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204-115
New Plugback Esets 7/26/2024 Well Name API Number PTD Number ESet Number Date CD2-09 PB1 50-103-20496-70-00 204-129 T39280 2-22-2006 CD2-10 PB1 50-103-20473-70-00 203-195 T39281 2-22-2006 CD2-28 PB1 50-103-20435-70-00 202-217 T39282 2-22-2006 CD2-40 PB1 50-103-20464-70-00 203-126 T39283 2-22-2006 CD2-43 PB1 50-103-20474-70-00 203-197 T39284 10-29-2004 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 E-20AL1 PB1 50-029-22561-70-00 204-055 T39286 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 I-17L1 PB1 50-029-23212-70-00 204-099 T39290 2-22-2006 S-01 PB1 50-029-23141-70-00 203-034 T39291 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 S-18 PB1 50-029-23133-70-00 202-242 T39293 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 D-28B PB1 50-029-21556-70-00 209-089 T39298 8-20-2012 E-01A PB1 50-029-20166-70-00 203-033 T39299 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 S-102L1 PB1 50-029-22972-70-00 203-156 T39302 10-26-2005 W-09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 RECEIVED • • STATE OF ALASKA y • ALASKA OIL AND GAS CONSERVATION COMMISSION JAN ® 4 2017 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed �r`j�t�0 p"9 C Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well ❑ Other:Set Patch itv h<r1 y 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-115 ✓ 3. Address: P.O.Box 196612 Anchorage, Development EI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21011-02-00 7. Property Designation(Lease Number): ADL 0028303 8. Well Name and Number: PRUDHOE BAY UNIT K-03B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11585 feet Plugs measured feet true vertical 8824 feet Junk measured feet Effective Depth: measured 11501 feet Packer measured 8732 feet true vertical 8824 feet Packer true vertical 8061.42 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 30-110 30-110 Surface 2655 13-3/8"72#L-80 29-2685 29-2681 4930 2670 Intermediate 8532 9-5/8"47#L-80 28-8559 28-7898 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9900-10800 feet 11100-11480 feet True vertical depth: 8777-8815 feet feet 8819-8824 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 26-8789 26-8116 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: r Intervals treated(measured): k Q r P c Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 387 P0913 22 1800 1835 Subsequent to operation: 438 25273 26 820 1645 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development l f Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 1C _ Phone +1 907 564 4424 Date 1/3/17 Form 10-404 Revised 5/2015 / %� >' + 2 l RBDMS LL-JAN 2 5 201 Submit Original Only • • 0) p, OOOOO c� r— OO � c., .t N V CD CD M �4g CD O M M O) OD N Nttt m V CO OD OD y- OD N N O CO O I's N y- y- CO OD N co v N I- co OD co 12111111 r� o) OODNJ- � Cp M N N N MM • co t CO LO O) N- CV CO 00 NOD0000 Z _ Q = OO) 000) O) CO co N N OD 00 N CO I W O 0 O O 0)_ _ OJOOD0000 _ a) MN *k ((OCo N N X N 4 (V ("Ni c OCO - N c- U N � �O\D _ �. M ••-- N 4 t C)O i) cc) a) coM = co CO L.O J N oD N00 W CC cW a N . U U w C � O � CeCLCLZ Z a W W W m ODl— ZZ D 0 u) Z J J F— • • Packers and SSV's Attachment PRUDHOE BAY UNIT K-03B SW Name Type MD TVD Depscription K-03B PACKER 8405.39 7757.92 7" Baker Packer K-03B TBG PACKER 8731.86 8061.42 4-1/2" Baker S-3 Perm Packer K-03B PACKER 8798.41 8125.79 4-1/2" Baker ZXP Packer • II rn Q c as O c O Z d c c H c W O = - '=,c0 3 o p D cLlw m Cl) 0 Q O rn Cn m 0 H 0_ C C v rn ~ 1- Oft m cam = d N vMO m a .� a a0 I- w =1 -06 c ao 45 E u O > LL a -1 cn Co 2 CU o ,n Q J }, C EU 'a J W = O N c- us us Q o� a) 0 d U) Z •V) m 0_ 5 co J z CO I- °' a) a. x J Q M = V) Q w a� m -0 0_ Dm c W v w 0 p m o as c`a U � W LULL m a. 11 ,- ,-� m OZ Ep �nO CO 7 .-. 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CV d CO TREE= 41/8"CARERDN 411 WB..LFEAD= MCEVOY SA NOTES: WELL ANGLE>70°@ 9902'. ACTUATOR= ALSO K-03B KB.B_B/= 61.07'. BF.81/= 24.57' KOP= 3050' Max Angle= 91"@ 11347' I I2092' —141/2"FES X NP,D=3.813" Datum MD= 9803' Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" —i 2691' 2989'-3027' 4-1/2"BKR FLO-GUARD ONE TRP PATCH, 1 C D=2.45"(11/22116) GAS LFT MANDRELS Minimum ID =2.45" 2989' VIIIIIIMIIIMIIIIII ST MD TVD DEV TY FE VLV LATCH PORT DATE 4 3235 3228 3 MMG-M DMY RK r 0 02/29/16 4-1/2" FLO-GUARD PATCH L 3 5206 5008 31 MMGM OWRK ' 0 02/29/16 2 6764 6329 32 MMG-M OW RK ' 0 08/05/04 1 8271 7636 26 14M3M DMV RK ' 0 08/05/04 till 8405' —19-5/8"X 7"BAKER LNR TOP PKR 9-5/8"CSG,47#,L80,BTM,D=8.681" H 8559' 1-- 9-5/8"ML.LOUT WINDOW 8559' PERFORATION SUMMARY I 8711' 1-14-1/2"FES X NP,D=3.813• REF LOG:SFERRY GR/MWD ON 02/99 g _ ANGLE AT TOP RTF: 89@9900' SEC I—7•X a-1/2'BAKER 3FKR D=3.875'/ Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DAIS I 8756' --14-1/2"HES X NP,D=3.813' 2-7/8" 4 9900-10800 0 08/01/04 2-7/8" 4 11100-11480 0 08/01/04 M 8776' —14-1/2•FES XN NP,D=3.725' 8776' H4-1/2"X 2-7/8"NP RED(7/27/16) 8789' Our WLEG 4-1/2"TBG,12.6#,1-80,.0152 bpf,D=3.958" --1 8789' 1-----------1 8794' —14-1/2"HGR LNR TOP PKR ■ 7"LNR,26#,L-80,.383 bpf,D=6.276' --1 8950' A L I I 4-1/2"LNR,12.6/1,1-80,.0152 bpf,D=3.958' —1 11585' &�����n�� DATE RE/BY COMMENTS DATE REV BY COMMENTS FRLDFDE BAY UNIT r 1983 ORIGINAL COMPLETION 03/09116 GB/JMD GLV GO(02/29/16) WELL: K-03B 02/22/99 SIDETRACK COMPLETION(A) 08/01/16 TBD/AU SET NP FiS)&XX RUG(07/27/16) PHRMT No:'1990030 08/05/04 /TLP SIDETRACK COMPLETION(B) 09/08/16 MGS/JMD RJLLED XX RUG(09/07116) API No: 50-029-21011-02 08/19/04 F4A V1LP'GLV co 12/01/16 KFS/JND'SET FLO-GUARD PATCH(11/22/16) SEC 4,T11N,R14E,1728'FTS&1121'Fa 08/28/04 /TLH CORRECTIONS 03/19/10 JLW/SV CSG CORRECTIONS BP Exploration(Alaska) 2.o4 -( - kt5 • -2--74Cot WELL LOG TRANSMITTAL PROACTIVE DIAC,NOSTIC SERVICES, INC. DATA LOGGED ECE I �. 1,4 ,201E aM.K.BENDER AUG.08 2016 To: AOGCC Makana Bender AOGCC 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merlon Kendall LR2-1 900 Benson Blvd. Anchorage, AK 99508 gancpdc(a.bp.com and SCANNED NOV 1 02016 ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 25-Jul-16 K-03B BL /CD 50-029-21011-02 2) Signed : v 6,,,,„„est Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Wchives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BPTransmit.docx e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d Q '+ - j L 5 Well History File Identifier Organizing (done) o Two-sided 11111111111" 111111 o Rescan Needed ""1111111 II 11I11I RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~skettes, No. 1+ o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date q I 'Ii 0 ~ 151 vnp Scanning Preparation BY: ~ ( '- u.~.:;-/ Date q, /9,/ () fn .J." x 30 = foo Date q / I fð / /) h IIIIIIIIIIII~ IIIII 151 V\1 r + {p = TOTAL PAGES fo b (Count does not include cover sheet) I"A IC) 151 r r H Project Proofing BY: ~ Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: (0 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES Maria) Date: q / I tð / D to If NO in stage 1 page(s) discrepancies were found: YES NO Stage 1 151 rn f NO BY: / l .... BY: Maria Date: 151 11111111I11I11 1111/ Scanning is complete at this point unless rescanning is required. ReScanned '" II 111111 1111111I BY: Maria Date: 151 Comments about this file: Quality Checked III 111/1111I111111I 10/6/2005 Well History File Cover Page.doc • • MICROFILMED 03/01/2008 DO NOT PLACE .:~"=; ,~, ". ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc L{j~ DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2041150 Well Name/No. PRUDHOE BAY UNIT K-03B Operator BP EXPLORATION (ALASKA) INC MD 11585 / TVD 8824 '-' Completion Date 8/4/2004 i- Completion Status 1-01L _..__._~-,--_.~"---~ Current Status 1-01L -~--,~._- .~-'-'~_.~- ~--~---- --'~-'~ ~- -~_.,-~-- REQUIRED INFORMATION Mud Log No Samples No ~~_._~-- --~-~-~- DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / RES, DIR / GR / RES / NEU Well Log Information: A¿ßO~-O~-~:~~~O~ y UIC N -----"-~_._-~~-~.._-~_.-_._.- Directional Surv~ Yes ~ ~._,--~- (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH ~ASC- ---- Directional Survey 8892 11585 f: Directional Survey 8892 11585 D Asc Directional Survey 8892 11585 [..f'(pt Directional Survey 8892 11585 I~ D Asc Directional Survey 8491 9550 I~ Directional Survey 8491 9550 , ED D Asc Directional Survey 8491 9550 I~t Directional Survey 8491 9550 I-ED D 12687 Gamma Ray 8202 11533 I )iqJt 12687 LIS Verification 8202 11533 1-e6 C Lis 13507 Induction/Resistivity 8559 11585 Open I L__,~~ Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received . Received Comments 9/14/2004 IIFR 9/14/2004 IIFR 9/14/2004 MWD MWD IIFR PB1 IIFR PB1 9/14/2004 MWD PB1 9/14/2004 MWD PB1 GR, EWR4, ABI,ROP GR, EWR4, ABI,ROP ROP DGR EWR plus Graphics / PB 1 ROP I DGR EWR 8559-11585 .__~~~D CTN 8:59-1158:J 9/14/2004 9/14/2004 9/14/2004 9/28/2004 9/28/2004 2/22/2006 . DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2041150 Well Name/No. PRUDHOE BAY UNIT K-03B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21011-02-00 MD 11585 TVD 8824 ADDITIONAL INFORMATION Well Cored? ® Chips Received?- Y / N Analysis Received? ~ Comments: Compliance Reviewed By: __ Completion Date 8/4/2004 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? ~ QiN Formation Tops ~ ---'~- D..., . Jl..~ ~ . . . . WELL LOG TRANSMITTAL 2'C4- 115 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17,2006 } 3!3:) 7 RE: MWD Fonnation Evaluation Logs K-03B + PB 1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 K-03B + PBl: LAS Data & Digital Log Images: 50-029-21011-02, 72 1 CD Rom ~--<::A (ì ~ ., - ~ 2-/2- õ/ ú/cJ . 20 if.- r I ':J RECEIVED /2rP~7 SEP 2 8 2004 WELL LOG TRANSMITTAL Alaska Oil & Gas Cons. Commission Anchorage . To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin IXa;:,v¡{ 333 West 7th Avenue, Suite 100 J\nchorage, Alaska 99501 September 15, 2004 RE: MWD Formation Evaluation Logs K-03B, AK-MW-3190564 1 LDWG formatted Disc with verification listing. API#: 50-029-21011-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. J\nchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. J\nchorage, Alaska 99508 Date 18 f,;)'¡ Si~¡~ , ... STATE OF ALASKA I ALAS~L AND GAS CONSERVATION COM 'SiaN WELL COMPLETION OR RECOMPLETION REPORT AND LOG o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1728' SNL, 1121' EWL, SEC. 04, T11N, R14E, UM Top of Productive Horizon: 601' SNL, 3375' EWL, SEC. 04, T11N, R14E, UM Total Depth: 383' SNL, 1293' EWL, SEC. 04, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 671384 y- _ 5975491 Zone- ASP4 TPI: x- 673609 y- 5976669 Zone- ASP4 Total Depth: x- 671521 y- 5976840 Zone- ASP4 1a. Well Status: a Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 25.110 One ¡Other 5. Datel Comp., Susp., or Aband. ! 8/4/2004 6. Date! Spudded 7/25/2004 7. DateIT.D. Reached 8/1/2004 I 8. KB $Ievation (ft): i 52.42' 9. Plug Back Depth (MD+ TVD) 11501 + 8824 10. Total Depth (MD+TVD) 11585 + 8824 11. Depth where SSSV set (Nipple) 2092' MD 19. Water depth, if offshore N/A MSL CASING, LINER AND CEMENTING RECORD SETT/NGDeP'tHMD Sl:rt'lNG DePTH TVD Top aø'Fr"oM 'lOP BO'Fr"oM Surface 110' Surface 110' Surface 2694' Surface 2691' Surface 8559' Surface 7898' 8394' 8949' 7748' 8272' 8791' 11585' 8119' 8824' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oil -Bel 298 No. of Completions 18. Directional Survey aYes DNo 21. Logs Run: DIR I GR I RES, DIR I GR I RES / NEU 22. 20" x 30" Insulated Conductor 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# L-80 4-1/2" 12.6# L-80 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 2-7/8" Gun Diameter, 4 spf MD TVD MD TVD 9900' - 10800' 8777' - 8815' 11100' - 11480' 8819' - 8824' 26. Date First Production: August 30, 2004 Date of Test Hours Tested PRODUCTION FOR 9/2/2004 4 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 569 900 24-HoUR RATE Oil-Bel 1,790 25. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls of Diesel 36" 17-1/2" 12-1/4" 8-112" 6-1/8" SIZE 4-1/2", 12.6#, L-80 REceIveD SEP -3 2004 Arta" Oil & G"s Co c,, 1b. Well Class: or ns. O,I"r.:"S'OI1 a Development M~ªøory o Stratigraphic 0 Service 12. Permit to Drill Number ~JI;t6 13. API Number 50-029-21011-02-00 14. Well Name and Number: PBU K-03B 15. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028303 17. Land Use Permit: GAs-McF 1,090 WATER-Bel 15 20. Thickness of Permafrost 1900' (Approx.) 8 cu yds Concrete 3729 cu ft Permafrost 'E' & PF II 1981 cu ft Class 'G', 133 cu ft PF 'C' 180 cu ft Class 'G' 403 cu ft Class 'G' DEPTH SET (MD) 8789' PACKER SET (MD) 8732' GAs-McF 6,537 WATER-Bel 87 CHOKE SIZE I GAS-Oil RATIO 57° 3,653 Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r·~··_··_·~·· ." . . C"".'" ....-,..... ~.i.'::.!d; .~ '"j;.;' i --'- - I \ \1-· ~ .~ V~:¡ t,/Yc : Form 10-407 'Reqisett--t212'003 None ORIGINAL CONTINUED ON REVERSE SIDE aii:3li? M.oJi (' tR\19i_~~i;) SEP G <: G\~ G .28. e GEOLOGIC MARKERS NAME MD TVD Sag River 8952' 8275' Shublik A 9003' 8325' Shublik B 9020' 8342' Shublik C 9039' 8360' Sadlerochit 9048' 8369' Top CGL I Top Zone 3 9128' 8447' Base CGL 9192' 8510' 23SB 9220' 8537' 21TS 9310' 8619' Zone 1 B 9395' 8684' Zone 1A I TDF 9480' 8730' 29. e FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECEIVED SEP - 3 2004 Alaska Oil & Gas C A ons. Commission nchorage 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubble ~Å!tÌ..t- ~ Title Technical Assistant Date 09,03-()t( PBU K-03B 204-115 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No. I Approval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Name: Common Name: K-03 K-03B 7/24/2004 7/27/2004 8/2/2004 FIT FIT LOT 8,590.0 (ft) 8,590.0 (ft) 11,585.0 (ft) 7,927.0 (ft) 7,927.0 (ft) 8,826.0 (ft) 10.20 (ppg) 8.50 (ppg) 8.40 (ppg) 550 (psi) 650 (psi) 3,500 (psi) 4,750 (psi) 4,150 (psi) 7,351 (psi) 11.54 (ppg) 10.08 (ppg) 16.03 (ppg) -- e Printed: 8/9/2004 9:37:34 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-03 K-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Sta rt: 7/14/2004 Rig Release: 8/4/2004 Rig Number: Spud Date: 10/2/1983 End: 8/4/2004 7/21/2004 09:30 - 13:00 3.50 MOB P PRE Prepare rig for move to C-17B. RD rig floor and top drive. Lay down derrick. Move the shop buildings to K pad. 13:00 - 22:30 9.50 MOB P PRE PJSM prior to moving Sub. Pull sub off of C-17B and move, with derrick down, to K-03B. Lay herculite, raise derrick, spot and level the sub. 22:30 - 00:00 1.50 MOB P PRE Move Rig Camp and Pits from C pad to K pad. RU rig loor and top drive. 7/22/2004 00:00 - 03:00 3.00 MOB P PRE Move Rig Camp and Pits from C pad to K pad. Spot Pits, Camp and Cuttings box. 03:00 - 03:30 0.50 MOB P PRE Hold Pre-spud meeting with all personnel. Accept Rig @ 0300 7/22/2004 03:30 - 04:30 1.00 MOB P PRE RU secondary annulus valve. PU DSM lubricator. 04:30 - 05:30 1.00 WHSUR P DECOMP Pull BPV with lubricator. Take on Seawater. RD DSM. 05:30 - 06:00 0.50 KILL P DECOMP RU and test lines to circulate out diesel freeze protection fluid. 06:00 - 08:00 2.00 KILL P DECOMP Reverse circulate out freeze protection diesel from tubing. Pump soap pill down tubing and displace freeze protection diesel from the annulus @ 11 bpm - 2,900 psi. Well is dead - 0 psi on Tbg and IA. 08:00 - 10:30 2.50 WHSUR P DECOMP Dry rod TWC and test from below to 1,000 psi. ND tree. 10:30 - 13:00 2.50 BOPSUP P DECOMP NU BOP's. 13:00 - 17:30 4.50 BOPSUP P DECOMP MU test joint and test valves and BOPE to 250/3,500 psi and Annular to 250/2,500 psi. LD test joint. Witness of the BOP test was waived by Jeff Jones of the AOGCC. 17:30 - 21:30 4.00 WHSUR P DECOMP PU riser and MU lubricator. Attempt to pull TWC - failed. PU joint of DP and wash top of hanger. Attempt to pull TWC - failed. RU floor to pull tubing while redressing pulling tool. Pull TWC with lubricator. RD DSM lubricator. 21 :30 - 00:00 2.50 PULL P DECOMP PU landing joint and screw into hanger. Back out the lock down screws and pull hanger to the floor. Required 260K (including block weight) to break free, once free PU - 140K. LD hanger and landing joint. RU SLB control line spooler. POH LD tubing. 7/23/2004 00:00 - 02:30 2.50 PULL P DECOMP Pull 4-1/2" tubing from well to 6,503'. RD SLB spooling unit. Clear floor. 02:30 - 10:00 7.50 PULL P DECOMP Pull 4-1/2" tubing from 6,503' to surface. Removed 266 jts 4-1/2" tubing, 8 GLM's, SSSV, Sliding Sleeve and Seal Assy. Recovered 30 clamps and pins and 2 stainless steel bands. RD tubing handling equipment and clear floor. 10:00 - 11 :30 1.50 BOPSUP P DECOMP PU test joint and MU test plug. Test BOPE and top drive to 250/3,500 psi. Pull test plug and LD test joint. Set wear ring. 11 :30 - 17:30 6.00 DHB P DECOMP RU SWS. RIH w/ 8.5" GR and Junk Basket. Tag stump @ 8,590'. POH. MU EZSV and firing head. RIH and set EZSV @ 8,582' ELM. POH and RD SWS. 17:30 - 18:00 0.50 DHB P DECOMP Test 9-5/8" 47# casing above EZSV set @ 8,582' ELM to 3,500 psi and hold for 30 minutes - good test. 18:00 - 19:00 1.00 STWHIP P WEXIT PU Whipstock BHA to 112' - Anchor, Whipstock, Window Mill, Lower Watermelon Mill, Upper Watermelon Mill, 1 x HWDP, Float Sub, MWD. 19:00 - 20:30 1.50 STWHIP P WEXIT Upload MWD tools. Problem with signal. Trouble shoot signal. Shallow test MWD - good test. 20:30 - 22:30 2.00 STWHIP P WEXIT MU remaining Whipstock BHA to 1,045' - Bumper Sub, 9 x DC, Printed: 8/9/2004 9:37:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-03 K-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/14/2004 Rig Release: 8/4/2004 Rig Number: Spud Date: 10/2/1983 End: 8/4/2004 7/23/2004 20:30 - 22:30 2.00 STWHIP P WEXIT 22:30 - 00:00 1.50 STWHIP P WEXIT 7/24/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT 01 :00 - 02:00 1.00 STWHIP P WEXIT 02:00 - 07:00 5.00 STWHIP P WEXIT 07:00 - 08:00 1.00 STWHIP P WEXIT 08:00 - 09:30 1.50 STWHIP P WEXIT 09:30 - 17:30 8.00 STWHIP P WEXIT 17:30 - 18:30 18:30 - 19:30 1.00 STWHIP P 1.00 STWHIP P WEXIT WEXIT 19:30 - 22:00 2.50 STWHIP P WEXIT 22:00 - 23:30 1.50 STWHIP P WEXIT 23:30 - 00:00 0.50 STWHIP P WEXIT 7/25/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT 01 :00 - 04:30 3.50 STWHIP P WEXIT 04:30 - 07:00 2.50 STWHIP P WEXIT 07:00 - 08:30 1.50 STWHIP P WEXIT 08:30 - 10:30 2.00 STWHIP P WEXIT 10:30 - 11 :00 0.50 STWHIP P WEXIT 11 :00 - 12:00 1.00 STWHIP P WEXIT 12:00 - 17:00 5.00 DRILL P INT1 17:00 - 18:00 1.00 DRILL P INT1 18:00 - 19:30 1.50 DRILL P INT1 19:30 - 20:30 1.00 DRILL P INT1 20:30 - 00:00 3.50 DRILL P INT1 21 x HWDP, XO. Changeout elevators. PU DP from 1,045' to 2,448'. Fill pipe. PU DP from 2,448' to 2,997' Service Top Drive and adjust brakes. PU DP from 2,997' to 8,515', filling pipe every 3,000'. Install blower hose. Orient whipstock to 85 LHS. PU - 215K, SO - 165K. Set down 25K and set Anchor @ 8,582'. Set down 30K and shear lug. Set down 40K to ensure off of whipstock. TOW - 8,559' Displace well over to 10.2 ppg LSND fluid to mill window - 570 gpm, 2,240 psi. Mill window in 9-5/8", 47# casing from 8,559' to 8,575'. Drill new hole to 8,590'. Recovered 235# of metal. TOW - 8,559' BOW - 8,575' Pump a high vise sweep. CBU @ 12.7 bpm, 2,900 psi. Pull into casing and perform FIT to 11.5 ppg EMW with 10.2 ppg fluid and 550 psi surface pressure. Monitor well. Slug pipe and blow down the surface equipment. Remove the blower hose. POH with DP from 8,590' to top of the BHA @ 1,045'. Change out the elevators. Stand back the BHA from 1,045' to 121'. LD Bumper Sub, MWD, and Mills. Upper mill in gauge. Clear the floor Service wear ring. RU and flush the stack. Flush BOP's. Function Rams. Install Wear ring. MU BHA to 1,181 '. Orient and upload MWD. Surface test MWD - good. BHA: Smith M75 rr, 7" Sperry motor, Non-Mag FLoat Sub, MWD/LWD,3 x Non-Mag Flex Collars, 9 x Drill Collars, 6 x HWDP, Jars, 17 x HWDP, XO. PU 4" DP from 1,181' to 5,197' RIH w/4" DP from 5,197' to 8,471' filling pipe every 3,000' Slip all new drilling line. Service Top Drive and Crown. Install blower hose and orient 85 LHS. Tag undergauge hole @ 8,588' - ream to 8,590'. Drill directionally from 8,590' to 8,950' (TD). AST - 1.79, ART- 1.64, PU - 275K, SO - 135K, ROT - 185K. TO on - 17K, TO off -15K Pump a high vise sweep, CBU - 565 gpm, 2,600 psi. Monitor well - stable. POH w/ DP from 8,950' to 8,559' - no problems. POH and MAD Pass from 8,431' to 8,231' - 350 fph. RIH from 8,231' to 8,950' - no fill. Pump a high vise sweep. CBU - 500 gpm, 2,400 psi. Spot liner running pill. Monitor well - stable. POH from 8,950' to 8,559' - no problems. Slug pipe and blow down surface equipment. Drop rabbitt. POH from 8,559' to 1,181 '. Change out the elevators and LD BHA from 1,181' to 872'. Printed: 8/9/2004 9:37:42 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-03 K-03B REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 7/14/2004 Rig Release: 8/4/2004 Rig Number: Spud Date: 10/2/1983 End: 8/4/2004 7/26/2004 00:00 - 03:00 3.00 DRILL P INT1 LD BHA from 872'. Download MWD and flush tools. Clear and clean the floor. RU 7" handling equipment. 03:00 - 04:30 1.50 CASE P LNR1 PJSM. PU 7" Float Shoe joint, Float Collar joint and Insert Landing Collar joint - Bakerloc'd connections - and RIH. Fill and check floats - holding. Pick up 10 more joints of 7",26#, L-80, BTC-m liner and RIH. Change out handling equipment. PU Baker HMC Liner Hanger and ZXP Liner Top Packer assembly and RIH. Changeout handling equipment. RIH with a stand of 4" DP. Liner weight - 15K 04:30 - 05:00 0.50 CASE P LNR1 Circulate liner volume - 3 bpm, 80 psi. Clear floor. 05:00 - 08:30 3.50 CASE P LNR1 RIH with 4" DP from 674' to 8,464' 08:30 - 09:00 0.50 CASE P LNR1 Circulate DP and Liner volume - 6 bpm, 600 psi. 09:00 - 09:30 0.50 CASE P LNR1 RIH from 8,464' to 8,931'. MU cement head and break circulation @ 1 bpm. Tag bottom @ 8,950'. PU - 195K, SO- 130K. PU l' and chain the brake down with bottom of liner @ 8,949'. Liner Tieback - 8,394' ZXP Packer - 8,405' HMC Hanger - 8,411' Insert Landing Collar - 8,867' Float Collar - 8,907' Float Shoe - 8,947' 09:30 - 11 :00 1.50 CEMT P LNR1 Circulate and stage the pump up to 8 bpm - 1,550 psi. Hold PJSM. 11 :00 - 11 :30 0.50 CEMT P LNR1 Flush 5 bbls fresh water to clear lines. Shut down and pressure test Schlumberger lines to 4,000 psi. Pump 15 bbls of 11 .2 ppg Mudpush Spacer @ 5 bpm - 765 psi. Pump 32 bbls of 15.8 ppg cement @ 3.7 bpm - 700 psi. Wash lines and drop dart. Displace with the rig - 10.2 ppg mud. Bump plug with 3,800 psi @ 101 bbls displaced. CIP @ 11 :30 11 :30 - 12:00 0.50 CASE P LNR1 Hold 3,800 psi for 5 minutes to set the hanger. Bleed off pressure. Check floats - holding. Set down 50K. Release from the hanger. Pressure up to 1,000 psi and unsting. Circulate 500 stks @ 220 spm to get cement up the hole. Reduce pump rate to 3 bpm and slack off 75K and weight set the liner top packer. Rotate on top of the packer to verify. Good surface indication of packer setting. 12:00 - 14:00 2.00 CEMT P LNR1 Circulate bottoms up @ 13 bpm, 2,700 psi. Slug the pipe and blow down the surface equipment. Trace amount of cement returned to surface. 14:00 - 14:30 0.50 CEMT P LNR1 RD cement head and circulation lines. 14:30 - 17:30 3.00 CASE P LNR1 POH with 4" DP from 8,394'. LD running tool and clear the floor. 17:30 - 18:15 0.75 DRILL P PROD1 MU BHA #3 - Smith XR20, 5" motor, non-mag float sub, GR/RES, and DM HOC and set back. 18:15 -19:00 0.75 CASE P INT1 Cement test> 500 psi. RU and test 7" liner x 9-5/8" casing to 3,500 psi and hold for 30 minutes - good test. 19:00 - 21:00 2.00 DRILL P PROD1 PU Nukes, TM HOC, 3 x non-mag DC, circ sub, 3 x HWDP, DNT jars, and XO to 328'. Upload MWD and test - good. 21 :00 - 23:00 2.00 DRILL P PROD1 RIH with 4" DP from 328' to 8,393' - fill pipe every 3,000 '. Printed: 8/9/2004 9:37:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-03 K-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/14/2004 Rig Release: 8/4/2004 Rig Number: Spud Date: 10/2/1983 End: 8/4/2004 7/26/2004 21 :00 - 23:00 2.00 DRILL P PROD1 Install blower hose. 23:00 - 00:00 1.00 DRILL P PROD1 RIH from 8,393' to landing collar @ 8,867'. Wash and ream from 8,800' to 8,864'. PU - 200K, SO - 120K, ROT - 155K, TOotf - 9K, TO on - 9.5K. 7/27/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Drill out float equipment from 8,867' to the top of the float shoe @ 8,947'. 01 :00 - 02:30 1.50 DRILL P PROD1 Change over from 10.2 ppg LSND to 8.5 ppg Flo-Pro drilling fluid. 02:30 - 03:00 0.50 DRILL P PROD1 Drill out float shoe and 20' of new formation to 8,970'. Perform FIT to 10 ppg EMW. 03:00 - 11 :30 8.50 DRILL P PROD1 Drill Directionally from 8,970' to 9,362'. 185K UP 145K Dn 160 RT. ART=.18 AST=6.38 11:30 -12:00 0.50 DRILL P PROD1 Circ cuttings up into casing. POH from 9,362 to 8,927' 12:00 - 13:30 1.50 DRILL P PROD1 Open circ sub. CBU 12 BPM @ 1,100 psi. Monitor well, OK. Pump slug. Blow down surface equipment. 13:30 - 16:00 2.50 DRILL P PROD1 POH from 8,927' to 327' 16:00 - 16:30 0.50 DRILL P PROD1 PJSM. Stand back BHA. Remove sources. 16:30 - 18:00 1.50 DRILL P PROD1 Change bit and kick pad. Adjust motor to 2.0 degree bend. Load sources. RIH with BHA. Shallow test MWD. 18:00 - 18:30 0.50 DRILL P PROD1 Service rig 18:30 - 22:00 3.50 DRILL P PROD1 Continue RIH to 8,949 filling pipe every 3,000'. Install blower hose. RIH to 9,300'. Precautionary wash from 9,300' to 9,362'. 22:00 - 00:00 2.00 DRILL P PROD1 Directional drill from 9,362' to 9,486'. 185K UP 145K DN 165K RT. ART=O AST=1.3 7/28/2004 00:00 - 01 :30 1.50 DRILL P PROD1 Directional drill from 9,486' to 9,550'. Not getting doglegs required to maintain wellbore path as per geology requirements. 01 :30 - 02:00 0.50 DRILL P PROD1 Circulate open hole clean. Consult with rig and office team and geologist. Decided to POH to perform a geologic plug back. Geologic pick of the base of the Sadlerochit moved up 8'-10'. 02:00 - 02:30 0.50 DRILL N DPRB PROD1 POH from 9,550' to 8,927' 02:30 - 04:00 1.50 DRILL N DPRB PROD1 Open circulating sub and pump sweep around 04:00 - 06:30 2.50 DRILL N DPRB PROD1 POH from 8,927' to BHA 06:30 - 09:00 2.50 DRILL N DPRB PROD1 PJSM. Change out handling equipment. POH with BHA. Remove sources. Down load MWD. Flush BHA with water. Lay down BHA. 09:00 - 12:00 3.00 DRILL N DPRB PROD1 Make up mule shoe and RIH to 8,883'. Make up head pin to single in mouse hole. Continue RIH to 9,536' 12:00 - 13:00 1.00 DRILL N DPRB PROD1 Make up head pin assembly and circulating lines. RIH to 9,550'. Stage pumps to 6 BPM @ 700 psi. PJSM with all personnel for cement job. 13:00 - 14:00 1.00 CEMT N DPRB PROD1 Schlumberger pump 10 BBL water. Test lines to 4,500 psi - OK. Pump 26 BBL 17 ppg class G cement. Displace with 5 bbl water followed by 80 BBL sea water nutplug pill. Cement in place at 13:45 hrs. 14:00 - 14:30 0.50 DRILL N DPRB PROD1 POH slowly from 9,550' to 8,604' 14:30 - 15:30 1.00 DRILL N DPRB PROD1 CBU at 13 BPM, 1,000 psi. Noted trace of cement in returns. Monitor well - OK. Slug pipe and blow down surface equipment. 15:30 - 17:00 1.50 DRILL N DPRB PROD1 Cut drill line and service rig 17:00 - 19:30 2.50 DRILL N DPRB PROD1 POH. Lay down mule shoe. Clean rig floor. 19:30 - 21 :30 2.00 STKOH N DPRB PROD1 Make up BHA #5. Upload and test MWD tools. 21 :30 - 00:00 2.50 STKOH N DPRB PROD1 RIH to 8,620'. Install blower hose. Printed: 8/9/2004 9:37:42 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-03 K-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/14/2004 Rig Release: 8/4/2004 Rig Number: Spud Date: 10/2/1983 End: 8/4/2004 7/29/2004 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 04:30 04:30 - 12:00 12:00 - 13:30 13:30 - 16:00 16:00 - 17:30 17:30 - 19:00 19:00 - 21 :30 21 :30 - 22:00 22:00 - 22:30 22:30 - 00:00 7/30/2004 00:00 - 10:00 10:00 - 23:30 7/31/2004 23:30 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 02:00 02:00 - 04:30 04:30 - 06:30 06:30 - 08:30 08:30 - 11 :30 11 :30 - 12:30 12:30 - 00:00 8/1/2004 00:00 - 08:30 08:30 - 10:30 10:30 - 12:00 12:00 - 13:30 13:30 - 14:30 14:30 - 17:30 17:30 - 19:30 1.00 STKOH N 0.50 STKOH N 3.00 STKOH N 7.50 STKOH N 1.50 STKOH N 2.50 STKOH N 1.50 STKOH N 1.50 STKOH N 2.50 STKOH N 0.50 STKOH N 0.50 STKOH N 1.50 STKOH N 10.00 STKOH N 13.50 DRILL P 0.50 DRILL P 0.50 DRILL P 1.00 DRILL P 0.50 DRILL P 2.50 DRILL P 2.00 DRILL P 2.00 DRILL P 3.00 DRILL P 1.00 DRILL P 11.50 DRILL P 8.50 DRILL P 2.00 DRILL P 1.50 DRILL P 1.50 DRILL P 1.00 DRILL P 3.00 DRILL P 2.00 DRILL P DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DPRB PROD1 DPRB PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Displace well to sea water while washing down from 8,620' to 8,900'. Tagged cement at 8,900'. Drill cement from 8,900' to 8,950'. Control drill 3-4 ftlhr from 8,950' to 8,960'. Kicked off cement plug. Directional drill from 8,960' to 9,119'. 180K UP 145K DN 165K RT AST =8.25 ART =.24 MWD failed. POH from 9,119' to 8,949'. Troubleshoot MWD. Drop dart and open circ sub. CBU 13 BPM at 1,250 psi. Monitor well. Slug pipe. Blow down surface equipment and remove blower hose. POH from 8,949 to BHA PJSM. Stand back BHA. Download and flush MWD tools. Lay down MWD and bit. Pick up new bit and MWD. Upload and shallow test MWD tools. Make up remainder of BHA. RIH to shoe at 8,949'. Service rig and TDS RIH from 8,949' to 9,119'. Precautionary wash last stand. No fill. Take SPR's Directional drill from 9,119' to 9,185'. 185K UP 145K DN 165K RT. AST=1.19 ART=O Directional drill from 9,185' to 9,550' Directional drill from 9,550' to 10,310'. 190K UP 140K DN 160 RT TO ON 8-9K TO OFF 6-7K. ART =6.42 AST=10.18 Circulate Hi Vis sweep prior to bit trip. 6 BPM @ 1,550 psi. Clrc Hi Vis sweep prior to POH for bit change POH to shoe at 8,949'. Drop dart and open circ sub. Circ sweep to surface. Pump slug. PJSM. Flow check. POH from 8,949' to BHA LD bit, download MWD. Clean rig floor. PU new motor, set bend at 1.76. PU MWD, change out probe. MU new bit. Surface test MWD RIH to 10,053'. Test MWD every 3,000'. Tight spots at 9,310' and 10,053'. Wash and ream from 10,053' to 10,310'. Tight from 10,052' to 10,113'. Work through then clear. Directional drill from 10.310' to 10,975'. 190K UP 135K DN 160K RT. AST =2.1 ART =4.4 Directional drill from 10,975' to 11,585' 190K up 135K DN 165K RT TO ON 9K TO OFF 6K ART =3.21 AST =2.15 Pump sweep surface to surface. 320 gpm @ 2,450 psi POH from 11,585' to 8,900'. Max overpull 35K in high doglegs from 9,550' to 8,950' Slip and cut drill line. Inspect and service brake. Service TDS RIH from 8,900' to 11,585'. Hole in good shape. Circulate hi vis sweep around. 245 gpm at 3,500 psi. Noted pump pressure increase of approximately 1,000 psi. Suspect plugged jet.. Spot liner running pill. Monitor well. POH LD drill pipe from 11,585' to 9,087'. Continue POH Printed: 8/9/2004 9:37:42 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-03 K-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/14/2004 Rig Release: 8/4/2004 Rig Number: Spud Date: 10/2/1983 End: 8/4/2004 8/1/2004 17:30 - 19:30 2.00 DRILL P PROD1 racking pipe in derrick to 8,900'. 19:30 - 20:00 0.50 DRILL P PROD1 Drop dart, open circulating sub. Pump slug. Blow down surface equipment. 20:00 - 22:30 2.50 DRILL P PROD1 POH from 8,900' to BHA. 22:30 - 00:00 1.50 DRILL P PROD1 Change out handling equipment. LD BHA. Down load MWD. Flush MWD and motor with water. 8/2/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Break off bit. Finish LD BHA. Note: One jet in bit was plugged with a piece of rubber. 01 :00 - 01 :30 0.50 DRILL P PROD1 Clear and clean rig floor 01 :30 - 02:30 1.00 CASE P LNR2 RU liner running equipment. Hold PJSM with all personnel. 02:30 - 03:00 0.50 CASE P LNR2 PU and MU shoe-float-landing collar assembly. Test float- OK. 03:00 - 05:00 2.00 CASE P LNR2 Finish run total 67 jts 4.5", 12.6#/ft, L-80, IBT-M production liner as per program. MU torque = 3,500 fVlbs. 05:00 - 06:00 1.00 CASE P LNR2 MU 1 stand DP and circ one liner volume, 70 spm, 150 psi. RD tbg equipment. 06:00 - 08:30 2.50 CASE P LNR2 RIH on DP to 8,900'. 08:30 - 09:00 0.50 CASE P LNR2 Circ pipelliner volume at shoe. 410 psi @ 5 bpm. 09:00 - 10:00 1.00 CASE P LNR2 RIH on DP to 11,563' without problem. 10:00 - 10:30 0.50 CASE P LNR2 PU & MU cement head and a DP single. Break circulation at 2 BPM, 340 psi. 195K UP 130K DN. RIH and tag btm at 11,585'. 10:30 - 12:00 1.50 CEMT P LNR2 PJSM. Batch mix cement. Clrc and reciprocate pipe. Pump at 5 BPM, 780 psi. 12:00 - 13:30 1.50 CEMT P LNR2 Change over to Schlumberger. Pump 5 BBL water, test lines to 4,500 psi - OK. Pump 15 BBLS CW-100, 25 BBLS Mudpush 2 spacer @ 9.5 ppg, 71 BBLS latex cement @ 15.8 ppg. Flush lines, drop dart, displace with 70 BBLS perf pill and mud. Bump plug at 131 BBLS. Pressure up to 3,500 psi. Set hanger. Set down with 60K to verify hanger set. Bleed off pressure and check floats - OK. Release from hanger. Cement in place at 1330 hrs. 13:30 - 14:30 1.00 CEMT P LNR2 Pressure up to 1,000 psi. PU to verify released from hanger. When pressure dropped off, circulated 500 strokes @ 220 spm. Rotate off packer. Slowed pump to 45 spm and set 70K down to set packer. Circulate Btms up @ 220 spm, 2,700 psi. 170K UP 140K DN (NOTE: Recovered 15 BBLS cement). 14:30 - 16:00 1.50 CEMT P LNR2 Displace well to seawater. 220 spm @ 2,700 psi. Pump slug. Blow down surface equipment. 16:00 - 16:30 0.50 CEMT P LNR2 LD cement head 16:30 - 19:30 3.00 CEMT P LNR2 POH from 8,950'. LD running tool. 19:30 - 21 :00 1.50 PERFOB P OTHCMP RU Schlumberger 2-7/8" perf gun handling equipment. Hold PJSM for perf run. 21 :00 - 21 :30 0.50 PER FOB P OTHCMP Test 9-5/8 X 7 X 4-1/2 csg to 3,500 psi for 30 minutes and record on chart. Good test. 21 :30 - 23:30 2.00 PERFOB P OTHCMP MU 2-7/8" perf guns as per plan to 1,616'. MU firing head. 23:30 - 00:00 0.50 PERFOB P OTHCMP RIH by MU 2-7/8" DP from 1,616' to 1,976'. 8/3/2004 00:00 - 01 :00 1.00 PERFOB P OTHCMP RIH PU 2-7/8" PAC DP from 1,976' to 2,764'. RD power tongs. Change out elevators. 01 :00 - 04:00 3.00 PERFOB P OTHCMP RIH on 4" DP from 2,764' to 11,425'. LD DP single. Tag landing collar at 11,501'. Pick up 20.5' for space out. 04:00 - 04:30 0.50 PER FOB P OTHCMP Break circulation. Close annular preventer, pressure up to 2,500 psi - Hold for 2 minutes - Bleed off pressure - Open Printed: 8/9/2004 9:37:42 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-03 K-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/14/2004 Rig Release: 8/4/2004 Rig Number: Spud Date: 10/2/1983 End: 8/4/2004 8/3/2004 04:00 - 04:30 0.50 PERFOB P OTHCMP annular - Perforate 9,900 to 10,800' & 11,100 to 11,480' with 2 7/8" HSD guns 4 spf, 2906 power jet charge, 60/120 phasing 04:30 - 05:30 1.00 PERFOB P OTHCMP Pooh 18 stands to 9,762' - Monitor well, static loss 3 bph 05:30 - 10:30 5.00 PERFOB P OTHCMP Pooh lay down drill pipe 10:30 - 12:00 1.50 PER FOB P OTHCMP Lay down 2 7/8 PAC drill pipe 12:00 - 17:00 5.00 PERFOB P OTHCMP Lay down 2 7/8 perf guns - All shots fired - Clear rig floor 17:00 - 18:30 1.50 PERFOB P OTHCMP TI H with 18 stands of drill pipe to clear derrick, Pooh lay down 18:30 - 19:30 1.00 BOP8UF P RUNCMP Pull wear bushing, Clear rig floor 19:30 - 20:30 1.00 RUNCOMP RUNCMP Rig up Power tongs, 4 1/2" 'YT' elevators, and hand slips - Pre-job safety meeting on running completion 20:30 - 00:00 3.50 RUNCOMP RUNCMP Make up Baker 7 x 4 1/2" S-3 Packer and tail pipe assembly, Saker-Lok all connection below packer - Run 4 1/2" 12.6# L-80 IBT tubing, 4500' in hole at 2400 hrs 8/4/2004 00:00 - 03:30 3.50 RUNCOMP RUNCMP Continue running 41/2" 12.6# L-80 1ST tubing completion - Tag up inside tie back sleeve 03:30 - 04:00 0.50 RUNCOMP RUNCMP Space out with 21.62' of pup jts (9.76 + 9.74 + 2.12) - Ran total 206 jts 41/2" 12.6# L-80 IBT Class A R-3 Tubing 04:00 - 04:30 0.50 RUNCOMP RUNCMP Make up McEvoy 13 x 41/2" SSH tubing hanger with TC-II landing thread - Land tubing string - P/U wt.135K, 8/0 105K 04:30 - 08:30 4.00 RUNCOMP RUNCMP Rig up Lines, Reverse circulate 288 bbls of filtered inhibited seawater at 3 bpm 190 psi, Followed by 182 bbls of Filtered seawater to top GLM at 3234' 08:30 - 10:00 1.50 RUNCOMP RUNCMP Drop 1 7/8" ball and rod assembly, Pressure tubing to 3500 psi and set Baker S-3 packer at 8,731' - Test tubing for 30 minutes, ok - bled tubing pressure to 1500 psi, Test annulus to 3500 psi for 30 minutes, ok - Sled tubing pressure to zero, shear circ valve in top GLM, Bled all pressure to zero. 10:00 - 10:01 0.02 RUNCOMN WAIT RUNCMP 1 minute NPT for DIMS fooling 10:01 - 10:30 0.48 RUNCOMP RUNCMP Install Cameron 4" Two way check valve, Test to 1000 psi from below 10:30 - 13:00 2.50 RUNCOMP RUNCMP Blow down lines, Nipple down bop stack and set back 13:00 - 15:00 2.00 RUNCOMP RUNCMP Nipple up Cameron 135/8 x 41/8" 5k tubing head adapter, Nipple up Cameron 4 1/8" 5K Tree 15:00 - 16:00 1.00 RUNCOMP RUNCMP Test tubing hanger void area to 5000 psi for 15 minutes, ok- Test Tree to 5000 psi ok 16:00 - 16:30 0.50 RUNCOMP RUNCMP Rig up Drill Site Maintenance Lubricator, Pull Two way check valve - No pressure on well 16:30 - 19:30 3.00 RUNCOMP RUNCMP Freeze protect by pumping 155 bbls diesel down annulus at 3 bpm 1500 psi, taking returns out tubing - 'U' Tube diesel to tubing side until balance 19:30 - 20:00 0.50 RUNCOMP RUNCMP Install Cameron 4" type 'H' Spv - test from below to 1000 psi -ok 20:00 - 21 :00 1.00 RUNCOMP RUNCMP Blow down lines, Remove double annulus valve, Install companion flanges, Release rig at 2100 hrs 8/4/2004 Printed: 8/9/2004 9:37:42 AM . . 07 -Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well K-03B Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,892.92' MD 8,950.00 I MD 11,585.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Ie¡ JJflY:-JJJr; t1 Signed 1im} Ú¡¿/ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) J.Ò'-i -I f j- e Halliburton Sperry-Sun North Slope Alaska BPXA PBU_WOA K Pad K-03B Job No. AKZZ3190564, Surveyed: 1 August, 2004 Survey Report 2004 26 August, e W) Your Ref: API 500292101102 Surface Coordinates: 5975491.00 N, 671384.00 E (70020' 20.1095" N, 148036' 33.2731 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Survey Ref: svy4349 Surface Coordinates relative to Project H Reference: 975491.00 N, 171384.00 E (Grid) Surface Coordinates relative to Structure Reference: 2304.12 N, 1094.29 E (True) Kelly Bushing Elevation: 52.42ft above Mean Sea Leve/ Kelly Bushing Elevation: 52.42ft above Project V Reference Kelly Bushing Elevation: 52.42ft above Structure Reference 5pE!I'"""I'"""~-5Ui"" DAICCING SEAVIc:èS A Halliburton Company Halliburton Sperry-Sun Survey Report for PBU_ WOA K Pad - K-03B Your Ref: API 500292101102 Job No. AKZZ3190564, Surveyed: 1 August, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8892.92 14.790 62.520 8164.95 8217.37 1041 .11 N 2420.06 E 5976587.16 N 673779.63 E -2420.06 Tie On Point MWD Magnetic 8950.00 13.590 60.400 8220.29 8272.71 1047.79 N 2432.36 E 5976594.11 N 673791.77 E 2.291 -2432.36 Window Point 8975.13 8.890 40.940 8244.94 8297.36 1050.72 N 2436.20 E 5976597.13 N 673795.55 E 23.786 -2436.20 9018.53 12.310 1.670 8287.65 8340.07 1057.89 N 2438.53 E 5976604.35 N 673797.72 E 17.942 -2438.53 e 9050.99 13.080 325.100 8319.36 8371.78 1064.37 N 2436.53 E 5976610.78 N 673795.57 E 24.464 -2436.53 9082.70 10.970 310.520 8350.38 8402.80 1069.27 N 2432.18 E 5976615.58 N 673791 .11 E 11 .613 -2432.18 9111.58 12.030 288.610 8378.70 8431.12 1072.02 N 2427.24 E 5976618.22 N 673786.10 E 15.463 -2427.24 9145.22 10.350 267.820 8411.71 8464.13 1073.02 N 2420.89 E 5976619.08 N 673779.74 E 12.903 -2420.89 9175.66 10.300 262.240 8441.66 8494.08 1072.55 N 2415.47E 5976618.48 N 673774.32 E 3.288 -2415.47 9204.26 13.690 281.260 8469.64 8522.06 1072.87 N 2409.61 E 5976618.66 N 673768.46 E 18.059 -2409.61 9238.19 20.050 287.810 8502.10 8554.52 1075.43 N 2400.12 E 5976621.01 N 673758.91 E 19.535 -2400.12 9271 .16 26.340 292.820 8532.39 8584.81 1080.00 N 2387.99 E 5976625.30 N 673746.68 E 19.979 -2387.99 9299.63 31.090 293.710 8557.35 8609.77 1085.41 N 2375.43 E 5976630.42 N 673734.00 E 16.751 -2375.43 9333.04 36.170 288.600 8585.16 8637.58 1092.03 N 2358.17 E 5976636.65 N 673716.59 E 17.394 -2358.17 9364.77 42.120 289.470 8609.76 8662.18 1098.57 N 2339.25 E 5976642.75 N 673697.53 E 18.831 -2339.25 9393.25 47.570 289.160 8629.95 8682.37 1105.21 N 2320.30 E 5976648.95 N 673678.43 E 19.152 -2320.30 9422.69 53.700 288.010 8648.61 8701.03 1112.45N 2298.73 E 5976655.70 N 673656.71 E 21.039 -2298.73 9455.01 60.120 287.090 8666.25 8718.67 1120.60N 2272.93 E 5976663.26 N 673630.72 E 20.006 -2272.93 9485.29 66.120 285.570 8679.93 8732.35 1128.18 N 2247.02 E 5976670.25 N 673604.65 E 20.314 -2247.02 9518.45 73.030 284.150 8691.50 8743.92 1136.14 N 2217.00E 5976677.52 N 673574.45 E 21.221 -2217.00 9550.71 77.940 283.420 8699.58 8752.00 1143.58 N 2186.68 E 5976684.26 N 673543.97 E 15.377 -2186.68 e 9578.99 81 .270 283.200 8704.68 8757.10 1149.98 N 2159.61 E 5976690.04 N 673516.76 E 11 .800 -2159.61 9612.46 82.140 283.870 8709.51 8761.93 1157.73N 2127.41 E 5976697.05 N 673484.40 E 3.268 -2127.41 9641 .97 83.140 283.310 8713.29 8765.71 1164.61 N 2098.97 E 5976703.28 N 673455.80 E 3.876 -2098.97 9670.50 87.720 280.580 8715.56 8767.98 1170.49 N 2071.15 E 5976708.52 N 673427.86 E 18.672 -2071.15 9704.43 87.280 276.220 8717.05 8769.47 1175.44 N 2037.63 E 5976712.71 N 673394.23 E 12.903 -2037.63 9736.86 86.480 275.340 8718.81 8771.23 1178.70N 2005.41 E 5976715.23 N 673361.95 E 3.664 -2005.41 9765.39 89.070 276.180 8719.92 8772.34 1181.56 N 1977.05 E 5976717.44 N 673333.53 E 9.543 -1977.05 9798.78 88.270 277.050 8720.69 8773.11 1185.41 N 1943.89 E 5976720.53 N 673300.29 E 3.539 -1943.89 9829.80 87.530 277.700 8721.83 8774.25 1189.39 N 1913.15 E 5976723.80 N 673269.46 E 3.174 -1913.15 26 August, 2004 - 10:31 Page 2 of 4 Dri/lQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_ WOA K Pad - K-03B Your Ref: AP/500292101102 Job No. AKZZ3190564, Surveyed: 1 August, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9858.05 86.910 277. 770 8723.20 8775.62 1193.18 N 1885.19 E 5976726.96 N 673241.42 E 2.209 -1885.19 9907.74 89.260 276.330 8724.86 8777.28 1199.28 N 1835.91 E 5976731.93 N 673192.02 E 5.546 -1835.91 9950.74 89.200 276.780 8725.44 8777.86 1204.19 N 1793.19 E 5976735.86 N 673149.20 E 1.056 -1793.19 10000.33 88.770 277.130 8726.32 8778.74 1210.19 N 1743.97 E 5976740.74 N 673099.86 E 1.118 -1743.97 10044.34 88.460 277.810 8727.38 8779.80 1215.91 N 1700.35 E 5976745.46 N 673056.11 E 1.698 -1700.35 e 10092.12 88.090 277 .440 8728.82 8781.24 1222.25 N 1653.01 E 5976750.71 N 673008.65 E 1.095 -1653.01 10136.20 89.200 274.440 8729.86 8782.28 1226.81 N 1609.19 E 5976754.27 N 672964.73 E 7.255 -1609.19 10184.46 89.440 274.820 8730.43 8782.85 1230.70 N 1561.09 E 5976757.06 N 672916.55 E 0.931 -1561.09 10229.29 89.070 275.140 8731.02 8783.44 1234.59 N 1516.43 E 5976759.93 N 672871.82 E 1.091 -1516.43 10323.60 86.850 273.710 8734.37 8786.79 1241.87 N 1422.47 E 5976765.05 N 672777.72 E 2.799 -1422.47 10416.35 86.110 272.080 8740.07 8792.49 1246.54 N 1330.02 E 5976767.62 N 672685.18 E 1.927 -1330.02 10509.83 86.420 272.260 8746.16 8798.58 1250.07 N 1236.81 E 5976769.02 N 672591.91 E 0.383 -1236.81 10601.79 85.680 271.740 8752.49 8804.91 1253.28 N 1145.12 E 5976770.12 N 672500.18 E 0.983 -1145.12 10695.67 86.170 271 .420 8759.16 8811.58 1255.86 N 1051.51 E 5976770.56 N 672406.53 E 0.623 -1051.51 10787.66 89.690 272.210 8762.49 8814.91 1258.77 N 959.65 E 5976771 .38 N 672314.62 E 3.922 -959.65 10822.58 90.060 272.420 8762.56 8814.98 1260.18 N 924.75 E 5976771.99 N 672279.71 E 1.218 -924.75 10879.20 90.060 271.030 8762.50 8814.92 1261.88 N 868.16 E 5976772.40 N 672223.09 E 2.455 -868.16 10928.49 89.570 272.760 8762.66 8815.08 1263.51 N 818.90 E 5976772.90 N 672173.81 E 3.648 -818.90 10973.73 88.830 272.600 8763.29 8815.71 1265.63 N 773.71 E 5976773.98 N 672128.58 E 1.674 -773.71 11025.46 88.330 273.130 8764.58 8817.00 1268.21 N 722.07 E 5976775.39 N 672076.89 E 1 .408 -722.07 11066.80 88.150 276.910 8765.85 8818.27 1271.83 N 680.91 E 5976778.06 N 672035.66 E 9.150 -680.91 e 11119.04 87.960 277.720 8767.62 8820.04 1278.48 N 629.13 E 5976783.52 N 671983.74 E 1.592 -629.13 11162.66 87.720 277.230 8769.26 8821.68 1284.15 N 585.91 E 5976788.20 N 671940.40 E 1.250 -585.91 11210.08 88.210 278.110 8770.95 8823.37 1290.47 N 538.94 E 5976793.45 N 671893.31 E 2.123 -538.94 11255.15 88.400 278.590 8772.28 8824.70 1297.01 N 494.37 E 5976798.98 N 671848.60 E 1.145 -494.37 11305.09 90.060 278.130 8772.95 8825.37 1304.27 N 444.97 E 5976805.10 N 671799.04 E 3.449 -444.97 11347.73 90.620 278.600 8772.70 8825.12 1310.48 N 402.78 E 5976810.34 N 671756.72 E 1.715 -402.78 11441.09 90.120 278.520 8772.10 8824.52 1324.37 N 310.46E 5976822.12 N 671664.11 E 0.542 -310.46 11519.79 90.000 278.210 8772.01 8824.43 1335.82 N 232.60 E 5976831.79 N 671586.01 E 0.422 -232.60 11585.00 90.000 278.210 8772.01 8824.43 1345.13 N 168.06 E 5976839.62 N 671521.27 E 0.000 -168.06 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 270.000° (True). 26 August, 2004 - 10:31 Page 3 of 4 DrillQuest 3.03.06.006 North Slope Alaska Halliburton Sperry-Sun Survey Report for PBU_ WOA K Pad - K-03B Your Ref: API 500292101102 Job No. AKZZ3190564, Surveyed: 1 August, 2004 BPXA Based upon Minimum Curvature type calculations, at a Measured Depth of 11585.00ft., The Bottom Hole Displacement is 1355.59ft., in the Direction of 7.122° (True). Comments Measured Depth (ft) 8892.92 8950.00 11585.00 8217.37 8272.71 8824.43 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment It 1041.11 N 1047.79 N 1345.13 N Tie On Point Window Point Projected Survey 2420.06 E 2432.36 E 168.06 E Survey tool program for K-03R Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 8491.35 8892.92 0.00 7836.19 8217.37 26 August, 2004 - 10:31 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 8491.35 8892.92 11585.00 BP High Accuracy Gyro (K-03) MWD+IIFR+MS (K-03BPB1) MWD Magnetic (K-03B) 7836.19 8217.37 8824.43 - Page 4 of 4 Dri/lQuest 3.03.06.006 . . 07 -Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well K-038 P81 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,491.35' MD 8,559.00 I MD 9,550.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 /l / Date (Y1r:t:-~q S¡gned!:4wJ.. ~tLJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) v<. (jv{ ~( I )- It e Survey Ref: svy4348 Halliburton Sperry-Sun North Slope Alaska BPXA PBU_ WOA K Pad K-03BPB1 Job No. AKZZ3190564, Surveyed: 28 July, 2004 Survey Report 26 August, 2004 Your Ref: API 500292101172 Surface Coordinates: 5975491.00 N, 671384.00 E (70020' 20.1095" N, 148036' 33.2731" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 975491.00 N, 171384.00 E (Grid) Surface Coordinates relative to Structure Reference: 2304.12 N, 1094.29 E (True) Kelly Bushing Elevation: 52.42ft above Mean Sea Level Kelly Bushing Elevation: 52.42ft above Project V Reference Kelly Bushing Elevation: 52.42ft above Structure Reference s¡ ·.....1 II"""Y-SUI'1 DRt.L..L.fNG SERVices A Halliburton Company Halliburton Sperry-Sun Survey Report for PBU_ WOA K Pad - K-03BPB1 Your Ref: API 500292101172 Job No. AKZZ3190564, Surveyed: 28 July, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8491.35 24.070 70.500 7783.77 7836.19 991.21 N 2307.57 E 5976534.69 N 673668.31 E -2307.57 Tie On Point MWD+IIFR+MS 8559.00 23.920 70.630 7845.58 7898.00 1000.36 N 2333.51 E 5976544.44 N 673694.03 E 0.235 -2333.51 Window Point 8597.55 22.170 69.400 7881.05 7933.47 1005.51 N 2347.69 E 5976549.91 N 673708.10 E 4.708 -2347.69 8633.51 18.910 68.090 7914.72 7967.14 1010.08 N 2359.45 E 5976554.74 N 673719.75 E 9.155 -2359.45 e 8664.54 16.590 66.800 7944.27 7996.69 1013.70N 2368.19 E 5976558.56 N 673728.40 E 7.583 -2368.19 8693.05 16.040 65.460 7971.63 8024.05 1016.94 N 2375.51 E 5976561.97 N 673735.65 E 2.338 -2375.51 8786.21 14.290 59.550 8061.55 8113.97 1028.11 N 2397.14 E 5976573.63 N 673757.01 E 2.504 -2397.14 8879.73 14.250 60.950 8152.18 8204.60 1039.55 N 2417.15 E 5976585.53 N 673776.76 E 0.371 -2417.15 8892.92 14.790 62.520 8164.95 8217.37 1041.11 N 2420.06 E 5976587.16 N 673779.63 E 5.066 -2420.06 8982.60 12.920 59.010 8252.02 8304.44 1051.56 N 2438.81 E 5976598.03 N 673798.14 E 2.285 -2438.81 9012.89 11.080 41 .120 8281.66 8334.08 1055.50 N 2443.63 E 5976602.08 N 673802.87 E 13.626 -2443.63 9044.12 12.020 19.360 8312.27 8364.69 1060.83 N 2446.69 E 5976607.48 N 673805.80 E 14.182 -2446.69 9077.64 13.550 357.820 8344.98 8397.40 1068.05 N 2447.69 E 5976614.72 N 673806.64 E 14.835 -2447.69 9108.72 13.990 337.840 8375.18 8427.60 1075.17 N 2446.14 E 5976621.80 N 673804.92 E 15.292 -2446.14 9136.84 12.480 322.770 8402.56 8454.98 1080.74 N 2443.02 E 5976627.30 N 673801.68 E 13.345 -2443.02 9170.57 14.300 304.110 8435.39 8487.81 1085.98 N 2437.36 E 5976632.41 N 673795.90 E 13.825 -2437.36 9201.42 18.430 303.320 8464.98 8517.40 1090.80 N 2430.13 E 5976637.06 N 673788.56 E 13.406 -2430.13 9229.25 22.230 302.150 8491.07 8543.49 1096.02 N 2421.99 E 5976642.09 N 673780.31 E 13.732 -2421.99 9263.67 26.710 302.620 8522.39 8574.81 1103.66 N 2409.96 E 5976649.45 N 673768.10 E 13.028 -2409.96 9294.10 30.930 301.910 8549.05 8601.47 1111.48N 2397.55 E 5976656.99 N 673755.52 E 13.913 -2397.55 9323.53 34.020 300.730 8573.87 8626.29 1119.69N 2384.05 E 5976664.89 N 673741.84 E 10.717 -2384.05 e 9356.52 38.310 297.770 8600.50 8652.92 1129.17 N 2367.06 E 5976673.98 N 673724.63 E 14.037 -2367.06 9387.75 42.140 291.620 8624.35 8676.77 1137.55N 2348.74 E 5976681.94 N 673706.13 E 17.656 -2348.74 9417.89 46.030 287.630 8646.00 8698.42 1144.57 N 2328.99 E 5976688.50 N 673686.22 E 15.851 -2328.99 9449.69 49.260 283.570 8667.43 8719.85 1150.86 N 2306.37 E 5976694.28 N 673663.46 E 13.860 -2306.37 9481.86 54.370 282.000 8687.31 8739.73 1156.44 N 2281.71 E 5976699.29 N 673638.69 E 16.340 -2281.71 9550.00 54.370 282.000 8727.01 8779.43 1167.96 N 2227.54 E 5976709.57 N 673584.26 E 0.000 -2227.54 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 270.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9550.00ft., 26 August, 2004 - 10:30 Page 2 of 3 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_ WOA K Pad - K-03BPB1 Your Ref: API 500292101172 Job No. AKZZ3190564, Surveyed: 28 July, 2004 BPXA North Slope Alaska The Bottom Hole Displacement is 2515.17fl., in the Direction of 62.331° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment e 8491.35 8559.00 9550.00 7836.19 7898.00 8779.43 991.21 N 1000.36 N 1167.96 N 2307.57 E 2333.51 E 2227.54 E Tie On Point Window Point Projected Survey Survey tool program for K-03RPB1 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8491.35 0.00 7836.19 8491.35 9550.00 7836.19 BP High Accuracy Gyro (K-03) 8779.43 MWD+IIFR+MS (K-03BPB1) e 26 August, 2004 - 10:30 Page 3 of 3 Dril/Quest 3.03.06.006 . . 07 -Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well K-03B MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,892.92' MD 8,950.00' MD 11,585.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 7 / II Date 1<1 ¥lvÖ'f't Signed 1WwIVJ! OiL¡ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 9/0 V( - I t j ~ e Halliburton Sperry-Sun North Slope Alaska BPXA PBU_ WOA K Pad K-03B MWD 2004 Job No. AKMW3190564, Surveyed: 8 August, Survey Report 2004 26 August, e W) Your Ref: API 500292101102 Surface Coordinates: 5975491.00 N, 671384.00 E (70020' 20.1095" N, 148036' 33.2731" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Survey Ref: svy4351 Surface Coordinates relative to Project H Reference: 975491.00 N, 171384.00 E (Grid) Surface Coordinates relative to Structure Reference: 2304.12 N, 1094.29 E (True) Kelly Bushing Elevation: 52.42N above Mean Sea Level Kelly Bushing Elevation: 52.42N above Project V Reference Kelly Bushing Elevation: 52.42ft above Structure Reference spe....,....,y-sul"l b^AILLING seAVlces A HalliÞurton Company Halliburton Sperry-Sun Survey Report for PBU_ WOA K Pad - K-03B MWD Your Ref: AP/500292101102 Job No. AKMW3190564, Surveyed: 8 August, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8892.92 14.790 62.330 8164.97 8217.39 1045.47 N 2417.27 E 5976591.45 N 673776.74 E -2417.27 Tie On Point 8950.00 13.590 60.400 8220.31 8272.73 1052.17 N 2429.55 E 5976598.42 N 673788.87 E 2.260 -2429.55 Window Point 8975.13 8.890 44.530 8244.96 8297.38 1055.01 N 2433.48 E 5976601 .36 N 673792.73 E 22.223 -2433.48 9018.53 12.310 1.780 8287.67 8340.09 1062.04 N 2435.98 E 5976608.44 N 673795.07 E 19.179 -2435.98 9050.99 13.080 325.400 8319.39 8371.81 1068.53 N 2434.00 E 5976614.89 N 673792.94 E 24.342 -2434.00 e 9082.70 10.970 311.010 8350.41 8402.83 1073.47 N 2429.68 E 5976619.72 N 673788.51 E 11.513 -2429.68 9111.58 12.030 289.040 8378.72 8431.14 1076.25 N 2424.76 E 5976622.39 N 673783.53 E 15.502 -2424.76 9145.22 10.350 268.370 8411.74 8464.16 1077.31 N 2418.43 E 5976623.31 N 673777. 17 E 12.840 -2418.43 9175.66 10.300 262.800 8441.68 8494.10 1076.89 N 2412.99 E 5976622.76 N 673771.75 E 3.282 -2412.99 9204.26 13.690 281.810 8469.67 8522.09 1077.26 N 2407.14 E 5976623.00 N 673765.89 E 18.053 -2407.14 9238.19 20.050 288.180 8502.12 8554.54 1079.90 N 2397.67 E 5976625.42 N 673756.36 E 19.493 -2397.67 9271.16 26.340 292.780 8532.41 8584.83 1084.50 N 2385.55 E 5976629.75 N 673744.13 E 19.840 -2385.55 9299.63 31.090 294.070 8557.38 8609.80 1089.95 N 2373.00 E 5976634.91 N 673731.47 E 16.825 -2373.00 9333.04 36.170 289.190 8585.19 8637.61 1096.72 N 2355.80 E 5976641.28 N 673714.12 E 17.213 -2355.80 9364.77 42.120 290.200 8609.79 8662.21 1103.47 N 2336.96 E 5976647.60 N 673695.12 E 18.859 -2336.96 9393.25 47.570 289.540 8629.97 8682.39 1110.29 N 2318.07 E 5976653.99 N 673676.09 E 19.206 -2318.07 9422.69 53.700 288.430 8648.64 8701.06 1117.68N 2296.56 E 5976660.88 N 673654.41 E 21.024 -2296.56 9455.01 60.120 286.950 8666.27 8718.69 1125.90 N 2270.77 E 5976668.50 N 673628.44 E 20.230 -2270.77 9485.29 66.120 286.330 8679.96 8732.38 1133.62N 2244.90 E 5976675.64 N 673602.41 E 19.899 -2244.90 9518.45 73.030 285.210 8691.52 8743.94 1142.06 N 2215.02 E 5976683.39 N 673572.33 E 21.077 -2215.02 9550.71 77.940 283.240 8699.61 8752.03 1149.72N 2184.75 E 5976690.36 N 673541.90 E 16.327 -2184.75 e 9578.99 81.270 283.440 8704.71 8757.13 1156.14 N 2157.69 E 5976696.15 N 673514.70 E 11.796 -2157.69 9612.46 82.140 281.700 8709.54 8761.96 1163.35 N 2125.37 E 5976702.62 N 673482.22 E 5.764 -2125.37 9641.97 83.140 282.550 8713.32 8765.74 1169.49 N 2096.75 E 5976708.11 N 673453.47 E 4.432 -2096.75 9670.50 87.720 279.300 8715.59 8768.01 1174.88N 2068.84 E 5976712.86 N 673425.45 E 19.662 -2068.84 9704.43 87.280 276.970 8717.07 8769.49 1179.67 N 2035.29 E 5976716.89 N 673391.79 E 6.982 -2035.29 9736.86 86.480 276.110 8718.84 8771.26 1183.36 N 2003.12 E 5976719.84 N 673359.54 E 3.619 -2003.12 9765.39 89.070 275.850 8719.94 8772.36 1186.33 N 1974.76 E 5976722.16 N 673331.13 E 9.124 -1974.76 9798.78 88.270 276.600 8720.72 8773.14 1189.95N 1941.58 E 5976725.02 N 673297.88 E 3.284 -1941.58 9829.80 87.530 277.600 8721.86 8774.28 1193.78 N 1910.82 E 5976728.15 N 673267.03 E 4.009 -1910.82 9858.05 86.910 277.850 8723.23 8775.65 1197.58 N 1882.86 E 5976731.30 N 673238.99 E 2.366 -1882.86 9907.74 89.260 276.410 8724.89 8777.31 1203.74 N 1833.59 E 5976736.33 N 673189.59 E 5.546 -1833.59 9950.74 89.200 313.270 8725.49 8777.91 1221.49 N 1795.24 E 5976753.21 N 673150.85 E 85.713 -1795.24 10000.33 88.770 278.860 8726.39 8778.81 1242.95 N 1751.37E 5976773.66 N 673106.50 E 69.383 -1751.37 10044.34 88.460 277.830 8727.46 8779.88 1249.34 N 1707.83 E 5976779.05 N 673062.83 E 2.443 -1707.83 26 August, 2004 - 10:33 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_ WOA K Pad - K-03B MWD Your Ref: API 500292101102 Job No. AKMW3190564, Surveyed: 8 August, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10092.12 88.090 277.280 8728.89 8781.31 1255.62 N 1660.49 E 5976784.24 N 673015.36 E 1.387 -1660.49 10136.20 89.200 314.990 8729.97 8782.39 1274.68 N 1621.64 E 5976802.41 N 672976.08 E 85.560 -1621.64 10184.46 89.440 274.780 8730.57 8782.99 1294.57 N 1578.76 E 5976821.32 N 672932.76 E 83.315 -1578.76 10229.29 89.070 315.750 8731.18 8783.60 1313.30 N 1539.08 E 5976839.13 N 672892.66 E 91.385 -1539.08 10323.60 86.850 272.950 8734.70 8787.12 1351.28N 1455.22 E 5976875.19 N 672807.95 E 45.410 -1455.22 e 10416.35 86.110 272.500 8740.40 8792.82 1355.68 N 1362.75 E 5976877.48 N 672715.40 E 0.933 -1362.75 10509.83 86.420 272.770 8746.49 8798.91 1359.97 N 1269.56 E 5976879.63 N 672622.15 E 0.439 -1269.56 10601.79 85.680 273.620 8752.82 8805.24 1365.08 N 1177.97 E 5976882.65 N 672530.46 E 1.224 -1177.97 10695.67 86.170 273.000 8759.49 8811.91 1370.49 N 1084.48 E 5976885.92 N 672436.87 E 0.840 -1084.48 10787.66 89.690 272.310 8762.82 8815.24 1374.75 N 992.66 E 5976888.08 N 672344.98 E 3.899 -992.66 10822.58 90.060 272.610 8762.89 8815.31 1376.25 N 957.78 E 5976888.78 N 672310.07 E 1.364 -957.78 10879.20 90.060 271.240 8762.83 8815.25 1378.15 N 901.19 E 5976889.39 N 672253.45 E 2.420 -901.19 10928.49 89.570 272.700 8762.99 8815.41 1379.84 N 851.93 E 5976889.95 N 672204.17 E 3.124 -851.93 10973.73 88.830 272.570 8763.62 8816.04 1381.92 N 806.74 E 5976891.00 N 672158.95 E 1.661 -806.74 11025.46 88.330 272.600 8764.91 8817.33 1384.25 N 755.08 E 5976892.15 N 672107.25 E 0.968 -755.08 11066.80 88.150 275.780 8766.18 8818.60 1387.27 N 713.88 E 5976894.23 N 672065.98 E 7.701 -713.88 11119.04 87.960 278.040 8767.95 8820.37 1393.55 N 662.05 E 5976899.32 N 672014.03 E 4.339 -662.05 11162.66 87.720 277 .350 8769.59 8822.01 1399.39 N 618.85 E 5976904.17 N 671970.71 E 1.674 -618.85 11210.08 88.210 278.250 8771.28 8823.70 1405.82 N 571.90 E 5976909.53 N 671923.62 E 2.160 -571.90 11255.15 88.400 276.510 8772.61 8825.03 1411.61 N 527.23 E 5976914.29 N 671878.83 E 3.882 -527.23 11305.09 90.060 277.100 8773.28 8825.70 1417.52 N 477.65 E 5976919.07 N 671829.12 E 3.528 -477.65 e 11347.73 90.620 277.870 8773.03 8825.45 1423.08 N 435.37 E 5976923.66 N 671786.73 E 2.233 -435.37 11441.09 90.120 278.310 8772.43 8824.85 1436.22 N 342.94 E 5976934.68 N 671694.03 E 0.713 -342.94 11519.79 90.000 277.400 8772.34 8824.76 1446.97 N 264.98 E 5976943.65 N 671615.84 E 1.166 -264.98 11585.00 90.000 277.400 8772.34 8824.76 1455.37 N 200.31 E 5976950.57 N 671551.00 E 0.000 -200.31 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 270.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11585.00ft., The Bottom Hole Displacement is 1469.09ft., in the Direction of 7.837° (True). 26 August, 2004 - 10:33 Page 3 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_ WOA K Pad - K-03B MWD Your Ref: API 500292101102 Job No. AKMW3190564, Surveyed: 8 August, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8892.92 8950.00 11585.00 8217.39 8272.73 8824.76 1045.47 N 1052.17 N 1455.37 N 2417.27 E 2429.55 E 200.31 E Tie On Point Window Point Projected Survey e Survey tool program for K-038 MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8491.35 0.00 8491.35 7836.19 11585.00 7836.19 BP High Accuracy Gyro (K-03) 8824.76 MWD Magnetic (K-03BPB1 MWD) e 26 August, 2004 - 10:33 Page 4 of 4 DrillQuest 3.03.06.006 . . 07 -Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well K-038 P81 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,491.35' MD 8,559.00' MD 9,550.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 1/ A DateN 1,i-J{)ù c1 Signed Iw~(l (JJLJ Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager AUachment(s) Ä5L{ -{ { ~- e Halliburton Sperry-Sun North Slope Alaska BPXA PBU_ WOA K Pad K-03BPB1 MWD Job No, AKMW3190564, Surveyed: 28 July, 2004 Survey Report e W) 2004 Your Ref: API 500292101172 Surface Coordinates: 5975491.00 N, 671384.00 E (70020' 20.1095" N, 148036' 33.2731 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 26 August, Surface Coordinates relative to Project H Reference: 975491.00 N, 171384,00 E (Grid) Surface Coordinates relative to Structure Reference: 2304,12 N, 1094,29 E (True) Kelly Bushing Elevation: 52.42ft above Mean Sea Level Kelly Bushing Elevation: 52.42ft above Project V Reference Kelly Bushing Elevation: 52.42ft above Structure Reference Survey Ref: svy4350 spe.............v-sur-, r,:) ~IL.,L.,JI\I (; !!is AV Ice S A Halliburton Company Halliburton Sperry-Sun Survey Report for PBU_ WOA K Pad - K-03BPB1 MWD Your Ref: API 500292101172 Job No. AKMW3190564, Surveyed: 28 July, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8491.35 24.070 70.500 7783.77 7836.19 991.21 N 2307.57 E 5976534.69 N 673668.31 E -2307.57 Tie On Point MWD Magnetic 8559.00 23.920 70.630 7845.58 7898.00 1000.36 N 2333.51 E 5976544.44 N 673694.03 E 0.235 -2333.51 Window Point 8597.55 22.170 69.400 7881.05 7933.47 1005.51 N 2347.69 E 5976549.91 N 673708.10 E 4.708 -2347.69 8633.51 18.910 68.090 7914.72 7967.14 1010.08N 2359.45 E 5976554.74 N 673719.75 E 9.155 -2359.45 e 8664.54 16.590 70.510 7944.27 7996.69 1013.43 N 2368.29 E 5976558.30 N 673728.51 E 7.844 -2368.29 8693.05 16.040 51.050 7971.65 8024.07 1017.27 N 2375.20 E 5976562.29 N 673735.33 E 19.184 -2375.20 8786.21 14.290 56.630 8061.57 8113.99 1031.68N 2394.81 E 5976577.15 N 673754.61 E 2.444 -2394.81 8879.73 14.250 59.550 8152.21 8204.63 1043.87 N 2414.38 E 5976589.78 N 673773.89 E 0.771 -2414.38 8892.92 14.790 62.330 8164.97 8217.39 1045.47 N 2417.27 E 5976591.45 N 673776.74 E 6.684 -2417.27 8982.60 12.920 58.360 8252.04 8304.46 1056.05 N 2435.94 E 5976602.45 N 673795.17 E 2.338 -2435.94 9012.89 11.080 40.890 8281.68 8334.10 1060.03 N 2440.73 E 5976606.54 N 673799.86 E 13.372 -2440.73 9044.12 12.020 20.790 8312.29 8364.71 1065.34 N 2443.85 E 5976611.92 N 673802.86 E 13.162 -2443.85 9077.64 13.550 356.740 8345.00 8397.42 1072.53 N 2444.87 E 5976619.13 N 673803.71 E 16.387 -2444.87 9108.72 13.990 337.540 8375.20 8427.62 1079.64 N 2443.22 E 5976626.20 N 673801.91 E 14.706 -2443.22 9136.84 12.480 322.700 8402.58 8455.00 1085.20 N 2440.08 E 5976631.69 N 673798.64 E 13.175 -2440.08 9170.57 14.300 302.960 8435.41 8487.83 1090.37 N 2434.38 E 5976636.72 N 673792.82 E 14.500 -2434.38 9201.42 18.430 302.030 8465.01 8517.43 1095.03 N 2427.04 E 5976641.21 N 673785.38 E 13.414 -2427.04 9229.25 22.230 301.130 8491.10 8543.52 1100.08 N 2418.80 E 5976646.08 N 673777.03 E 13.700 -2418.80 9263.67 26.710 301.070 8522.42 8574.84 1107.44N 2406.60 E 5976653.16 N 673764.66 E 13.016 -2406.60 9294.10 30.930 300.490 8549.07 8601.49 1114.95 N 2394.00 E 5976660.37 N 673751.89 E 13.898 -2394.00 9323.53 34.020 301.960 8573.90 8626.32 1123.14 N 2380.49 E 5976668.26 N 673738.20 E 10.836 -2380.49 e 9356.52 38.310 298.610 8600.53 8652.95 1132.93 N 2363.67 E 5976677.66 N 673721.16 E 14.314 -2363.67 9387.75 42.140 292.360 8624.38 8676.80 1141.56 N 2345.47 E 5976685.87 N 673702.77 E 17.805 -2345.47 9417.89 46.030 288.680 8646.03 8698.45 1148.88 N 2325.84 E 5976692.74 N 673682.97 E 15.447 -2325.84 9449.69 49.260 284.310 8667.45 8719.87 1155.53 N 2303.31 E 5976698.87 N 673660.30 E 14.359 -2303.31 9481.86 54.370 281.730 8687.34 8739.76 1161.20N 2278.68 E 5976703.98 N 673635.54 E 17.087 -2278.68 9550.00 54.370 281.730 8727.03 8779.45 1172.46 N 2224.45 E 5976714.00 N 673581.07 E 0.000 -2224.45 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 270.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9550.00ft., 26 August, 2004 - 10:32 Page 2 of 3 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_ WOA K Pad - K-03BPB1 MWD Your Ref: API 500292101172 Job No. AKMW3190564, Surveyed: 28 July, 2004 BPXA North Slope Alaska The Bottom Hole Displacement is 2514.53ft., in the Direction of 62.207" (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment e 8491.35 8559.00 9550.00 7836.19 7898.00 8779.45 991.21 N 1000.36 N 1172.46 N 2307.57 E 2333.51 E 2224.45 E Tie On Point Window Point Projected Survey Survey tool program for K-D3BPR1 MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8491.35 0.00 7836.19 8491.35 9550.00 7836.19 BP High Accuracy Gyro (K-03) 8779.45 MWD Magnetic (K-03BPB1 MWD) e 26 August, 2004 - 10:32 Page 3 of 3 DrillQuest 3.03.06.006 TREE = 4-1/8" CArvERON WB...U-EAD = MCEVOY ACrUÄToR;- AXELSON' KÊCEL.:EV = 61:0'1' B F. ElEir; --, "24:57', KOP';--- . 'ào5Õ' ,~~~~,~Ie ':_._~L~ 134_!.' Datum MD = 9803' -~..~~~~.~ ~~ DatumTVD = 8800'SS e K-03B 13-3I8"CSG, 72#,L-80, ID=12,347" H 2692' ~ ~ Minimum ID = 3.725" @ 8776' I 4-1/2" OTIS XN NIPPLE L - ST MD 4 3235 3 5206 2 6764 1 8271 14-112" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" ~NOTæ 2092' H4-1/2"I-ESXNIP,D=3.813" I TVD GAS LIFT MANDRELS DBI TYPE V LV LA TCH MM3-M OOME RK MM3- M S/O RK MM3- M DMY RK MM3-M DMY RK PORT QI\ TE 16 08119104 20 08119104 K z---1 8405' H 9-5/8" X 7" BAKER LNR TOP PKR 12-7~ L"', 6.16#, L-BO, .00579 "", ID "2.441" H 11287 ~ PERFORA nON SU'v1M1\ RY RB= LOG: SÆRRY GRiMWD ON 02/99 ANGLE A T TOP PERF: 89 @ 9900' Note: Refer to A"oduction œ for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 9900 - 10800 0 08/01/04 4 11100 - 11480 0 08/01/04 17" LNR, 26#, L-80, .383 bpf, D = 6.276" H 8950' 14-1/2"LNR, 6.16#, L-80, .00579bpf, ID=2.441" H 11585' I DATE 1983 02/22/99 08/05/04 08/19/04 REV BY COrvMENTS ORIGINAL COM PLETION SIDETRACK COMPLETION (A) /TLP SIDETRACK COMPLETION (B) RMH'TLP GL V C/O QI\ TE REV BY COMMENTS 9-5/8" MlLOUTWINDOW 8559' :8 ---1 8711' H4-1/2" HES X NIP, ID= 3.813" rl 8731' ~7"X 4-1/2" BAKER I S-3 A<R, ID = 3.875" --1 8755' H4-1/2" HES X NIP, ID = 3.813" I --I 8776' H4-1/2" HE'S XN NIP, ID = 3.725" ~ 8789' H4-1/2" WLEG 8794' H4-1/2" HGR LNRTOP PKR :I .. ~ t m ~ PRLDI-DEBAY U'JIT WELL: K-03B PERMff I\b: 1990030 AA I\b: 50-029-21011-02 SEC4, T11N, R14E, 1728' Ft\I... & 1121'FEL BP Exploration (Alaska) · 204 --1I~ . Winton, As per our discussion this morning, Nabors 2es is currently on K-03B. Yesterday, while attempting to build angle and land horizontal in Ivishak Zone 1, we experienced trouble with our directional assembly and were unable to build angle at our required doglegs. The plan was to build at an average 15/100'. The BHA was only delivering an average of 12-13/100'. This BHA was pulled and the motor bend was increased. We now needed 18/100' to 'catch up' and land at the geologic target. This second BHA only delivered 16/100', again getting us further behind the plan. The decision was made to plug and abandon the first 6-1/8" hole and start over from the 7" casing shoe. Open-ended drillpipe was run to TD and the production interval was filled with 26 bbls of 17.0 ppg Glass 'G' cement. Currently we are in the hole with our 6-1/8" directional BHA cleaning out cement in the 7" liner. The excess cement volume left -50' of cement in the 7" liner. The plan is to redrill the 6-1/8" section to the same geologic target, and drill the Zone 1 horizontal as originally planned. Please call with any questions. Regards, Rob Tirpack Op Drilling Eng BPXA 564-4166 office 440-8633 cell tirpacrb~bp.com . . Phil, Per 20 AAC 25.035 (h) (1), alternate BOPE is hereby approved for wells C-17B (PTD 204-094) and K-03B (PTD 204-115), as described below. All other permit stipulations apply. Winton Aubert AOGCC 793-1231 Smith, Phil G (ASRC) wrote: Winton, As discussed yesterday, I neglected to request in the permit application dispensation from changing rams to 7" while running the drilling liner on C-17B. We would like to keep the drillpipe rams in place while running the liner as it is a safer, more efficient method. Please confirm your approval with a reply. Likewise the K-03B permit has been approved without the ram dispensation. K-03B and C-17B are quite similar except that K-03B has just a 550' liner planned (about half that of C-17B). We also request the same dispensation for K-03B. Apologies for the inconvenience, Phil Smi th Operations Drilling Engineer 564-4897 . [ill fÆ ~c . l ¡ , I ¡ I í ¡ I i ¡ ¡ FRANK H. MURKOWSKI, GOVERNOR AI#ASHA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay K-03B BP Exploration (Alaska) Inc. Permit No: 2~lt5 Surface Location: 1728' SNL, 1121' EWL, SEC. 04, TIIN, RI4E, UM Bottomhole Location: 370' SNL, 1296' EWL, SEC. 04, TIIN, RI4E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you :&om obtaining additional permits or approvals required by law :&om other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 7 (pager). élf J K BY ORDER OF THE COMMISSION DA TED thi~ day of June, 2004 cc: Department ofFish & Game, Habitat Section wlo encI. Department of Environmental Conservation wlo encI. \¡JGÆ- ~, ¿ ? / ¿oo4 o Drill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1728' SNL, 1121' EWL, SEC. 04, T11N, R14E, UM Top of Productive Horizon: 578' SNL, 3235' EWL, SEC. 04, T11N, R14E, UM Total Depth: 370' SNL, 1296' EWL, SEC. 04, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 671384 y- 5975491 Zone- ASP4 16. Deviated Wells: Kickoff Depth Casing Program Size Casinç¡ 7" . STATE OF ALASKA I ALAS~IL AND GAS CONSERVATION C MISSIOrf< PERMIT TO DRILL JUN.23/2004 20 MC 25.005 / II Redrill I rb. Current Well ClaÖ Stratigraphic Test 8 ~~~f~:tOry ~\~~~~~~~ r:~~~.~~I~~~i'· 5. Bond: a Blanket 0 Single Well 11. Well NarneandNumber: Bond No. 2S100302630-277 PBU K-03B / 6. Proposed Depth: 12. Field / Pool(s): MD 11662 TVD 8827 Prudhoe Bay Field / Prudhoe Bay 7. Property Designation: Pool ADL 028303 8. Land Use Permit: 13. APproximateæp Ð~e: Ju. ~04 14. Distance to ~ rést Property: 8650' 9. Acres in Property: 2560 4-1/2" Weight 26# 12.6# Maximum Hole Angle SPeCifications Grade Coupling L-80 BTC-M L-80 IBT-M 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):Plan 52.4 feet K-06A is 315' away at 11514' ~ 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3250 psig Surface: 2380 psig 8560 ft 90° Hole 8-1/2" 6-1/8" Lenç¡th 550' 2822' MD 8400' 8800' TVD MD TVD (includinç¡ staç¡e data) 7754' 8949' 8267' 173 cu ft Class 'GY 8125' 11622' 8827' 400 cu ft Class 'G' /' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD Junk (measured): 11287 8725 None 11221 8723 None Structural Conductor 110' 20" x 30" 8 cu yds Concrete 110' 110' Surface 2694' 13-3/8" 3729 cu ft Permafrost 'E' & PF II 2694' 2691' Intermediate 8966' 9-5/8" 1981 cu ft Class 'G', 133 cu ft PF 'c' 8966' 8274' Production Liner 558' 7" 334 cu ft Class 'G' 8677' - 9235' 8007' - 8522' Liner 2573' 2-7/8" 129 cu ft Class 'G' 8714' -11287' 8041' - 8725' 20. Attachments a Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8699' - 8724' a Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report a Drilling Fluid Program a 20 AAC 25.050 Requirements Perforation Depth MD (ft): 9470' -11190' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Date: Contact Phil Smith, 564-4897 Phone 564-5521 Permit To Drill Permit Approva) L Number:2o.7'- //5 50-029-21011-02-00 Date: II j3ø ¡Vi Conditions of Approval: Samples Required DYes ):gNo Mud Log Required Hydrogen Sulfide Measures ~es D No Directional Survey Required ßoPE ~ÇOO (-'5./ pe/ L,O. 5/t:,.oov, See cover letter for other requirements DYes ~No ~Yes D No --- ORIGINAL BY ORDER OF THE COMMISSION Date t~(J ~ y; Z~;'Du~Plicate · . I Well Name: I K-03B Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 1 A Bottom Hole Location: x = 671,383.9 Y = 5,975,490.9 / 1728' FNL 1121' FWL Sec. 4, T11 N, R14E Umiat ./ X = 673,468.0 Y = 5,976,689, TVDss 8725' 578' FNL 3235' FWL Sec. 4, T11 N, R14E Umiat X = 671,524.0 Y = 5,976,852.0 TVDss 8775' 370' FNL 1296' FWL Sec. 4, T11 N, R14E Umiat /' I AFE Number: 1 PBD4P2243 1 I Estimated Start Date: I 07/26/04 I Rig: 1 Nabors 2ES /' I Operating days to complete: 117.7 I MD: 111.662' 1 I TVD: 18,827' 1 I GL: 123.9' 1 I KB: 128.5' I I KBE: 152.4' I Well Design (conventional, slim hole, etc.): I Two String Horizontal Sidetrack I Objective: 1 Ivishak Zone 1 A Formation Markers Formation Tops (wp02) MD TVD TVDss Comments CM2 7263 -7211 ABOVE KICKOFF CM1 7477 -7425 THRZ 7663 -7611 LCU 7882 -7830 T JD 7882 -7830 T JC 8587 7923 -7871 T JB 8744 8072 -8020 T JA 8848 8171 -8119 Sag River 8949 8267 -8215 Shublik 9003 8319 -8267 TSAD 9046 8361 -8309 TCGL 9123 8437 -8385 BCGL 9180 8492 -8440 TZ1 B 9386 8667 -8615 TDF 9519 8742 -8690 BSAD (at landing) 9787 8782 -8730 TD 11,622 8827 -8775 TD Criteria: Reach planned TD unless drilling conditions deteriorate. Extra footage has been designed in the drilling polygon (200ft) so well objectives (800-1000ft perf'able 1 A /1 B) can be met. " 3250 PSI = 7.25 ppg EMW K-03B Permit to Drill Page 1 . . Directional - Sperry wp02 KOP: 18560' MD Maximum Hole Angle: _240 in the 8-1/2" intermediate section (at KOP) -900 in the 6-1/8" horizontal section Only K-06A does not pass BP's anti-collision policy for major risk. The well passes minor risk criteria at 1/200. It is currently on production at 1600 blpd without artificial lift. The center-to-center distance is 315', or 58' inside the allowable deviation / for major risk. When minor risked the allowable deviation increases to 278' MW D Standard 8650' to the nearest PBU property line K-06A is 315' away from planned well K-03B at 11,514' planned MD. Close Approach Wells: Survey Program: Nearest Property Line: Nearest Well within Pool: CasinglTubing Program Hole Size Csgrrbg Wt/Ft Grade Conn Length Top Btm O.D. MDrrVD MDrrVD 8-1 /2" 7" 26# L-80 BTC-M 550' 8400'n,754' 8949'/8,267' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2822' 880018125' 11,622/8827' Tubing 4-1/2" 12.6# L-80 IBT-M 8770' GL 8800/8125' Mud Program Section Millinr Mud Properties: LSND Density (ppg) Viscosity I PV 10.2 45-55 15-22 I Whip Stock Window 9-5/8", 47# I YP I TauO I MBT 28-35 3-5 <20 PH 9.0-9.5 Intermediate Mud Properties: LSND DenS~!~o/. ( pg) I Viscosity I PV ~ 38-45 15-22 I 8-1/2" hole section YP I TauO 22-30 2-4 I MBT <20 PH 9.0-9.5 Production Mud Properties: FloPro DensitG... ~) I Viscosity I PV 8.4 8.!j 45-55 <10 ,/ YP 25-35 I LSVR I >35,000 pH 8.5 - 9.0 I API FII 9-9.5 Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GR/Res Open Hole: None Cased Hole: None 6-1/8" Production: Drilling: Open Hole: Cased Hole: Sample Catchers - over entire interval, samples described Dir/GRlRes/Neu/ABI (Neu/Den may be discontinued after picking GOC) None None K-03B Permit to Drill Page 2 . . Cement Program I Casing Size 17" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: Based on 80' shoe track, 389' of 7" X 8-1/2" open hole with 40% excess, 150' 7" X 9-5/8" lap, and 200' O~9 '5~X 4" DP excess. Tail TOC: 2I-OpYMD (Top of Liner) I Total Cement Volu ~ 1 Tail 131 bbls, 173 ft3~aCkS Class G @ 15.8 PP9&t3/sack I Casing Size 14.5" 12.6#, L-80 Production liner Basis: Lead: None Tail: Based on 80' shoe track, 2673' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner Lap, ~. 2"90' of 7" X 4" DP excess. Tail TOC:t~g>y/MD (Top of Liner) _, I Total Cement Volum~: 1 Tail 171 bbls, 400 ft3,@acks Class G @ 15.8 ppg€§.Ji3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing/7" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 3250psi @ 8700' TVDss (7.3 ppg EMW) 238~ (.10 psi/ft gas gradient to surface) lýTfÍnjté with an 11.5 ppg FIT / ~s test to 3,500 psi/250 psi. /" Annular test to 2,500 psi/250 psi 3500 psi surface pressure 11.5 ppg FIT after drilling 20' from middle of window 3250 psi @ 8800' TVDss (7.1 ppg EMW) 23~P i (.10 psi/ft gas gradient to S.u.. rface) I in· with a 10.0 ppg FIT , R . s test to 3,500 psi/250 psi. ./ Annular test to 2,500 psi/250 psi 3500 psi surface pressure 10.0 ppg FIT after drilling 20' of new hole 8.5 ppg Seawater / 7.2 ppg Diesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. K-03B Permit to Drill Page 3 . . Sidetrack and Complete Procedure Summary Current Condition: ./ Passed MITlA 3500 psi and MITOA to 2000 psi on 7/6/03. ./ Set and tested XX-plug @ 8532' in sliding sleeve. Set PXX-plug @ 2035' on 10/30/03 for wellhead repair and pulled both plugs on 12/10/03 ./ The well last tested BOPD: 687, BWPD: 12, MCFPD: 30,377, AL Rate: 0 on 4/3/04 Scope Pre-Riq Work: 1. Fluid pack as necessary for cement plug. 2. R/U and RIH with coil tubing to plug and abandon the well bore from PBTD at 11,220' to window depth of 9200'. Estimated cement volume = 12 bbls. 3. Pressure test the tubing and cement plug to 3500 psi. 4. R/U slick-line. Drift the 4 W' tubing to at least 8,600' md to confirm clear to the required cut depth. 5. R/U E-line. RIH with chemical cutter and severe the 4 %" tubing in the center of the full joint of tubing between the sliding sleeve and the production packer -8,600' md. 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,100' MD with diesel. 7. Bleed casing and annulus pressures to zero. 8. Cycle the tubing hanger LDS and test the 9 5/8" mandrel packoff to 5000 psi. 9. Set a BPV and test to 1000 psi from tubing annulus. Secure the well. Level the pad as necessary. RiCl Operations: /" 1. MI I RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPVrrWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull BPVrrWC. / 4. R/U. Pull 4 %" tubing from the cut at -8,600' MD and above. /. 5. RIH wi 8 %" gauge ring I junk basket to top of tubing stub. 6. RIH with HES EZSV and set bridge plug a~ required to avoid cutting casing collar and place top of whip stock at -8560. POOH. RID E-line. ,./ / 7. Pressure-test the 9 5/8" casing to 3,500psi for 30 minutes. Record test. . 8. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired,/ and set on bridge plug. Shear off of whip stock. 9. Displace the well to 10.2 ppg LSND based milling fluid. Completely displace the well prior to beginning ~ milling operations. . 10. Mill window in 9 5/8" casing at ± 8,650' MDvPfús approximately 20' beyond middle of window. Circulate well bore clean. // 11. Pull up into 9 5/8" casing and conduct an FIT to 11.5 ppg EMW. POOH. 12. M/U 8 %" Dir/GR/Res assembly. RIH, kick off and drill the 81/2" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to win~. POOH. 13. Run and cement a 7",26.0#, L-80 intermediate drilling liner. 14. Test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the tesV 15. M/U 6 1/8" Dir/GR/Neu/Den/ABI assembly. RIH to the landing C7ollar. 16. Drill out the 7" liner float equipment and cement to the shoe. 17. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 18. Drill out the 7" shoe plus drill -20' new formation; pull up into the shoe and conduct an FIT to 10.0ppg EMW. Drill ahead to horizontal landing point. POOH for bit I BHA change. Drop Neu/Den. / 19. RIH, drill horizontal section to planned TD, short trip as necessary. 20. Circulate, short trip, spot liner running pill, POOH. 21. Run and cement a 4 W', 12.6#, L-80 solid production liner. POOH UD all drill pipe. // K-03B Permit to Drill Page 4 . . 22. RIH with 2 7/8" perf guns and perforate ±800'. 23. R/U and run 4 1/2",12.6#, L-80 completion tubing. Land the tubing RILDS/ 24. Set a TWC and test to 1000 psi . 25. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. /' 26. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 27. Shear the DCK valve and freeze protect the well to -2,100'. Secure the well. 28. Rig down and move off. / Post-Riq Work: 1. Install well house and instrumentation 2. MI / RU slick-line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 3. POP well to test unit until cleaned up. K-03B Drilling Program Job 1: MIRU Hazards and Contingencies ~ K-03A is 35' south of K-12A and 40' north of K-16A. No well houses will require removal or shut-in for the rig move onto K-03A. ~ K-Pad is not designated as an H2S site. Recent H2S data from the pad is as follows: - #1 Closest SHL #2 Closest SHL #1 Closest BHL #2 Closest BHL Well Name K-16A K-12A K-06A K-04A H2S Reading 10 ppm 10 ppm 10 ppm 10 ppm Date 8/12/2000 8/25/2000 8/27/2000 5/04/2004 No wells have more than 10 ppm H2S recorded ~ Post Permit to Drill in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies ~ K-03 was coiled tubing sidetracked to K-03A and completed with a 2 7/8" liner hung off in the original tubing tailpipe. Pre-Rig operations will include P&Aing the perforations in the 2-7/8" liner with cement to approximately 500' below the tubing tail. After the cement work and tubing cut, the wellbore will be fluid packed, pressure tested and freeze protected. ~ There is no caliper survey on record for K-03A and no suspicion of significant corrosion. Limit pull to 80% of tensile strength. ~ NORM test all retrieved well head and completion equipment. ~ Verify the hanger type and connection. Be prepared with necessary equipment to remove. K-03B Permit to Drill Page 5 . . Reference RP .:. "De-completions" RP -=--......, Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies ~ The intermediate section will kick off in the Colville and TD at the top of Sag River. Since K-03B will start at <300 inclination and drop angle, 10.2 ppg mud weight will be adequate to maintain wellbore stability though the Kingak shale to interval TD. Follow all shale drilling practices to minimize potential problems. ~ There are no fault crossings in the intermediate section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ KICK TOLERANCE: In e worst-case scenario of 8.4 ppg pore pressure at the Sag River depth, a fracture gradient 0 1. ppg at the 9-5/8" casing window, and 10.2 ppg mud in the hole, the kick tolerance is' i~. ,~ Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 6: Install 7" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP K-03B Permit to Drill Page 6 e . Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ The geologic polygon is approximately 180 feet wide and the driller's polygon is roughly half that at 70% confidence. Both the north (avoid interference) and south (avoid faulting & potential LC) sides are hard lines. Well is designed to geosteer in Zone 1A mouthbar sands, and toe up into lower Zone 1 B with 200' of room at the end of the polygon for additional drilling if required to achieve minimum pay. ~ The landing is targeted 3' above BSAD. If BSAD comes in higher than expected, geosteer up into Z1 A after consultation with town geologist. ~ K-06A has been minor risked to allow drilling (see anti-collision report). Watch for magnetic interference in the areas of interest. ~ KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gr~.· 9.5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolerance i~e. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.5 ppg mud will be -650psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Schlumberger Cement Program Job 10: DPC Perforate Production Casinq Hazards and Contingencies ~ Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. K-03B Permit to Drill Page 7 e . Reference RPs .:. Follow Schlumberger perforating practices and recommendations. .:. "OPC Perforating" RP ,'W .:If::::::,-____=!!Irum¡;!-, ,""."".,,~:,__':'Nf_, .Job 12: Run Completion Hazards and Contingencies ).> Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRelease RiCl Hazards and Contingencies ).> No wells will require well house removal or shut-in for the rig move off of K-03B. See MIRU section for nearest well. Reference RP .:. "Freeze Protecting an Inner Annulus" RP K-03B Permit to Drill Page 8 , TREE= , 4" CAMERON WELLHEAD = MCE:VOY AërùA T6R~ . AxäsON ~ ,.' ,- - ~., KB. ELEV = 61.07' .. " -, .-. ~ ~ ~-,- ~~,- BF. ELEV = 24.57' , ,.. " -- KOP = 3050' Max Angle = 95 @ 9724' ~., <..~ < -.. Datum MD = 9803' ~- - ._" . - Datum ìVD = 8800' SS e K-03A / LN01ES, 70o@9479'&90o@9655' . 2063' 1-f4-1/2" OTIS SSSV NIP, ID = 3.813" I L - ST MD ~ r 8 3166 7 5031 6 6366 5 7328 4 7820 3 7944 2 8379 1 8504 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2692' ~ Minimum IC = 3.725" @ 8737' 4-1/2" OTIS XN NIPPLE I TOP OF 7" LNR H TOPOF2-7/8" LNR H 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H I 9-5/8" CSG, 47#, L-80, ID = 8.681" H 1 TOP OF WHIPSTOCK H IRA TAGH I TOP OF CEMENT H I PBID H [ 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H ÆRFORA TION SUMMARY REF LOG: SPERRY GRlMWD ON 02/99 ANGLEATTOPÆRF: 66 @ 9470' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL OpnlSqz DATE 2" 6 9470 - 9484 0 04/26/03 2" 6 9490 - 9506 0 04/26/03 2" 6 9664 - 9714 0 03/07102 2" 6 9757 - 9782 0 03/07102 2" 4 10450 - 10610 0 02/22/99 2" 4 10658 - 10900 0 02/22/99 2" 410950-11110 0 02/22/99 2" 4 11149 - 11190 0 02/22/99 DATE 1983 02/22/99 03/09/02 05/20103 05/27103 06/27103 REV BY COMMeITS ORIGINAL COM PLETION SIDETRACK COM PLETION RNITP CORRECTIONS ASITLH ADÆRF CORRECTIONS A IDITLP GL V CORRECTIONS CAO/KK GL V C/O 8677' 8714' 8775' I 8964' 9235' 9244' 9328' 9544' 9584' ..LJ.. í ì :8: :& . . 8563' 8614' 8638' J 8693' 8714' 873T 8775' 8775' ~ ~ ~ . GAS LIFT MANDRELS ìVD DEV TYPE LATCH 3082 8 DMY RK 4770 31 DMY RK 5960 31 DMY RK 6724 31 DMY RK 7158 28 DMY RK 7246 28 DMY RK 7692 25 DMY RK 7783 24 DMY RK PORT DATE o 06/27103 o 06/27103 o 01/02/92 o 01/02/92 o 01/02/92 o 01/02/92 o 01/02/92 o 01/02/92 H4-1/2" OTIS XA SLDG SL V I w I X PROFILE, ID = 3.813" I-fTBG SEAL ASSY I 1-f9 5/8" X 4-1/2" BOT A<R, ID = 3.813" I 1-f4-1/2" OTIS X NIP, ID = 3.813" I 1-fDEA..OYMENTSLEEVE I H4-1/2" OTIS XN NIP, ID = 3.725" I H4-1/2" TBG TAIL, ID = 3.958" 1 l-f ELMD TT LOGGED 10/19/83 I I MILLOUT WINDOW 9235' - 9243' I I PBID H 11220' 12-7/8" LNR, 6.16#, L-80, .00579bpf, ID=2.441" l-f 1128T I DA TE REV BY COMMENTS 10/29/03 JLJITLP CHANGE OTIS XA SLV TO 4-1/2" PRUDHOE BA Y UNIT WELL: K-03A PERMIT No: 1990030 API No: 50-029-21011-01 SEC4, T11N, R14E, 1728' FNL & 1121' FEL BP Exploration (Alaska) Proposed NOTES: , TREE: 4" CAMERON WELLHEAD: MCEVOY ACTUATOR: 2100' X NIP,ID: 8800' SS 1 113-3/8" CSG. 72#. L-80, ID: 12,347" H 2692' -Á ~ S1 MD rvD 4 3260 3 5200 2 6785 1 8285 PORT ---L 4.5" x 1.5" Minimum ID = 3.725" @##' 4-1/2" OTIS XN NIPPLE 141/2" 12.6#LSO BTRS-m (3.958"ID) I l J 17" 26# L-80 Drilling Liner (6.276"ID) H 8400' I - II II! 8560' l-t 9 5/S" Window PERFORATION SUMMARY REF LOG: SPERRY GRlMWD ON 02/99 ANGLE AT TOP PERF: 66 @ 9470' Note: Refer to Production DB SIZE SPF INTERVAL I I 8,755' I 8,775' I 8,790' 8,800' H4 8,800' 8,949' 7" LNR - I TOP OF 2-7/S"LNR - 14-1/2" TBG, 12.6# tubing tail 19-5/8" CSG, 47#, L-SO, ID: 8.6S1" - ITOC 2 7/S" liner ~ ~ ~ 141/2" 12.6# I 9-5/S" x 4 1/2" -~ -9200' _A ~ I TOP OF WHIPSTOCK 9235' I I I 7" LNR, 26# abandoned liner DATE 1983 02122/99 05105/04 REV BY COMMENTS ORlGtNAL COMPleTION SIDETRACK COM PI..ETION PGS PROPOSED SIDETRACK BY 2-7/S" LNR, 6.16#, L-8(), .00579 bpf, COMMENTS SEC4, CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size No. TVDPath MDPath Formation 1 &948.78 7 casing 7.000 1 7923.42 8586.84 T1C 2 8072.42 8744.35 TJB 2 I 1622.00 4 112 Casing 4.500 3 8171.42 &&4&.14 TJA 4 8267.42 8948.78 Sag River 5 &319.42 9003.16 Shublik 6 8361.42 9046.21 TSAD 7 8437.42 9123.20 TCGL 7200- 8 8492.42 9179.72 BCGL 9 8667.42 9385.77 T2m 10 8742.42 951K82 TDF !I 8782.42 9786.77 BSAD 7800 " :¡; "" ~ ~ ¿S g 8lO0 € " :> " '" þ COMPANY DJ:rIAILS REFERENCE INFORMATION SURVEY PROGRAM Plan: K~03.B WP02 (K~û3/K-03B Plan) Ikpth Fm Depth To SurveyiPJan 8560.00 ¡ 1622J5 P!anne¢ K.ffiB WP02 V25 Too] Created By: Troy Jakabosky Date: 5/5/2004 MWD Date Revíewed: Dðte: WELL DETAILS Name -~N!-S "-E¡-W Nnrtbìng l::&sting Latitl!tW Longùude Slot K-03 2305.56 1094.61 5975491.00 67B84.ûlJ 7002û'20.109N 148°36'33.273W 03 TARGET DETAILS Name TVD +NI-S +EI-W Northing Basting SIillpe K-03B TlB 8777.42 II50.1I 21I 1.00 5976688.98 673468.02 Point K-03B poly 8777.42 978.46 2400.55 5976524.00 67376 I.40 Polygon K-03B 12 8827.42 1251.23 882.89 5976762.00 672238.00 Point K43B T3 8827.42 1357.54 171.08 5976852,00 671524.00 Point 7500 SECTION DETA1LS Sec MD Inc Azi TVD +NI-S +EI'W DLeg TFace VSec 1 8560.00 23.92 70.63 7898.91 1000.50 2333.90 0.00 0.00 -2333.90 2 8580.00 24.24 76.46 7917.17 1002.81 2341. 72 12.00 85.00 -2341.72 3 8657.70 17.47 65.60 7989.76 1011.37 2367.88 10.00 -155.28 -2367.88 4 8983.60 17.47 65.60 8300,63 1051.78 2456.98 0.00 0.00 -2456.98 5 9669.25 87.61 274.67 8777.42 !I50.!I 2111.00 .Ã'5.00 -150.14 -2111.00 6 9670.31 87.56 274.52 8777.46 !I50.20 2109.94 15.00 -107,84 -2109.94 7 10785.95 87.56 274.52 8824.94 1238.01 998.78 0.00 0.00 -998.78 8 10902.65 90.00 278.50 8827.42 1251.23 882.89 4.00 58.56 -882.89 9 11622.35 90.00 278.49 8827.42 1357.54 171.08 0.00 -90.00 -171.08 Target K..(J3B TlB K..(J3B T2 K..(J3B 13 8400 8700 o "¡¡' ~ c c c +' ~ " ~ ~ 1200 " " fI) COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Plan: K~03B WP02 (K-031K-03B Plan) BPAmŒ<J Date: 5/512004 DeptbFm Depth To Survey/Plan 8560,00 j 1622.35 Pkm1K<d: K-03B WPÜ2 V25 roo! Created By: Troy Jakabosky Cheçked: WELL DETAILS Af<A.l.LœHI;TONn)Mí\'",II,," Longitude Slot MWD Date" Nlfffie +NJ-S ~ E/..W Northing Ea:;Üng ¡~mtude FORM". TION TOF OET AILS CASING OET AILS No. TVD MD Name Size 8267.42 8948.78 7 casing 7.000 8827.42 11622.00 4 1/2 Casing 4.500 K-03 2305.56 1094.61 597541JLOO 671384.00 70"20'20J09N 148"36'33,273W û3 No. TVOFath MDPath Formation TARGET OET AILS Name TVD +N/-S +E/-W Northing K-03B TlB 8777.42 1150.11 2111.00 5976688.98 K-03B poly 8777.42 978.46 2400.55 5976524.00 K-03B 1'2 8827.42 1251.23 882.89 5976762.00 K-03B T3 8827.42 1357.54 171.08 5976852.00 Point Polygon Point Point Easting Shape I 2 3 4 5 6 7 8 9 10 II 7923.42 8072.42 8171.42 8267.42 8319.42 8361.42 8437.42 8492.42 8667.42 8742.42 8782.42 8586.84 8744.35 8848. 14 8948. 78 9003.16 9046.2 I 9123.20 9179.72 9385.77 9518.82 9786.77 TJC TJB TJA Sag River Shublik TSAD TCGL BCGL TZIB TDF BSAD 673468.02 673761.40 672238.00 671524.00 SECTION DETAILS Sec MD lue Azi TVD +N/-S +E!cW pLeg TFace VSec Target I 8560.00 23.92 7M3 7898.91 1000.50 2333.90 0.00 OJ)O -2333.90 2 8580.00 24.24 76.46 7917.17 1002.81 2341.72 12.00 85.00 -2341. 72 3 8657.70 17.47 65.60 7989.76 IOII.37 2367.88 to.OO -155.28 -2367.88 4 8983.60 17.47 65.60 8300.63 1051.78 2456.98 0.00 0.00 -2456.98 5 9669.25 87.61 274.67 8777.42 JJ50.JJ 2JJ 1.00 ~$.OO -150.14 -2H1.00 K-03B TlB 6 9670.31 87.56 274.52 8777.46 JJ 50.20 2109.94 15.00 -107.84 -2109.94 7 10785.95 87.56 274.52 8824.94 1238.01 998.78 0.00 0.00 -998.78 8 10902.65 90.00 278.50 8827.42 1251.23 882.89 4.00 58.56 -88n9 K-03BT2 9 11622.3 5 90.00 278.49 8827.42 1357.54 171.08 0.00 -90.00 -171.08 K-03B T3 1800 1500 900 . BP Planning Report . Principal: Yes Plan: K-03B WP02 Date Composed: Version: Tied-to: Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB K Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5973161.33 ft 670342.10 ft Latitude: 70 19 Longitude: 148 37 North Reference: Grid Convergence: Well: K-03 Slot Name: K-03 Well Position: +N/-S 2305.56 ft Northing: 5975491.00 ft Latitude: +E/-W 1094.61 ft Easting: 671384.00 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: K-03B Plan Current Datum: Magnetic Data: Field Strength: Vertical Section: Casing Points 23.92+28.5 2ES 4/13/2004 57595 nT Depth From (TVD) ft 28.42 Drilled From: TiMln Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 4/13/2004 25 From: Definitive Path Alaska, Zone 4 Well Centre bggm2003 57.435 N 5.245 W True 1.30 deg 03 70 20 20.109 N 148 36 33.273 W K-03 8560.00 ft Mean Sea Level 25.36 deg 80.89 deg Direction deg 270.00 8948.78 8267.42 11622.00 8827.42 Formations Height 52.42 ft +N/-S ft 0.00 7.000 4.500 8.500 6.125 7 casing 4 1/2 Casing 8586.84 8744.35 8848.14 8948.78 9003.16 9046.21 9123.20 9179.72 9385.77 9518.82 9786.77 0.00 0.00 0.00 0.00 0.00 7923.42 8072.42 8171.42 8267.42 8319.42 8361.42 8437.42 8492.42 8667.42 8742.42 8782.42 CM2 CM1 THRZ LCU TJD TJC TJB TJA Sag River Shublik TSAD TCGL BCGL TZ1B TDF BSAD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 . . BP Planning Report Targets K-038 T1 8 8777.42 1150.11 2111.00 5976688.98 673468.02 70 20 31.418 N 148 3531.605 W K-03B poly 8777.42 978.46 2400.55 5976524.00 673761.40 70 2029.729 N 148 3523.148 W -Polygon 1 8777.42 1038.48 2400.42 5976584.00 673759.90 70 20 30.319 N 1483523.151W -Polygon 2 8777.42 1089.58 1828.10 5976622.00 673186.60 70 20 30.823 N 148 35 39.869 W -Polygon 3 8777.42 1117.04 1195.82 5976635.00 672553.90 70 20 31.094 N 148 3558.340 W -Polygon 4 8777.42 1199.88 547.41 5976703.00 671903.80 70 20 31.910 N 148 36 17.282 W -Polygon 5 8777.42 1305.75 -13.86 5976796.00 671340.30 70 20 32.951 N 148 36 33.678 W -Polygon 6 8777.42 1471.16 58.04 5976963.00 671408.40 70 20 34.578 N 148 36 31.577 W -Polygon 7 8777.42 1341.07 891.24 5976852.00 672244.30 70 20 33.298 N 148 36 7.237 W -Polygon 8 8777.42 1296.54 1832.84 5976829.00 673186.60 70 20 32.859 N 148 35 39.730 W -Polygon 9 8777.42 1181.87 2472.62 5976729.00 673828.80 70 20 31.729 N 148 3521.040 W -Polygon 10 8777.42 1038.48 2400.42 5976584.00 673759.90 70 20 30.319 N 148 3523.151 W K-038 T2 8827.42 1251.23 882.89 5976762.00 672238.00 70 20 32.415 N 148 36 7.481 W K-038 T3 8827.42 1357.54 171.08 5976852.00 671524.00 70 20 33.461 N 148 3628.275 W ptan Section Information 8560.00 23.92 70.63 7898.91 1000.50 2333.90 0.00 0.00 0.00 0.00 8580.00 24.24 76.46 7917.17 1002.81 2341.72 12.00 1.60 29.16 85.00 8657.70 17.47 65.60 7989.76 1011.37 2367.88 10.00 -8.71 -13.97 -155.28 8983.60 17.47 65.60 8300.63 1051.78 2456.98 0.00 0.00 0.00 0.00 9669.25 87.61 274.67 8777.42 1150.11 2111.00 15.00 10.23 -22.01 -150.14 K-038 T1 B 9670.31 87.56 274.52 8777.46 1150.20 2109.94 15.00 -4.59 -14.29 -107.84 10785.95 87.56 274.52 8824.94 1238.01 998.78 0.00 0.00 0.00 0.00 10902.65 90.00 278.50 8827.42 1251.23 882.89 4.00 2.09 3.41 58.56 K-038 T2 11622.35 90.00 278.49 8827.42 1357.54 171.08 0.00 0.00 0.00 -90.00 K-038 T3 Survey 8560.00 23.92 70.63 7898.91 1000.50 2333.90 0.00 0.00 0.00 Start Dir 12/100' : 8560' 8575.00 24.14 75.02 7912.61 1002.31 2339.73 12.00 1.46 29.26 MWD 8580.00 24.24 76.46 7917.17 1002.81 2341.72 12.00 2.02 28.87 Start Dir 10/100' : 8580' 8586.84 23.62 75.75 7923.42 1003.48 2344.41 10.00 -9.06 -10.44 TJC 8600.00 22.44 74.27 7935.53 1004.81 2349.38 10.00 -8.98 -11.23 MWD 8650.00 18.10 67.02 7982.43 1010.43 2365.73 10.00 -8.66 -14.50 MWD 8657.70 17.47 65.60 7989.76 1011.37 2367.88 10.00 -8.27 -18.41 End Dir : 8657.7' MD, 79 8700.00 17.47 65.60 8030.11 1016.62 2379.45 0.00 0.00 0.00 MWD 8744.35 17.47 65.60 8072.42 1022.12 2391.57 0.00 0.00 0.00 TJB 8800.00 17.47 65.60 8125.50 1029.02 2406.78 0.00 0.00 0.00 MWD 8848.14 17.47 65.60 8171.42 1034.99 2419.94 0.00 0.00 0.00 TJA 8900.00 17.47 65.60 8220.89 1041.42 2434.12 0.00 0.00 0.00 MWD 8948.78 17.47 65.60 8267.42 1047.46 2447.46 0.00 0.00 0.00 7 casing 8983.60 17.47 65.60 8300.63 1051.78 2456.98 0.00 0.00 0.00 Start Dir 15/100' : 8983. 9000.00 15.38 60.98 8316.37 1053.85 2461.12 15.00 -12.72 -28.18 MWD 9003.16 14.99 59.95 8319.42 1054.26 2461.84 15.00 -12.32 -32.67 Shublik 9025.00 12.46 51.15 8340.63 1057.15 2466.12 15.00 -11.60 -40.30 MWD 9046.21 10.40 38.85 8361.42 1060.08 2469.11 15.00 -9.72 -57.98 TSAD 9050.00 10.09 36.16 8365.15 1060.61 2469.52 15.00 -8.12 -70.92 MWD 9075.00 8.73 14.60 8389.82 1064.22 2471.29 15.00 -5.43 -86.24 MWD 9100.00 8.87 349.92 8414.54 1067.96 2471.43 15.00 0.54 -98.72 MWD 9123.20 10.29 330.69 8437.42 1071.52 2470.10 15.00 6.12 -82.92 TCGL . . BP Planning Report Survey 9125.00 10.44 329.44 8439.19 1071.80 2469.94 15.00 8.35 -69.29 MWD 9150.00 12.93 315.49 8463.68 1075.75 2466.83 15.00 9.96 -55.81 MWD 9175.00 15.91 306.32 8487.89 1079.78 2462.10 15.00 11.94 -36.67 MWD 9179.72 16.51 304.96 8492.42 1080.54 2461.03 15.00 12.67 -28.76 BCGL 9200.00 19.17 300.09 8511.73 1083.86 2455.79 15.00 13.08 -24.04 MWD 9225.00 22.57 295.64 8535.08 1088.00 2447.91 15.00 13.60 -17.80 MWD 9250.00 26.06 292.31 8557.86 1092.16 2438.50 15.00 13.97 -13.30 MWD 9275.00 29.61 289.73 8579.97 1096.33 2427.60 15.00 14.21 -10.32 MWD 9300.00 33.20 287.66 8601.30 1100.49 2415.26 15.00 14.37 -8.28 MWD 9325.00 36.82 285.95 8621.78 1104.63 2401.53 15.00 14.48 -6.83 MWD 9350.00 40.46 284.51 8641.30 1108.73 2386.47 15.00 14.56 -5.76 MWD 9375.00 44.12 283.27 8659.79 1112.76 2370.14 15.00 14.62 -4.96 MWD 9385.77 45.70 282.79 8667.42 1114.47 2362.73 15.00 14.66 -4.50 TZ1B 9400.00 47.79 282.19 8677.17 1116.71 2352.62 15.00 14.68 -4.23 MWD 9425.00 51.47 281.22 8693.36 1120.57 2333.97 15.00 14.71 -3.87 MWD 9450.00 55.15 280.35 8708.30 1124.32 2314.28 15.00 14.74 -3.49 MWD 9475.00 58.84 279.55 8721.91 1127.94 2293.63 15.00 14.76 -3.19 MWD 9500.00 62.53 278.81 8734.15 1131.41 2272.12 15.00 14.78 -2.95 MWD 9518.82 65.32 278.29 8742.42 1133.93 2255.40 15.00 14.79 -2.78 TDF 9525.00 66.23 278.12 8744.96 1134.73 2249.82 15.00 14.80 -2.70 MWD 9550.00 69.93 277.47 8754.29 1137.88 2226.85 15.00 14.80 -2.61 MWD 9575.00 73.64 276.85 8762.10 1140.84 2203.29 15.00 14.81 -2.49 MWD 9600.00 77.34 276.25 8768.36 1143.60 2179.25 15.00 14.82 -2.39 MWD 9625.00 81.05 275.67 8773.05 1146.15 2154.83 15.00 14.83 -2.32 MWD 9650.00 84.75 275.10 8776.14 1148.47 2130.14 15.00 14.83 -2.28 MWD 9669.25 87.61 274.67 8777.42 1150.11 2111.00 15.00 14.83 -2.25 K-03B T1B 9670.31 87.56 274.52 8777 .46 1150.20 2109.94 15.00 -4.59 -14.29 End Dir : 9670.31' MD, 8 9700.00 87.56 274.52 8778.73 1152.53 2080.38 0.00 0.00 0.00 MWD 9786.77 87.56 274.52 8782.42 1159.36 1993.95 0.00 0.00 0.00 BSAD 9800.00 87.56 274.52 8782.98 1160.40 1980.78 0.00 0.00 0.00 MWD 9900.00 87.56 274.52 8787.24 1168.27 1881.18 0.00 0.00 0.00 MWD 10000.00 87.56 274.52 8791.49 1176.15 1781.58 0.00 0.00 0.00 MWD 10100.00 87.56 274.52 8795.75 1184.02 1681.98 0.00 0.00 0.00 MWD 10200.00 87.56 274.52 8800.00 1191.89 1582.38 0.00 0.00 0.00 MWD 10300.00 87.56 274.52 8804.26 1199.76 1482.78 0.00 0.00 0.00 MWD 10400.00 87.56 274.52 8808.51 1207.63 1383.18 0.00 0.00 0.00 MWD 10500.00 87.56 274.52 8812.77 1215.50 1283.58 0.00 0.00 0.00 MWD 10600.00 87.56 274.52 8817.02 1223.37 1183.99 0.00 0.00 0.00 MWD 10700.00 87.56 274.52 8821.28 1231.24 1084.39 0.00 0.00 0.00 MWD 10785.95 87.56 274.52 8824.94 1238.01 998.78 0.00 0.00 0.00 Start Dir4/100': 10785. 10800.00 87.85 275.00 8825.50 1239.17 984.79 4.00 2.09 3.42 MWD 10902.65 90.00 278.50 8827.42 1251.23 882.89 4.00 2.09 3.41 K-03B T2 11000.00 90.00 278.50 8827.42 1265.62 786.61 0.00 0.00 0.00 MWD 11100.00 90.00 278.50 8827.42 1280.40 687.71 0.00 0.00 0.00 MWD 11200.00 90.00 278.50 8827.42 1295.17 588.81 0.00 0.00 0.00 MWD 11300.00 90.00 278.49 8827.42 1309.94 489.90 0.00 0.00 0.00 MWD 11400.00 90.00 278.49 8827.42 1324.71 391.00 0.00 0.00 0.00 MWD 11500.00 90.00 278.49 8827.42 1339.47 292.10 0.00 0.00 0.00 MWD 11600.00 90.00 278.49 8827.42 1354.24 193.19 0.00 0.00 0.00 MWD 11622.00 90.00 278.49 8827.42 1357.48 171.43 0.00 0.00 0.00 4112 Casing 11622.35 90.00 278.49 8827.42 1357.54 171.08 0.11 0.00 -0.11 K-03B T3 . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME Æt{ ;::~ 0313 PTD# Zot.¡ -//5 Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) Pn,OT (PH) Exploration Stratigraphic ~'CLUE'" Tbe permit is for a new weJlboresegment of existing well Permit No, .' API No. Production. sbould continue to be reported as a function' of tbe original API number stated above. HOLE In accordance witb 20 AAC 25.005(f), all records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing exception tbat may occur. All dry ditcb sample sets submitted to tbe Commission must be in no greater -tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample intervals tbrougb target zones. . . D D Well bore seg Annular Disposal Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT K-03B Program DEV PTD#: 2041150 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore On Administration 1 Pe(mitJee attacheD. . . - - - - - Yes - - - - - 2 .Lease .number .appropriSlt.e. . . . . . . · Yes - - - - - - - - - - - - 3 .Unlque welln.a[1lß.aod ou.mb.er . . . . . . . . . . . . . . . . . . . . . . .__.....Y.es - - - - - - - - - - - - - - - - - -- 4 WellJQcated in.aßefineD POQI . . . . - - - - .. Yes 5 WeJIJQcaled pr.operdistaoçe. from driJling unilb.ound.alY. . .. Yes - - - -- 6 WeJIJQcated proper .distance. from Qther wells. . . . . - - - - Yes - - - - - - - - -- 7 S.utfjcienLacreage.ayaiISlble indritliog unjL - - - - - .. Yes - - - - - 8 Jf.deviated. js weJlbQre plç¡tincJuded . . .. Yes - - - - - - 9 Ope(ator onl¥ affected party. . - - - - - · . Yes 10 .Ope(ator bas.appropriate.b.ond InJorce . . . . . . . . . . . . . . . . . ........ Yes - - - - - - - - - - - - - - - - - -- 11 Pe(mil c.ao be lssu.ed withQut conservaiion order. . . · . .Yes - - - - - - - - - - - Appr Date 12 Pe(mil G.é!O be issued wjtbQut ad.minist(atÌ\le.approval . - - - - - - - - - - Yes - - - -- RPC 6/29/2004 13 Can permit be approved before 15-day wait Yes 14 WellJQC<lted within area andstrç¡ta .authorized by.lojectioo Orde( # (putlO# inc.o[1l[1leots). (For .NA - - - - - 15 .AJlwelJs.wit!1in.1l4.mite.area.of(eyiewideotlfied(Fo(servjc.e.w.eUonl¥>............... .NA - - - - - - - - - - - - - - - - - - - 16 Pre-prQduçed. il1jector; DvratJonof pre-prodvction less than. 3 months. (For .ser:vice welt QnJy) . . .NA 17 AÇMP. finding.of CQn.sist.el1cy.h.as bee.nJssued. for. this project . .NA Engineering 18 .C.ol1du.ct.or stÖng.prQvided . . . . . . . - - - - - .. .NA - - - -- 19 .SwfaCß .cç¡sing.protec.ts all known. USDWs . .NA - - - - -- 20 CMTv.otadeQu.ateJo circutate.o.n.cond.uctor.& SUJf.csg . . .... .NA - - - - - - 21 .CMTv.otadeQu.atetotie-inJQng.stril1gt.o.surfcsg. . .... . .NA - - - - - - 22 .CMTwill coyeraJl kno.w.npro.ductiYe bQrizQn.s. . . . . . . . · Yes - - - - - 23 .C.asil1g desigos ad.eClua.te fO( C,T. B.&permafr.ost . . .. Yes - - - - - 24 .AdequSlt.etan.kç¡ge.or re.ser:ve pit. . . - - - - - -- - - - - - . . . . . Yes ~abot"S.2.ES, . . . . 25 Jf.a.re-d(iII~ hasa. 1.0-403 fQr Slbandon.ment beel1 apPJQved . - - - - - - Yes 6/26/2004. 26 .AdequSlle .weUbore separatio.n proposed. . . . . . . . . . . . . . . . . . . . . . . . .. .. .Yes - - - - - - - - - - - - - - - - - -- 27 Jf.djver:terrequired, dQes itmeel reguJations. . . . . . . . . NA Sidet(ack. . - - - -- Appr Date 28 DJiUiog fJujd. program sc.hematic& eq.uip JistadequSlt.e. . . · . Xes Mç¡x MW to,2.ppg.. . . WGA 6/29/2004 29 B.OPEs..d.o they meel reguJation . . - - - - - -- - - - - - - · Yes 30 .BOP.E.PJess ratiog appropriate; test t.o(put PSig in .comments) . · . Xes Test 1.03500. psLMSF' 2380 psi 31 C.hokemanifold cQmplies. w/APtRF'-53 (May 84>. . . .Yes 32 WQrk will oCC.ur withoy!operatjonshutdow.n. . . . . . .. Yes 33 .Is. presel1ce. Qf H2S gas. proQable. . . - - - - No. 34 Mecha.nicaLcondillo!lOf wells within ,ð.Oß yertfied (For.s.ervjce welJ on.ly). · .NA Geology 35 .Permit c.ao be lssu.ed wfo hyd(ogen s.ulfide measuœs. . . .. No. 36 .D.ata.PJeseoted on. pote.ntia' pveJpres.sure .zones. .. NA Appr Date 37 .Seismic.anç¡lysis. Qf sbaJlow gas.zooes. . .. .NA RPC 6/29(2004 138 Seç¡bedcondition survey.(if Off-sho(e) . ...'. NA 39 . CQnta.ct namelpnoneJorweekly progress reports [explorç¡tolY O!lly). NA Geologic Engineering ~ Commissioner: Date: Commissioner: Date . ioner Date DT5 ( ! 30/1 Ý~y - e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . ~o4-((S RECE'VED/2 fe'67 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Sep 15 09:09:11 2004 SEP 2 8 2004 "\Iaska 011 & Gas Cons. Commission AnchOf8ge Reel Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/09/15 Origin.................. .STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.. ....... ............04/09/15 Origin. . . . . . . . . . . .. . . . . . . . STS Tape Name...... ..........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PBU/WOA MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA K-03B 500292101102 BP Exploration Sperry-Sun Drilling Services 15-SEP-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003190564 J. PITCHER R. BORDES MWD RUN 5 MW0003190564 J. BOBBITT J. RALL MWD RUN 6 MW0003190564 J. PITCHER J. RALL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW0003190564 J. BOBBITT J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 4 11N 14E 1728 1121 52.42 23.92 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 8559.0 8950.0 # REMARKS: . . 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. K-03B PBl WAS PLUGGED BACK TO THE 7" CASING SHOE AT 8950'MD AND A NEW SIDE- TRACK WAS EFFECTED BY TIME DRILLING. THE KOP FOR K-03B IS 8960'MD. NO DATA ARE PRESENTED FOR MWD RUNS 1, 3, AND 4. 4. MWD RUNS 2, 5 - 7 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND AT-BIT INCLINATION (ABI). 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 2' DOWNHOLE, PER E-MAIL FROM K. COONEY (SIS/BP) DATED 17 AUGUST 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 6. MWD RUNS 2, 5 - 7 REPRESENT WELL K-03B WITH API#: 50-029-21011-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11585'MD/8824'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name........ .....STSLIB.OOl Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/09/15 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8202.5 8561.5 8561. 5 8561.5 8561. 5 8561. 5 8592.5 STOP DEPTH 11533.5 11540.5 11540.5 11540.5 11540.5 11540.5 11587.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8202.5 GR 8200.5 . . 11587.0 $ 11585.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 2 5 6 7 MERGE TOP 8200.5 8950.0 9120.0 10310.0 MERGE BASE 8950.0 9120.0 10310.0 11585.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction........ .........Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units..... . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT!H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8202.5 11587 9894.75 6770 8202.5 11587 ROP MWD FT!H 0.13 1151.8 112.144 5990 8592.5 11587 GR MWD API 14.19 547.21 64.972 6346 8202.5 11533.5 RPX MWD OHMM 0.21 963.71 35.7879 5959 8561. 5 11540.5 RPS MWD OHMM 0.16 1430.95 42.9259 5959 8561.5 11540.5 RPM MWD OHMM 0.16 2000 50.2875 5959 8561.5 11540.5 RPD MWD OHMM 1.05 2000 68.81 5959 8561. 5 11540.5 FET MWD HOUR 0.19 86 2.69391 5959 8561.5 11540.5 First Reading For Entire File..........8202.5 Last Reading For Entire File...........11587 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04!09!15 Maximum Physical Record..65535 File Type................LO Next File Name. ........ ..STSLIB.002 Physical EOF File Header Service name...... ..... ..STSLIB.002 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04!09!15 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.OOl . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 8200.5 8559.5 8559.5 8559.5 8559.5 8559.5 8590.5 STOP DEPTH 8918.0 8910.5 8910.5 8910.5 8910.5 8910.5 8950.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN 25-JUL-04 Insite 66.37 Memory 8950.0 8590.0 8950.0 14.4 23.9 TOOL NUMBER 163686 157645 8.500 8559.0 LSND 10.20 45.0 9.3 900 3.7 .850 .440 .900 2.000 71.0 141.8 71. 0 71. 0 . . Max frames per record.............Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Uni ts . . . . . . . . . . . . . . . .. . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEFT FT 8200.5 8950 8575.25 1500 8200.5 8950 ROP MWD020 FT/H 1. 86 308.1 127.591 720 8590.5 8950 GR MWD020 API 42.95 156.16 111.598 1119 8200.5 8918 RPX MWD020 OHMM 0.62 4.61 1.58536 703 8559.5 8910.5 RPS MWD020 OHMM 1. 08 462.56 2.28 703 8559.5 8910.5 RPM MWD020 OHMM 1. 05 5.15 1. 6667 703 8559.5 8910.5 RPD MWD020 OHMM 1. 09 15.51 1. 75667 703 8559.5 8910.5 FET MWD020 HOUR 0.21 1.28 0.545846 703 8559.5 8910.5 First Reading For Entire File..........8200.5 Last Reading For Entire Fi1e...........8950 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/15 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name..... ..... ...STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/15 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS FET RPD RPX RPM GR ROP $ 3 header data for each bit run in separate files. 5 .5000 START DEPTH 8911.0 8911.0 8911. 0 8911.0 8911. 0 8918.5 8950.5 STOP DEPTH 9073.5 9073.5 9073.5 9073.5 9073.5 9067.5 9120.0 # LOG HEADER DATA . DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units................. . . . . . . Datum Specification Block sub-type...O 29-JUL-04 Insite 66.37 Memory 9120.0 8950.0 9120.0 8.9 13.6 TOOL NUMBER 91360 156401 6.125 8950.0 Flo-Pro 8.40 42.0 9.7 3800 7.4 1.200 .850 2.000 1. 200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FTIH 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD050 FTIH Min 8911 0.34 Max 9120 76.43 Mean 9015.5 34.3147 Nsam 419 340 . 70.0 101.0 70.0 70.0 First Reading 8911 8950.5 Last Reading 9120 9120 . . GR MWD050 API 22.79 547.21 123.45 299 8918.5 9067.5 RPX MWD050 OHMM 0.21 963.71 16.7771 326 8911 9073.5 RPS MWD050 OHMM 0.16 1430.95 33.7053 326 8911 9073.5 RPM MWD050 OHMM 0..16 2000 132.565 326 8911 9073.5 RPD MWD050 OHMM 1. 05 2000 306.072 326 8911 9073.5 FET MWD050 HOUR 1. 58 86 25.4441 326 8911 9073.5 First Reading For Entire File..........8911 Last Reading For Entire File...........9120 File Trailer Service name.. ....... ....STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/09/15 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.......04/09/15 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPS RPD RPM ROP $ header data for each bit run in separate files. 6 .5000 START DEPTH 9068.0 9074.0 9074.0 9074.0 9074.0 9074.0 9120.5 STOP DEPTH 10244.5 10251. 5 10251.5 10251.5 10251. 5 10251. 5 10310.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 30-JUL-04 Insite 66.37 Memory 10310.0 9120.0 10310.0 11. 0 89.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 151107 148579 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 . . DRILLER'S CASING DEPTH (FT): 8950.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-Pro 8.40 44.0 9.6 4850 7.5 1.200 .720 2.200 2.000 70.0 122.0 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units... . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHl'1M 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9068 10310 9689 2485 9068 10310 ROP MWD060 FT/H 2.28 1151.8 86.1516 2380 9120.5 10310 GR MWD060 API 14.19 137.21 48.4466 2354 9068 10244.5 RPX MWD060 OHMM 0.91 118.43 42.7477 2356 9074 10251.5 RPS MWD060 OHMM 1. 29 242.01 52.3746 2356 9074 10251. 5 RPM MWD060 OHMM 1. 96 616.53 57.0835 2356 9074 10251.5 RPD MWD060 OHMM 2.04 1829.59 72.7744 2356 9074 10251. 5 FET MWD060 HOUR 0.55 12.89 1.68331 2356 9074 10251. 5 First Reading For Entire File..........9068 Last Reading For Entire File...........10310 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number... . . . . . . . .1. 0.0 Date of Generation.......04/09/15 Maximum Physical Record..65535 File Type.......... ......LO Next File Name...........STSLIB.005 . Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04!09!15 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 5 . header data for each bit run in separate files. 7 .5000 START DEPTH 10245.0 10252.0 10252.0 10252.0 10252.0 10252.0 10310.5 STOP DEPTH 11531.5 11538.5 11538.5 11538.5 11538.5 11538.5 11585.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL 1FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH 1FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB!G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE IDEGF) MUD AT MEASURED TEMPERATURE IMT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): 01-AUG-04 Insite 66.37 Memory 11585.0 10310.0 11585.0 85.7 90.6 TOOL NUMBER 151107 148579 6.125 8950.0 Flo-Pro 8.50 44.0 9.5 4800 8.1 1. 200 .620 2.200 2.000 70.0 143.0 70.0 70.0 . . EWR FREQUENCY (HZ): # REMARKS: s # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point........ ..... .Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units...................... . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10245 11585 10915 2681 10245 11585 ROP MWD070 FT/H 0.13 272.47 142.42 2550 10310.5 11585 GR MWD070 API 32.35 86.44 53.022 2574 10245 11531. 5 RPX MWD070 OHMM 24.77 70.53 41.1666 2574 10252 11538.5 RPS MWD070 OHMM 29.84 70.36 46.5463 2574 10252 11538.5 RPM MWD070 OHMM 33.36 65.54 46.9255 2574 10252 11538.5 RPD MWD070 OHMM 37.69 75.93 53.4452 2574 10252 11538.5 FET MWD070 HOUR 0.19 14.01 1.32425 2574 10252 11538.5 First Reading For Entire File..........l0245 Last Reading For Entire File...........11585 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/09/15 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name.............LISTPE Date.....................04/09/15 Origin.................. .STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.... ........... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.. ...................04/09/15 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.......... ...... .ST8 LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File . .
