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Home My WebLink About202-084 Image ,loject Well History File Cover F-,-"Je XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ¿:¿ Q:J..- 015 b} 'We II History File Identifier Organizing (dolH:~) RESCAN 'f5J Color items: 0 Two~Sided 7T:~s::t::, No. , 0 Other, Norrype (;J~ ,<escan Needed < " OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner lØ' Grayscale items: 0 0 Poor Quality Originals: 0 Other: OVERSIZED (Non-Scannable) 0 Logs of various kinds BY: BEVERLY ROBIN VINCENT SHERY~INDY 1 ( 0 Other DATE:] I otf Isl f) -Y11' NOTES: BY: BEVERLY ROBIN ~L' ~ f VINCENT SHER~INOY DATE:'/¡IO'+ Isl V)1IO.. ,~- ~ x 30 = 100 + I f = TOTAL PAGES 79 tr } VINCENT SHERY~ WINDY. DATE:1/leJf 151 yYlfJ ,i! J Project Proofing Scanning Preparation BY: BEVERLY ROBIN Production Scanning -" A Að Stage 1 PAGE COUNT FROM SCANNED FILE: ?š 0 êß.J..l!A./ p~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /' YES NO ! - - BEVERLY ROBIN VINCENT SHERYLBWINOY DATE: ß 9b 'ÓIfSI VV( J Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO BY: BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS Due TO QUALITY . GRAYSCALE OR COLOR IMAGES) ReScanned filHfÍ\'idp,,1 pH}" [:;¡''-'U,l/ ,lf101ltiOIl;'.<,(;,1ì,nillg Cf)mpl~tûd) RESCANNED Br: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ISI General Notes or Comments about this file: Quality Checked (dnllf.'\ 12/1 O/02Rev3NOTScanned. wpd e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) STATE OF ALASKA ) RE.CE\VED ALASKA OIL AND GAS CONSERVATION COMMISSION 2, ß '2.004 REPORT OF SUNDRY WELL OPERATIONEPEC , ,. . s¡OIl -r 1. Operations Performed: Abandon 0 RepairWell 0 Plug Perforations 0 Stimulate D. ',0.' &>a,'.'. CQI\,~I ~~-~ AlterCasing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 ~\a'~' Ti~e ~~9b' \i{.- rT Change APProv~~~;~rQam~ Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 0- 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory 0 202-084 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360 50-029-22641-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 68' 3M-29A 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk Oil Pool Total Depth measured 13314' feet true vertical 6066' feet Effective Depth measured 13314 feet true vertical 6276' feet Casing Length Size MD Structural CONDUCTOR 121' 16" 121' SURFACE 5759' 9-5/8" 5827' PRODUCTION 11532' 7" 11600' CSG WINDOW 4' 5-1/2" 11 600' OPEN HOLE 199' 2-7/8" 13314' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3422' 6015' 6015' Perforation depth: Measured depth: 11347-13081' SCANNED DEC 2 82004 true vertical depth: 5835'-6051' Tubing (size, grade, and measured depth) 3-1/2", L-80, 11530' MD. Packers & SSSV (type & measured depth) pkr= BAKER SAB-3 PERMANENT PACKER (BEHIND SLOTTED LINER) pkr= 11504' SSSV= NIP SSSV= 514' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 111 216 Not yet available Not yet available 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Oil-Bbl 60 Not yet available CasinQ Pressure 1107 TubinQ Pressure 121 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X WDSPLD Contact ", ,.'.' Bra...,d G athman~/.,M.,,~/ oveland@65-f224 p~inted Name ¿, /...lfi~ JJ- eland /." Title Signature .~r7ø' ~ "1 _// Phone J ///// ~~ Form 1 -404 Revised 04/2004 d~ Problem Wells Supervisor 907 -659-7224 Date ~ S -0 e c 0 '( ~ ~SUbmit Original Only ) 3M-29A ') DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/22/2004 Dummied off GL String, MIT IA pretest pressure - 2150/1550/170, Initial 2150/3000/170, 15 min 2150/2950/170, 30 min =2100/2950/170 - witness by Eddie Zemba 12/23/2004 RAN KOT AND FLAGGED FOR ETD TOOL. RAN ETD TOOL AND SET ECLIPSE PACKER @ 112601 RKB. RAN ECLIPSE TEST TOOL ( GOOD TEST ). PULLED DGL V FROM ST A # 4 ( 112481 RKB ) AND SET 1" DPHFCV IN ST A # 4. - 12/24/2004 SET JET PUMP @ 11260' RKB ITOP OF JET PUMP (K-3 PACKOFF-10' SPACER PIPE- JET PUMP-51 SPACER PIPE-SNAP LATCH = 2113" OAL) TOP OF K-3 @ 112381 RKB ( ASSEMBLY ST ADDLES GLM # 4 @ 112481 RKB )-( 3" RC JET-PUMP SER. PH-1119 AND HAS A 9-B RATION #9 NOZZLE I #10 THROAT). TESTED K-3 PACKOFF WI STANDING VALVE. SET SLlPSTOP ONTOP OF K-3 PACKOFF @ 11238' RKB. ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 3M-29A 12/22/04 Eddie Zemba - H ES Packer Depth Well 3M-29A Type Inj N T.V.D. 5945 Tubing P.T.D.2020840 Type Test P Test psi 1500 Casing Notes: Pre Surface Powered Jet Pump conversion MIT Pretest Initial 15 Min. 30 Min. 2150 2150 2150 2150 Interval 0 1550 3000 2950 2950 P/F P Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type I nj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Test Details: Producer MIT - before swapping from GL to Jet Pump TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT Report Form Revised: 05/19/02 MITP KRU 3M-29 12-21-04.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) 12/25/2004 [Fwd: Producer MITIA 3M-29 (PTD 202-084)] ') ') Subject: [Fwd: Producer MITIA 3M-29 (PTD 202-084)] From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 27 Dec 2004 13:55:38 -0900 To: Jim Regg <jim_regg@admin.state.ak.us> Jim, FYI. You weren't copied on this. I don't show that I have any emails on their changing the artificial lift method. Such a change is not an activity that would require a sundry. Doing an MIT on these type wells is something we have talked about for a while. It will be nice to see more such tests. Tom -------- Original Message -------- Subject: Producer MITIA 3M-29 (PTD 202-084) Date: Sat, 25 Dec 2004 14:02:34 -0900 From: NSK Problem Well Supv <n1.617@conocophillips.com> To: bob fleckenstein@admin.staLe.ak.us, Thomas Maunder <torn maunder@admin.state.ak.us> ...-.........-.........-............................-.....................-....-...................,..................-..................................-............-..-..... Bob and Tom, Attached is a pre surface powered jet pump conversion MITIA on a producer. Please let me know if you have any questions A lO-404 is in the mail. MJ Loveland ConocoPhillips Problem Well Supervisor' 659-7224 «MITP KRU 3M-29 12-21-04.xls» KRU 3M-29 Content-Type: application/vnd.ms-excel Content-Encoding: base64 SCANNED OEC 2 ? 2004 1 of 1 12/27/20041:56PM ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ) Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 3M-29A 12/22/04 Eddie Zemba - HES Packer Depth Well 3M-29A Type Inj N T.V.D. 5945 Tubing P.T.D. 2020840 Type Test P Test psi 1500 Casing Notes: Pre Surface Powered Jet Pump conversion MIT Pretest Initial 15 Min. 30 Min. 2150 2150 2150 2150 Interval 0 1550 3000 2950 2950 P/F P Well Type Inj TV.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj TV.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Jnterval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing I Jnterval P.TD. Type Test Test psi 1500 Casing P/F Notes: Test Details: Producer MIT - before swapping from GL to Jet Pump TYPE I NJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MITP KRU 3M-29 12-21-04-1.xls 12/27/2004 I,Co J'N~- , DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020840 MD 13314 .-- ---------- -- --- ._------.~-- Well Name/No. KUPARUK RIV UNIT 3M-29A TVD 6066 ./' Completion Date 5/16/2002 - Completion Status 1-01L Current Status 1-01L REQUIRED INFORMATION Samples No --------------- ~ ------ -- Mud Log No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type MedlFrmt SED -~C~--- I , Log Log Log Rpt : <RPi ,~ C , L-6g 1:óg Rpi trf)/ 6 ¡tog :-(og J4c ,~ MWD, GR, Memory RES Electr Dataset Number Name 11058 LIS Verification Gamma Ray Gamma.Ray Gamma ,Ray Directional Survey LIS Verification {1'057 Gamma LIS Verification Æ1134 Directional Survey. Gamma Ray GammaRay Gamma Ray LIS Verification Gamma ¡-tog ¡ Rpt l___--__- Well Cores/Samples Information: Name LIS Verification Interval Start Stop Operator CONOCOPHILLlPS ALASKA INC )/1 (fie!.. 5" Mt] ~'11 2- API No. 50-029-22641-01-00 UIC N Directional Survey No (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No 1 Interval OH / Start Stop CH Received Comments 11542 13089 Open 9/19/2002 PB 1 PB1 Also contains directional data for 3M-29A and 3M- 29APB1 13089 Open 10/8/2002 PB1 13089 Open 9/19/2002 PB 1 5 5 Blu Blu 11542 13089 Open 10/8/2002 11500 13315 Open 1 0/8/2002 11500 13315 Open 10/8/2002 12674 13314 Open 7/15/2002 11542 13089 Open 9/19/2002 11500 13315 Open 9/19/2002 11542 13089 Open 10/8/2002 11542 13089 Open 9/19/2002 11500 13315 Open 1 0/8/2002 12674 13314 Open 7/15/2002 11500 13315 Open 9/19/2002 11500 13315 Open 9/19/2002 11500 13315 Open 1 0/8/2002 5 Blu 5 25 Blu Blu 25 25 Blu Blu 25 Blu 11500 11542 11500 13315 Open 9/19/2002 Sent Sample Set Number Comments Received '--"'" PB1 PB1 PB1 - DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020840 Well Name/No. KUPARUK RIV UNIT 3M-29A Operator CONOCOPHILLlPS ALASKA INC MD 13314 1VD 6066 Current Status 1-01L Completion Date 5/16/2002 Completion Status 1-01L ADDITIONAL INFORMA~N Well Cored? Y ,Ø Daily History Received? CtbN {J/N Chips Received? <~ Formation Tops Analysis Received? ~- -- ----- ---- Comments: ---.-------- 'k Date: -.----- ----- Compliance Reviewed By: API No. 50-029-22641-01-00 UIC N ---- J-.1J~ ~~ .~ ) Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: Revised 3M-29A & 3M-29APB1 Contains the following (per well): 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary ) r&l. BAKER HUGHES Anchorage GEOScience Center 1 blueline - Gamma/Directional Measured Depth 1 blueline - Gamma/Directional TVD Depth 0 Please replace all deliverables for wells 3M-29A & 3M-29PB1 (delivered Sept 16) with the revised contents contained within. LAC Job#: 296123 Sent By: Glen Horel Received a- { d 000 f1' ~ Date: Oct 7, 2002 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 RECEIVED aOd-o~1 .~.. ..._~-- ~._.~...~,.'- ---..-- - .."-. .-.'.-.. I [";~~-~~:;~~~;J .. -.. ;,i;', :l:;;; ,::: -:..;.¡: ~~...... UrIfIt.... ........ ..' ~,~ ~l'It " ." ... :1NIm''''', '..wI ,"'~ It,' ~¡., .'O.. '''''' ..'. , .. ..,. .',¡ .... ,--------.------------.---- <IMHIÞ',", -III oV. ¡""" ,..-""'"~., ",".,...,..."'" :~:':'~.... l i--------~~~':'_----~-:'_----------_. ~WM' '''I MIjIll ...: ..'II ~l"" I., ., "'". ~I"" .. 'r". ~------------------------------------- -'.... '11IIIIIIII ... ~" ~'''''h' . . -:,..., -"'." . ......-----.-....--'.-.-_'r_"__..-.'"-'. : &H.~r::~\' -----,-... , . "-'-. ' '~ l " .~ OCT 0 8 2002 Alatka OH & Gas Cons. Cornmil8!Qn Anchorage . \ , ') aDa-O'6~ Transmittal Form r&.. BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 3M-29A & 3M-29PBl \ Contains the following (per well): I 11 II !' I !. I: \ 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - Gamma/Directional Measured Depth 1 blueline - Gamma/Directional TVD Depth I, ,I ¡! II I: ,I n I. LAC Job#: 296123 Sent By: Glen Horel ReceiVed~~(A~ Date: Sept 16, 2002 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ii--- "'"'''''-100.'''''''''''''' I :"'--"'-"._"\;~,:~;~ì:':I';:';¡:"'l;;""""". !:--'~ '" ~ :~ ~," :'..~ i ~"'" \~ :: I(I!.IIIQ'''I!':. "IØI ..~ .,'IS, ~!', =:2:~Tr ::::~:.., l ~ ~;::::~~~~:=~~,~-,~~~l:b I .~". '''¡',''., :MIùr:'WI ,.. "" I"~ .~(>' ..", .. .. ......'"J. ~ .. ------~~-~---~-~ ."----------- i ar-u.D",;~m "~ I... :!ìI8"'..- RECE\VED SEP 19 2002 Alaska O¡' & Gas Coos. Commission---_m- .-. Anchorage ....-.---- -~- ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well IBI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator Phillips Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 13321 SNL, 1756' WEL, SEC. 25, T13N, R08E, UM !"CÖP.1'PlETióÑl l£œÃ)-~ At top of productive interval ' DAre J' ~~. "'~ 2588' SNL, 4430' WEL, SEC. 35, T13N, R08E, UM . ~..'-,'It n ~ (J,:J,~, ':" Þ " . ,,' "1:1-"', ,"'~ At total depth VE1YJ1 ~ t.. 5:1:;) 'i 5. ~:~;;i::i~ :~;n~~;eS:~':: :t:~)N. R~E~~: ~å~d Se~~iÑo~:~ RKB = 68' ADL 025523 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 5/5/2002 5/14/2002 5/16/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 13314 6066 FT 13081 6052 FT IBI Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, Memory RES 23. CASING SIZE 1611 9-5/811 711 WT. PER FT. 62.58# 36# 26# 4.43# 2-3/811 Classification of Service Well 7. Permit Number 202-084 8. API Number 50- 029-22641-01 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3M-29A 11. Field and Pool Kuparuk River 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 513' MD Approx. 1380'ss 17tJ";1../-Þ-J.<J 1/ s;q~' /YIp GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 121' 2411 270 sx Arcticset I Surface 58271 12-1/411 1230 sx AS III, 730 sx Class 'G' Surface 11596' 8-1/211 200 sx Class 'GI 11334' 13115' 311 Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-3/8" Slotted Liner 311 Open Hole MD TVD MD TVD 11347' -13081' 5835' - 6052' 13115' -13314' 6052' - 6066' 27. Date First Production May 21, 2002 Date of Test Hours Tested 5/27/2002 18.2 25. SIZE 3-1/2", 9.3#, L-80 AMOUNT PULLED TUSING RECORD DEPTH SET (MD) 11530' PACKER SET (MD) 11503' 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 20001 Freeze Protected PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BSl TEST PERIOD 101 WATER-Bsl 793 WATER-Bsl Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL -BSl GAs-McF 162 GAs-McF GAS-Oil RATIO 1378 CHOKE SIZE 176 Oil GRAVITY-API (CORR) CORE DATA R F C F ~ \1 t [} Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. J! J '1 0 ?n~'ì No core samples were taken. '... ~ U <- v I,; :- 28. Form 10-407 Rev. 07-01-80 n r'} t (~\, ¡ r, f P, I ' ~ - . " . ,-- ¡ ~ \', \ I' ,,.\ ~I /' 'j " '\', : II t""j! :, ~ oj \:".t .. '.~ Alaska Ol! &. G;i,:~ (-'U(\~. i.;w:u.¡¡SSlûí AnchoraQe' R B 0 M S B FL SCSEP~ '2 rW1j~ In Duplicate G, Ý ) ') 29. Marker Name Geologic Markers Measured Depth 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR. and time of each phase. Base C4 12075' 6019' Top A2 Sand 12600' 6036' Top A1 Sand 127151 60451 Top A1 Sand 13040' 6053' ~11 ~~.. l". Ir~ ~ \.... f If'" D ," ~'~ ~.., ~ I r" I I, \, ~... Íi.,,,,. \1"" ~ ,,1 ',.." i,. !! ¡I '1 (> <"jon";> \.. \., :.... U L I.' i.." Alaska Oil & Gas Güns. (Jommìgf~¡ði! Anchoraoe 31. list of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Tenie Hubble 4 ~ ~ ~ Mfe Title Technical Assistant 3M-29A 202-084 Well Number Permit No. / Approval No. Date 07"/8 .o~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 .~F)I('~ r I ~" r : <" \...../ ¡,\ ~ t,./ J //~ f~ ) ) PHILLIPS PETROLEUM CO. . Operations Summary Report Page 1 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/30/2002 00:00 - 00:00 24.00 MOB N WAIT PRE Begin Standby Rate at 00:00 hrs on 4/30/02. Parked on 3C-04A while WOW (Phz 1 30-40 mph winds, drifting snow). Also, WO mousehole to be drilled on 3M-29. Weather conditions @ Phz 3 by midnight. 5/1/2002 00:00 - 00:00 24.00 MOB N WAIT PRE Continue to standby on 3C-04A while WOW & for mousehole to be drilled @ 3M-29. Normal driving conditions on main road & Phz 2 on all other roads as @ midnight. 5/2/2002 00:00 - 08:30 8.50 MOB N WAIT PRE Continue to standby on 3C-04A while WOW & for mousehole to be drilled @ 3M-29. 08:30 - 09:00 0.50 MOB P PRE SAFETY MEETING. Reviewed rig move procedure and all road I other conditions for rig move with all personnel. Ended rig standby for weather at 08:30 hrs. 09:00 - 15:30 6.50 MOB P PRE Moved rig to 3M Pad. 8.5 miles. No problems. Meanwhile field crew drilled 21 ft deep rathole and set 16" casing, 5 ft 3 in. center to center from front of tree. 15:30 - 16:00 0.50 MOB P PRE SAFETY MEETING. Reviewed rig back over well procedure, WHP and Flowline press bleed to 0 psi. 16:00-18:00 2.00 MOB P PRE ACCEPT NORDIC #1 ON KRU 3M-29A AT 16:00 HRS, 05/02/02. Perform general rig-up. Spot trailers, etc. 18:00 - 21 :30 3.50 BOPSURP DECOMP Nipple up BOPE. Made visual inspection of 2-3/8" pipe I slip rams, rubber still in new condition after drilling 2 sidetracks. Prep for BOPE test. Meanwhile spot & berm cutting tank & flowback tanks. 21 :30 - 00:00 2.50 BOPSURP DECOMP PJSM. Pressure tested BOPE to 3500psi as per drilling permit. Witnessing of test waived by State Rep John Spaulding. 5/3/2002 00:00 - 00:30 0.50 BOPSUR P DECOMP Continue P/testing BOPE. Check valve on kill line leaking - will rebuildlretest @ end of other tests. Meanwhile observe short in e-line. Bulkhead @ reel tests OK. Open up UQC & found wet e-line core. 00:30 - 01 :00 0.50 BOPSUR N SFAL DECOMP Suspend BOPE test. P/U injector & cut 55' of CT/e-line to locate dry e-line core. 01 :00 - 02:00 1.00 BOPSURP DECOMP Valve crew removed IA VR plug. 02:00 - 08:00 6.00 BOPSURP DECOMP Resume P/testing BOPE. Meanwhile take-on 210bbls of used 8.7ppg KCLlNACL milling Flo-Pro mud. Also M/U new BHI CTC & carried out successful continuity tests on e-line system. Pull test CTC to 20k & press test with inner reel valve to 3500psi - OK. 08:00 - 08:15 0.25 STWHIP P WEXIT SAFETY MEETING. Reviewed well plan and BHA MIU procedure and hazards. 08:15 - 09:15 1.00 STWHIP P WEXIT M/U straight motor and 2.80" HC, D331 Mill #1 [ Parabolic diamond mill]. 09: 15 - 11 :40 2.42 STWHIP P WEXIT RIH with BHA #1. Straight motor and 2.80" D331 Mill #1. 11 :40 - 12:40 1.00 STWHIP P WEXIT Tag fill at 11524' CTD, correct to 11,542 ft BKB, [+18 ft], assuming at D Nipple. Started milling. 1.5/1.5 bpm, 2800 psi, 700 WOB. Milling like cement. Slower milling from 11546 - 11548 ft. but unable to clearly see D Nipple milling. Milled to 11,548 ft. 7K dwn wt, 23K up wt. Back ream to 11532 ft. 12:40 -13:10 0.50 STWHIP P WEXIT Log GR tie-in at GR spike at 11500 ft. Ref. Perf log GRlCCL. -6 ft CTD. Corrected TD at 11,542 ft. Which is the D Nipple depth off the Printed: 5/20/2002 3:16:13 PM ) ) Page 2 of 16 PHILLIPS PETROLEUM CO. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: Code NPT 5/3/2002 12:40 - 13:10 13:10 - 13:50 0.50 STWHIP P 0.67 STWHIP P WEXIT WEXIT 13:50 - 15:20 1.50 STWHIP P WEXIT 15:20 - 15:40 0.33 STWHIP P WEXIT 15:40 - 16:10 0.50 STWHIP P WEXIT 16:10 - 17:00 0.83 STWHIP P WEXIT 17:00 - 19:15 2.25 STWHIP P WEXIT 19:15 - 19:45 0.50 STWHIP P WEXIT 19:45 - 20:45 1.00 STWHIP P WEXIT 20:45 - 21 :35 0.83 STWHIP P WEXIT 21 :35 - 21 :50 0.25 STWHIP P WEXIT 21 :50 - 00:00 2.17 STWHIP P WEXIT 5/4/2002 00:00 - 00:10 0.17 STWHIP P WEXIT 00:10 - 00:30 0.33 STWHIP P WEXIT 00:30 - 06:30 6.00 STWHIP P WEXIT 06:30 - 07: 15 0.75 STWHIP P WEXIT 07: 15 - 07:30 0.25 STWHIP P WEXIT 07:30 - 10:00 2.50 STWHIP P WEXIT 10:00 - 13:00 3.00 STWHIP P WEXIT perf record log. Mill down from 11542 - 11550 ft. Milling like cement. 20 fph, 2000# WOB, 1.5/1.5 bpm, Ream D nipple up I down twice. Milling Summary: Milled cement from 11536-11542 ft. Milled D Nipple at 11542-11543 ft. Milled firm cement 11543-11550 ft. 20 fph with 2200# WOB. POOH with milling BHA #1. Open circ valve and circ at 1.3 bpm, 1900 psi. Layout milling BHA #1. SAFETY MEETING. Held pre-spud Safety Meeting with crews and Phillips personnel. MIU BHA #2 with 1.75 deg motor and Mill #1 RR, 2.80", HC, D331 diamond mill. Added orienter to BHA. RIH with milling BHA #2. Open circ sub. Pump 0.3 bpm, 800 psi while RIH. RIH to 11500'. Meanwhile held prespud mtg with D. Venhaus & nite crew covering scope, objectives, critical issues, risks & contingencies of 3M-29A DOCTD operations. Log GR tie-in @ GR spike from 11500' & add 8' to CTD. RIH & tag TOC @ 11550'. Close EDC. Orient to 165-180TF & backream to 11524' (original tag). Mill down to 11552' (TT). Repeat milling passes @ 4 different quadrant TFs to cleanout cmt patches. Orient to 180TF & drill pilot hole interval from 11552' to 11588' @ 1.6/1.6bpm, 4k WOB, 3200/3460psi & 40fph ave Rap. Cmt quality is considered good as Rap drops to <20fph @ 2-3k WOB. Orient to HS TF & drill 8' cement ramp to 11596' @ 1.6/1.6bpm, 3.5k WOB, 3200/3550psi & 30fph ave Rap. Didn't see much erratic TF expected with a mechanical orienter. Paint EOP flag @ 11500'. Open EDC & POOH with milling BHA #2 @ 1.6bpm, 2500 psi. LID milling BHA #2. P/U window milling BHA #3 with HCC 2.8" DP0064 DSM (with brass ring guide) & 2.5 degs fixed motor. Open EDC & RIH with window milling BHA #3 @ 0.3 bpm, 800 psi. Stack out @ almost every tbg connection from 4524' (GLM) - orienting TF to rollover & fall thru. Continue working BHA in hole to 8630 ft. Close EDC, pump min. rate of 0.2 bpm, RIH easily, no more tags. RIH to Flag and correct +9 ft CTD. Log down across GR marker at 11,500 ft. Correct +1 ft to CTD. Total corr. = +10 ft. Up Wt. = 21 K, Dwn Wt. = 7K RIH. Dry Tag PBTD at 11596 ft. Pick up, Circ 1.5 bpm. TF at 0 deg. Tag at 11595', correct to 11596 ft. Flag CT. Pick up 1 ft. Time mill window as per time schedule. Start time milling at 07:40 hrs, at 11595 ft. 1.5/1.5 bpm, 3330 psi, TF = 0 deg. Milled to 11595.6'. Time Milling Window as per time schedule. TF = 5R, 1.5 11.5 bpm, 3300 psi, Printed: 5/20/2002 3:16:13 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 FrOtll- To Hours Task Code N PT Phase 5/4/2002 10:00 - 13:00 13:00 - 14:30 3.00 STWHIP P 1.50 STWHIP P WEXIT WEXIT 14:30 - 15:00 0.50 STWHIP P WEXIT 15:00 - 17:00 2.00 STWHIP P WEXIT 17:00 - 18:55 1.92 STWHIP P WEXIT 18:55-19:15 0.33 STWHIP P WEXIT 19:15 - 19:40 0.42 STWHIP P WEXIT 19:40 - 21 :50 2.17 STWHIP P WEXIT 21 :50 - 22:05 0.25 STWHIP P WEXIT 22:05 - 00:00 1.92 STWHIP P WEXIT 5/5/2002 2.50 STWHIP P WEXIT 00:00 - 02:30 02:30 - 04:30 2.00 STWHIP P WEXIT 04:30 - 05:00 0.50 STWHIP P WEXIT 05:00 - 05:15 0.25 DRILL P PROD1 05: 15 - 05:30 0.25 DRILL P PROD1 05:30 - 06:00 0.50 DRILL P PROD1 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 07:15 0.75 DRILL P PROD1 07:15 - 08:30 1.25 DRILL P PROD1 08:30 - 10:40 2.17 DRILL P PROD1 10:40 - 11 :00 0.33 DRILL P PROD1 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: [)éScriptionof ()perations 400-2200# WOB, Milled to 11597.1 ft. Time Milling Window. 1.5 11.5 bpm, 3380 psi, TF = 5L, 2500# - 1800# WOB, Milled to 11,598.6 ft. WOB is decreasing indicating mill is past half way point thru casing. Time Milling Window. 1.5/1.5 bpm, 3380 psi, TF = 5L, 1800 - 1200 # WOB, Exit casing with mill at 11,598.8 ft. Top of window at 11,596 ft,'" Bottom of window at 11,599 ft. Milling Formation, 1.5/1.5 bpm, 3220 psi, Stacking wt. Drill with 4000-5000# WOB. Drilled to 11608 ft. Back ream clean. Lost 5 bbls to formation while Drilling formation. 3 bbls I hr. fluid loss. POOH for Taper mill to dress window. Stop at 10500 ft and perform flow check. No Flow. POOH to 500 ft. Close EDC & check for flow - no flow. POOH to surface. OOH. LID window milling BHA #3. Wear on mill center indicates crossing csg wall. P/U window dressing BHA #4 with Baker cut-rite crayola mill & 1.75 degs motor. Open EDC & RIH with window dressing BHA #4 @ 0.2 bpm, 560 psi. RIH to 11500'. Log GR tie-in @ GR spike from 11500' & add 8' to CTD. Clsoe EDC. Drift thru pilot hole @ 180TF & thru cmt ramp @ HS TF. Stack out @ window. PUH to 11588'. RBIH to 11594' & bring on pumps. Stall 3x @ 11596.5', 1x @ 11597.7', 3x @ 11601.2', 2x @ & 11601.5' while reaming to btm @ HS TF, 1.5/1.5bpm, 3150/3600psi. Ream open hole to 11605'. Ream to btm @ 11608.4'. Make several backream passes @ various TFs & dress window clean. Drift window without pumping 6x - OK. Meanwhile swap hole to recycled 8.7ppg Formate Flo-Pro mud & take-on 250bbls of 10.4ppg KWF into upright. Open EDC & POOH with window dressing BHA #4 @ 0.8bpm, 1500 psi. IP/AP - 4135/3510psi. 3bph losses. POOH to 500 ft. Close EDC & check for flow - no flow. POOH to surface. OOH. LID window milling BHA #3. Mill wear indicates successful dry passes. Stab injector on well with UQC on. M/U & test drilling BHA #5 on catwalk. PJSM for slack management. RIU for slack management. Crew change & pre tour safety meeting. Reverse circ 2 CT volumes at max rate of 3.1 bpm at 3900 psi. for E-line slack management. Pumped 81 bbls. M/U Coiltrak BHA #4 with 2.80 deg motor and 2.75" DPI Bit #5. Check BHA for electric continuity. OK. CIO 2" CT pack-off. RIH. Pump full rate down CT thru open Circ sub. OK, still have continuity. RIH. Log tie-in with RA marker at 11,500 ft. Added 11 ft to CTD. RIH, Orient to high side. Close EDC. Went thru window clean Printed: 5/20/2002 3: 16: 13 PM PHILLIPS PETROLEUM CO. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: Date From-TO HoUrs Task COde NPT Phase DesctiptiOn ofOperatiöns 5/5/2002 10:40 - 11 :00 0.33 DRILL P PROD1 at 30R TF. 11 :00 - 11 :30 0.50 DRILL P PROD1 Drill build section. Tag TD at 11607 ft with pumps on. Drilling, TF = 5R, 1.5/1.5 bpm, 3400 psi, 120 fph, Drilled to 11632 ft and stalled motor. Fluid loss of 3 BPH. Short in Coiltrak at stall. Pull up thru window. 11 :30 - 14:30 3.00 DRILL N DFAL PROD1 CoilTrak has short. Pump bottoms up. Check surface bulkhead for short. Bulkhead connection was dry. Short is in BHA POOH to check BHA. 14:30 - 14:45 0.25 DRILL N DFAL PROD1 SAFETY MEETING. Reviewed CT cutting procedure and hazards. 14:45 - 18:00 3.25 DRILL N DFAL PROD1 At surface, layout CoilTrak BHA Found wet cable on BHA end of cable. Cut CT and E-Line until dry, total of 32 ft. Re-head. Press test CTC. 18:00 - 18:40 0.67 DRILL N DFAL PROD1 MIU Coiltrack BHA. 2.80 deg motor and 2.75" Bit #6. 18:40 - 20:40 2.00 DRILL N DFAL PROD1 Open EDC & RIH with drilling BHA #6 @ 0.1 bpm, 560 psi. RIH to 11500'. 20:40 - 20:50 0.17 DRILL N DFAL PROD1 Log GR tie-in @ GR spike from 11500' & add 9' to CTD. Up wt - 24k, Dn wt - 6k. 20:50 - 21:10 0.33 DRILL N DFAL PROD1 RIH thru window @ HS without bobbles. Close EDC. SID pumps & observe IP/AP of 2880/2850psi but coming down. Hydrostatic (AP) should be @ 2700psi - figure it takes a while for pressures to stabilize in gelled mud. RIH to btm. 21:10-22:20 1.17 DRILL P PROD1 Drill build to 11679' @ HS TF, 1.5/1.5bpm, 3125/3500psi, 3k DWOB & 50fph ave ROP. Had frequent motor stalls & ratty PIUs. IP/AP - 4550/3600psi. 1 bph losses. Landed build section with +1-93degs incl @ TD & decided to POOH for lateral BHA 22:20 - 23:20 1.00 DRILL P PROD1 Open EDC & POOH with drilling BHA #6 @ 1.5 bpm, 2780 psi & following 650psi pressure schedule for POOH to minimize pressure swings on shales. POOH to 5600' & re-evaluate shale stability risk while changing out BHA Decide to RBIH & circulate in KWF. 23:20 - 00:00 0.67 DRILL P PROD1 RBIH & start circ KWF @ 7600'. RIH to 11000'. 5/6/2002 00:00 - 00: 15 0.25 DRILL P PROD1 Continue RIH to 11524'. 00:15 - 00:35 0.33 DRILL P PROD1 Circulate 5 bbls of KWF out of EDC @ 1.5bpm 2400psi. 00:35 - 02:25 1.83 DRILL P PROD1 POOH with drilling BHA #6 circulating 1: 1 & holding 50psi WHP. 02:25 - 02:55 0.50 DRILL P PROD1 OOH. LID drilling BHA #6. Observe wear ring on bit gauge chamfer & backreaming cutters - explains ratty PIUs which may be due to piece of metal junk from the window. However no marks on other BHA component. 02:55 - 03:20 0.42 DRILL P PROD1 P/U lateral drilling BHA #7 with HYC 2.75" x 3.0" bi-center bit & 1.1 degs motor. 03:20 - 05:20 2.00 DRILL P PROD1 Open EDC & RIH with drilling BHA #7 circ KWF @ 0.3 bpm, 185psi (suprisingly low). Can't confirm loss rate as MM out is by-passed for taking returns to clean tigger tank. RIH to 11500'. 05:20 - 05:30 0.17 DRILL P PROD1 Log GR tie-in @ GR spike from 11500' & add 6' to CTD. Start swaping 10.4ppg KWF to 8.7ppg mud. Pumped a total of 170bbls of KWF. 05:30 - 05:45 0.25 DRILL P PROD1 RIH thru window @ HS without bobbles. Close EDC. RIH to btm. 05:45 - 07: 15 1.50 DRILL P PROD1 Drill lateral @ 90-1 OOTF, 1.5bpm, 3050/3350psi, 3k DWOB. Incl = 93.5 deg. 60 FPH. Drilled to 11,772'. Printed: 5/20/2002 3: 16: 13 PM ) ) PHILLIPS PETROLEUM CO. Operations Summary Report Legal Well Name: 3M-29 Common Well Name: 3M-29A Spud Date: 1/20/1996 Event Name: REENTER+COMPLETE Start: 4/30/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 5/16/2002 Rig Name: NORDIC 1 Rig Number: From- .To HoUrs Code NPT ÐescriptiOn.....of.Oþeratiol1s 5/6/2002 07: 15 - 08:25 1.17 DRILL P PROD1 Drilling, 1.5/1.5 bpm, 3050 I 3200 psi, 3.2K WOB, Incl = 94.5 deg. 60 FPH. Drilled to 11,830 ft. 08:25 - 08:40 0.25 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 08:40 - 10:50 2.17 DRILL P PROD1 Drilling, 1.5/1.5 bpm, 3050 I 3600 psi, 2300# WOB, TF = 90R, Incl = 92 deg, 80 FPH, Drilling in A1 lower sand. Drilled to 11,950'. 10:50 -11:30 0.67 DRILL P PROD1 Drilling, 1.5/1.5 bpm, 3100 I 3600 psi, 2300# WOB, TF = 90L, Incl = 92.5 deg, Drilled to 11,969 ft. Stacking wt. 11 :30 - 12:00 0.50 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 12:00 - 14:45 2.75 DRILL P PROD1 Drilling, 1.5/1.5 bpm, 3200 I 3800 psi, 2300# WOB, TF = 90L, Incl = 94.7 deg, Plan to drill up to 5952' TVDSS at 94 deg. Hit slow drilling stringer at 11990 ft. Added 170 bbls new Formate FloPro. Higher viscosity increased pump press by 500 psi. Drilled to 11,997 ft. 14:45 - 17:30 2.75 DRILL P PROD1 Drilling, 1.5/1.5 bpm, 3600 I 3900 psi, 3800# WOB, TF = 100L, Incl = 94.7 deg, Very slow I hard drilling from 11990-12005 ft. 3-4000# WOB, Several stallslstacking wt. Fluid loss of 2 BPH. Drilled to 12,015 ft. 17:30 - 19:45 2.25 DRILL P PROD1 Drilling, 1.5/1.5 bpm, 3350 I 3900 psi, 2-3000# WOB, TF = 70L, Incl. = 94 deg. Slowly grind on to 12022 ft. Getting good wt transfer but no reactive torq or drill off with 4k DWOB & 550psi motor work. Geo picking up some ankerite-cemented formation in samples. Decide to wiper & cycle EDC to ensure it is fully closed. 19:45 - 20:30 0.75 DRILL P PROD1 PUH & observe motor work @ 11988'. Continue wiper trip to window. Cycle EDC. RBIH clean to btm. 20:30 - 22:45 2.25 DRILL P PROD1 See motor work @ 12018'. Spud bit to drill - no progress. Patiently grind-on & control-drill with @ 60psi motor work & 1 k WOB. Finally broke thru. Drill ahead to 12028' & observe @ 5bph losses. Ream & backream hard spot to ensure BHA pass is clean. 22:45 - 00:00 1.25 DRILL P PROD1 Drill ahead to 12053' @ 240TF, 1.5/1 Abpm, 3250/3550psi, 2k WOB & 25fph ROP. IAlAP - 4450/3730psi. Getting better reactive & motor work now. Losses increase to 9bph. 5/7/2002 00:00 - 00:50 0.83 DRILL P PROD1 Drill ahead to 12059' @ 270TF, 1.5/1.35bpm, 3300/3550psi, 2k WOB & 20fph ROP. IAlAP - 4350/3750psi. Drill into another hard streak. Not getting any drill off. Stacking wt. 9bph losses. 00:50 - 01 :10 0.33 DRILL P PROD1 100' Wiper trip. RBIH to btm & get wt back. 01 :10 - 03:40 2.50 DRILL P PROD1 Attempt to drill-on @ 12059' - no success. Grind on to 12064' - getting motor work & occasional reactive, but no drill offs. 9bph losses. Decide to POOH to check BHA to ensure we don't have any other downhole BHA problems. 03:40 - 05:10 1.50 DRILL P PROD1 Lay-in 20bbls of flo-vis pill on btm to minimize losses. Start KWF downhole. 05: 1 0 - 06:00 0.83 DRILL P PROD1 Open EDC. POOH with drilling BHA #7 circulating 10Appg KWF @ 1:1 & holding 50psi WHP. 06:00 - 06:30 0.50 DRILL N SFAL PROD1 1 Gal. Drilling Mud spill to pad. 4" mud charge pressure line leaked drilling mud where line exits mud pit Mud leaked out Printed: 5/20/2002 3: 16: 13 PM ') ') PHILLIPS PETROLEUM CO. Operations Summary Report Page 6 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: 5/712002 06:00 - 06:30 0.50 DRILL N SFAL PROD1 wall of mud pump room onto pad. Isolated leak. Does not leak with charge pump off. Called KRU Enviromental and reported spill to all responsible KRU and BPX supervisors. Fully cleaned up mud spill on pad. Vac'd out mud pits using 2 vac trucks. 06:30 - 07:30 1.00 DRILL P PROD1 POOH with BHA. 07:30 - 09: 15 1.75 DRILL P PROD1 At Surface, check bit, center PDC's OK, gauge cutters broken but still OK for drilling. C/O motor, check CT connecter for wash out. Test BHA. Coiltrak BHA OK. M/U new Bit #8, HC Bi-center, 4 bladed bit with better gauge protection. 09:15 - 11 :30 2.25 DRILL P PROD1 RIH with CoilTrak BHA #8, 1.1 deg motor, Bit #8, HC Bi-Center. 11 :30 - 11 :50 0.33 DRILL P PROD1 Tied-in with RA marker at 11,500 ft. Log down, Added 7 ft to CTD. Circ out brine while logging tie-in. 1 bpm, 1900 psi, recover brine. 11:50-12:15 0.42 DRILL P PROD1 RIH to TD. Clean Hole. Tag TD at 12,070 ft. 12:15 -14:15 2.00 DRILL N SFAL PROD1 BHI CoilTrak surface computer not keeping MWD data. Re-boot computer. Data base had overloaded. 14:15 -16:30 2.25 DRILL P PROD1 Drilling, 1.5/1.5 BPM, 3340 psi, TF = 45R, Incl = 92 deg. Several stalls. Full returns. CT Sliding problems, added Lubetex for better lubricity. Drilled to 12,099 ft. 5950'SS. Geologist decided to drill with lowside TF to get deeper TVDSS. Samples show we were close to Kalubik Shale. 16:30 - 18:30 2.00 DRILL P PROD1 Drilling, 1.5/1.5 BPM, 3340 psi, TF = 180, Incl = 90 deg. Several stalls. Slow drilling. 18:30 - 19:30 1.00 DRILL P PROD1 12140', Drilling ahead. Slow drilling. 20 fph. 19:30 - 20:30 1.00 DRILL P PROD1 12156', Slow drilling, although we are drilling A1 sand according to Geo. 1.5/1.4/3430 psi, 235 TF, ROP=59 fph, Pit vol=197 bbls. 20:30 - 21 :25 0.92 DRILL P PROD1 12167', 1.5/1.4/3300 psi. Contiued slow drilling. Pit Vol=193 bbls. Continuing to loose fluid. 21:25 - 22:15 0.83 DRILL P PROD1 12200', Wiper trip to shoe. Clean PU off bottom at 20klbs. Small amount of motor work at 11644', slow and backream thru. Clean RIH. 22: 15 - 23:30 1.25 DRILL P PROD1 Back on bottom, resume drilling. Still in A1 sand, continuing to hold 85 deg, dropping TVD in anticipation of crossing fault. 1.5/1.4/3650 psi. Free spin 3120 psi. Pit level 175 bbls. 23:30 - 00:00 0.50 DRILL P PROD1 12246', Update at 23:30. Pit volume=164 bbls. 5/8/2002 00:00 - 00:20 0.33 DRILL P PROD1 Drilling lateral section fr 12275'. 00:20 - 01 :15 0.92 DRILL P PROD1 Update at 00:20. 12286', 1.5/1.4/3600, Pit vol 154 bbls. ROP 50 fph. 01 :15 - 02:00 0.75 DRILL P PROD1 12350', Wiper trip to shoe. Clean PU off bottom at 20klbs. 02:00 - 04:00 2.00 DRILL P PROD1 Resume drilling. Pit volume=136 bbls. 1.5/.3/3730. 04:00 - 04:45 0.75 DRILL P PROD1 12487', Lost all returns. Probably fault expected at 12450'. Attempt to drill ahead and generate some cuttings. Returns coming back, now at 1.4/0.7/3200 psi. Pit vol=11 0 bbls. 12493', returns now 1.5/0.9. Taking on 200 bbls of new mud. 04:45 - 05:40 0.92 DRILL P PROD1 12517', Returns still 50% on bottom. Pumping 1.5, getting back 0.8. Drilling an additional 30' did not seem to help, after Printed: 5/20/2002 3: 16: 13 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PHILLIPS PETROLEUM CO~ Operations Summary Report 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: 5/812002 04:45 - 05:40 FrQm... To Hours 05:40 - 07:00 07:00 - 08:45 08:45 - 09:00 09:00 - 10:00 10:00 - 10:20 10:20 - 11 :00 11 :00 - 12:30 12:30 - 15:00 15:00 - 16:00 16:00 - 17:30 17:30 - 19:00 19:00 - 20:00 20:00 - 20: 1 0 20: 1 0 - 20:55 20:55 - 21 :20 21 :20 - 21 :35 21 :35 - 22:00 22:00 - 00:00 5/9/2002 00:00 - 01 :00 01 :00 - 02:30 0.92 DRILL P 1.33 DRILL P 1.75 DRILL P 0.25 DRILL P 1.00 DRILL P 0.33 DRILL P 0.67 DRILL P 1.50 DRILL P 2.50 DRILL P 1.00 DRILL P 1.50 DRILL P 1.50 DRILL P 1.00 DRILL P 0.17 DRILL P 0.75 DRILL P 0.42 DRILL P 0.25 DRILL P 0.42 DRILL P 2.00 DRILL P 1.00 DRILL P 1.50 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 initial improvement. Short trip to shoe. PU off bottom clean at 21 klbs. Back on bottom. 1.5/0.8/3500, Still only getting 50% returns. 256 bbls in pits. Call for 400 bbls new mud, plan to drill an additional 70', for at total of 100' past fault to see if drill solids help stop losses, then confer with town about LCM. ROP 87 fph. Returns getting better. Drilling at 12,577 ft. 1.4/0.9 bpm. 60% returns. Drilling, 1.4/0.9 bpm, 60% Returns, 3330 psi, TF = 120R, ROP = 80 FPH, Incl = 88 deg. Build 15 PPB Mix 2 Fine LCM 25 bbl pill. Drilled to 12,680 ft. Close choke, stop pump, open circ sub. SIWHP = 520 psi, Res press. = 3235 psi, Res. Grad. = 10.4 PPG. Lay in 25 BBI of 15 PPB LCM pill at 1.3 bpm, Lay in 10 bbl below fault at 12487 ft, pull 1 0 ft above with no overpull. RIH to 30 ft below fault and lay in 5 bbl LCM. 1.3 I 0.8 bpm, No reduction in losses from LCM. Lay in last 10 bbls at 0.6 I 0.2 bpm while holding 300 psi WHP and POOH at 30 fpm. No response yet from LCM. Lay in LCM to window. Wiper trip up to 10000 ft. 1.51 1.0 bpm. POOH at 60 FPM, 21 K up wt. Stop at 10000 ft. Circ. 1.5/1.1 bpm. Still have 0.4 bpm losses at 10000 ft. RIH to 11,500 ft. 1.2/1.1 bpm while RIH. Log tie-in with RA marker at 11,500'. Added 16 ft to CTD. RIH to TD. Clean hole. Tagged TD at 12,689 ft. Drilling, 1.4/1.1 bpm, 2920/3500 psi, TF = 100R, 80 fph, 86 DEG. INCL. Drilled to 12,734 ft. Drilling, Geo. decided to turn up and drill to 5967' SS. 1.4 11.1 bpm, 3000 I 3460 psi, TF = 25-80R, 40 FPH, Drilled to 12,803 ft. Drilling, Found good A1 sand again at 12,830 ft. 1.4/1.1 bpm, 3000 - 3300 psi. TF = 120R, Drilled to 12850 ft. Wiper trip to window. Clean hole. RIH. 1.3/1.0 bpm, 2680 psi. Drilling, 1.5/1.2 bpm, 3100 I 3600 psi, Incl. = 93 deg. 12937', Drilling ahead. 1.5/1.1/3340 psi. Current free spin 2950 psi. 176 bbls pit vol. 12966', Very slow ROP. Short trip to window. Clean PU off bottom. Open EDC, Kick on pumps to 2 bpm, PUH at 50 fpm, Returns 1.2 bpm. Wash tubing up to 10500'. Getting significant cuttings accross shaker. Log tie in pass down at 170 fph, from 11500'. Make +10' correction. Shut EDC, continue wiper trip in hole. 1969', resume drilling. 1.1.5/1.23400 psi, 3100 psi free spin. Pit vol=294 bbls. (Took on 100 from vac truck). 13009', Continue drilling ahead. 1.5/1.2/3300, pit vol=265 bbls. Still loosing at 18 b/hr. 13029', Update at 01 :00. 1.5/1.2/3260. Drilling high gamma Printed: 5/20/2002 3:16:13 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: HOUrs Task Code NPT Phase 5/9/2002 01 :00 - 02:30 1.50 DRILL P PROD1 rock all tour so far. ROP low. Pit vol at 01 :00=244 bbls. 02:30 - 04:00 1.50 DRILL P PROD1 13040'. Confer with town. Geo uncertain as to TVD depth of A 1 sand. Thinks we are below A 1 sand in the Miluveach shale. Plan forward is to drill up at 98 deg to find sand, then consider sidetrack. 04:00 - 05:00 1.00 DRILL P PROD1 13047'. 1.5/1.2/3200 psi. Difficult drilling. Pit Vol=176 bbls. Geo now thinks we are above A1 sand in Kalubik shale! Continue drilling pilot hole up at 98 deg to confirm. 05:00 - 06:00 1.00 DRILL P PROD1 13056', take on an additional 100 bbls of new mud. Continue drilling up. 06:00 - 09:30 3.50 DRILL P PROD1 13064', 1.5/1.3/3225, Continued hard drilling. Trying to build to 98 deg incl and drill up. Drilled to 13,086 ft. Incl = 96.5 deg at TD. Change in plan. Geology decided we were in Kalubik Shale so need to drill down to find A1 sand. 09:30 - 10:30 1.00 DRILL P PROD1 Drilling, TF = 108R, 1.5/1.2 bpm, 3100/3400 psi. Drilled to 13,088 ft. Geology decided on open hole sidetrack to get deeper TVD. 10:30 - 13:00 2.50 DRILL C PROD1 POOH for open hole sidetrack at 12,690 ft. Trap 650 psi at surface. 13:00 - 13:30 0.50 DRILL C PROD1 SAFETY MEETING. Review Press Undeployment procedure and Hazard mitigation. 13:30 - 15:15 1.75 DRILL C PROD1 SIWHP = 270 psi. Press Undeploy BHA. Change out bit and adjust motor to 2.30 deg bend. Check SIWHP. SIWHP = 0 psi. Monitor SIWHP for 30min. Well dead. Deploy BHA #9. 15:15 -15:30 0.25 DRILL C PROD1 RIH with BHA #9,2.3 deg bend motor and 2.75", DPI bit #9 for OH sidetrack. 15:30 - 16:00 0.50 DRILL X RREP PROD1 Install calibrated pressure transducers on Rig Mud pump line and at CT reel. Test: pump 1.5 bpm, CT = 2000 psi, Pump = 2420 psi, pump 0.2 bpm, CT = 670 psi, Pump = 760 psi. 16:00 - 16:45 0.75 STKOH C PROD1 RIH with BHA#9. 16:45 - 17:00 0.25 STKOH C PROD1 SAFETY DRILL: Held H2S drill with Rig Evacuation. All personnel accounted for at muster area. 14 total. Reviewed H2S rig evacution drill procedure and H2S gas characteristics and hazards. 17:00 - 17:45 0.75 STKOH C PROD1 Cont RIH with BHA #9. 17:45 - 18:05 0.33 STKOH C PROD1 Log GR tie-in at RA marker at 11,500 ft. Added 6 ft to CTD. 18:05 - 18:50 0.75 STKOH C PROD1 RIH 18:50 - 19:55 1.08 STKOH C PROD1 Begin Trough down from 12675' at 15 fph as per plan. Free spin 2900 psi. 1.5/1.1 TF 200 deg (160L). Pit Vol=240 bbls. 19:55 - 20:15 0.33 STKOH C PROD1 Flag pipe at 12690', backream up at 1 fpm to 12670'. 20:15-21:35 1.33 STKOH C PROD1 Second down troughing pass from 12675' to 12690' at 15 fph, TF 200 deg (160L), Pit vol=21 0 bbls. Free spin now 2950 psi at 1.5 bpm. Got 150 Ibs motor work on last 4'. 21 :35 - 21 :50 0.25 STKOH C PROD1 Second backreaming pass up at 1 fpm to 12670'. 21:50-23:15 1.42 STKOH C PROD1 Third down troughing pass from 12675'-12690' at 15 fph. TF 200 deg (160L), Pit Vol=176 bbls. Free Spin now 2950 psi at 1.5 bpm. 100 Ibs motor work for last 1 '. 23:15 - 23:30 0.25 STKOH C PROD1 Stop at flag for 15 minutes. 240 Ibs weight on bit and 100 Ibs motor work when first stopping at bit Drilled off on both pressure and WOB after 3 minutes. 23:30 - 00:00 0.50 STKOH C PROD1 Begin time drilling at 0.1 '/6 minutes (1 fph). 1.6/1.2/3150, Printed: 5/20/2002 3: 16: 13 PM Operations Summary Report Legal Well Name: 3M-29 Common Well Name: 3M-29A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Code NPT 5/9/2002 23:30 - 00:00 0.50 STKOH C PROD1 5/10/2002 00:00 - 01 :05 1.08 STKOH C PROD1 01 :05 - 01 :10 0.08 STKOH C PROD1 01 :10 - 02:05 0.92 STKOH C PROD1 02:05 - 03:30 1.42 STKOH C PROD1 03:30 - 03:50 0.33 STKOH C PROD1 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: Descriptiön...of.Qþeratiöns 03:50 - 04:20 0.50 STKOH C PROD1 04:20 - 05:00 0.67 STKOH C PROD1 05:00 - 05:25 0.42 STKOH C PROD1 05:25 - 06:00 0.58 STKOH C PROD1 06:00 - 06:45 0.75 STKOH C PROD1 06:45 - 08:00 1.25 STKOH C PROD1 08:00 - 09:00 1.00 STKOH C PROD1 09:00 - 11 :00 2.00 STKOH C PROD1 11 :00 - 13:30 2.50 STKOH C PROD1 13:30 - 14:30 1.00 STKOH C PROD1 14:30 - 16:00 1.50 STKOH C PROD1 WOB=-3.85 Ibs. Pit vol=287 bbls. Continue Sidetrack at 12690.5'. 1.5/1.1/2970, TF160L, Pit Vol=276 bbls. 12691.7'. Coil appeared to be stacking in hole for last .5', No WOB or motor work observed for last 5, 0.1' clicks. Pickup. 3000 Ibs overpull on pickup. Pull up to 12685', RIH at 15 fph. 12691.2', Begin time drilling down at 0.1'/6 minutes. Getting 400 Ibs on WOB sensor. Getting drilloffs. 12691.7', Appear to be stacking again. Pickup 10' WOB sensor reads -66 Ibs on pickup. RIH to 12791.7' again, free spin 3035 psi. 12693'. Completed time drilling program at 1 fph. Begin time drilling at 2 fph (0.1'/3minutes) as per schedule. Seem to be stacking pipe again. Pickup at 35klbs, should be 20klbs. Probably differentially sticking. Finally broke back. PUH to 12670', RIH 12692.5', Back on bottom. WOB=434 Ibs, String weight=3800 bls. CTP=3066 psi, TF=200 deg (160L). Resume time drilling at 0.1'/6 min. 12693', seem to be carrying weight better, and are not stacking pipe. Begin time drilling at .1'/3min. WOB=367 Ibs. 12694.5'. Stacking weight again. String weight -1000 Ibs, no increase in WOB on last 0.5'. PU at 30klbs, overpulled, then broke over to 20klbs on up weight. RIH and resume time drilling. 12694.3', Resume time drilling. 1.5/1.1/3070 psi. TF 160L, WOB=635Ibs. String weight=2200 Ibs. Pit vol=251 bbls. Not seeing any motor work. 12696.3', Stacking weight again. PU at 39klbs, then broke back to 20klbs. RIH slow. Stacking wt. Back ream 80 ft. RIH to 12694 ft. 12694 ft. 3022 psi, 1.4 bpm, 1.4/1.1 bpm. 160L, Time drilled to 12695.6 ft. Stacking wt again. Added 2 drums of Lubetex and 1 drum FloLub. Wiper trip to window to clean up open hole while getting higher lubricity FloPro circulated. 22.6 K up wt. RIH. Much better down wt at 12,690 ft. 5K dwn wt vs. 3 K dwn wt before adding lub. Ream down at 2 FPM from 12675-12690'. Saw WOB increase to 200# at 12690'. Stop and Time drill at 12690-91 ft. 1 FPH. 1.4/1.1 bpm, 2960 psi, TF = 160L, 0 WOB, 4500# CT wt. CT sliding OK. Drilled 2 FPH 12691-93'. Time drilling at 2 FPH, had motor work and 150# WOB at 12693.1 ft. 500# WOB at 12694 ft. Time drilling 4 FPH at 12694-98'. Looks good, motor work and up to 1200# WOB. Time drilling at 8 FPH, 1.4 11.1 bpm, 2850 psi, TF = 160L, Drilled to 12704'. Kicked off on new open hole section. Drilling ahead at 24 FPH. 1.4 11.1 bpm, 2900 psi, TF = 160L, to 12710 ft. Drilling at 40 FPH to 12715 ft. Surveys show we are away from Printed: 5/20/2002 3:16:13 PM ) ') PHILLIPS PETROLEUM CO. OperationsSu m maryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: Date From - To Hours Task Code NPT Phase Description of Operations 5/10/2002 14:30 - 16:00 1.50 STKOH C PROD1 old hole. Drilling 50 FPH, TF = 90L, 3100 I 3400 psi, 2300-3600# WOB. Drilled to 12725 ft. Orient to 160R, backream up to 12670 ft, RIH and drill to 12,735 ft. 16:00 - 17:00 1.00 STKOH C PROD1 Drilling, 1.4/1.1 bpm, 3100 I 3400 psi, TF = 130R, Drilled to 12,750 ft. Back ream sidetrack at 90R, Backream sidetrack at OR TF. 17:00 - 19:30 2.50 STKOH C PROD1 POOH with OH sidetracking BHA. Open circ sub at window. POOH following choke schedule for WHP. 19:30 - 19:45 0.25 STKOH C PROD1 Stop at 200', Trap 650 psi, bleed off slowly. Open 2" line, bleed stack to 0 psi, standby for no flow test. Well flowing. Treat as live well, and proceed to pressure undeploy. 19:45 - 19:50 0.08 STKOH C PROD1 POH, tag up at surface, pressure up WHP to 500 psi. SI choke, SD pumps. WHP bled down to 240 psi. 19:50 - 20:10 0.33 STKOH C PROD1 Safety meeting prior to undeployment of BHA. 20: 1 0 - 22:00 1.83 STKOH C PROD1 Undeploy Sidetrack BHA. 22:00 - 00:00 2.00 STKOH C PROD1 Weekly BOP test. Pull and inspect 2-3/8" Combi BOP rams. Rams checks ok. Proceed with BOP test. 5/11/2002 00:00 - 03:00 3.00 STKOH C PROD1 Weekly BOP Pressure Test. 2-3/8" pipe rams visually inspected prior to BOP test. Looked in "like new" condition. BOP test passed ok. 03:00 - 03:25 0.42 STKOH C PROD1 Safety meeting prior to pressure deployment. 03:25 - 05:00 1.58 STKOH C PROD1 Make up BHA #10. 1.1 deg extreme motor, 2.70-3.0" HC bicenter bit. 05:00 - 06:45 1.75 STKOH X RREP PROD1 Halt deployment of BHA to repair hydraulic hose on tugger. 06:45 - 07:00 0.25 STKOH C PROD1 SAFETY MEETING. Review Press Deployment Procedure. Review hazards. 07:00 - 07:45 0.75 STKOH C PROD1 Open pipe rams. Check SIWHP. SIWHP = 20 psi and slowly dropping. Surface check Coiltrak BHA. OK. 07:45 - 09:45 2.00 STKOH C PROD1 RIH with BHA #10. Hold 400 psi WHP at start. Follow choke schedule as RIH. 09:45 - 10:00 0.25 STKOH C PROD1 Log tie-in at 11500'. Added 3 ft to CTD. 10:00 - 11 :00 1.00 STKOH C PROD1 Run thru window at high side, close circ sub, RIH. Stop at 12665 ft and get survey. Survey did not correlate. 11 :00 - 11 :30 0.50 STKOH C PROD1 Pull back to window taking surveys every 100 ft, to check correlation with previous surveys. Surveys are not within tolerance. 11:30-13:30 2.00 STKOH X DFAL PROD1 POOH to change out Coiltrak BHA. Circ. 1.4 bpm, Follow choke schedule. 13:30 - 14:00 0.50 STKOH X DFAL PROD1 SAFETY MEETNG. MonitorWHP. Well dead. 14:00 - 17:00 3.00 STKOH X DFAL PROD1 Layout BHA #10. Check survey tools out on well pad. Found Coiltrak BHA was magnetized. Added motor and saw 6 degree shift in Azimuth. Motor magnetized also. Change out BHA and motor. 17:00 -18:00 1.00 STKOH X DFAL PROD1 M/U BHA #11 18:00 - 20:45 2.75 STKOH X SFAL PROD1 Repair umbilical cable from reel to Baker logging cabin. Was damaged earlier today when Schlumberger was taking measurements of reel for construction of Nordic 2. Repairs required prior to surface testing drilling BHA. 20:45 - 21 :00 0.25 STKOH X DFAL PROD1 Check Drilling BHA #11. All eq appears to work properly at surface. 21 : 00 - 21 : 1 0 0.17 STKOH X DFAL PROD1 Chain down injector. Prepare to RIH. Printed: 5/20/2002 3: 16: 13 PM ) ') Page 11 of 16 PHILLIPS PETROLEUM CO. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Spud Date: 1/20/1996 End: Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: 5/11/2002 5/12/2002 COde.. NPT 21:10 - 23:00 1.83 STKOH X DFAL PROD1 RIH with BHA #11. Hold pressure as per choke proceedure in well plan. 23:00 - 23:20 0.33 STKOH C PROO1 Log tie in pass from 10500'. Make +6' correction. 23:20 - 00:00 0.67 STKOH X RREP PROO1 Mud Pump #2 down. Can not go into open hole with only 1 pump. Standby at window for rig mud pump repairs. 00:00 - 01:10 1.17 STKOH X RREP PROD1 Continue to standby, waiting on pump repairs. 01:10 - 03:20 2.17 STKOH X OFAL PROD1 While sitting waiting for pump #2 to be fixed, BHI reports their Coiltrack tools are no longer working. POOH to make repairs to BHA. Attempt to follow TOOH pump schedule in proceedure, but had 100% losses. Reduced surface pressure to 250 psi to get returns back. Held constant 250 psi to get OOH. 03:20 - 03:30 0.17 STKOH X DFAL PROD1 Tag up at surface. Check for flow. No flow observed. Bleed lubricator. 03:30 - 04:30 1.00 STKOH X DFAL PROD1 Troubleshoot problem. BHI found shorted pin in upper quick connect. Repair problem. Verify BHA is working correctly. 04:30 - 06:30 2.00 STKOH X DFAL PROD1 RIH with BHA. Stop at 200', open EDC, cycle orienter, confirm that BHA is working properly, RIH, pumping at 0.3 bpm following RIH pump schedule from procedure. SWS pump truck on location at 04: 15 to act as backup to 1 function rig pump. Rig pump repaired at 05:00. 06:30 - 07:00 0.50 STKOH X SFAL PROD1 BHI CoilTrak data base was full. Down load data and reload software. 07:00 - 07: 15 0.25 STKOH C PROO1 Log Tie-in with GR marker at 11,500'. Added 3 ft to CTD. 07:15-08:15 1.00 STKOH C PROD1 RIH to 12741 ft. POOH taking surveys, getting magnetic interference, 1 good survey, max difference in Azimuth in original hole was 6 degrees. Inclination readings are good. 08:15 - 10:00 1 .75 STKOH C PROD1 Drilling sidetrack, 1.4 11.1 bpm, 3050 I 3600 psi, TF = 170L, Oriling shale, slow ROP. Drilled to 12773 ft. Back ream to 12600'. Had 20K over pull at 12690 ft, OH sidetrack depth, packed off also, worked free. 23K up wt at 12600'. 10:00-11:15 1.25 STKOH C PROD1 RIH and entered old hole. Ream OH sidetrack area of 12690 ft. Ream down from 12675' at 165L TF at 1 FPM. to 12730 ft. Ream down to 12785', still in old hole. 11:15 -12:15 1.00 STKOH C PROD1 Ream down from 12675' at 90L, [original hole was drilled at 90R], at 1 FPM, 1.4/1.1 bpm, 2850 psi, Ream down to 12790 ft. Still in old hole. Unable to enter sidetrack hole. 12:15 - 14:30 2.25 STKOH C PROO1 POH for OH sidetrack motor and bit. 14:30 - 16:30 2.00 STKOH C PROD1 At surface, Well dead. Re-head CTC. Last CT rehead was 7 days ago. Cut off 20 ft. CT. Pull test with 25K, Press test CTC. Change out directional tools, per Anc. request. 16:30 - 17:00 0.50 STKOH X WAIT PROO1 Wait on BHI CoilTrak tools from Oeadhorse. 17:00 -18:15 1.25 STKOH C PROD1 MIU BHA # 12 with 2.3 deg motor and Bit#12, 2.75" DPI POC Bit. 18:15 - 20:20 2.08 STKOH C PROO1 RIH with BHA #12 to cleanout new sidetrack. Hold pressure at surface while RIH, as per choke schedule in proceedure. 20:20 - 20:35 0.25 STKOH C PROD1 Log tie in pass down from 11500'. Make +4' correction. 20:35 - 21 :00 0.42 STKOH C PROD1 RIH, Check survey at 11992' bit depth. Current BHA reads Printed: 5/20/2002 3:16:13 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Frbm- To Hours Täsk COde N PT Phäse 5/12/2002 PROD1 20:35 - 21 :00 0.42 STKOH C 21 : 00 - 21 : 1 0 21 : 1 0 - 21 : 30 PROD1 PROD1 0.17 STKOH C 0.33 STKOH C 21 :30 - 21 :35 0.08 STKOH C PROD1 21 :35 - 21 :50 0.25 STKOH C PROD1 21 :50 - 22:10 0.33 STKOH C PROD1 22:10 - 23:50 1.67 STKOH C PROD1 23:50 - 00:00 0.17 STKOH C PROD1 5/13/2002 00:00 - 00:05 0.08 STKOH C PROD1 00:05 - 00:30 0.42 STKOH C PROD1 00:30 - 00:45 0.25 STKOH C PROD1 00:45 - 01 :05 0.33 STKOH C PROD1 01 :05 - 01 :40 0.58 STKOH C PROD1 01:40-02:10 0.50 STKOH C PROD1 02: 1 0 - 02:25 0.25 STKOH C PROD1 02:25 - 02:45 0.33 STKOH C PROD1 02:45 - 03: 15 0.50 STKOH C PROD1 Page 120f 16 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: Descri ptionofOperatiÖns 250.41 deg azimuth. Azimuth from original BHA that drilled this portion of wellbore read 249.67 deg. Difference of 0.74 deg, which is within survey accuracy. Inclination difference was 0.25 deg. Repeat survey check at 12089' bit depth. Current BHA= 235.03 deg, Original BHA=241.67 deg. Appears to be a descrepancy at this depth. Continue RIH. Made it to bottom easily, with no loss of weight. Stop at 12670', Orient to 160l TF. RIH at 5 fpm. Did not see any bobbles on weight, or motor work at sidetrack. RIH to 12800'. Confirm we are in old wellbore by surveys and no tag. Pit vol=266 bbls. PUH to 12670'. Try different orientation of 90l (270 deg). RIH at 5 fpm. No weight bobbles or motor work at sidetrack depth. Confirm from surveys we are in old wellbore. Confirm that proper scribe information has been entered into MWD computer, it is ok. Ream up and down at 160l (200 deg) tool face. at 10 fpm. from 12690'-12670'. Down ream at 15 fph from 12670'. Stacking wt @ 12694'. Short trip up 200', to clean up hole. Wiper trip up to 12490'. Restart down reaming from 12694'. Downream 12694' to 12700'. Never saw any motor work. RIH, to 12800'. No Tag up, still in old wellbore. Continue to RI H to check motor. Tag old TD at 13089', push on motor. Got motor work, its ok. PUH doing wiper trip to 12500' to ensure clean hole. Position BHA at 12685'. Third down reaming pass at 15 fph and TF=160l (200 deg). WOB=-165Ibs. 12693.0', WOB up to 450 Ibs, String weight=2700 Ibs, CTP=3029 psi, no motor work! 12694.0', WOB up to 1200 Ibs, String weight=1900 Ibs, CTP=3010 psi, Still no motor work! 12695.4', WOB up to 1900 Ibs, String weight=900 Ibs, CTP=3300 psi, Motor finally took a bite! Stop to let motor drill off for 2 minutes. CTP fell back to 3070 psi, String weight up to 3700 Ibs, WOB down to 512 Ibs. Resume feeding in at 15 fph. 12700.0', WOB=600 Ibs, String weight=3430 Ibs, CTP=3025 psi. We appear to have been able to sidetrack ok. 12700.0', Curent Inc=84.97, original well bore=87 deg. Confirming we are in a sidetrack. Try to RIH, negative tool weight getting into sidetrack. let orienter float, TF holds at 255 deg (105l) getting 3400 psi CTP. RIH at 65 fph. WOB=31 00, String Weight=-6000 Ibs. Drilling new hole? 12711 Getting consistent 400 Ibs motor work. Unable to RIH without drilling. Sidetrack depth 12694.0'. 12725', broke thru, back into old hole. RIH, tagged up at 12750', started getting motor work again. Drill to 12785'. ROP Printed: 5/20/2002 3: 16: 13 PM ) PHILLIPS PETROLEUM CO. Operations Summary Report Page 13 of 16 Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: Hours Task Code NPT Phase 5/13/2002 02:45 - 03: 15 0.50 STKOH C PROD1 and GR indicate we are in sand. 03:15 - 03:30 0.25 STKOH C PROD1 12785', wiper trip to clean new hole. Up to 12725', then back to TD. Repeat. Hole is clean. 03:30 - 05: 1 0 1.67 STKOH C PROD1 Backream up thru high dogleg part of window at 160L, made it in sidetrack ok. Confirm on Inc. Repeat 6 times. 05:10 - 05:15 0.08 STKOH C PROD1 Pumps down, 600 psi on whp, RIH dry. Made it into sidetrack ok, and down to TD. 05:15 - 07:00 1.75 STKOH C PROD1 POH to pick up lateral section BHA. Taking surveys every 50' in open hole. Surveys from TD are off on azimuth 3 to 6 degrees. 07:00 - 08:45 1.75 STKOH C PROD1 POH, maintain choke I pump schedule. End at 400 psi to reduce mud loss. 08:45 - 09:00 0.25 STKOH C PROD1 SAFETY MEETING. Review Pressure Undeployment Procedure. Review hazards. 09:00 - 10:00 1.00 STKOH C PROD1 SIWHP = 215 psi. Press. Undeploy. 2.3 deg motor/bit hung up in stack, work thru, OK. M/U BIT #13,2.74 - 3.0" HC Bicenter. Adjust motor to 1.50 deg. bend. 10:00 - 10:15 0.25 STKOH C PROD1 SAFETY MEETING. Review Pressure Deployment Procedure. Review hazards. 10:15 - 10:45 0.50 STKOH C PROD1 Pressure Deploy BHA #13. 1.5 deg bend motor and Bicenter Bit went in OK on slickline. SI WHP = 160 psi when opened pipe rams. Calculated reservoir gradient = 9.3 ppg, based on 8.75 ppg mud and 160 psi WHP. 10:45 - 13:00 2.25 STKOH C PROD1 RIH with BHA #13. 1.5 deg motor and Bit #13, HC bicenter bit. Maintain choke I pump schedule. Start at 400 psi. 13:00 - 13:15 0.25 STKOH C PROD1 Log Tie-in at GR marker at 11,500 ft. Added 3 ft. 13:15 - 14:15 1.00 STKOH C PROD1 RIH, clean hole, 1.4/1.2 bpm, RIH to 12670 ft. pump min. rate and RIH with 160L TF. Ran into open hole sidetrack with min. pump and 160L TF easily. No wt loss or motor work. Tagged TD at 12,786 ft. 14:15 - 16:30 2.25 STKOH C PROD1 Drilling, TF = 45R, 1.4/1.2 bpm, 3050 I 3400 psi, ROP = 90-150 FPH, Incl = 89 deg. Clean 40-60 API GR sand. Drilled to 12950 ft. 16:30 - 17:45 1.25 STKOH C PROD1 Wiper trip to window, pull thru open hole ST at 12700' with 170L TF. Clean hole to window. RIH. Clean hole. Ran thru OHST at 160 L wI 0.3 bpm. No wt loss. RIH to TD. 17:45 - 18:30 0.75 STKOH C PROD1 Drill ahead. 18:30 - 20:05 1.58 STKOH C PROD1 12985', Drilling ahead in sand, and occasional siderite stringers. 1.4/1.1/3200. Pit volume=251 bbls. Drilling with -3500 Ibs string weight when going thru siderite stringers. Add 1 drum lubtex to system. 20:05 - 21 :20 1.25 STKOH C PROD1 13062', Hard drilling, make wiper trip. ROP appears to have dropped down considerably. Clean PU off bottom. Add 1 additional drum of lubtex, and 1 drum of Flolube. Concentration now is 4% lubetex, 0.5% Flolube. Slick up and down thru window. 21 :20 - 00:00 2.67 STKOH C PROD1 Drilling ahead. Hard drilling. 1.5/1.3/3300 psi. 191 pit volume. Holding 90deg, TVD=5982'. At 23:00 geo decided to drill back down out of hard stuff instead of drilling up. Midnight depth = 13115'. 5/14/2002 00:00 - 01 :00 1.00 STKOH P PROD1 13115', Drilling ahead. 01 :00 - 01: 15 0.25 STKOH P PROD1 13137', still drilling shale. Weight transfer getting difficult. Printed: 5/20/2002 3: 16: 13 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: From..To Hours Task Code NPT 5/14/2002 01 :00 - 01: 15 01 :15 - 02:40 02:40 - 04:00 04:00 - 06: 15 06:15 - 07:15 07: 15 - 07:30 07:30 - 08:45 08:45 - 09:00 09:00-10:15 10:15 - 11 :00 11 :00 - 11 :45 11 :45 - 13:45 0.25 STKOH P 1.42 STKOH P PROD1 PROD1 1.33 STKOH P PROD1 2.25 STKOH P PROD1 1.00 STKOH P PROD1 0.25 STKOH P PROD1 1.25 STKOH P PROD1 0.25 STKOH P 1.25 STKOH P PROD1 PROD1 0.75 STKOH P PROD1 0.75 STKOH N DPRB PROD1 2.00 STKOH N DPRB PROD1 13:45 - 14:30 0.75 STKOH N DPRB PROD1 14:30 - 14:45 0.25 STKOH N DPRB PROD1 14:45 - 18:45 4.00 STKOH N DPRB PROD1 18:45 - 20:15 1.50 STKOH N DPRB PROD1 Make 200' mini wiper trip to clean up hole. Resume drilling. Broke back down into sand. 1.4/1.1/3500 Tf 90R, Pit vol=262 bbls, ROP=99 fph. Yahoo! 13231', Drilling sand. Good weight transfer due to recent mud additives. Wiper trip to shoe. Clean PU off bottom. No problems at sidetrack. Dropped rate to 0.3 bpm, and did not even see a bobble. Resume drilling 3250 psi free spin. 1.5/1.3/3450 psi. Drilled to 13,300 ft. Took on 100 bbls of new formate flopro at 2% lubetex. Diluted system. Could not get weight to bit. Add an additional 2 drums of lubtex and 1 of flolube. Make short wiper while new mud gets to bit. Drilling, 3300 psi, 1.4 11.2 bpm, TF = 90R, Still stacking wt. 500# WOB puts CT in full lock up. Need a wiper trip to window to drill last 40 ft. Anc. Mgmt. called well at TD. Drilled to 13,305 ft CTD. Wiper trip to window. 1.5/1.0 bpm, 3260 psi, 30 fpm, Very clean hole, no overpulls or motor work. Log Tie-in, Added 16 ft to CTD. RIH to TD. 1.5/1.2 bpm, 3500 psi, no motor work, RIH at 30 fpm, No wt loss or motor work going thru OHST at 12,694 ft. RIH clean to TD. RIH with 1500# CT WT with 1.5 bpm. RIH with no pump, CT WT = 2000 # just off bottom. Tagged Final Corrected TD at 13,314 ft BKB. Laid in very high viscosity I high lubricity Formate FloPro pill in open hole. Pull at 45 fpm, pump 0.8 bpm. Up Wt = 23K, Dwn Wt = 2K. Pull to window. Stop pump, hold 600 psi on superchoke. Open circ valve. Saw well flowing with choke at 600 psi. SII choke. S/I WHP = 1200 psi. Lowest downhole ann. press was 3640 psi, when circ sub was opened, had 3800 psi while laying in high vis pill in open hole. 3640 psi = 11.6 ppg fluid gradient. shut in well. Inj mud to fault with WHP = 730 psi, with 8.7 ppg Flopro in hole, res = 11.1 ppg. RIH to TD to circ. bottoms up and lay in very high vis I high lubricity pill. Circ. 1.5/1.4 bpm, DH Ann. press = 4010 psi near TD. Circ. bottoms up 1.5/1.4 bpm. Circ. Pill to bit at 13,314 ft. Pill at bit, POOH at 45 fpm, pump 0.8 bpm, hold 400 psi whp, BHP = 3870 psi. Pull up to 11,564 ft. Bit inside 7" casing. S/I well. stop pump, trapped 650 psi with choke. WHP inc. to 1200 psi, Opened choke and bled whp to 760 psi. close choke and S/I well again. Monitor WHP wI bit at 11530' while XO crews. Beginning WHP 835 psi wI AP 3349 psi, 4 hrs later 465 psi wI AP 3128 psi. Assume packed off above BHA or "breathing shales" PVT 188. Fill CT wI 9 bbls pumping thru EDC. Drop WHP to 200 psi while bring pump up to rate 1.5/3100 psi. Getting 0.5 bpm returns initially. PUH 20'/min 18k to 10400' while circ btms up wI 200 psi BP AP 3700. No crudelgaslwater in returns. In/out improved to 1.5/1.1. RBIH Printed: 5/20/2002 3: 16: 13 PM Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours Task Code .N PT Phase 5/14/2002 20:15 - 21 :00 0.75 STKOH N DPRB PROD1 21 :00 - 21:45 0.75 STKOH P PROD1 21 :45 - 23:40 1.92 STKOH P PROD1 23:40 - 00:00 0.33 STKOH P PROD1 00:00 - 00:30 0.50 STKOH P PROD1 00:30 - 00:40 0.17 STKOH P PROD1 00:40 - 01 :15 0.58 STKOH P PROD1 01: 15 - 01 :25 0.17 CASE P COMP 01 :25 - 01 :45 0.33 CASE P COMP 01 :45 - 03:45 2.00 CASE P COMP 03:45 - 04:45 1.00 CASE P COMP 04:45 - 05:30 0.75 CASE P COMP 05:30 - 07: 15 1.75 CASE P COMP 07:15 - 08:50 1.58 CASE P COMP 5/15/2002 08:50 - 14:20 5.50 CASE P COMP 14:20 - 14:45 0.42 CASE P COMP 14:45 - 15:25 0.67 CASE P COMP 15:25 - 15:35 0.17 CASE P COMP 15:35 - 17:30 1.92 CASE P COMP 17:30 - 17:40 0.17 CASE P COMP 17:40 - 17:50 0.17 CASE P COMP 17:50 -19:10 1.33 CASE P COMP 19:10-21:10 2.00 CASE P COMP 21:10 - 23:20 2.17 CASE P COMP 23:20 - 00:00 0.67 CASE P COMP I Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: Description of Operations PVT 140. CBU from 11500' 1.5/1.3 2900 psi wI no BP PVT 130. Btms up clean 1.5/1.3 3050. Pump 5 bbl viscous pill. Swap to 10.6 KWF dn CT POOH for liner displacing to KWF 1.5/1.3 1900 Tag up. Monitor well stability-on sli vac. Lost 7 bbls while POOH Fill hole wI 3 bbls (after 20 min). Fill pits wI rest of KWF. PVT 86 bbls Safety mtg re: LD BHA LD BHI drilling assy. PVT 84 Safety mtg re: liner RU to run liner MU 55 jts 2-3/8" 4.6# L-80 STL slotted liner wI guide shoe, o-ring sub and turbos. Fill hole every 30 min PVT 77 MU Baker deploymnet sleeve wI GS assy. MU 7 2-1/8" DC's 4.7#/ft MU BHI Coiltrak BHA wI EDC, chks, disc. PVT 66 RIH wI CT to 11550' circ thru open EDC 0.2/170. Up wt = 29k. Close EDC. RIH liner in open hole. Set down & work thru various tight spots @ 12434',12486',12553',12661',12684' (OHST pt @ 12694'), 12708' & 12715' (41 degs DLS @ 12713'). Continue RIH to tight spot @ 12754'. Work without success. P/U with 50k to 12600' & observe up wt go down to 36k. RIH smoothly thru OHST pt & tag up @ 12758'. Work pipe (gaining & loosing depths) to 12760' & then to 12770', 12806', 12828',12840',12861',12895',12906',12968', 12978', 12991', 13001', 13015', 13021', 13037', 13062', 13078', 13090' (old hole TD @ 13088'), 13126'. Not working pass 13126'. Decide to spot hi-lube pill. Open up EDC & prepare hi- lube 10.6ppg formate flo-pro pill. Start circulating 24bbls hi-lube 1 0.6ppg formate flo-pro pill with EDC open @ 1.5/1.1 bpm, 2000psi With 4bbls of lube pill out of EDC, starting working liner in hole with 44k up & wt - No progress. S/I @ the superchoke & squeeze-in 7 bbls of fluid down the backside. Work pipe down to 13115' & call it good!! Close EDC. Pressure up to 4000 psi @ 1.5bpm, pump hydraulic GS open & release from liner. P/U & confirm liner release with 26.5k up wt. TOL will be @ 11334' from tally (above GLM #6 @ 11449'). Maximum CT wear from coillife = 42% from 11000' to 11100'. Open EDC & POOH LRT circulating KWF @ 1.2bpm/1200psL Run out of KWF, thus start circ 2% KCL water down CT. POOH to 400'. Circ total of 25bbls KCL water down CT. Close EDC. POOH & tag up @ surface. PJSM. UD BHI coiltrack, DCs & LRT. LD BHI tools, DC's, GS. MU nozzle assy RIH wI nozzle to 11300' CTD. Circ 2% KCI to nozzle POOH displacing wellbore to 2% KCI and adding BP assuming 10.3 ppg grad. Displace top 2000' of wellbore with 20 bbls diesel. Full returns thruout. Send 109 bbls KWF back to MI OOH. SI swab, master (20 ea). Bleed off final BP of 900 psi. Printed: 5/20/2002 3:16:13 PM ) ') Page 16 of 16 PHILLIPS PETROLEUM CO. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3M-29 3M-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 NPT PhaSe 5/15/2002 5/16/2002 0.67 CASE P 0.75 GASAIR 0.25 TA 3.00 TA COMP COMP COMP COMP 23:20 - 00:00 00:00 - 00:45 00:45 - 01 :00 01 :00 - 04:00 04:00 - 05:45 1.75 RIGD COMP 05:45 - 08:30 2.75 RIGD COMP 08:30 - 11 :00 11 : 00 - COMP COMP 2.50 RIGD 0.00 RIGD Start: 4/30/2002 Rig Release: 5/16/2002 Rig Number: Spud Date: 1/20/1996 End: Descriþtion...of..Operê3tions Jet stack wI remaining 2% KC!. LD BHA Blow back CT wI air. Set back injcetor Safety mtg re: Set plugs RU Halliburton WL tools. Open tree valves to 470 psi. Set 3-1/2" MCX injection valve wI 2.812" CS lock in SSSV nipple at 514'. Bleed off press and held. Set BPV. Close master and swab. RDMO WL'ers Set 60' lub in injector bay and secure. RU to pump slack management. Install new reverse line. PT and failed at grayloc. Fix and PT @ 4600 psi. Cut off CTC Reverse circ 1-1/2 CT vols at max rate of 4bpm at 3900 psi for e-line slack management. Pumped a total of 75bbls. Blow down stack & fluid back in CT with air. Cut 12' of CT & did not see any eline. Suspend slack mgt. PJSM. ND BOPE. Close SSV. NU Tree cap & PT @ 4000 psi. RREL @ 11 :00 hrs on 5/16/02 & make preparation to move off location. Printed: 5/20/2002 3: 16: 13 PM Well: Field: API: Permit: ) ) 3M-29A Kuparuk River Unit 50-029-22641-01 202-084 Rig Accept: 05/02/02 Rig Spud: 05/05/02 Rig Release: 05/16/02 Drilling Rig: Nordic #1 POST RIG WORK 05/17/02 BPV PULLED. MCX PULLED AT 514' RKB. ENCOUNTERED HYDRATES IN TUBING AT 2800' SLM. INITIAL BHP SUSPENDED DUE TO 40 BBLS HOT DIESEL PUMPED. DRIFT TUBING WITH 2.735" AND TAGGED LINER TOP AT 11334' RKB. SET VAVLE CATCHER AT 11334' RKB. 05/18/02 MEASURED BHP AT 11330' RKB, PSI = 2788 AND 130 TEMP AND GRADIENT. AT 11030' RKB PSI = 2720 AND 130 TEMP. PULLED DV's AT 11248' AND 10190' RKB. OV SET AT 11248' RKB, POCKET OPEN AT 10190' RKB. 05/19/02 PULLED DV's AT 8264' AND 4501' RKB. SET GLV's AT 10190', 8264' AND 4501' RKB, TESTED GOOD. PULLED VALVE CATCHER AT 11334' RKB. ) ) .8 BA HUGIIIS INTEQ BP Baker Hughes INTEQ Survey Report Height 68.00 ft Company: Phillips Alaska, Inc. Field: Kuparuk River Unit Site: KRU 3M Pad Well: 3M-29 Wellpath: 3M-29A Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Site: KRU 3M Pad UNITED STATES - North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 3M-29 500292264100 Well Position: +N/-S -1329.20 ft +E/-W -1756.34 ft Position Uncertainty: 0.00 ft Well: Northing: Easting : Wellpath: 3M-29A 500292264101 Current Datum: 3M-29 Magnetic Data: 4/18/2002 Field Strength: 57433 nT Vertical Section: Depth From (TV D) ft 0.00 Survey Program for Definitive Wellpath Date: 6/26/2002 Validated: Yes Actual From To Survey ft ft 121.00 11596.00 11596.00 12674.76 12690.00 13314.00 3M-29 (0) MWD (2) MWD Annotation Date: 6/28/2002 Time: 10:05:40 Co-ordinate(NE) Reference: Well:. 3M~29, True North Verti.cal (TVD) Reference: 3M:'2968.0 Section (VS) Reference: Well (0~00N,0.00E,260.40Azi) Survey Calculation Method: Minimum Curvature Db: Page: Sybase Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2000 6017499.33 ft Latitude: 70 27 32.522 N 507866.86 ft Longitude: 149 56 8.843 W North Reference: True Grid Convergence: 0.06 deg Slot Name: 6016168.40 ft Latitude: 70 27 19.448 N 506112.10 ft Longitude: 149 57 0.436 W +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 3M-29APB1 12674.76 ft Mean Sea Level 25.76 deg 80.75 deg Direction deg 260.40 Version: Toolcode 2 Tool Name MWD MWD MWD MWD - Standard MWD - Standard MWD - Standard TVD ft 12674.76 6039.77 KOP 13314.00 6066.62 TD Survey: MWD Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Survey MD Incl Azim TVD SSTVD ft deg deg ft ft 12674.76 86.53 266.12 6039.77 5971.77 12690.00 83.07 264.28 6041 .15 5973.15 12713.50 77.13 256.65 6045.19 5977.19 12730.74 82.00 254.20 6048.31 5980.31 12771.85 85.92 254.51 6052.64 5984.64 12802.05 88.93 260.35 6054.00 5986.00 12835.35 89.42 265.67 6054.48 5986.48 12869.52 88.80 271.95 6055.01 5987.01 12898.16 90.80 276.79 6055.11 5987.11 12939.40 89.32 285.58 6055.06 5987.06 12969.68 91.60 291.01 6054.82 5986.82 Start Date: 5/14/2002 Engineer: Tied-to: From: Definitive Path N/S E/W MapN MapE VS DLS ft ft ft ft ft deg/1000 -6547.00 -8019.07 6009615.48 498099.21 8998.60 0.00 -6548.26 -8034.19 6009614.20 498084.09 9013.72 25.69 -6552.08 -8056.99 6009610.37 498061.29 9036.84 40.75 -6556.35 -8073.39 6009606.09 498044.89 9053.73 31.51 -6567.37 -8112.75 6009595.03 498005.55 9094.37 9.56 -6573.93 -8142.18 6009588.45 497976.13 9124.49 21.74 -6577.98 -8175.22 6009584.37 497943.10 9157.74 16.04 -6578.69 -8209.36 6009583.63 497908.96 9191.52 18.47 -6576.51 -8237.91 6009585.79 497880.41 9219.30 18.28 -6568.52 -8278.32 6009593.75 497839.99 9257.82 21.61 -6559.02 -8307.06 6009603.23 497811.25 9284.57 19.45 ) ') BP Baker Hughes INTEQ Survey Report lNTEQ Company: Phillips Alaska. Inc. Date: 6/28/2002. Time: 10:05:40 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3M-29, True North Site: KRU 3M Pad Vertical (TVD) Reference: 3M-29 68.0 Well: 3M-29 Section (VS) Reference: Well (0 . OON ,0 .00E,260 .40Azi) Wellpath: 3M-29A Survey Calculation Method: Minimum. Curvature Db: Sybase Survey MD loci Azim TVD SSTVD N/S E/\" MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/1000 12999.70 92.03 296.69 6053.87 5985.87 -6546.89 -8334.49 6009615.33 497783.81 9309.59 18.97 13030.11 90.68 303.74 6053.15 5985.15 -6531.60 -8360.75 6009630.60 497757.55 9332.93 23.60 13060.11 92.89 310.67 6052.21 5984.21 -6513.48 -8384.61 6009648.69 497733.67 9353.44 24.23 13090.42 90.12 314.35 6051.42 5983.42 -6493.01 -8406.94 6009669.14 497711.33 9372.04 15.19 13120.53 84.75 318.36 6052.77 5984.77 -6471.26 -8427.69 6009690.87 497690.56 9388.88 22.25 13151.50 82.92 324.13 6056.09 5988.09 -6447.26 -8446.96 6009714.85 497671.28 9403.87 19.44 13180.39 83.45 329.67 6059.52 5991.52 -6423.24 -8462.62 6009738.86 497655.60 9415.30 19.13 13210.01 87.51 333.49 6061.86 5993.86 -6397.28 -8476.66 6009764.81 497641.53 9424.82 18.79 13240.73 88.99 338.56 6062.80 5994.80 -6369.23 -8489.14 6009792.84 497629.04 9432.44 17.18 13272.00 87.88 343.58 6063.65 5995.65 -6339.68 -8499.27 6009822.39 497618.88 9437.51 16.44 13289.93 85.43 346.39 6064.70 5996.70 -6322.39 -8503.91 6009839.67 497614.23 9439.20 20.77 13314.00 85.43 346.39 6066.62 5998.62 -6299.07 -8509.56 6009862.98 497608.56 9440.88 0.00 Phillips Alaska, Inc. Parent Wellpath: Tie on MD: WELLPATH DETAILS 3M.29A 500292264101 3M-29APB1 12674.76 Rig: Nordic 1 Ref. Datum: 3M-29 68.0Oft V.Sectlon Origin Origin Starting Angle +NI-S +E/-W From TVD 260.40° 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/E~ Reference: Well Centre: 3M-29, True North Vertical (ND Reference: System: Mean Sea Level Section (VS Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: 3M-29 68.00 Calculation Method: Minimum Curvature ANNOTATIONS TVO 5971.77 12674.76 KOP 5998.62 13314.00 TO 5300 5350 5400 5450 - C 5500 . ~5550 . II) - .c 5600 .. ~650 . Q -5700 CO U i:5750 CÞ > 5800 CÞ 25850 I- 5900 5950 . 6000 : 6050 MO Annotaüon ~EJ-W Shipe ( 00 -6M2-60 .179! 40 Pay¡JDn 000 -554595 -ðS57.5J Pot'tIJ=an ~~ ~ ~~ ~ JU.29AP~1 3101.29AF.liA I f1oIotgcn g~¡IT'- ~ ~) B r&íì8 ~œ" ,.~, ilLs :" - ~"..', -0" ,~' INTEQ ~~~~~~: {~~r~l~I;@i~~f:q.com 8aker Hughes INTEO: (90T) 267-6600 T ^M ,\ é LEGEND - 3M.29,3M-29A,Plan #5 - 3M-29 (3M-29) ---- 3M-29 (3M-29APBI) - 3M-29A Well path: (3M-29/3M-29A) Azimuths to True North Magnetic North: 25.76. Magnetic Field Strength: 57433nT Dip Angle: 80.75. Date: 4/18/2002 Model: BGGM2000 Created By: Brij Potnis Date: 6/2812002 Contact information: -5500-- -5600 -5700--':1 -5800-j -SOOO--: ,5 J = -6100'] 0 :.1 ~ -6200 ~. - - '+ -6300-) . - .c ~ ~ -640o-i- 0 j ~ -6500 .. f - - - .c -6600-;' .. :s n 0-6700-' - tn 'u -6800-j -7000 .: - Ir n""Tc"f'TT"'T' , '. .' . .', '-r1Trr"'T .' . I -9300 -9200 -9100 -9000 -8900 -8800 -8700 -8600 -8500 -8400 -8300 -8200 -81 00 -8000 -7900 -7800 -7700 -7600 -7500 -7400 -7300 -7200 -71 00 -7000 -6900 -6800 -6700 West(-)/East(+) [100ft/in] ." ',' . ': . I ' .. . ' . 8600 86'50 8750 88'00 8850 89'00 8950 9000 9050 9100 9150 92'00 Vertical Section at 260.40° [50ft/in] 6/28/2002 10:03 AM - '~ ) \ ) BP Baker Hughes INTEQ Survey Report Height 68.00 ft Company: Phillips Alaska, Inc. Field: KuparukRiver Unit Site: KRU 3M Pad Well: 3M-29 Wellpath: 3M-29APB1 Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Site: KRU 3M Pad UNITED STATES - North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 3M-29 500292264100 Well Position: +N/-S -1329.20 ft +E/-W -1756.34 ft Position Uncertainty: 0.00 ft Well: Northing: Easting : Wellpath: 3M-29APB1 500292264170 Current Datum: 3M-29 Magnetic Data: 6/26/2002 Field Strength: 57434 nT Vertical Section: Depth From (TVD) ft 0.00 Survey Program for Definitive Well path Date: 6/26/2002 Validated: Yes Actual From To Survey ft ft 121.0011596.00 11596.00 13088.00 3M-29 (0) MWD Annotation Date: 6/28/2002 Time: 10:16:40 Co.,or;dinate(NE) Reference: Well: 3M-29, True North Vertical (TVD) Reference: 3M-2968.0 Section (VS) Reference: Well (0.00N,O.00E,232.46Azi) Survey Calculation Method: Minimum CUlvature Db: Page: Sybase Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2000 6017499.33 ft Latitude: 70 27 32.522 N 507866.86 ft Longitude: 149 56 8.843 W North Reference: True Grid Convergence: 0.06 deg Slot Name: 6016168.40 ft Latitude: 70 27 19.448 N 506112.10 ft Longitude: 149 57 0.436 W +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 3M-29 11596.00 ft Mean Sea Level 25.70 deg 80.75 deg Direction deg 232.46 Version: Toolcode Tool Name MWD MWD MWD - Standard MWD - Standard TVD ft 11596.00 6013.06 13088.00 6025.00 KOP TD Survey: MWD Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Survey MD Incl Azim TVD SSTVD ft deg deg ft ft 11596.00 41.57 229.19 6013.06 5945.06 11645.24 74.00 226.95 6038.96 5970.96 11670.83 93.52 222.28 6041.73 5973.73 11700.80 93.60 225.41 6039.87 5971.87 11729.80 93.87 228.52 6037.98 5969.98 11758.82 94.51 233.05 6035.86 5967.86 11787.83 94.49 237.27 6033.58 5965.58 11817.81 94.21 242.91 6031.31 5963.31 11847.81 91.50 247.24 6029.81 5961.81 11877.78 91.35 248.24 6029.07 5961.07 11907.74 90.88 250.20 6028.48 5960.48 11937.82 93.75 251.00 6027.27 5959.27 Start Date: 5/9/2002 Engineer: Tied-to: From: Definitive Path N/S E/W MapN MapE VS DLS ft ft ft ft ft deg/1000 -5957.73 -7160.09 6010205.40 498957.62 9307.55 0.00 -5985.30 -7190.57 6010177.80 498927.16 9348.52 65.96 -6003.33 -7208.33 6010159.76 498909.42 9373.59 78.39 -6024.90 -7229.05 6010138.17 498888.72 9403.16 10.43 -6044.65 -7250.20 6010118.41 498867.59 9431.96 10.74 -6062.94 -7272.62 6010100.10 498845.19 9460.88 15.72 -6079.46 -7296.35 6010083.56 498821 .4 7 9489.77 14.50 -6094.36 -7322.25 6010068.64 498795.58 9519.38 18.78 -6106.98 -7349.41 6010056.00 498768.43 9548.61 17.01 -6118.33 -7377.14 6010044.63 498740.72 9577.51 3.37 -6128.96 -7405.14 6010033.98 498712.73 9606.19 6.73 -6138.94 -7433.49 6010023.98 498684.39 9634.75 9.90 ) ) 'i8 BP BA IIUGIIß Baker Hughes INTEQ Survey Report .lNTEQ Company: Phillips Alaska, Inc. Date: 6/28/2002 Time: 10:16:40 Page: 2 Field: Kuparuk River Unit Co~ordi~ate(NÈ) Reference: Well: 3M~29, True North Site: KRU 3M Pad Vertical (TVD) Reference: 3M-29 68.0 Well: 3M-29 Section (VS) Reference: Well (0.00N,0.00E,232.46Azi) Wellpath: 3M~29APB1 Survey Calculation Method: Minimum. Curvature Db: Sybase Survey E/W ft 11967,74 94.39 247.89 6025.14 5957.14 -6149.42 -7461.43 6010013.48 498656.46 9663.29 10.59 11997.85 94.11 243.20 6022.91 5954.91 -6161.85 -7488.76 6010001.03 498629.15 9692.53 15.56 12027.68 93.50 238.76 6020.93 5952.93 -6176.28 -7514.78 6009986.57 498603.14 9721.96 14.99 12065.13 90.18 231.92 6019.73 5951.73 -6197.55 -7545.54 6009965.28 498572.40 9759.32 20.29 12093.79 91.32 230.04 6019.35 5951.35 -6215.60 -7567.81 6009947.22 498550.15 9787.96 7.67 12123.81 88.86 229.36 6019.30 5951.30 ~6235.01 -7590.70 6009927.79 498527.28 9817.95 8.50 12154.87 87.48 228.17 6020.30 5952.30 -6255.47 ~7614.04 6009907.31 498503.95 9848.92 5.87 12184.99 86.16 224.92 6021.97 5953.97 ~6276.15 -7635.87 6009886.61 498482.14 9878.83 11.63 12214.86 86.66 220.17 6023.84 5955.84 -6298.11 -7656.02 6009864.64 498462.01 9908.19 15.96 12244.77 87.24 216.97 6025.43 5957.43 -6321.46 -7674.64 6009841 .28 498443.41 9937.18 10.86 12275.79 86.59 212.67 6027.10 5959.10 -6346.88 -7692.32 6009815.84 498425.75 9966.69 14.00 12305.79 86.47 216.42 6028.92 5960.92 -6371.54 -7709.30 6009791.17 498408.80 9995.18 12.48 12334.82 89.17 221.04 6030.02 5962.02 -6394.16 -7727.45 6009768.54 498390.68 10023.35 18.42 12367.79 88.28 223.95 6030.76 5962.76 -6418.46 -7749.71 6009744.22 498368.43 10055.81 9.23 12397.83 88.99 225.79 6031.47 5963.47 -6439.75 -7770.90 6009722.92 498347.27 10085.58 6.56 12430.69 88.34 228.65 6032.24 5964.24 -6462.06 -7795.00 6009700.60 498323.18 10118.29 8.92 12459.50 87.88 234.12 6033.19 5965.19 -6480.02 -7817.49 6009682.62 498300.71 10147.06 19.04 12490.80 88.86 240.10 6034.08 5966.08 -6497.00 -7843.75 6009665.62 498274.46 10178.23 19.35 12520.79 88.74 245.03 6034.71 5966.71 -6510.81 -7870.36 6009651.78 498247.87 10207.74 16.44 12550.75 88.83 250.13 6035.34 5967.34 -6522.23 -7898.04 6009640.34 498220.21 10236.65 17.02 12581.02 88.22 254.86 6036.12 5968.12 -6531.33 -7926.89 6009631 .22 498191.37 10265.07 15.75 12610.87 89.17 258.06 6036.80 5968.80 -6538.32 -7955.90 6009624.21 498162.36 10292.33 11.18 12640.77 86.92 262.01 6037.82 5969.82 -6543.49 -7985.32 6009619.02 498132.95 10318.81 15.20 12674.76 86.53 266.12 6039.77 5971.77 ~6547.00 -8019.07 6009615.48 498099.21 10347.71 12.13 12705.18 87.23 264.76 6041.42 5973.42 -6549.41 -8049.34 6009613.04 498068.94 10373.19 5.02 12735.14 87.97 268.12 6042.68 5974.68 -6551.27 -8079.21 6009611.16 498039.07 10398.01 11.47 12765.12 93.38 269.67 6042.32 5974.32 -6551.85 -81 09. 18 6009610.56 498009.11 10422.12 18.77 12795.14 95.29 273.64 6040.05 5972.05 -6550.98 -8139.09 6009611.40 497979.20 10445.31 14.64 12825.59 94.03 277.00 6037.58 5969.58 -6548.17 -8169.30 6009614.19 497948.99 10467.56 11.75 12872.67 92.58 283.14 6034.86 5966.86 -6539.95 -8215.56 6009622.36 497902.73 10499.23 13.38 12901.71 93.23 286.68 6033.39 5965.39 -6532.49 -8243.58 6009629.80 497874.71 10516.90 12.38 12931.10 93.75 291.02 6031.60 5963.60 -6523.02 -8271.33 6009639.25 497846.95 10533.14 14.85 12961.19 92.39 294.13 6029.99 5961.99 -6511.48 -8299.07 6009650.76 497819.20 10548.11 11.27 12996.06 88.83 290.35 6029.62 5961.62 -6498.29 -8331.34 6009663.93 497786.93 10565.66 14.89 13026.12 92.67 288.51 6029.22 5961.22 -6488.30 -8359.68 6009673.90 497758.58 10582.04 14.16 13055.48 94.30 289.57 6027.44 5959.44 -6478.74 -8387.38 6009683.43 497730.88 10598.18 6.62 13088.00 94.30 289.57 6025.00 5957.00 -6467.87 -8417.93 6009694.27 497700.32 10615.79 0.00 Phillips Alaska, Inc. (Pa I ¡UPS' . ~. T!T!IB .,~ INTEQ--~ 8a~e' Hughes /~~~~ ~~t¥~~i~~q.com T ^M 4 LEGEND ~ 3M.29,3M-29APlan #5 ~ 3M-29 (3M-29) --- 3M.29 (3M-29APB 1) ~ 3M-29A Wellpath: (3M-29/3M-29A) Azimuths to True North Magnetic North: 25.76° Magnetic Field Strength: 57433nT Dip Angle: 80.75° Date: 4/18/2002 Model: BGGM2000 Created By: Brij Potnis Date: 6128/2002 Contact ~nfQrrnatk)r:: WELL PATH DETAILS 3M-29A 500292264101 Parent Well path: Tie on MD: Rig: Ref. Datum: 3M.29APB1 12674.76 6B.OOft --" -550{}-j . Nordic 1 3M-29 V.Sectlon Angle 260.40" Origin +NJ-S 0.00 Starting From TVD -5600--3 Origin +EJ.W 0.00 0.00 -5700-':; REFERENCE INFORMATION -5800j 0 Co-ordinate (NJE¡ Reference: Well Centre: 3M-29, True North Vertical (¡YO Reference: System: Mean Sea Level Section (VS Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: 3M-29 68.00 Calculation Method: Minimum Curvature 5971.77 12674.76 KOP 5998.62 13314.00 TO - C5500 . ~5550 : &I) ;5600 .. ~650 . Q -5700 . ~5750 ~ ~ 5800 : '" CÞ '" 25850 \. ... 5900 , ANNOTATIONS ~OOO-. ,5-' = -610{}-J 0-:: ~ -6200 . - .. ,. "/\' {c;'29AI; "'.." ", \ 3M.29 (3M.29APBI)1 .. 3M.29,3M.29APlan ~ .. '",,- \. ) ',\ / '\¿.. ~ . . .~:S.:.: TVD MD Annotation 0 ()J -584260 -n9d.&O Pdygon 0 OJ -!&S5 95 -ð5S7 53 PcIygon ~I~i~.i ~ ~~~~~~ ~m¡¡r- /-/. / ...,.........,y: /. //j / / ./' 5300 +,,-6300"':; :c .. ~ -6400--:: 0 ~ -6500-t: . :c -6600...1~ .. - :I - 0 -6700'" .. en . -6800; . 5350 . --- 5400 5450 -70oo--t- -9300 -9200 -9100 -9000 -8900 -8800 -8700 -8600 -8500 -8400 -8300 -8200 -81 00 -8000 -7900 -7800 -7700 -7600 -7500 -7400 -7300 -7200 -71 00 -7ÓOO -6900 -6800 -6700 West(-)/East(+) [100ft/in] 5950 . 6000 . 6050 . ' I' . . 8550 8750 8800 8850 8900 8950 9000 9050 9100 Vertical Section at 260.40° [50ft/in] 6/28/2002 10:03 AM ) ) ~~1~E :¡ ~~fÆ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Kuparuk River Unit 3M-29A Phillips Alaska, Inc. Permit No: 202-084 Sur Loc: 1332' SNL, 1756' FEL, Sec. 25. T13N, R08E, UM Btmhole Loc. 2227' SNL, 5264' WEL, Sec. 35, T13N, R08E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above referenced well. This permit is being redrilled by BP Exploration (Alaska), Inc. under the coiled tubing shared services agreement with Phillips Alaska, Inc. The operator of the Kuparuk River Unit is Phillips Alaska, Inc. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit 3M-29A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, c~e~~l~ Chair BY ORDER 0] THE COMMISSION DATED this.11h day of April, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,.<.. f¡J GA '" It/o "2- ,JI ) STATE OF ALASKA \ ALASKA ~.L AND GAS CONSERVATION COMM~ -~ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil 0 Service 0 Development Gas e Single Zon~þ 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 68' Kuparuk River 6. Property Designation ADL 025523 7. Unit or Property Name Kuparuk River Unit 8. Well Number 3M-29A 9. Approximate spud date 04/18/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13505' MD / 59641 TVDss 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 99 0 Maximum surface 2779 psig, At total depth (TV D) 5953' / 3374 psig Setting Depth TaD Bottom Quantitv of Cement Lenath MD TVD MD TVD (include stage data) 1985' 115201 5888' 13505' 5964' Uncemented Slotted Liner Return Approved to BPX 1 a. Type of work 0 Drill III Redrill 0 Re-Entry 0 Deepen 2. Name of Operator Phillips Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1332' SNL, 1756' WEL, SEC. 25, T13N, R08E, UM At top of productive interval 2012' SNL, 3636' WEL, SEC. 35, T13N, R08E, UM At total depth 2227' SNL, 5264' WEL, SEC. 35, T13N, R08E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 025524,14' MQ No Close Approach 16. To be completed for deviated wells Kick Off Depth 11596' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casing Weight Grade CouDlina 2-3/8" 4.6# L-80 ST-L 11. Type Bond (See 20 AAC 25.025) S"f.¡ 52. 19b NUmber~)?j) Hole 3" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11866 feet 6218 feet 11767 feet 6142 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 121' 5827' 16" 9-5/8" 270 sx Arcticset I 1230 sx AS III, 730 sx Class IG' 121' 5827' 121' 3421' 11856' 7" 200 sx Class ,<RECEIVED 11856' 6211' APR Perforation depth: measured 11594' - 116141 9 2002 Alaska Oil i GasConl,Ccxnmission AndlMïg: true vertical 6011' - 6026' 20. Attachments III Filing Fee 0 Property Plat III BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer NameINumber: Mark Johnson, 564-5666 Prepared By NameINumber: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true correct to the best of my knowledge Signed Mark Johnson ~ Ó. 'tie CT Drilling Engineer Comm¡~ion Use Only,. , Permit NumbE1; Oc¿i" API Nu r AP'~~OV! ~ate ~ See cover letter zç.)~ -- C-Y 50- 029-22641-01 "'-...,.1. t' . \) j \ for other requirements Conditions of Approval: amples Required 0 Yes fZI No Mud Log ReqUl t::d 0 Yes Œ1 No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T t~s.t- ßt7 f>E '{:ë:, ~'rpo pc;.,.:. \I.J§k Original Signed By by order of COln"'y 0I.cf1.1i 0 m'Gi,sKrl~ L the commission Date if/g/o7- Approved By Form 10-401 Rev. 12-01-85 Date Ù ~j1 / ~ ¡ () ~ ~b'hlit In Tri~ic\te )KRU 3M-29A Sidetrack - Coiled Tubing ..tiling Summary of Operations: ./ Coiled tubing drilling will sidetrack KRU 3M-29 using the dynamically overbalanced coiled tubing drilling (DOCTD) technique (see description below). This horizontal sidetrack (3M-298) will target Kuparuk A sand reserves for production. 3M-29A will be a producing well. Prior to CTD arrival, service coil will abandon the existing perforations in 3M-29 (sundry form 10-403 submitted). / CrD Drill and Complete 3M-29A proaram: Planned for April 18. 2002 1 ) M ill cement ramp window through 7" at 11596' and mill 10' of openhole. ' 2) Drill 2.7x3" bicenter hole horizontal sidetrack 3M-298 from window to -13505' TD targeting Kuparuk A sand interval. 3) Complete with 23/8" slotted liner from TD to -11520' (--10 inside tubing tail). 4) Post CTD rig - Run GLVs. Bring on production. Mud Program: . Steps 1: 9 ppg KCUNaCI biozan brine I . Steps 2-3: Flo-Pro (9 ppg) Disposal: /' . No annular injection on this well. . Class II liquids to KRU 1 R Pad Class II disposal well . Class II drill solids to Grind & Inject at PBU Drillsite 4 . Class I wastes will go to Pad 3 for disposal. Casing Program: / . 23/8",4.6#, L-80, STL slotted liner from 11520'-13505'. Well Control: . BOP diagram is attached. / . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plans for 3M-29A . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . A Gamma Ray log will be run over all of the open hole section. . Memory resistivity logging in sections of the openhole Hazards . Two faults are expected to be crossed, both in the A s~. Lost circulation risk is low. Res. pressure is 10.9 ppg. Well 3M-29 has a H2S reading of 116 ppm. 3M-24 has the highest H2S on the pad at 231 ppm. 3M pad is a H2S pad. All H2S monitoring equipment will be operational. Reservoir Pressure . Res. pressure is approx. 3374 psi @ 5953'ss (10.9 ppg). Max. surface pressure with gas (0.1 psi/ft) to surface is 2779 psi. I (continued) MOJ 564-5666 office, 240-8034 cell 1/3 ) . "KRU 3M-29A Sidetrack - Coiled Tubing lilling As done in the past at KRU by CTD, dynamically overbalanced coiled tubing drilling (DOCTD) techniques will be employed to address high reservoir pressure. Plans are to use 9 ppg drilling fluid in combination with / annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique with an underbalanced mud weight requires deployment of the BHA under trapped wellhead pressure. Deployment will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attache~ BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. At least two times hole volume of kill weight fluid will be on location as a contingency. Once drilling is comp~te, the slotted production liner will be deployed into the wellbore after killing the well with kill weight fluid. MOJ 564-5666 office, 240-8034 cell 2/3 ), KRU 3M-29A Sidetrack - Coiled Tubing Jrilling Kuparuk 3M-29A Potential Drilling Hazards POST ON RIG 1. Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. 2. H2S - Well 3M-29 has a H2S reading of 116 ppm. 3M-24 has the highest IDS on the pad at 231 ppm. 3M pad is a H2S pad. All H2S monitoring equipment will be operational. H2S procedures must be followed according to the AK Safety Handbook and Shared Services Drilling H2S SOP. All personnel must be supplied with required PPE and H2S certified. Influxes of reservoir fluid could result in H2S in the pit area, although KRU CTD sidetracks have not seen this in the past. The Pit watcher should always carry a calibrated personal H2S monitor. ~' 3. Reservoir pressure - 3M-29A BHP is expected to be 3374 psi at 5953' TVD SS (10.9 ppg EMW). Reservoir frac gradient is ~0.75 psi/ft or 14.4 EMW, 4465 psi. Maximum anticipated wellhead pressure wi full column of gas is 2779 psi with a 0.1 psi/ft gas gradient. 4. The Dynamically Overbalanced Coiled Tubing Drilling (DOCTD) technique will be used. Drilling will be done with a less than kill-weight fluid (9.0 ~ Flo-Pro). While drilling and circulating at 1.5 BPM, head from the 9 ppg mud (2786 psi), plus 1160 psi of annular friction, plus 0 psi choked backpressure held on the return side will provide a 3946 psi BHP and overbalance the reservoir by ~572 psi. However, when circulation is shut down, the reservoir could'be underbalanced by ~588 psi. Maintain at least 1100 psi WHP / when not circulating to prevent reservoir in-flux and to maintain formation stability by keeping static BHP close to circulating BHP seen during drilling. Adjust SIWHP accordingly when BHP increases are seen on the downhole PWD sub. Increases will occur from higher-than-expected friction pressures and/or reservoir pressures. Refer to the PWD BHP vs Depth chart to detem1ine if deviations occur. Monitor return-line flow rate and pit volume continuously. If a pit gain has been identified (underbalance event occurred), divert those returns to an outside tank. 5. No gas saturated intervals are expected. However, be prepared for the potential for gas influx since a nearby injector has received MI injection in the past. Ensure all PVT equipment is fully operational and monitor return-line flow rate and pit volume continuously. 6. Lost circulation is not expected. Two faults (13-18' throw) could be encountered along the wellbore trajectory. Lost circulation to these faults is considered low risk. If lost circulation occurs plan to control it with adjustments to the DOCTD parameters. Lower circulation rate (1 BPM minimum) and a reduction in mud density would be utilized prior to LCM treatments. However, as a contingency ensure that LCM material is on location so that a pill could be mixed quickly if required. Pump only Liquid Casing or OM Seal fine through a slimhole drilling BHA. Do not pump MI Seal through a drilling BHA due to plugging potential. MOJ 564-5666 office, 240-8034 cell 3/3 TUbin¿ @ 11530' Perfs 11594-11614' ) , KRU 3M-29A PROPOSED CT HORIZONTAL ~')DETRACK LJ+ Camco DS landing nipple 514' 9-5/8" Shoe @ 5827' .. - -- 3-1/2",9.3#,L-80 Production Tubing to Surface B J B 3-1/2" x 7" Baker SAB-3 Packer @ 11504' --.- ---- Top of 2-3/8" Liner@11520' (proposed) Mill Window in 7" Casing @ 11596' / ~ 7" Liner & Perfs P&A'd with 17.0 ppg Cement 3" oP\hole 007 0000 2-3/8" STL 4.6# pre drilled liner 4 holes per foot ",,/ TD @ 13505' » 0000 Last tag fill at 11715' MOJ 3119/02 A ~ 7" Shoe @ 11856' ') .PHlllIPS Alaska, Inc. ~ A Slbsldlary of PHILLIPS PETROLEUM COMPANY I." "M"" , ',!f :3 ..29; ,~ API: 500292264100 - " '., SSSV Type: Cameo 'OS' Landing Nipple ,tj Annular Fluid: ~~ l NIPPLE (514-515, OD:3.5OO) Gas Lift MandreINalve 1 (4502-4503, 00:5.390) Gas Lift MandrelNalve 2 (8264-8265, OD:5.390) Gas Lift MandrelNalve 3 (10190-10191, 00:5.390) Gas Lift MandreVDummy Valve 4 (10925-10926, 00:5.390) Gas Lift MandreVOummy Valve 5 (11246-11249, 00:5.390) Gas Lift MandrelNalve 6 (11449-11450, 00:6.018) NO GO (11495-11496, 00:3.500) SEAL ASSY (11503-11504, OD:3.5OO) NO GO (11520-11521. OD:3.5OO) TUBING (0-11530. OD:3.5OO. J 10:2.992) SHEAR OUT (11529-11530, 00:3.500) Perf (11594-11614) I , , ' -,,""',i,.,'.' .f I ::;i :! .-:18, ,,:,',~' .8IJ18 ': ;~1 . :'? :~ . -.r..",',',', " ' .... .. --- Ij'1~ ----- &-IISo<f/ ~ - ~ - IIS1P .~t;l~~ ~:,:;: L'1.~ . .. ,- , 'J~ I --0~h4- -- Reference Log: Last Tag: 11707 Last Tag Oate: 11/23/00 Casln~fStrlnQ$'~:AII ' Description Size CONOUCTOR 16.000 SURF CASING 9.625 PROO CASING 7.000 TUblnQ:StrlnQs~:ÄII'. Description Size TUBING 3.500 Peñoratlons SUmm'3rY Interval TVD 11594 - 6012 - 6027 11614 . '. k.,1 3M-29 Well Type: PROD Orig Compltn: 1/27/96 Last W /0: Angle@ TS: 42 deg @ 11592 Angle @ TO: 40 deg @ 11866 Rev Reason: Tag Update; JWP. Last Update: 12/18/00 Ref Log Date: TO: 11866 ftKB Max l:IoIe 68 deg @ 7829 Angle: Top Bottom TVD Wt Grade 0 121 121 62.58 H-40 0 5827 3422 36.00 J-55 0 11856 6211 26.00 J-fi . ~ . ',. .. " Top Bottom TVD Wt Grade 0 11530 5964 9.30 L-80 . ' ", , . Thread Thread EUE 8RO AB MOO " ~.. , Zone Status Ft SPF Date Type Comment A-1 20 4 5/3/96 IPERF 2118" EnerJet, 180 deg ph; Oriented 90 deg CW & CCW F/Lcm Gas,l.Jff¡MântitêlšNalVijs: , St" MD' WD"Man Man Mfr Type 1 4502 2873 Cameo KBMM 2 8264 4391 Cameo KBMM 3 10190 5193 Cameo KBMM 4 10925 5564 Cameo KBMM 5 11248 5770 Cameo KBMM 6 11449 5905 Cameo MMM Other(P'luq$t:'eqÜlp~,.etc.)- JEWELRY Depth TVD Type 514 513 NIPPLE Cameo 'OS' Landing 11495 5938 NO GO Cameo W' Nipple 11503 5944 SEAL Baker 'KBH-22' ASSY 11504 5945 PKR Baker 'SAB-3' Hyd. . 11520 5957 NO GO Cameo '0' Nipple 11529 5963 SHEAR Baker OUT 11530 5964 TUBING TAIL Genèral,;,Nô(j!s Date I Note 7/1/99 SBHP = 1043 psi. V Mfr V Type V OD Latch Port TRO GLV GLV GLV OMY OMY OV BK 0.156 1341 BK 0.156 1342 BK 0.250 1483 BK-5 0.000 0 BK-5 0.000 0 RK 0.250 0 1.0 1.0 1.0 1.0 1.0 1.5 Description , . ' , ' . ~. . ", ~ . Date Vlv Run Cmnt 6/4/96 6/4/96 6/4/96 4/19/96 4/19/96 6/3/96 ID 2.812 2.812 3.250 3.250 2.750 2.992 2.992 :; 5550--: I ::r....,....................................LF. ."..:.:'. -...... ~ 0"0'-'''' '''::. ::. ::~ -:-":"."-"-':_'-". :'-':::_'~'. - -'.':; .:- :_-:-~--:-1---'---'-':~--::~ ::_-::-:--~--:--:_--'-~--:--:--~----'-------~--~--:-'~.::_-:~..:-.t-:_---.-.~--~-.::_---------~- -; -~ ~~.~.-~-~ ~t.~~;1 . ~ \"'f'" ;.:. ;'f.;.;.i'~'''''':'!';'''~'f'¡';';'~'''':';''';''';'f''';':.i'f"':"¡'''''f.,.j';'~'f''';'-'; -,. ',- ¡ )..~.; 7800 7Ij50 7900 7950 80'00 80'50 81'00 81'50 8200 8250 8300 8350 8400 8450 8500 8550 a800 8650 8700 8750 8800 8850 Vertical Section at 260.400 [50ft/in] Phillips Alaska, Inc. InUJIATH ÐETAlLI ~~:r __1petIo1 T-OfIMÐI Alii ..... D8bY8 3~ 11468.00 _"1 3~ v.- b.1o 280M. ~~ ~ ::..'% REFERENCE INFORMATION Co-ordinate ~¡ Reference. Well Centre 3M.29, True North V~=ri (VS¡ ~:r.;= ~~70~o:.osoo~~e"e' Measured Depth R.fe,.",œ. 31.4-29 68.00 Calcutation Method. Minimum Curvature ... .. 1t4U.OO "".1"5 ~.t7 2 1USO...2t 41." 221.2. 1 '15.11.00 4IUI1 »'1.11 '" 1. TD!.12 ".00 »t.GO s Ul0.4.OG ..... 2J4.08 ; ur.:SS IH~ m~ ;, §iit5 E~ =:: 1~ :=;:00 ":00 ::::: h ~~~::H n:i! :~1: TVD fN/-l .EI.Jff Dt.A8 Tf8<. suo.'" -5H1.5.2 -'084.1-G aM 0.00 JI.14 rJ~:: ~~~: ::~3J: ~ ~::1: .n !!Ita,.. ..fUO.U -nr1.D' ..,.80 ut.n H8Q.'11 ...-08234 -7310.11 10.... 30.00 ~J::: ::~~~ :~:U:fl ~:::g :~:= .13 5i!~ t1!!~ :;n!5 1~ 'i~:ñ iæ:! ItH.t.4 ",M8A2 .7....1-G 10.00 "'.00 8&47..20 =: ::rj~ :!!~~ ~!! ß:: !:rJ; ANNClTAn0N8 TV!! TVü Hi'-! +f;.W ~ 3If-2iI'TI 5e4Ooo..QOOeo .J'S1'99S ~ 3U-2MT2 ~oo ~5(54 .n.a5.11 P.rI: w.~ T] 5BeOOO -&ti'824 -QiS,2;4 P-:.rt ~T4 5QlS4.00 .æ,4i9l!l -lI62'3.1~ pg,:;, :!.1.1-2ioI<T!. !l!ltAO;) -e,nl1 ...Qœ.œ PG"'1 15160.78 11481.00 ðUS.o1 1188'.00 5181.10 1 "03~ 15180..31 11804.00 alUM 111'8.00 a,,"AI t2~.ðO &840.11 12114.Oa 8163.64 12308.øa &860.14 12401.00 688ð.14 12481.00 atÐQ.14 1851.00 T. ~ p08tion lOck off Pokrt i : ~ I . 5400'::j. 5450':; :1 5500-:-j ...- --.....----""." .-..-..- Ctüp r&'i1l IAKER HUOHI.I .-..............., INTEQ ..;¡'-':n-:: ~:::¡'f;.,-r; :;:;ì"....;~ Fi ~:1~.): n:~o-:~ :~':'~?J:: ~~J¡1~;:~:!:~g~~f;;9-;"-!-<~'J;: T 1\ M ft ¡ L.\ '.."¡'., Azimuths to True North Plan: Plan #4 (3M-29/Plan #4 3M.29A) Magnetic North: 25.79" Created By: James Ohlinger Date: 02104412002 LEGEND uu 3M-2.9(3M-29) -- Plan #4 3/J-29Ä __h PI2n #4 Magnetic Field Strength: 57432nT Dip Ãngle: 80.75" Date: 12i03312002 Model: BGGM2000 ':.>.ir.~~\,;'. 1~~')j~(-1~Ø.i~: £ + i' 1: 0 ~ i' .... ~ 0 en West(-)/East(+) [ft] -- -' ) Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ) ..: l;:sn;Q -------'-- Company: Field: Site: Well: Wellpatb: Field: Phillips Alaska. Inc. Kuparuk River Unit KRU 3M Pad 3M~29 Plan #4 3M-29A Date: 02/044/2002 Time: 14:00:29 Co-ordinate(NE) Reference: Well: 3M-29t True North Vertical (TVD) Reference: 3M-2968.0 Section (V8) Reference: Well.(O.00N,0.OOE.260.40Azi) Suncy Calculation Method: Minimum Curvature Db: Sybase Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: KRU 3M Pad Page: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2000 UNITED STATES - North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 3M-29 500292264100 Well Position: +N/-S -1329.20 ft +E/-W -1756.34 ft Position Uncertainty: 0.00 ft Northing: Easting : 6017499.33 ft Latitude: 70 27 32.522 N 507866.86 ft Longitude: 149 56 8.843 W North Reference: True Grid Convergence: 0.06 deg Slot Name: 6016168.40 ft Latitude: 70 27 19.448 N 506112.10 ft Longitude: 149 57 0.436 W Well: Well path: Plan #4 3M-29A 500292264101 Current Datum: 3M-29 Magnetic Data: 12/033/2002 Field Strength: 57432 nT Vertical Section: Depth From (TVD) ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 3M-29 11468.00 ft Mean Sea Level 25.79 deg 80.75 deg Direction deg 260.40 28/033/2002 1 From: Definitive Path Plan: Principal: Yes Targets Annotation 11468.00 11596.00 11703.62 11804.00 11879.00 12039.00 12114.00 12306.00 12401.00 12461.00 12951.00 Plan #4 Name 3M-29A T1 3M-29A T2 3M-29A T3 3M-29A T 4 3M-29A T5 MD TVD ft 5918.75 6013.06 6055.90 6048.31 6036.59 6013.09 6008.16 6021.54 6028.14 6028.14 6028.14 Height 68.00 ft +N/-S ft 0.00 Date Composed: Version: Tied-to: Map Map <-- Latitude --> <- Longitude --> Description TVn +N/-S +E/-W Northing Eastiog Deg }\lin See Deg Min See Dip. Dir. ft ft ft ft ft 6008.00 -6200.80 -7579.95 6009962.00 498538.00 70 26 18.426 N 150 0 42.915 W 6028.00 -6430.58 -7886.17 6009732.00 498232.00 70 26 16.163 N 150 0 51.896 W 6028.00 -6476.24 -8295.24 6009686.00 497823.00 70 26 15.710 N 150 1 3.901 W 6032.00 -6314.96 -8623.15 6009847.00 497495.00 70 26 17.292 N 150 1 13.530 W 6032.00 -6177.79 -8808.05 6009984.00 497310.00 70 26 18.639 N 150 1 18.962 W Tie in Position Kick off Point 1 2 3 4 5 6 7 8 9 ) Baker Hughes INTEQ " ) f&i1l -"'$ Baker Hughes INTEQ Planning Report ' . . . . . . . . . . . . . , . . lþlTEQ Company: Phillips Alaska, Inc. Date: 02/044/2002 Time: 14:00:29 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3M-29, True North Site: KRU 3M Pad Vertkal (TV D) Reference: 3M-29 68.0 WeU: 3M~29 Section (V8) RefeNnce: Well (0.00N,0.00E.260AOAzi) Wellpath: Plan #4 3M-29A Survey Calculation Method: Minimum Curvature Db: Sybase Plan Section Information MI> loci Azim TVD +N/-S +E/-W OLS Build Turn TFO Target ft deg deg ft ft ft deg/10Oft deg/10Oft deg/10Oft deg' 11468.00 43.95 229.97 5918.75 -5901.52 ~ 7094.30 0.00 0.00 0.00 0.00 11550.29 41.97 229.28 5978.97 -5937.85 -7137.03 2A7 ~2A1 -0.84 193.11 11596.00 41.57 229.19 6013.06 -5957.73 ~7160.09 0.88 -0.88 -0.20 188.49 11703.62 90.00 229.00 6055.90 -6020.13 -7232.06 45.00 45.00 ~0.18 359.75 11804.00 98.68 234.06 6048.31 -6082.34 -7310.31 10.00 8.65 5.04 30.00 11879.00 99.26 241.63 6036.59 ~6121.74 -7372.98 10.00 0.77 10.09 85.00 12039.00 97.53 257.71 6013.09 -6176.50 -7520.91 10.00 -1.08 10.05 95.00 12114.00 90.03 257.71 6008.16 -6192.42 -7593.98 10.00 -10.00 0.00 180.00 12306.00 82.03 240.19 6021.54 -6260.76 -7771.94 10.00 -4.16 -9.12 -115.00 12401.00 90.00 235.00 6028.14 -6311.50 -7851.85 10.00 8.39 -5.47 326.74 12461.00 90.00 229.00 6028.14 -6348.42 -7899.10 10.00 0.00 -10.00 -90.00 12951.00 90.00 278.00 6028.14 -6483.39 -8354.74 10.00 0.00 10.00 90.00 13313.00 88.82 314.18 6032.00 -6326.83 -8674.45 10.00 -0.33 10.00 92.00 13505.00 91.18 333.24 6032.00 -6172.79 -8787.56 10.00 1.23 9.92 83.00 Survey ...~ .....-----.---- -"""--,--"""",,,,--,-,----""'--------'-----.---.----- ----.-.~.,--.-.~------...,............---.....--....._......-.-.--.--. --- l\ID Incl Azim SSTVD N/S E/W MapN MapE DLS VS 1'FO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg ------..........-..-.~~ ._'---------------"'--- - -'- 11468.00 43.95 229.97 5850.75 -5901.52 -7094.30 6010261.65 499023.35 0.00 7979.14 0.00 MWD 11500.00 43.18 229.71 5873.94 ~5915. 75 -7111.16 6010247.41 499006.51 2.47 7998.13 193.11 MWD 11550.29 41.97 229.28 5910.97 -5937.85 -7137.03 6010225.30 498980.66 2.47 8027.33 193.30 MWD .j 1589.23 ¡ 41.63 ??9.?0 5940.00 -5954.79 -7156.69 6010208.33 498961.01 0.88 8049.54 188.49 3M-29A uw.""_I~.....~J 11596.00 41.57 229.19 5945.06 -5957.73 -7160.09 6010205.40 498957.62 0.88 8053.38 188.55 MWD /(oP 11600.00 43.37 229.18 5948.01 -5959.49 -7162.13 6010203.63 498955.57 45.00 8055.69 359.75 MWD 11610.00 47.87 229.15 5955.00 -5964.16 -7167.54 6010198.95 498950.17 45.00 8061.80 359.75 MWD 11617.71 51.34 229.13 5960.00 ~5968.01 -7171.98 6010195.11 498945.73 45.00 8066.82 359.77 3M-29A I 11620.00 52.37 229.13 5961.41 -5969.18 ~ 7173.34 6010193.93 498944.37 45.00 8068.36 359.78 MWD '\J<t 11624.33 54.32 229.12 5964.00 -5971.46 ~ 7175.97 6010191.65 498941.75 45.00 / 8071.33 359.79 3M~29A 'P -, \ð 11630.00 56.87 229.11 5967.20 ~5974.52 -7179.50 6010188.59 498938.22 45.00 8075.33 359.79 MWD u - \}\~ 11640.00 61.37 229.09 5972.33 -5980.14 -7185.99 6010182.97 498931.74 45.00 8082.66 359.80 MWD S ~YC" 11650.00 65.87 229.08 5976.77 -5986.00 -7192.76 6010177.10 498924.97 45.00 8090.31 359.81 MWD 11660.00 70.37 229.06 5980.50 -5992.08 -7199.77 6010171.01 498917.97 45.00 8098.23 359.82 MWD 11670.00 74.87 229.05 5983.49 -5998.33 -7206.97 6010164.76 498910.77 45.00 8106.38 359.82 MWD \It 11680.00 79.37 229.03 5985.72 -6004.72 -7214.33 6010158.36 498903.42 45.00 8114.70 359.83 MWD 11690.00 83.87 229.02 5987.17 -6011.21 -7221.80 6010151.87 498895.96 45.00 8123.15 359.83 MWD 11700.00 88.37 229.00 5987.85 -6017.75 -7229.33 6010145.32 498888.43 45.00 8131.66 359.83 MWD 11703.62 90.00 229.00 5987.90 -6020.13 -7232.06 6010142.94 498885.70 45.00 8134.75 359.83 MWD 11'150.00-'- 94.02 ~31.32 5986.28 -6049.81 -7267.64 6010113.23 498850.15 10.00 8174.79 30.00 MWD 11804.00 98.68 234.06 5980.31 -6082.34 -7310.31 6010080.68 498807.51 10.00 8222.28 30.08 MWD 11850.00 99.05 I 238.70 5973.21 -6107.49 -7348.14 6010055A9 498769.70 10.00 8263.78' 85.00 MWD 11879.00 99.26 241.63 5968.59 -6121.74 ~7372.98 6010041.23 498744.88 10.00 8290.64 85.72 MWD 11900.00 99.07 243.75 5965.25 -6131.25 -7391.40 6010031.70 498726.48 10.00 8310.39 95.00 MWD ,^vvV' ~ 11950.00 98.57 248.78 5957.58 -6151.13 -7436.61 6010011.79 498681.28 10.00 8358.28 95.34 MWD 12000.00 98.01 253.80 5950.36 -6166.99 ~7483A6 6009995.89 498634.45 10.00 8407.12 96.11 MWD vf 12039.00 97.53 257.71 5945.09 -6176.50 -7520.91 6009986.35 498597.01 10.00 8445.63 96.83 MWD 12050.00 96.43 257.71 5943.76 -6178.82 -7531.57 6009984.02 498586.35 10.00 8456.54 180.00 MWD 12100.00 91.43 257.71 5940.33 -6189.44 ~ 7580.30 6009973.36 498537.64 10.00 8506.35 180.00 MWD t.{1 D 12114.00 90.03 257.71 5940.16 -6192.42 -7593.98 6009970.37 498523.96 10.00 8520.33 180.00 MWD {'I (CI(/tft, '11') 12150.00 88.50 254.44 5940.62 -6201.08 -7628.91 6009961.68 498489.04 10.00 8556.22 245.00 MWD 12200.00 86.40 249.90 5942.84 -6216.36 -7676.45 6009946.36 498441.52 10.00 8605.64 245.04 MWD 12250.00 84.32 245.34 5946.89 -6235.33 -7722.52 6009927.36 498395.47 10.00 8654.23 245.24 MWD 12300.00 82.28 240.75 5952.72 -6257.83 -7766.77 6009904.83 498351.25 10.00 8701.61 245.61 MWD 12306.00 82.03 240.19 5953.54 -6260.76 -7771.94 6009901.89 498346.07 10.00 8707.20 246.15 MWD 12350.00 85.72 237.77 5958.24 -6283.30 -7809.42 6009879.33 498308.62 10.00 8747.92 326.74 MWD 12401.00 90.00 235.00 5960.14 -6311.50 -7851.85 6009851.09 498266.22 10.00 8794.45 327.00 MWD It 51(.. - (3$'05 :;:; /709/ ) Baker Hughes INTEQ ' ) .-4~ Baker Hughes INTEQ Planning Report 1.N'T'F~Q Company: Phillips Alaska, Inc. Date: 02/044/2002 Time: 14:00:29 Page: 3 Field: Kuparuk River Unit CQ-otdinate(NE) Reference: Well: 3M-29, True North Site: KRU 3M Pad Vertical (TVD) Reference: 3M-29 68.0 WeU: 3M-29 Seetion (VS) Ret'ercncc: Well (O.00N,0.00E,260.40Azi) Well path: Plan #4 3M-29A Survey Calculation Method: Minimum Curvature Db: Sybase Survey 1\ID loci Azim SSTVD N/S EIW MapN MapE DLS VS TFO Tool ft deg deg .ft ft ft ft ft. deg/10Oft ft deg 12450.00 90.00 230.10 5960.14 -6341.29 ~7890.74 6009821.27 498227.36 10.00 8837.76 270.00 MWD 12461.00 90.00 229.00 5960.14 -6348.42 -7899.10 6009814.13 498219.00 10.00 8847.20 270.00 MWD 12500.00 90.00 232.90 5960.14 -6372.99 ~7929.39 6009789.54 498188.73 10.00 8881.16 90.00 MWD 12550.00 90.00 237.90 5960.14 ~6401.37 -7970.53 6009761.13 498147.62 10.00 8926.46 90.00 MWD 12600.00 90.00 242.90 5960.14 -6426.06 -8013.99 6009736.41 498104.18 10.00 8973.43 90.00 MWD 12650.00 90.00 247.90 5960.14 -6446.87 -8059.44 6009715.57 498058.75 10.00 9021.71 90.00 MWD 12700.00 90.00 252.90 5960.14 -6463.64 -8106.53 6009698.76 498011.68 10.00 9070.94 90.00 MWD 12750.00 90.00 257.90 5960.14 -6476.24 -8154.90 6009686.12 497963.33 10.00 9120.73 90.00 MWD 12800.00 90.00 262.90 5960.14 -6484.57 -8204.18 6009677.75 497914.06 10.00 9170.72 90.00 MWD 12850.00 90.00 267.90 5960.14 -6488.58 -8254.01 6009673.70 497864.24 10.00 9220.51 90.00 MWD 12900.00 90.00 272.90 5960.14 -6488.23 -8303.99 6009674.01 497814.26 10.00 9269.74 90.00 MWD 12951.00 90.00 278.00 5960.14 -6483.39 -8354.74 6009678.81 497763.52 10.00 9318.97 90.00 MWD 13000.00 89.83 282.90 5960.21 -6474.50 -8402.92 6009687.65 497715.34 10.00 9364.99 92.00 MWD 13050.00 89.66 287.89 5960.44 -6461.23 -8451.11 6009700.88 497667.14 10.00 9410.29 91.99 MWD 13100.00 89.49 292.89 5960.81 -6443.82 -8497.96 6009718.26 497620.28 10.00 9453.58 91.97 MWD 13150.00 89.32 297.89 5961.33 -6422.38 ~8543.11 6009739.65 497575.12 10.00 9494.53 91.93 MWD 13200.00 89.16 302.89 5962.00 -6397.10 -8586.22 6009764.90 497531.99 10.00 9532.82 91.88 MWD 13250.00 89.00 307.89 5962.80 -6368.16 -8626.97 6009793.80 497491.22 10.00 9568.17 91.81 MWD 13300.00 88.86 312.88 5963.74 -6335.78 -8665.04 6009826.15 497453.13 10.00 9600.30 91.73 MWD 13313.00 88.82 314.18 5964.00 -6326.83 -8674.45 6009835.09 497443.71 10.00 9608.10 91.64 MWD 13350.00 89.27 317.86 5964.62 -6300.21 -8700.14 6009861.68 497418.00 10.00 9628.98 83.00 MWD 13400.00 89.89 322.82 5964.98 ~6261.73 -8732.04 6009900.13 497386.07 10.00 9654.02 82.94 MWD 13450.00 90.51 327.78 5964.81 -6220.64 -8760.50 6009941.20 497357.58 10.00 9675.23 82.90 MWD 13505.00 91.18 333.24 5964.00 -6172.79 -8787.56 6009989.02 497330.49 10.00 9693.93 82.92 MWD l ) ) Johnson, Mark 0 From: Sent: To: Cc: Subject: Tom Maunder [tom_maunder@admin.state.ak.us] Thursday, March 07, 20024:53 PM Dan Venhaus JohnsoMO@bp.com; Michael B Mooney; R Marty Lemon Re: KRU permits to BP office !::J Card for Tom Maunder Thanks Dan, this will do just fine. Dan Venhaus wrote: > Tom, > > > > > > > > > > > > > If you need anything else, let me know. > > > > > > > > > > > > > > > > > > Dan, > > > > > > Tom needs a e-mail from you authorizing delivery of the Phillips operated > well permits to the BP office (even though they originated from me) > > > > > > > The Kuparuk CTD program starting up in April consists of 3 wells: 3H-16A, 3C-04A, and 3M-29A. Well 3H-16A's permit was submitted by Phillips and has been approved. This well is a combination rotary/CTD sidetrack with the rotary part completed in November 2001 with Phillips' Nordic 3 rig. / Wells 3C-04A, 3M-2~ (and the 3H-16A extension) are to be drilled solely with BP's Nordic 1 CTD unit. BP's CT drilling services are being provided to the operator Phillips via a Shared Service operation. As such, Phillips authorizes the delivery of 3C-04A and 3M-29A permits to BP (Terry Hubble) . Phillips does request that BP provide a copy of the approved permits. Dan Venhaus Phillips Alaska, Inc. CT Drilling Engineer 263-4372 work 230-0188 cell ----- Forwarded by Dan Venhaus/PPCO on 03/07/2002 02:36 PM ----- "Johnson, Mark 0" <JohnsoMO@BP.com> 03/06/2002 07:14 AM To: Dan Venhaus/PPCO@Phillips cc: Subject: KRU permits to BP office I was talking to Tom Maunder this morning. It does not look like he can make a DOCTD meeting today and he will get back with me on an alternate date. Content 1) Please send KRU CTD sidetrack permits to BP office (normal Terrie Hubble address) 2) Background on why they need to go to BP. (CTD is a shared service (BP & Phillips) with the rigs operated by BP, but sidetracking KRU wells.) 3) Three well program in 2002 (list well names). 1 ) Nordic CTD BOP Detail 7-1/16" ID, 5000 psi working pressure \... ./ Ram Type Dual Gate I I I I BOPE TOT FC:' - 'i:::=J=i I Blind/Shear I Manual over Hydraulic ~ I t=L= @ I 2" Combi Pipe/Slip Flanged Fire Resistant HCR I I - . K~~o~~:a~gl~al [@Itffi ~I¡n~i've I l 7-1/16" ID, 5000 psi working pressure ~ ~~~~~. F~ I 2 3/8" Combi Pipe/Slip Ram Type Dual Gate I It;;:::i ~ BOPE TOT ~ (ci) I 2" Combi Pipe/Slip, Manual over Hydraulic c:: I I I .1 XO Spool as necessary \ / 2 flanged gate valves I I @) , I @ I I THA I J '--fò\-- ~ 7" Annulus Tubing ~ í Spool =, I I -@ - ~ 9 5/8" Annulus /UI I 0f Methanol Injection ~ I Otis 7" WLA Quick I Connect - I I r Tree or Double Manual Master Valves II L MOJ 01/23/01 ) o~ -- CT Injector ~ Head I .w k" ::>tuttll1g Box (Pack-Off), 1 0,000 pSI or II1g Pressure I -- ~ - 7" Riser I I I , Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure Fire resistant Kelly Hose / I I H 206296 DATE INVOICE / CREDIT MEMO 03i2ü2 CKü3i202F PYMT COMMENTS: HANDL.~ NG I NST: DESCRIPTION Pernit to Drill Fee S/H - Terrie Hubble RECEIVED APR 9 2 Q()"¿ AIa8ka Oit & Gas ConI. COIJ1mit¡sk)n And10rage THE ArTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY TOTAL ~ I ioo.ool X4628 GROSS 3 rlrl '~:2- q /1 100 on DATE CHECK NO. (~).3_/ 1.4 / C);~ {=} C} 2 Ci t:l 2 S¡ 6 VENDOR DISCOUNT Ai AShA¡-! T ¡ /:, NET . - - -- It;;t). ()t) ino no No. H2O 6 2 9 6 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO DATE 03i~ 14/-{J2 III 2 0 b 2 g b III I: 0 L. ¡. 2 0 :¡ B g 5 I: 0 0 B L. L. ¡. g III To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 56-389 ---¡:j2 CONSOLIDATED COMMERCIAL ACCOUNT 002()62SI6 ONE HUNDRED & OO/iOO************************************* US DOLLAR AMOUNT $100. 00 NOT VALID AFTER 120 DAYS \( ~t. ( ~ /}/,' 'J ~(3i' "/'d' 'J~ { :i ( .! H ~ .- ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BEINCLUDEDINTRANSNUTTALLETTER WELL NAME ¡¿ fll .3/Í(-2-c¡A CHECK 1 ST ANDARD LEITER DEVELOPMENT DEVELOPMENT REDmLL / EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) , ~NUL? D~SAL t7'NO ANNULAR DISPOSAL <.--> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new well bore segment of existing weD ~PermitNo, ,API No. . " Production should continue to be reported as a function of the original API number stated above. ' In accordance with' 2,0 AAC 2S.00S(f), all r~ords, data and logs acquired for tbe pilot bole must be dearly , differentiated in both name (name on permit plus PH) and API number (SO -70/80) from , records, data and logs acquired for wel~ (na,me on permit). Annular disposal has ~ot' been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated... . ANNULUS L-J YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill tbe above referenced well. The permit is approved .sùbJed to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuanee of a conservation order approving a spacing exception. (Company Name) will assume tbe liability of any protest to tbe spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY ~ //1"..5 WELL NAME Kelt., 3A(- a Æ FIELD & POOL Ý?I)/é(") INIT CLASS '-::Þ.EV 1/)/( .- ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . \ N 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . IN 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y , N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N AP~ DATE 12. Permit can be issued without administrative approval.. . . . . N /UJ '-I. (D-D"L 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ¥--tr 15. Surface casing protects all known USDWs. . . . . . . . . . . -Y N - .( II 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ¥--'"N- 1~j4- 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . u¥--N- ~l I " 18. CMT will cover all known productive horizons. . . . . . . . . . -¥--'fr c:;/u?flUl it ~ . 19. Casing designs adequate for C: T, B & permafrost. . . . . . . tfi2 N " ' , - A J - J ~ ( 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . fi2 N C--T D&l. - l'-'PtM. L . 21. If a re-drill, has a 10-403 for abandonment been approved. . . á/ N A-pPYl9IjQ-d ~ {wlo 'l. . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N 23. If diverter required, does it meet regulations. . . . . . . . . . ¡fAil/\- 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . ,- N APPR DATE 26. BOPE press rating appropriate; test to ~ 50L0 psig. .. N ¡vu,~ S'¡J ;; 'Z 777 ¡l k" '. WGA Llf¡II-'z- 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ N 28. Work will occur without operation shutdown. . . . . . . . . . . N, L "". - A 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . " N ~. IJ-fé-~ ' 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Yí'N) (?lli'.~1..'¡" ~ 34'-2....9;. ~LJ /~ ~ ~S, 31. Da~a ~resented. on potential overpressure zones. . . . . . . (J)~ E}£~M ~t/o'r- ~.5.5.i.';'~ ¡/; ;e') 1'9 d7J?! é: ::%??"Cé). 32. Seismic analysIs of shallow gas zones. . . . . . . . . . . .. A.. Y N (j - - II , (/ {/ AP~~ O.ATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . .. ,AI~ þD l.f ./0./;12-- 34. Contact name/phone for weekly progress reports [exploratory on!tJt y I~ ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool;-and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: PROGRAM: Exp - Oev ~ Redrll V"Serv - Wellbore seg - Ann. disposal para req- GEOL AREA fJ7() UNIT# 0 1/ / (-.,["J ON/OFF SHORE ~/1 ( GEOLOGY .( APPR OA TE ~ ~ No W,-"LuiAr ~SI)DÇA) r'1?t\tI,-Þd ' Commentsllnstructions: RPC' TEM SF~ WGA W4A- COT DTSO<f( () lo¿ JMH, G: \geology\templates\checklist, doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history me. To improve the readability of the Well History me and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPEN.DIX. No special "effort has been made to chronologically " . organize this category of information. \ " dQ;(-O?'I **** REEL HEADER **** MWD 02/09/26 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/09/26 296123 01 2 3/8" CoilTrak *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! Remark File Version 1.000 Extract File: ldwg.las ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11500.0000: STOP.FT 13315.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value Phillips Alaska 3M-29A Kuparuk River Unit 70 deg 27' 19.448"N North Slope Alaska Baker Hughes INTEQ 2 3/8" Coil Trak 14-May-02 500292264101 149 deg 56' 60.000"W ------------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . ~Remarks 14 12N 09E MSL 0 RKB 68 KB 68 N/A N/A N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ) ') (1 ) (2 ) (3 ) ( 4 ) All depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data presented is realtime data. Well 3M-29A was sidetracked at 11596' MD (5944' SSTVD) from the borehole of 3M-29 S TK1 and was drilled to TD @ 13315' MD (5998' SSTVD) on Run 14. Baker Hughes Inteq utilized CoilTrak downhole tools and the (5) Advantage (6 ) to a PDC surface system. The data presented here is final and has not been depth shifted (Primary Depth Control) Log. Per PAI Geoscience standing order this MWD GR is the depth reference for this well. (7) Gamma ray detector type is a scintillator. (8) The interval from 13291' MD (5995' SSTVD) to 13315' MD (5998' SSTVD) (9) was not logged due to sensor to bit offset. A Magnetic Declination correction of 26.92 degrees has been applied to the Directional Surveys. MNEMONICS: GRCX -> Gamma Ray MWD-API [MWD] (MWD-API ROPS -> Rate of Penetration, feet/hour SENSOR OFFSETS: RUN GAMMA 9 24.00 ft. 10 24.00 ft. 11 24.00 ft. 12 24.00 ft. 13 24.00 ft. 14 24.00 ft. uni t s ) DIRECTIONAL 24.00 ft. 24.00 ft. 24.00 ft. 24.00 ft. 24.00 ft. 24.00 ft. Tape Subfile: 1 68 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 Philips Alaska Inc. 3M-29A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** ! ! ! !! !! !!! ! ! !! ! ! !!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has not been depth shifted to a PDC Log. 3. Per PAI Geoscience standing order,no depth shifting has been done ) ) as this MWD GR is the depth reference for this well. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRCX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 API F/HR 4 4 4 4 ------- 8 Total Data Records: 44 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.000000 13315.000000 0.500000 **** FILE TRAILER **** Tape Subfile: 2 53 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VAL U ---------------------------- WDFN LCC CN WN FN COUN STAT raw.xtf 150 Philips Alaska Inc. 3M-29A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !! ! ! !! !! ! !!! !! ! ! !!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRCX ROPS ---------------------------------------------------- GRCX ROPS GRCX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 . Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 1 1 4 4 4 4 68 68 GRCX MWD ROPS MWD API F/HR ------- 8 Total Data Records: 87 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.250000 13315.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 3 96 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD ') 02/09/26 296123 01 **** REEL TRAILER **** MWD 02/09/26 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: ) 2 records... 132 bytes 132 bytes ) ') Tape Subfile 1 is type: LIS ') Tape Subfile 2 is type: LIS DEPTH 11500.0000 11500.5000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13100.0000 13200.0000 13300.0000 13315.0000 GR -999.2500 -999.2500 46.1429 72.5396 74.8196 53.3320 46.4161 47.7683 53.2608 65.9666 48.4486 73.5375 72.4756 83.1831 58.9639 46.9303 68.1817 84.0689 64.3935 -999.2500 -999.2500 ) ROP -999.2500 -999.2500 6.6000 84.1800 63.4900 33.9600 0.0000 21.5000 2.3692 52.5200 110.2700 45.1200 83.5100 28.8000 105.9000 130.6200 36.0800 50.7900 60.0000 54.0000 336.1486 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.000000 13315.000000 0.500000 Tape Subfile 3 is type: LIS DEPTH 11500.2500 11500.5000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13100.0000 13200.0000 13300.0000 13315.0000 GRCX -999.2500 -999.2500 44.3869 72.7079 74.5188 54.2939 46.6423 48.0250 52.7258 66.5458 47.7974 73.8249 71.1611 83.4113 58.1542 46.6172 67.6035 84.0028 65.2254 -999.2500 -999.2500 ROPS -999.2500 -999.2500 6.6000 84.1800 63.4900 33.9600 0.0000 21.5000 2.3692 52.5200 110.2700 45.1200 83.5100 28.8000 105.9000 130.6200 36.0800 50.7900 60.0000 54.0000 336.1486 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.250000 13315.000000 0.250000 Tape Subfile 4 is type: LIS ó1 (Jd- of{Y **** REEL HEADER **** MWD 02/09/26 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/09/26 296123 01 2 3/8" CoilTrak *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: ldwg.las ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11500.0000: STOP.FT 13089.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. . STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value Phillips Alaska 3M-29APBl Kuparuk River Unit 70 deg 27' 19.448"N North Slope Alaska Baker Hughes INTEQ 2 3/8" Coil Trak 09-May-02 500292264170 149 deg 57' 00.436"W ------------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . ~Remarks 35 13N 08E MSL 0 RKB 68 KB 68 N/A N/A N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1 ) (2 ) (3 ) (4 ) ) All depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data presented is realtime data. Well 3M-29APB1 was kicked off at 12690' MD (5972' SSTVD) from the original hole 3M-29 and was drilled to TD @ 13089' MD (5956' SSTVD) on Run 8. Baker Hughes Inteq utilized CoilTrak downhole tools and the (5) Advantage (6) to a PDC surface system. The data presented here is final and has not been depth shifted (Primary Depth Control) Log. Per PAI Geoscience standing order this MWD GR is the depth reference for this well. (7) Gamma ray detector type is a scintillator. (8) The interval from 13065' MD (5995' SSTVD) to 13089' MD (5956' SSTVD) was not logged due to sensor to bit offset. MNEMONICS: GRCX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour SENSOR OFFSETS: RUN GAMMA 1 24.10 ft. 2 35.20 ft. 3 35.00 ft. 4 35.85 ft. 5 24.74 ft. 6 24.74 ft. 7 24.97 ft. 8 24.97 ft. Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 DIRECTIONAL 23.10 ft. 34.10 ft. 33.90 ft. 34.80 ft. 23.69 ft. 23.69 ft. 23.92 ft. 23.92 ft. 68 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 Philips Alaska Inc. 3M-29APB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! !!!! ! ! !!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has not been depth shifted to a PDC Log. 3. Per PAI Geoscience standing order, no depth shifting has been done as this MWD GR is the depth reference for this well. ,) *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRCX05 ROPS05 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 API F/HR 4 4 4 4 ------- 8 Total Data Records: 38 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.000000 13089.000000 0.500000 **** FILE TRAILER **** Tape Subfile: 2 47 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT ) mwd.xtf 150 Philips Alaska Inc. 3M-29APBl Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRCX ROPS ---------------------------------------------------- GRCX ROPS GRCX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 68 68 1 1 4 4 4 4 GRCX MWD ROPS MWD API F/HR ------- 8 Total Data Records: 76 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.000000 13089.500000 0.250000 **** FILE TRAILER **** Tape Subfile: 3 85 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/09/26 ') 296123 01 **** REEL TRAILER **** MWD 02/09/26 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes ) Tape Subfile 1 is type: LIS I ' Tape Subfile 2 is type: LIS DEPTH 11500.0000 11500.5000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13089.0000 GR -999.2500 -999.2500 42.7012 73.1265 72.8254 56.9069 47.2987 46.6882 52.2143 68.2573 48.5128 74.9632 71. 6488 77.1764 69.7819 79.7681 94.0094 -999.2500 ) ROP -999.2500 -999.2500 11.2200 85.2300 63.4900 33.9600 23.8737 22.2000 10.0728 52.5200 110.3250 45.3200 83.5100 20.3102 28.9500 80.8800 27.7500 40.5816 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.000000 13089.000000 0.500000 Tape Subfile 3 is type: LIS DEPTH 11500.0000 11500.2500 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13089.5000 GRCX -999.2500 -999.2500 42.7012 73.1265 72.8254 56.9069 47.2987 46.6882 52.2143 68.2573 48.5128 74.9632 71. 6488 77.1764 69.7819 79.7681 94.0094 -999.2500 ) ROPS -999.2500 -999.2500 11. 2200 85.2300 63.4900 33.9600 23.8737 22.2000 10.0728 52.5200 110.3250 45.3200 83.5100 20.3102 28.9500 80.8800 27.7500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.000000 13089.500000 0.250000 ) ) Tape Subfile 4 is type: LIS ) ao~~ocg4 I 105 7 ) **** REEL HEADER **** MWD 02/09/07 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/09/07 296123 01 2 3/8" CallTrak *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11500.0000: STOP.FT 13315.0000: STEP.FT 0.1000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- Remark File Version 1.000 Extract File: ldwg.las 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value Phillips Alaska 3M-29A Kuparuk River Unit 70 deg 27' 19.448"N 3M Alaska Baker Hughes INTEQ 2 3/8" Coll Trak 14-May-02 214160170 149 deg 56' 60.000"W ------------------------------- Description 14 12N 09E MSL 0 RKB 68 KB 68 N/A N/A N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . ~Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 3M-29A was sidetracked at 12690' MD (5917' SSTVD) from the borehole of 3M-29 S TK1 and was drilled to TD @ 13315' MD (5998' SSTVD) on Run 14. ) (5 ) Advantage Baker Hughes Inteq utilized CallTrak downhole tools and the (6 ) to a PDC surface system. The data presented here is final and has not been depth shifted (Primary Depth Control) Log. The MWD Gamma Ray is the PDC for this borehole. (7) Gamma ray detector type is a scintillator. (8) The interval from 13291' MD (5995' SSTVD) to 13315' MD (5998' SSTVD) (9) was not logged due to sensor to bit offset. A Magnetic Declination correction of 26.92 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API ROPS -> Rate of Penetration, feet/hour SSTVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA 9 24.00 ft. 10 24.00 ft. 11 24.00 ft. 12 24.00 ft. 13 24.00 ft. 14 24.00 ft. uni ts) DIRECTIONAL 24.00 ft. 24.00 ft. 24.00 ft. 24.00 ft. 24.00 ft. 24.00 ft. Tape Subfile: 1 68 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT gamma.xtf 150 Philips Alaska Inc. 3M-29A Kuparuk River Unit 3M Alaska *** LIS COMMENT RECORD *** !! !!! !! ! !!! !!! ! !! !! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has not been depth shifted to a PDC Log 3. The MWD Gamma Ray is the PDC for the borehole *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX01 ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) ) ) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.100000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.100 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 API F/HR 4 4 4 4 ------- 8 Total Data Records: 217 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.199219 13315.000000 0.100000 **** FILE TRAILER **** Tape Subfile: 2 226 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT gamma.xtf 150 Philips Alaska Inc. 3M-29A Kuparuk River Unit 3M Alaska *** LIS COMMENT RECORD *** !! ! !! !! ! ! !! !! !! ! ! !! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CRAN DIMT CNAM ODEP ---------------------------------------------------- GRAX RaPS GRAX RaPS GRAX RaPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.100000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.100 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRAX MWD RaPS MWD 68 68 1 1 API F/HR 4 4 4 4 ------- 8 Total Data Records: 217 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.199219 13315.000000 0.100000 **** FILE TRAILER **** Tape Subfile: 3 226 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/09/07 296123 01 **** REEL TRAILER **** MWD 02/09/07 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: ) 132 bytes ) ) .J Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 11500.1992 11500.2988 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13100.0000 13200.0000 13300.0000 13315.0000 GR -999.2500 -999.2500 46.1429 72.5396 74.8196 53.3320 46.4161 47.7683 53.2608 65.9666 48.4486 73.5375 72.4756 83.1831 58.9639 46.9303 68.1817 84.0689 64.3935 -999.2500 -999.2500 ) ROP -999.2500 -999.2500 6.6000 84.1800 63.4900 33.9600 0.0000 21.5000 2.3692 52.5200 110.2700 45.1200 83.5100 28.8000 105.9000 130.6200 36.0800 50.7900 60.0000 54.0000 336.1486 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.199219 13315.000000 0.100000 ) Tape Subfile 3 is type: LIS DEPTH 11500.1992 11500.2988 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13100.0000 13200.0000 13300.0000 13315.0000 GRAX -999.2500 -999.2500 44.3869 72.7079 74.5188 54.2939 46.6423 48.0250 52.7258 66.5458 47.7974 73.8249 71.1611 83.4113 58.1542 46.6172 67.6035 84.0028 65.2254 -999.2500 -999.2500 ROPS -999.2500 -999.2500 6.6000 84.1800 63.4900 33.9600 0.0000 21.5000 2.3692 52.5200 110.2700 45.1200 83.5100 28.8000 105.9000 130.6200 36.0800 50.7900 60.0000 54.0000 336.1486 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.199219 13315.000000 0.100000 ) } Tape Subfile 4 is type: LIS ) ) a oJ~oítj Ilo5'l **** REEL HEADER **** MWD 02/09/12 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/09/12 296123 01 2 3/8" CallTrak *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: Idwg.las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11500.0000: STOP.FT 13089.0000: STEP.FT 0.2500: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value Phillips Alaska 3M-29PBl Kuparuk River Unit 70 deg 27' 19.448"N North Slope Alaska Baker Hughes INTEQ 2 3/8" ColI Trak 09-May-02 500292264101 149 deg 57' 00.436"W ------------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . -Remarks (1) All (2) All (3) All 35 13N 08E MSL 0 RKB 68 KB 68 N/A N/A N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 depths are Measured Depths (MD) unless otherwise noted. depths are Bit Depths unless otherwise noted. Gamma Ray data presented is realtime data. .. (4) Well 3M-29PB1 was kicked off at 11696' MD (5972' SSTVD) from the original hole 3M-29 and was drilled to TD @ 13089' MD (5956' SSTVD) on Run 8. (5) Baker Hughes Inteq utilized CallTrak downhole tools and the Advantage (6) to a PDC surface system. The data presented here is final and has not been depth shifted (Primary Depth Control) Log. The MWD Gamma Ray is the PDC for this borehole. (7) Gamma ray detector type is a scintillator. (8) The interval from 13065' MD (5995' SSTVD) to 13089' MD (5956' SSTVD) was not logged due to sensor to bit offset. MNEMONICS: GRCX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour SSTVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA 1 24.10 ft. 2 35.20 ft. 3 35.00 ft. 4 35.85 ft. 5 24.74 ft. 6 24.74 ft. 7 24.97 ft. 8 24.97 ft. Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 DIRECTIONAL 23.10 ft. 34.10 ft. 33.90 ft. 34.80 ft. 23.69 ft. 23.69 ft. 23.92 ft. 23.92 ft. 68 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 Philips Alaska Inc. 3M-29PB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !! !! ! !! ! !! ! !!! !! ! !! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has not been depth shifted to a PDC Log 3. The MWD Gamma Ray is the PDC for the borehole *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- ) GR ROP GR ROP GRCX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 . Datum Frame Size is: 12 bytes Logging direction is .down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 API F/HR 4 4 4 4 ------- 8 Total Data Records: 76 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.000000 13089.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 2 85 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/09/12 296123 01 **** REEL TRAILER **** MWD 02/09/12 BHI 01 Tape Subfile: 3 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes ) Tape Subfile 1 is type: LIS ) Tape Subfile 2 is type: LIS DEPTH 11500.0000 11500.2500 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13089.0000 GR -999.2500 -999.2500 42.7012 73.1265 72.8254 56.9069 47.2987 46.6882 52.2143 68.2573 48.5128 74.9632 71. 6488 77.1764 69.7819 79.7681 94.0094 -999.2500 ) ROP -999.2500 -999.2500 11.2200 85.2300 63.4900 33.9600 23.8737 22.2000 10.0728 52.5200 110.3250 45.3200 83.5100 20.3102 28.9500 80.8800 27.7500 40.5816 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 11500.000000 13089.000000 0.250000 ) ) Tape Subfile 3 is type: LIS