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Home My WebLink About201-197 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 JAN 0 3 2011 Nrita CMS. t ti &^� ��3 3,(111$ �� $$ Otl December 20, 2010 floorage Mr. Tom Maunder �� Alaska Oil and Gas Conservation Commission JAN 333 West 7 Avenue Anchorage, Alaska 99501 C) 1 1 917 Subject: Corrosion Inhibitor Treatments of GPB U Pad 0 ~ i S Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from U Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska Inc. ( as a) . c Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) U -pad Date: 12/20/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal U -01 1920110 50029222440000 NA 0.8 NA 3.4 1/12/2010 U -02A 1982390 50029211700100 NA 0.6 NA 1.7 1/12/2010 U -03 1841470 50029211730000 NA 0.4 NA 1.7 1/12/2010 U -05A 2090700 , 50029211920100 NA 0.6 NA 3.4 1/12/2010 U -06B 2050640 50029211170200 NA 1.9 NA 15.3 1/13/2010 U -07 1840900 50029211270000 NA 0.6 NA 5.1 1/13/2010 U -08A 1982020 50029211360100 NA 1.4 NA 8.5 1/13/2010 U -09A 198212b 50029211440100 NA 0.2 NA 1.7 1/13/2010 U -10 1851970 50029214230000 NA 7.7 NA 57.8 12/28/2009 U -11B 1931080 50029214200200 NA 0.8 NA 5.1 1/13/2010 U -12A 2041470 50029214090100 NA 0.6 NA 3.4 1/12/2010 U -13 1781010 50029203550000 NA 0.1 NA 3.4 1/12/2010 (4 U -14 1931000 50029223860000 _ NA 0.1 NA 1.7 1/13/2010 tJ -158 2011970 50029225650200 NA 1.4 NA 13.6 1/13/2010 RE: U-15B (PTD #2011970) Classified as Problem Well e e Subject: RE: U-1513 (PTD #2(11970) Class; flcd as Problem IV el\ \2ff'l \1, \ ~ Cç From: "NSLJ, ADW Wclllntegrity Engineer" <NSUADWWclllntegrityEngineer@;.BP.com> nate: Tim, 13 Oct 2005 20:03:27 -0800 To: "NSLJ, ADW Wclllntegrity Engincer" <NSUADWWcllrntegrityEnginccr@BP.com>, "Lucdkc-Chan, "Beverly (PRA)" <LucdkcB(t;£1BP.com>, "GPB, GC2 Area Mgr" <GPBGC2TL@ßP.com>, "i\SU, ADW Well Operations Supervisor" <NSCAD\VWeIlOperationsSupervisor@BP.com>, "Rossberg, R Steven" <RossbeRS@~BP.com>, "GPß, Wells Opt Eng" <GPBWel1s0ptEng(i.i;BP.com>, "AOGCC Jim Regg (E-mail)" <~jimJcgg@ad111in.statc.ak.us>, "AOGCC Winton Aubert (E-mail)" <winton.ßubert@admin.stale.ak.us>, "NSU, ADW WI. & Completion Supervisor" <NSUADW\\.'L&CompletionSupervisor@ßP.com>, "GPß, GC2 Well pad Lead" <GPBGC2WcllpadLcad@BP.com>, "GPB, Prod Controllers" <GPBProdControl1ers([~¿BP.com> All, Well U-15B (PTD #2011970) has been found to have sustained casing pressure on the inner annulus and has been classified as a Problem well. TIO pressures were 2020/2050/300 psi on 10/11/05 when the well failed a TIFL. The plan forward for this well is as follows: 1. SL: OGL V c/o in Sta #1 at 8728' MD 2. 0: Re- TIFL A well bore schematic has been included for reference. Please call if you have any questions. «U-15B.ZIP» Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Work: 1-907-659-5525 Pager: 1-907-659-5100 x1923 Email: robert.mielke@bp.com }:';';'I¡" l;',i'AHf\blc=¡' ''''wnu\j!''\J~,_j Content-Description: U-15B.ZIP Content-Type: applicationlx -zip-compressed Content-Encoding: base64 ..:¥l =: ?ÁJSV ~ : 7~\' , ("117ft f\}5C.c.. " ~ }.¡~ p:::. r S:cP ;;. 6c¿90 þ: Z't'Ô% ~~p ~' ò~ per> eo 4,c·tz.- 1 of 1 12/22/2005 4:36 PM e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicl1e\CvrPgs _ Inserts\Microfilm _ Marker.doc DATE OB/04r.15 02l05'{1 03/08A:!1 07/0 1 A:! 1 11iõ"1'm 1211J7A:!1 REV BY I(sB 515- Q,Ä.A S IS- tvD CHlKA.K SRB/tih GMT & WHIPSTOGK CTD SDElRACK(A TTE""'l) -:::Ot.lJv1ENTS ORIGINAL COMPLETION CONVERTED TO CANVAS FINAL CORREC1l0NS DATE 1212810 1 04/19102 REV BY C OMIv'ENTS CHITP CDRRECTIONS GCII<AK OH #3 CDRREC1l0NS SEC BP PRUDHOE BAY WEl..1..: lJ..15B PERMT N'J: 2\1'11970 API N~: 5O-D29-22565-1J2 19. T11N, R13E 5173' NSL & 1809' WEL Bcplor ortian (Alas k,;¡ UNIT I 5·1/2" LNR, 17#, 1.:8D, ID= 4.8..2" 10138' I U·15B SDTRI<#1 ( P&A' D) 10T11' J TOP OF 1STWHPSTOCK I~ I PBTD 9990' 9999' 10050' L ~ l OH SD1RK #3 FLLED W/MUD &JUNK 13-3/4" 5·112" MLLOUT WINDOW .( #1 ) 99¡;¡1'·991>7' (OFF WHIPSTOCK) "\ jIT0588' OH ~ 10759' I PERFORA 1l0N SUMfvlð.RY REF LO~: TC P PERF ANGLE AT TOP PERF: 55 @ l;rI7B' Note: Retet to Ptadu<otiot1 DB tot hb.totiè,,1 pelt d~b SIZE SPF INTERVAL - - 3-3Æ" 4 91ïB· 9216 3- 318" 4 9340· 940D 3-3Æ" 4 958D· 968D 3-3/8" 4 972D· 002D Opn/Sqz S S S S DATE 11101101 11101/01 11101/01 11101/01 ......~ r--- 11395' =3 I 5-112" MLLOUT WINDOW (#2) 0041' - 964Q' (WHIPSTOGI( @0041') \j·1!5B SD1RI(#2 (3.3/4" OH) J L 7·518' CSG, 29.7#, NSCC, ID = 6.875" 9086' l--4 .... 7-518" X4-1/2" BKR PKR W/ HMC HGR, D = 4.008" I 4112" 18G, 12.6#. L-80, .0152 bpf, D = 3.968" Ht i I I 4112" WLEG, ID = 3.96'8" I 8..MD TTNOT LOGGED 8932' 8934' I I . 8888' 8912' 8923' B93§' 7-518" X4-1/2" BKR SABI.:3 PKR, ID = 3.875" 41f.2" HES X NIP, ID = 3.813" I 4112" HES "-N NIP, MIl..1..ED OUT,ID =3.800" J ::8': r:::::;;:> Minim um ID = 3.800" @ 8923 4-112" HES XN NIP MILLED BY CTD I 8876' ~ GAS UFT MANDRELS ST tvD TVD DEV TYPE VLV LATCHIPORT - - 15 31ï2 3163 ï KBMG- M DV BK 0 5 5124 5070 20 KBMG- M DV BK 0 JJ 4 15639 6507 16 KBMG- M DV BK 0 3 7651 7483 '16 KBMG-M DV BK 0 2 84148214 18 KBMG-M DV BK 0 1 Bna 8502 27 KBMG- M DV BK 0 4112" HESX NIP, ID=3.813"J DATE D412ï/O 1 04/27/01 04/27/0 1 04/27/0 1 04/27/01 04/27/01 I TREE= W8..LHEAD = A GTUA TOR = K6. ELEV = B F. HEV = KOP= M~ At1~1e = DõitumMD= Dmum TVD = 10·3/4' CSG. 45.5#, NT·ao. ID = 9.e50" 41/1t1" GIW FMC BAKER 77.3' 46.8' 3D50' 108 @11157' 9242' 55 8800' 55 3036' e µ . U-15B 2213' SAFETY NOT ES: ORIGINAL we. L U· 15 WAS P&A'D W/ GMT & IS NOT SHOWN ON THIS DIAGRAM. U·15A EXGEEDS70"@930D' & GOESHORIZONTAL@9500' · SEVERAL ATTEMPTS TO SDTRKU-15A FAILED(lJ. 15Bl. UNABL ET 0 C LEAN- OUT HOL ET 0 T D to RUN LNR. WELL FP'DT02200' W/'5(J/fIJ METHANOL. --- 4112" HES HXO SSSV NIP, ID = 3.8·13"J 7 :J ~ -;LÓèJ '-( DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011970 Well Name/No. PRUDHOE BAY UNIT U-15B Operator BP EXPLORATION (ALASKA) INC :Sf¡ u\ ~ ').<f pJov ~ tM I API No. 50-029-22565-02-00 MD 11395 .----- TVD Completion Date 121712001.-/ Completion Status -- __H_- -------- --- - -~- 8762 r 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No (data taken from Logs Portion of Master Well Data Maint) DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Logi Electr Data Digital Dataset Typ_,: Med/Frmt Number C Pdf J1360 Name Log Log Run Scale Media No 1 ¡ I ~D !'SÐ- I ! ¡ Rpt í i Rpt I D D <-11084 '-11083 1 1 1 1 Well Cores/Samples Information: Name Interval Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? Y I~ Directional survey- -Nc-_1~- ------- - -'- Interval OH / Start Stop CH Received Comments --- - . -- -- ---- 9637 11395 Case 12/3/2002 Digital Well Log Data, including PB1 PB1 9977 1 0727 Case 9/27/2002 9636 11352 Case 9/27/2002 9636 11352 Case 9/27/2002 9977 1 0727 Case 9/27/2002 PB1 Sample Set Number Comments ---~"- Daily - History Received? ~ N Formation Tops WN Chips Received? Y I t4 Analysis Received? - '(iN _____n- - ------ Comments: Compliance Reviewed By: ~ Date: ~ J:-l&~'-f n___- ( ~: c9o/-/917 ! 18 (Po WELL LOG TRANSMITI AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn. : Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 02, 2002 RE: MWD Fonnation Evaluation Logs U-15B & U-15B PBl AK-MW-11193 U-15B: Digital Log Images: 50-029-22565-02 1 CD Rom U-15B PBl: Digital Log Images: 50-029-22565- 72 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~~ VE\) RECE\ DE CO:) 2.002. M ~a o~, &. Gas coos.CQmmiMton ~a~!i Ançborage Sc~lußlbepgep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Log Description Date Job# 2H-09 1 Q-09 1C-125 2H-12 2T -39 1 B-04 3A-12 3A-13 2K-02 3N-07 2M-O1 1C-119 PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE 1- INJECTION PROFILE ,.~ STATIC PRESSURE SURVEY ..... ~ W'I STATIC PRESSURE SURVEY 1 PRODUCTION PROFILE J r O~ g-- LEAK DETECTION LOG [ PRODUCTION PROFILE dDI-I J INJECTION PROFILE 08/29/02 09/04/02 09/11/02 09/07/02 09/09/02 09/04/02 08/31/02 08/31/02 09/08/02 08/30/02 09/13/02 09/05/02 5IGN~ ~~ DATE: NO. 2433 Company: Field: BL Sepia 09/23/02 Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk -- CD Color 1 1 1 1 1 1 1 1 1 1 1 1 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ~, RECE'VED OCT 0 1 200l AlaIka Oil I Gal Coni. ConII8IiJn MdMn98 ~ do/-/91 110'[3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tll Avenue, Suite 100 Anchorage, Alaska September 26, 2002 RE: MWD Fonnation Evaluation Logs U-15B, AK-MW-11193 1 LDWG fonnatted Disc with verification listing. API#: 50-029-22565-02 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signe~ (A.~ Date: IY~CE:ltI~D 8£p 2 AI-a Qtt. ? 2002 ~I & Gas Aß Cot}s, GO. . rdlorage If11flJ/B8iol1 ( ( WELL LOG TRANSMITI AL ~O/- /97 IIO'(~ To: September 26, 2002 State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs U-15B PBl, AK-MW-11193 1 LDWG formatted Disc with verification listing. llPI#: 50-029-22565-72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~l~ RECEIVED SEP27 2002 Alaska O¡.¡ & Gas Cons. Commission Anchorage l ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMIt>$ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-197 301-343 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22565-02 4. Location of well at surface . "" -, Il~l<oNS 9. Unit or Lease Name , ". '. ~..I\ I 5172' NSL, 1808' WEL, SEC. 19, T11N, R13E, UM ~ ::':'~ ~ Prudhoe Bay Unit At top of productive interval ; -,-;.:...£:.O) ."j SuG.- ~ 1671' NSL, 4735' WEL, SEC. 18, T11N, R13E, UM t', I r ; ~ 10. Well Number ' ,. "1 C . -r 1 At total depth ¡ ":&t ,: ¡ $.;I~~-=-~~' U-15B 1675' NSL, 665' EWL, SEC. 17, T11N, R13E, UM '-""r.......~... c:::::--=--_........:.:..::J 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 76.10' ADL 028283 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 11/28/2001 12/3/2001 12/7/2001 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11395 8762 FT 11395 8762 FT ~Yes ONo (Nipple) 2214' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES 23. CASING. LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# NT80LHE 29' 3036' 13-1/2" ß40SX cs III, 375 SX 'G', 190sx CS II 7-5/8" 29.7# 13Cr80/NT95HS 27' 9086' 9-7/8" 1265 sx Class 'G' 5-1/2" 17# L-80 8932' 9641' 6-3/4" 1260 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/4" Open Hole 4-1/2", 12.6#, L-80 8936' 8889' MD TVD MD TVD 9641' - 11395' 8922' - 8762' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 33 Bbls of MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 21,2002 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology. porosity, fractures, apparent dips and presence of oil. gas or water. Submit COR'ËC E I VE 0 No core samples were taken. FEB 2 7 2002 Alaska Oil & Gas Cons. Commission '"~ 0 Anchorage Form 1 0-407 Rev. 07-01-80 '\i1"1~li"~ìl'!~F~t ~r Submit In Duplicate " iJ".;\~ r V-~i ~ ~ '1' (L.J't, ~, ,"" '. /¡ "'w.... lJ~~~ I' .. ( (' 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top of Sadlerochit 11269' 8790' 31. List of Attachments: Summary of Daily Drilling Reports and Surveys were attached to the 10-404 dated 01/16/02. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ r\¡ J a.a.Pz.. Title Technical Assistant Date O~. 'íÁ 7 . O_C?l U-15B Well Number 201-197 301-343 Permit No. / Approval No. Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 (" STATE OF ALASKA t ALASKAuIL AND GAS CONSERVATION COMM1\:)~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: II Operation Shutdown D Stimulate D Pull Tubing D Alter Casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 D Plugging D Perforate D Repair Well D Other 5. Type of well: aa Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (OF or KB) KBE = 76.10' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 5172' NSL, 1808' WEL, SEC. 19, T11N, R13E, UM At top of productive interval 1671' NSL, 4735' WEL, SEC. 18, T11N, R13E, UM At effective depth 1675' NSL, 665' EWL, SEC. 17, T11N, R13E, UM At total depth 1675' NSL, 665' EWL, SEC. 17, T11N, R13E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8. Well Number U-15B 9. Permit Number / Approval No. 201-197 301-343 10. API Number 50- 029-22565-02 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 11395 feet 8762 feet 11395 feet 8762 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 260 sx Arcticset (Approx.) 110' 110' 940 sx CS III, 375 sx 'G', 190 sx CS II 30361 3029' 265 sx Class "G' 90861 8787' 260 sx Class 'G' 8932' - 96411 8677' - 8922' 1101 20" 3007' 10-3/4" 9059" 7-5/8" 12061 5-1/2" Perforation depth: measured None - Open Hole 9641' to 113951 with an inadvertent sidetrack from 10590' to 10727' true vertical None Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 89361 Packers and SSSV (type and measured depth) 7-5/8" Baker "SABL-31 packer at 88891; 4-1/2" SSSV Landing Nipple at 22141 : , 13. Stimulation or cement squeeze summary Intervals treated (measured) ,JAN 1. 6 2002 Treatment description including volumes used and final pressure i~laska Oil ,& Gas Cons. 'Commission ~\ncho~?ge 14. Representative Dailv Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 181 Copies of Logs and Surveys run aa Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Si ned Terrie Hubble ~ ... Title Technical Assistant 16. Status of well classifications as: 181 Oil 0 Gas 0 Suspended Service Date 01" (~.D~ Form 10-404 Rev. 06/15/88 Prepared By Name/Number: Terrie Hubble, 564-4628 Submit In Duplicate JAN 2 2 2002 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/18/2001 11/19/2001 11/20/2001 11/21/2001 ( ( BP EXPLORATION Operations Summary Report U-15B U-15B RE ENTER NABORS NABORS 38 From - To Hours Activity Code NPT 00:00 - 03:00 03:00 - 09:00 09:00 - 22:00 22:00 - 22:15 22:15 - 22:37 22:37 - 22:45 22:45 - 23:15 23: 15 - 23:45 23:45 - 00:00 00:00 - 01 :35 01 :35 - 03:45 03:45 - 09:15 09:15 -11:45 11:45-12:15 12:15 - 14:30 14:30 - 18:30 18:30 - 20:00 20:00 - 20:15 20:15 - 22:35 22:35 - 00:00 00:00 - 02:30 02:30 - 04:30 04:30 - 05:04 05:04 - 05:30 05:30 - 13:30 13:30 -15:20 15:20 - 16:00 16:00 - 17:30 17:30 - 21:20 21 :20 - 22:30 22:30 - 23:10 23:10 - 00:00 00:00 - 05:00 Phase 3.00 RIGU 6.00 RIGU P P PRE PRE 13.00 RIGU P PRE 0.25 RIGU P 0.37 RIGU P 0.13 RIGU P 0.50 RIGU P 0.50 RIGU P 0.25 RIGU P 1.58 RIGU P 2.17 STWHIP P PRE PRE PRE PRE PRE PRE PRE WEXIT 5.50 STWHIP P WEXIT 2.50 STWHIP N 0.50 STWHIP N WEXIT WEXIT 2.25 STWHIP N 4.00 STWHIP N WEXIT WEXIT 1.50 STWHIP N 0.25 STWHIP N 2.33 STWHIP N 1.42 STWHIP N 2.50 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT 2.00 STWHIP P WEXIT 0.57 STWHIP P WEXIT 0.43 STWHIP P 8.00 STWHIP P WEXIT WEXIT 1.83 STWHIP P 0.67 STWHIP P WEXIT WEXIT 1.50 STWHIP P 3.83 STWHIP P 1.17 STWHIP P WEXIT WEXIT WEXIT 0.67 STWHIP P 0.83 STWHIP P 5.00 STWHIP P WEXIT WEXIT WEXIT Page 1 of 11 Start: 11/17/2001 Rig Release: 12/7/2001 Rig Number: Spud Date: 11/18/2001 End: 12/7/2001 Description of Operations MIRU Nabors 3S. Accept rig at 0300 hrs 11-18-2001. NU bop's set in backside hardline. Test bop's. Notified AOGCC. Witnessing wavied by Chuck Shieve. (DS unit #4 on location at 0900 hrs. Rig up same. Cut-off 750' coil.Had to rebuild one valve in choke manifold. RD cutter RU coil connector. Pull test coil connector. Pull BPV. Change packoff Pressure test coil connector, inner real valve and hardline. Pressure test MHA RIH with cement milling BHA to 9583' first stringers at 9574'. Milling wi 1/2# Bio. Free spin 1460 psi at 2.5 bpm. 1600-1700 psi on bottom 12-18'/hr. Milled f/9574' to 9606'. Unable to stall motor only 200 psi motor work, might be TOH (work on levelwind) Cement mills inserts worn down 1/4 of the way. PIU parabolic diamond mill and change out motor. (old motor looked okay). PT MHA TIH Mill cement f/9606'. 2.7/2.72000 off bottom 2200 on. 20'/hr slowing to 10'/hr. Pumping bio sweeps. Mixing 35 pill with 3% lube-tex. Pumping 2 bbl sweeps every 10 mins - helping some. ROP < 10'/hr avg. unbearable! TOH Change out speed mill for PDC Bit RIH to 9634. Drilling cement at 2.6bpm 1960 psi. ROP=20ftlhr Drill cement at 9700 2.6 bpm at 1845 psi ROP 14 ftlhr. Sweep every 10' with 5 bbl pill short trip every 20 '. Drilling cement at 9770 2.6 bpm at 1783 psi ROP 42 ftlhr short tripping to toc and sweeping hole every 15' with 5bbl pill. Drilling at 9790 at 2.6 bpm at 1780 psi ROP 50+ in perforations last set. Flow check pick up 200' shut down pump. Well stable. Drill at 9800' at 2.6 bpm with 1854 psi ROP 27-40'/hr. Short trips to TOC every 40'. Pumping 1.5 bbls bio sweeps every 10'. Drill cement to 9972'. No losses noted. POOH. LD motor and PDC bit. Bit has even wear (gage, shoulder, and even nose cutters). No broken cutters. Same 3.77 gage. MU motor, SM, tapered DSM. RIH. Sat down 9630'. Mill sheath from 9630' to 9972' at about 100 FPH. Drill cement 2.6 bpm 2874psi ROP 27 from 9972 to 9996.8' to whipstock tray. Pressure increase, ROP decrease here. Short trip to 9200'. Mill window @ 2.7 bpm with (3080 psi free spin) 3550 psi Mill window 9,997' to 10,000' CTM at 2.7 bpm and 3370 psi ( free spin 3150 psi). WeB 2-8m. At 10,000', saw pressure Printed: 12/10/2001 11: 16:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/21/2001 11/22/2001 ( (' .. Page 2 of 11 BP EXPLORATION Operations Summary Report U-15B U-15B RE ENTER NABORS NABORS 3S 00:00 - 05:00 From - To Hours Activity Code NPT WEXIT 05:00 - 07:00 07:00 - 07:30 07:30 - 09:00 09:00 - 11 :00 11 :00 - 11 :50 11:50 -12:15 12:15 -13:15 13:15 -14:15 14:15 - 15:00 15:00 - 15:45 15:45 -18:00 18:00 - 00:00 00:00 - 03:40 03:40 - 05:00 05:00 - 09:00 09:00 - 10:30 10:30 - 11 :30 11 :30 - 18:00 18:00 - 19:15 19:15-21:15 21 :15 - 23:15 5.00 STWHIP P 2.00 STWHIP P 0.50 STWHIP P 1.50 DRILL 2.00 DRILL 0.83 DRILL 0.42 DRILL 1.00 DRILL 1.00 DRILL 0.75 DRILL 0.75 DRILL 2.25 DRILL 6.00 DRILL 3.67 DRILL 1.33 DRILL 4.00 DRILL 1.50 DRILL 1.00 DRILL 6.50 DRILL 1.25 DRILL 2.00 DRILL 2.00 DRILL Phase WEXIT WEXIT P PROD1 P P P P PROD1 PROD1 PROD1 PROD1 P PROD1 P PROD1 N P P DFAL PROD1 PROD1 PROD1 P PROD1 P P PROD1 PROD1 P PROD1 N SFAL PROD1 P PROD1 P N PROD1 SFAL PROD1 P PROD1 Start: 11/17/2001 Rig Release: 12/7/2001 Rig Number: Spud Date: 11/18/2001 End: 12/7/2001 Description of Operations spike and wt fell off. Acting like formation starting here. Drill to 10012'. Ream and backream window. No motor work. Dry tag clean thru window. Spot pill. POH LD milling BHA. Normal wear on DSM (3.78" CD). Minimal wear on string mill (3.80" OD). MU drilling BHA (#5): DS49, 1.1 deg Anadril motor, Sperry MWD, Schl TORC orienter. RIH. Log tie-in at 9730' GR. Correct depth (-8'). RIH with 60L TF. Tag and fell thru 9997'. Tag TD 10006'. Start drilling 2.5/2875 to 10017'. TF wandered to 135L and did not correct itself back to 60L. Maybe in a bind. PUH above window and check TF. Still at 135L. Clean pits and swap well over to Fro-pro. Check TORC. OK in continuous rotating mode. Send TF command -- good. Must have just lost itself. Drill starting with 30L TF. Shifted to 135L. Drill to 10026'. Seeing 92 deg inc. Stalled and TF shifted to 180. Saw RA at 9999' corrected. Top of whipstock 9990', top of window 9991', bottom of window 9997'. PUH above window to reset TF high left. Drilling slow. Stalls easy, then shifts to 135L. Drilled slow to 10080 until BHA cleared window. Drill ahead to 10,138' Still experiencing magnatic interferance from old well bore. Shoe of old liner at 10138'.Some reported problem with TORC not holding tool face. Directionally drilled to 10224'. Had interference from old well bore until 1 0170' MD. End of old liner 10138'. Shublik deeper than predicted. At 10224' start experiencing loss at 40 bph. Advised Ted Stagg. Will switch to KCL water as mud inventory decreases. Currently have 179 bbl mud and 600bbl KCL on location. Drill 2.8 bpm 2850 psi ROP 36 ftIhr loss rate .4 bpm Losses steady at 14 BPH. Continue drilling with mud. Looks like we're still in the Shublik or got knocked back into it after crossing a fault. Shoot for 8832' SSTVD (about 15' below plan line). Drill to 10310'. Wiper to window. Pulled heavy wlo motor work at 10100'. RIH and sat down here with motor work. Ream area. Wiper to 9200' (60 deg). RIH. Slight MW at 10100' shale. Dowell software problem. Troubleshoot. Rates, ROPS, pressures are all over the place. Nabors pump RPM staying constant, so still able to control TORC orienter. Drill 10 - 30 FPH to 10318'. Hot shale at 10285' tough to get back down through. Requires RIH dry to get thru. Continue drilling. Losses 10 -20 BPH. Made it to 8832' SSTVD. Still in Shublik. Continue dropping at 87 deg inc. Looks like we got into 24 at 10380'. Drill to 10430'. Wiper to window.9950 Trouble shoot and repair mirco motion flow data. Grounding issue caused stray voltage. RIH to 10307 multiple attempts to work thru at 90degrees RT. Printed: 12/10/2001 11: 16:53 AM ( (' - "-. BP EXPLORATION Page. 3 of 11 Operations Summary Report Legal Well Name: U-15B Common Well Name: U-15B Spud Date: 11/18/2001 Event Name: RE ENTER Start: 11/17/2001 End: 12/7/2001 Contractor Name: NABORS Rig Release: 12/7/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/22/2001 21:15 - 23:15 2.00 DRILL P PROD1 RIH to 10430 23:15 - 00:00 0.75 DRILL P PROD1 Directionally drilling at 10,430' 11/23/2001 00:00 - 03:00 3.00 DRILL P PROD1 Directionally drilling at 2.8bpm 2958 psi (free spin 2750psi) to 10,500'. ROP 30 fph loss rate 16 bpm. Experiencing problems with the DS pump controller. Running pump from the rig floor. 03:00 - 03:30 0.50 DRILL P PROD1 Attempt to go back to conputer control of pump while continuing to drill ahead. Drilled to 10508. Need to make tool face correction. 03:30 - 04:00 0.50 DRILL P PROD1 Wiper trip to shoe.tight at 10308-10283 pulled 7 over 04:00 - 08:15 4.25 DRILL N SFAL PROD1 Wait on DS Instrument technision to correct DS Pump controller. Could not fix. Will try to use Dowell pump and hope that the noise doesn't affect MWD signal. 08:15 - 08:30 0.25 DRILL P PROD1 RIH with pumps. Sat down at 10305'. PU. RIH dry clean. Hole in pretty good shape. 08:30 - 09:30 1.00 DRILL P PROD1 Orient. 09:30 - 09:45 0.25 DRILL P PROD1 Currently at 8837' SSTVD in 24. Plan to start bringing it up with right turn. Drill to 10515'. 09:45 - 10:30 0.75 DRILL N SFAL PROD1 Lost control of Dowell pump. Tripped. Pull to window. Fix. RIH. 10:30 - 15:15 4.75 DRILL P PROD1 Drill to 10650' 15:15 -16:15 1.00 DRILL P PROD1 Wiper to window. Overpull and MW in1 0520' shale and 10300' shale. Ratty at same spots RIH. 16:15 - 18:00 1.75 DRILL P PROD1 Drill to 10700' 18:00 - 20:45 2.75 DRILL P PROD1 POOH to put on resistivity. 20:45 - 00:00 3.25 DRILL P PROD1 Change out bit, motor, MWD and TORC 11/24/2001 00:00 - 03:00 3.00 DRILL P PROD1 RI H to 9700' 03:00 - 04:40 1.67 DRILL P PROD1 Tie in log. Correct depth (-11'). 04:40 - 05:00 0.33 DRILL P PROD1 RIH. 05:00 - 07:30 2.50 DRILL N DPRB PROD1 Attempt to get thru 10305' shale. Tried multiple TF's. Spot 7% lubetex pill. Finally got it thru. Packed off in choke line a couple of times -- shale. 07:30 - 07:45 0.25 DRILL P PROD1 RIH. No other tough spots. Tag TD 11693'. 07:45 - 10:00 2.25 DRILL P PROD1 Cycle pumps to get in fast sampling mode. Log real time resistivity to window at 300 FPH. RIH. Sat down 10080'. 10:00 - 11 :00 1.00 DRILL N DPRB PROD1 Work to get thru shale at 10080'. Backream. 11 :00 - 11 :30 0.50 DRILL P PROD1 RIH. Made it thru 10300' shale without too much trouble. 11 :30 - 16:30 5.00 DRILL P PROD1 Drill. Starting out in more shale, slow drilling. Drill to 10771'. Back in Shublik. Need to plugback. 16:30 -18:00 1.50 DRILL C PROD1 POOH for plugback. Overpull and motor work starting at 9530' (in horizontal 500' above window). Slow down and keep rate up. Wash to 60 deg. Wash down again. 18:00 - 18:15 0.25 DRILL C PROD1 Log tie-in. Correct depth (+6'). Flag pipe 9500' EOP. 18:15 -18:30 0.25 DRILL C PROD1 POOH. Overpull, motor work, packed off, stuck in tail pipe 8900'. Work free. POOH. 18:45 - 20:30 1.75 DRILL C PROD1 POH to surface. LD drilling BHA. 20:30 - 21 :30 1.00 DRILL C PROD1 Discuss plan forward. Anch reviewing options. 21 :30 - 00:00 2.50 DRILL C PROD1 Finish LD BHA and pick up underreamer assembly. 11/25/2001 00:00 - 01 :38 1.63 STWHIP C WEXIT RIH with underreamer top of cement sheath at 9558. 01 :38 - 03:00 1.37 STWHIP C WEXIT Change over to water High pump pressure tripping pop-off. 03:00 - 04:00 1.00 STWHIP C WEXIT Mill to 9580 pump sweep. 04:00 - 04:48 0.80 STWHIP C WEXIT Short trip to 9500 OK. 04:48 - 06:45 1.95 STWHIP C WEXIT Underream to 9800', 3250 psi at 2.3 bpm. Losses about 10 BPH with KCL water. Printed: 12/10/2001 11: 16:53 AM .- BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: U-15B Common Well Name: U-15B Spud Date: 11/18/2001 Event Name: RE ENTER Start: 11/17/2001 End: 12/7/2001 Contractor Name: NABORS Rig Release: 12/7/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/25/2001 06:45 - 08:30 1.75 STWHIP C WEXIT POOH. Pull heavy in tail pipe again at 8942' and 8928'. Push negative to pop free. 08:30 - 09:30 1.00 STWHIP C WEXIT LD underreamer. Significant wear, but blades still measure 4.75" +. 09:30 - 10:00 0.50 STWHIP C WEXIT Set TWC. 10:00 -16:00 6.00 STWHIP C WEXIT Perform weekly BOP test. Witness waived by AOGCC's Lou Grimaldi. 16:00 - 17:30 1.50 STWHIP C WEXIT Pull TWC. Cement on top of plug (from cycling rams). Stab coil and jet top of TWC. Pull TWC. 17:30 - 18:00 0.50 STWHIP C WEXIT Unload tools. 18:00 - 18:30 0.50 STWHIP C WEXIT PJSM and handover. 18:30 - 20:10 1.67 STWHIP C WEXIT Pressure test MHA & PU BHA 20:10 - 22:28 2.30 STWHIP C WEXIT Correct to flag at 9500' PU to 9440. 22:28 - 23:55 1.45 STWHIP C WEXIT Tie in. No correction. 23:55 - 00:00 0.08 STWHIP C WEXIT TORC tool successfully oriented the tool face to high side on start up of the pump. The whipstock held position thru tie-in (straight up).Slight orientation change after setting on depth. Whipstock set 10R. Set whipstock. 11/26/2001 00:00 - 02:00 2.00 STWHIP C WEXIT POH with BHA#8 after setting whipstock. Immediately after changing over to the Nabors pump, plugged the BHA. Pump slow thru coil and well via backside. 02:00 - 03:10 1.17 STWHIP C WEXIT LD BHA FAIV plugged 03:10 - 05:30 2.33 STWHIP X SFAL WEXIT Hydraulic leak in line to chain tensioner. WO mechanic. Fix. 05:30 - 06:30 1.00 STWHIP C WEXIT MU nozzle. 06:30 - 08:30 2.00 STWHIP C WEXIT RIH. correct depth at old flag (+51'). Huge correction??? RIH and tag whipstock pinch point 9645'. Stack 5k. PU overpull. Repeat. No movement. 08:30 - 09:30 1.00 STWHIP C WEXIT PUH 10'. Perform inj test. 1.0 BPM, 940 psi. 1.5 BPM, 1150 psi. 2.0 BPM, 1260 psi. 09:30 - 10:30 1.00 STWHIP C WEXIT RU cementers 10:30 - 11 :00 0.50 STWHIP C WEXIT Safety meeting. 11:00 -12:00 1.00 STWHIP C WEXIT Pump 10 bbls 13.8 ppg. Circulate to nozzle (9636') at 2.8 BPM; 1200 psi CTP. SI backside. Bullhead cement past whipstock 1.9 BPM; 1330 psi WHP. Pressure response with cement at fault. Final squeeze -- 0.3 BPM; 1500 psi WHP. Left 4 - 5 bbls of cement above fault. 12:00 - 12:30 0.50 STWHIP C WEXIT Pump bio water. Wash whipstock face clean. 12:30 - 14:30 2.00 STWHIP X STUC WEXIT POOH at 2.7 BPM. Pulled heavy and packed off 8810'. Work pipe in both directions, able to get about 10' of free movement but still packed off with zero returns. Made progress, then lost progress in both directions -- all with no returns. Surge well by pressuring-up coil and CTlTub annulus, then dump the pressure. Made progress. Gained 50' of movement, still packed off. Repeat surging several times, started seeing an intermittent trickle at pits, and finally dragged free and got full returns. Because of pack-off, cement is overdisplaced by lots and lots and lots. 14:30 - 16:30 2.00 STWHIP C WEXIT POOH. BU samples showing fine grained shale and cement. 16:30 - 17:30 1.00 STWHIP C WEXIT LD nozzle. MU window milling BHA. (#10) 17:30 - 19:50 2.33 STWHIP C WEXIT RIH to 9577 mill thru bridge. Correct depth at flag (-14'). Mill stringer with 2.3 bpm at 1530 psi from 9605 to pinch point at 9641. Loss rate 6 bph. 19:50 - 00:00 4.17 STWHIP C WEXIT Mill window 9641 to 9644.7 Free Spin 1600psi, Milling at 1800 { ( (' \ Printed: 12/10/2001 11: 16:53 AM ( (" BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: U-15B Common Well Name: U-15B Spud Date: 11/18/2001 Event Name: RE ENTER Start: 11/17/2001 End: 12/7/2001 Contractor Name: NABORS Rig Release: 12/7/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/26/2001 19:50 - 00:00 4.17 STWHIP C WEXIT psi at 2.6 bpm. Loss rate 5-9 bph. 11/27/2001 00:00 - 07:45 7.75 STWHIP C WEXIT Continue milling window with sweeps to 9949'. Drill formation 30 FPH to 9960'. 07:45 -10:15 2.50 STWHIP C WEXIT Ream window. Swap well to Flo-Pro. Check losses -- 12 BPH. Dry tag 9661' clean. 10:15 -11:30 1.25 STWHIP X DPRB WEXIT Pump 15 bbl LCM pill: 5 ppb OM Seal Fine; 7.5 ppb Safecarb med (CaC03); 7.5 ppb Mix II Fine. Circulate to bit. SI backside and squeeze past whipstock 1.3 BPM; 1100 psi WHP initial and 0.2 BPM; 2000 psi WHP final. Pill passed easily thru motor. Squeezed a total of 10 bbls past whipstock, but must have bridged across whipstock because the lead of the pill was about 1 bbl short of the fault at final conditions. Wash across whipstock to TD 9660' on choke at 600 psi WHP. Full returns. 11 :30 - 13:30 2.00 STWHIP C WEXIT POOH. Pulled heavy and stalled 8810'. Worked free. Pulled heavy and stalled 8710'. Worked free. POOH. Chasing debris all the way out. Plugged MM. Bypass. Shakers puking large amounts of shale with carbolite. 13:30 - 14:00 0.50 STWHIP C WEXIT Safety meeting. 14:00 - 14:30 0.50 STWHIP C WEXIT LD milling BHA. Mills in gage, normal wear. Marble size chunks of cement impregnated with proppant stuck in string mill blades. 14:30 - 16:00 1.50 STWHIP C WEXIT MU drilling BHA. 16:00 - 17:30 1.50 STWHIP X DPRB WEXIT LD drilling BHA. Lots of expensive stuff. Nervous about hole conditions. Will make another motorlmill run to assess conditions. MU motor and diamond whipstock mill. 17:30 - 20:10 2.67 STWHIP X DPRB WEXIT RIH. Full pump rate 8500' to TD at 9660' (made -21' correction here). No motor work, clean RIH weight. 20:10 - 20:35 0.42 STWHIP X DPRB WEXIT POOH at 3.0 BPM. Flag pipe 9200' EOP. Slight overpull at 9400' - 9390' but no motor work. OP + MW at 9200'. 20:35-21:15 0.67 STWHIP X DPRB WEXIT Continue to POOH and saw overpull and motor stall at 9204'. Continue to pull up to 8750' (inside the tubing) without any more overpull or motor work. Drop back down to 9500' to wipe the hole again and saw a weight bobble and some motor work at 9400'. Pick back up on coil from 9500'. Did not see any overpull or motor work at 9390'-9400'. Continue to pull up hole to 9190' and saw motor work and over pull. Also, cutting packed off in the micro-motion at surface. Collected a sample that appeared to be cement with a small amount of scale and shale. 21 :15 - 23:00 1.75 STWHIP X DPRB WEXIT Run back down hole to 9217' to wipe the casing again. Pick up from 9217' and saw motor work and overpull from 9217' to 9172'. Run back down hole to 9450' without seeing any motor work. Pick back up hole to 9150' without seeing any motor work or over pull. Circulate bottoms up at 9150' and returns to surface were clean. 23:00 - 00:00 1.00 STWHIP X DPRB WEXIT POOH with mill and motor. 11/28/2001 00:00 - 01 :30 1.50 STWHIP X DPRB WEXIT Continue to POOH with diamond mill assy. 01 :30 - 02:00 0.50 STWHIP X DPRB WEXIT Lay down diamond mill assy. 02:00 - 02:30 0.50 DRILL C PROD1 Make up drilling BHA. 02:30 - 03:30 1.00 DRILL C PROD1 Surface test TORC tool. 03:30 - 03:55 0.42 DRILL C PROD1 Repair depth counter on injector. 03:55 - 04:30 0.58 DRILL C PROD1 RIH to 3000' and shallow hole test the MWD. Sperry tools tested ok. However, the pump will not properly send the signal Printed: 12/10/2001 11 :16:53 AM BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: U-15B Common Well Name: U-15B Spud Date: 11/18/2001 Event Name: RE ENTER Start: 11/17/2001 End: 12/7/2001 Contractor Name: NABORS Rig Release: 12/7/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/28/2001 03:55 - 04:30 0.58 DRILL C PROD1 to the TORC tool. 04:30 - 05:15 0.75 DRILL X RREP PROD1 Trouble shoot and repair problem with pumps. 05:15 - 05:40 0.42 DRILL C PROD1 Shallow hole test TORC tool. OK. 05:40 - 07:00 1.33 DRILL C PROD1 Continue to RIH with drilling BHA. Correct depth at flag (-15'). 07:00 - 07:30 0.50 DRILL C PROD1 Log tie-in at 9413' GR spike. Correct depth (+12'). 07:30 - 07:45 0.25 DRILL C PROD1 RIH. Tag 9665'. 07:45 - 12:00 4.25 DRILL C PROD1 Drill, starting high right. Swap to Nabors pump to disconnect 4" v line to install new axle on the rig. Drill to 9850'. Full returns. 12:00 - 12:15 0.25 DRILL C PROD1 Wiper to window 3.0 BPM. 12:15 - 16:00 3.75 DRILL C PROD1 Drill with full returns to 10030'. 16:00 - 18:30 2.50 DRILL C PROD1 POOH for resistivity 3.0 BPM; 3000 psi 18:30 - 19:00 0.50 DRILL C PROD1 PJSM prior to pulling BHA to the rig floor. 19:00 - 21:30 2.50 DRILL C PROD1 Pick up Resistivity tool and program on the rig floor. 21:30 - 22:15 0.75 DRILL C PROD1 RIH with drilling BHA with Sperry resistivity tool. 22:15 - 22:30 0.25 DRILL C PROD1 Shallow hole test MWD and orienter. Ok. 22:30 - 23:30 1.00 DRILL C PROD1 Continue to RIH with drilling BHA. 23:30 - 00:00 0.50 DRILL C PROD1 Tie-in with coil flag. Subtract 12' from coil depth. Tie in to Gamma ray at 9414'. 11/29/2001 00:00 - 00:15 0.25 DRILL C PROD1 Continue tie-in with the gamma ray. Add 8' to coil length. 00:15 - 00:35 0.33 DRILL C PROD1 RIH and tag TD at 10,030'. 00:35 - 03:20 2.75 DRILL C PROD1 Orient tool face to 90 R. Had some difficulties getting signal to the TORC tool due to the orifice setting in the pulser. Drill ahead to 10,123'. 03:20 - 03:40 0.33 DRILL C PROD1 Wipe the hole to 9920'. 03:40 - 05:30 1.83 DRILL C PROD1 Drill ahead to 10,162' 05:30 - 06:00 0.50 DRILL X RREP PROD1 Dowell's triplex pump went down. Suspect problem was fuel tank being run too low and sucking air into the fuel pump. Ordered out an additional fuel delivery each day to eliminate the problem in the future. 06:00 - 07:00 1.00 DRILL C PROD1 Wiper trip to the window. Memory logged the section of the hole from 9650' to 10,050' while making the wiper trip. 07:00 - 10:30 3.50 DRILL C PROD1 Drill. Failed packing on Dowell pump. Switch to nabors pump. Continue drilling in rotation mode to 10263'. In shale. Stacking. 10:30 - 11 :00 0.50 DRILL C PROD1 Wiper trip to window 11:00 -15:00 4.00 DRILL X SFAL PROD1 Need to lock in TF -- finish getting Dowell pump ready. Lines froze. Steam to thaw. 15:00 -15:30 0.50 DRILL C PROD1 RIH. 10215' shale is sticky. Likely 24 shale, as samples don't suggest Shublik. 15:30 - 17:30 2.00 DRILL X SFAL PROD1 Orient. Unable to execute TF command. MM rates bouncing all over the place. Also, bad MWD detection. Also, bad day. Call DS technician. 17:30 - 20:00 2.50 DRILL C PROD1 Finally got a TF command to take. Drill ahead to 10,303'. Hole is taking mud at a rate of about 12 BPH. 20:00 - 20:10 0.17 DRILL C PROD1 Wiper trip into the tubing tail. 20:10 - 21:35 1.42 DRILL X SFAL PROD1 Tie-in to gamma ray for depth control while waiting for the trouble shooting on the micro-motion meter. Add 7' to coil depth after tie-in run. Hole taking fluid at a rate of about 8 BPH. 21 :35 - 00:00 2.42 DRILL X SFAL PROD1 Reciprocate pipe while Dowell technician trouble shoots problem with micro-motion and coil cab data display. 11/30/2001 00:00 - 01 :35 1.58 DRILL X SFAL PROD1 Wait for Dowell tech to trouble shoot data display and micro-motion. 01 :35 - 05:35 4.00 DRILL C PROD1 Drill ahead from 10,303' while in continuous rotation mode. ( ( Printed: 12/10/2001 11 :16:53 AM BP EXPLORATION Page 7 of 11 Operations Summary Report Legal Well Name: U-15B Common Well Name: U-15B Spud Date: 11/18/2001 Event Name: RE ENTER Start: 11/17/2001 End: 12/7/2001 Contractor Name: NABORS Rig Release: 12/7/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/30/2001 01 :35 - 05:35 4.00 DRILL C PROD1 Drilling slowed down to less than 12 FPH at about 10,415' to about 10,427'. ROP picked up to about 40 FPH after 10,427'. 05:35 - 06:30 0.92 DRILL C PROD1 Wiper trip to the window due to stacking. 06:30 - 10:45 4.25 DRILL C PROD1 Drill to 10530'. 10:45 - 16:30 5.75 DRILL X SFAL PROD1 Something rattling around on pump suction. Open bypass and the MM plugged immediately. Long strips of rubber from inner layer of discharge hose (runs between rig charge pump and Dowell pump). Call for new hose. Wiper trip to tailpipe 8900'. Rebuild pump (full of debris). RIH. Ratty in shales. 16:30 - 18:00 1.50 DRILL X SFAL PROD1 Orient. MM trouble again. Finally locked in at 90L. 18:00-21:10 3.17 DRILL C PROD1 Drill ahead with a toolface of 90L to 10,580'. 21:10-21:35 0.42 DRILL C PROD1 Drill ahead at 90L tool face to 10,585'. Only getting 5 to 6 degree doglegs and need 12 degree to keep in polygon. 21 :35 - 00:00 2.42 DRILL C PROD1 POOH to pick up motor with a stronger bend. 12/1/2001 00:00 - 00:15 0.25 DRILL C PROD1 PJSM prior to changing out motors. 00:15 - 01 :30 1.25 DRILL C PROD1 Down load memory data from resistivity tool and lay down Anadrill1.15 degree motor. 01 :30 - 03:45 2.25 DRILL C PROD1 MU new Weatherford motor and change out bit. Program TORC and resistivity tool, and pressure test MHA. 03:45 - 04:00 0.25 DRILL C PROD1 RIH to 3,000'. 04:00 - 04:20 0.33 DRILL C PROD1 Shallow hole test. Ok. 04:20 - 05:45 1.42 DRILL C PROD1 Continue to RIH. 05:45 - 06:45 1.00 DRILL C PROD1 Log tie-in. Correct depth (+7'). 06:45 - 07:30 0.75 DRILL C PROD1 RIH. Shales in fair condition. Position TF to 90L. 07:30 - 09:45 2.25 DRILL C PROD1 Drill 50 - 60 FPH to 10700'. 09:45 - 11 :30 1.75 DRILL P PROD1 Back on productive time. Continue drilling. Drill to 10765'. Differentially stuck. Pull free. 11 :30 - 12:45 1.25 DRILL P PROD1 Wiper to window. Work shales. 12:45 - 14:15 1.50 DRILL P PROD1 Orient. Stalls 6' off bottom causing us to lose our locked-in toolface. Grabby even without moving pipe. In vicinity of fault. Maybe rubble area? 14:15 -16:30 2.25 DRILL P PROD1 Drill to 10836'. Tough punchin thru shales. Losses still about 8 BPH. Resistivity wet. Plan is to be 5' to 10' above the line around 10950' 16:30 - 17:15 0.75 DRILL P PROD1 Orient. 17:15 -18:30 1.25 DRILL P PROD1 Drill slow to 10,861'. 18:30-21:20 2.83 DRILL P PROD1 Wiper trip into the tubing tail. Hole packed off with the bit at 8950' on the way up to the tubing tail. Work pipe and pu II up through the cuttings bed. Pull up into the tubing tail at 8775'. Drop back down and see motor work in the casing at 9570'-9600', and 9612'. Pull up through the cutting beds and launch a hi-vis pill. No motor work observed passing down through the hole interval 9570'-9612' after pumping the pill. Continue on to TD. Observed motor work at the following depths in the open hole: 10,217'-10,231' ,10,245' ,10,405' , 10,444'-10,455' ,10,478',10,520'-10,530' ,10,569'-10,575'. Obtain slow circulating rates as follows: 0.5/1230, 1.411800, 2.8/3300. 21 :20 - 00:00 2.67 DRILL P PROD1 Drill ahead from 10,861' at a 90L tool face. TORC orienter not correcting for reactive torque and we are having to frequently send commands down to correct the toolface. Put TORC into continuous rotation mode at 10,905 to 10,925'. Orient tool face to 120L at 10,925'. ( (" Printed: 12/10/2001 11:16:53AM .. BP EXPLORATION Page 8 of 11 Operations Summary Report Legal Well Name: U-15B Common Well Name: U-15B Spud Date: 11/18/2001 Event Name: RE ENTER Start: 11/17/2001 End: 12/7/2001 Contractor Name: NABORS Rig Release: 12/7/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/2/2001 00:00 - 01 :15 1.25 DRILL P PROD1 Drill ahead to 10,985'. Losses were 53 BPH over the last hour. 01:15 - 04:00 2.75 DRILL P PROD1 Wiper trip to tubing tail. Switch over to 3% KCI drilling fluid at end of wiper trip. Saw over pull and motor work in the casing at 9389',9202',8912', and 8950'. Had sticky spots in the open hole when running in at 10,165',10,197'-10,219', 10,225'-10,230' ,10,410' ,10,575'. 04:00 - 04:15 0.25 DRILL P PROD1 Orienting tool face to 90R. 04:15 - 07:00 2.75 DRILL P PROD1 Start drilling ahead from 10,985'. Stacking weight. Launch a 5 bbl flo-vis pill. Weight transfer seemed to improve. Drill to 11095'. Lost total returns here. Yippee! Should help with our weight transfer. 07:00 - 08:00 1.00 DRILL P PROD1 Continue drilling with no returns 2.7; 1800 psi FS at 100 FPH, exellent weight transfer. Jeff Jones with AOGCC OK'd delay of BOP test for at least one day. Drill to 11165'. 08:00 - 10:45 2.75 DRILL N DPRB PROD1 Bad MWD detection since we lost all returns. Pull off bottom. Switch to Nabors pump to see if signal improves. Yes, signal improved. Will have to swap back and forth -- orient with Dowell pump and drill with Nabors pump. Also, need Nabors pump to confirm if TF command was sent. Can't get TF to come off of 90R. Drill to 11179'. 10:45 - 13:45 3.00 DRILL N DPRB PROD1 POOH. Clean thru liner and tailpipe 13:45 -15:15 1.50 DRILL N DPRB PROD1 Download TORC and resistivity data. LD BHA. 15:15 -15:30 0.25 DRILL P PROD1 Set TWC. 15:30 - 21:30 6.00 DRILL P PROD1 Pressure test BOPE. Witness waived by AOGCC's Jeff Jones. 21 :30 - 22:00 0.50 DRILL P PROD1 PJSM prior to pulling 2-way check and picking up drilling BHA. 22:00 - 22:30 0.50 DRILL P PROD1 Pull 2-way check. 22:30 - 00:00 1.50 DRILL N MISC PROD1 Wait for Schlumberger electrician to wire up remote operation package into Nabor's pump. 12/3/2001 00:00 - 02:00 2.00 DRILL N MISC PROD1 Wait on Schlumberger electrician to hook up remote to Nabor's pump. 02:00 - 02:15 0.25 DRILL P PROD1 PJSM prior to picking up drilling BHA. 02:15 - 03:50 1.58 DRILL P PROD1 Pick up drilling BHA. Program resistivity tool. 03:50 - 04:40 0.83 DRILL P PROD1 RIH to 3000' and shallow hole test BHA. 04:40 - 05:45 1.08 DRILL P PROD1 Continue to RIH with BHA. 05:45 - 06:45 1.00 DRILL P PROD1 Log tie-in. Correct depth (-10'). 06:45 - 11: 15 4.50 DRILL N DPRB PROD1 RIH. Try to work past shale at 10177'. No progress. Pump 10 bbllubetex pill. With part of pill out bit, worked past dry. Set down in all the shales, most with motor work. Pumped a bunch of pills to get to bottom. Tag 11190'. 11:15-11:30 0.25 DRILL P PROD1 Orient 11 :30 - 18:30 7.00 DRILL P PROD1 Drill 2.7; 2250 psi FS. Drilling weight = 10k. ROP 100 FPH. Current plan is to stay south of line. Drill to 11250'. Stacking in shale. Looks like Shublik. Drill Shublik with negative weight 10 - 20 FPH. Occasional BHA wiper trips to loss zone 11100'. 18:30 - 20:30 2.00 DRILL N STUC PROD1 Drill to 11,395' and start wiper trip to window. Pick up off bottom was sticky and we had +1- 10k Ibs of overpull up to 11,038' where we hung up. Work pipe and pull up to 11,035'. At this point could not get pipe to move down or up. 20:30 - 23:30 3.00 DRILL N RREP PROD1 Attempt to launch flo-pro pills with lubetex in order to get free. However, had problems with pit isolation (a nut that holds together the gate that isolates pill pit from pit #1 backed off and caused the malfunction). The gate had to be repaired to prevent the pill from becoming contaminated with fluids from pit (' ( ,.. Printed: 12/10/2001 11:16:53AM -- BP EXPLORATION Page 9 of 11 Operations Summary Report Legal Well Name: U-15B Common Well Name: U-15B Spud Date: 11/18/2001 Event Name: RE ENTER Start: 11/17/2001 End: 12/7/2001 Contractor Name: NABORS Rig Release: 12/7/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/3/2001 20:30 - 23:30 3.00 DRILL N RREP PROD1 #1. 23:30 - 00:00 0.50 DRILL N STUC PROD1 Mix a 28 bbl flo-vis pill with 4.3% lubetex. 12/4/2001 00:00 - 00:45 0.75 DRILL N STUC PROD1 Continue mixing pill. 00:45 - 01 :45 1.00 DRILL N STUC PROD1 Launch a 28 bbl. pill. Displace the pill 1 0 bbls past the BHA at a rate of 2.7 to 2.8 BPM (2300 psi). and shut down pumps. The mud continued to be sucked through the coil at 0.8 BPM after shutting down the pump. Let the pill soak for 10 min and tried to set 13.5K Ibs down. No movement. Pull up with 70K, no movement. Set down with 13.5K again and did not get the coil to move. 01 :45 - 03:40 1.92 DRILL N STUC PROD1 Rig up to pump down the coil x tubing annulus. Pump a 50 bbl flo-pro pill containing 5% lubetex, followed by 70 barrels of 2% KCI water. Work pipe without success. 03:40 - 04:45 1.08 DRILL N STUC PROD1 Put TORC tool into continuous rotation mode to see if the bit is hung up. Found that the orienter was moving the bit and motor when the pipe was in both tension and compression. We now believe the hang-up is at the coil connector. Stack weight down on the coil and pump down the annulus again at about 1 .8 BPM and 1150 psi. Pipe moved downhole 2'. Continued to pump and work pipe without any additional pipe movement. Have now displaced all of the mud that was in the annulus into the formation. 04:45 - 08:00 3.25 DRILL N STUC PROD1 Pump another 50 barrels of flo-pro mud down the annulus, followed by 70 barrels of 2% KCI water. Pump 30 barrels of flo-pro mud down coil, followed by 20 barrels of 2% KCL water. Work pipe down. No movement. BH down coil 2.5 BPM and BS 2.7 BPM. Work pipe. 08:00 - 08:30 0.50 DRILL N STUC PROD1 Shut in suction on Dowell pump to cavitate pump to rattle pipe. Repeat. Fairly good jolts in ops cab and injector. Did not break free. 08:30 - 12:30 4.00 DRILL N STUC PROD1 WO crude. Pump 60 bbls crude, let 15 bbls go out bit. SD pump. Work pipe free, dragging in ugly hole. Inch it up at full pumps to 10960', not going over 60k (1 Ok overpull). Lots of dragging, with very little motor work. Pump more crude. 12:30 - 13:45 1.25 DRILL N STUC PROD1 Drag drilling assy OOH wi @10k overpull to 10385'. Pump additional 50 bbls crude. Continue dragging BHA pass window. 13:45 -16:00 2.25 DRILL N STUC PROD1 POOH smoothly to surface! 16:00 - 17:30 1.50 DRILL N STUC PROD1 Download Sperry Res tool. and lid same. 17:30 -18:45 1.25 DRILL N STUC PROD1 Check out motor & bit -ok. PIU Sperry MWD/Gr check service breaks align TF. 18:45 - 19: 15 0.50 DRILL N STUC PROD1 RIH to 3000' (hold PJSM review well with new crew). 19:15 - 20:30 1.25 DRILL N STUC PROD1 Shallow hole test. TORC orienter not responding to commands. Suspect pump noises. Troubleshoot & put TORC into continuous rotation mode & successfully oriented. 20:30 - 20:45 0.25 DRILL N STUC PROD1 Changeout leaking seals on Nabors pump cap. 20:45 - 21 :45 1.00 DRILL N STUC PROD1 Continue RIH with BHA to 9304'. 21 :45 - 22:25 0.67 DRILL N STUC PROD1 Log GR tie-in. Correct depth (-12'). Pumping 2.7bpm in & getting 1.2-1.5bpm out. Supect possible bridging downhole. 22:25 - 23:00 0.58 DRILL N STUC PROD1 Continue RIH with BHA to 10345'. Set down in all the shales. 23:00 - 00:00 1.00 DRILL N STUC PROD1 Backreamed thoroughly from 10345' to 10150' pumping 5-10bbls of flopro per 20bbls of KCI water. Very sticky shales. Had to ream/backream area in/out until clean @ 2.7bpm & 2300 psi using same drilled HS TF. PIU wt = 50k. Observe no ( ( Printed: 12/10/2001 11: 16:53 AM BP EXPLORATION Page 10 of 11 Operations Summary Report Legal Well Name: U-15B Common Well Name: U-15B Spud Date: 11/18/2001 Event Name: RE ENTER Start: 11/17/2001 End: 12/7/2001 Contractor Name: NABORS Rig Release: 12/7/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/4/2001 23:00 - 00:00 1.00 DRILL N STUC PROD1 motor work. Acting like differential sticking. 12/5/2001 00:00 - 00:40 0.67 DRILL N DPRB PROD1 Continue BR to f/1 0150' to 10100'. Pumping 5 bbl pills after every 25 bbl2% KCL. Returns varying from 60-70%. Pumping at 2.7 bpm. Little to no cuttings over shaker. 00:40 - 01 :40 1.00 DRILL N DPRB PROD1 Wash & ream back down to 10367'. very grabby 01 :40 - 03:25 1.75 DRILL N DPRB PROD1 Stuck at 10367' work pipe free with and without pumps. 03:25 - 04:00 0.58 DRILL N DPRB PROD1 Wash & ream down to 10450'. 04:00 - 04:15 0.25 DRILL N DPRB PROD1 Backream to 10400'. 04:15 - 08:00 3.75 DRILL N DPRB PROD1 Wash & ream to 10736'. Making frequent 50' backreaming runs. Pumping 5 bbls sweeps every 10 min. 08:00 - 12:00 4.00 DRILL N DPRB PROD1 Start wiper trip back into 4 1/2" casing. Tight a 10610' but work troug h. Tig ht with motor work f/1 0566' to 1 0546'. Extremely tight at 10380'-10350' pulling 70K working this area very carefully for 1 1/2 hrs thinking we have been stuck. No motor work just tight. Continue up to 4/12" without any major overpulls. 12:00-13:15 1.25 DRILL N DPRB PROD1 Pump 50 bbl pill out of coil while at window to possiblly carry any cuttings from casing. 13:15 - 13:30 0.25 DRILL N DPRB PROD1 RIH to 10157' before having problems. 13:30 -19:15 5.75 DRILL N DPRB PROD1 Wash & ream from 10157'. Motor work at numerous spots but went fairly good until 1 0525'. Very slow go with motor work fl 10525' to 10610'. Wash & ream down to 10727' recieved survey at 10702' (89.72 deg 98.91 azm vs. 10712' 93.3 deg 69.73 azm in old hole) that indicates we may be sidetracked. 19:15 - 20:00 0.75 DRILL N DPRB PROD1 Picking up and tagging bottom withlwo pumps but appears that we are sidetracked. Retake survey at 10702' and obtain same results, Incl = 89.72 deg & azm = 98.91 deg. Confirmed departure from old hole from 10590'. 20:00 - 21 :00 1.00 DRILL N DPRB PROD1 Attempt to communicate with TORC tool. TORC orienter not responding to commands. PUH and pull tight at 10345'. Work free & Continue PUH to log GR tie-in. Meanwhile review options with Anchorage. 21:00-21:40 0.67 DRILL N DPRB PROD1 Log GR tie-in. Correct depth (+12'). 21 :40 - 00:00 2.33 DRILL N DPRB PROD1 POOH drilling assembly & paint EOP flags @ 9200' & 5000'. Continue POOH to 1500'. Pumping 2.7bpm in I 0-0.9 bpm. Forward plan is to run 2-7/8" slottedlsolid completion once OOH. 1216/2001 00:00 - 00:25 0.42 DRILL N DPRB PROD1 Continue POOH drilling assembly to surface. 00:25 - 00:40 0.25 DRILL N DPRB PROD1 Freeze protect coil 00:40 - 02:45 2.08 DRILL N DPRB PROD1 LD BHA#16. Observe TORC tool was in continuous rotation mode till @ 16:00 Hrs on 12/5/01 when it was damaged. 02:45 - 03:00 0.25 DRILL N DPRB PROD1 Line-up & circulate KCL water across wellhead @ 2.6bpm in & @ 0.6bpm out. Pumped 20 bbls of Flopro mud to see if losses can reduce. 03:00 - 03:10 0.17 CASE P PROD1 PJSM on running liner assy. 03:10 - 03:30 0.33 CASE P PROD1 RIU to run 2-7/8" liner. Clear out excess tubulars from rack and start prepping 1-1/4" CSH. 03:30 - 04:00 0.50 CASE P PROD1 Pump additional 20 bbls of Flopro mud. Returns increase to 1.8bpm. Back off nabors pump to 0.5bpm returns. 04:00 - 06:30 2.50 CASE P PROD1 MIU & RIH 3 jts of 2-7/8", STL slotted liner & 50 jts 2-7/8" STL solid liner and jewelry. 06:30 - 07:00 0.50 CASE P PROD1 PJSM with new crews. 07:00 - 08:30 1.50 CASE P PROD1 Continue PIU 2 7/8" liner. Keeping hole full with nabors charge ( (" - - Printed: 12/10/2001 11:16:53 AM BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: U-15B Common Well Name: U-15B Spud Date: 11/18/2001 Event Name: RE ENTER Start: 11/17/2001 End: 12/7/2001 Contractor Name: NABORS Rig Release: 12/7/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/6/2001 07:00 - 08:30 1.50 CASE P PROD1 pump. Hole taking .5bpm 08:30 - 09:30 1.00 CASE P PROD1 Prep drift 1 1/4" tbg, floor and tools for same. 09:30 - 09:45 0.25 CASE P PROD1 PSJM concerning handling of tbg. 09:45-13:15 3.50 CASE P PROD1 PIU 53 jts tbg space out plu CTLRT. Wait on 1 3 1/2" drill collar (stripdown joint). MIU same. 13:15-16:00 2.75 CASE P PROD1 MIU new CTC pressure and pull test same. Displace meth from coil. PIU injector stab-on to liner. 16:00 -18:10 2.17 CASE P PROD1 RIH wi liner. Stopped at 10184'. 18:10 - 20:50 2.67 CASE N DPRB PROD1 Working liner at 10184' circ on bottom at 2.5 bpm 2500 psi (no returns), PIU & RIH at varying speeds up to 170 fpm. Made no progress. 20:50 - 21:15 0.42 CASE N DPRB PROD1 Set down -15klbs max @ 10184' and attempt to wash down. Meanwhile review fallback options with Anchorage. Decide to POOH & RDMO to 15-36. 21:15-21:30 0.25 CASE N DPRB PROD1 Held PJSM on RDMO operations. 21 :30 - 23:30 2.00 CASE N DPRB PROD1 POOH 2-7/8" liner assy to surface filling-up via CT and annulus. 23:30 - 00:00 0.50 CASE N DPRB PROD1 Displace coil to methanol. 12/7/2001 00:00 - 01:15 1.25 CASE N DPRB PROD1 Continue displacing coil to methanol. Setback injector. 01:15 - 01:30 0.25 CASE N DPRB PROD1 PJSM for UD completion string. 01:30 - 04:15 2.75 CASE N DPRB PROD1 UD 1 3-1/2" DC, CTLRT, 53 jts 1-1/4" CS Hydril tubing & Baker stinger. 04:15-07:30 3.25 CASE N DPRB PROD1 UD 53 jts of 2-7/8" liner 07:30 - 08:30 1.00 CASE P PROD1 PIU injector bullhead 33 bbl 50/50 methanol to freeze protect well. 0 wellhead pressure. Well on vacuum. Close master valve. 08:30 - 09:00 0.50 CASE P PROD1 Blowdown coil with N2 (unable to start motor) will install BPV. 09:00 - 10:15 1.25 CASE P PROD1 Install BPV. Close master valve. 10:15 - 10:45 0.50 RIGD P POST PJSM. review plans for RD and operations for blowing down coil w/N2. 10:45 - 12:30 1.75 RIGD P POST RD lines etc from DS#4. Prep to blowdown coil. 12:30 - 14:00 1.50 RIGD P POST Blowdown wi N2. Rig down DS Unit #4 14:00 -17:00 3.00 RIGD P POST Nipple down BOPE. empty opentop, tiger tank, rig and cuttings tanks. Install tree cap and test to 4000 psi. Notified AOGCC of rig move to PBU 15-36 Nabors 3S released at 1700 hrs on 12-07-2001 Last report ( (' Printed: 12/10/2001 11:16:53AM ~. AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well U-15BPB1 éJ,o/-19, Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,971.26' MD Window / Kickoff Survey 9,990.00' MD Projected Survey: 10,771.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) (" ~Q¿ , r¡¡ -:J .,."..,H'-'~':";)"'¡;;""""'¡l"""""'""';"::""':":'1.,V"i'" '1;'~¡ììi~~;,;"i,'".;Sli:::I:i'rl,;!l',I"'~1:;lIY"~'\\:!~:"",'" "\~'if"'I"':I/',"': 28-Dec-01 RECEIVED DEC 2 8 2001 Alaska Oil & Gas Cons. COmn'IiSSIOt Anc~<lrage DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_WOA U Pad, Slot U-15 U-15BPB 1 Job No. AKMW11193, Surveyed: 24 November, 2001 -~c SURVEY REPORT 27 December, 2001 Your Ref: API 500292256572 Surface Coordinates: 5960477.88 H, 632197.12 E (70018' 00.2706" H, 148055' 45.4863" W) Kelly Bushing: 76.00ft above Mean Sea Level -- spe"-'Y-SUIl DRILLING seRVIc:es A Halliburton Company Survey Ref: 5vy11058 Sperry-Sun Drilling Services Survey Report for U-15BPB1 Your Ref: API 500292256572 Job No. AKMW11193, Surveyed: 24 November, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA U Pad Measured Sub-Sea Vertical local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9971.26 88.800 90.300 8820.35 8896.35 1462.64 N 1151.95E 5961960.56 N 633323.15 E 1444.50 Tie On Point .-.- MWD Magnetic --- 9990.00 89.440 90.130 8820.64 8896.64 1462.57 N 1170.68 E 5961960.82 N 633341.89 E 3.534 1462.77 Window Point 10009.81 90.830 89.200 8820.59 8896.59 1462.68 N 1190.49 E 5961961.28 N 633361.69 E 8.442 1482.12 10057.36 88.680 85.900 8820.80 8896.80 1464.72 N 1237.99 E 5961964.15 N 633409.15 E 8.283 1528.91 10112.91 88.860 81.700 8821.99 8897.99 1470.71 N 1293.19 E 5961971.11 N 633464.23 E 7.566 1584.08 10137.01 88.680 81.400 8822.51 8898.51 1474.25 N 1317.02 E 5961975.07 N 633488.00 E 1.451 1608.11 10156.36 86.920 81.500 8823.25 8899.25 1477.13 N 1336.14 E 5961978.28 N 633507.07 E 9.110 1627.39 10170.08 86.220 81.730 8824.07 8900.07 1479.12 N 1349.69 E 5961980.52 N 633520.58 E 5.369 1641.05 10229.01 87.100 85.620 8827.51 8903.51 1485.60 N 1408.15 E 5961988.03 N 633578.92 E 6.757 1699.51 10251.58 88.510 90.190 8828.37 8904.37 1486.43 N 1430.68 E 5961989.25 N 633601.43 E 21.175 1721.67 10281.16 91.060 90.190 8828.48 8904.48 1486.33 N 1460.26 E 5961989.67 N 633631.00 E 8.621 1750.51 10332.86 87.710 83.860 8829.04 8905.04 1489.01 N 1511.85 E 5961993.26 N 633682.54 E 13.850 1801.44 10399.44 86.310 86.490 8832.51 8908.51 1494.60 N 1578.10 E 5962000.01 N 633748.68 E 4.470 1867.30 10443.11 86.480 85.440 8835.26 8911.26 1497.67 N 1621.58 E 5962003.84 N 633792.09 E 2.431 1910.39 10480.42 88.260 84.570 8836.97 8912.97 1500.91 N 1658.70 E 5962007.74 N 633829.16 E 5.309 1947.32 10531.19 92.810 82.450 8836.49 8912.49 1506.65 N 1709.13 E 5962014.36 N 633879.48 E 9.887 1997.78 10586.36 98.260 78.940 8831.17 8907.17 1515.52 N 1763.29 E 5962024.18 N 633933.47 E 11 .733 2052.57 -~~'. 10623.14 99.230 78.060 8825.58 8901.58 1522.76 N 1798.91 E 5962032.05 N 633968.96 E 3.542 2088.91 10656.01 99.840 74.010 8820.13 8896.13 1530.58 N 1830.36 E 5962040.43 N 634000.27 E 12.292 2121.31 10707.71 97.530 68.670 8812.32 8888.32 1546.94 N 1878.76 E 5962057.63 N 634048.37 E 11. 144 2172.12 10749.26 98.500 61.620 8806.52 8882.52 1564.22 N 1916.07 E 5962075.56 N 634085.37 E 16.963 2212.31 10771.00 98.500 61.620 8803.31 8879.31 1574.44 N 1934.99 E 5962086.11 N 634104.11 E 0.000 2233.01 Projected Survey --_._--..- 27 December, 2001 - 17:15 Page 2 of 3 Dril/Quest 2.00.08.005 - Sperry-Sun Drilling Services Survey Report for U-15BPB1 Your Ref: API 500292256572 Job No. AKMW11193, Surveyed: 24 November, 2001 . North Slope Alaska Alaska Drilling & Wells PBU WOA U Pad All data is in Feet (US) 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. Magnetic Declination at Surface is 26.3350 (27-Dec-01) ~" "-- The Dogleg Severity is in Degrees per 1 00 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 77.3400 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 1 0771.00ft., The Bottom Hole Displacement is 2494.60ft., in the Direction of 50.8660 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9971.26 9990.00 10771.00 8896.35 8896.64 8879.31 1462.64 N 1462.57 N 1574.44 N 1151.95 E 1170.68 E 1934.99 E Tie On Point Window Point Projected Survey ~~. Survey tool program for U-15BPB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 9971.26 0.00 8896.35 9971.26 10771.00 8896.35 8879.31 AK-3 BP _HM - BP High Accuracy Magnetic (U-15A) MWD Magnetic (U-15BPB 1 ) - -.- - --. 27 December, 2001 - 17:15 ----------- Page 3 of 3 DrillQuest 2.00.08.005 l ( (' '6i';c5"Y:: ~~~"f q~":7 ":".c"" 28-Dec-0 1 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well U-158 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,619.09' MD Window / Kickoff Survey 9,640.00' MD Projected Survey: 11,395.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED DEC 2 8 2001 Alaska Oil & Gas Cons. Commassim ' AncOOrage North Slope Alaska Alaska Drilling & Wells PB U - WOA U Pad, Slot U-15 U-15B Job No. AKMW11193, Surveyed: 4 December, 2001 SURVEY REPORT 27 December, 2001 D EFI NITIVE ~-. Your Ref: API 500292256502 Surface Coordinates: 5960477.88 N, 632197.12 E (70. 18' 00.2706" N, 1480 55' 45.4863" W) Kelly Bushing: 76.00II above Mean Sea Level ~Y-1IIUI1 _c-c SIIIVP.Y UP.': svy110S9 Sperry-Sun Drilling Services Survey Report for U-158 Your Ref: API 500292256502 Job No. AKMW11193, Surveyed: 4 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA U Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9619.09 84.200 83.300 8843.64 8919.64 1457.97 N 801.85 E 5961949.73 N 632973.19 E 1068.65 Tie On Point --., MWD Magnetic "'--- 9640.00 85.850 84.690 8845.45 8921.45 1460.15 N 822.56 E 5961952.27 N 632993.87 E 10.300 1089.40 Window Point 9664.00 89.030 85.000 8846.52 8922.52 1462.30 N 846.44 E 5961954.84 N 633017.70 E 13.313 1113.24 9693.44 90.700 88.250 8846.59 8922.59 1464.03 N 875.82 E 5961957.09 N 633047.05 E 12.411 1142.40 9725.64 90.440 92.000 8846.27 8922.27 1463.96 N 908.02 E 5961957.59 N 633079.24 E 11.673 1173.97 9763.49 88.330 93.000 8846.68 8922.68 1462.31 N 945.82 E 5961956.60 N 633117.07 E 6.169 1210.75 9793.14 87.800 90.000 8847.68 8923.68 1461.54 N 975.44 E 5961956.35 N 633146.70 E 10.269 1239.66 9833.26 88.240 88.250 8849.06 8925.06 1462.15 N 1015.53 E 5961957.67 N 633186.77 E 4.495 1279.11 9861.67 87.980 84.380 8850.00 8926.00 1463.97 N 1043.86 E 5961959.99 N 633215.07 E 13.645 1307.26 9912.92 88.770 79.990 8851.46 8927.46 1470.94 N 1094.60 E 5961967.85 N 633265.68 E 8.700 1358.39 9948.17 89.910 77.530 8851.86 8927.86 1477.81 N 1129.17 E 5961975.32 N 633300.12 E 7.691 1393.64 9980.24 90.090 72.080 8851.86 8927.86 1486.21 N 1160.11 E 5961984.27 N 633330.90 E 17.003 1425.61 10009.79 90.000 76.120 8851.84 8927.84 1494.30 N 1188.52 E 5961992.86 N 633359.17 E 13.675 1455.06 10049.23 89.690 82.410 8851.95 8927.95 1501.65 N 1227.25 E 5962000.88 N 633397.76 E 15.968 1494.47 10087.36 88.900 87.700 8852.41 8928.41 1504.93 N 1265.23 E 5962004.84 N 633435.67 E 14.026 1532.36 10115.81 88.490 91.670 8853.06 8929.06 1505.09 N 1293.66 E 5962005.49 N 633464.10 E 14.025 1560.29 ' 10141.88 89.430 92.810 8853.54 8929.54 1504.07 N 1319.71 E 5962004.93 N 633490.16 E 5.667 1585.65 ~-- 10170.61 88.810 93.690 8853.98 8929.98 1502.44 N 1348.39 E 5962003.81 N 633518.86 E 3.747 1613.47 10210.98 90.840 92.630 8854.10 8930.10 1500.22 N 1388.69 E 5962002.29 N 633559.20 E 5.673 1652.59 10242.38 89.690 91.580 8853.96 8929.96 1499.06 N 1420.07 E 5962001.69 N 633590.60 E 4.959 1683.15 10284.96 91.170 90.670 8853.64 8929.64 1498.23 N 1462.64 E 5962001.60 N 633633.17 E 4.080 1724.76 10329.76 92.250 91.050 8852.30 8928.30 1497.55 N 1507.41 E 5962001.72 N 633677.95 E 2.555 1768.55 10382.41 91.720 92.460 8850.48 8926.48 1495.94 N 1560.01 E 5962001.03 N 633730.56 E 2.859 1819.84 10429.06 91.720 93.690 8849.07 8925.07 1493.44 N 1606.57 E 5961999.35 N 633777.16 E 2.635 1865.04 10499.73 91.540 94.750 8847.06 8923.06 1488.24 N 1677.02 E 5961995.39 N 633847.69 E 1.521 1933.15 10527.54 90.570 94.220 8846.55 8922.55 1486.07 N 1704.74 E 5961993.71 N 633875.45 E 3.974 1959.93 10559.66 91.370 92.630 8846.01 8922.01 1484.15 N 1736.79 E 5961992.35 N 633907.53 E 5.541 1991.01 10618.55 91.450 84.880 8844.56 8920.56 1485.43 N 1795.61 E 5961994.67 N 633966.31 E 13.157 2048.96 10672.45 92.070 76.420 8842.90 8918.90 1494.17 N 1848.72 E 5962004.34 N 634019.26 E 15.730 2102.76 10712.22 93.300 69.730 8841.03 8917.03 1505.73 N 1886.70 E 5962016.57 N 634057.04 E 17.085 2142.26 ~- - -- --. -------- ----.-- - 27 December, 2001 - 17:22 Page 2 of 4 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for U-15B Your Ref: API 500292256502 Job No. AKMW11193, Surveyed: 4 December, 2001 .. Alaska Drilling & Wells North Slope Alaska PBU WOA U Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10757.95 100.700 66.910 8835.46 8911.46 1522.48 N 1928.85 E 5962034.05 N 634098.88 E 17.299 2186.85 ~'c 10795.40 102.640 61.620 8827.88 8903.88 1538.39 N 1961.87 E 5962050.54 N 634131.62 E 14.771 2222.33 '-...- 10826.05 102.110 58.100 8821.31 8897.31 1553.42 N 1987.76 E 5962066.03 N 634157.24 E 11.350 2250.64 10872.27 104.140 52.810 8810.81 8886.81 1578.93 N 2024.82 E 5962092.18 N 634193.85 E 11.980 2291.93 10911.90 104.760 46.820 8800.91 8876.91 1603.67 N 2054.13E 5962117.44 N 634222.72 E 14.720 2325.47 10948.50 103.170 41.530 8792.08 8868.08 1629.14 N 2078.86 E 5962143.34 N 634247.00 E 14.683 2354.66 11011.15 102.560 51.050 8778.10 8854.10 1671.29 N 2122.96 E 5962186.26 N 634290.35 E 14.845 2406.08 11065.38 103.080 58.100 8766.05 8842.05 1701.92 N 2166.02 E 5962217.64 N 634332.86 E 12.712 2454.25 11086.13 104.230 61.970 8761.15 8837.15 1711.99 N 2183.48 E 5962228.02 N 634350.14 E 18.951 2473.33 11101.27 105.990 62.680 8757.20 8833.20 1718.78 N 2196.43 E 5962235.03 N 634362.97 E 12.475 2487.34 11156.72 107.840 63.030 8741.07 8817.07 1742.98 N 2243.63 E 5962260.06 N 634409.74 E 3.391 2538.34 11229.60 102.560 72.900 8721.92 8797.92 1769.25 N 2308.74 E 5962287.47 N 634474.37 E 14.937 2607.29 11283.55 100.530 80.650 8711.11 8787.11 1781.32 N 2360.15 E 5962300.44 N 634525.57 E 14.568 2660.07 11322.72 102.560 88.400 8703.26 8779.26 1784.99 N 2398.32 E 5962304.78 N 634563.67 E 20.064 2698.23 11355.85 104.580 92.810 8695.48 8771.48 1784.65 N 2430.51 E 5962305.01 N 634595.86 E 14.303 2729.75 11395.00 104.580 92.810 8685.63 8761.63 1782.80 N 2468.36 E 5962303.82 N 634633.73 E 0.000 2766.52 Projected Survey All data is in Feet (US) 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. Magnetic Declination at Surface is 26.369° (19-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 78.850° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11395.00ft., The Bottom Hole Displacement is 3044.86ft., in the Direction of 54.161° (True). ----- 27 December, 2001 - 17:22 Page 3 of 4 DrillQuest 2.00.08.005 North Slope Alaska Comments -, ',--. Measured Depth (ft) 9619.09 9640.00 11395.00 Sperry-Sun Drilling Services Survey Report for U-15B Your Ref: API 500292256502 Job No. AKMW11193, Surveyed: 4 December, 2001 . 1457.97 N 1460.15 N 1782.80 N Survey tool program for U-15B Alaska Drilling & Wells PBU WOA U Pad Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8919.64 8921.45 8761.63 From Measured Vertical Depth Depth (ft) (ft) 0.00 9619.09 --_._- -----. 0.00 8919.64 27 December, 2001 - 17:22 To Measured Vertical Depth Depth (ft) (ft) 9619.09 11395.00 8919.64 8761.63 ---------------- Comment -~. 801.85 E 822.56 E 2468.36 E Tie On Point Window Point Projected Survey Survey Tool Description AK-3 BP _HM - BP High Accuracy Magnetic (U-15A) MWD Magnetic (U-15B) .~è.. Page 4 of 4 DrillQuest 2.00.08.005 J: t STATE OF ALASKA ,'-- ALASKA ,-,IL AND GAS CONSERVATION COM~.. ....310N APPLICATION FOR SUNDRY APPROVAL \ '\It-.." \ '( ,. ./-7 ù\~'y ;a \) It \' ¡tIt 0 "-')'. \ \ \ "'\ ;." ./ ,,(""-':::.P 7¥c; 7 1. Type of Request: 0 Abandon 0 Suspend 0 Plugging 0 TIme Extension 0 Perforate 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance 0 Other 0 Change Approved Program II Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 5172' NSL, 1808' WEL, SEC. 19, T11N, R13E, UM At top of productive interval 1268' NSL, 1434' WEL, SEC. 18, T11N, R13E, UM At effective depth At total depth 1778' NSL,1233' EWL, SEC. 17, T11N, R13E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 11395 feet 8686 feet 11395 feet 8686 feet true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Size 110' 20" 3007' 10-3/4" 9059' 7-5/8" 1206' 5-1/2" Perforation depth: measured None true vertical None 5. Type of well: ~ Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) KBE = 76' 7. Unit or Property Name Prudhoe Bay Unit (As Planned) 8. Well Number U-15B 9. Permit Number 201-197 10. API Number 50- 029-22565-02 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Plugs (measured) Junk (measured) Cemented MD TVD 260 sx Arcticset (Approx.) 110' 110' 940 sx CS III, 375 sx 'G', 190 sx CS II 3036' 3029' 265 sx Class 'G' 9086' 8787' 260 sx Class 'G' 8932' - 9641' 8677' - 8922' RECEIVED DEC 1 1 ZOD1 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 8936' AlaskaOil&GasCons.Comrnission Anchorage Packers and SSSV (type and measured depth) 7-5/8" Baker 'SABL-3' packer at 8889'; 4-1/2" SSSV Landing Nipple at 2214' I 13. Attachments ~ Description Summary of Proposal / 14. Estimated date for commencing operation December 7, 2001 16. If proposal was verbally approved Tom Maunder 12/7/2001 Name of approver Date Approved Contact Engineer Name/Number: Thomas McCarty, 564-5697 17. I ~ereby certify t~foregoing is true and correct to the best of my knowledge Signed Th ---- / ¿::;, .c rt t ........~A¿ Ct: Title CT Drilling Engineer omas M'cc a y /,V{ , , ' .. " , . , " "."Commï~si~ri:U~e:,Only' , Conditions of Approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test - Subsequent form required 1 0- l{'a '-\ .. Original Sìgned By am C I 0 Detailed Operations Program 15. Status of well classifications as: ~ Oil 0 Gas 0 Suspended 0 BOP Sketch Service Prepared By Name/Number: Terrie Hubble, 564-4628 Date 7 Commissioner Plans for U-15B (' (' " Subject: Plans for U-15B Date: Tue, 11 Dec 2001 17:48:30 -0600 From: "Warren, Mike (Orbis)" <WarrenM@BP.com> To: IIItom_maunder@admin.state.ak.uslll <tom_maunder@admin.state.ak.us> CC: "McCarty, Thomas Mil <McCartTM@BP.com>, "Dickey, Doug" <DickeyD1@BP.com>, "Babcock, Dan" <8abcocDR@8P.com> Tom: To recap our phone conversation, we plan to obtain a flow test on U-158 to determine whether to produce this toe drill out as an open hole completion. We need to do this within the year, but will try to do it much sooner. (Test separator availability is the constraint.) We also owe you a 10404 (Sundry) on the well. Mike Warren 1 of 1 12/13/01 3:18 PM ., ( , (' ~~!. bp ~: ....~ --.,- To: Tom Maunder Sr. Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Thomas McCarty CTD Engineer Date: December10, 2001 Re: Temporary shutdown of drilling operations on U-15B The AOGCC field inspector was notified of our intent to shut-down drilling operations on 12/07/01. U-15b was previously permitted for sidetracking in September 2001 (permit no. 201-197). The permit no 201- 197 called for setting a whipstock, milling a window, drilling a 2100' sidetrack and running a solid/cemented completion. On our second sidetrack attempt (after pumping cement and plugging the 151 attempt due to poor hole conditions) we drilled to 11,3951, called TD and planned to run liner as per plan. Total loss circulation combined with exposed shales and poor hole conditions resulted in an inadvertent sidetrack at 10,5901 on the clean-out run prior to running liner. Despite the poor hole conditions and the inadvertent sidetrack an attempt was made to run liner unfortunately the bottom of the liner would not pass by 10,1841. The liner was then pulled out of hole. At that point the decision was made to cease operations and determine an alternate path forward. The following describes the current well condition and is submitted as an attachment to Form 10-403. The well was left open hole from 9641 to 11395, with an inadvertent sidetrack from 10590 to 10727. The perforations in the 5-1/2" liner were abandoned prior to milling the initial window. To secure the well, the wellbore was displaced with 2%KCL and Freeze protect fluid to 2000' and a back pressure valve was set in the tubing hanger. Further operations may resume within 60 days. 7Z. -~ . ~ r r'"--" Thomas McCarty -;7 CTD Drilling Engineer 564-5697 mccarttm @ bp.com CC: Well File TREE = ... W8...LHEAD= A CTUA.TOR= -.. .. '" ..'" ,-w'" ,,' KB. B..EV = BF. B..EV = -", ' KOP= Max Angle = ",,-"""""""""""""""" Datum MD = Datum lVD = 4-1/16" CWV FMC BAKER 77.3' 46.8' 3050' . , ..- 100 @ 9747' , """""."""'.""-""" 9242' 8800' SS (" U-15b Current condition I 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" I 3036' Minimum 10 = 3.72588 @ 8923' 4-1/2" HES XN NIPPLE 7-5/8" X 5-1/2" BKR PKR WI HMC LNR HGR, ID = 4.938" I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 8932' 8934' I 7-5/8" CSG, 29.7#, NSCC, ID = 6.875" -1 9086' ÆRFORA TION SUMMARY REF LOG: TCP ÆRF ANGLE AT TOP ÆRF: 55 @ 9178' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9178' -9216' 0 08/02/95 3-3/8" 4 9340' -9400' 0 08/02/95 3-3/8" 4 9580' -9680' 0 08/02/95 3-3/8" 4 9720' -9820' 0 08/02/95 SA~' ~OTES: ORIGINAL WB..L U-15 WAS P&A'DW/ CMT Ò< 'v NOT SHOWN ON THIS DIAGRAM. U-15A EXCEEDS 70 DEG @ 9300' & GOES HORIZONTAL @ 9500'. 2213' ~4-1/2" HES - HXO SSSV NIP, ID = 3.813" I 6) I Spy set in profile of tubing hanger I GAS LIFT MANDRB..S ST MD lVD DEV TYÆ VLV LATCH SIZE DATE 6 3172 3163 7 KBMG-M DV BK 04/27/01 5 5124 5070 20 KBMG-M DV BK 04/27/01 4 6639 6507 16 KBMG-M DV BK 04/27/01 3 7651 7483 16 KBMG-M DV BK 04/27/01 2 8414 8214 18 KBMG-M DV BK 04/27/01 1 8728 8502 27 KBMG-M DV BK 04/27/01 8876' 8888' 8912' 8923' 8935' ~4-1/2" HES X NIP, ID = 3.813" I ~ 7-5/8" x 4-1/2" BKR SABL-3 PKR, ID = 3.875" I ~4-1/2" HES X NIP, ID = 3.813" I ~4-1/2" HES XN NIP, ID = 3.725" I 1~4-1/2" WLEG, ID = 3.958" I 1-1 ELMD IT NOT LOGGED I TOC @ - 9574, inside 5-1/2" / 11,395' Uncemented Open hole 9641' \ 5-1/2" LNR, 17#, L-80, 0.0232 bpf, ID = 4.892" --I 10138' I DATE REV BY COMMENTS DATE REV BY COMMENTS 08/04/95 KSB ORIGINAL COMPLETION 02/05/01 SIS-QAA CONVERTED TO CANVAS 03/08/01 SIS-MD FINAL 07/01/01 CHiKAK CORRECTIONS PRUDHOE BAY UNIT WELL: U-15A ÆRMrT No: 95-0970 APt No: 50-029-22565-01 5173' NSL & 1809' WB.. Sec. 19, T11N, R13E BP Exploration (Alaska) Re: U-15b operations shutdown ( (' Subject: Re: U-15b operations shutdown Date: Fri, 07 Dee 2001 17:01 :06 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "McCarty, Thomas M" <MeCartTM@BP .com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> ~O\.... \~ '"\ Thomas, I have received your message regarding U-15b. Based on the numbers I have from the permit review, it appears that you can only get 200' or so out of your window. It appears that shutting down the operations is an appropriate course of action. Although you do identify a potential course of action, you have indicated a time of return. It appears that provided you plan to use the same window, a sidetrack should be possible. You should make plans to return to the well in the near future to either begin the new sidetrack or put cement across the window. Also, please note that in the future, I would appreciate the opportunity to be apprised of your plans prior to them going into effect. Tom Maunder, PE AOGCC "McCarty, Thomas Mil wrote: > Tom.. > > Nabors 38 will shut down operations on U-15b today 12/07/2001. The decision > was made to shut down the operation and consider our remedial options which > could possibly include another sidetrack attempt or abandoning the well with > cement. > > We drilled to 11,395', called TD and planned to run liner as per plan. We > encountered total lost circulation during drilling and had difficulty with > shales and poor hole conditions which caused us to inadvertently sidetrack > the well at 10,590' on the clean-out run prior to running Uner. We did > attempt to run liner but were unsuccessful as the hole conditions would not > allow it, the bottom of the liner would not pass by 10, 184'. > > U-15b will be displaced to 2%KCL, freeze protected and a BPV set. The AOGCC > field inspector was notified of our intent to shut-down this afternoon > 12/07/01. > > A Sundry Notice will be prepared and filed as soon as possible. > > Please give me a call or email with any questions or concerns. > > Thomas McCarty > BP Exploration Alaska (/nc.) > Coil Tubing Drilling Engineer > Office: 907-564-5697 > Cell: 907-240-8065 Thank You. r 1 of 2 12/11/01 12:38 PM Re: U-15b new window ( ( Subject: Re: U-15b new window Date: Mon, 26 Nov 2001 09:53:44 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Stagg, Ted 0 (ORBIS)" <StaggTO@BP.com> .dO \ -\'\ '\ Ted, No need for the 403. Good luck. Tom "Stagg, Ted 0 (ORB IS)" wrote: > Thanks Tom. If the 403 is not needed then I would like to skip it as Terrie > Hubble is out of the office through tomorrow. If you do need the 403 then > let me know and I will get it done somehow. > > The only change to the plan is that we are in the process now of pumping 15 > bbls cement rather than 10 bbls. The new directional plan goes to exactly > the same BHL. > > Ted > > -----Original Message----- > From: Tom Maunder [mailto:tom maunder@admin.state.ak.usl > Sent: Monday, November 26,2001 7:35 AM > To: Stagg, Ted a (ORBIS) > Subject: Re: U-15b new window > > Thanks for the notice Ted. We appreciate the updated paperwork as well, > although I don't think strictly that a 403 is needed since this is "plugging > back for geologic trouble" and the BHL hasn't changed. Good luck with the > new > hole. > Tom > > "Stagg, Ted a (ORB IS) " wrote: > > > Tom, » > > On Saturday Nov. 24, 2001, U-15b encountered the Shublik deeper than > > expected. A plug back and re-drill from the existing window could not > avoid > > re-drilling a part of the troublesome Shublik formation. Instead, a new > > whipstock will be set at approx. 9650-9700 and a new window milled. The > > target BHL is unchanged but the well path from the new window to the > target > > interval will be deeper to avoid Shublik. After setting the new > whipstock, > > U-15b PB1 will be plugged by pumping approx. 10 bbls cement past the new > > whipstock. The purpose of the cement is to shut off mud losses to the > U-15b > > PB1 wellbore. » > > N3S is currently doing a weekly BOP test. The next operation will be > > setting the new whipstock. A new directional plan is being prepared and 10f2 11/26/01 9:56 AM Re: U-15b new window -. ' ( ( > > will be submitted along with a 10-403 by tomorrow. The AOGCC inspector on > > the slope has been advised of this change in the well plan. » > > Ted Stagg > > 564-4694 office > > 345-0228 home > > 240-8074 cell jl~ Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer I Alaska Oil and Gas Conservation Commission ! 2 of2 11/26/01 9:56 AM I ~~~VŒ (ill~ ~~~~[ß~ ( ALAS IiA 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit U-15B BP Exploration Alaska, Inc. Pennit No: 201-197 Sur Loc: 5172' NSL, 1808' WEL, Sec. 19, T11N, R13E, UM Btmhole Loc. 1778' NSL, 1233' EWL, Sec. 17, T11N, R13E, UM Dear Mr. McCarty: Enclosed is the approved application for pennit to redrill the above referenced well. The pennit to redrill does not exempt you from obtaining additional pennits required by law from other govenunental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Prudhoe Bay Unit U-15B. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ( llYk- A. ()wML .~ C~~;~chsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 5th day of October, 2001 jj c/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 310N ,ftO(~ " 1?75 /~!//- ALASK4:' STATE OF ALASKA L AND GAS CONSERVATION COM~ PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work 0 Drill 181 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 5172' NSL, 1808' WEL, SEC. 19, T11N, R13E, UM At top of productive interval 1268' NSL, 1434' WEL, SEC. 18, T11N, R13E, UM At total depth 1778' NSL, 1233' EWL, SEC. 17, T11N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028282,3501' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9990' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casino Weiaht Grade Couolina Lenath 3-3/4" 3.3I16"x2.7/S" 6.2#/6.16# L-80 ST-L 2960' 1 b. Type of well 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10138 feet 8898 feet 10052 feet 8896 feet Length Size 110' 3007' 9059' 20" 10-3/4" 7-5/8" 1206' 5-1/2" 0 Exploratory Dßtratigraphic Test 181 Development Oil 0 Service 0 Development Gas Ii!J Single~ne 0 Multiple Zone 5. Datum Elevation (DF or KB) 10.l=ield and Pool KBE = 76' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028283 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number U-15B 9. Approximate spud date 11/08/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12020' MD / 8770' TVDss 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 102 Maximum surface 2244 psig, At total depth (TVD) 8800' / 3300 psig Setting Depth Too Bottom MD TVD MD TVD 9060' 8694' 12020' 8770' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantitv of Cement (jnclude stane data) 162 sx Class 'G' ;¡\::, :,"" ,""""",. " 'J', i:~"_.,,, Ii."",::,:, 'J t, ,,::",:,:. i,"'" '" , ,i'""." L_,,/r: Plugs (measured) SF p ~) I"" ~., 1,,1 / 2007 Ala').!(" ". ',I\,;:¡ (hi () ~ " "¡(\"(-;-'~(" ". .. "Ci,;.) ,...on;,:,:. (>1,." ' J",/,,¡ -",,0/)"11"'-'- . ¡¡ IA)Oi";:::On ' , I Ù;'>!(It: , \.,.c; Junk (measured) Cemented MD TVD 260 sx Arcticset (Approx.) 940 sx CS III, 375 sx 'G', 190 sx CS II 265 sx Class 'G' 110' 3036' 9086' 110' 3029' 8787' 260 sx Class 'G' 89321 - 10138' 8677' - 8898' true vertical 9178' - 9216', 9340' - 94001, 9580' - 9680', 9720' - 9820' 8843' - 8863', 8905' - 8910', 8917' - 8923', 8919' - 8905' 181 Filing Fee 0 Property Plat 181 BOP Sketch 0 Diverter Sketch II Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foreqoing is true and correct to the best of my knowledge Date o/-, r /rJ I Signed Thomas McCarty 7 ~ /' ~y ~ Title CT Drilling Engineer (/~ 0/ v , "',:, ',', """",.,"',,':",7:""', ",',,",,' ,:", ,:",r',"',Øømrni;ssip1'1'QsèOnly::;,::,',."',,:;:,,',.""'",'::,':";;,;,,::,'.;",;',"',';"',,'::;:":,,:"".,.,',: Permit Number I C/--. API Number Appro"'iLDa.t~ , See cover letter 2C> 1,- I J 50- 029-22565-02 1 N' ~ 10, for other reQuirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Reql ired' 0 Yes 15J' No Hydrogen Sulfide Measures IE Yes 0 No Directional Survey Required ~ v,es 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K ~.5K psi for CTU Other: Perforation depth: measured 20. Attachments by order of the commission Date ê) < I (j \ Submit In" Triplicate Approved By Form 10-401 Rev. 12-01-85 Original Signed By ... I I t. Commissioner Or< G \A... ( ~. BPX U-15B Sidetrack Summary of Operations: A CTD through tubing sidetrack is planned for well U-15A. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Drift tubing/liner. Set whipstock. P&A with cement. Mill Window Planned to begin Oct 15, 2001 . Drift well with dummy whipstock. . Caliper the tubing and liner. ~. . Set whipstock using service coil at approximately 9990' (-8820'tvdss) ~ ð . P&A the existing perfs with cement. ~O .. Mill out cement in 5.5" liner. Mill 3.8" window off the whipstock with service coil time permitting. Phase 2: Drill and complete sidetrack. Planned to begin Nov 8, 200t. 2-%" coil will be used to drill approx. 2100 feet of 3-%" OB sidetrack, (as per attached plan) and run a 2-Ys" x 3-3/16" liner completion. The liner will be cemented, a memory CNL will be run and the liner will be perforated. Mud Program: . Phase 1: Seawater . Phase 2: Seawater/Biozan and Flo-Pro (8.6 - 8.7ppg) Disposal: . No annular injection on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 27/8",6.16#, L-80, X-over to 3-3/16", 6.2#, L-80 solid liner run from approx. 9060' (TaL, -8694'TVDss) to TD. The 3-3/16" liner will be placed from the TaL down to approx. two joints outside the window. The liner will be cemented in place by pumping approx. 33bbls of 15.8ppg cement. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray log with resistivity will be run over the open hole section. Hazards BzS was most recently measured at 8 ppm. Two prognosed faults will be crossed along the planned hoizontal well path. Reservoir Pressure Res. press. is estimated to be 3300 psi at 8800ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2244 psi. TREE = 4-1/16" CrN W8...LHEAD= FMC A CTl..LA. TOR= BAKER KB. ELEV = 77.3' B F. ELEV = 46.8' KOP= 3050' Max Anae = 100 (ã2 9747 Datum MD = 9242' DatumTVD = 8800' SS ( U-15A SA FETY NOTES: ORGINA. L WELL U-15 WAS P&A'D W/ GMT & S NOT SHOWN ON THS DIAGRAM. U-15A EXCEEDS 70 ŒG @ 9300' & GOES HORIZONTAL @ 9500'. I 10-314" CSG, 45.5#, NT-80, ID = 9.953" H 3036' Minimum 10 = 3.725" @ 8923' 4-1 (2" HES XN NIPPLE 7-518" X 5-1/2" BKR A<R WI Hv1C LNR 1-K3R, ID = 4.938" I 4-1/2"1BG,12.6#,L-80,.0152bpf,D=3.958" 8932' 8934' I 7-518" CSG, 29.7#, NSCC, ID = 6.875" :-1 9086' PERFORATION SUMIvV\RY REF LOG: TCP PffiF ANGLEATTOP ÆRF: 55 @ 9178' I\bte: Refer to A-oduction DB for his torical perf data SIZE SA= INTffiV A L Opn/Sqz DATE 3-318" 4 9178'-9216' 0 08/02/95 3-318" 4 9340' -9400' 0 08/02/95 3-318" 4 9580' -9680' 0 08/02/95 3-318" 4 9720' -9820' 0 08/02/95 2213' 4-1/2" rES - HXO SSSV f\lP, 10 = 3.813" - GAS LIFT MANDRELS ST tv[) lVD DEV TYPE VLV LATCH SIZE D«\ TE 6 3172 3163 7 KBtv'G-M DV BK 04f2.7/01 5 5124 5070 20 KBtv'G-M DV BK 04f2.7/01 4 6639 6507 16 KBtv'G-M DV BK 04f2.7/01 3 7651 7483 16 KBtv'G-M DV BK 04f2.7/01 2 8414 8214 18 KBtv'G-M DV BK 04f2. 7/01 1 8728 8502 27 KBtv'G-M DV BK 04f2.7/01 8876' 8888' 8912' 8923' 8935' ~ x ')¡ v ~4-1/2" rES X NP, ID = 3.813" I ~ 7-5/8" x 4-1/2" BKR SABL-3 A<R. ID = 3.875" I ~4-1/2" rES X NP, D = 3.813"1 ~4-1/2" HES XN NIP, ID = 3.725" 1 ~4-1f2." WLEG, D =3.958"1 1-18...MD TT NOT LOGGED 1 OPEN HOLE SIDETRACK OFF CMf @ 9582' 10050' x x 5-1/2" LNR, 17#, L-80, 0.0232 bpf, ID = 4.892" -f 10138' 1 D«\ TE REV BY COMrvENTS DATE RBI BY ooWlv1ENTS 08/04/95 KSB ORIGINAL 00 rvPL EriON 02/05/01 SIS-QAA ooNVffiTED TO CANV AS 03/08/01 SIS-MD ANAL 07/01/01 CH'KAK ooRRECTIONS PRUDHOE BAY lJ'J1T WELL: U-15A ÆRMT I\b: 95-0970 APII\b: 50-029-22565-01 5173' NSL & 1809' W8... Sec. 19, T11 N, R13E BP Exploration (Alaska) ( REE: 4-1/16" FMC W/ 4"TREE CAP ELLHEAD: CAMERON CTUATOR: BAKER ( U-15b Proposed Completion KB. ELEV = 77.30' BF. ELEV = 46.80' 10 3/4"~~~:~ I 3,0361~ KOP: 2600' MAX ANGLE: Horizontal 4-1/2", 12.6#/ft, L-80, MOD, BTRS TUBING ID: 3.958" CAPACITY: .01522 BBUFT Top of 5-1/2 liner I 8,9321 7-5/8", 29.7#/ft, I NSCC, 13CR & 9,0861 ~ S95 MOD BTRS Top of Liner approx. 9060' MD (8694ss) PERFORATION SUMMARY Size SPF Interval Open/Sqzed 3-3/8" 4 9,178-9,216' Open 3-3/8" 4 9,340 - 9,400' Open 3-3/8" 4 9,580 - 9,680' Open 3-3/8" 4 9,720 - 9,820' Open . SSSV LANDING NIPPLE (HES-HXO) (3.813" ID) I 2,2141 GAS LIFT MANDRELS 4 1/2" X 1" Cameo KBMG-M W/ BK LATCH NQ MD(BKB) TVDss Dev 6 3,172 3,163 7.1 5 5,124 5,070 19.9 4 6,639 6,507 16.3 3 7,651 7,483 15.7 2 8,414 8,214 17.8 1 8,728 8,502 27.1 4-1/2" "X" NIPPLE I (HES) (3.813" ID) 8,8771 - ~ 7-5/8" PACKER ......-- {BAKER SABL-3 ){3.875"ID) I 8,8891 4-1/2" "x" NIPPLE I 8,9121 (HES) (3.813" ID) . . 4-1/2" "XN" NIPPLE 1 8,9231 ( HES) (3.725" ID) 4-1/2" WLEG 18,9361 (ELMD) 2 7/8" Sf-L Top of whipstock approx. 9990' MD hole angle = 89 deg. (' 38 CTD BOP Detail t Methanol Injection gtis 711 WLA Quick onnect - 7-1/16" 10,5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Flanged Fire Resistant Kelly Hose to Dual Choke Manifold G HCR 0 7-1/16" 10, 5000 psi worKing pressure Ram Type Dual Gate BOP~ TOT Manual over Hydraulic XO Spool as necessary Single Manual Master Valve (optional depending on RU) MOJ 5/21/01 -... CT Injector Head --- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ - T1 Riser Annular BOP (Hydril),7-1/1611 ID 5000 psi working pressure Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold I 2 7/811 Combi Pipe/Slip I 2 3/811 Combi Pipe/Slip 2 flanged gate valves 7" Annulus 9 5/811 Annulus I I BP Amoco WELLPATH DETAILS PI..#17 U-1.. .00n"""'02 Pa..., W.llpaü, TIe .. MD: U-1.A '110.00 RIg: Rot. D...... zs . 15 .128/..05 00000 71.0'" V.5octi.. ""0'. 77.00' O.~ S"m.. F......TVD Oris;. . EI-W 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (NÆ) Reference: Well Centre: U-15. True North Vertical (TVD) Reference: System: Mean Sea level Section (VS) Reference: Slot - 15 (O.OON.O.OOE) Measured Depth Reference: 25: 15 612611995 00:00 76.00 Calculation Method: Minimum Curvature "CnoN OETAILS ... "0 ... AzI 'TVJ ....... ..,.w OL.. TF... vSe. T...... 1 ..71.2. ""0 00.30 ""'35 1462.57 1151.92 0.00 0.00 1451.41 2 9900.00 ...... 00.13 .....64 146"50 1170... 3.53 345.12 "".., 3 10010.00"'" ...53 "20.85 148..56 1100..' ..00 -30.00 "".15 4- 10110.00"'47 7..53 NI...2 147..08 1280.0' 10.00 -00.00 "".1. 5 10330.00 ..... 101.53 "17.33 1470.06 1508.70 10.00 "'00 "".73 . 10830.00 81.70 71.53 Nlo... "'7." 1804..7 10.00 .....00 2093.14- 7 10050.00 100... ..... .774.87 186.... 2065.55 10.00 .7..00 2386.5. . 11500.00 101.09 ...77 8860.94 ,...... 2547.0' 10.00 84.00 US7..' . 12020.00 54.3& 7..5. 87."" ...5.73 3036.0. 10.00 ...5.00 33&2.47 ANNOTATIONS TARGETOETALS 1VO -.s +EI-W 5- TVD MD "".....10. 8820.35 1171.2. TIP 1120.84 'IIO.DO KOP 1120.1. 10010.00 1 11...12 10110.00 2 1117.33 10330.DO 3 1110'" 10130.00 . 8774.17 101S0.00 . 1180.84 11500.00 . 1711.., 12020.00 TO 7600 - 7700 7800 -7900 C ~ = 8000 0 0 "I'" 8100 - .c 8200 .. Do & 8300 ëi 8400" U :e 8500' Q) > 8600 Q) :s ~ 8700 8800- 8900 9000 9100 800 . . . . . . .' . . . 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 190020002100220023002400250026002700280029003000 310032003300340035003600370038003900400041004200 4300 4400 4500 4600 Vertical Section at 77.00. [100ft/in] 9/6/2001 11:09AM 2200 - c ~ 2100- = 0 02000- "I'" - _1900 . + - .c 1800 1:: ~ 1700 - - . . -1600' .c .. Š 1500 en 1400 Of] -------- ------ T l Plan: Plan #17 (U.151PIan#17 U.15B) Created By: Brij Potn;s Date: 91612001 lEGENO N-11A(N-11A) --- U-15 (U-15) - U-15 (U-15A) - U-15 (U-15APB1) - U-15 (U-15APB2) - Plan#17U-15B Plan #17 Azimuths to True North Magnetic North: 26.44' Magnetic Field Strength: 57482nT Dip Angle: 80.77' Date: 9/6/2001 Model: BGGM2001 B. --- Con\aç\ ir,f;.wndt;Ot.. i ! I ! O,¡<;r.l.r:,O7¡Lü'!.¡,r,i3 E."",¡!: b,i¡D.)t!,,:;,¡~ir,tcQ'cm Bé!~f:' H¡¡\1i1('~ iNTEO' ;'JÓ7ì 2f;ì-t-:'t;;;r¡ 2600 , j ¡ , , ¡ ! ¡ f I í j 2500 2400 2300- è N-11A{N-11A), .--, : PI.ñ#17 u.15B1 /""'"'"'-"-'_uu,u"u_"~(~-,_uu",,--u_,,u,---,,'--'---""-.--.-.-,." i., 'TO} //' ,/ .../ ;'51 / , ':/ ~, ..j~-;-----¿~'-;-~~~/// 1200 .. 1100-- 1000 . ---, 1000 1100 1200 1300 1400 1500 1600 1700 1800 190020002100220023002400250026002700280029003000 3100 3200 3300 3400 3500 3600 West( - )/East( +) [1 OOft/i n] f \ J ' í \ ! \ ! \ I \ I I J W - \ / "~"~""., \ æ . ---.....,..--/.,..--...."""""'-"'-"" ...._---~~""""'" ! TO ¡ \ .. ..-----" . f ""-J \ u_..:":,,,......./_uu_..---"""""""- ;- \ f \ f \ ¡ \ /J N-11A (N-11A); t;U~-j5 (ll-IS») j.{,.. 0,- -;-" bp ( BP Amoco Baker Hughes INTEQ Planning Report ( lB.. IIAIŒII HUGHES '_'..__n..-"--"---"----""'--"--"'-- INTEQ ------.---------,,-------------.---------.------ - - ,---_.. ,-----__'___m______--..-----------------------------------. --'--"-'--__n-n______- ------ ------------- ------- --.-------------- - Company: BP Amoco ; Field: Prudhoe Bay : Site: PB U Pad I ! Well: U-15 L__!!_I!!>..~~~ ...!:I~_~ ~~_? -- ~ =!~~- .-- - -- ----- - - --- - -- - Date: 9/6/2001 Time: 11:14:31 Co-ordinate(NE) Reference: Well: U-15, True North Vertical (fVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,O.00E,77.00Azi) Survey Calculation Method: Minimum Curvature Db: Page: 1 Oracle n----------- ---_----_n____'---------------'---------------------- -.. ___n--- --- -_--__---_n--_- -----~------------ ------------ --.----- -----.. ---------- --- - - - --- -- ---..- --- Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 .. Geo Datum: NAD27 (Clarke 1866) :_-~~~~~~_!-'!..~~-~~~~~~el_____- - ------- ----- ...---- ---------------------------- ---- ------- ------- --- .-- ------ -- Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 ------------------------------- ----------------------------_____--n -------_..-- -- ___n-"--_------------------ -..------------------------..- - - -------.---- ----- -- - - - -- .. -- - - - -.. Site: PB U Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5960534.13 ft 630178.07 ft Latitude: 70 18 1.170 N Longitude: 148 56 44.315 W North Reference: True Grid Convergence: 0.99 deg -------.._---- ------------- - ..-__--_n------- - --- --.. - ------_.._-,,- -- ---- ---- -----_.._----------~------------------------------------- - _"__m m- --. - -------- ---- .------ --- ----,,---------- .. ..----..----...-..--------- ------- ----,--------- ---------------"-----"-------"---"-'------- ---______m____._--------..----- -.-.---------------------------______n__n___'- ..----- -----.. ----. Well: U-15 U-15 Well Position: +N/-S -91.23 +E/-W 2017.93 Position Uncertainty: 0.00 Slot Name: 15 ft Northing: ft Easting: ft 5960477.88 ft 632197.12 ft Latitude: Longitude: 70 18 0.271 N 148 55 45.486 W ----..---..---------..---..--..-...----...... ....-----------_... - - ---- -- . -. - '-______n..n_._n______----------------"-----'-----'--- -------.----.....-..------------- "- ----------_..--_n-- __n - - ---------.._---------- ----"------m_-' m.._..__...--------.--------.- --- - .-------..--- ..--...----------- ----------..--.---------------------- _..-.- --------------...-----...-.. Wellpath: Plan#17 U-15B 500292256502 Current Datum: 25: 156/26/199500:00 Magnetic Data: 9/6/2001 Field Strength: 57482 nT Vertical Section: Depth From (TVD) ft ------.....------..-------------.--------.--..--.-..- -_. 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: 76.00 ft Above System Datum: Declination: Mag Dip Angle: +E/-W ft . ----- - - ---- . 0.00 ....-"--------- --------.. U-15A 9990.00 ft Mean Sea Level 26.44 deg 80.77 deg Direction deg 77.00 ------_..-------.._-- ..- -- ---- ----- Height --- - ------.. -----.-.._.__mm--"'" ---------.---....- - "-----,--,---"",----"--,,,,,,-,,---"-'----"~----"--------"--..-......-----..-..--------" -........"___m__.........-..-- ...."- "_n ..-- --.- :~:::iPal: - :~:#17-- -. . -.----"" -...- - ----- --- - .-- -. ---.- -..-. - --- --- - .. ]:Æ~~tp~~d:~~::..:t~:::~fin~~e~at~_::~:::~~.~:."-- Targets ..",.-..,....-..-......-..-...--....,...,..........-...-.-......,........................................".... ........""""'...,................."".".'........-...........".".,"'.."""--"",,,-"""'-""'-......._mm."'.-".-""""..."",,'---"..-..-...-......-......_n._._.....-.--....--.-""""""""""""-"...................................-......-..............,..,.. ......................,..,.................-.................. """""""""""",.,. Map Map <---- Latitude ---> <--- Longitude ---> I Name Description" TVD +N/-S +E/~W Northing Easting Deg Min Sec Deg Min See t=~=.=~~~..~~~~:,~~:~_:~-=-~=-:-~~::~~.._-~=~-~_..,-:~~~~=-~::"".~~:=~::~-~::'~..~-::-=:-_:-~~~'::~~-:::-:-:::~-:"~=::~:::=..~=~::..:~==:~~~::==:::'=:-_:':-~."~'=:~~~~:_:..~-..=:-:-:""--:..--:-::::"'~...--~=--~:-:~~-."=--:_-~"':=:'::'.."-] Annotation lID TVD ft ft . . 9971.26 8820.35 TIP 9990.00 8820.64 KOP 10010.00 8820.65 1 10110.00 8819.82 2 10330.00 8817.33 3 10630.00 8810.59 4 10950.00 8774.67 5 11500.00 8660.94 6 12020.00 8769.91 TD . . . ...... .' . ........ --"'.'- ..-.-._..___m__._.._--........-.- -. ...... .-.-.- -.... _.----- _.......-- --. - -- .. --.----..---.-. . -..--.....-.. - --.. .--..-.--... -- .._--..-- .-..- m.._...._...- -....'-.-- .-- ----.-.---...-------...__-----__m_""'__'-- ---....-...".....- ... ... .-".'....-..- ""--'.-"--- Plan Section Information ¡-- MD ~i~cl Azim ---TVD---------Ï-N/-S --..--- +Ei-W-_.._-~nDis-"--ßuild ---"T~-;-;'----iFO--T;';grt'----"-----""------"'---l ;-----_....~-_.........9:~.- ......_..._~:~_.. .-..... .............___ft,__.._..- "'_0'" ~........_m.:~____. _?~~(~.~~~_9:.~(~.~~~_.~,:~/!~~~_. -~:g- ......... ..o" ..--...--....-.-- . ..--_.-' .....-.....-....... -'. 9971.26 88.80 90.30 8820.35 1462.57 1151.92 0.00 0.00 0.00 0.00 9990.00 89.44 90.13 8820.64 1462.50 1170.66 3.53 3.42 -0.91 345.12 10010.00 90.48 89.53 8820.65 1462.56 1190.66 6.00 5.20 -3.00 -30.00 10110.00 90.47 79.53 8819.82 1472.08 1290.08 10.00 -0.01 -10.00 -90.00 10330.00 90.81 101.53 8817.33 1470.06 1508.70 10.00 0.15 10.00 89.00 10630.00 91.70 71.53 8810.59 1487.99 1804.67 10.00 0.30 -10.00 -88.00 10950.00 100.89 40.66 8774.67 1662.40 2065.55 10.00 2.87 -9.65 -72.00 11500.00 101.09 96.77 8660.94 1850.09 2547.01 10.00 0.04 10.20 84.00 ----------..--.-...-----.----..-.--..--..-- ----..-.....-.------.-.-.---.----...-... ----.--.-..-'.'-__.___m..._'- - . ------------.- .---.....---------.--- ...-.. --____'.m___-"_"'_._'_m__._...-..-..-...-.-".---....-.-----.---..---.....---..---....-..-.----.--------- ObP ( BP Amoco ( Baker Hughes INTEQ Planning Report Bíí8 BAIŒIt HUGIIIS -"-""""""""""-'-""'--""""'-' INTEQ ,-_0._-"'0."'-""-- .._M"_...'__..-.--- --"-"-"'0., ..--.... .-.-..--....----'-.----.----......--------..."""h_"h.'_----.---.---.-...------- -...__h. -..----....--.-'----_h____h____'_-'--------"--'-----"___""_h I i Company: BP Amoco I Field: Prudhoe Bay j Site: PB U Pad I Well: U-15 ; Wellpath: Plan#17 U-15B Date: 9/6/2001 Time: 11:14:31 Page: 2 Co-ordinate(NE) Reference: Well: U-15, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,O.00E.77.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle "_..___m_h_h___....---.-..--......--..--..--..---...-....--..--.--....---..........__h...__..--..........----...........h- ..-..----.-.--.....................................-....m-"h'h"'......-"-"-..--...--..--_..""'__hh,,"mm_.___.-"'-"_'-_._m._......-..---"""'_mm_- "'....."'-"""-"-.'-" .. m_"""'hhh"_'_"'-"""-"'-"'-"""""""""---.._..._.h'.......--' Plan Section Information --. . "'0._--" -- --'-.-.. -.-. .---.--- ----------...-----. ---..... _m_____- __h'-- .--..-"'-.--- '----'-._"'_h.... ..-.. ....h____h_____...h______------------ MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target . ft deg deg ft ft ft deg/100ft deg/100ft deg/10OO deg , L- ..... .... .-...... """_"m.. ..-.... _. ........ .-. .......... .-..... ..'" ..0.---'" ........... ...... 0..... ...... ......... -... ..h.. ....... _h.... ........--...-. ."--""....-. ...-. "0._-"'-"" _......... -.... "_h"-"'-'-'-'-"-"-'-""-"" """"h"'.....--_...-_..... _""h""'" hh........h"""""', h"_". --"'....."""'" ....-. ...._--.....-....h' .......h.. hh.... ........ .-...... ..hh.h ...-. ... .....'" ""-' .......- ....... ""_h -h_"__'_"""" 12020.00 54.38 72.59 8769.91 1885.73 3036.09 10.00 -8.98 -4.65 -155.00 Survey '--'---'-'----"'---_--___h--- -'--'.- ---.-..--- ----...---___--__n --_m,___,,-_"_h ----.- ---"'.---h'__--m'-'h'_'__'--'--"-' ------"-'----------~---'--'--'---'--'---"-'-----'- ._._----~ --. h______---'_____m_'_'h'---_'--"~-'--'--'", '----'---'--'-"-----------""'- -- -----'-"""'-'-- MD ft 9971.26 9975.00 9990.00 10000.00 10010.00 10025.00 10050.00 10075.00 10100.00 10110.00 10125.00 10150.00 10175.00 10200.00 10225.00 10250.00 10275.00 10300.00 10325.00 10330.00 10350.00 10375.00 10400.00 10425.00 10450.00 10475.00 10500.00 10525.00 10550.00 10575.00 10600.00 10625.00 10630.00 10650.00 10675.00 10700.00 10725.00 10750.00 10775.00 10800.00 Incl deg 88.80 88.93 89.44 89.96 90.48 90.48 90.48 90.48 90.47 90.47 90.50 90.54 90.58 90.62 90.66 90.70 90.73 90.77 90.80 90.81 90.88 90.96 91.05 91.13 91.21 91.28 91.36 91.43 91.50 91.57 91.63 91.69 91.70 92.32 93.08 93.85 94.60 95.35 96.09 96.82 10825.00 97.53 10850.00 98.23 10875.00 98.92 10900.00 99.59 10925.00 100.25 10950.00 100.89 10975.00 101.14 11000.00 101.37 Azim deg 90.30 90.27 90.13 89.83 89.53 88.03 85.53 83.03 80.53 79.53 81.03 83.53 86.03 88.53 91.03 93.53 96.03 98.53 101.03 101.53 99.53 97.03 94.53 92.03 89.53 87.04 84.54 82.04 79.54 77.04 74.54 72.03 71.53 69.63 67.24 64.86 62.47 60.07 57.67 55.27 52.85 50.43 48.00 45.56 43.12 40.66 43.19 45.73 SSTVD ft 8820.35 8820.42 8820.64 8820.69 8820.65 8820.52 8820.32 8820.11 8819.90 8819.82 8819.69 8819.47 8819.22 8818.96 8818.68 8818.39 8818.07 8817.75 8817.40 8817.33 8817.04 8816.63 8816.19 8815.72 8815.21 8814.67 8814.09 8813.48 8812.84 8812.17 8811.47 8810.75 8810.59 8809.89 8808.71 8807.20 8805.36 8803.19 8800.70 8797.89 8794.77 8791.34 8787.61 8783.58 8779.28 8774.67 8769.89 8765.01 N/S ft 1462.57 1462.55 1462.50 1462.50 1462.56 1462.88 1464.28 1466.77 1470.35 1472.08 1474.61 1477.97 1480.24 1481.43 1481.53 1480.53 1478.45 1475.28 1471.04 1470.06 1466.41 1462.81 1460.29 1458.86 1458.51 1459.26 1461.10 1464.02 1468.02 1473.09 1479.23 1486.42 1487.99 1494.64 1503.81 1513.94 1525.00 1536.97 1549.83 1563.55 1578.11 1593.47 1609.62 1626.51 1644.12 1662.40 1680.66 1698.15 E/W ft 1151.92 1155.66 1170.66 1180.66 1190.66 1205.66 1230.61 1255.49 1280.23 1290.08 1304.86 1329.63 1354.53 1379.50 1404.49 1429.47 1454.38 1479.17 1503.80 1508.70 1528.36 1553.09 1577.96 1602.91 1627.90 1652.89 1677.81 1702.63 1727.30 1751.76 1775.99 1799.92 1804.67 1823.52 1846.74 1869.55 1891.89 1913.73 1935.02 1955.73 1975.81 1995.23 2013.94 2031.92 2049.13 2065.55 2081.95 2099.12 MapN ft 5961960.37 5961960.42 5961960.63 5961960.81 5961961.04 5961961.62 5961963.47 5961966.40 5961970.40 5961972.31 5961975.10 5961978.89 5961981.60 5961983.23 5961983.77 5961983.21 5961981.57 5961978.84 5961975.03 5961974.13 5961970.83 5961967.66 5961965.58 5961964.59 5961964.69 5961965.87 5961968.15 5961971.51 5961975.94 5961981.44 5961988.00 5961995.61 5961997.27 5962004.24 5962013.83 5962024.35 5962035.80 5962048.15 5962061.38 5962075.46 5962090.37 5962106.08 5962122.55 5962139.75 5962157.66 5962176.22 5962194.76 5962212.56 MapE ft 633323.04 633326.78 633341 .78 633351.77 633361.77 633376.76 633401.68 633426.51 633451.18 633461.00 633475.74 633500.44 633525.29 633550.23 633575.22 633600.21 633625.15 633649.99 633674.69 633679.60 633699.32 633724.12 633749.02 633773.99 633798.98 633823.95 633848.83 633873.59 633898.18 633922.56 633946.67 633970.47 633975.19 633993.92 634016.97 634039.59 634061.74 634083.36 634104.42 634124.88 634144.70 634163.84 634182.27 634199.95 634216.85 634232.94 634249.01 634265.87 DLS deg/100ft 0.00 3.53 3.53 6.00 6.01 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.02 10.02 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 9.99 9.99 10.00 10.00 VS ft 1451.40 1455.04 1469.65 1479.39 1489.15 1503.83 1528.46 1553.26 1578.17 1588.16 1603.14 1628.03 1652.79 1677.39 1701.77 1725.88 1749.68 1773.13 1796.17 1800.72 1819.06 1842.35 1866.01 1890.00 1914.28 1938.78 1963.48 1988.32 2013.26 2038.24 2063.22 2088.16 2093.14 2113.00 2137.69 2162.19 2186.45 2210.42 2234.06 2257.32 2280.16 2302.54 2324.41 2345.73 2366.46 2386.57 2406.65 2427.32 TFO deg 0.00 TI P 345.12 MWD 345.13 KOP 330.00 MWD 330.04 1 Tool 270.00 MWD 269.99 MWD 269.97 MWD 269.95 MWD 269.77 2 89.00 MWD 89.01 MWD 89.04 MWD 89.06 MWD 89.09 MWD 89.11 MWD 89.14 MWD 89.17 MWD 89.21 MWD 89.25 3 272.00 MWD 271.97 MWD 271.93 MWD 271.89 MWD 271.84 MWD 271.79 MWD 271.73 MWD 271.68 MWD 271.62 MWD 271.55 MWD 271.48 MWD 271.39 MWD 271.31 4 288.00 MWD 287.93 MWD 287.82 MWD 287.68 MWD 287.50 MWD 287.29 MWD 287.05 MWD 286.78 MWD 286.48 MWD 286.15 MWD 285.79 MWD 285.47 MWD 285.05 5 84.00 MWD 84.48 MWD -. -------'----""'h"--'-- -'-....-....._- ---- ..--....._- ....--. -. -- --.........-...-_._.."'h_"_---'-'------'-"""-----_""--_"h___."---------------_.._----"-~__"_'_h--__._.._--..._..._-----_.._- ""--,,,---,-----'------"-'---'" ObP ( BP Amoco ( Baker Hughes INTEQ Planning Report R.8 BAKD HUGHES --------------- - - -- ------------ ---------- -- -- --,,- -- --------" ,,--,,- - --- -",,-- ------ --"--------_.-"-------"-----"---------------""---"---"------__--___m______------,,---------------,,---------u_----,,------.._-" ------- ------------'-----------------------.- lNT EQ Company: BP Amoco Date: 9/6/2001 Time: 11:14:31 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: U-15, True North Site: PB U Pad Vertical (TVD) Reference: System: Mean Sea Level Well: U-15 Section (VS) Reference: Well (0.00N.0.00E.77.00Azi) l_m~~~~~!_~~-~!~~~!_~~!?_~-----__..__--m______----------------.----- ---- - ----,,-----,,--,,-_.,,-------_.----~~~~~--~~~~~!~~~~-~~.!~-~~~-- ----__~~_i~~_~_~-~~~!~~~"__--_m___"__~~:w_-_9._~?!~-------,,-,,-- Survey i--- -MD- - ..-- -" "I~~ï- - ¡;¡;'-----SS-iVD--------N/S-------------E¡W------ MapN ---M~pE-------DL-S---------VS---------TFO------T~~i-----I l______----~----------_.._~_~~m- -" ---" - -- -~-~~u_-- -_m_-----~----_____--m__m --"" -~" - -- -- - ---------" -- ~- -"" -" --_m--.------------- -_!!- -- ___--_m- ----------" -u- - ~- -- -- ---" --" """-~-~~~--~?~____'_m'~ - ,-" -'----, ,--..- ,----~ ~~'" - on - ".", ----", ------ -- -" - '" - j 11025.00 101.58 48.27 8760.04 1714.86 2117.04 5962229.58 634283.49 10.00 2448.54 84.98 MWD 11050.00 101.76 50.82 8754.98 1730.74 2135.66 5962245.79 634301.83 10.00 2470.26 85.49 MWD 11075.00 101.93 11100.00 102.07 11125.00 102.18 11150.00 102.28 11175.00 102.35 11200.00 102.39 11225.00 102.41 11250.00 102.41 11275.00 102.39 11300.00 102.34 11325.00 102.26 11350.00 102.16 11375.00 102.04 11400.00 101.90 11425.00 101.73 11450.00 101.54 11475.00 101.33 11500.00 101.09 11525.00 98.82 11550.00 96.55 11575.00 11600.00 11625.00 11650.00 11675.00 11700.00 11725.00 11750.00 11775.00 11800.00 11825.00 11850.00 11875.00 11900.00 11925.00 11950.00 11975.00 12000.00 12020.00 94.28 92.01 89.73 87.46 85.18 82.91 80.64 78.37 76.11 73.85 71.60 69.36 67.12 64.89 62.67 60.47 58.28 56.11 54.38 53.37 55.92 58.48 61.03 63.59 66.15 68.71 71.27 73.83 76.39 78.94 81.50 84.05 86.61 89.15 91.70 94.24 96.77 95.70 94.65 93.60 92.56 91.52 90.48 89.44 88.39 87.34 86.26 85.17 84.06 82.92 81.76 80.55 79.31 78.02 76.68 75.28 73.81 72.59 8749.85 8744.65 8739.40 8734.10 8728.77 8723.41 8718.04 8712.67 8707.30 8701.95 8696.62 8691.33 8686.09 8680.90 8675.78 8670.74 8665.78 8660.94 8656.62 8653.27 8650.91 8649.54 8649.17 8649.78 8651.38 8653.98 8657.55 8662.11 8667.63 8674.11 8681.53 8689.88 8699.15 8709.32 8720.36 8732.26 8745.00 8758.54 8769.91 1745.77 1759.92 1773.16 1785.47 1796.82 1807.19 1816.56 1824.91 1832.24 1838.51 1843.73 1847.88 1850.95 1852.94 1853.85 1853.67 1852.40 1850.09 1847.42 1845.18 1843.39 1842.05 1841.16 1840.73 1840.74 1841.21 1842.13 1843.50 1845.32 1847.59 1850.29 1853.43 1857.00 1860.99 1865.39 1870.20 1875.41 1881.00 1885.73 2154.97 2174.91 2195.45 2216.56 2238.18 2260.29 2282.83 2305.77 2329.06 2352.66 2376.52 2400.60 2424.85 2449.22 2473.67 2498.16 2522.62 2547.01 2571.49 2596.16 2620.98 2645.90 2670.88 2695.87 2720.82 2745.68 2770.40 2794.94 2819.25 2843.29 2867.01 2890.36 2913.30 2935.79 2957.78 2979.23 3000.10 3020.35 3036.09 5962261.15 5962275.65 5962289.25 5962301.92 5962313.65 5962324.41 5962334.17 5962342.93 5962350.66 5962357.35 5962362.98 5962367.55 5962371.05 5962373.47 5962374.81 5962375.06 5962374.22 5962372.34 5962370.10 5962368.30 5962366.95 5962366.05 5962365.60 5962365.60 5962366.05 5962366.96 5962368.31 5962370.12 5962372.36 5962375.05 5962378.17 5962381.72 5962385.69 5962390.07 5962394.86 5962400.05 5962405.62 5962411.57 5962416.58 634320.87 634340.56 634360.86 634381.75 634403.17 634425.09 634447.46 634470.25 634493.40 634516.89 634540.65 634564.65 634588.84 634613.17 634637.60 634662.08 634686.56 634710.98 634735.50 634760.21 634785.06 634810.00 634834.99 634859.98 634884.92 634909.76 634934.46 634958.97 634983.25 635007.24 635030.90 635054.19 635077.07 635099.48 635121.38 635142.75 635163.52 635183.67 635199.32 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 9.99 9.99 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 9.99 2492.45 2515.06 2538.06 2561.39 2585.02 2608.89 2632.96 2657.19 2681.53 2705.94 2730.36 2754.75 2779.07 2803.27 2827.30 2851.11 2874.67 2897.91 2921.16 2944.70 2968.48 2992.46 3016.60 3040.85 3065.16 3089.49 3113.78 3138.01 3162.10 3186.03 3209.75 3233.21 3256.37 3279.17 3301.59 3323.57 3345.08 3366.07 3382.47 86.00 MWD 86.52 MWD 87.05 MWD 87.59 MWD 88.13 MWD 88.68 MWD 89.23 MWD 89.78 MWD 90.33 MWD 90.88 MWD 91.42 MWD 91.97 MWD 92.51 MWD 93.05 MWD 93.57 MWD 94.10 MWD 94.68 MWD 95.18 6 205.00 MWD 204.82 MWD 204.67 MWD 204.58 MWD 204.52 MWD 204.50 MWD 204.53 MWD 204.59 MWD 204.70 MWD 204.85 MWD 205.05 MWD 205.29 MWD 205.58 MWD 205.92 MWD 206.31 MWD 206.75 MWD 207.26 MWD 207.83 MWD 208.47 MWD 209.18 MWD 209.89 TO -.. ---_u,-"--,, -" """" ----"".....- - ,,---- --_._...__..",-,._---,,----------- -""'---'---____,_m--__- --.--..---..------,,----------------,,-- "---,,--,-" ,,---'------,,----"-""--_'___n.._..___----,--,,--------"- , (' .," i( H 194721 107 ITImrl I CHECK N°'1 00194721 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 072701 CK072701L PYMT OMMENT5: HANDL NG INST: 100.00 100.00 Per it To Drill ee 5tH - Terrie Hub Ie X4628 U.\<$8 TOTAL ~ IE ATIACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. 100.00 100.00 f. '. ,,' FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 194721 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 --¡:j"2 00194721 PAY ONE HUNDRED 8c 00/ 1 OO~'**~*************t*';~*~**~.*********** US DttJLLAR To The ORDER Of ',.'.DATE. """ I I 07./3'1101 , '.., "'f",,, , , , , , ' ii',AMOÜNT , '; ~1 O~ti:@q;;1 ' , ,'" , , ' , " ' .. , , , . ' " ,ALASKA OIL AND GAS, "'CONS;ER V ~f IO~COMMI aSION. 333WESm, 7TH ,AVENUE '" "" SUITE 100 ' ' ANCHORAQ~ NOTVALlQ~FTERi20, DAYS " AK 99501 ~J¡~~:: III . g ~ 7 2 .111 I: 0 ~ . 2 0 ~ 8 g 51: 008 ~ ~ . gill CHECK 1 ST ANDARD LEITER DEVELOPMENT D EVELO PMENT REDRILL ~. EXPLORATION INJECTION WELL INJECTION WELL RED RILL ( ( TRANSMIT AL LETTER CHECK LISl CIRCLE APPROPRIATE LETIER/P ARAGRAPHS TO BE INCLUDED IN TRANSNUTTAL LETTER rL)d d-/~¡5 WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DIsPOSAL ( I Æ NO 1:7""" ANNULAR DISPOSAL L-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new well bore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved, subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY WELL NAME L/-/~ PROGRAM: exp - dev - redrll FIELD & POOL I INIT CLASS ~V I Ó! L- GEOL AREA D ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Uniquewellnameandnumber:t. . . . . . . . . . . . . . . . N.~ P~\ft~...r~ ~V\1;'.{;-y LL-¡Ç}3 ~ire..d ~/¥.61(Píj)#1C¡7-06ï~.)ÝA 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N ---------rT ~ 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available. in drilling unit.. . . . . . . . . . . N. 8. If deviated, is wellböre plat induded.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N 12. Permit can.be issued without administrative approval.. . . . . N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N ~ i: ~;~;~~~~~?;¡II:I~~ ~~~:~~ i ~~rt .~g.: .: .: : .: ,vA ~ ~1 o~ ~,:~ :::: ~ ':::: ~ 17. CMT vol adequate to tie-In long string to suñ csg. . . . . . . . Y N \ ""> 18. CMT will cover all known productive horizons. . . . . '. . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ~'\.-=:'\\\t'~.~ t ...",D 'Nè~~"")Cr..~\\- 21. If a re-drill, has a 10-403 for abandonment been approved. . . N SO\-?-C¿; .7 ~ ~ k.~~ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N ~~\c~ Q.?~tC~C:: . . Ct.~- -' . 23. If diverter required, does it meet regulations. . . . . . . . . . ~ N. ~ ~ 24. Drilling .fluid program schematic & equip list adequate. . ~ . . ~ N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . l&) N { OA b..; . 26. BOPE press rating appropriate; test to ~sig. Qþ N '--'- ¡,., "':>\> .." \.Q? ;;2.;;1'1.\ '-\ V'; \ . '. . (J.). 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ N . . ~~. WI ork will °ca;rH~hout ope~a~fn shutdown. . . . . . . . . . . Y ~\-\J¿)~\u~\ <:':)t;: \-\)' ~ \'; Q ~ ~ ~ ( . ~ \: . s presence 0 2 gas pro a e.. . . . . . . . . . . . . . . . '-!V... - ~.. '. ':> 1 ~'«-~":;\£, . ~. "'- Q~^ ;~: 6:~~r:~~t:~s~~ep~:'~ti:Y:~~;~e:~~~ez~~::u.r~s.. .. ...... . A~~ /~~ ~ /JtL4S~ ¿z ~ . //~ d-/s;-# 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . .. AI, ~ APOO DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . /' Y N ~ 7"" Z9'tD I 34. Contact name/phone for weekly progress reports [exploratt>ry only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. , (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface;" ' (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING:.' UIC/Annular COMMISSION: Rr;ð . WM ~. '8~ S ,~ t 0( '-.. JM~ serv well bore seg _ann. disposal para req- UNIT# 0/ /to 5Z::) ON/OFF SHORE ðr¡ c 0 Z 0 -t :E ::0 ( APPR DATE I c:¡ 21)10 ENGINEERING - -f' m - Z -f J: GEOLOGY - APPR DATE Y N Y N en » ::0 m :Þ l \ /_., " ---".-.----.-'-- . Com m entsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ( ~, 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. ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Sep 18 12:56:57 2002 Reel Header Service name... ........ ..LISTPE Date.....................02/09/18 Origin...................STS Reel Name...... ......... . UNKNOWN Continuation Number... ...01 Previous Reel Name...... . UNKNOWN Comments.................STS LIS Tape Header Service name............ .LISTPE Date.....................02/09/18 Origin...................STS Tape Name.. ........... ...UNKNOWN Continuation Number..... .01 Previous Tape Name.... ...UNKNOWN Comments....... ......... .STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. MWD RUN 4 AK-MW-lll93 B. JAHN MCMULLEN/CUB MWD RUN 7 AK-MW-ll193 B. JAHN MCMULLEN/CUB MSL 0) Writing Library. Writing Library. U-15B 500292256502 BP Exploration Sperry Sun 18-SEP-02 MWD RUN 5 AK-MW-lll93 B. JAHN MCMULLEN/CUB 19 llN 13E 5172 1808 77.30 .00 .00 ( Scientific Technical Services Scientific Technical Services (Alaska), Inc. MWD RUN 6 AK-MW-ll193 B. JAHN MCMULLEN/CUB OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.625 9086.0 5.500 9040.0 ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE aO} -)91 !Jo't3 ( ~.. NOTED. 2. MWD RUN 4 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. MWD RUNS 5 - 7 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 4. ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) DATA FROM 9653' MO, 8846' SSTVD TO 10003' MO, 8852' SSTVD WAS OBTAINED ON A MADPASS WHILE PULLING OUT OF THE HOLE BEFORE DRILLING MWD RUN 5 AND IS APPENDED TO TOP OF MWD RUN 5 DRILLING DATA TO COMPLETE THE RESISTIVITY DATA. 5. GAMMA RAY (SGRC) DATA IS REALTIME FROM 11148' MO, 8744' SSTVD TO 11352' MO, 8696' SSTVD DUE TO UNRECOVERABLE RECORDED DATA. 6. DEPTH SHIFTING / CORRECTION WAIVED PER THE EMAIL FROM D. SCHNORR OF 02/08/02. MWD CONSIDERED POCo THIS WELL KICKS OFF FROM U-15A AT 9640' MO, 8845' 88TVD (TOP OF WHIPSTOCK) ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 4 - 7 REPRESENT WELL U-15B WITH API # 50-029-22565-02. THIS WELL REACHED A TOTAL DEPTH OF 11395' MO, 8685' SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY 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 $ File Header Service name............ .ST8LIB.001 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation..... ..02/09/18 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS 1 clipped curves; all bit runs merged. .5000 START DEPTH 9636.5 9653.0 9653.0 9653.0 STOP DEPTH 11352.0 11366.0 11366.0 11366.0 ( t , RPX ROP FET $ 9653.0 9667.5 9678.5 11366.0 11395.0 11366.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 4 5 6 7 MERGE TOP 9636.5 10030.5 10585.5 11190.5 MERGE BASE 10030.0 10585.0 11190.0 11395.0 # REMARKS: MERGED MAIN PASS. $ # 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 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 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9636.5 11395 10515.8 3518 9636.5 11395 ROP MWD FT/H 0.45 3691. 57 61.9373 3456 9667.5 11395 GR MWD API 20.43 200 51.9414 3432 9636.5 11352 RPX MWD OHMM 0.59 2000 12.6096 3427 9653 11366 RPS MWD OHMM 0.14 2000 17.7525 3427 9653 11366 RPM MWD OHMM 0.1 2000 22.9492 3427 9653 11366 RPD MWD OHMM 0.16 2000 31.8477 3427 9653 11366 FET MWD HR 0.28 27.5 5.79179 3376 9678.5 11366 First Reading For Entire File......... .9636.5 Last Reading For Entire File......... ..11395 File Trailer Service name. ......... ...STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...02/09/18 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...... .....1.0.0 Date of Generation. .... ..02/09/18 Maximum Physical Record..65535 File Type. .......... ... ..LO Previous File Name..... ..STSLIB.001 Comment Record FI LE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ( header data for each bit run in separate files. 4 .5000 START DEPTH 9636.5 9667.5 STOP DEPTH 10001. 0 10030.0 # 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ # 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 28-NOV-01 Insite 4.05.5 7.75 Memory 10030.0 85.9 90.7 TOOL NUMBER 002 3.750 F10 Pro 8.60 62.0 9.0 15600 9.6 .150 .072 .200 .230 68.0 150.0 68.0 68.0 ( ( Max frames per record............ .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9636.5 10030 9833.25 788 9636.5 10030 ROP MWD040 FT/H 1. 26 99.15 66.8194 726 9667.5 10030 GR MWD040 API 20.43 93.82 31. 856 730 9636.5 10001 First Reading For Entire File. ........ .9636.5 Last Reading For Entire File... .... ... .10030 File Trailer Service name.... ........ .STSLIB.002 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .02/09/18 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...... .02/09/18 Maximum Physical Record. .65535 Fire 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 RPM RPD RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 5 .5000 START DEPTH 9653.0 9653.0 9653.0 9653.0 9678.5 10001.5 10030.5 STOP DEPTH 10554.5 10554.5 10554.5 10554.5 10554.5 10540.5 10585.0 # 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: 30-NOV-01 Insite 4.05.5 3.3 Memory 10585.0 88.4 ( 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 Max frames per record..... ....... .Undefined Absent value............... ...... .-999 Depth units....................... Datum Specification Block sub-type...O ( 92.3 TOOL NUMBER 69706 PB02279RF3 3.750 FloPro 8.70 62.0 8.5 14400 5.0 .240 .113 .220 .250 67.0 150.0 67.0 67.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 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 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9653 10585 10119 1865 9653 10585 ROP MWD050 FT/H 0.45 3691. 57 58.3713 1110 10030.5 10585 GR MWD050 API 21.16 177.41 62.9316 1079 10001. 5 10540.5 RPX MWD050 OHMM 0.59 2000 9.60208 1804 9653 10554.5 RPS MWD050 OHMM 0.14 2000 14.1567 1804 9653 10554.5 RPM MWD050 OHMM 0.1 2000 15.9352 1804 9653 10554.5 RPD MWD050 OHMM 0.16 2000 14.2162 1804 9653 10554.5 FET MWD050 HR 0.35 23.02 8.84128 1753 9678.5 10554.5 First Reading For Entire File........ ..9653 Last Reading For Entire File. ....... ...10585 ( File Trailer Service name...... ...... .STSLIB.003 Service Sub Level Name... Version Number.. ... .... ..1.0.0 Date of Generation... ... .02/09/18 Maximum Physical Record. .65535 File Type............ ... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .02/09/18 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 RPD RPM RPS RPX ROP $ 4 (' header data for each bit run in separate files. 6 .5000 START DEPTH 10541. 0 10555.0 10555.0 10555.0 10555.0 10555.0 10585.5 # 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 $ STOP DEPTH 11147.5 11161.0 11161. 0 11161.0 11161.0 11161.0 11190.0 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: 02-DEC-01 Insite 4.05.5 3.3 Memory 11190.0 91. 5 104.8 TOOL NUMBER 72829 PB02279RF3 3.750 Flo pro/ KCL .00 8.7 9.5 25000 6.4 .125 .058 .185 70.0 158.9 70.0 { ( MUD CAKE AT MT: .160 70.0 # 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 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 MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10541 11190 10865.5 1299 10541 11190 ROP MWD060 FT/H 0.65 277.18 64.5155 1210 10585.5 11190 GR MWD060 API 22.32 164.43 44.7384 1214 10541 11147.5 RPX MWD060 OHMM 2.29 32.27 8.35421 1213 10555 11161 RPS MWD060 OHMM 2.39 30.88 8.58479 1213 10555 11161 RPM MWD060 OHMM 2.49 35.81 8.88932 1213 10555 11161 RPD MWD060 OHMM 2.72 28.09 9.59584 1213 10555 11161 FET MWD060 HR 0.28 11.19 1.74476 1213 10555 11161 First Reading For Entire File......... .10541 Last Reading For Entire File.......... .11190 File Trailer Service name.. ...... .... .STSLIB.004 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .02/09/18 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.. .... .02/09/18 Maximum Physical Record. .65535 File Type.... .......... ..LO Previous File Name.. ..., .STSLIB.004 Comment Record ( FILE HEADER FI LE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 5 It header data for each bit run in separate files. 7 .5000 START DEPTH 11148.0 11161.5 11161.5 11161.5 11161.5 11161.5 11190.5 STOP DEPTH 11352.0 11366.0 11366.0 11366.0 11366.0 11366.0 11395.0 # 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. 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 Max frames per record....... ..... .Undefined Absent value.................... ..-999 Depth Units....................... 03-DEC-Ol Insite 4.05.5 3.3 Memory 11395.0 100.5 107.8 TOOL NUMBER 69706 PB02279RF3 3.750 KCL/Flo Pro 8.40 60000.0 9.0 10000 6.4 .130 .057 .190 .160 70.0 167.0 70.0 70.0 ( ( 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 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11148 11395 11271.5 495 11148 11395 ROP MWD070 FT/H 2.28 156.37 55.3382 410 11190.5 11395 GR MWD070 API 22.24 200 80.1765 409 11148 11352 RPX MWD070 OHMM 3.87 1304.07 38.4324 410 11161.5 11366 RPS MWD070 OHMM 3.39 1725.88 60.6971 410 11161.5 11366 RPM MWD070 OHMM 3.15 2000 95.4075 410 11161.5 11366 RPD MWD070 OHMM 3.35 2000 175.259 410 11161.5 11366 FET MWD070 HR 0.28 27.5 4.72661 410 11161. 5 11366 First Reading For Entire File. ........ .11148 Last Reading For Entire File....... ....11395 File Trailer Service name.. ....... '" .STSLIB.005 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation...... .02/09/18 Maximum Physical Record..65535 File Type..... """"" .LO Next File Name.. ........ .STSLIB.006 Physical EOF Tape Trailer Service name... ....... ...LISTPE Date.....................02/09/18 Origin...................STS Tape Name....... """" . UNKNOWN Continuation Number.. ....01 Next Tape Name.......... . UNKNOWN Comments........ """" .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.... """" .LISTPE Date.....................02/09/18 Origin...................STS Reel Name.... """"'" . UNKNOWN Continuation Number.... ..01 Next Reel Name....... ....UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ( ,( ( aO}-) 91 ( 0 ~4 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Sep 17 16:33:23 2002 Reel Header Service name..... ... .....LISTPE Date.....................02/09/17 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.....................02/09/17 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 Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA U-15BPB1 500292256572 BP Exploration Sperry Sun 17-SEP-02 (Alaska), Inc. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-ll193 B. JAHN MCMULLEN/LOL MWD RUN 2 AK-MW-ll193 B. JAHN . MCMULLEN/LOL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 llN 13E 5172 1808 MSL 0) 77.30 .00 .00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.625 9086.0 5.500 9990.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. ( ( 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 4. GAMMA RAY (SGRD) LOGGED BEHIND CASING FROM 9978' MD, 8820' SSTVD TO 9990' MD, 8821' SSTVD. 5. ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) DATA FROM 9999' MD, 8821' SSTVD TO 10663' MD, 8819' SSTVD WAS OBTAINED ON A MADPASS WHILE PULLING OUT OF THE HOLE BEFORE DRILLING MWD RUN 2 AND IS APPENDED TO TOP OF MWD RUN 2 DRILLING DATA TO COMPLETE THE RESISTIVITY DATA. 6. DEPTH SHIFTING / CORRECTION WAIVED PER THE EMAIL FROM D. SCHNORR OF 02/08/02. MWD CONSIDERED PDC. THIS WELL KICKS OFF FROM U-15A AT 9990' MD, 8821' SSTVD (TOP OF WHIPSTOCK) ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 & 2 REPRESENT WELL U-15BPB1 WITH API # 50-029-22565-72. THIS WELL REACHED A TOTAL DEPTH OF 10771' MD, 8803' SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY 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 $ File Header Service name.... ........ .STSLIB.001 Service Sub Level Name... Version Number.. ....... ..1.0.0 Date of Generation... ....02/09/17 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 9977.5 9999.0 9999.0 9999.0 9999.0 9999.0 10010.5 STOP DEPTH 10727.5 10741.0 10741.0 10741.0 10741.0 10741.0 10771. 0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- { ( BASELINE DEPTH $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 MERGE TOP 9977.5 10693.5 MERGE BASE 10693.0 10771. 0 # REMARKS: MERGED MAIN PASS. $ # 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 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 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9977.5 10771 10374.3 1588 9977.5 10771 ROP MWD FT/H 0.42 2541. 32 56.7396 1522 10010.5 10771 GR MWD API 22.93 778.68 142.021 1501 9977.5 10727.5 RPX MWD OHMM 0.55 2000 39.1948 1485 9999 10741 RPS MWD OHMM 0.59 2000 46.66 1485 9999 10741 RPM MWD OHMM 0.61 2000 116.743 1485 9999 10741 RPD MWD OHMM 0.8 2000 534.686 1485 9999 10741 FET MWD HR 1. 34 70.17 39.392 1485 9999 10741 First Reading For Entire File....... ...9977.5 Last Reading For Entire File....... ....10771 File Trailer Service name... """'" .STSLIB.001 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .02/09/17 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.......... .1.0.0 Date of Generation..... ..02/09/17 Maximum Physical Record..65535 File Type...... """ ... .LO Previous File Name.. .... .STSLIB.001 Comment Record FILE HEADER ( FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 { header data for each bit run in separate files. 1 .5000 START DEPTH 9977.5 10010.5 STOP DEPTH 10663.0 10693.0 # 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # 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.. ...0 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 DEPT ROP MWD010 GR MWD010 23-NOV-01 Insite 4.05.5 7.75 Memory 10693.0 86.0 100.0 TOOL NUMBER 002 3.750 FloPro 8.70 62.0 9.5 13800 10.0 .000 .000 .000 .000 .0 150.0 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 if I~ ¡Ii.i I~ First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9977 .5 10693 10335.3 1432 9977.5 10693 ROP MWD010 FT/H 0.42 2541. 32 59.7304 1366 10010.5 10693 GR MWD010 API 22.93 778 . 68 141.058 1372 9977.5 10663 First Reading For Entire File...... ... .9977.5 Last Reading For Entire File...... .... .10693 File Trailer Service name........ .... .STSLIB.002 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .02/09/17 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...... .02/09/17 Maximum Physical Record. .65535 File Type.. ..... ..... ... .LO Previous File Name... ... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 9999.0 9999.0 9999.0 9999.0 9999.0 10663.5 10693.5 STOP DEPTH 10741. 0 10741. 0 10741. 0 10741. 0 10741. 0 10727.5 10771. 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: 24-NOV-01 Insite 4.05.5 4.30 Memory 10771.0 97.5 98.5 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 69706 PB02279RF3 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 it ( 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: FloPro 8.70 62.0 9.5 13500 .0 .150 .071 .210 .230 67.0 150.0 67.0 67.0 # 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 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 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 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9999 10771 10385 1545 9999 10771 ROP MWD020 FT/H 2.64 111.25 30.551 156 10693.5 10771 GR MWD020 API 30.14 438.52 152.262 129 10663.5 10727.5 RPX MWD020 OHMM 0.55 2000 39.1948 1485 9999 10741 RPS MWD020 OHMM 0.59 2000 46.66 1485 9999 10741 RPM MWD020 OHMM 0.61 2000 116.743 1485 9999 10741 RPD MWD020 OHMM 0.8 2000 534.686 1485 9999 10741 FET MWD020 HR 1. 34 70.17 39.392 1485 9999 10741 First Reading For Entire File......... .9999 Last Reading For Entire File...... .... .10771 File Trailer Service name......... ....STSLIB.003 Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation..... ..02/09/17 Maximum Physical Record..65535 File Type...... ........ ..LO Next File Name. ........ ..STSLIB.004 .. ( Physical EOF Tape Trailer Service name....... ..... .LISTPE Date.....................02/09/17 Origin...................STS Tape Name.............. ..UNKNOWN Continuation Number......01 Next Tape Name.. ... ......UNKNOWN Comments.................STS LIS Reel Trailer Service name.... ... ..... .LISTPE Date.....................02/09/17 Origin...................STS Reel Name............. ...UNKNOWN Continuation Number.. ....01 Next Reel Name. ...... ....UNKNOWN Comments.................STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Writing Library. ( Scientific Technical Services Scientific Technical Services