staged pumps up to 5.0 bpm I 750 psi. washed down from 5872' to 5907', set down with 5k to 96 units gas @ bottoms up Lowered YP from 34 to 24, FV from 55 to 48, Gels from 15/20 to 11/1 Reciproceted pipe with full returns throughout - final rate 7.0 bpm 1858 psi. PJSM - reload cmt 620 psi, 6, Temp Survey: Hrs Prior to Log: Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Bond Quality: CBL Run: Under Pressure: Bond Quality: Cet Run: Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful (psi) ft) Test For: Cement Found between Shoe and Collar: Pressure: Tool: Open Hole: ft Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Press: (psi) (min) (ppge) Legal Well Name: 3S-1 Common Well Name: 3S-1 Event Name: ROT DRILLING Report #: Start: 2 1/25/2003 Spud Date: Report Date: End: 1/26/2003 2/3/2003 2/1 0/2003 6 6 ) ) Printed: 24 HR SUMMARY: Run 7' csg, circ, cement, PU BOP stack, set FMC emerg slips wi 190k on ind, dress cutoff, install & test packoff to 4300 psi, tighten stack, change top rams to 4", prep TD & iron rough f/4", RU to test BOPE 3/11/2003 4:05:32 PM 23:00 23:45 23:45 00:00 0.75 0.25 WELCTL X RIGMNT N:EQIP BOPE RGRP NTRM1 NTRM1 9:30 20:30 20:30 23:00 .00 2.50 WELCTL X DRILL X OTHR OTHR INTRM1 INTRM1 PJSM. Chann" ~"n n:n" Set 13 5/8" and tighten Jack on well. ""," '"I''' 1""1"''' rams to 4". Pick up in cellar. Change out bales to drilling bales. Change top drive over to 4" Change out iron roughneck jaws to smaller size fl 4" drill pipe. RU to test 135/8" 5m BOPE. Repair electrical switch on iron roughneck. from 5" 8:00 7:00 7:30 19:30 17:30 18:00 .50 0.50 0.50 WELCTL X WELCTL P WELCTL P NUND OTHR OTHR NTRM1 INTRM1 NTRM1 Tighten bolts on of way. Final cut and dress 7" nstall FMC packoff f/7". RILDS. Test min. OK. 11 fl packoff. packoff to 4300 psi 5m spool. Install (80% of burst) f/ riser o 16:00 4:30 5:00 17:00 15:00 16:00 .00 0.50 .00 WELCTL P CEMENT P WELCTL P OTHR RURD NUND NTRM1 NTRM1 NTRM1 Cut and tubing spool remove cutoff fl 7" casing joint # 3:00 3:30 13:30 14:30 0.50 .00 CEMENT P CEMENT P PUMP DISP NTRM1 NTRM1 11:00 11:30 11:30 13:00 0.50 .50 CEMENT P CEMENT P RURD CIRC NTRM1 INTRM1 08:00 09:30 09:30 11:00 .50 .50 CASE P CASE P RUNC CIRC NTRM1 NTRM1 press) @ 2902 strokes. RID cement equipment. to 120k. PU Continue to ,~ PU joint 140. L.. circ bottoms up, packing off. Rig down Frank's Circulate and condition cement job. Circ final Cement per plan. Rig displace @ 7 bpm wi 805 psi Bump plugs wi 60 psi(500 over circ floats. OK. @ 7 bpm wi 845 psi. fillup tool. RU Dowell cementing head. fl cement job, circ total of 7000 strokes prior to 11 CIP @ 1410 hrs. Bleed off press. Check Blow down lines. Clear tools f/ floor. Remove turnbuckles f/13 5/8" BOP stack. Split 31/2" spool. PU BOP stack. Set FMC emergency slips wi 190K on indicator. 140. Move stack out (1 "",reak circ and stage up to 70 spm wi 750 psi. Wash to TD. After No fill was encountered. No stage up to 85 spm w/715 psi. stayed the same. ~'In 7" 26 ppf L-80 BTC-mod casing to 5872' Continue to run 7" 26 ppf L-80 BTC-mod casing to 4655' (110 joints in hole) Circulate and condition mud and hole @ 4655'. Circ 2527 strokes. Stage up f/ 19 spm @ 635 psi, final press 612 psi wi 82 spm. SO weight increased f/1 07k 39 joints in hole) 00:00 03:00 03:00 03:30 03:30 07:00 07:00 08:00 3.00 0.50 3.50 .00 CASE P CASE P CASE P CASE P RUNC CIRC RUNC CIRC NTRM1 INTRM1 INTRM1 NTRM1 Run 7" Circulate and condition mud and hole @ 2529' 26 ppf L-80 BTC-mod casing to 2529' LAST CASING 9.625 (in) 2,558.9 (ft) NEXT CASING 7.000 (in) @ 6,237.0 (ft) Testing 135/8" 24 HR FORECAST Fin RU Itest BOPE, install FMC wb, PU/MU 61/8", PU 4" DP LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP INC 8.510 LAST SURVEY: 1/31/2003 DATE TMD 5,786.82 AZIM 220.720 @ 2/2/2003 LEAKOFF 18.1 7 0027968 LAST BOP PRES TEST 1/29/2003 AFE DAILY INT WIO MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 293,916 AUTH. 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD ,408,784 BOPE. Witness waived by AOGCC ins pee Chuck 3S-16 SUPERVISOR I RIG NAME & NO. Dave Burley/Granville Riz n1268@conocop CURRENT STATUS Nabors 7ES JOB NUMBER I EVENT CODE 124 HRS PROG ODR FIELD NAME I OCS NO. Kuparuk River ACCIDENTS LAST 24 HRS.? TMD 5,907.0 AUTH MD TVD I DFS 5,839.0 7.75 DAILY TANG 0.00 REPT NO. I DATE 9 2/2/2003 CUM. TANG WELL NAME ) ) ) ) WELL. NAME I JOB NUMBER IEVE~DC~DE 124 HRS PROG ITMD IDFS REPT NO. DATE 38-16 5,907.0 5,839.0 7.75 9 2/2/2003 ~N ConocoPhillips 2 Baroid 2 Nabors 27 APC 2 Doyon Universal 5 BHI 1 8perry 8un 3 It!: Fuel (camp) gals 1,651 Fuel gals 2,146 10,893 Water, Potable gals 4,480 0,440 Water, Drilling bbls 365 793 38-18 38-15 596 2.1 750 G&I 38-15 0 0 R-18 38-15 0 0 Printed: 3/11/2003 4:05:32 PM Voume Bled Back -üals Pressure Integrity Test Pumping Shut-in Strks psi Min psi o 0 0 300 4 ~~' 66 0.25 280 8 ~~145 0.5 260 12 \\ù 255 1 250 16 \Y:G396 1.5 250 20 \Ceo 576 2 245 24 332 2.5 240 28 291 3 240 32 302 3.5 240 36 311 4 240 40 328 4.5 240 44 333 5 235 48 341 5.5 235 52 337 6 230 56 337 6.5 225 60 332 7 225 64 330 7.5 225 . 8 225 8.5 225 9 220 9.5 220 10 220 ... Pump Rate: 8.0 Strk/min ... Casing Test Pumping Shut-in Strks I psi Min Volume L Bled Back üals Volume/Stroke o 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Strokes :... 0.0698 ! I Volume Input ! 5 0 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point o 1 234 USE LIST ~CASING TEST ~LEAK-OFF TEST 95/8 shoe FIT=18.2 ppg Comments: ,^l 0/1 LLJ ex: ::J (J) f~ (J) . LLJ ex: a.. . '. . . . . . 500· 1000· PIT 15 Second Shut-in Pressure, psi 280 ~ ..L EMW = Leak-off Pressure + Mud Weight = 576 + 11 8 0.052 x TVD 0.052 x 2558 . EMW at 2559 Ft-MD (2558 Ft-TVD) = 16.1 ¡ ,. 16.1 ppg 572 psi Desired PIT EMW: Estimates for Test: -0.1 bbls PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Well Name: 3S-16 I Rig: Nabors 7ES I Date: 2/3/2003 Drilling Supervisor: Burley / Rizek I Pump used: ] #2 Mud Pump I. Type of Test: I Annulus Leak Off Test for Disposal Adequacy j ...1 Pumping down I annulus. ! ... Hole Size: i 8-1/2" ¡ · Casing Shoe Depth I Hole Depth RKB-CHF: 26.6 Ft 2,559 Ft-MD 2,558 Ft-TVD 5,017 Ft-MD 4,965 Ft-TVD Casina Size and Description: I USE PICK LIST 1·1 Chanaes for Annular Adequacy Test Pressure IntearityTest Enter outer casing shoe test results in comments Mud Weight: 11.8 ppg ~ Casing Description references outer casing string. Inner casing aD: 7.0 In. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. Interpolation Method:MD Depth Range From: 2SS8.00 Maximum Range: 812.10 Interval: 1.00 To: 2SS9.00 Reference: Definitive Survey P~~~Inc. ~ WfllP ATIf DErAIlS 3S,16 501032<»4500 lVEIL DErAIlS ~3:IIY_ +Sf,S +EJ·IV K<>nhing Eastin¡! Uaitud< t.ongilUd<. Slot 3S,16 43.53 ·305.74 5993881.49 476149.43 70'23'39.9-I8¡'; 15O'11'38.600W Sf A ANTI-COLLISION SETTINGS COMP Æ"" DErAILS o CakuJation M<ù1o<!: Minitrnm Curvature ~:~~ ~~~~Pbno FIror Surface.: Elliptical + ~Ìng W:mùIJg Memo<!: Ruks Bssoo Rig: Ref. Datum: V.S«:bon Ang< 229,00" N7ES 3S-16 : 56.67ft ~1 ~ 0.00 0.00 S tarlÍng From TVD 0.00 -1320 -1240 lJ2(J From Colour ToMD 0 200 200 400 400 600 600 800 800 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 2500 2500 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 8000 8000 9000 9000 11000 - -413 1240 -1033 -827 ---D20 ---620 \ \ \ \ \ %~ 20~/ ('<M/~ 3.~~~....2..6.(. 3...S...-.1._...6...)....\..,..,8. .........'. .... ..)..0.·.........·..<..·.......'.· .........,.............,.......'..' ............ 3\(3S-26A).~ ...... _07 90 -207 -0 270 -207 -413 ì -827 -1033 -1240 -1320 124U 1/4 Mile Radius of 35-16 ... 9-5/8" CsgPt (@ 2558'MD /2558' TVD) 180 hw Reference Azimuth Angle [deg] vs Centre to Centre Separation [ft] Geological Information This well lies within the Palm development area, which is located within the western margin of the Kuparuk River Unit as defined by the Eighth Expansion of the Unit Area approved by the Division of Oil and Gas on September 26, 2002. The Palm development area is also situated within the boundary of the Kuparuk River Unit aquifer exemption issued by the EPA. On the injectivity test, the pressure builds steadily to 575 psi when it sharply breaks and a stabilized injection pressure was developed at about 325 psi. After pumping was stopped, a 50 psi drop was recorded after 1 minute with a stabilized pressure of between 240 and 230 psi being reached by the end of 5 minutes and holding for the remainder of the observation period. The pressure plots for 3S-16 are similar to those presented for the other wèlls, although the pump in pressure is lowest of any of the wells analyzed to date. The casing was successfully pressure tested prior to drillout. When tested, the formation did not leak off at about 18.2 ppg EMW. During the 10-minute observation period, the pressure dropped about 190 psi. The well was drilled into the Kuparuk reservoir and the 7" casing string was set and cemented Well 35-16 Information In the case of 3S-16, it is noted that over 200 bbls of cement were circulated. Based on spreadsheet calculations, gauge plus 60% XS cement was left in the well. It is indicated that the surface casing is adequately cemented. Offset Well Information The supplied information indicates the closest well to 3S-16 is 3S-26 with about 150' of separation at the shoe. The next nearest wells are 3S-07 and 3S-14 about 1000' distant. 3S-18 is approximately 1150' distant. 3S-07 and 3S-18 have been approved for annular disposal. The casing and cementing reports for all the wells are provided It is indicated that in each case the casings were successfully run and cemented Operational History 3S-16 is 5th development well on Drill Site 3S. This drill site is developing the Palm discovery. In the documents submitted, information from 4 wells that are within % mile is provided. Three wells were drilled since November 2002. The 4th well is the original Palm discovery well, since renamed 3S-26, which was drilled in February 2001. Summary ConocoPhillips (ConPPCo) has requested approval for annular disposal on the subject well. This is the 3rd well on Drill Site 3S that ConPPCo has sought approval for annular disposal. They have submitted the required information. This document analyzes the information and recommends approving their request. Request for Annular Disposal Approval ) 35-16...203-007...303-085 NOTE TO FILE ) Recommendation Based on the presented information, we recommend annular disposal in 3S-16 (203-007) be approved. fr~~~ Tom Maunder, PE Sr. Petroleum Engineer Steve Davies Petroleum Geologist I \C\-o ~~ \... that ConocoPhillips' request Æ:t~ for In well 3S-16, the base of the permafrost lies at approximately 1,550' MD and TVD, and the West Sak Sands lie between approximately 2,000' and 2,460' MD and TVD. The 9- 5/8 inch casing shoe is set in the Colville Shale at 2,559' MD, about 100' below the base of the West Sak Sands. In the nearby Palm #1 exploratory well (renamed 3S-26), the Colville Shale is several thousand feet thick, and is composed of very soft to moderately firm claystone, mudstone and siltstone, with minor sand and rare conglomerate. In the Geologic Considerations section of Note to File for well 3S-07, Bob Crandall notes that this disposal interval has low mechanical strength, and that the sands are minor, low permeability, low in volume, and frequently hydrocarbon-bearing. He also notes that the Colville Shale has a long track record of successfully receiving annular disposal in the Alpine, Meltwater, Tarn and Kuparuk River Unit areas. ) ) Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well Job# Log Description Date 3S-15 ~m.~5,: 3S-16ao3,007 23085 23084 SCMT SCMT 02123/03 02123/03 5IG~~~ ~ DATE: NO. 2694 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 1 1 -1\I"-D RECtJ vC·· -....".... ".^,\~ /1 ( ',It!",:) I'HM... v. £..... V Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. AI . C,:,} C! !~-~.~ i~'~~ ('-'\~~~~~!1 ua~s. ":1 & \;~'" ..1_1.-. \~4¿.'.""4""'"" t~¡:h~a 03/06/03 ...- --~/ c [: I__J_ RT/skad CP AI Drilling Kuparuk Drilling Team Leader \~ R. Thomas Sincerely, If you have any questions Scott Lowry at 265-6869 l ~ regarding ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations for the Kuparuk well 3S-16. this matter, please contact me at 265-6830 or Dear Subject: Commissioner: Well Completion Report for 3S-16 (APD # 203-007 / 303-034) Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 March 4. 2003 ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ) ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells Form 0-407 Rev. 7-1-80 RBOMS BFl c.,ç CQNTINUE;D'ON REVERSE SIDg 1/~R 2 r'I''-''(''¡') I Submit in duplicate N/A pressure 28. Brief description of lithology, porosity, CORE DATA ractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Flow Tubing psi Production for Test Period> Calculated 24-Hour Rate> 27. Date First Casing Pressure Injection February 25, 2003 Date of Test Hours Tested OIL-BBL Method of Operation PRODUCTION TEST (Flowing, gas ift, etc.) Injector OIL-BBL GAS-MCF GAS-MCF W A TER-BBL WATER-BBL OIL GRAVITY CHOKE SIZE IGAS-OIL RATIO API (corr) N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5915' 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 5934' MD 5847' 5866' TVD 6spf 26. 25. SIZE 3.5" TUBING RECORD DEPTH SET (MD) 5735' PACKER SET (MD) N/A CASING SIZE 16" 9.625" 7" 3.5" WT. PER FT. 62.5# 40# 26# 9.3# L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP Surface Surface Surface 5717' BOTTOM 108' 2559' 5907' 6145' HOLE SIZE 42" 2.25" 8.5" 8.5" CEMENTING RECORD 30 sx Arctic Crete 440 sx AS IIIL, 240 sx LiteCrete 86 sx Class G 21 sx Class G GRADE B AMOUNT PULLED MD 16079' TVD 22. Type Electric or Other Logs Run GR/Res/Dens/Neut, CBL w/SCMT 23. 7. Total 6150' February 8,2003 ' 8. Plug Back Depth (MD + TVD) 6049' MD I 5980' TVD 9. Directional YES 0 Date Comp., ~~~ Or Aba~'l February~2003 ~ Survey 120. No 0 Land Nipple @ 530' Thickness of Permafrost 1546' MD January 26, 2003 Depth (MD + TVD) 115. Water N/A Depth where SSSV set 21 2. 5. I 2377' FSL, ,567' FEL, Sec. 18, T12N, R8E, UM (475693,5993514) Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 28 feet ADL 380107 ALK 4624 Date Spudded 3. Date T.D. Reached 4. Depth, Kuparuk River Oil Pool Kuparuk River Field If offshore feet MSL 6. No. of Completions 2528' FNL, 1110' FEL, Sec. At Top Producing Interval 2402' FSL, 1541' FEL, Sec. At Total Depth 8, T12N, R8E, UM 8, T12N, R8E, UM ConocoPhillips Alaska, Inc. Address P. O. Box 4. Location of 3. Oil 0 Gas 2. Name of Operator 00360, Anchorage, well at surface AK 99510-0360 Abandoned 0 :>.;'~':: ::::.<: ~ ~" (', ::~:~r:YÒ~~;~" ..,\.~ Di~T¡;I~ r ~Z_·~".,:l··()~K ;1 '1'¡~-r-:"r'I"''j1 ~ :,~ ""J~..â, 'i I ": I;, '.""".'.,'" "" ''''',j~,~~. '~"~;:t'~. .;('.'';'IP!'~;.'''1'i!I'I1.~~,;;!'¡' i" (475719,5993540) (ASP: 476149, 5993887) Kuparuk River o. Well Number 3S-16 Field and Pool 50-1 03-20445-00 Unit or Lease Name Unit ~ 9. MW AG injector 7. Permit Number 203-007 I 303-034 8. API Number 1. o WELL COMPLETION OR RECOMPLETION REPORT AND LOG Status of well Classification of Service Well Suspended o Service o STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION ') i Form 0-407 Item 28: tem 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. If no cores taken, indicate "none" Item 23: of the cementing tool. Attached supplemental records for this well should show the details of any multiple stage cementing and the location tem 21 Item 16 and 24: If this well is completed for separate production fro ~ item 16, and in item 24 show the producing intervals for the interval..... .....' L....' '. tem 27. additional interval to be separately produced, showing the data pertinent to such interval. Indicate whether from ground level (GL) or other elevation (DF, KS, etc.). "ðp^rtod in than one interval (multiple completion), so state in Submit a separate form for each tem 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. tem 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt supply for injection, observation, injection for in-situ combustion. water disposal, water 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. NSTRUCTIONS .... Signed \ R. ...J Thom1s Title Kuparuk Drilling Team Leader Date Prepared by Sharon Allsup-Drake 32. 31 Top C Sand Top A Sand <...~ - LIST OF ATTACHMENTS Summary of Daily Operations, hereby certify that the following is \~ Directional Survey rue and correct to 5914' 5932' ~ the best of my knowledge. 5846' 5864' ~/'1' /0 3 Questions? Call Scott Annulus left open Lowry 265-6869 - freeze protected with diesel. MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, aU fluids recovered and gravity. GOR, and time of each phase. 29. NAME GEOLOGIC MARKERS ) 30. ) FORMATION TESTS Printed: 2/24/2003 10:40:32 AM 1/27/2003 2:00 02:00 00:00 20:00 20:30 00:00 01 :00 - 02:00 01:00 20:30 00:00 13:00 12:00 .00 DRILL 10.00 DRILL DRILL 0.50 DRILL 3.50 DRILL .00 DRILL .00 DRILL DRLG DRLG OTHR SURFAC SURV DRLG DRLG SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC Gyro survey @ 265' wi HOWCO slickline and Sperry Sun. Drill 12 1/4" hole f/265' to 628'. (363') TVD = 628' ART = 2.25 hrs Drill wI 500 gpm(171 spm) @ 1487 psi, 80 rpm, mm 75 rpm, PU wt 58 k, SO wt 58 k, Rot wt 58 k, torque on bttm 3000 ft/lb, torque off bttm 1000 ft/lb Rotary table to (16" slip- on) lock downs = 29.60' Rotary table to ground level = 28.97' Drill 12 1/4" hole f/628' to 719'. (91') TVD = 719' ART =.5 hrs Drill wi 500 gpm(171 spm) @ 1490 psi, 80 rpm, mm 75 rpm, PU wt 60 k, SO wt 60 k, Rot wt 60 k, torque on bttm 3000 ft/lb, torque off bttm 1000 ft/lb Hi line tripped off line fl rig wi working pipe prior to connection. Reset equip breakers wI working pipe in down direction every so often. Drill 12 1/4" hole fl 719' to 1854'. (1135') TVD = 1854' ART =6.0 hrs AST = 1 hr Drill wi 25-30k WOB, 500 gpm(171 spm) @ 1490-1745 psi, 80 rpm, mm 75 rpm, PU wt 60-90 k, SO wt 60-90 k, Rot wt 60-90 k, torque on bttm 3000-4000 ft/lb, torque off bttm 1000-2000 ft/lb Drill 12 1/4" hole fl 1854' to 961 (1 07') TVD = 1961 AST = 0 hr ART =1 .0 hrs Blow down steam and water in pit Finish RID injection line. Move out injection skid Move out ball mill. Set down on pad. Move out mud pits. PJSM. Jack up sub and move off well 3S-1 cellar area. Blade pad around well 3S-16. Set mats around cellar area fl sub module. Grade pad location where rig will be setting fl well 3S-16. Spot tree and wellhead equipment in cellar area. Move & spot rig over well. Spot pit module, set mats, spot ball mill, lay herculite & mats. Put a load of water in pits @ 0400 hrs. Lay herculite, spot injection skid, generator and fuel tank fl injection skid. Spot all out buildings. Build berms around rig. Nipple up surface stack and diverter. Work 20" Annular, function test 16" knife valve. Install 4 joints total of 16" diverter line. Secure line. Function test diverter system wI AOGCC rep Jeff Jones. Tested gas detectors, function PVT system . RU HOWCO WL unit fl gyro surveys. MU stand of DC's. Stand back in derrick. MU BHA # 1. Fill stack, check f/leaks. Test mud line to 3500 psi. Drill 12 1/4" hole f/1 08' to 265'. (157')TVD= 265' ART = 1.5 hrs . Drill wi 500 gpm(171 spm) @ 1148 psi, 80 rpm, mm 75 rpm, PU wt 43 k, SO wt 43 k, Rot wt 43 k, torque on bttm 2000 ft/lb, torque off bttm 1500 ftllb 1/26/2003 14:00 15:00 15:30 17:30 18:00 07:00 09:30 00:00 - 02:30 04:00 - 07:00 02:30 - 04:00 3:30 - 15:00 - 15:30 17:30 18:00 20:00 14:00 09:30 13:30 1.00 DRILL 0.50 DRILL 2.00 DRILL 0.50 DRILL 2.00 DRILL 2.50 4.00 .50 MOVE 3.00 MOVE 2.50 0.50 WELCTL BOPE SURFAC MOVE MOVE MOVE WELCTL NUND SURFAC MOVE OTHR OTHR OTHR OTHR DRLG MOVE MOVE RURD SURFAC SURFAC SURFAC SURFAC SURFAC MOVE MOVE MOVE 23:00 - 00:00 9:00 20:00 20:30 21:00 21:30 22:00 20:00 20:30 21:00 21:30 22:00 23:00 .00 1.00 MOVE 0.50 MOVE 0.50 MOVE 0.50 MOVE 0.50 MOVE 1.00 MOVE MOVE RURD RURD RURD RURD RURD RURD RURD MOVE MOVE MOVE MOVE MOVE MOVE MOVE 5. Remove 20" Annular fl 1/25/2003 module. Legal Well Name: 3S-16 Common Well Name: 3S-16 Event Name: ROT - DRILLING Contractor Name: n1268@conocophillips.com Rig Name: Nabors 7ES Start: 1/25/2003 Rig Release: 2/10/2003 Rig Number: Spud Date: 1/26/2003 End: 2/10/2003 Group: ) ;:) e ) 7:45 - 20:00 2.25 CEMENT PUMP SURFAC 20:00 - 20:45 0.75 CEMENT DISP SURFAC Printed: 2/24/2003 Line up to cementers, pumped 5 bbls of CW 100, tested lines to 3500 psi. Pumped additional 45 bbls of CW 100 - dropped bottom plug. Pumped 45 bbls of 10.5 ppg Mud PUSH XL with die marker - 336 bbls of 10.7 ppg AS Lite lead cement followed with 96 bbls of 12.0 ppg LiteCRETE tail slurry. Drop top plug -Cementers pumped 20 bbls of of FW - switched to rig pumps and displaced with 115 bbls of mud @ 7.0 bpm 1400 - 600 psi, 25 bbls @ 5 bpm I 570 psi, last 27 bbls @ 4 bpm 450-500 psi (167 bbls total mud) bumped plugs to 1000 psi, floats held. Reciprocated pipe 0:40:32 AM 02:30 - 05:00 2.50 DRILL TRIP SURFAC 05:00 - 08:00 3.00 CASE RURD SURFAC 08:00 - 08:30 0.50 CASE SFTY SURFAC 08:30 - 13:30 5.00 CASE RUNC SURFAC 13:30 - 14:15 0.75 CEMENT PULD SURFAC 14:15 - 17:45 3.50 CEMENTCIRC SURFAC ') Legal Well Name: 3S-16 Common Well Name: 3S-16 Event Name: ROT - DRILLING Contractor Name: n1268@conocophillips.com Rig Name: Nabors 7ES 1/27/2003 12:00 - 13:00 1.00 DRILL DRLG SURFAC 13:00 - 14:00 1.00 RIGMNT RGRP SURFAC 14:00 - 20:00 6.00 DRILL DRLG SURFAC 20:00 - 22:30 2.50 DRILL CIRC SURFAC 22:30 - 00:00 00:00 - 1/28/2003 00:00 - 02:30 2.50 DRILL DRILL .50 DRILL TRIP TRIP SURFAC SURFAC SURFAC (609') TVD = 2569' AST = 0 hr Drill w/30-45k WOB, 500-555 gpm(171-188 spm) @ 1917-2339 psi, 80 rpm, mm 75-83 rpm, PU wt 95 k, SO wt 92-94 k, Rot wt 95 k, torque on bttm 4000-6000 ftllb, torque off bttm 2000-3000 ftllb Circulate and condition mud and hole f/9 5/8" casing. Pump Hi Vis sweep, circ 3 x surf-surf if 13" hole (15,543 strokes @ 121 spm = 8.43 bpm) Maintain 9.2 ppg MW in, 150 FV in, MW out = 9.2 180 FV out Monitor well. POOH fl 2570' to 1200'. Stand # 4 @ 2260' & 2224' had 20k overpull. Work through, OK. SLM, record torque and drag data. Note: Slight overpull @ 1112', 1042' and 1027'. work out. Continue POOH fl csg. Monitor well. POOH f/1200' to 0'. Slight overpull @ 1112', 1042', and 1027', work through, OK. Continue POOH. SLM (no correction). Record torque and drag data. Reset bend on motor, UD stab, clear rig floor. RU to run 9 5/8", 40#/ft, L-80 BTC surf casing. RU casing equip, change bales to long bales, RU Frank's fillup tool. Rig up stabbing board stabbing board. PJSM on running 9 5/8" casing wi rig crew and casing crew. MU 95/8" Float Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 62 Jts of 9 5/8" Csg, (Total of 64 Jts Ran 2558.90') TIH with No Problems, Circ 50 bbls @ 3bpm 1240 psi @ 670', Continue RIH, Landed Csg in Head- Landed Csg wI FS @ 2558.90', FC @ 2469.36'. Ran 14 Bow Spring Centralizers Per Well Program Remove fillup tool. Blow down mud line. MU Dowell cement head. Establish circ @ 1.75 bpm wi 321 psi. Stage pumps up to 8 bpm wI 563 psi and condition mud. Reduced FV fl 240 to 54. PV fl 38 to 19. YP fl 64 to 16. Gels 60/110 to 8/11. Maintain MW @ 9.2 ppg. Total volume pumped 1320 bbls, last 100 bbls wI nutpJug marker. Reciprocated pipe wI full returns throughout. Final rate 8 bpml 515 psi. PUW 125K SOW 125K. PJSM Drill wI 5-30k WOB, 500 gpm(171 spm) @ 1643 psi, 80 rpm, mm 75 rpm, PU wt 90 k, SO wt 90 k, Rot wt 90 k, torque on bttm 3000-4000 ftllb, torque off bttm 1000-2000 ftllb Hole starting to load up and returns slowing down. Circ hole clean before connection. Lost shaker due to short on wiring at junction box. Repair shorted wiring. Drill 12 1/4" hole f/1961' to 2570' ART =4.0 hrs Start: 1/25/2003 Rig Release: 2/10/2003 Rig Number: Spud Date: 1/26/2003 End: 2/10/2003 Group: ') 1/30/2003 00:00 00:00 2:00 DRILL 2.00 DRILL DRLG SURFAC INTRM1 22:15 21 :00 - 22:15 9:15 9:45 18:00 8:15 7:00 11:30 13:00 13:45 14:15 14:30 15:00 5:45 0:30 11 :30 .00 WELCTL BOPE SURFAC 1/29/2003 04:30 - 05:30 05:30 - 10:30 23:30 00:00 02:00 03:00 22:00 - 23:30 20:45 00:00 .75 DRILL .25 DRILL 19:45 21:00 8:15 9:15 8:00 3:00 13:45 14:15 14:30 5:00 5:45 7:00 22:00 LOT CIRC 0.50 CASE MIT 1.25 CEMENT DSHO 0.25 CASE 1.00 CASE MIT MIT .00 DRILL .50 DRILL OTHR SURFAC 0.75 DRILL OTHR SURFAC 0.50 RIGMNT RGRP SURFAC 0.25 DRILL OTHR SURFAC 0.50 DRILL TRIP SURFAC 0.75 DRILL PULD SURFAC 1.25 RIGMNT RSRV SURFAC 00:00 02:00 03:00 04:30 SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC TRIP SURFAC 1.00 5.00 0.50 2.00 1.00 1.50 .50 CASE .25 WELCTL BOPE SURFAC WELCTL BOPE SURFAC WELCTL NUND SURFAC WELCTL NUND SURFAC WELCTL NUND SURFAC WELCTL NUND SURFAC RURD SURFAC CASE RURD SURFAC untilllast 27 bbls of displacement PUW 11 OK SOW 95K, had full returns with 203 bbls of 10.7 ppg cement returns to surface, CIP @ 2030 hrs. LD cement head - flush surface stack and flowline. Flutes on hanger were partially plugged. Blow down cement line. LD landing jnt. LD casing elevators and long bails - remove tools from rig floor. Hang short (drilling) bails on Top Drive. Rig down stabbing board. Remove riser, then drop 20" extension to set riser off to side. N/D 20" diverter assembly. Install FMC Gen V, 7" wellhead & 31/2" wellhead. NU 135/8" BOP stack. Test FMC metal to metal seal to 1,000 psi f/10 min. OK. PJSM. PU mousehole. RU to test BOPE. Test 135/8" 5m BOPE. Test witness waived by AOGCC insp Jeff Jones. Tested Hydril to 250psi low then 2500 psi high. Tested Top pipe rams, choke manifold, upper & lower IBOP, floor valve, manual choke and kill, HCR's on both choke & kill lines, bottom pipe rams, floor inside BOP, blinds to 250 psi low and 5000 psi high. UD test joint. PU 7" test joint. Test variables to 250 psi low and 5000 psi high. UD test joint. PU test joint, install FMC wear bushing. Blow down choke manifold and all lines. PU I MU BHA # 2 to MWD. Program Sperry Sun MWD tool. Trouble shoot # 1 rig engine wiring problem to Hi-Line power. Fill pit wI water and shallow test MWD. RIH w/BHA # 2 to all 5" HWDP in hole. PU 21 joints 5" DP from pipe shed. Run on top of 5" HWDP. PJSM. Service top drive and crown. Change out grease zerks on man rider sheaves. RIH w/ BHA # 2 to top of cement. Tag cement in 9 5/8" 40 #/ft L-80 BTC casing @ 2452'. Break circulation, circ drill pipe volume to get air out of drill pipe. Stand back stand. RU to test 9 5/8" 40#/ft L-80 BTC. Blow Down Top Drive, RU & Tested 95/8" Csg to 2,500 Psi for 30 Min & Charted Same RID test equipment. Blow down all lines. MU stand of 5" drill pipe. Drill 17' of cement on top of Float collar, then plugs, (float collar @ 2469'), cement, (float shoe @ 2558.90) and clean out rat hole to 2570'. Drill 20' of new hole from 2570' to 2590'. Drill wi 8-10 k WOB, 50 rpm, MM 148 rpm, 450 gpm (153 spm) wi 1135 psi. Torque on bottom 3500 ft/lb Circ bottoms up @ 550 gpm (190 spm) w/ 1517 psi. Displace mud system @ 450 gpm (153 spm) wi 1056 psi to new LSND 9.2 ppg , 46 FV. Blow Down Top Drive, RU & Perform FIT to 18.2 ppg EMW with 9.2 ppg new LSND mud in hole. Call engineer to discuss test. RID test equipment. Note: Cut off both 4" outlets on the 16" conductor fl 3S-16. Drill 8 1/2" hole per dirctional plan from 2590' to 3751' (1,161') TVD= 3745' ART 41/2 Hrs, AST 2 Hrs Drill w/ 10-20k WOB, 60-100 Rpm's, 190 Spm (557 Gpm's) with 1350-1750 Psi off bttm & 1400-1900 Psi on bttm , Off Btm Printed: 2/24/2003 0:40:32 AM 1/28/2003 20:00 - 20:45 0.75 CEMENT DISP SURFAC Legal Well Name: Common Well Name Event Name: Contractor Name Rig Name: - DRILLING n1268 @conocophillips.com Nabors 7ES Start: 1/25/2003 Rig Release: 2/10/2003 Rig Number: Spud Date End: Group: 3S-16 3S-16 ROT 1/26/2003 2/1 0/2003 ) r ) 3:00 13:30 09:30 07:00 - 08:00 00:00 - 03:00 03:00 - 03:30 03:30 - 07:00 2/2/2003 23:30 - 00:00 22:00 - 23:30 11 :00 11:30 08:00 - 09:30 0.50 CASE .50 CASE 3:30 14:30 11:00 RUNC INTRM1 RUNC NTRM1 11 :30 3:00 0.50 CEMENT PUMP INTRM1 .00 CEMENT DISP INTRM1 0.50 CEMENT RURD INTRM1 .50 CEMENTCIRC INTRM1 3.00 CASE 0.50 CASE 3.50 CASE 20:30 21:00 08:30 07:30 - 08:30 .50 CASE .50 CASE .00 CASE 11 :30 11 :00 CIRC RUNC INTRM1 CIRC INTRM1 RUNC INTRM1 8:30 9:00 5:00 CIRC RUNC INTRM1 NTRM1 21:00 22:00 19:00 20:30 8:30 5:00 11 :30 11 :00 NTRM1 0.50 CASE .00 CASE 0.50 DRILL .50 CASE 2.50 RIGMNT RGRP INTRM1 NTRM1 3.50 DRILL 3.50 DRILL 0.50 DRILL .00 DRILL SFTY RUNC OTHR INTRM1 RURD INTRM1 TRIP TRIP TRIP TRIP NTRM1 NTRM1 NTRM1 NTRM1 NTRM1 midnight. Run 7" 26 ppf L-80 BTC-mod casing to 2529' Circulate and condition mud and hole @ 2529' Continue to run 7" 26 ppf L-80 BTC-mod casing to 4655' (110 joints in hole) Circulate and condition mud and hole @ 4655'. Circ 2527 strokes. Stage up f/19 spm @ 635 psi, final press 612 psi wi 82 spm. SO weight increased f/1 07k to 120k. PU wt stayed the same. Continue to run 7" 26 ppf L-80 BTC-mod casing to 5872' (139 joints in hole) PU joint 140. Break circ and stage up to 70 spm wi 750 psi. Wash to TO. After circ bottoms up, stage up to 85 spm w/715 psi. No fill was encountered. No packing oft. Rig down Frank's fillup tool. RU Dowell cementing head. Circulate and condition fl cement job, circ total of 7000 strokes prior to cement job. Circ final @ 7 bpm wI 845 psi. Cement per plan. Rig displace @ 7 bpm wI 805 psi. Bump plugs wI 1160 psi(500 over circ press) @ 2902 strokes. CI P @ 1410 hrs. Bleed oft press. Check floats. OK. gpm (170 spm) 2100 psi, 60 rpm, flow show 34%, max gas units 104 Circulate 11.3 ppg mud around. Shale appears to be splintering fl wall of hole. Continue circulating, increase MW f/11.3 ppg to even out mud @ 11.8 ppg to control shale. Monitor well. Pump first stand out. No problems. MU top drive to stand # 2, attempt to pump stand out; mud went everywhere from washpipe area of top drive. Evaluate problem. POOH 5 stands for a total of 6 to 5340'. No overpull. Hole in good shape @ this depth (above top of HRZ). Repair washpipe problem on top drive. Cleanup top of top drive, determine problem. Fix, by replacing washpipe assembly. Cleanup top drive and rig floor. Test new washpipe to 3300 psi. Monitored hole to trip tank wi working on top drive. Worked pipe when in between operations to fix problem. Blow down top drive. Replace fluid in trip tank to 11.8 ppg. The original fluid had been watered back due to washing rig floor and top drive on prior operation. Continue to POOH. SLM. Monitor well @ 9 5/8" casing shoe. OK. Continue to POOH to BHA. Monitor well. OK. UD 5" HWDP and BHA. Flush out Sperry Sun tools wi water. UD MWD, motor and bit. Pull FMC wear bushing. PJSM. RU casing equipment. Change out bales to longer casing running bales. MU Frank's fillup tool. RU GBR casing tools. PJSM with crews on running 7" casing. Run Weatherford 7" model 303 float shoe, 2 joints 7" 26 #/ft L-80 BTC-mod casing, Weatherford model 402 float collar. Cut oft Rays OIL Tool 7" x 8 1/4" 00 aluminum centalizer oft of joint # 3. Run 2 joints 7" 26 #/ft L-80 BTC-mod, attempt to fill wi Frank's fillup tool. Pressured up to 1200 psi. Bleed pressure to zero. Break oft fillup tool, blow down top drive to confirm top drive not a problem. MU Frank's tool. Thaw out tool due to ice plug. Circ shoe joints. Continue to run 7" 26#/ft L-80 BTC-mod casing. 11 joints in hole @ Printed: 2/24/2003 10:40:32 AM 1/31/2003 2/1/2003 22: 15 - 00:00 00:00 - 07:30 .75 DRILL 7.50 DRILL CIRC CIRC NTRM1 NTRM1 Legal Well Name: 3S-16 Common Well Name: 3S-16 Event Name: ROT - DRILLING Contractor Name: n1268@conocophillips.com Rig Name: Nabors 7ES Start: 1/25/2003 Rig Release: 2/10/2003 Rig Number: Spud Date: 1/26/2003 End: 2/10/2003 Group: ) .~ ~ ,) i. .... .iii. ii i ..... .'. ... 01:00 01:30 02:30 01:30 02:30 11 :30 0.50 WELCTL BOPE 1.00 RIGMNT RGRP 9.00 CEMENT DSHO NTRM1 NTRM1 NTRM1 Printed: Repaired Leaking Fittings on Test Equipment Prior to Testing Manual Valve Tested Manual Valve on Top Drive, 250 Psi Low & 5,000 Psi High Replaced Broken Die in Top Drive & Installed Stabbing Guide Washed Down from 5,788' to 5,823', Drilled Plugs & Float Collar at 5,823', Drilled Med to Hard Cement to Float Shoe @ 5,906.5'. Best 2/24/2003 0:40:32 AM 2/4/2003 00:00 23:30 - 00:00 21 :00 - 22:00 11 :00 3:30 22:00 - 23:30 6:45 3:30 6:00 0:00 11:00 21:00 01:00 6:00 16:45 .00 RIGMNT RGRP 0.50 WELCTL BOPE CEMENT 4.25 DRILL .00 RIGMNT RGRP 2.50 DRILL PULD 2.50 DRILL PULD 0.75 RIGMNT RGRP .50 CEMENT .00 CEMENT COUT PULD NTRM1 NTRM1 NTRM1 INTRM1 INTRM1 INTRM1 NTRM1 NTRM1 NTRM1 NTRM1 procedure on valve removal. Remove excess subs fl rig floor. Clean up rig floor. Pickup 6 1/8" BHA. Change out elevators to 3 1/2" due to lifting subs fl drill collars are 3 1/2". MU bit, bit sub to 4 3/4" flex drill collars, PU 4" HWDPfl pipe shed, wI RIH. PU and RIH 4" drill pipe on top of 4" HWDP. 62 joints in hole. Reinstall lower IBOP on top drive. MU clamps. Valve was rebuilt & tested to 250 psi low and 5000 psi high prior to reinstall. Continue to PU 4" drill pipe, RIH w/6 1/8" BHA. Fill pipe on jt # 105, continue to PU 4" dp. to joint # 162. Tagged cement @ 5788'. Circ wi 97 spm (284gpm) & 1467 psi. Pump 20 bbls water ahead, follow w/11 ppg mud wI BAROTRL. RU and test 7" casing to 3500 psi w/11 ppg mud in hole. Chart test fl 30 min. RID test equipment. RU to test manuallBOP valve on top drive. Note: Perform LOT on 9 5/8" x 7" annulus established 16.1 ppg EMW Followed test wi 300 bbls fresh water flush, freeze protected with 57 bbls diesel. 2/3/2003 08:00 02:00 - 07:00 23:00 - 23:45 23:45 - 00:00 00:00 - 00:30 00:30 - 02:00 10:00 07:00 - 08:00 2.00 RIGMNT RGRP 5.00 0.75 0.25 0.50 1.50 .00 WELCTL OTHR WELCTL BOPE WELCTL BOPE INTRM1 RIGMNT RGRP INTRM1 RIGMNT RGRP INTRM1 WELCTL OTHR INTRM1 NTRM1 NTRM1 NTRM1 19:30 - 20:30 20:30 - 23:00 7:00 7:30 8:00 6:00 7:30 8:00 7:00 9:30 .00 2.50 0.50 0.50 .50 .00 WELCTL OTHR DRILL OTHR WELCTL OTHR WELCTLOTHR WELCTL OTHR WELCTL NUND INTRM1 NTRM1 NTRM1 NTRM1 NTRM1 NTRM1 RID cement equipment. Blow down lines. Clear tools fl floor. Remove turnbuckles f/13 5/8" BOP stack. Split 31/2" tubing spool f/7" casing spool. PU BOP stack. Set FMC emergency slips wi 190K on indicator. Cut and remove cutoff joint # 140. Move stack out of way. Final cut and dress 7" fl packoff. Install FMC packoff fl 7". RILDS. Test packoff to 4300 psi (80% of burst) f/1 0 min. OK. Set 13 5/8" BOP stack back on well. Tighten bolts on 11' 5m spool. Install riser and tighten turnbuckles. PJSM. Change top pipe rams to 4". Pick up in cellar. Change out bales to drilling bales. Change top drive over to 4" from 5". Change out iron roughneck jaws to smaller size fl 4" drill pipe. RU to test 13 5/8" 5m BOPE. Repair electrical switch on iron roughneck. Repair electrical switch on iron roughneck. MU floor safety valve & dart valve(inside bop) on test joint. Set test joint in hole wi FMC test plug. Hook up fittings. Fill stack with water, filling choke manifold as well. Test 135/8" BOPE. Test Hydril to 250 psi low and 5000 psi high. Test top pipe rams (4"), choke manifold, floor safety valve and inside BOP (floor safety valve), manula valve on kill line, HCR on kill line, manual valve on choke line, HCR on choke line, lower pipe rams (2 7/8" x 5"), blindlshear rams to 250 psi low and 5000 psi high. Test accumulator. Witness of test by AOGCC inspector Chuck Sheeve was waived. While testing lower IBOP on top drive, the IBOP failed. Pull test joint and test plug. Set FMC wear bushing. Blow down choke & kill lines and choke manifold. Break and lay down 4" test joint. Remove lower IBOP valve fl Canrig topdrive. PJSM and review 2/2/2003 14:30 15:00 15:00 16:00 0.50 .00 CEMENT RURD INTRM1 WELCTL NUND INTRM1 Legal Well Name: 3S-16 Common Well Name: 3S-16 Event Name: ROT - DRILLING Contractor Name: n1268@conocophillips.com Rig Name: Nabors 7ES Start: 1/25/2003 Rig Release: 2/10/2003 Rig Number: Spud Date: 1/26/2003 End: 2/10/2003 Group: .... ... ...... .............. ........ ..... < ~r .:.i. ......... i: .... i ..................... /.............................. ............/......../ .. '. .... ...... ) ) Legal Well Name: 3S-16 Common Well Name: 3S-16 Event Name: ROT - DRILLING Contractor Name: n1268@conocophillips.com Rig Name: Nabors 7ES 2/4/2003 02:30 - 11 :30 9.00 CEMENT DSHO INTRM1 11 :30 - 17:30 6.00 CEMENT TRIP INTRM1 17:30 - 19:30 2.00 DRILL TRIP INTRM1 19:30 - 20:30 1.00 RIGMNT RSRV INTRM1 20:30 - 22:00 1.50 DRILL TRIP INTRM1 22:00 - 23:00 1.00 DRILL CIRC INTRM1 23:00 - 23:30 0.50 DRILL DRLG INTRM1 23:30 - 00:00 0.50 DRILL CIRC INTRM1 2/5/2003 00:00 - 00:30 0.50 DRILL CIRC INTRM1 00:30 - 01 :30 1.00 FRMTST OTHR INTRM1 01 :30 - 05:00 3.50 DRI LL OTHR INTRM1 05:00 - 09:00 4.00 DRILL TRIP INTRM1 09:00 - 10:00 1.00 DRILL TRIP INTRM1 10:00 - 11 :00 1.00 FISH PULD INTRM1 11 :00 - 15:00 4.00 FISH TRIP INTRM1 15:00 - 15:30 0.50 FISH WASH INTRM1 15:30 - 16:30 1.00 FISH CIRC INTRM1 16:30 - 20:00 3.50 FISH TRIP INTRM1 20:00 - 21 :00 1.00 FISH TRIP INTRM1 21 :00 - 22:00 1.00 FISH PULD INTRM1 22:00 - 00:00 2.00 FISH TRIP INTRM1 2/6/2003 00:00 - 01 :30 .50 FISH TRIP INTRM1 01 :30 - 03:00 .50 FISH MILL INTRM1 Printed: 2/24/2003 ROP WIDrig Cmt was 60'/Hr, Unable to Drill Out Float Shoe,Pumped Hi Vis Sweep with No Change, Rot Wt 11 OK, PU 125K, Down Wt 97K, Torque Off Btm 2.5K Ft#'s, On Btm 3K Ft#'s, Pumped 300 Gpm @ 1,200 Psi, 5-20K WOB and 110 RPM's Monitored Well & POOH to BHA, SLM No Corr, Monitored Well @ BHA-Static, POOH & LD Bit, Bit 8-8 with No Cutters Left on Bit MU 61/8" Tri Cone Bit #4 with Junk Bskt & TIH with BHA #4 to 2,077' Serviced Top Drive & Drawworks Cont TIH to 5,837' Est Circ @ 250 Gpm's, 1,475 Psi, RIH Tagging Up & Working Junk Bskt @ 5,907', Pumped 40 bbl70 Vis Sweep & Circ Out, with No Changed in Cuttings Over Shaker Drilled Float Shoe @ 5,907' and 3' of New hole to 5,910' MD/5,842' TVD, Pumped @ 250 Gpm's @ 1,425 Psi, 90-110 Rpm's & 10-14K WOB, Rot Wt 106K, PU 110K, Dwn Wt 100K, Torque Off Btm 2.5K Ft#'s, On Btm 3K Ft#'s Circ Hole Clean for F.I.T., Circ @ 250 Gpm's, 1,430 Psi, 60 Rpm's, 3K Ft#'s Off Btm Torque, Ave BGG 20 Units Fin Circ Btms Up for F.I.T., Circ @ 250 Gpm's, 1,340 Psi, 11.0 Mw In & Out, Monitored Well-Static RU & Performed F.I.T., to 12.7 ppg EMW, Good Test, RD & Blow Down Lines RIH to Btm with Bit, Circ & Worked Junk Basket, Had Torque once on Btm, Worked Bit on Btm, Torque would Smooth Out, Then We Would PU Off Btm & Shut Pump Down, Waited Several Minutes, RIH and Would Torque Up & Smooth Out, Drilled l' of New Form to 5,911' MD/5,843' TVD, While Working Bit & Junk Basket, Attempted to Drill 2 Add Ft with No Success, Torque Off Btm, 2.5K Ft#'s, On Btm 3-8K Ft#s, Circ @ 240 Gpm's, 1,340 Psi, Ave 60 Rpm's, Varied WOB to 15K, Monitored Well- Static POOH, Monitored Well @ BHA-Static, POOH, Found #3 Cone on Bit Broke Off And Was Left in Hole Broke Out Bit and Cleaned out Junk Basket, Recovered Several Pieces of Aluminium FIFlt Equip and Several Pieces of Matrix from PDC and a Few Pieces of Cutters, Cleared Rig Floor PU & MU Baker Fishing's Reverse Junk Basket with 3 Junk Baskets on BHA #5 & RIH TIH with Rev Junk Basket & Tagged Up at 5,911' Worked Rev Junk Basket on Btm, Dropped Ball to Rev Circ, on Seat in 8.5 Min, Rev Circ & Cont to Work Basket, Circ @ 208 Gpm's, 1,020 Psi, 40 Rpm's Circ Btms Up, No Gas or Losses, Monitored Well-Static POOH, Monitored Well @ BHA-Static, POOH with Rev Junk Basket Broke Down Rev Junk Basket & Recovered Cone with Journal Pin, Several Large Pieces Approx 1 1/2" in Dia of PDC Bit, 1 with 2 Broken Cutters, 1 Smaller Piece of Broke Cutter, Several Pieces of Aluminum from Fit Equip, Cleaned Out Junk Baskets and Recovered Mosly Med to Large Pieces of Shale, Cleared Rig Floor PU & MU Bakers 6"· 6 Bladed OH Mill with 3 Junk Baskets on BHA# 6 TIH with Mill to 3,982' Fin TIH with 6" Mill, Tagged Btm At 5,911' Worked Mill On Btm with No Torque, Milled Add l' of New Form to 5,912' MDI 5,844' TVD with No Increase in Torque, ART 1 Hr, Ran 8K 0:40:32 AM Start: 1/25/2003 Rig Release: 2/10/2003 Rig Number: Spud Date: 1/26/2003 End: 2/10/2003 Group: ) ) 2/6/2003 01 :30 - 03:00 .50 FISH MILL INTRM1 03:00 - 03:30 0.50 FISH CIRC INTRM1 03:30 - 07:30 4.00 FISH TRIP INTRM1 07:30 - 08:30 1.00 FISH TRIP INTRM1 08:30 - 09:30 1.00 CORE PULD INTRM1 09:30 - 13:30 4.00 FISH TRIP INTRM1 13:30 - 14:00 0.50 FISH FISH INTRM1 14:00 - 18:00 4.00 FISH TRIP INTRM1 18:00 - 18:30 0.50 FISH PULD INTRM1 18:30 - 20:30 2.00 CORE PULD INTRM1 20:30 - 21 :30 1.00 CORE CIRC INTRM1 21 :30 - 00:00 2.50 CORE TRIP INTRM1 21712003 00:00 - 01 :30 1.50 CORE TRIP PROD 01 :30 - 02:30 1.00 CORE WASH PROD 02:30 - 05:00 2.50 CORE CORE PROD 05:00 - 06:00 1.00 CORE CIRC PROD 06:00 - 09:00 3.00 CORE TRIP PROD 09:00 - 10:00 1.00 CORE CIRC PROD 10:00 - 14:00 4.00 CORE TRIP PROD 14:00 - 20:30 6.50 CORE TRIP PROD 20:30 - 22:30 2.00 CORE PULD PROD Printed: 2/24/2003 WOB, 80 Rpm's, 250 Gpm's, 1,100 Psi, 3K Ft#'s Torque Off Btm, 3.5K On Btm, Rot WT 108K, PU WT 120K, Dn Wt 105K, Ave BGG 15 Units Circ Btms Up at 250 Gpm's 1,060 Psi Monitored Well-Static, POOH with Baker 6" Mill & Junk Baskets Broke Out & LD Mill -0- Wear, Cleaned Out Junk Baskets & Recovered Shale, No Metal, Clear Rig Floor Held Safety Mtg on PU Core bbls, PU & MU 6 1/8" Core Bit on 4 3/4" Core bbl, RIH, Using Collar Clamp, PU & MU 2nd Core bbl & Started in Hole When Core bbl Backed Out of Lift Sub Causing Core bbl to Drop in Hole, Fish in Hole 61/8" Core Bit, 2- 4 3/4" Core bbls, Total 64' Long, Top of Fish @ 5,847' MU 6" Stab, Repositioned Dc's in Derrick, RIH with Stab on Fishing BHA #7, Tagged TOF @ 5,847' Est Circ Above TOF, Slacked Off & Engaged Fish, Saw increase in Press & Torque, Worked Torque into Fish, Off Btm Torque 3.5K Ft#'s, Worked 8K Ft#'s into Fish, PU & Fish was Free, Circ @ 170 Gpm's, 575 Psi, Rot Wt 11 OK, PU Wt 120K, Dn Wt 100K Monitored Well-Static, POOH & Recovered Fish LD 61/8" Core Bit, Had 1 Broken Tooth, LD Both Core bbls, bbls Appear Ok, Cleaned Rig Floor MU New 61/8" Core Bit, 2-43/4" Core bbls with 2 5/8" Inner bbls, Fit Sub & PBL Sub (BHA #8) Function Tested PBL Sub, Dropped Activation Ball & Opened Sub, Dropped 2 De-Activation Balls & Closed Sub, PU & Retrieved Balls Cont TIH with Coring Assembly BHA #8 to 5,275' Cont RIH with 6 1/8" Core Bit & 4 3/4" Core bbls to 5,906' Est Circ @ 250 Gpm's 1,115 Psi, Washed Down F/5,906' & Tagged Btm @ 5,912', No Fill, Worked Core Bit to Clean Btm Prior to Coring, Circ Btms Up, No Gas, Dropped Ball to Divert Flow in Core bbl, Est Circ Rates @ 200 Gpm 1,325 Psi, 250 Gpm's 1,845 Psi, Took Slow Pump rates Cored Kup "C" Sand, Cored from 5,912' to 5,971' MD/5,902' TVD, (59'- 23.6'/Hr Ave), Ave 10K WOB, 60 Rpm's, 215 Gpm, Initial Press 1,350 Psi, Final Press 1,600 Psi, Off Btm Torque 3K Ft#'s, Ave On Btm Torque 4K Ft#'s, Drilled with No Mud Loss or No Increase in Gas with 11.0 ppg Mw in & Out, Rot Wt 11 OK, PU Wt 120K, Dn Wt 100K PU to 135K St Wt & Broke Core Off (25K Over St Wt), Circ Btms Up @ 215 Gpm's, 1,600 Psi, No Gas On Btms Up or Mud Loss Blow Down Top Drive, Monitored Well-Static, POOH 5 Stds Hole Not Taking Calc Fill, Monitored Well-Static, PuliS More Stds to 5,054' Hole Took 2.6 bbls, Monitored Well-Static, Ran Back in Hole to 5,967' Est Circ At 5,967', Pulled Up Into Shoe @ 5,907' & Circ Btms Up, 11.0 ppg Mw In & Out, No Gas on Btms Up, Dropped Activation Ball & Opened PBL Sub, Dropped Locking Ball & PBL Sub Didn't Lock Open Pumped Out of Hole from 5,907' to 4,990', Hole Taking Calc Fill, Monitored Well-Static Cont to POOH Without Pumping, Hole Taking Calc Fill, POOH Wet, Monitored Well @ BHA-Static, POOH Slow per Well Plan to Maintain Core Integrity, POOH to Core bbls, LD PBL Sub & Recovered Both Balls Pulled Inner Core bbls & LD in Pipe Shed, (Core Lab Cut & Boxed Up Core) Full 59' Core Recovery, LD Core bbl's & Bit, NO Wear on Core Bit, Cleaned Rig Floor 0:40:32 AM Legal Well Name: 3S-16 Common Well Name: 3S-16 Event Name: ROT - DRILLING Contractor Name n1268@conocophillips.com Rig Name: Nabors 7ES Start: 1/25/2003 Rig Release: 2/10/2003 Rig Number: Spud Date: 1/26/2003 End: 2/10/2003 Group: . .../.< .i ,! i " , "" ...!,./ ) ) 12:30 09:45 02:00 - 03:30 09:00 - 09:45 08:00 - 09:00 03:30 - 08:00 3:30 12:30 .00 CEMENT PUMP PROD 2.75 CEMENTCIRC RUNL RUNL OTHR 4.50 CASE 0.75 CASE .00 CASE .50 CASE RUNL PROD PROD PROD PROD PROD 2/9/2003 00:00 01:00 01:00 02:00 .00 CASE .00 CASE RURD PROD PULR PROD 7:30 20:30 20:30 00:00 3.00 DRILL 3.50 DRILL TRIP TRIP PROD PROD 5:30 17:30 2.00 DRILL TRIP PROD 14:30 3:00 4:00 07:30 13:00 5.50 DRILL DRLG PROD 06:00 - 07:30 22:30 00:00 02:00 00:00 02:00 06:00 5:30 14:00 14:30 .50 LOG .50 DRILL 2.00 DRILL 4.00 DRILL .00 DRILL .00 DRILL 0.50 DRILL DLOG PULD PULD TRIP CIRC CIRC WIPR PROD PROD PROD PROD PROD PROD PROD MU 6 1/8" Bit #6, Started PU BHA #9, Orient & Up Load MWD Fin PU & MU BHA #9, Tested MWD & Loaded Radioactive Source PU & MU 12 Jts of 4" DP from Pipe Shed and Stood Back, TIH with BHA #9 to 5,850' Log Down While RIH, Madd Pass from 5,850' to 5,907' @ 200' Hr Recorded Log, Washed & Madd Pass from 5,907' to 5,971' in OH @ 100' Hr Real Time Log, No Problems or Fill DriIl61/8" Hole from 5,971' to 6,150' MD/6,079' TVD (179') Hole T.D., Drilled at 238 Gpm, 2,000 Psi, 15K WOB, 90 Rpm's, Off Btm Torque 3K Ft #'s, On Btm 3.5K Ft #'s, Ave BGG 40 Units, Clean Hole ECD 12. ppg, Ave 12.25, Max ECD 12.5 with No Mud Loss Circ Btms Up, No Increase in Gas, Circ @ 80 Spm 1,680 Psi Wiped Hole 3 Stds to Csg Shoe @ 5,907', Monitored Well- Static, RIH to Btm No Problems Pumped 35 bbl 120 Vis Sweep & Circ Out, No Gas or Change in Cuttings at Btms Up, Circ Clean, Monitored Well-Static POOH Wet to 4,831', Hole Taking Calc Fill, Monitored Well-Static, Pumped Dry Job & Blew Down Top Drive POOH to HWDP & Monitored Well-Static, POOH to Dir Drlg BHA PJSM with Sperry Sun, POOH, Removed Radioactive Sources, Downloaded MWD, POOH & LD BHA RU GBR Liner Running Equipment PU & RIH with 3 1/2" 9.3# L-80 SLHT Liner, Ran Baker "V" Set Float Shoe, 2 Jts 31/2" Liner, Baker Fit Collar, 1 Jt 31/2" Liner, Baker Landing Collar, Thread Locked Conn's, RIH with 8 Jts of 3 1/2" Liner, 1-Pup Jt 3.75' Long for Marker Jt & 1 Jt of 31/2" Liner (Total 12 Jts with Pup & Fit Equip 375.41') Ran 9 Rigid Centralizers PU & MU Baker 7" x 5" ZXP Liner Top Pkr WIHR Profile & Flex Lock Hanger and RIH, Circ Liner Cap, Liner Wt 3K#'s, Blew Down Top Drive RIH with 31/2" Liner on 4" DP to 5831'. Filled Pipe Every 10 Stds, Ave Running Speed 50-60 fpm. Stage pumps up to 4.0 bpm 1750 psi. Establish baseline Torque and drag readings - @ 15 rpm PUW 95K 2500 fibs - SOW 95K 2500 fibs - ROT 90K 2200 fIbs. Circ pipe volume - load Plug Dropping head on skate -ready circulating hose and valve manifold. RIH to 6120' - PU Plug Dropping Head and MU circulating hose and manifold. Add single from mousehole - MU in string with Top Drive. Establish circ and wash down - tagged bottom @ 6150'. Stage pumps up to 4.0 bpm / 775 psi and condition mud. Rotate and reciprocate liner PUW 105K SOW 102K - 2700-3000 fibs torque. Reduced YP from 25 to 19 - Gels from 8/10/11 to 6/8/10 maintained wt @ 11.0 ppg. Held PJSM with Rig Team. Batch mix cement and Mud Push spacer. Line up to cementers - pumped 5 bbls of CW 100 and tested lines to 4200 psi. pumped remaing 5 bbls of CW 100 - 15 bbls of 12.0 ppg MudPush spacer and 25 bbls of 15.8 ppg cement. Flushed cement lines to rig floor, dropped wiper plug and displaced with 61.4 bbls of 11.0 ppg mud (rig pumps) @ 5 bpm 645 - 1450 psi. Bumped plugs to 1900 psi - Reciprocated and rotated pipe untilllast 5 bbls of displacement, full returns throughout. Increased pressure to 2550 psi, hung liner with shoe @ 6145'. Slacked off 50K to confirm hanger set- with 25k on liner increased pressure to 3750 psi - and released setting tool. PU to clear rotating dog sub and set liner top packer with 50K Printed: 2/24/2003 0:40:32 AM 2/7/2003 2/8/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-16 38-16 ROT DRILLING n1268@conocophillips.com Nabors 7E8 Start: 1/25/2003 Rig Release: 2/10/2003 Rig Number: Spud Date: 1/26/2003 End: 2/10/2003 Group: : ...·.T·.Ty ¡ir+ < ..... :..... .. Ti< < ........0·m!·I..II.~.~. .... ...... Sw :'~~F ........ . .... .... ¡.¡. ...¡' .¡¡. .... ........ ..... iT t·... ) ) 22:00 - 00:00 20:30 22:00 2.00 CMPL TN RURD CMPL TN .50 CMPL TN FRZP CMPL TN 5:00 - 17:30 7:30 - 20:30 3:00 14:00 11 :45 10:45 09:30 07:30 - 08:30 08:30 - 09:30 05:00 - 07:30 2/10/2003 00:00 - 02:30 02:30 - 05:00 9:30 20:30 21:30 22:00 22:30 14:00 3:30 4:00 0.50 CEMENTOTHR PROD SOW. Held 300 psi on drill pipe and pulled packoff into tie back sleeve increased rate to 8 bpm /1800 psi. Circulate hole 8.3 bpm / 1800 psi - dumped Mud push and 50 bbls of cement contaminated mud - est 5 bbls of cement returns to surface. Break out joint below Plug dropping head in mousehole, RD circ hose and manifold - LD Plug Dropping head. Pumped Dry Job, POOH LD 4" DP, POOH to Liner Setting Tool, LD 183 Jts DP Broke Out & LD Baker Liner Setting TIH with 6 Stds of 4" HWDP, POOH LD Pulled Wear Bushing RU GBR 31/2" Tongs & Elevators, Held Safety Mtg With Crew MU Baker Seal Assembly & Completion Assembly and Began RIH on 3 1/2" 9.3# L-80 EUE Mod Tbg to 1,175' Cont TI H with Seal Assembly PU 3 1/2" Tbg to 3,125' Suspended Operations Due to Phase 3 Weather Conditions, Reviewed Tbg Running Procedure Cont PU 31/2" Tbg & RIH with Seal Assembly to 5,735', PU Total of 183 Jts, 5,668' of 3 1/2" 9.3# L-80 EUE AB-Mod Tbg RU & Tested 7" Csg & 31/2" Liner to 3,500 Psi for 30 min, Good Test PU jnt #184 - circ down @ 1.2 bpm I 240 psi - observed pressure increase @ 5757.5', down pump I bleed off pressure, slack off and tag with locator sub - tail @ 5773' (15.5') - PU to 5735'. Change over well untill clean: Pumped 35 bbls of 200+ FV sweep - 50 bbls of fresh water and 250 bbls of seawater @ 8.0 bpm 11610 psi. After first tubing volume took returns to pit #4 to monitor gain / loss, monitor well, static. Space out tubing- MU tubing hanger and landing joint - land tubing (2' above fully located) tail @ 5771'. RILDS. RU and test tubing to 3680 psi bled off 30 psi in 15 min. Bleed tubing to 1680 psi. Test 3 1/2" X 7" annulus to 3500 psi, bled off 65 psi in 15 min. Bleed casing to zero I bleed tubing to zero - pressure up annulus, DCR valve sheared @ 3550 psi. LD landing joint - blow down lines - install TWC. Changed Out Top set of 4" Pipe Rams to 41/2" x 7" Variables, Sim Op's Cleaning Mud Pits ND BOP Stack NU Gen V 5K# Tree & adadpter Spool, Had to Move Adapter Spool 2 Bolt Holes to Line Up Tree, RU & Tested Tree to 5,000 Psi, Pulled TWC. Sim Op, Cont Cleaning Mud Pits RU Little Red, Tested Lines to 2,500 Psi, Freeze Protected Well Pumping 105 bbls Diesel Down Tbg, Diesel in Tbg to RP Valve @ 5,650' Leaving Diesel In 31/2" x 7" Down to 2,100', RD Little Red & Installed BPV in Well, Secured Well Fin Cleaning Mud Pits & Cellar Area, Rig Off High Line Power @ 22:30 Hrs, RELEASED RIG @ 24:00 Hrs 1/10/03 Printed: 2/24/2003 0:40:32 AM 11:45 14:00 5:00 3:00 0:45 2.50 CMPL TN NUND CMPL TN 3.00 CMPL TN NUND CMPL TN 2.50 CMPL TN RUNT CMPL TN .25 .00 CMPL TN DEQT CMPL TN .00 CMPL TN RUNT CMPL TN .25 .00 CMPL TN SOHO CMPL TN CMPL TN .00 CMPL TN OTHR CMPL TN .00 CMPL TN RURD CMPL TN CMPLTN CIRC CMPL TN DEQT CMPL TN 14:30 20:30 21:30 22:00 22:30 00:00 19:30 4:30 2.50 2.50 5.00 0.50 CEMENT PULD .00 CEMENT PULD PROD .00 CMPL TN TRIP PROD 0.50 CMPL TN OTHR PROD 0.50 CMPL TN RURD PROD .50 CMPL TN RUNT PROD CMPL TN RUNT CMPL TN WAlTON WOW CMPL TN CEMENTTRIP PROD PROD 2/9/2003 12:30 3:30 .00 CEMENT PUMP PROD Legal Well Name: 3S-16 Common Well Name: 38-16 Event Name: ROT - DRILLING Contractor Name n1268@conocophillips.com Rig Name: Nabors 7E8 Start: 1/25/2003 Rig Release: 2/10/2003 Rig Number: Spud Date End: Group: 1/26/2003 2/1 0/2003 ) ) ) Page CEMENT BOND LOG W/SCMT-BB, TAGGED PBTD @ 6050' ELMD, LOGGED ACROSS JEWELRY & FOUND GOOD CEMENT UP TO BTM OF SEAL BORE ASSY. POOH, RIH W/2.5" HSD 6 SPF, PJ GUN LOADED 19'. PERFORATE 5915'.5934' ELMO. WHP UP TO 800 AFTER SHOT. POOH, RIH W/PSP STRING, LOG POST PERF STATIC BHPIT @ 5925' MD (MID PERFS) AND 5725' (JUST BELOW PKR) 1 of 1 2/24/2003 02/23/03 02/22/03 02/21/03 02/19/03 02/18/03 Date 01/26/03 02/17/03 Comment STAND BY FOR RIG. RUN SPERRY GYRO TOOL TO 180' SLM. PULLED BACK PRESSURE VALVE - FULL FUNCTION AND BOP TEST - MUD CLEANOUT TO 6040' CTM USING SLICK WATER AND FREEZE PROTECTED WITH DIESEL FROM BOTTOMS UP - HELD PRESSURE ON IA TO KEEP MUD OUT [FCO] DRIFTED TBG 2.72" & TAGGED @ 6054' RKB. DRIFTED TBG W/ 22' X 2.5" HC DMY GUN TO 6054' RKB, EST. 120' BELOW TARGET PERFS. SET DV @ 5651' RKB. MITT 3000 PSI, GOOD. MITIA 3000 PSI, GOOD. [TAG, GLV, MIT] ATTEMPTED CEMENT BOND LOG. RIH TO 4250' MD, HAD TOOL FAILURE, POOH. FOUND SHORTED CENTRALIZER AND DAMAGED COMPUTER. RDMO, LEFT WELL SHUT IN. NOTIFIED DSO OF DEPARTURE. [PERF, PRESSURE DATA] ATTEMPTED CEMENT BOND LOG W/ SCMT. TOOLS STUCK IN GLM @ 5651' MD. WORKED TOOLS UP & DOWN W/ NO LUCK. PULL OUT OF WEAK POINT, POOH. RDMO, PREPARE FOR SL TO FISH TOOLS LEFT WELL SHUT IN. NOTIFY DSO OF WELL STATUS. [PRESSURE DATA] RECOVERED E-LlNE TOOL STRING @ 6001' SLM. GAUGED TBG TO 2.49", NO OBSTRUCTIONS. [FISH] ) 35-16 Event History ) ) ) d03-0ð7 ¡ 20-Feb-03 AOGCC Lori Taylor 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3S-16 Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: 0.00' MD Window / Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 6,150.00' MD Please call me at 273-3545 if you have any questions or concerns Regards, William T. Allen Survey Manager Attachment(s) í~ECE'\JE() 8 2 -. ,. 0 t'I '1 FE t> i~... V~I AJa~n ()~; ~, G~'~~ \~~H:,. Lr;;i~I:t~~ l\1:.~~,~~¡J DEF N T''I£ Sperry-Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 35 Pad 35-16 ~_/ Job No. AKMW30010, Surveyed: 8 February, 2003 Survey Report 19 February, 2003 Your Ref: API 501032044500 Surface Coorpinates: 5993887.49 N, 476149.43 E (70023' 39.9477" N, 150011'38.6000" W) . Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -- Surface Coordinates relative to Project H Reference: 993887.49 N, 23850.57 W (Grid) Surface Coordinates relative to Structure: 43.51 N, 305.71 W (True) Kelly Bushing: 56. 67ft above Mean Sea Level Elevation relative to Project V Reference: 56. 67ft Elevation relative to Structure: 0.57ft sru-....,......y-sLJl'1 DRIL..L..ING seRVices A Halliburton Company Survey Ref: svy10025 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-16 Your Ref: AP/501032044500 Job No. AKMW30010, Surveyed: 8 February, 2003 ConocoPhillips Western North Slope 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) (0/100ft) 0.00 0.000 0.000 -56.67 0.00 0.00 N 0.00 E 5993887.49 N 476149.43 E 0.00 Tolerable Gyro 108.00 0.000 0.000 51.33 108.00 0.00 N 0.00 E 5993887.49 N 476149.43 E 0.000 0.00 172.50 0.500 79.000 115.83 172.50 0.05 N 0.28 E 5993887.54 N 476149.71 E 0.775 -0.24 MWD Magnetic 289.00 0.290 143.480 232.33 289.00 0.09 S 0.95 E 5993887.40 N 476150.38 E 0.393 -0.66 379.73 0.370 142.320 323.06 379.73 0.50 S 1.27 E 5993886.98 N 476150.69 E 0.088 -0.63 469.82 0.500 165.780 413.14 469.81 1.11 S 1.54 E 5993886.37 N 476150.97 E 0.242 -0.43 -~ 561.30 0.570 142.130 504.62 561.29 1.86S 1.92 E 5993885.62 N 476151.34 E 0.251 -0.23 649.50 0.670 144.340 592.81 649.48 2.638 2.49 E 5993884.86 N 476151.91 E 0.117 -0.16 741.08 0.600 343.650 684.39 741.06 2.60 S 2.67E 5993884.88 N 476152.09 E 1.367 -0.31 831.99 0.830 329.920 775.29 831.96 1.57 S 2.20E 5993885.91 N 476151.63 E 0.314 -0.63 927.79 1.360 341.010 871.08 927.75 0.10 N 1.48 E 5993887.59 N 476150.91 E 0.593 -1.19 1023.41 1.520 337.870 966.67 1023.34 2.35 N O.64E 5993889.84 N 476150.07 E 0.187 -2.02 1118.62 1.620 328.820 1061.84 1118.51 4.67 N O.54W 5993892.16 N 476148.91 E 0.280 -2.66 1214.27 1.690 324.470 1157.45 1214.12 6.98 N 2.06W 5993894.47 N 476147.40 E 0.150 -3.02 1308.65 1.930 328.950 1251.78 1308.45 9.47 N 3.68W 5993896.97 N 476145.78 E 0.295 -3.43 1403.54 0.940 309.540 1346.64 1403.31 11.33 N 5.11 W 5993898.84 N 476144.36 E 1.148 -3.58 1499.03 0.430 337.810 1442.13 1498.80 12.16 N 5.85W 5993899.67 N 476143.62 E 0.625 -3.57 1594.29 0.560 2.870 1537.38 1594.05 12.96 N 5.96W 5993900.47 N 476143.51 E 0.262 -4.00 1690.93 0.620 8.690 1634.02 1690.69 13.95 N 5.86W 5993901.46 N 476143.62 E 0.088 -4.73 1786.95 0.710 5.130 1730.03 1786.70 15.05 N 5.73W 5993902.56 N 476143.75 E 0.103 -5.56 1881.84 0.720 11.950 1824.91 1881.58 16.22 N 5.55W 5993903.73 N 476143.93 E 0.090 -6.46 1976.42 0.720 350.610 1919.49 1976.16 17.39 N 5.52W 5993904.90 N 476143.96 E 0.282 -7.24 2073.01 0.330 28.340 2016.07 2072.74 18.23 N 5.49 W 5993905.74 N 476144.00 E 0.519 -7.82 2167.03 0.370 2.600 2110.09 2166.76 18.78 N 5.35W 5993906.28 N 476144.14 E 0.171 -8.28 .-- 2261.24 0.400 351.570 2204.30 2260.97 19.41 N 5.38W 5993906.91 N 476144.11 E 0.085 -8.67 2357.70 0.890 334.670 2300.75 2357.42 20.42 N 5.75W 5993907.92 N 476143.74 E 0.540 -9.05 2451.45 0.940 4.190 2394.49 2451.16 21.84 N 6.01 W 5993909.35 N 476143.49 E 0.500 -9.80 2502.92 0.780 14.500 2445.96 2502.63 22.60 N 5.89W 5993910.11 N 476143.61 E 0.431 -10.38 2638.44 0.920 8.690 2581.46 2638.13 24.57 N 5.49 W 5993912.08 N 476144.01 E 0,121 -11.97 2734.50 3.280 346.150 2677.45 2734.12 28.00 N 6.03W 5993915.51 N 476143.48 E 2.556 -13.82 2830.07 4.530 341.930 2772.80 2829.47 34.24 N 7.86W 5993921.76 N 476141.68 E 1.341 -16.53 2924.92 4.850 342.960 2867.33 2924.00 41.64 N 10.20 W 5993929.16 N 476139.37 E 0.349 -19.62 3020.32 5.420 323.280 2962.35 3019.02 49.11 N 14.07 W 5993936.64 N 476135.51 E 1.929 -21.60 3115.47 6.250 300.090 3057.02 3113.69 55.31 N 21.24 W 5993942.86 N 476128.36 E 2.605 -20.25 3210.83 6.810 279.200 3151.78 3208.45 58.81 N 31.32 W 5993946.40 N 476118.30 E 2.544 -14.95 19 February, 2003 - 13:28 Page 2 of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-16 Your Ref: API 501032044500 Job No. AKMW30010, Surveyed: 8 February, 2003 ConocoPhillips Western North Slope 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) C/100ft) 3304.74 7.160 261.230 3245.00 3301.67 58.81 N 42.60 W 5993946.44 N 476107.02 E 2.347 -6.43 3399.88 6.790 238.060 3339.46 3396.13 54.93 N 53.23 W 5993942.59 N 476096.37 E 2.962 4.14 3497.02 8.720 230.520 3435.71 3492.38 47.21 N 63.79 W 5993934.90 N 476085.79 E 2.242 17.17 3592.78 11.330 223.560 3530.00 3586.67 35.78 N 75.88 W 5993923.51 N 476073.67 E 3.000 33.79 3688.12 13.180 222.520 3623.16 3679.83 20.98 N 89.68 W 5993908.75 N 476059.82 E 1.954 53.92 3784.45 12.820 221.900 3717.02 3773.69 4.93 N 104.24 W 5993892.75 N 476045.21 E 0.401 75.44 .~ 3880.06 14.380 223.660 3809.95 3866.62 11.56 8 119.52 W 5993876.31 N 476029.87 E 1.688 97.79 3974.53 14.090 223.480 3901.52 3958.19 28.39 8 135.53 W 5993859.53 N 476013.81 E 0.311 120.91 4069.82 16.190 220.670 3993.50 4050.17 46.88 8 152.17 W 5993841.09 N 475997.11 E 2.334 145.60 4165.83 16.100 221.630 4085.72 4142.39 66.99 8 169.74 W 5993821.05 N 475979.48 E 0.293 172.05 4260.90 15.910 221.800 4177.11 4233.78 86.55 8 187.18 W 5993801.53 N 475961.97 E 0.206 198.05 4356.43 15.900 222.130 4268.98 4325.65 106.02 8 204.69 W 5993782.13 N 475944.41 E 0.095 224.03 4451.50 15.830 221.970 4360.43 4417.10 125.328 222.09 W 5993762.88 N 475926.94 E 0.087 249.83 4546.94 15.570 223.260 4452.31 4508.98 144.32 8 239.58 W 5993743.93 N 475909.39 E 0.456 275.50 4643.30 15.110 223.740 4545.23 4601.90 162.82 8 257.12 W 5993725.50 N 475891.79 E 0.495 300.87 4738.51 14.580 223.330 4637.27 4693.94 180.50 8 273.93 W 5993707.87 N 475874.93 E 0.567 325.15 4833.91 13.800 224.530 4729.75 4786.42 197.34 8 290.15 W 5993691.07 N 475858.66 E 0.874 348.44 4929.01 13.320 223.950 4822.20 4878.87 213.32 8 305.70 W 5993675.15 N 475843.05 E 0.525 370.67 5024.59 12.450 224.170 4915.38 4972.05 228.63 8 320.52 W 5993659.88 N 475828.18 E 0.912 391.90 5119.05 11.910 223.280 5007.71 5064.38 243.03 8 334.30 W 5993645.52 N 475814.36 E 0.605 411.74 5214.11 11 .120 223.740 5100.85 5157.52 256.80 8 347.36 W 5993631.80 N 475801.25 E 0.837 430.63 5310.35 11.840 222.020 5195.17 5251.84 270.84 8 360.39 W 5993617.80 N 475788.18 E 0.828 449.67 5404.62 11.710 222.250 5287.46 5344.~3 285.108 373.29 W 5993603.58 N 475775.23 E 0.147 468.77 5500.25 10.850 221.610 5381.24 5437.91 299.02 8 385.80 W 5993589.70 N 475762.68 E 0.909 487.34 --- 5595.71 9.800 221.290 5475.15 5531.82 311.848 397.12 W 5993576.92 N 475751.31 E 1.102 504.30 5690.98 8.920 220.250 5569.15 5625.82 323.57 8 407.25 W 5993565.22 N 475741.15 E 0.941 519.63 5786.82 8.510 220.720 5663.88 5720.55 334.62 8 416.67 W 5993554.21 N 475731.69 E 0.434 534.00 5909.56 8.920 223.080 5785.21 5841.88 348.45 8 429.10 W 5993540.41 N 475719.22 E 0.443 552.45 6002.24 8.700 224.870 5876.79 5933.46 358.66 8 438.95 W 5993530.23 N 475709.34 E 0.379 566.59 6089.76 8.950 226.520 5963.28 6019.95 368.048 448.56 W 5993520.88 N 475699.70 E 0.406 579.99 6150.00 8.950 226.520 6022.78 6079.45 374.49 8 455.36 W 5993514.46 N 475692.88 E 0.000 589.35 Projected Survey 19 February, 2003 - 13:28 Page 3 of4 DríllQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-16 Your Ref: API 501032044500 Job No. AKMW30010, Surveyed: 8 February, 2003 ConocoPhillips Western North Slope All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.61' MSL. Northings and Eastings are relative to 2528' FNL, 1110' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 2528' FNL, 1110' FEL and calculated along an Azimuth of 229.000° (True). Magnetic Declination at Surface is 25.207°(24-Jan-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 6150.00ft., The Bottom Hole Displacement is 589.57ft., in the Direction of 230.566° (True). ~ Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6150.00 6079.45 374.49 S 455.36 W Projected Survey Survey tool program for 35-16 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) '-' 0.00 172.50 0.00 172.50 172.50 6150.00 172.50 Tolerable Gyro 6079.45 MWD Magnetic 19 February, 2003 - 13:28 Page 4 of4 Dri/lQuest 3.03.02.004 Date; 11..Feb..o3 We" Name: Conoco..Phillips Kuparuk 38..16 Number of Samples: 60 Contaot: Do",g Knock D.8crlptlon of Mat.rlal: Core Chip Sampl" Depths: 5912-5972 Sent By: Dave Foster Core Laboratories Received By: 1Lo-r~ oÛ.) From: Core Laboratories eoo W. 58th Ave.. Unit Anchorage, Alaska 98518 D ';¿o2> To: Alaska 011 & Gas Cons. Commission 333 W. 7th #100 Anchorage, Alaska 99501 907..279..1433 (JOr ~f FEf3 1 "j 200,3 Alaska Oil & Gas Gons. Commission Anchorage . Å -5"~ r( #/1l( )1 - RECEIVED / C(ß£AB " . ,~ " ~~t~1 ,.~1?9~r:i'lqri~!"c·"~I,,~, ) \, Alaska Oil & Gas l\ncho :.'':;:'/E; Co;;rniss¡o RL T Iskad 1=[8 0 ,5 2003 Greater CPAI Drilling ~~ t'." t ,u ~\ ~ '>r. t.. ¡ ~,If f" r ~ ~r I""" ¡I '1' i~ tl~" Kuparuk Team Leader ~ '- / R. Thomas RE l ~ Sincerely, If you have any questions regarding n lieu of a cement bond log in the 7" casing, ConocoPhillips proposes to perform a wellbore temperature survey after an initial water injection period (probably 15 days) A cement bond log will be performed inside the 3 %" liner prior to perforating the wel this matter, please contact Scott Lowry at 265-6869. /' Upon drilling out the 7" casing shoe, it is proposed to drill 2-3' of new hole prior to conducting a leak-off test to prevent drilling into the Kuparuk "C" sand prior to obtaining an acceptable leak-off test. The leak-off test will be taken to a maximum of / 12.5 ppg equivalent mud weight (EMW). The 7" casing was set above the Kuparuk "C" sand at 5907' MD I 5839' TVD (approximately 10' above the "C" sand). The casing was cemented with 185 sacks of 91á~ "G" with additives mixed at 15.8 ppg. The estimated top of cement is at sf QrMD. 6 1/8" hole will be drilled to the oriœnally planned total depth, and a 3 %" ~ ppf L-80 SLHT production liner will be~ and cemented. Top of the liner will be at approximately 5757' MD (150' liner overlap). / /' The proposed changes from ConocoPhillips Alaska, Inc. submits the attached Application for Sundry to change original approved program for Kuparuk well 3S-16. the approved program are as follows the /' Dear Subject: Commissioner: Application for Sundry for 3S-16 (203-007) Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 ) ConocriP'hillips February 3. 2003 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ) Randy Thomas Greater Kuparuk Team Leader Drilling & Wells Form 0-403 Rev 06/15/88 ryaoMS 8Fl ORIGIN^l SIGNeD C~· M l. am \ FEB 2003 SUBMIT IN TRIPLICATE Approved by order of the Commission ('\ Vev 74 FOR COMMISSION USE ONLY Notify Commission so representative may witness Plug integrity _ BOP Test_ Mechanical Integrity Test_ A1tL l.~~o3oéù ç.¡:T Commissioner Location clearance I J 1 Subsequent form required 1 0- ~ Ð ..J-e4 it~ t~tb~ì'~:t- ~~I/.(J Date Approval no. . 0 -.'::? d 3C' ::s - .. - .J (- tz/7 f ? Conditions of approval: Signed ..... \ <- ~.L~ .~~ R. Thomas ~-""""- \ -¿/S/03 Date Prepared by Sharon Allsup-Drake \~ Name of approver Winton Aubert 17. I hereby certify that the foregoing is ~ '1 \¡..J6k Oil j February f, 2003 Date approved Service _XX rue and correct to the best of my knowledge. Title: Kuparuk Drilling Team Leader Questions? Call Scott Lowry 265-6869 6. 13. Attachments 14. Estimated date for If proposal was verbally approved Description summary of proposal commencing operation February 3, 2003 Gas_ Detailed operations program 15. Status of well classification as: Suspended _XX BOP sketch _ t¡as GommissiŒ"' ¿\n:ChOfd98 Packers & SSSV type & measured depth) None !\!aska Oil & Tubing (size, grade, and measured depth true vertical None None l'-'I:~r3 o 5 200,3 Perforation depth: Effective depth: Casing Conductor Surface Production measured true vertical measured true vertical Length 108' 25311 5879' None At total depth 398' FSL, 1578' FEL, Sec. 18, T12N, R8E, 2. Present well condition summary Total depth: measured UM 5907 5839 5823 5755 Size 16" 9.625" 7" Field/Kuparuk River Oil Pool True vertical Depth 108' 2559' 5839' RECf feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured Depth 240.5 sx Arctic Crete 108' 440 sx AS IllLite, 240 sx LiteCrete 2559' 185 sx Class G 590T "l E· [' \'" ) (as proposed) 11 Kuparuk River P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2528' FNL, 1110' FEL, Sec. At top of productive interval 2362' FSL, 1560' FEL, Sec. 18, At effective depth Development _XX Exploratory Stratigraphic _ Service _ 8, T12N, R8E, UM (asp's: 476149, 5993887) T12N, R8E, UM (as proposed)) 50-103-20445 Field I Pool Kuparuk River Unit 8. Well numb~ 3S-16 9. Permit num»er I approval number 203-007 / O. API number ) ) . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon _ Suspend _ Operational shutdown _ Alter casing _ Repair well _ Plugging _ Change approved program _XX Pull tubing _ 5. Type of Well: 2. Name of Operator ConocoPhillips Alaska, 3. Address Inc. 7. Unit Re-enter suspended well _ Time extension _ Stimulate _ Variance _ Perforate _ 6. Datum elevation (DF or KB feet) RKB 28 or Property name Type,~f request: Other _ INGA- Z-/S/0'3 I^ t.A? ')..( r¡ ð 'J {)1s ~J7(00 Scott Lowry 02/03/03 Production Liner 3-1/2" 9.3# L-80 SLHT (6237' MD /6155' TVD) ..... ~../ 3-1/2" Baker Landing Collar 2 jts 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe C Sand Perfs (to be done after rig moves off) ~ ~ ~ ~ ~ þ ~ þ / 3-1/2" 9.3# L-80 SLHT liner as needed Baker 20' Seal Bore Extension XO Sub, 5" Stub Acme box x 3-1/2" SLHT pin , Intermediate csg. I 7" 26.0# L-80 BTCM (5907' MD / 5839' TVD) - Liner Assembly (run on drillDiDe), 150' of liner overlaD Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock' Liner Hanger /' /" Surface csg. 9-5/8"40# L-80 BTC (2559' MD / 2559' TVD) 16"x30" nsulated conductor @ +/- 108' MD r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ...-:¡~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ .,/ .Ji ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ... ... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ..- 4-112" Baker GBH-22 casing seal assembly w/12' stroke, 3-1/2" L-80 EUE8RD box up t 3-1/2" 9.3# L-80 EUE8RD tubing 5.125" x 3" Baker locator sub 3-1/2" Cameo IDS' nipple w/2.813" No-Go profile t 3-1/2" 9.3# L-80 EUE8RD tubing Valve #5: 3-1/2" x 1-112" 'MMG' GLM w/ DCR Dump Kill Valve (3000 psi casing shear). 6' L-80 handling pups installed on top and bottom of mandrel. to tubing ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ .... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ !'.. 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down Special Drift 2.91 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required Special Drift 2.91" 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface Special Drift 2.91" 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. KRU 35-16 njecJr Proposed Completion Schematic T QPset Case Contingency G ~p. ..... ··h·· ····1·11'· onoco¡:'!; 'I. . .lpS ) of2 2/5/2003 1:40 PM > we > > > Is this > discuss > discuss acceptable this, this. submit it. to you as proof of isolation? If you would I can get Randy and Chris together this afternoon If this is acceptable, we can include this in the Please let me know what you think like to and we can 403 before > The maximum BHP when the well is on injection is likely to be around 4500 > psi (14.7 ppg EMW). If we take the leak-off test to a minimum of 15.0 ppg > EMW, this should provide fairly conclusive evidence of isolation > comments > > > well > > Normally, when we set > the liner. In th se > shoe and the top ~ > isolation by bond l~gg > casing. > > I believe we can prove > the following: > > - Good cement job > aspects) > - Good leak-off below) Bond log ran inside the 3 1/2 " liner after the rig moves off the test upon drilling out the 7 casing shoe (see on the 7 " casing as described above (operational isolation ""f zone "" ing these wells, we will only This raises the liner only, without a bond log of we run a cement quality log inside have about 10' between the 7" casing the question of whether we can prove or do we need to bond log the 7" the 7 " casing with > We ran our 7 > full returns, > We should get casing to bottom yesterday and the cement pipe reciprocation throughout job drilled out tomorrow > Winton > job went plug bumped, we 11 (i. e floats held) Scott L Lowry wrote Winton Aubert AOGCC 793-1231 Thank you for the 3S-16 update. For injection wells, AOGCC regulations require a cement quality log and a demonstration of mechanical integrity prior to injection. In lieu of a cement bond log in the 7" casing, the Commission will accept a well bore temperature surveyor water flow log performed after an initial water injection period, which is usually fifteen days. With your forthcoming Form 10-403, please specify your chosen cement quality log, a description of 3S-16's alternate casing program (the 3-1/2" liner was not originally approved), and an acknowledgment of the drill-out depth (prior to FIT) variance All other 3S-16 (PTD 203-007) permit stipulations apply Scott Subject: Date: From: Organization: To: CC: Re: 3S-16 Progress Over Weekend Mon, 03 Feb 2003 13:41:19 -0900 Winton Aubert <Winton _ Aubert@admin.state.ak.us> AOGCC Scott L Lowry <Scott.L.Lowry@conocophillips.com> Camille 0 Taylor <cammy_taylor@admin.state.ak.us> Michael L Bill <mike _ bill@admin.state.ak.us>, Daniel Seamount <dan _ seamount@admin.state.ak.us> R~(3 3-16 Progress Over Weekend ) ) ~e;,3S-16 Progress Over Weekend ) > Thanks, > > Scott L Lowry > Drilling Engineer > ConocoPhillips Alaska Inc > Voice: 907-265-6869 > Cell; 907-240-5322 > E-Mail scott.l.lowry@conocophillips.com 20f2 2/5/2003 1:40 PM ) Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section cc: BY ORDER OF THE COMMISSION DATED thisl3~day of January, 2003 Michael L. Bill Commissioner Sincerely, Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Enclosed is the approved application for permit to drill the above referenced development well. Dear Mr. Kuparuk River Unit 3S-16 ConocoPhillips Alaska, Inc. Permit No: 203-007 Surface Location: 2528' FNL, 1110' FEL, Sec. 18, TI2N, R8E, UM Bottomhole Location: 398' FSL, 1578' FEL, Sec. 18, TI2N, R8E, UM Thomas: !Æl!Æ~~~!Æ AIIA.SIiA. OIL AND GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team· Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510-0360 Re: 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 ~1r~1JŒ E~ ) FRANK H. MURKOWSKI, GOVERNOR ) e 1 Alaska OB & Gas Cons. Commission Anchorage ~ ~ ""~ Randy Thomas GKA Drilling Team Leader JAN 0 9 2003 RECE , VED Sincerely, If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Please find attached for the review of the Commission the information / ConocoPhillips Alaska, inC. hereby applies for a Permit to Drill an onshore service well development well. required by 20 ACC 25.005 (c) KRU 3S-16, a Dear Commissioner Taylor: Re: Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Application for Permit to Dri njector 3S-16 January 8, 2002 Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com ¥.. ) COnocoPhillips ) Form Approved by 0-401 Permit Number I API number c:.J .:z.o$-~7 50-103-26/CzlS Conditions of approval Samples required DYes JZI No Mud log required Hydrogen sulfide measures D Yes ~ No Directional survey required Required working pressure for BOPE D2M; D 3M; D 5M; D 10M; D ~ther: p it'( .~C' ~~C ~ZS~ '-Ì i~L ( b )1'_ tJ Q.t:~.e..~... ðef~'-' r'-l.rJ ~L,~h.L ~lt~\...t- : ~ ,:,...: 4PfH'~\i(M..l r-c:·6"'Y.;N-d ~~'( t\.{~'~''''''''j..-tt. C~W"'1 rY"~rtitM.,~, by order of Commissioner the commission Rev. 12/1/85 · OnlGINAI SIGNFO BY ML sm c V· J L !XI Yes D'T€st- ; Þ¡,.t V t J , 'lL ~~ " I ' 17-; Submit ~ee cover letter for other r~quirements Yes Q(I No D No B:7 ¡)E tt7 S'OOC ~'Ç. ì J-A ~T) c'Ul t .Zr,(l\-li t( D:': ~ t-<Õ -'li6fo J in triplicate Commission Use Only I Approval date R. ~ Date l (-t lð3 PrAn::JrArl hv Sh::Jmn AII!';t m-nr::JkA 21 Signed Attachments Filing fee 0 Drilling fluid program 0Time vs depth plot hereby certify that the foregoing is true and correct to . \ \~ Property Plat D Qefraction analysis the best of my knowledge Title: Kuparuk Drilling Team Leader BOP Sketch D D Seabed Diverter Sketch D Drilling program 0 report D 20 AAC 25.050 requirements 0 Questions? Call Scott Lowry 265-6869 20. Alaska Oil & Gas Cons i\nchoraQ8 Perforation depth: rue vertical measured Commission JAN 0 RECE 9 2003 VED Casing Conductor Surface Production Length Size Cemented Measured depth True Vertical depth Effective Depth: measured rue vertical measured rue vertical feet feet feet feet Junk (measured) 9. To be completed for Red rill , Re-entry, Present well condition summary Total Depth: Plugs (measured) Hole 42" 2.25" 8.5" Casing 16" 9.625" 7" Weigh 62.5# 40# 26# and Deepen Operations. Specifications Grade Coupling H-40 Weld L-80 BTC L-80 BTCM Length 80' 2538' 6109' MD 28' 28' 28' TVD 28' 28' 28' MD 108' 2566' 6137' TVD 108' 2566' 6058' 480 sx AS Lite & 220 sx LiteCrete 300 sx Class G /. Quantity of Cement (include stage data) 9 cy High Early V" Kickoff depth: 8. Casing program size Top 2448 7. Anticipated pressure (see 39 AAC 25.035 (e)(2)) Maximum surface 2977 psig At total depth (TVD) 3620 psig Setting Depth Bottom 1578' FEL, Sec. 2. Distance to nearest property I 2362' @ Target 6. To be completed for deviated wells 2650 MD 8, ine Maximum hole angle T12N, Rl 'M I 13'~~1¡;~' r""~t?nce to nearest well @ 41' @ 200' 14° ./ feet 9. Approximate spud date January 20, 2003 4. Number of acres in property 5. Proposed depth (MD and TVD) 6137' MD 16058' TVD work: Re-entry Name of Operator ConocoPhillips Alaska, 3. Address P.O. Box 100360 Anchorage, :4. Location of well at surface 2528' FNL, 1110' FEL, At top of productive interval 2362' FSL, 1560' FEL, At total depth 398' FSL, Amount $200,000 Sec. 18, T12N. R8E, UM 8. Unit or property Name Kuparuk River Unit Well num~v 3S-16 Number #59-52-180 Sec. 18, T12N. R8E, UM 7. 11 . Type Bond Statewide (see 20 AAC 25.0251) 2. AK 99510-0360 Drill ~ Redrill DDeepen D D 6. Property Designation ADL 380107 ALK 4624 b. Type of well. Exploratory Stratigraphic Test Service 0 Development Gas Single Zone 5. Datum elevation (OF or KB) RKB = 28' u o U D Development Multiple Zone 10. Field and Pool Kuparuk River Field Oil Kuparuk River Oil U D Pool a. Type of PERMIT TO DRILL 20 AAC 25.005 ,) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) \{J6 Æ ( 18f () '5 o I~"ì Î ~í nJAL 38-16 PERMIT IT. DOC Page 1 of 7 Printed: 8-Jan-03 13. Proposed Drilling Program 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) 6 6 .6 . Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) 6 6 11 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) 6 6 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) 5 5 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) 4 .4 4 .4 6. Casi ng and Cementing Program ........... ..................................................................4 Requirements of 20 AAC 25.005(c)(6) . ........................................................ ........ ......................... ......4 5. Procedure for Conducting Formation Integrity Tests........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ......................................................3 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) 3 .3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ..... .......................................................................3 Location Summary 2 Requirements of 20 AAC 25.005(c)(2) ................ ................................................................................... 2 Requirements of 20 AAC 25.050(b) .2 2 Well Name Requirements of 20 AAC 25.005 (f) 2 2 1 Table of Contents Application for Permit to Drill Document Perm it It - Kuparuk Well 38-16 ') Applir.ation for Permit to Drill, Well 3S-16 ) Revision No.O J Saved: 8-Jan-03 ORIG , If ", ¡ iVAL 38-16 PERMIT IT. DOC Page20f 7 Printed: 8-Jan-03 Please see Attachment 1 Requirements of 20 AAC 25.050(b) If a weir is to be intentionally deViated, the application for a Permit to Dnll (1'0/77110-401) must (1) /ì7C/ude a plat drawn to a SlIftable scal<> Showing the path of the prOPOsed wellbo",- induding all adjacent wellbores WiWn 200 feet of any portion of tile proposed welt Directional Plan and (0) other information reqwi-ed by 20 AAC 25.0S0(b); 6137' 6058' 6002' Location at Total NGS Coordinates Northings: 5,993,460 Eastings: 475,662 I I I Sec 18, T12N, R8E, UM Measured Depth( RKB: Total Vertical Depth/ RKB: Total Vertical Depth/55: Depth Eastings: 475,700 398' FSl, 1578' FEl, I I I Measured Depth( RKB: Total Vertical Depth/ RKB: Total Vertical Depth, 55: 5910' 5838' 5782' Location at Top of Productive Interval (Kuparuk "c" Sand) NGS Coordinates Northings: 5,993,500 2362' FSl, 1560' FEL, Sec 18, T12N, R8E, UM Eastings: 476,150 1110' FELr l T12N, R8E, UM RKB Elevation Pad Elevation 56.1' AMSL 28.0' AMSL I I Location at SUrface NGS Coordinates Northings: 5,993,888 Sec 18, location Summary Requirements of 20 AAC 25.005(c)(2) An appb,-aöon for a Permit to Drill must be accompanied by eacli of tfle folloWing items. except for an item already on file WiIt1 commi..c,:,'/on and Identitìed li7 the application: (2) a plat Identifying the proÞerty and the PfOþerty's owners and Sliowing (A)the roOrdinates of the propoSed location of the well at tfle sUrface, at the top of eadJ objective formation, and at total deptli, referenced to lJovemmental seäion line!;.... (B) tfle Coordinates of llie PfOþO.Sed location of lt1e Well at llie surface, referenced to tfle slate plane coordinate system for tfI/s state as maintained by the National Geodelic Survey In tlie National Oceanic and Afmosplien'c Adminrstration; (C) tfle proPOSed depth or the We/I at lt1e top of eacli objective formaóon and at total deptll; 2528' FNL, the 2. Well Name Requirements of 20 AAC 25.005 (f) EadJ well must be identified by a unique name designated by the operator and a unique API number as.<igned by the commission tinder 20 Me 25. 04O(b). For a well With mult/ple Well brandJes. each branc/¡ mtlsl similarly be /dentiTied by a unique flame and API number by adding a S1Jffìx to tIle name designated for the well by Ifle operator and to the number a'<;s!'l/Ied to the well by tfle COfliflii.."iSiofl. The well for which this application is submitted will be designated as 3S-16 1 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards................ Attachment 3 Well Schematic................ 7 7 .6 .6 14. Discussion of MUd and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c}(14) ........._................... 7 Requirements of 20 AAC 25.005 (c)(13) ) 6 Applic§ltion for Permit to Drill, Well 3S~16 ) Revision No.O ... Saved: 8-Jan-03 ORiG A procedure is on file with the commission for performing LOT's. For 3S-16 the procedure will be followed with one exception. The surface casing shoe will be pressured until leak-off occurs and the 16.0 ppg EMW maximum will not be observed. (see step 6 in the procedure) r ~.JA L ¡ r:~· 38-16 PERMIT IT. DOC Page 3 of 7 Printed: 8-Jan-03 Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill mllst be accompanied by each of'the following item~ commission and IdentIfied in the application: (5) a description of the procedure for conducting formation integrity test';, as required under 20 MC 25.030(f); except for an item already on ft1e wIth the 5 Please see Attachment 2 and (C) data concerning potentli:JI causes of 170le problems such as abnormally geo-pres!;;ì..lred stratal 105t circulation zoneSr and zones that have a propensity for differential stickti7g; Drilling Hazards Summary The well bore is not expected to penetrate any gas zones. (B) data 0/7 potef7t/~71 gas zones/' The maximum potential surface pressure (MPSP) while drilling 3S-16 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5838' tvd: MPSP =(5838 ft)*(0.62 - 0.11 psi/ft) = 2977 psi / A pressure build-up test performed on Palm 1A (3S-26)~'~19... 1 indicated a reservoir pressure in the Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft or~pg EMW (equivalent mud weight). Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be acc;ompanied by each of the tollowing Item5~ C()mmi5:.c,ion and identitied in the application: {4} infolmation on drilling hazard~ including (A) the maximum downhole pressure that may be encounterect pressure based 0/7 a methane gradient; cntetia used to determine it except tor an item and maxtlnum potential ::;"urface already on file with the 4. Blowout Prevention Equipment Requirements of 20 AAC 25.005(c)(3) An application for a Pel717it to Drill must be ac:r;ompanied by each of the following ItemSr except for an Item already on file with the commission and identified in the applìc.ì:.7tion: (3) a dt~7gram and description of'the blowout prevention equipment {BOPE} as required by 20 AAC 2.'i,035r 20 AAC 25.036r or 20 AAC 25.037; as ðpp/ìcable/ /' Please reference BOP schematics on file for Nabors 7ES. 3. nformation The Applicant is the only affected owner. and (2) for all wells witt7in 200 feet of the proposed wellbore (A) I/":'t the names of the operators of those well.,,~ to tl7e extent that tl70se names are known or discoverable li7 and show that each named operator has been furnished a copy of the application by certified ma/¿' or (8) state that the applicant is the only affected owner. public recordSr ') Applir..ation for Permit to Drill, Well 3S-16 ) Revision No.O .. Saved: 8-Jan-03 ORIG ~!II, ~AL j JV ~ 3S-16 PERMIT IT. DOC Page 4 of 7 Printed: 8-Jan-03 Drilling will be done using mud systems having the following properties Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to 01711 must be accompanied by each of the following item:,~ commission and Identified in the application: (8) a drilling flUId program" including a diagram and description of the drilling fluid system, as required by 20 MC 25. 033,,· except for an item already on file WItt] the 8. Please reference diverter schematic on file for Nabors 7ES. /' Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applk-ation for a Peli17it to Drill must be accvmpanied by each of the fallowing Item5~ Item cvmmission and identified in the application: (7) a dI~îgram and description of the diverfer system as required by 20 AAC 25. 035, unless thi'i æqukement is waived by tl1e commi'isiol7 under 20 AAC 25.035(11)(2); except far an already on tile with the 7. If 7" casing must be top-set above the Kuparuk C sand, a 3 '/2" production liner will be used and an exception to 20 AAC 25.412 (b) is requested. The distance between seals at the top of the 3 '/2" liner and the top perforation will exceed 200' MD. In the top-set case, the distance between the seals and the top perforation will be "'400' MD. An adequate leak-off test of the 7" casing shoe, combined with a cement bond log of the liner section below the 7" casing shoe will provide proof of zonal isolation between the seals and the perforated interval. ~ 3-1/2 9.3 L-80 EUE 8rd Mod 5532' 28' / 28' 5560'/5498' SAB- 3 packer set at 5560' MD 7 8-1/2 26 L-80 BTC-Mod ../ 6109' 28'/28' 6137'/6058' Lead: 480 sx 10.7 ppg AS Lite Tail: 220 sx 12.0 ppg 'LiteCRETE'. (Yield=2.40 cuft/sk) Planned TOC=Surface 300 sx 15.8 ppg 'G' w/ ~~~ned TOC~ MD ~ 9-5/8 Casinq and Cementinq Proqram Hole , Size Weight ./ (in) (Ib/ft) Grade 42 62.5 H-40 CsgíTbg 00 (in) 30 X 16 Insulated 12-1/4 40 L-80 BTC / Connection Welded 2538' Length (ft) 80 28'/28' Top MOíTVD (ft) 28 / 28 2566'/2566' Btm MDíTVO (ft) 108 / 108 Cement Program 9 cy High Early 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 Ule tollowing Item5~ commission and identified in the applk<'1tion: (6) a mmplete proposed cafJing and cementing progré.1fl7 as required by 20 MC 25. 030" and a description pedorated line~ or screen to be Ìf7stallect' olany slotted line~ pre- except for an item already on file with the 6. ) Applie.¡3.tion for Permit to Drill, Well 35-16 ) Revision No.O . Saved: 8-Jan-03 OR Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a PermIt to Onll must be accompanied by each of the following items, except for an item already on file wIth the commission and Identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as reqwì'ed by 20 AAC 25. 033(f); N/A - Application is not for an exploratory or stratigraphic test well r ~ I' ,~ fi U r. ~ !t , .;' {~ ¡¡ i ;,1 d fJ , ìA 1";~ ...\ '\ L 3S-16 PERMIT IT.DOC Page 5 of 7 Printed: 8-Jan-03 9. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033 Diagram of Nabors 7ES Mud System on file. 11-15 9.5 40-55 Production Hole mud properties initial Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) 10 second Gel Strength (lb1100 sf) 10 minute Gel Strength (lb1100 sf) pH API Filtrate(cc) Solids (%) 9-9.5 <6 6-11 9-9.5 <6 9-14 9-9.5 <6 1 0-15 9-9.5 <4 1 0-15 9-9.5 <4 15-1 9 4-10 7-10 7-112 7-12 8-16 2-5 3-6 3-6 4-7 4-8 6-12 8-15 8-16 8-18 15-25 20-25 C40 10.2 42-55 20-25 Top Morraine 10.6 42-58 20-25 Top HRZ 10.8 42-58 20-25 KUr;Ja1~ r1·2.~ ~58 API Filtrate(cc) Solids (%) *9.4 35-55 Sulface Hole mud properties Spud to Base of Permafrost Initial Value Final Value 8.6 9.0-9.2 120-150 120-150 ) Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) 10 second Gel Strength (lb1100 sf) 10 minute Gel Strength (lb1100 sf) pH 3-7 if hydrates are encountered 8.5 - 9.5 12-15 8.5- 9.5 <10 6-12 8.5 - 9.5 <10 6-12 8.5 - 9.5 <10 6-12 25-55 25-55 25-50 25-50 0-30 0-30 1 0-30 1 0-30 8-15 11-22 15-30 15-30 30-40 30-40 Base of Permafrost to Total Depth Initial Value Final Value .<9.4* ~9.4* 20-150 120-150 APPlk~~,tion for Permit to Drill, We1l3S-16 ) Revision No.O . Saved: 8-Jan-03 35-55 OR ' :'"", ¡ .!\J A L I (;i' i:, /1 38-16 PERMIT IT. DOC Page 6 of 7 Printed: 8-Jan-03 Note: If the 7" 26# L-SO BTCM casing must be top-set above the Kuparuk C sand, 6 lIS" hole will be drilled to total depth according to the directional plan and a 3 112" 9.3# L-SO SLHT liner will be ran and cemented across the productive interval. The cement bond log will be done after moving the rig off the well. / is 1. MIRU Nabors 7ES./ / 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/S" surface casing point according to directional plan equipment required. /,e 4. Run and cement 9-5/S" 40#, L-SO BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform top job. Install and test BOPE to 5000 psi. ""Íest casing to 2500 psi. 5. Drill out cement and 20' of new hole. Perform LOT. 6. Drill S-1/2" hole to total depth according to directional plan. Run LWD logging equipment with /' GR, resistivity, and density-neutron. Run 7" 26# L-SO BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped for isolation in accordance with 20 MC 25.030(d)(3)(C). A cement bond log will be performed prior to perforating the well. 7. Run 3-1/2" 9.3#~~~~rd EUE Srd-Mod completion assembly wI SAB-3 permanent packer and ..,,/ PBR. Set packe ~bove top planned perforation, shear out of PBR, P/U tubing hanger, and land tubing. Pre re test tubing to 3500 psi. Pressure test 3 112" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. Set TWC and ND BOPE. Install and pressure test production tree. Freeze protect. Secure well. Rig down and move out. / '. Handover well to Operations Personnel. S. 9. 10. No LWD logging The proposed drilling program 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Dlill must be accompanied by ead} commission and Identified in the application: isted below. Please of the following item!J~ refer as well to Attachment exæpt for an 3, 'tern Wel already on Schematic. fl/e with the 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the f'ollowing Items,. except f'or an iÜ?m commission and Identified in the appliœtion: (12) eVIdence showing that the requirements of 20 MC 25,025' (Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission already on flÏe with the 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill mu!:>t be acr;ompanied by eac17 of the following Jtem5~ with c:vmmission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic retraction or reflection analy~is as required by 20 MC 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 for a Pem7lt to Drill must be accompanied by eaä7 of the following item!:>:, commission and identified in the application: (1.1) fvr a well cililled fi-om an offsfJOre platfvrm/ mobile bottom-founded structure/ jack-up rig/ or of seabed conditions as required by 20 MC 25", 061 (b)/ NIA - Application is not for an offshore well. floating drilling vessel, exæpt for an an analysis tem already on file with the exc.-ept tÖr an item already on file tfle ') APPlil\')tion for Permit to Drill, We1l3S-16 Revision No.O Saved: 8-Jan-03 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. ORIG R~'~'A,' L I ¡, .. 38-16 PERMIT IT. DOC Page 7 of 7 Printed: 8-Jan-03 At the end of drilling operations, an application may be submitted to permit 35-16 for annular pumping of fluids occurring as a result of future drilling operations on 35 pad. Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 35 pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 35 pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. / 14. Discussion of Mud and Cuttings Disposal and Annular Disposa Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following item~ except for an item ala?ady on file with the commiS!:>1on and identified in the application: (14) a general desì.YliJtion of flOW the operator pk:.ms to dit;pose of drilling mud and cutting."; and a statement operator intend; to request authorization under 20 AAC 2.S~080 for an annular disposal operation 1i7 the well., ), Applk~~tion for Permit to Drill, We1l3S-16 ) Revision No.O Saved: 8-Jan-03 of whether the , .-", Sperry-Sun Drilling Services ConocoPhillips Western North Kupa '-' CJ ::-1;:) ~~:r..oõ..,._~ oposal Report !::'J ~ rr_:._,_"3 - --~ ~-- 8 January, 2003 ~-'~~ r-- Your Ref: Kickoff Below Surface Csg... Build & Hold to 140 Surface Coordinates: 5993887.51 N. 476149.55 E (70023' 39.9479" N. 150011'38.5965" W) Grid Coordinate System: NAD27 Alaska State Planes. Zone 4 Kelly Bushing: 56. 10ft above Mean Sea Level -- SpElr'r'Y-SLI ! afJn;;:¡;:ì:;fI:iI~'::'¡I:;I:!!;2::t:C;;I:. juì¡¡ì¡ì~ O:tripmf Proposal Ref: pro 10006 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-16 Plan - 35-16 (wp05) Your Ref: Kickoff Below Surface Csg... Build & Hold to 14° ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -56.1 0 0.00 0.00 N 0.00 E 5993887.51 N j 0.00 SHL (2528' FNL & 1110' FEL, SEC 18- T12N - R8E) 100.00 0.000 0.000 43.90 100.00 0.00 N 0.00 200.00 0.000 0.000 143 .90 200.00 O.OON 0.00 300.00 0.000 0.000 243.90 300.00 0.00 N 0.00 400.00 0.000 0.000 343.90 400.00 0.00 N 0.00 500.00 0.000 0.000 443.90 500.00 7.51 N 476149.55 E 0.000 0.00 ..~ 600.00 0.000 0.000 543.90 600.00 87.51 N 476149.55 E 0.000 0.00 <:::) 700.00 0.000 0.000 643.90 700.00 993887.51 N 476149.55 E 0.000 0.00 800.00 0.000 0.000 743.90 800.00 5993887.51 N 476149.55 E 0.000 0.00 ::::0 900.00 0.000 0.000 843.90 900.00 5993887.51 N 476149.55 E 0.000 0.00 ---- 1000.00 0.000 0.000 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 ~ 1100.00 0.000 0.000 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 ---- 1200.00 0.000 0.000 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 ~ 1300.00 0.000 0.000 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 ._~ 1400.00 0.000 0.000 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 );~ r-- 1500.00 0.000 0.000 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 --=-1546.10 0.000 0.000 O.OON 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 B. Permafrost 1600.00 0.000 0.000. 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 1700.00 0.000 "Ô~ôOÓ" 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.000 0;00 1800.00 0.000 ',0;090 ' 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 1900.00 0.000 0.000 1843.90 1900.00 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 2000.00 0.906' '0.006 1943.90 2000.00 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 2011.10 0.000 0.000 1955.00 2011.10 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 T. WestSak 2100.00 0.000 0.000 2043.90 2100.00 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 2200.00 0.000 0.000 2143.90 2200.00 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 "-- 2300.00 0.000 0.000 2243.90 2300.00 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 2400.00 0.000 0.000 2343.90 2400.00 O.OON 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 2456.10 0.000 0.000 2400.00 2456.10 O.OON 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 B. West Sak 2500.00 0.000 0.000 2443.90 2500.00 O.OON 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 2566.00 0.000 0.000 2509.90 2566.00 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.000 0.00 9-5/8" Csg Pt ... Drill out 8-1/2" Hole 2566.00ft MD, 2566.00ft TVD 9 5/8" Casing 8 January, 2003 - 7:25 Page 2 of6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-16 Plan - 35-16 (wp05) Your Ref: Kickoff Below Surface Csg... Build & Hold to 140 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 2600.00 0.000 0.000 2543.90 2600.00 0.00 N 0.00 E 5993887.51 0.00 2650.00 0.000 0.000 2593.90 2650.00 0.00 N 0.00 E 5993887.51 0.00 Begin Dir @ 3.00/100ft : 2650.00ft MD, 2650.00ft TVD 2666.10 0.483 330.000 2610.00 2666.10 0.06 N -0.01 C-80 (K-10) 2700.00 1.500 330.000 2643.89 2699.99 0.57 N -0.12 2800.00 4.500 330.000 2743.75 2799.85 5.10 N -1.12 2816.67 5.000 330.000 2760.36 2816.46 6.29 N 476145.94 E 3.000 -1.39 End Dir, Start Sail @ 5.0° : 2&~7 MD, 2816.46ft TVD 2900.00 5.000 330.000 2843.37 2899.47 476142.32 E 0.000 -2.77 3000.00 5.000 330.000 2942.99 2999.09 476137.99 E 0.000 -4.44 3016.67 5.000 330.000 2959.60 3015.70 476137.27 E 0.000 -4.71 Begin Dir @ 2.00/100ft : 3016.67ft MD, 3015.70ft TVD C) 3100.00 4.315 311 .1 53 3042.66 16.53 W 5993914.16 N 476133.11 E 2.000 -4.98 ::t:; 3200.00 4.276 284.211 22.97 W 5993917.57 N 476126.67 E 2.000 -2.34 --- 3300.00 5.093 261.628 30.98 W 5993917.87 N 476118.67 E 2.000 3.53 C~') 3400.00 6.448 246.854 40.54 W 5993915.04 N 476109.10 E 2.000 12.61 -tl 3500.00 8.075 237.580 51 .63 W 5993909.11 N 476097.99 E 2.000 24.90 ~..............~ 3600.00 9.839 231.500 64.24 W 5993900.06 N 476085.35 E 2.000 40.39 ~--~--:~':'.A ~ t~p37 .71/ """- 3700.00 11 .679 2?7,.?ßß.< 3693.87 0.16 N 78.37 W 5993887.92 N 476071.18 E 2.000 59.04 ,,£~ r-- 3800.00 13.564 224:216' 3735.35 3791.45 15.11 S 93.99 W 5993872.70 N 476055.52 E 2.000 80.85 3829.71 14.130 223.4;f?0 3764.20 3820.30 20.24 S 98.91 W 5993867.59 N 476050.58 E 2.000 87.93 End Dir, Start Sail @ 14.13° : 3829.71ft MD, 3820.30ft TVD 3900.00 14.130 223.4q() 3832.36 3888.46 32.70 S 110.71 W 5993855.17 N 476038.73 E 0.000 105.01 4000.00 14.130 223.460 3929.34 3985.44 50.41 S 127.50 W 5993837.50 N 476021.88 E 0.000 129.30 4100.00 14.130 223.460 4026.31 4082.41 68.13 S 144.30 W 5993819.84 N 476005.04 E 0.000 153.60 4124.43 14.130 223.460 4050.00 4106.10 72.46 S 148.40 W 5993815.52 N 476000.92 E 0.000 159.54 C-40 (K-3) --- 4200.00 14.130 223.460 4123.29 4179.39 85.85 S 161 .09 W 5993802.17 N 475988.19 E 0.000 177.90 4300.00 14.130 223.460 4220.26 4276.36 103.57 S 177.88 W 5993784.50 N 475971 .34 E 0.000 202.20 4400.00 14.130 223.460 4317.23 4373.33 121.29 S 194.67 W 5993766.84 N 475954.49 E 0.000 226.50 4500.00 14.130 223.460 4414.21 4470.31 139.01 S 211.47 W 5993749.17 N 475937.64 E 0.000 250.80 4600.00 14.130 223.460 4511.18 4567.28 156.73 S 228.26 W 5993731.51 N 475920.79 E 0.000 275.09 4700.00 14.130 223.460 4608.16 4664.26 174.45 S 245.05 W 5993713.84 N 475903.95 E 0.000 299.39 4800.00 14.130 223.460 4705.13 4761.23 192.17 S 261.84 W 5993696.17 N 475887.10 E 0.000 323.69 4900.00 14.130 223.460 4802.11 4858.21 209.89 S 278.63 W 5993678.51 N 475870.25 E 0.000 347.99 8 January, 2003 - 7:25 Page 3 of6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-16 Plan - 35-16 (wp05) Your Ref: Kickoff Below Surface Csg... Build & Hold to 14° ConocoPhil/ips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 5000.00 14.130 223.460 4899.08 4955.18 227.61 S 295.43 W 5993660.84 372.29 5100.00 14.130 223.460 4996.06 5052.16 245.33 S 312.22 W 5993643.18 396.59 5200.00 14.130 223.460 5093.03 5149.13 263.05 S 329.01 W 5993625.51 N 420.88 5258.75 14.130 223.460 5150.00 5206.10 273.46 S 338.87 W 5993615.13 N 435.16 Top Morraine 5300.00 14.130 223.460 5190.00 5246.10 280.77 S 345.80 W 599 4N 445.18 5400.00 14.130 223.460 5286.98 5343.08 N 475786.01 E 0.000 469.48 5500.00 14.130 223.460 5383.95 5440.05 2.51 N 475769.16 E 0.000 493.78 ~ 5521.70 14.130 223.460 5405.00 5461.10 68.68 N 475765.50 E 0.000 499.05 Top H RZ 5600.00 14.130 223.460 5480.93 5537.03 993554.85 N 475752.31 E 0.000 518.08 5700.00 14.130 223.460 5577.90 5634.00 5993537.1 8 N 475735.46 E 0.000 542.37 5727.94 14.130 223.460 5605.00 ,417.66 W 5993532.24 N 475730.75 E 0.000 549.16 Base H RZ 0 5800.00 14.130 223.460 5674.88 429.76 W 5993519.51 N 475718.61 E 0.000 566.67 :::x:J 5838.28 14.130 223.460 5712.00 436.19 W 5993512.75 N 475712.16 E 0.000 575.97 K-1 5900.00 14.130 223.460 5771 .85 446.55 W 5993501 .85 N 475701.76 E 0.000 590.97 --- 5910.4 7 14.130 223.460 5782.00 448.31 W 5993500.00 N 475700.00 E 0.000 593.51 TARGET: 5910.47ft MD, 5838.1 Oft ç',) TVD (2362' FSL & 1560' FEL, See -.........~-:."%~ T12N-R8E) ",::::::;!\I Kuparuk l-~.~ 3S-16 (Geo Target), 150.00 Radius :r~ Current Target r-- 5936.25 14.13p 2231460 5863.10 393.51 S 452.64 W 5993495.45 N 475695.66 E 0.000 599.78 Miluveaeh 6000.00 14.130 ··g?3':4~g; 5868.83 5924.93 404.81 S 463.35 W 5993484.18 N 475684.91 E 0.000 615.27 6100.00 14.130 ??3.4Q() 5965.80 6021 .90 422.53 S 480.14 W 5993466.52 N 475668.07 E 0.000 639.57 6137.00 14.130 223.460 6001.68 6057.78 429.08 S 486.35 W 5993459.98 N 475661.83 E 0.000 648.56 Total Depth: 6137.00ft MD, 6057.58ft TVD (2322' FSL & 1 c:t'\q' FEL, SEC. 18-T12N-R8E) ~ 7" Casing All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.1' MSL. Northings and Eastings are relative to 2528' FNL, 1110' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 2528' FNL, 1110' FEL and calculated along an Azimuth of 229.000° (True). Magnetic Declination at Surface is 25.223°(07-Jan-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 6137.00ft., The Bottom Hole Displacement is 648.58ft., in the Direction of 228.580° (True). 8 January, 2003 - 7:25 Page 4 of6 DrillQuest 3.03.02.002 Western North Slope Comments Measured Depth (ft) 0.00 2566.00 2650.00 2816.67 3016.67 3829.71 5910.47 6137.00 Sperry-Sun Drilling Services Proposal Report for Kuparuk 3S Pad - 3S-16 Plan - 3S-16 (wp05) Your Ref: Kickoff Below Surface Csg... Build & Hold to 14° Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ConocoPhillips ~ a Formation Tops :Jo ~~-::... !:tJ Measured Vertical Sub-Sea ~- Depth Depth Depth; Eastings Dip Up-Dip Formation Name ~:-~ (ft) (ft) .J~)' (ft) Angle Dirn. ,~ :r~ 1546.10 1546;10' ·_1_~9qlgO O.OON 0.00 E 0.000 359.817 B. Permafrost r--- 2011.10 2011:1 Ö 1955.00 O.OON 0.00 E 0.000 359.817 T. West Sat< 2456.10··· .' 2456.10 24QQ·00 O.OON 0.00 E 0.000 359.817 B. West Sat< 2666.10~ 2666~1 0 2610.00 0.06 N 0.03W 0.000 359.817 C-80 (K-10) 4124.43 .'41Q6:19 4050.00 72.46 S 148.40 W 0.000 359.817 C-40 (K-3) 5258.75 5206.10 5150.00 273.46 S 338.87 W 0.000 359.817 Top Morraine ..~ 5521.70 5461.10 5405.00 320.06 S 383.03 W 0.000 359.817 Top H RZ 5727.94 5661.10 5605.00 356.60 S 417.66 W 0.000 359.817 Base HRZ 5838.28 5768.10 5712.00 376.15 S 436.19 W 0.000 359.817 K-1 5910.4 7 5838.10 5782.00 388.94 S 448.31 W 0.000 359.817 Kuparuk 5936.25 5863.10 5807.00 393.51 S 452.64 W 0.000 359.817 Miluveach 8 January, 2003 - 7:25 0.00 0.00 N 0.00 E 2566.00 0.00 N 0.00 E 2650.00 0.00 N 0.00 E 2816.46 6.29 N 3.63W 3015.70 21.39 N 12.35 W 3820.30 20.24 S 5838.10 388.94 S 6057.78 429.08 S SHL (2528' FNL & 1110' FEL, 9-5/8" Csg Pt ... Drill out Begin Dir @ 3. End Dir, S Begin il :130 : 3829.71 ft MD, 3820.30ft TVD 0.47ft MD, 5838.1 Oft TVD (2362' FSL & 1560' FEL, Sec 18-T12N-R8E) 137.00ft MD, 6057.58ftTVD (2322' FSL & 1599' FEL, SEC. 18-T12N-R8E) Page 50f6 DrillQuest 3.03.02.002 a ~~-,",....~.- ~ ~;:,; o"E":<-........".: --:'-.'t 6',- :, "'. ~ -oj --..:. ~- ~ :~.... ):-~ r-- Western North Slope Casino details Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> 2566.00 2566.00 <Surface> <Surface> <Run-TO> <Run-TO> Taroets associated with this wellpath Target Name 3S-16 (Goo Target) 8 January, 2003 - 7:25 Sperry-Sun Drilling Services Proposal Report for Kuparuk 3S Pad - 3S-16 Plan - 3S-16 (wp05) Your Ref: Kickoff Below Surface Csg... Build & Hold to 14° Casing Detail 9 5/8" Casing 7" Casing Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Shape Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Target Radius: Target Thickness: 5838.10 388.94 S 448.31 W 5782.00 5993500.00 N 475700.00 E 700 23' 36.1222" N 1500 11' 51.7272" W Circle 150.00ft 35.00ft Page 6016 ConocoPhillips - Target Type Current Target -- DrillQuest 3.03.02.002 9-5/8" Csg Pt ... Drill out 8-1/2" Hole .~ 2566.00ft MD, 2566.00ft TVD ~""""'~~.-' - ----------- Ii. V'(':'i S"'. 'I Vi·' .>.)1,. i(lii 9:snrëšgPI. .- J MD: 2566.00ft --I TVD: 2566.00ft A PPRO i lED PI ~ ,""TiK';; "\~""¡;Il~ - -- - - - - - - - - - -- - -- V j an ~ 2800 - . ~~ Begin Dir@3.00/100ft: ~ 2650.00ft MD, 2650.00ft TVD Current Well Properties II ~.. III End Dlr, Start Sail @ 5.00: Well: 3S-16 :::s::: 2816.67ft MD, 2816.46ft TVD II:. Horizontal Coordinates: ~ . Begin Dir @ 2.00/100ft : Ref. Global Coordinates: 5993887.51 N, 476149.55 E ë.' Ref. Structure: 43.54 N, 305.59 W Q) ! 3016.67ft MD, 3015.70ft TVD Ref. Geographical Coordinates: 700 23' 39.9479" N, 1500 11' 38.5965" W o 3500 - I 2528' FNL & 1110' FEL, SEC. 18- T12N - ëij t' .~ RKB Elevation: 56. 10ft above Mean Sea Level t I ~ I North Reference: True North .............. Units: Feet (US) .............. End Dir, Start Sail @ 14.13° : i t 3829.71ft MD, 3820.30ft TVD -----+---------- 4200 _ .>40: ];...1\. TV;'. .1) 1,').\ ¡if: I I I (.iJ I ~ sp~~y-~ ~ ~lf', ,.l"~,,~.,,J.N... J3...,,,.,..,.,,,,,........IB.Y_l.t;..ltB 4900 - I -ö "." ..".... ...... ^'. .. ,...":!m.,,.... ,. ....... ._'.'"'.'.~..__M.'. .."...::...:".. .."n..:.."'......... .::.".,~"" .... ."... .,. I '§, 1\ ">Iib"""" c......", ~,~r'''l' :::,,,;'7,,,: ¡ - - - - - ~F,~~~9~C~V~), 583f3.~Oft TVD- - ~. F:~¡ -+- _ _ 1- _ (23~'.~SI... & 'I ~O' FlJ.., ~eC18-'l~ 2N-H8~ _ I / 5600-_. .---i---- -....'.~---------- ì~~",\·Ht.,1!. )\L) ::,:;",1 ;:::". .' ~".~~ - -Í- - - - -:.:-:..~.=.~s..¡~)..:¡~- - -- ,;,;;¡'" ,j.; ,;,;;: T = =r.; '" = = 4ts' II: ~<;~: 3,~,;:;i::{:' 448.3 ~ I~ 7" Csg PI. I MD: 6137.0011 I TVD,6057.7811 o () .....'\ (.",!.~ lA L 'i ).,' a'¡' .~..}. I ~J L' ", ¡J Scale: 1 inch = 700ft DrillQuest 3,03,02.002 6300- I 700 I 400 2100 .:t:: o o r-- II .c (,) .£ (¡j (tj (,) (f) Total Depth (2322' FSL & : 6137.00ft MD, 6057.58ft TVD 1599' FEL, SEC. 18-T12N-R8E) R8E ~d~TVD:'.;,nl].lm ~ ""'" -- """ -- Yo/W<""-- -.,. -- --- -- -- -- --- 2100 - 400- Ù.~\~:·'~\Ar(~, 'I'\;:.~:::>,~~rrt\~~- - 35-16 (wp05) ../ ConocoPhillips Alaska North Slope, Alaska Palm (3S Pad) 700 - ConocoPhillips nc 0- SHL. (2S28' FN &. ,¡ I FE SEC 8.. T12N ) Fi8E) ) C-:) --..... ~",:J ~4...~__... r.'"··- ~ ~~- -.c.o-..., ~-.~_J :~~-~ J~.~ r-- /' Conoc~Phillips ConocoPhillips Alaska, Inc. North Slope, Alaska Palm (3S Pad) 3S-16 (wp05) -1050 I -900 I N "~f ''""'IF' Reference is True North Well: Current Well Properties 3S-1 6 Ei ~Y-5U11. g~!!lLzLlm,m,,¡,,;;:;;;;;;;,,~~;,~ .A1þ~ ~O~ ~bA ~q -150 I <:~¡; i?528' FNL & 11;0' PEL, SEC. 18· T12N· RSE)", 9-518" Csg PI... Drill o~; ~~1;;" 'HOle : 2566.00ft MD, 2566.00ft TVD . Begin Dir @ 3.00/100ft: 2650.00ft MD, 2650.00ft TVD '--':n~D~~il~:~8~M~~ft~ - - -- - - - - -- - B . D·lr@200/100ft·301667ftMD,3015.70ftTVD 0------- egln . .. End Dir, Start Sail @ 14.13° : 3829.71ft MD, 3820.3011 TV -1 50 - en 0> C :c t o Z -300 - Total Depth: 6137.00ft MD, 6057.5811 TVD (2322' FSL& 1599' FEL, SEC. 18-T12N-R8E) ~ o to II .£: U .S -450 - (¡j ~ en I -1050 I -900 Scale: 1 inch = 150ft DrillQuesl 3.03.02.002 Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure: . Ref. Geographical Coordmates : 5993887.51 N, 476149.55 E 43 54 N, 305.59 W . 70~ 23' 39.9479" N, 1500 11' 38.5965 W 2528' FNL & 1110' FEL, SEC. 18- T12N - R8E 56.1 Oft above Mean Sea Level True North Feet (US) RKB Elevation: North Reference: Units: -750 I -600 I -450 I -300 I ~~;~:i ~:·-¡~l~1·~ ~;i:1~~:t ~~~~·L: :~¥;B1 ~~~:~:~~;~-~:~RBE} I -750 I I -600 -450 Eastings I -300 D73700~ - - - 0 19-518" Csg PI. MD: 2566.0011 TVD: 2566.OOIt I I I I I I t I t I I I I 35-16 (Geo Target} I C'ircle, Radius: IS{U}{~t1, '. .. 5838.10 ITD, 388J}·j S, ·14831 W I -150 o ~. - -1 50 en 0> C :c t o Z - -300 --- - -450 Õ to II .£: U .S (¡j (ij u en ConocoPhillips Alaska, Inc. 35-16 (wp05) MD Inc Azim. SSTVD TVD N/S EIW y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) r/100ft) (ft) 0,00 0.00 0.00 -56.10 0.00 0.00 N 0.00 E 599388751 N 476149.55 E 0.00 0.00 SHL 1546.10 0.00 0.00 1490.00 1546.1 0 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.00 0.00 B. Permafrost ~ 2011.10 0.00 0.00 1955.00 2011.10 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.00 0.00 T. West Sak C> 2456.10 0.00 0.00 2400.00 2456.10 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.00 0.00 B. West Sak 2566.00 0.00 0.00 2509.90 2566.00 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.00 0.00 9-5/8" Csg pt ... Drill out 8-1/2" Hole ::I:J 2650.00 0.00 0.00 2593.90 2650.00 0.00 N 0.00 E 5993887.51 N 476149.55 E 0.00 0.00 Begin Dir @ 3.00/10Oft -.,. 2666.10 0.48 330.00 2610.00 2666.10 0.06 N 0.03 W 5993887.57 N 476149.52 E 3.00 -0.01 C-80 (K-10) ~ 2816.67 5.00 330.00 2760.36 2816.46 6.29 N 3.63 W 5993893.82 N 476145.94 E 3.00 -1.39 End Dìr; Start Sail --, 3016.67 5.00 330.00 2959.60 3015.70 21.39 N 12.35 W 5993908.94 N 476137.27 E 0.00 -4.71 Begin Dir @ 2.0o/10Oft ~:::: 3829.71 14.13 223.46 3764.20 3820.30 20.24 S 98.91 W 5993867.59 N 476050.58 E 2.00 87.93 End Dìr; Start Sail :L~ 4124.43 14.13 223.46 4050.00 4106.10 72.46 S 148.40 W 5993815.52 N 476000.92 E 0.00 159.54 C-40 (K-3) i~ 5258.75 14.13 223.46 5150.00 5206.10 273.46 S 338.87 W 5993615.13 N 475809.81 E 0.00 435.16 Top Morraine 5521.70 14.13 223.46 5405.00 5461.10 320.06 S 383.03 W 5993568.68 N 475765.50 E 0.00 499.05 Top HRZ 5727.94 14.13 223.46 5605.00 5661.10 356.60 S 417.66 W 5993532.24 N 475730.75 E 0.00 549.16 Base H RZ 5838.28 14.13 223.46 5712.00 5768.10 376.15 S 436.19 W 5993512.75 N 475712.16 E 0.00 575.98 K-1 5910.47 14.13 223.46 5782.00 5838. i 0 388.94 S 448.31 VV 5993500.00 N 475700.00 E 0.00 593.51 TARGET 5936.25 14.13 223.46 5807.00 5863.10 393.51 S 452.64 W 5993495.45 N 475695.66 E 0.00 599.78 Miluveach 6137.00 14.13 223.46 6001.68 6057.78 429.08 S 486.35 W 5993459.98 N 475661.83 E 0.00 648.56 Total Depth -.-/ Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad 3S-07 3S-09 3S-14 3S-18 3S-26 3S-26 Plan: 3S-03 Plan: 3S-06 Plan: 3S-06 Plan: 3S-08 Plan: 3S-08 Plan: 3S-10 Plan: 3S-15 Plan: 3S-17 Plan: 3S-17 Plan: 3S-19 Plan: 3S-19 Plan: 3S-20 Plan: 3S-21 Plan: 3S-21 Plan: 3S-22 Plan: 3S-23 Plan: 3S-24 OR g ~ ~~ f 11 L Ill,' I t~lti 3S-07 V5 3S-09 V2 3S-14 V2 3S-18 V4 3S-26 V2 3S-26A V3 Plan: 3S-03 V2 Plan: 3 Plan: 3S-06 V2 Plan: 3 Plan: 3S-06F V2 Plan: Plan: 3S-08 V2 Plan: 3 Plan: 3S-08F V2 Plan: 3S-10 (Rig Surveys) V1 Plan: 3S-15 V1 Plan: 3 Plan: 3S-17 VO Plan: 3 Plan: 3S-17F V1 Plan: Plan 3S-19FV2 Plan: 3 Plan: 3S-19 V1 Plan: 3 Plan: 3S-20 V1 Plan: 3 Plan: 3S-21 V1 Plan: 3 Plan: 3S-21 F V2 Plan: Plan: 3S-22 V2 Plan: 3 Plan: 3S-23 V1 Plan: 3 Plan: 3S-24 V1 Plan: 3 249.987 199.985 399.796 199.996 2750.295 3276.048 943.922 249.998 249.998 249.996 249.996 199.981 449.684 299.980 299.980 249.997 249.997 249.998 299.998 299.998 299.990 299.998 249.998 Reference MD ft Offset 1\10 ft 250.000 200.000 400.000 200.000 2750.000 3300.000 950.000 250.000 250.000 250.000 250.000 200.000 450.000 300.000 300.000 250.000 250.000 250.000 300.000 300.000 300.000 300.000 250.000 180.218 140.976 41.710 40.686 156.515 51.316 213.048 200.425 200.425 160.423 160.423 120.513 19.097 21.313 21.313 60.471 60.471 80.229 100.374 100.374 120.856 140.391 160.545 4.591 3.811 7.492 3.682 36.547 47.419 15.655 5.172 5.172 5.238 5.238 3.958 9.673 6.230 6.230 5.163 5.163 5.020 6.232 6.232 5.960 6.256 5.157 175.628 137.166 34.219 37.007 120.424 4.419 197.512 195.253 195.253 155.185 155.185 116.556 9.426 15.084 15.084 55.308 55.308 75.209 94.141 94.141 14.896 34.135 55.389 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Ctr-Ctr Distance ft No~Go Area ft Allowable DevÎätioll ft Waï:~g 2566.000 2566.000 9.625 6137.000 6057.765 7.000 Summary 12.250 8.500 95/8" 7" Survey Program for Definitive Well path Date: 5/15/2002 Validated: No Planned From To Survey ft ft 28.100 500.000 Planned: 3S-16 (wp05) V14 500.000 6137.000 Planned: 3S-16 (wp05) V14 Casing Point... CB-GYRO-SS MWD Version: Tookode Camera based gyro single shot MW D - Standard Tool Name NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.000 ft Depth Range: 28.100 to 6137.000 ft Maximum Radius: 816.590 ft 2 Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing C~JJ1pany: Field.: ~e~ere~~~~it~: ReferenceWeJl: ReferenccWellpatli: R9illjp~f.I~~K~J~c:· ISYP~ŒkRiY~nLJnit ~HP~~Yk 3§pad PIF~:9§tT6 Plan:3S46 ) Sperry-SUD Anticollision Report ) WIH. DETAILS Name +NI·5 +I'l-W N<1rtJmg 12.-..IÎ1g LatiluJe wngituJe Svt Pbn: 35·lh 43.552 ·30'i.hI9 59'13887.51 47h149.55 7[f23"39.94SN 150' I I"3S.S97W NJA COMPANY DETAILS WEILPATII DETAILS Plan: 3S-lh N7ES SIi.1 56.100ft ANI1-COLLISION SETI1NGS p~s Ahska loc. Engneering Knparuk CalcuJati:Jn Method: ~mmum Cur.-ature Error S)'SIem: ISCWSA Scan Method: Trav Cymde< North Emu Surface: Elliptical+ Casi:Jg Warni:Jg Method: RuJes Based Interval: 50.000 To: 6137.000 Reference: Plan: 3S-16 (wp05) Interpolation Method:MD Depth Range From: 28.100 Maximum Range: 816.590 Rig: Ref. Datum: V.SecOOD Angle Origin Oriril Startin2 +NI-S +F1'-W From fvD 229.00' 0.000 0.000 0.000 SURVEY PROGRAM Depth Fm Depth To SurveylPlan 28.100 500.000 Planned: 35-16 (wp05) VB 500.000 6137.000 Planned: 3S-16 (wp05) VB Tool From Colour ToMD 0 200 200 400 400 600 600 800 800 1000 WOO 1200 1200 1400 1400 1600 1600 1800 1800 2000 2000 2500 2500 3000 ......n 3000 3500 -40 3500 4000 4000 4500 4500 5000 5000 5500 5500 6000 6000 6500 -30 From Colour o 200 400 600 800 WOO 1200 1400 1600 1800 2000 2500 3000 3500 4000 4500 5000 5500 6000 CB-GYRO-SS MWD Plan: 3S-15 (plan: 3S-15) -207 -200 -150 -100 ~ "'? ',y :5'0 fir'/. ~~. / ~~ill ...~¿.....~.....[......;.)sEC?2-J?i"~/~/.'~ Ítw 3S~:S-18) ~ \\ _ \\'~~-J//" j !I):'// _<::"\\. ~.' . . . " Y", 120 ~ ~ '~~. ~ / ~ ---- ~ -30 ~f --i-\ / / 21 ~~_ lRJiW _~50 -<J() ¡~" 40 ~ SECTION DETAILS -.:J3 18dB -20 -100 -150 -200 -207 See MD Ine Azi TVD +N/-S +FJ-W DLeg TFace VSec Target I 28.100 0.00 0.00 28.100 0.000 0.000 0.00 0.00 0.000 2 2650.000 0.00 0.00 2650.000 0.000 0.000 0.00 0.00 0.000 3 2816.667 5.00 330.00 2816.455 6.294 -3.634 3.00 330.00 -1.387 3S..16 (WpOS) 4 3016.667 5.00 330.00 3015.694 21.390 -12.349 0.00 0.00 -4.713 5 3829.777 14.13 223.46 3820.363 -20.251 -98.925 2.00 -123.30 87.945 6 5910.480 14.13 223.46 5838.100 -388.981 -448.356 0.00 0.00 593.573 3S (16) Approved Plan 7 6137.000 14.13 223.46 6057.765 -429.124 -486.397 0.00 0.00 648.619 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [20ft/in] ToMD 200 400 600 800 1000 1200 1400 1600 1800 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 -' M iti~ation Strate~y Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM Use GKA LC decision tree. Lost Circulation Abnormal Reservoir Pressure Barite Sag Differential Sticking ", ~¡! Moderate Moderate Low Moderate \..i' i 4 àIIóI Page 3S-16 Drilling Hazards Summary. doc prepared by Scott Lowry 7/30/02 /' / of 1 Event Shale stability in HRZ, Miluveach High ECD and swabbing with higher MW's required K-l, and Moderate Risk Level Low 8-1/2" Hole / 7" Casina Interval Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM Lost Circulation Gravel/Sand Sloughing to 500' Hole Swabbing/Tight Hole on Trips Possible thaw bulb / around 1200' water flow Low Low Moderate Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Moderate If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Drilltreat. Gas Hyd rates Event Broach of Conductor Low Risk Level Low M iti~ation Strateqy Monitor cellar continuously during interval 12-1/4" Hole / 9-5/8" 35-16 Drillina Hazards Summary ) Casing Interval ') OR ~ ¡ \<~") & "';1 \.<~ q /", ! ~ l ;; .:¡.J .'.. ~ -): t: IM)I..- r;¡ r;¡ r I ~ ~ I ~ ~ ~ I ~ I ~ ~ ~ ~ íI. TAM 9-5/8" portJ _z ~ Collar Stnd . ~ Grade BTC ~ Threads (+/- Z ~ 1000'MDITVD) ~ ~ ~ ~ ~ ~ z ~ Surface csg. ~ ~ 9-5/8"40# L-80 ...1 ~ BTC (2566' MD I ~ 2566' TVD) ~ Casing point ~ 100' above the ~ C80 sand ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ j C .."::!' Sand Perfs - ":.:.:.) (to be done -, after rig moves ..~ off) . ~.:.:(~ ~ ~ ~ ~ ~ ~ ~ ~ .... ~ ~ ~ Production csg. 7" 26# L -80 BTCM (+1- 6137' MD) g~{~ :):~:r1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ TD @ 6,137' MD /6058' TVD (200' MD below Miluveach) Scott L Lowry 01/08/03 Baker 3-1/2" WL Re-entry Guide wI shear out sub. Tubing tail 320' above top planned perforation. ... ~ ~;" 16"x30" nsulated conductor @ +/- 108' MD w it ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 6' Pup Joint 3-1/2" 3-1/2" Camco 'D' nipple wI 2.75" No-Go profile. L-80, 9.3# EUE 8rd Mod Tubing. Baker 7" x 3-1/2" 'SAB-3' Permanent Packer set +1- Minimum ID through the packer 3.00". 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 350' MD above top planned perf. Baker '80-40' PBR. 6' Handling Pup Joint 3-1/2" L-80, 9.3# EUE 8rd Mod Tubing. Joint 3-1/2" L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco 'DS' nipple wI 2.813" No-Go profile ~ ~ I I I I I I I I I I ~~ ~ I ~ ~.... Joint 3-1/2" 3-1/2" x 1-1/2" 'MMG' GLM wI DCR Dump Kill Valve (3000 psi casing handling pups installed on top and bottom of mandrel. L-80, 9.3# EUE 8rd Mod Tubing. to tubing shear). 6' L-80 Use of port collar at the discretion of the drilling team. 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +1- 500' MD. 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" KRU - 38-16 Inj£}or Proposed Completion Schematic Single Completion FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91 ..~ G ) 'P'h'·I:I- ..... onoco! .. ¡il UpS ~.. CHASE Chase Manhattan Bank USA, N.A. Valid Up To. 5000 Dollars . ...... 200Wh~e Clay Center Dr., Newark. DE 19711 .. ," . . . .'. ..~. ". /" .. .... . .' i..' ~ ~. '~ ( í , --f! . n ~ I. ' I;~~ ~ ~O~)~·~ 1,1: 2 ~aoooo I, 2? 2 5 ~I:~: ~"'- cX::J S-.1,//) I .~ .. ~;~:1_:;: PAY TO THE <;7 rlT E c;'.F í-iLrtSl-:./i /'fL1él?((' I $lc~O, ({] ORDER OF , . . ~ ~ ,. j . j. . . - ~ /; - .,~ ----- C ~.1..k.- ¡~¿,",-,i r¿ c"/ . ø' ( þ. 1-> ~I '/ (Y:Jr--- DOLLARS éð b ~~"t 0t!{ V ¡'2å':>62-14!311 DATE S. K. ALLSUP-DRAKE PHILLIPS PETROLEUM COMPANY 711 G ST. ANCHORAGE AK 99501 1019 -. JAN 0 9 2003 Alaska Oil & Gas Cons. Commission Anchorage RECEIVED ~ Rev: 07/10/02 C\jody\templates DRY DITCH SAMPLE All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. SPACING EXCEPTION The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. PILOT (PH) In accordance with 20 AAC 25.005(1), 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). HOLE (If API number last two (2) digits are between 60-69) The permit is existing well , Permit No, API No. . Production should continue to be reported as a function· of the original API number stated above. CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL for a new wellbore "CLUE segment of PTD# WELL NAME TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER J ) { \ ( _ Serv x... Well bore seg 'l7Ò)ðc/#¿Ø6'~/OFF SHORE CŸV Re-Enter UNIT# _ Dev _ Redrl Rf~ PROGRAM: Exp GEOL AREA Permit fee attached. . . . . . . R N Lease number appropriate. . . Y N Unique well name and number. Y N W ell located in a defined pool.. . . . . . . . . . . . Y N Well located proper distance from drilling unit boundary. Y N Well located proper distance from other wells.. . . . . Y N Sufficient acreage available in drilling unit.. . . . . . . Y N If deviated, is wellbore plat included.. . . . . . . . . . Y N Operator only affected party.. . . . . . . . . . . . . . Y N Operator has appropriate bond in force. . . . . . . . . Y N Permit can be issued without conservation order. . . . Y N Permit can be issued without administrative approval.. . . W N W ell located w/in area & strata authorized by injection order # 2 ,ß rD. N All wells wlin X mile area of review identified. . . . . . . . .. (!) N ~1'1.,. 'L Conductor string provided. . . .' . . . . . . . . . . . . . . . ~N Surface casing protects all known USDWs. . . . . . . . . . . Y." N CMT vol adequate to circulate on conductor & surf csg. . . . . Œ N CMT vol adequate to tie-in long string to surf csg. . . . . . . Y @ P €1$~ ; b le Ai) CMT will cover all known productive horizons. . . .. . . . .. . ~. N Casing designs adequate for C, T, B& permafrost. . . . . . . N Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N tVOt.b ()Y' > 1 E S If a re-drill, has a 10-403 for abandonment been approved. . . .¥-N N1A- . Adequate wellbore separation proposed.. . ... . . . . . . . . ~ N If diverter required, does 'it meet regulations. ., . . . . . . . N Drilling fluid program schematic & equip list adequate. . . . . j~ N WI IÑ'L rr!/tI....1 12. ~ f Pj BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N BOPE press rating appropriate; test to 5000 psig. N r11 r; P 'L q 17 rt:.¡'· Choke manifold complies w/API RP-53 (May 84). . . . . . . . N Work will occur without operation shutdown. . . . . . . . . . . ~ tj..., Is presence of H2S gas probable.. . . . . . . . . . . . . . . . ); á¥ , l A ..-. () Mechanical condition of wells within AOR verified. . . . . . . . (jJ N Alt7 vu.£-'i <: ¡ '^'- I't1/ tc:- Permit can be issued wlo hydrogen sulfide measures. . . .. cY N Data presented on potential overpressure zones. . . .. )1.. L:J Seismic analysis of shallow gas zones. . . . . . , . . . . Y jt..J. õ7 J Seabed condition survey (itoff-shore). . . . . .. ..... N Contact name/phone for weekly progress reports. ..... Y N RESERVOIR ENGINEERING UIC ENGINEER WELL PERMIT CHECKLIST COMPANV{" ~c~~~ELL NAME;t2 L/ ,?,) - /h -~/r:{). fL9LJ/ðòÚtNITéLASS /-~JrT 1. . . . . . . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25, 26. 27. 18'. 29. 30. 31 32. 33. 34. 35. 36. Comments/Instructions: COMMISSIONER: COT 1 I DTS ()//I.r'03 MLB 01//0/03 JBR JDH MJW PETROLEUM ENGINEERING: TEM WGA V'. GEOLOGY: RP~ SFD G:\geology\permits\checklist.doc FIELD & POOL ADMINISTRATION APPR DATE /I+~ ¡/~ (Service Well Only) (Service Well Only) ENGINEERING APPR DATE Wc,A- ¡ )¡ol()~ (Service Well Only) GEOLOGY APPR DATE ,(j>~ trl'f (Explor tory Only) Rev: 10/15/02 ) ) Well History File APPENDIX nformation of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. .. To improve the readability of the Well History file and to sinlplify finding infomlation, 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 page 1 # WELL CASING RECORD # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION eFT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: .00 56.67 28.90 18 12N 8E 2526 1110 JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS Comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE # JOB DATA Tape Header service name.. . Date. . . . . . . . . . . ori gi n. . . . . . . . . Tape Name.......... continuation Number previous Tape Name. Comments... .... physical EOF Reel Header service name Date. . . . . . . . . . ori gi n. . . . . . . . . . . . . Reel Name...... .... Continuation Number previous Reel Name Comments. . . . . . . . LISTPE 03/04/14 STS UNKNOWN 01 UNKNOWN STS LIS writing Library scientific Technical Services LISTPE ( 03/04/14 STS UNKNOWN 01 UNKNOWN STS LIS writing Library scientific Technical services 3s-16 501032044500 Conoco phillips Alaska Inc sperry Sun 14-APR-03 MWD RUN 2 MWD RUN 3 Mw2260898000 Mw2260898000 P ROGER P SMITH D BURLEY D BURLEY ) 3s-16.tapx Sperry-sun DrilliryT.services LIS Scan Utl lty $Revision: 3 $ LisLib $Revision: 4 $ Mon Apr 14 14:13:52 2003 ) él03-Ôð 7 1/1.0'-/;;; ) ) 3S-16.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 2559.0 2ND STRING 6.125 7.000 5907.0 3RD STRING PRODUCTION STRING # REMARKS 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 100 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 200 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR)UTILIZING GEIGER-MUELLER TUBE DETECTORS,ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUN 300 WAS DIRECTIONAL WITH DGR, EWR4, STABILIZED LITHO- DENSITY (SLD), AND COMPENSATED THERMAL NEUTRON POROSITY (CTN), 6. MWD DATA ARE CONSIDERED PDC PER GKPA GEOSCIENCE GROUP. CNP DATA ARE CALCULATED USING THE SLD 'CALIPER' FOR HOLE SIZE INDICATION. 7. MWD RUNS 2,3 REPRESENT WELL 3s-16 API#:50-103-20445-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6150'MD / 6079'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY). SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR SLIDE= ORIENTED DRILLING INTERVALS AT BIT DEPTHS. COMPENSATED NEUTRON POROSITY PROCESSING PARAMETERS page 2 # Data Format specification Record Data Record Type..... ... ..... Data specification Block Type Logging Direction.. .......... o o Down page 3 # REMARKS # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2525.0 5907.0 MWD 3 5907.0 6150.0 $ MERGED MAIN PASS $ Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE ROP GR RPD RPS FET RPM RPX PEF NCNT FCNT DRHO RHOB NPHI $ START DEPTH 2525.0 2538.5 2549.0 2549.0 2549.0 2549.0 2549.0 5907.0 5907.5 5907.5 5908.5 5908.5 5909.5 STOP DEPTH 6150.0 6106.5 6113.5 6113.5 6113.5 6113.5 6113.5 6085.0 6070.0 6070.0 6085.0 6085.0 6070.0 1 clipped curves: all bit runs merged 5000 $ File Header service name.......... service Sub Level Name version Number..... ... Date of Generation. .... Maximum physical Record File Type......... previous File Name STSLIB.001 1.0.0 03/04/14 65535 LO STSLIB.OOO HOLE SIZE: 6. 125"F/TNPS MUD WEIGHT: 11.0 PPG MUD SALINITY: 400-500 PPM FORMATION WATER SALINITY: FLUID DENSITY: 1.0 G/ec MATRIX DENSITY: 2.65 G/ee LITHOLOGY: SANDSTONE 25000 PPM ) 3S-16.tapx ) File Trailer service name... ...... ....STSLIB.OOl service sub Level Name... version Number.. ........ .1.0.0 Date of Generation... ....03/04/14 Maximum physical Record. .65535 Fi 1 e T¥~e.. . . . LO Next Fl e Name STSLIB.002 physical EOF File Header service name STSLIB.002 page 4 First Reading For Entire File Last Reading For Entire File. 2525 6150 Name service unit DEPT FT ROP MWD FPH GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR NPHI MWD PU FCNT MWD CNTS NCNT MWD CTS/ RHOB MWD G/CC DRHO MWD G/CC PEF MWD BARN Min 2525 0.22 31.41 0.46 0.36 0.26 0.21 0.1492 18.14 13151.3 104.6 1.774 -0.037 3.23 Max 6150 311.11 431.33 2000 2000 2000 2000 177.603 59.84 36527.2 959.2 3.046 0.373 16.3 Mean 4337.5 180.949 119.902 6.76265 4.90186 9.0639 11.4236 2.05686 31.9901 23681.3 371.781 2.45835 0.0533136 5.65507 Nsam 7251 7250 7137 7072 7072 7072 7072 7072 322 326 326 354 354 357 Fi rst Reading 2525 2525 2538.5 2549 2549 2549 2549 2549 5909.5 5907.5 5907.5 5908.5 5908.5 5907 Last Reading 6150 6150 6106.5 6113.5 6113.5 6113.5 6113.5 6113.5 6070 6070 6070 6085 6085 6085 Name service order DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD units size Nsam Rep code offset channel FT 4 1 68 0 1 FPH 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 PU 4 1 68 32 9 CNTS 4 1 68 36 10 CTS/ 4 1 68 40 11 G/CC 4 1 68 44 12 G/cc 4 1 68 48 13 BARN 4 1 68 52 14 optical log depth units Data Reference point... Frame spacing.. ........ Max frames per record.. Absent value............. Depth uni ts . . . . . . . . . . . . . . Datum specification Block ) 3S-16.tapx · . . . . . Feet · . . . . . undefi ned · . . . . . . .60 .IIN ....... .undefined · . .. . . . . -999 · . . . . . . . sub-type 0 ') # page 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: 5 3.100 1.683 3.000 3.300 LSND 11.30 45.0 9.4 400 4.0 70.0 134.6 70.0 70.0 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) 8.500 2559.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG RESIS $ 4 TOOL NUMBER 155789 134758 # # 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 .9 16.2 31-JAN-03 Insite 6.02 Memory Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT # FILE SUMMARY VENDOR TOOL ROP GR FET RPD RPX RPM RPS $ START DEPTH 2525.0 2538.5 2549.0 2549.0 2549.0 2549.0 2549.0 STOP DEPTH 5907.0 5875.0 5897.0 5897.0 5897.0 5897.0 5897.0 CODE header data for 2 5000 2 each bit run in separate files service Sub Leve version Number.. Date of Generati~ Maximum physical File Type... . . . . . . previous File Name . . 'In.. . . . Record Name 3s-16.tapx 1.0.0 03/04/14 65535 LO STSLIB.OOl ) ) physi ca 1 EOF page 6 File Trailer Se rvi ce name.......... service sub Level Name version Number........ Date of Generation..... Maximum physical Record File T¥pe...... . Next Flle Name . STSLIB.002 1.0.0 03/04/14 65535 LO STSLIB.003 First Reading For Entire File Last Reading For Entire File. 2525 5907 Name Service unit DEPT FT ROP MWD020 FPH GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min 2525 6.74 54.61 0.46 0.36 0.26 0.21 0.1492 Max 5907 311.11 431.33 1086.62 103.74 2000 2000 52.3037 Mean 4216 190.634 121.227 3.51978 3.29902 4.64827 7.92382 0.853149 Nsam 6765 6765 6674 6637 6637 6637 6637 6637 Fi rst Reading 2525 2525 2538.5 2549 2549 2549 2549 2549 Last Reading 5907 5907 5875 5867 5867 5867 5867 5867 Name service order DEPT ROP MWD020 GR MWD020 RPX MWD020 RPS MWD020 RPM MWD020 RPD MWD020 FET MWD020 units size Nsam Rep code offset channel FT 4 1 68 0 1 FPH 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 # Data Format specification Record Data Record Type........ ..... 0 Data specification Block Type 0 Log~ing Direction............ . Down optlcal 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 0 ) NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN) EWR FREQUENCY (HZ) # REMARKS $ 3s-16.tapx ) page 7 # BOREHOLE CONDITIONS MUD TYPE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) LSDN 6.125 5907.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON EWR4 Electromag Resis. 4 $ TOOL NUMBER 184054 151872 153020 159436 # # 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 8.7 8.9 08-FEB-03 Insite 6.02 Memory Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP GR RPD RPX FET RPS RPM PEF NCNT FCNT DRHO RHOB NPHI $ START DEPTH 4749.0 5875.5 5897.0 5897.0 5897.0 5897.0 5897.0 5907.0 5907.5 5907.5 5908.5 5908.5 5909.5 STOP DEPTH 6150.0 6106.5 6113.5 6113.5 6113.5 6113.5 6113.5 6085.0 6070.0 6070.0 6085 . 0 6085.0 6070.0 3 header data for each bit run in separate files 3 5000 File Header service name. ......... service Sub Level Name version Number.... .... Date of Generation..... Maximum physical Record Fi 1 e Type.. . . . . . . . .. .. previous File Name. STSLIB.003 1.0.0 03/04/14 65535 LO STSLIB.002 ) 3S-16.tapx ) Name service unit DEPT FT ROP MWD030 FPH GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR NPHI MWD030 PU Min 4749 0.22 31.41 1.03 1.48 1.04 1.15 0.5314 18.14 Max Mean 6150 5449.5 303.61 150.329 132.35 100.805 2000 56.3651 2000 29.4185 2000 76.6012 2000 64.9674 177.603 20.3132 59.84 31.9901 page 8 Nsam 2803 2584 463 434 434 434 434 434 322 Fi rst Reading 4749 4749 5875.5 5897 5897 5897 5897 5897 5909.5 Last Reading 6150 6150 6106.5 6113.5 6113.5 6113.5 6113.5 6113.5 6070 Name Service order DEPT ROP MWD030 GR MWD030 RPX MWD030 RPS MWD030 RPM MWD030 RPD MWD030 FET MWD030 NPHI MWD030 FCNT MWD030 NCNT MWD030 RHOS MWD030 DRHO MWD030 PEF MWD030 units size Nsam Rep code offset channel FT 4 1 68 0 1 FPH 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 PU 4 1 68 32 9 CNTS 4 1 68 36 10 CNTS 4 1 68 40 11 GIcc 4 1 68 44 12 GIcc 4 1 68 48 13 BARN 4 1 68 52 14 # Data Format specification Record Data Record Type... .... ....... Data specification Block Type. Log~ing Direction............. optlcal log depth units....... Data Reference point.. ........ Frame spacing.. ........ ....... Max frames per record.... ..... Absent val ue. . . . . . . . . . . . . . . . . . . . Depth uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type o o Down Feet undefined 60 .1IN undefined -999 o # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) # TOOL STANDOFF (IN) EWR FREQUENCY (HZ) # REMARKS $ 3S-16.tapx 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: ) 1 1 1 2 11.00 45.0 9.3 400 3.6 800 491 700 100 84 102 8 84 ) o 8 4 o ) ) 3s-16.tapx FCNT MWD030 CNTS 13151.3 36527.2 23681.3 326 5907.5 6070 NCNT MWD030 CNTS 104.6 959.2 371.781 326 5907.5 6070 RHOB MWD030 G/CC 1.774 3.046 2.45835 354 5908.5 6085 DRHO MWD030 G/cc -0.037 0.373 0.0533136 354 5908.5 6085 PEF MWD030 BARN 3.23 16.3 5.65507 357 5907 6085 First Reading For Entire File .. .. .. 4749 Last Reading For Entire File. . . . . . .6150 File Trailer service name..... ...... STSLIB.003 service sub Level Name. version Number.. ....... 1.0.0 Date of Generation. .... 03/04/14 Maximum physical Record 65535 File T¥~e.......... LO Next Fl e Name..... STSLIB.004 physical EOF Tape Trailer Service name. ...... LISTPE Date. . . . . . . . . . . . . . . 03/04/14 ori gi n . . . . . . . . . . . . . STS Tape Name.......... UNKNOWN Continuation Number 01 Next Tape Name.. ... UNKNOWN Comments.......... . STS LIS writing Library scientific Technical services Reel Trailer service name....... LISTPE Date.............. . 03/04/14 Ori 1i n . . . . . . . . . . . . . STS Ree Name.......... UNKNOWN continuation Number 01 Next Reel Name UNKNOWN Comments. . . . STS LIS writing Library scientific Technical services physical EOF physical EOF End of LIS File page 9