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203-170
STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMIaN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 - Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other. 5C 7F` e//3P V 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 203-170 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22696-01-00 7. Property Designation(Lease Number): ADL 0028329 8. Well Name and Number. PBU 05-41A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED V Total Depth: measured 11956 feet Plugs measured 11279 feet !Y true vertical 9049 feet Junk measured feet 2 1 2017 Effective Depth: measured 11279 feet Packer measured See Attachment feet AUGU / true vertical 9047 feet Packer true vertical See Attachment feet OG CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"91.5#H-40 39-118 39-118 1490 470 Surface 3732 9-5/8"40#L-80 38-3770 38-3572 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment • Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10270-10800 feet 11335-11430 feet 11500-11910 feet True vertical depth: 9057-9058 feet feet 9048-9048 feet 9044-9049 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): t Treatment descriptions including volumes used and final pressure: SCANNED NOV V 0 7 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 599 49398 16 120 1057 Subsequent to operation: 347 37499 42 40 964 14.Attachments:(required per 20 AAc 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Oestgaard,Finn Contact Name: Oestgaard,Finn Authorized Title: Producjpn'Engineer Challenger Contact Email: Finn.Oestgaard©bp.com � 6/74/1-7 Authorized Signature: " __ -:60- '..‘41411: : Date: Contact Phone: +1 907 564 5026 Form 10-404 Revised 04/2017 c /6 / v� ,Y RBDMS I, , AUG 2 5 2017 Submit Original Only • • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED AUG 21 2017 RE: BP Exploration (Alaska), Inc. AOGCC Report of Sundry Well Operations Summary August 16, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug for Well 05-41A, PTD # 203-170. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Packers and SSV's Attachment PBU 05-41A SW Name Type MD TVD Depscription 05-41A TBG PACKER 9207.49 8538.23 4-1/2" HES TNT Perm Packer 05-41A PACKER 9347.62 8666.51 4-1/2" Baker KB LT Packer 05-41A TBG PACKER 9364.41 8681.86 4-1/2" Baker S-3 Perm Packer 05-41A PACKER 9864.43 9032.55 4-1/2"TIW SS Horiz Packer • • m moo0000 goo 0 v' M ti tO N M M co — Lo r- V CD CD m 'Alc Tr w N O01 D 000 M 03 000 r N 00 N Ns N N (O O) O) d' O Is O) e- U) CD U) U) QD C d' M 7= M C' wM O O OO O OO O 03 iw- CI llllllllllll H 00 N M N (O v- CD w Is. O1 v- Ns O M U) U) U) MMMMM (O (0OOOC') (O w CO w 0) O) O) CO co NN O N N CO 03 CV M M 0) O)0 ) O 0 , d) � a � N- < MOON- O ( L0N (D0 � U) ' a) � M M M M w OM) M M M O M O) c c M� W 00000 0 0 1- n 00 wwwww , m Ni C9 0 0 0 J J J J J 00 Jk 00 OD OD ( 4t It N4t 4t 4 'N Nt(? ° *k *k *k '- wC.j (O ' cO (V f/) N N N (O co - CO s 0 � � - - - oDNN � w - N U) � � c- M � N r N O) • N C�) d' c) N ct Tr t mmm C N N m O N N M N- N O d M w (O v- 0 J W W W Q Q Q c Wwww R = Q222 zz z � cooIL WWWwwwww _ m_ wwwwwwww m oDtttzzzzzDD • 0 ©. w o_ 2 o o o T & (/) 0 kici 0 / 2 7 f 6 / 0 E20 ■ = 00 0 >- E+ op E al < o& Ew o 2 ° � 2 ma � ® O < / % J 2 T •D d22 o 3 - k� cc0n 0R O 6 LLI- 2 E'CL O � a_ ° ® 4, cf03 � $ o © 2o) & 1 Ce 773 & 0c -I � � $ -I k � � I's iii Q CO f9 � 0Eo % 9 E / / ck | 3AI ' ,.-- .OK= o L ° EO = 72 cG u) bO _I 9 & n � sa ® e0 � mo a) c ® @ E _ m � om � & � \ o k • E ' cv � � 2 � la = w �2 � aU / \ � 2t I- 2 2 �| : 0 0 : k 7 w ¥ N. / k CV o - / C 5 @ P * N. 0 Tom'^ ow barcirwtt. Hr woks 4. LcAiu-aws. mrsraii..n." WELLHEAD= FMC WILL BEECTNELY PERFORATED IN THE FUTURE TO ACTUATOR= BAKER C ft5-41 A IMTIATE PRODUCTION FROM THE TOE OF TIE TIE ORIGINAL KB.ELEV= 72.4' SLOTTED LINER SECTION. RA TAGS WERE INSTALLED IN XN BF.ELEV- ' ri...... NP AS A MARKER X&XN NPS OF CTD LNR ARE NOT KOP= 1216' IRSFARI FnlFTnMIN tnf)FTHFI NZMvPKR Max Angle= 95°@ 11444' Datum MD= 9578' 1999' -4-14� �P�t313" Datum ND= 8800'SS ST MD ND DEV TYPE I VLV LATCH PORT DATE D 9-5/8"CSG,40#,L-80, =8.835" -1 3767' 3 4011 3790 25 KBG-2 DMY BK 0 07/20/11 14 2 5995 5599 24 KBG-2 DMY BK 0 07/20/11 1 7770 7213 23 KBG-2 DMY BK 0 03/01/11 7"CSG,26#,L-80,0=6276" -I $962' ' j 9171' --14-112"FES X NP,D=3.813" Minimum ID = 2.377" @ 10187' TOP OF 2-7/8" LNR Z gp---I 9200' H 7"X 4-1/2"HES TNT PKR,D=3.856" 4-1/2"TBG,12.6#,13CR-85 H 9306' 1 � I 9235' H4-112"HES X NP,ID=3.813" V A M TOP,.0152 bpf,D=3.958' V 9321' H 7"X 4-1/2"UNIQUE OVERSHOT TBG STUB(02/09/11) H 9312' S X 9348' H4-1/2"BKR KB LNR TOP PKR,D=2.560" z z, - 9360' H 7"x 4-1/2"BKR S-3 PKR,ID=3.875"(BERN)CT LNR) ç9375' -I-13.5"BKR DEPLOYMENT SLV,D=3.0" 9385' -13-1/2'HES X NP,0=2.813" 9392' _-14-112"I-ES X NP,D=3.813"(BRIM)CT LMR) 1 ' 9417' H 4-1/1"WLEG,D=3.958"(BEHIND CT LMR) 4-1/2"TBG,12.6#,L-80, H 9417' .0152 bpf,D=3.958" . 9864' H 7"X 4-1/2"11W SS LNR HGR&FKR,0=3.922" IN 9913' H4-1/2"PORTS)JONJT(BEHIND CT UR) 7"CSG,29#,L-80,ID=6.184" -I 9986' � , ' , 9985' --{3-1/2"HES XN NP W/RA MARKER,ID=2.750" 3-1/2"LNR,8.81#,L-80 STL, - 9996' I .0087 bpf,ID=2.992" 9996' -13-1/2"X 3-3/16"XO,0=2.786" MECHANICAL HOLLOW WI-I:STOCK 10002' (01/14/04) %�� ,„ MLLOUT WIDOW (05-41A)10002'-10007' PERFORATION SUMMARY I REF LOG: MCNUCCUGR ON 01/21/04 I ANGLE AT TOP PERF:91°@ 10270' ti C. 10187' H 3-3/16"X 2-7/8"XO,D=2.387" Note:Refer to Production CB for historical perf data I SCE SIT INTERVAL Opn/Sqz DATE I 11279' -12.187"WFD CEP(07!08!17) 2" 6 10270-10800 0 01/22/04 ' 2" 6 11335-11430 C 01/22/04 /, 2" 6 11500-11910 C 01/22/04 11922 VVF 4-112"WS-R-RB FKR 11021' 7•••••••••••V I-RITE) 4-1/2"SLTD LMR,12.6#,L-80,D=3.958" 11317' �, 2-3/8"TALPFE W/2 PERFED BTM JTS 10636' 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958" 11340' 3-3/16"LNR,6.2#,L-80 TCII,.0076 bpf,D=2.805" 10187' 2-7/8'LNR,6.16#,L-80 Sm,,0058 bpf,D=2.377" -I 11956' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUCHOE BAY UNIT 09/16/96 ORIGINAL COMPLETION 03/16/11 Cl-VJMD DRLG DRAFT CORRECTIONS WELL: 05-41A 01/23/04 DAV/KAK CTD SIDETRACK(05-41A) 07/28/11 TAW PJC GLV CIO(07/20/11) FERMT No:'' 031700 02/14/11 N7ES INVO 07/10/17 JTMYJMD SET CEP(07/08/17) APINo: 50-029-22696-01 02/23/11 ?/JM) DRLG DRAFT CORRECTIONS 07/12/17 JTM'JM) UPDATED CEP TO TOP DEPTH SEC 32,T11N,R15E,2291'FSL&11777'RM. . 03/08/11 TAWPJC GLV C/O/PLLL WRP(3/01-4/11) 03/08/11 PJC DRLG DRAFT CORRECTIONS . BP Exploration(Alaska) e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d- 03 - ~ f 0 Well History File Identifier D Two-sided III 111111111111111I Organizing (done) RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA ~kettes No. I D Other, NolType: D Poor Quality Originals: D Other: NOTES: Date ;µ/~Ó/Dh Date 0./ ~ / ðb / x 30 = (10 Date Jþøj06 BY: ~ Project Proofing BY: c~ Scanning Preparation BY: ~ Production Scanning D Rescan Needed 1111111111111 II 111I OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: MP 111111111111111111I mP 151 151 + 8J) = TOTAL PAGES l5Vp (Count does not include cover sheet) rA A . 151 V n 11/111111111111111I Stage 1 Page Count from Scanned File: (L)" / (Count does include cover sheet) Page Count Matches Number in scan"J"g Preparation: VYES BY~. Dated-/J3!Db Stage 1 If NO in stage 1 page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: NO 151 mf NO 151 11111111111I11 1111I 111111/1111I11 1111I 151 Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11,2012 Mr. Jim Regg 5 QED AUG 'OIL Alaska Oil and Gas Conservation Commission Q3 . ) 17 Q 333 West 7 Avenue 1 Anchorage, Alaska 99501 0 5— `4 ) Pi- Subject: Corrosion Inhibitor Treatments of GPB DS -05 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 05 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 ou require any additional information, please contact me or my alternate, Gerald Y q Y �p Y Murphy, at 659 -5102. Sincerely, off. Mehreen Vazir BPXA, Well Integrity Coordinator i • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -05 Date: 01/10/2012 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 gal 05 -01C 1990280 50029201360000 Sealed conductor NA NA N/A N/A NA 05 -02A 2012410 50029201440100 Sealed conductor NA NA N/A N/A NA 05 -03C 2000940 50029201470300 Sealed conductor NA NA N/A N/A NA 05 -04A 1960890 50029201520100 Sealed conductor NA NA N/A N/A NA 05 -05B 1961800 50029201700200 Sealed conductor NA NA N/A N/A NA 05 -06A 1950840 50029201730100 0 NA 0 N/A N/A NA 05 -07 1770130 50029202430000 Sealed conductor NA NA N/A N/A NA 05 -08A 2100550 50029202480100 Sealed conductor NA NA N/A N/A NA 05 -09A 1990140 50029202540100 Sealed conductor NA NA N/A N/A NA 05 -10C 2070980 50029202630300 Sealed conductor NA NA N/A N/A NA 05 -11A 1960970 50029202520100 Sealed conductor NA NA N/A N/A NA 05 -12B 2011800 50029202440200 Sealed conductor NA NA N/A N/A NA 05 -138 2071460 50029202500200 Sealed conductor NA NA N/A N/A NA 05 -14A 1930820 50029202530100 Sealed conductor NA NA N/A N/A NA 05 -15B 1960230 50029202550200 Sealed conductor NA NA N/A N/A NA 05 -16B 1991000 50029202620200 Sealed conductor NA NA N/A N/A NA 05 -17B 1981040 50029202710200 Sealed conductor NA NA N/A N/A NA 05 -18A 1981740 50029219600100 Split conductor NA NA N/A N/A N/A 05 -19 1890780 50029219620000 1.4 NA 1.4 N/A 8.5 4/11/2011 05 -20B 2042340 50029221370200 1.2 NA 1.2 N/A 5.1 4/18/2011 05 -21A 1981180 50029219690100 Dust Cover NA NA N/A N/A N/A 05 -22B 2071260 50029219760200 3.1 NA 3.1 N/A 18.7 4/17/2011 05 -238 2080610 50029219630200 1.2 NA 1.2 N/A 5.1 4/11/2011 05 -24A 2042180 50029222040100 1.5 NA 1.5 N/A 10.2 4/11/2011 05 -25C 2091240 50029219880300 6.0 NA 6.0 N/A 44.2 4/18/2011 05 -26A 2012210 50029219840100 0.5 NA 0.5 N/A 3.4 4/12/2011 05 -27B 2081910 50029219790200 Sealed conductor NA NA N/A N/A N/A 05 -28B 2060890 50029222080200 0.6 NA 0.6 N/A 1.7 4/10/2011 05 -30 1911150 50029222130000 1.2 NA 1.2 N/A 10.2 4/11/2011 05-31B 2100850 50029221590200 1.3 NA 1.3 N/A 6.8 4/12/2011 05 -32A 2020010 50029221900100 20.0 6.0 0.5 7/13/2011 3.4 7/23/2011 05 -338 2100810 50029221680200 4.8 NA 4.8 N/A 37.4 4/27/2011 05 -34A 2080370 50029222170100 3.9 NA 3.9 N/A 18.7 1/4/2012 05 -35A 2081340 50029221720100 2.7 NA 2.7 N/A 18.7 4/18/2011 • 05 -36A 2050700 50029221820100 2.3 NA 2.3 N/A 13.6 4/12/2011 05 -38 1961850 50029227220000 1.8 NA 1.8 N/A 15.3 4/10/2011 05 -39 1961730 50029227150000 1.3 NA 1.3 N/A _ 10.2 4/10/2011 05-40 1961590 50029227070000 1.6 N/A _ 1.6 N/A 16.2 1/10/2012 ....- 3r05 -41A 2031700 50029226960100 5.0 NA 5.0 N/A 58.7 1/8/2012 Producers with sustained casing pressu,n IA during proration • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, July 18, 2011 3:53 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 OSM; AK, OPS FS1 Ops Lead; AK, OPS GPMA Field O &M TL; AK, OPS GPMA OSM; AK, OPS GPMA OSS Cc: Walker, Greg (D &C); Grey, Leighton (CH2M Hill); Reynolds, Charles (ALASKA); Kaminski, Alice; Warner, Ross L; Oakley, Ray (PRA); Greaves, Damien C; Brown, Don L. Subject: Producers with sustained casing pressure on IA during proration All, The following producers were reported to have sus tained casing pressure on the IA during the proration and shutdown activity July 15 -18. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 05-41A (PTD #203170 P1 -04 (PTD #1930630) L -104 (PTD #2012380) V -04 (PTD #2061340) V -103 (PTD #2021860) A 1 t'a JUL 2, 0 ?WI W -36 (PTD #1881060) Y -04 (PTD #1791050) Y -16 (PTD #1830490) All the wells listed above will be re- classified as Not Operable until start-up operations are complete and stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells I Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 7/19/2011 STATE OF ALASKA RE Cl y ALAS•IL AND GAS CONSERVATION COMMISN REPORT OF SUNDRY WELL OPERATIONS mAR i Z Mil Alaska Gil & Oss Cons. Commission 1. Operations Performed: rA1..,,,,,,��R� ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspendel!gar ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number. BP Exploration (Alaska) Inc. ® Development ❑ Exploratory • 203 - 170 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 • 50 - 029 - 22696 - 01 - 00 7. Property Designation: 8. Well Name and Number: ADL 028325 & 028329 • PBU 05 9. Field / Pool(s): r Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 11956 feet Plugs (measured) None feet true vertical 9049 feet Junk (measured) None Effective depth: measured 11922 feet Packer: (measured) 9200 / 9360 feet true vertical 9049 feet Packer. (true vertical) 8531 / 8678 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3732' 9-5/8" 3767' 3569' 5750 3090 Intermediate Production 9953' 7" 9986' 9051' 7240 5410 Liner 138' 4-1/2" 9864' - 10002' 9032' - 9052' 8430 7500 Liner 3-1 /2" x X16 " x 2 -7/8" 9348' - 11956' 8667' - 9049' 10160 10530 Perforation Depth: Measured Depth: 10270' - 11910 M a 1 True Vertical Depth: 9057' - 9049' Tubing (size, grade, measured and true vertical depth): 4 - 1/2 ", 12.6# 13Cr - 9321' MD 8642' TVD 4 - 1/2 ", 12.6# L - 80 9417' MD 8730' TVD Packers and SSSV (type, measured and true vertical depth): 7" x 4 HES TNT packer 9200' MD 8531' TVD 7" x 4 BKR S - 3 Packer 9360' MD 8678' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Set plug. Set junk catcher on liner top packer. Cut and pulled 4-1/2" tubing from 9312' MD. Dressed off tubing stub © — 9307'. Change out 7" casing pack -off. Clean out and ran new 4-1/2" chrome tubing. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1550 1850 Subsequent to operation: 1222 35435 82 10 0 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory 00 Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ 1 ® Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564-5683 N/A Printed Name Elizabeth Barker Title Drilling Technologist ,ry f � �9 -i �' P re pa a rk e N uer. Signature Phone A 5 f 64 t - 5674 Date yi(/ p�� Elizab red Ba rker , 564 -5mb6 Form 10-404 Revised 10/2Q,/ r1BDMS MAR 2 i_ $, .7,3 vi Submit Original Only • • 05-41A Well History (Pre Rig Workover) Date Summary 1/27/2011 PPPOT -T : RU 2 HP BT onto THA 200 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment, re- installed Alemite caps. Cycle and torque LDS "ET style" all functioned with no problems. PPPOT -IC : RU 2 HP BT onto IC test void 350 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, cycle and torque LDS "ET style" all functioned with no problems. 1/29/2011 EQUALIZED AND PULLED 2 -7/8" XX PLUG BODY FROM 6,551' SLM. TAGGED 4 -1/2" BAKER KB PACKER @ 6,537' SLM W/ 3.805" CENT (No issues). PULLED 4 -1/2" BAKER KB PACKER (Missing 1 element) FROM 6,565' MD. RAN 4 -1/2" BLB, 3.69" WIRE GRAB TO BAKER LTP @ 9,348' MD (Recovered 2/3 of missing element). DRIFT TO DEVIATION @ 9,907' SLM W/ 2 -7/8" BLB, 2.30" WIRE GRAB (No recovery). RAN PDS GR/CCL LOG FROM 9,559' SLM TO 9,075' SLM (Good data). TAGGED 4 -1/2" BAKER LTP @ 9,324' SLM / 9,348' MD W/ 3.78" DUMMY WRP 1/30/2011 SET 4 -1/2" WFD WRP (3.77" od / 3.77' = oal) @ 9,341' MD (Center element). LRS PERFORMED PASSING CMIT T x IA TO 3500 PSI (See log for details). LRS PERFORMED FAILING MIT -OA, LLR OF 3 BPM @ 2000 PSI. DUMPED 1 1/4 BAGS OF SLUGGITS ON TOP OF 4 -1/2" WRP @ 9,322' SLM. SET 3.75" x 10' JUNK CATCHER ON TOP OF SLUGGITS @ 9,309' SLM. 1/30/2011 PASSED to 3500 psi. / MIT OA Failed to 2000 psi. CMIT TxIA pressured up to 3520/3440 psi. with 12.6 bbls crude. T/I lost 60/20 psi. in the first 15 minutes and 20/0 psi. in the second 15 min. for a total loss of 80/20 psi. in 30 min. Bled down pressure. (MIT OA) Established a LLR of 3 BPM at 2000 psi. for 25 bbls. (36 bbls pumped total) No increase on TxIA pressure. OA bled off to 1200 psi. and stabilized. Continued bleed (2.8 bbls back) to 0 psi. 1/30/2011 Pumped 12.6 bbls crude to reach test pressure T /IA = 3520/3460 1st 15min T /IA = 3460/3440, after 2nd 15 min T /la = 3440 3440 for a passing test. Rigged to OA MIT -OA failed w/ LLR of 3bpm /2000 psi. 1/31/2011 CUT TUBING AT 9312' WITH 3.65" POWERCUTTER. CORRELATED TO TUBING SUMMARY DATED 14 -SEP -1996. TAGGED TOP OF JUNK CATCHER TAGGED AT 9316'. 2/1/2011 Circ -out CMIT T x IA PASSED to 600 psi on 4th attempt. Pumped 5 bbls neat methanol and 470 bbls seawater down tubing while taking returns up IA to 05 -04 flowline. Pumped 82 bbls diesel down tubing for Freeze Protect. U -tube to IA for 30 minutes.Pumped 3 bbls diesel down hardline for freeze protect.CMIT TxIA to 600 psi. CMIT TxIA lost 10/10 psi in the 1st 15 min and 5/5 psi in the 2nd 15 min for a total loss of 15/15 psi in the 30 min test. Bled all pressure to 0. 2/3/2011 Verified barriers. Rigged up lubricator to set BPV. Tested to 300 psi low and 3500 psi high (passed) Set 4" CIW H BPV @ 110" w/ 1 -1' ext. Reinstalled tree cap and tested to 500 psi. Set VR plug in frontside I/A and removed valve. Installed blind flange with needle valve over VR plug on tubing spool. Tested blind flange to 3500 psi. (passed). 2/5/2011 START AND COMPLETE EXCAVATION ON WELL CELLAR. I I Page 1 of 1 TREE = CM/ SAFETY NOTES: ANGLE> 70° @ 9848'. WHIPSTOCK WELLHEAD = FMC WILL BE SELECT PERFORATED IN THE FUTURE TO ACTUATOR = BAKER C A-41A INITIATE PRODUCTION FROM THE TOE OF THE THE ORIGINAL KB. ELEV = 72.4' SLOTTED LINER SECTION. RA TAGS WERE INSTALLED IN XN BF. ELEV = 1 1 NIP AS A MARKER X & XN NIPS OF CTD LNR ARE NOT KOP = 1216' USEABLE DUE TO MIN ID OF THE LNR TOP PKR. Max Angle = 95° @ 11444' ' Datum MD = 9578' I 1999' H4 -1/2" HES X NIP, ID = 3.813" I Datum TV D = 8800' SS GAS LIFT MANDRELS 9 -5/8" CSG, 40 #, L -80, ID= 8.835" H 3767' ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4011 3790 25 KBG -2 DOME BK 16 03/01/11 2 5995 5599 24 KBG -2 SO BK 20 03/01/11 1 7770 7213 23 KBG -2 DMY BK 0 03/01/11 7" CSG, 26 #, L -80, ID = 6.276" I-I 896T I I 9171' 1-14-1/2" HES X NIP, ID = 3.813" I Minimum ID = 2.377" @ 10187' 9200' H 7" X 4 -1/2" HES TNT PKR, ID = 3.856" I TOP OF 2 -7/8" LNR 0 li 9235 H 4-1/2" HES X NIP, ID = 3.813" I 4 -1/2" TBG,12.6 #, 13CR -85 - I 9306' VAM TOP, .0152 bpf, ID = 3.958" 9321' 1-17" X 4 -1/2" UNIQUE OVERSHOT 1 I TBG STUB (02/09/11) H 9312' I 9348' 1-14-1/2" BKR KB LNR TOP PKR, ID = 2.560" I e 9360' j-1 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" (BEHIND CT LNR) 1 ■ 9375' J--I3.5" BKR DEPLOYMENT SLV, ID = 3.0" I 11 9385' J- -I3 -1/2" HES X NIP, ID = 2.813" I ' 9392' H 4 -1/2" HES X NIP, ID = 3.813" (BEHIND CT LNR) 1 I ill 9417' H 4 -1/2" WLEG, ID = 3.958" (BEHIND CT LNR) 1 4 -1/2" TBG,12.6 #, L -80, H 9417' .0152 bpf, ID = 3.958" 9864' H 7" X 4 -1/2" TIW SS LNR HGR & PKR, ID = 3.922" Ill 9913' 1-14-1/2" PORTED JOINT (BEHIND CT LNR) 1 7" CSG, 29 #, L -80, ID = 6.184" (-) 9986' 1 I 9985' H 3 -1/2" HES XN NIP W/ RA MARKER, ID = 2.750" 1 3 -1/2" LNR, 8.81 #, L -80 STL, 9996' I I I .0087 bpf, ID = 2.992" I 1 X 3- 3/16" XO, ID = 2.786" I MECHANICAL HOLLOW WHIPSTOCK H 10007 I (01/14/04) t's MILLOUT WINDOW (05- 41A)10002' - 10007' PERFORATION SUMMARY 1 REF LOG: MCNL /CCL /GR ON 01/21/04 ANGLE AT TOP PERF: 91 @ 10270' (8I I 10187' H 3- 3/16" X 2 -7/8" XO, ID = 2.387" I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE � I 2" 6 10270 - 10800 0 01/22/04 2" 6 11335 - 11430 0 01/22/04 2" 6 11500 - 11910 0 01/22/0 4111Y 11922' I-I PBTD 1 I W F 4-1/2" WS -R -RB PKR IH 11021' 1 ���� 1 . A . 4 -1/2" SLID LNR, 12.6 #, L -80, ID = 3.958" H 11317' I , . 1 2 -3/8" TAILPIPE W/ 2 PERFED BTM JTS I 10636' I 14 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 11340' 1 13-3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.805" I 10187' I2 -7/8" LNR, 6.16 #, L -80 STL, ,0058 bpf, ID = 2.377" I- I 11956' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/16/96 ORIGINAL COMPLETION 03/16/11 CRH/JMD DRLG DRAFT CORRECTIONS WELL: 05 -41A 01/23/04 DAV /KAK CTD SIDETRACK (05 -41A) PERMIT No: * 2031700 02/14/11 N7ES RWO API No: 50- 029 - 22696 -01 02/23/11 ? /JMD DRLG DRAFT CORRECTIONS SEC 32, T11 N, R15E, 2291' FSL & 11777' FWL 03/08/11 TAR/PJC GLV C/0 / PULL WRP (3/01 -4/11) 03/08/11 PJC DRLG DRAFT CORRECTIONS 1 BP Exploration (Alaska) • • >'� N America -ALASKA BFx Pagel of 17 N N y e O peration Summary Report a Well � �. �� � .� � . � x „ . W Common ell Name: 05-41 AFE No Event Type: WORKOVER (WO) I Start Date: 2/4/2011 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05 -41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ( 2/7/2011 00:00 - 17:00 17.00 MOB N WAIT PRE WO PAD WORK ON 5-41A - REVIEW 2010 SAFE WORK PLAN FOR UPDATES & ADDITIONS - PREP RIG FOR MOVE h- REPAIR HOLE FILL LINE ' -RIG AUDIT - PRE -W /O MTG WITH CREW l , * * PERFORM RIG EVACUATION DRILL ** 17:00 - 19:00 2.00 % MOB P PRE 1TRANSPORT PJSM, RAISE MUD PITS, CONNECT TRUCK & PULLRIG MATS - MOVE PETS AND STAGE ON PAD. - BLOW DOWN STEAM 19:00 - 21:00 2.00 MOB P PRE ,TRANSPORT' -MOVE SUB FROM DS5 -13B AND STAGE © 5-41A 1** NOTIFIED AOGCC REP LOU GRIMALDI @ 19:15 HRS OF UPCOMING BOP TEST ** (2ND CALL) 21:00 - 22:00 1.00 MOB P PRE MOB - RAISE DERRICK 22:00 - 00:00 2.00 — MOB P PRE MOB ,- SET HERCULITE IN CELLAR - SPOT RIG OVER DS 5-41A 2/8/2011 00:00 - 02:00 2.00 MOB P PRE MOVE AND SPOT PIT MODULE. - ADD FILL UNDER ONE JACK LEG. - STAGE RIG MATS. - SPOT & LEVEL PIT MODULE. 02:00 - 05:00 3.00 MOB P PRE CONTINUE TO RIG UP. - SPOT CUTTINGS TANK. - HOOK UP LINES TO INTERCONNECT. - HOOK UP STEAM. - RAISE CATTLE CHUTE. -PIN THE TORQUE TUBE AND RIG UP THE TOP DRIVE. 05:00 - 07:00 2.00 MOB P PRE RIG UP CELLAR. - MAKE UP DOUBLE ANNULUS VALVES. - HOOK UP CIRC LINES. - BEGIN TAKING ON SEAWATER TO THE PITS. *** RIG ACCEPT @ 06:00 * ** 07:00 - 08:00 1.00 MOB P PRE RIG UP DSM LUBRICATOR TO PULL BPV. - TEST BPV TO 250 PSI / 3500 PSI FOR 5 CHARTED MINUTES. - GOOD TEST. 08:00 - 09:00 1.00 DHB P j DECOMP PULL BPV AND LAY DOWN. _ RIG DOWN DSM LUBRICATOR. 09:00 - 10:00 1 1.00 PULL P DECOMP RIG UP TO CIRCULATE OUT THE DIESEL FREEZE PROTECT. Printed 3/4/2011 10:40:06AM ;"/"' operation • s ummar y Report Common Well Name: 05-41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05-41 @72.43ft (above Mean Sea Level) Date From - To Hrs j Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 13:30 3.50 PULL P DECOMP ' CIRCULATE OUT THE DIESEL FREEZE - REVERSE OUT THE DIESEL FROM THE TUBING. - 3 BPM AND 400 PSI. - PUMPED 42 BBLS OF HEATED 8.5 PPG SEAWATER. - RECOVERED -40 BBLS OF DIESEL. - CIRCULATE OUT THE DIESEL FROM THE ANNULUS. - 3 BPM AND 100 PSI. - PUMPED 50 BBLS OF HEATED 8.5 PPG 'SOAP SWEEP. - RECOVERED -42 BBLS OF DIESEL. 1 - CHASED SOAP SWEEP WITH HEATED 8.5 PPG SEAWATER. 6 BPM AND 975 PSI. RIG DOWN ND BLOW DOWN LINES. - MONITORED - WELL - WELL WAS STATIC. RECOVERED A TOTAL OF 82 BBLS OF DIESEL FREEZE PROTECT. 13:30 - 15:00 1.50 DHB P DECOMP. INSTALL TWC 1- RIG UP DSM LUBRICATOR. - TEST TO 250 PSI / 3500 PSI FOR 5 CHARTED MINUTES. i - GOOD TEST. - INSTALL TWC. - RIG DOWN DSM. 15:00 - 17:00 2.00 DHB P 1 DECOMP PRESSURE TEST TWC. - TEST TWC FROM ABOVE. - 250 PSI FOR 5 CHARTED MINUTES. - 3500 PSI FOR 10 CHARTED MINUTES. - GOOD TEST. - TEST TWC FROM BELOW. - 250 PSI FOR 5 CHARTED MINUTES. - PUMPED 0.4 BBLS. - 1000 PSI FOR 10 CHARTED MINUTES. - PUMPED 1.1 BBLS. - GOOD TEST. - RECOVERED 1.4 BBLS BACK AFTER BLEEDING OFF. - RIG DOWN AND BLOW DOWN ALL LINES. - FMC REPRESENTATIVE BLED DOWN THE CONTROL LINES AND TUBING HANGER VOID. 17:00 - 18:30 1.50 WHSUR P DECOMP NIPPLED DOWN THE TREE AND ADAPTER FLANGE. - FMC REPRESENTATIVE TERMINATED THE CONTROL LINES. - INSPECTED TUBING HANGER THREADS. - THREADS APPEAR TO BE IN GOOD CONDITION. - 7.5 TURNS TO MAKE UP THE XO TO THE TUBING HANGER. 18:30 21:00 2.50 BOPSUR P DECOMP NIPPLED UP BOPE. 121:00 - 21:30 0.50 ! BOPSUR P DECOMP INSPECTED BOPE INTERNALS. - UTILIZED A BORESCOPE TO INSPECT BOPE INTERNALS. 21:30 - 22:30 1.00 BOPSUR P DECOMP RIG UP TO TEST BOPE. Printed 3/4/2011 10:40:O6AM •� Arnleric8l ttA SKA BP P 3 of i7 gyration Summary Common Well Name: 05 -41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05-41 ©72.43ft (above Mean Sea Level) Date I From - To Hrs ' Task Code NPT 1 NPT Depth Phase Description of Operations 1 (hr) i (ft) 22:30 - 00:00 1.50 BOPSUR P DECOMP TEST BOPE PER BP POLICY AND AOGCC REGULATIONS. ' ! i I i - TESTED CHOKE MANIFOLD VALVES. - 250 PSI LOW / 3500 PSI HIGH FOR 5 ' CHARTED MINUTES. O � - GOOD TEST. TESTED 3.5" AND 4.5" FULL OPENING L SAFETY VALVE, DART VALVE, IBOP, KILL AND / [ CHOKE HCR AND MANUAL VALVES, AND j BLIND/SHEAR RAMS. - 250 PSI LOW / 3500 PSI HIGH FOR 5 I CHARTED MINUTES. 1 � - GOOD TEST . - TESTED'UPPER RAMS, 3 1/2" X 6" VBR. +" USED BOTH 4 " AND 4 1/2" TEST JOINTS. 250 PSI LOW / 3500 PSI HIGH FOR 5 CHARTED MINUTES. GOOD TEST. - TESTED LOWER RAMS, 2 7/8" X 5" VBR. USED BOTH 4" AND 4 1/2" TEST JOINTS. - 250 PSI LOW / 3500 PSI HIGH FOR 5 - - -� CHARTED MINUTES. GOOD TEST. - TESTED ANNULAR PREVENTER. 1 I 1 - USED 4" TEST JOINT. - 250 PSI LOW / 3500 PSI HIGH FOR 5 ' I CHARTED MINUTES. - GOOD TEST. - TEST WITNESS WAIVED BY LOU GRIMALDI 1 __ _ WITH AOGCC AT 18:30 Printed 3/4/2011 10:40:06AM A Bp Operation Summary , Report Common Well Name: 05-41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4 -OOPMS E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05-41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth l Phase Description of Operations (hr) (ft) 2/9/2011 00:00 - 03:00 3.00 BOPSUR P DECOMP CONTINUE TO TEST BOPE: TEST BOPE PER BP POLICY AND AOGCC REGULATIONS. - TESTED CHOKE MANIFOLD VALVES. - 250 PSI LOW / 3500 PSI HIGH FOR 5 CHARTED MINUTES. - GOOD TEST. - TESTED 3.5" AND 4.5" FULL OPENING SAFETY VALVE, DART VALVE, IBOP, KILL AND CHOKE HCR AND MANUAL VALVES, AND BLIND /SHEAR, RAMS. - 250 PSI LOW / 3500 PSI HIGH FOR 5 CHARTED MINUTES. GOOD TEST. - TESTED UPPER RAMS, 3 1/2" X 6" VBR. - USED BOTH 4" AND 4 1/2" TEST JOINTS. 250 PSI LOW / 3500 PSI HIGH FOR 5 CHARTED MINUTES. - GOOD TEST. - TESTED LOWER RAMS, 2 7/8" X 5" VBR. - USED BOTH 4" AND 4 1/2" TEST JOINTS. - 250 PSI LOW / 3500 PSI HIGH FOR 5 _ CHARTED MINUTES. - GOOD TEST. - TESTED ANNULAR PREVENTER. I I - USED 4" TEST JOINT. - 250 PSI LOW / 3500 PSI HIGH FOR 5 CHARTED MINUTES. - GOOD TEST. - TEST WITNESS WAIVED BY LOU GRIMALDI 1 WITH AOGCC AT 18:30 03:00 - 04:00 1.00 BOPSUR !r`' P - DECOMP RIG DOWN BOPE TEST EQUIPMENT AND BLOW DOWN LINES. 04:00 - 05:30 I, 1.50 DHB P DECOMP RIG UP TO PULL TWC. - INSTALL DUTCH RISER. - INSTALL DSM LUBRICATOR. - 250 PSI LOW/ 3500 PSI HIGH FOR 5 CHARTED MINUTES. - GOOD TEST. P 05:30 W 06 :30 1.00 i DHB P i DECOMP PULL TWC AND RD DSM LUBRICATOR. PULL DECOMP !RIG UP TO PULL AND LAY 06:30 - 07:30 1.00 I ' DOWN 4 1/2" TUBING TO CUT JOINT AT -9312' MD. - RIG UP DOUBLE STACK POWER TONGS. - XO'S FOR SAFETY VALVE. - LANDING JOINT WITH XO TO HANGER THREADS. 07:30 - 08:30 1.00 PULL P DECOMP PULL AND LAY DOWN TUBING HANGER. - RUN IN HOLE WITH LANDING JOINT AND MAKE UP TO TUBING HANGER. - FMC REPRESENTATIVE B.O.L.D.S. ! - UNSEAT AND PULL TUBING HANGER TO FLOOR. - UP WEIGHT = 138K LBS. - MONITORED WELL FOR 10 MINUTES. - WELL WAS STATIC. - BREAK OUT AND LAY DOWN TUBING HANGER. _ LAY DOWN LANDING JOINT AND XO. Printed 3/4/2011 10:40:06AM `dh Amet` A SKA BP' Pa of t7 - operation stinin ary: Report Common Well Name: 05-41 1AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: 500292269600 Active Datum: 05 -41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 11:30 3.00 PULL P DECOMP CIRCULATE A BARA -KLEAN PILL. - CLOSE THE ANNULAR AND LINE UP TO CIRCULATE THROUGH THE CHOKE. PUMP A 50 BBL BARA -KLEAN PILL. - CHASE WITH 120 DEG, 8.5 PPG SEAWATER. - 3 BPM AND 160 PSI. STOP AT BOTTOMS UP AND MONITOR WELL, - WELL WAS STATIC. r- OPEN ANNULAR AND CONTINUE TO CIRCULATE OUT BARA -KLEAN PILL. 1 - 10 BPM AND 380 PSI. - RIG DOWN AND BLOW DOWN LINES. 11:30 - 20:00 8.50 PULL P DECOMP PULL OUT OF THE HOLE AND LAY DOWN THE 4 1/2" TUBING. PULL 1 JOINT OF 4 112" TUBING. - UP WEIGHT = 135K LBS. ;ATTACH DUAL CONTROL LINES TO SPOOLING UNIT. - PULL 4 1/2" TUBING WITH DUAL CONTROL LINES AND LAY DOWN. - FROM 9244' TO 7125' MD. - UP WEIGHT = 110K LBS, DOWN WEIGHT = 100K LBS. - EXPERIENCED UP TO 20K LBS OVERPULL. - SS BANDS AND CONTROL LINE BALLED UP ION TOP OF THE SVLN. - RECOVERED 41 SS BANDS WITH BUCKLES I AND 2 SS BANDS WITHOUT BUCKLES. - ORIGINAL TALLY INDICATED 54 SS BANDS 114 THE HOLE. 20:00 - 00:00 4.00 PULL P DECOMP CONTINUE TO PULL OUT OF THE HOLE AND LAY DOWN 4 1/2" TUBING. { - FROM 7125' TO 4975'. i - UP WEIGHT = 78K LBS, DOWN WEIGHT = 175K LBS. - MODERATE TO SEVERE PITTING NOTED ON THE INSIDE OF THE 4 1/2" TUBING. 2/10/2011 00:00 - 05:00 5.00 PULL P T DECOMP CONTINUE TO PULL OUT OF THE HOLE AND LAY DOWN 4 1/2" TUBING. - FROM 4975. - UP WEIGHT = 78K LBS, DOWN WEIGHT = 75K LBS. - MODERATE TO SEVERE PITTING NOTED ON THE INSIDE OF THE 4 1/2" TUBING. - RECOVERED; - 220 FULL JOINTS OF 4 1/2" TUBING. - 1 CUT JOINT 4 1/2" TUBING. - 4.35' LONG, OD ON FLARE = 5.0" - 3GLMS. - 1 BAL -O SVLN - 41 SS BANDS WITH BUCKLES. - 2 SS BANDS WITHOUT BUCKLES. 05:00 - 05:30 ! 0.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR. RIG DOWN TUBING HANDLING EQUIPMENT. Printed 3/4/2011 10:40:06AM ,� th America -ALASKA BED ° Pa 6 of:17 ration Summary Common Well Name: 05-41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM 1 Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. 1 UWI: 500292269600 Active Datum: 05-41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:30 - 06:30 1.00 WHSUR P DECOMP FISH PIECE OF CONTROL LINE OUT OF TUBING SPOOL. I- DRILLER NOTICED A PIECE OF 1/4" CONTROL LINE SITTING IN THE TUBING SPOOL. -`CREW USED A HOOK AND SASH CORD TO FISH OUT SEVERAL SMALL PIECES OF 1/4" COTROL LINE FROM THE TOP OF THE TUBING SPOOL. 06:30 - 07:00 0.50 WHSUR j P DECOMP INSTALLED WEAR BUSHING. 07:00 - 10:00 3.00 FISH P DECOMP PICK UP AND MAKE UP BHA #1, 4 1/2" TUBING DRESS -OFF ASS'Y. - PJSM AND BRING ALL BHA COMPONENTS TO RIG FLOOR. - Ml} BHA #1 PER BAKER FISHING REPRESENTATIVE AS FOLLOWS: - 6" X 4 9116" DRESS -OFF SHOE (4) WASH PIPE EXTENSIONS INNER DRESS -OFF MILL - WASHOVER BOOT BASKET - PIN X PIN 'XO' SUB (2) BOOT BASKETS 7" CASING SCRAPER - BIT SUB - (2) STRING MAGNETS - BUMPER SUB - OIL JAR - (6) 4 3/4" DRILL COLLARS -'XO' BACK TO DRILL PIPE - TOTAL LENGTH = 258.17' - MAXOD =6" -MIN ID= 1" 10:00 - 12:00 2.00 FISH P j DECOMP RUN IN THE HOLE WITH BHA #1, 4 1/2" (TUBING DRESS-OFF ASS'Y, PICKING UP I DRILL PIPE. - PICK UP AND STAND BACK 15 JTS (5 STANDS) OF 4" DRILL PIPE. - CONTINUE TO PICK UP DRILL PIPE FROM THE PIPE SHED 1 X 1 AND RUN IN THE HOLE - FROM 258' TO 1981' { I - UP WEIGHT = 55K LBS, DOWN WEIGHT = 55K LBS. 12:00 - 15:00 3.00 FISH P DECOMP CONTINUE TO RUN IN THE HOLE WITH BHA #1 PICKING UP 4" DRILL PIPE. - FROM 1981' TO 4487'. 15:00 - 16:00 ! 1.00 FISH P DECOMP SERVICE AND INSPECT THE TOP DRIVE. - SHUT DOWN AND MONITOR THE WELL. - WELL IS STATIC WITH 8.5 PPG SEAWATER. - SERVICE THE TOP DRIVE. - GREASE THE WASHPIPE, KNUCKLE, AND BLOCKS. Printed 3/4/2011 10:40:06AM Amer -FLASK BFI Operation Summery: Report Common Well Name: 05-41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4 OOPMS E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05-41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 17:30 1.50 FISH N RREP 4,487.00 DECOMP REPAIR THE IRON ROUGHNECK. - THE RIG MECHANIC REPAIRED A BROKEN BOLT ON THE IRON ROUGHNECK. 1- ATTEMPTED TO FIX THE SPINNER CLAMPING HYDRAULIC RAM. - MECHANIC DETERMINED THAT ADDITIONAL PARTS ARE REQUIRED TO FIX. - IRON ROUGHNECK IS IN WORKING CONDITION AND THE MECHANIC WILL REPAIR THE SPINNER HYDRAULIC RAM WHEN THE PARTS ARE LOCATED AND OUT OF THE CRITICAL PATH., 17:30 - 21:30 4.00 FISH P DECOMP ( CONTINUE TO RUN IN THE HOLE WITH BHA #1, 4 1/2 ". TUBING ' DRESS -OFF ASS'Y. - PICKING UP SINGLE JOINTS OF 4" DRILL PIPE FROM THE PIPE SHED. - FROM 4487' TO 9093'. - UP WEIGHT = 165K LBS, DOWN WEIGHT = 145K LBS. 21:30 - 22:00 0.50 FISH P DECOMP WORK 7" CASING SCRAPER ACROSS PACKER SETTING DEPTH. j ' INSTALL TOP DRIVE BLOWER HOSE. - RUN IN THE HOLE WITH BHA #1, 4 1/2" TUBING DRESS -OFF ASS'Y. - FROM 9093' TO 9281'. - UTILIZING 4" DRILL PIPE STANDS FROM l DERRICK. - UP WEIGHT = 175K LBS, DOWN WEIGHT = 150K LBS. - WORK 7" SCRAPER ACROSS PACKER SETTING DEPTH 4 TIMES. 1 - FROM 9149' TO 9243'. Printed 3/4/2011 10:40:06AM �� I Am a - ALAS BP s aft17 +A� ' s O peratic Summary Report Common Well Name: 05-41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM 1Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05-41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task j Code NPT NPT Depth Phase Description of Operations (hr) 1 � (ft) 22:00 - 23:30 1.50 FISH P DECOMP DRESS OFF 41/2" TUBING STUB AT 9307' DPM. - E� STABLISH MILLING PARAMETERS: - 5 BPM AND 720 PSI. - 60 RPM WITH 3.5K FT -LBS TORQUE. - UP WEIGHT = 175K LBS, DOWN WEIGHT = 150K LBS. - ROTATING WEIGHT = 160K LBS. — TAKE SLOW PUMP RATES - 9281' MD, 8590' TVD. - EASE DOWN AND TAG 4 1/2" TUBING STUB AT -9307' DPM. j E - DRESS OFF 4 1/2" TUBING STUB. DRESS OFF FLARE AND CONTINUE TO SWALLOW STUB. SWALLOW -18' OF TUBING STUB, TO 9325'. OBSERVED PRESSURE INCREASE AS INNER MILL ENTERED TUBING STUB. MILLED OFF -6" OF 4 1/2" TUBING WITH rINNERMILL - WEIGHT ON MILL = 4K TO 8K LBS. - PRESSURES INCREASED TO OVER 1200 PSI. - REDUCED PUMP RATES AND CONTINUE TO CLEAN UP TUBING STUB. - PICKED UP OFF OF TUBING STUB WITH NO ROTATION AND PUMPS OFF. I i - MINIMAL DRAG NOTED. 1- EASED BACK DOWN OVER TUBING STUB. - REQUIRED MINIMAL ROTATION TUBING STUB ENTERED DRESS -OFF AS SHOE. - NO ROTATION AND PUMPS OFF. - MINIMAL DRAG NOTED. 23:30 - 00:00 0.50 FISH P DECOMP CIRCULATE HOLE CLEAN WITH HIGH -VIS SWEEP AND CLEAN 8.5 PPG SEAWATER. 1 - PICK UP OFF OF 4 1/2" TUBING STUB. - CIRCULATE 25 BBL HIGH -VIS SWEEP. 1- CHASE SWEEP WITH CLEAN 8.5 PPG SEAWATER. - WORK STRING -20' WHILE CIRCULATING. - 8.5 BPM AND 1980 PSI. - UP WEIGHT = 158K LBS, DOWN WEIGHT = 145K LBS. 2/11/2011 00:00 - 01:00 1.00 FISH P DECOMP CONTINUE TO CIRCULATE HOLE CLEAN WITH HIGH -VIS SWEEP AND CLEAN 8.5 PPG SEAWATER. - CIRCULATE 25 BBL HIGH -VIS SWEEP. - CHASE SWEEP WITH CLEAN 8.5 PPG 'SEAWATER. - WORK STRING 20' WHILE CIRCULATING. - 8.5 BPM AND 1980 PSI. - UP WEIGHT = 158K LBS, DOWN WEIGHT = 145K LBS. - PUMPED 350 BBLS. MINOR AMOUNT OF METAL SHAVINGS RECOVERED AT SURFACE. - OPEN AND MONITOR OA IN PREPARATION FOR PACK -OFF CHANGE OUT. Printed 3/4/2011 10:40:06AM Ce" A h Alri B P; ` ?agetof tT Op ati n Summer` Report Common Well Name: 05-41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05-41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 01:30 0.50 FISH P DECOMP RIG UP TO PULL OUT OF THE HOLE WITH BHA #1, 4 1/2" TUBING DRESS -OFF ASS'Y. - KILL LINE IN CELLAR DEVELOPED ICE DUE TO WINDS ENTERING CELLAR. - USE STEAM TO THAW KILL LINE. CHINK HOLES IN CELLAR TO REDUCE WIND INFILTRATION. 01:30 - 05:30 4.00 FISH P DECOMP PULL OUT OF THE HOLE WITH BHA #1, 4 1/2" TUBING DRESS -OFF ASS'Y. - STAND BACK 4" DRILL PIPE IN DERRICK. - MONITOR WELL PRIOR TO PULLING BHA. - VVELL'IS STATIC. 05:30 - 08:00 2.50 FISH P DECOMP LAY DOWN BHA #1, 4 V2" TUBING DRESS -OFF ASS'Y. - PJSM WITH RIG CREW AND BAKER FISHING F � REPRESEfVTAT6VE - -. - RECOVERED THE FOLLOWING FROM THE JUNK BASKETS: 1 SS BAND WITH THE BUCKLE ATTACHED. - 1 SS BAND BUCKLE. SEVERAL SMALL PIECES OF SS BAND. SEVERAL SMALL PIECES OF 1/4" CONTROL LINE. 08:00 - 10:30 2.50 WHSUR ( P DECOMP CHANGE OUT 7" CASING PACK -OFF. 1- PULLED THE WEAR BUSHING. FMC REPRESENTATIVE B.O.L.D.S. - PULL 7" PACK -OFF THROUGH THE STACK. - PULLED 15K LBS TO FREE PACK -OFF. - INSTALLED THE NEW 7" CASING PACK -OFF. - FMC REPRESENTATIVE R.I.L.D.S. 10:30 - 13:00 2.50 WHSUR P DECOMP !, RIG UP AND PRESSURE TEST THE 7" PACK -OFF SEALS. - TEST SEALS TO 250 PSI LOW FOR 5 I MINUTES. TE . CHARTED U S - GOOD TEST. - TEST SEALS TO 5000 PSI FOR 30 CHARTED M(RO I E5. - REQUIRED 2 HOURS TO GET A 30 MIN STABLE TEST. - PRESSURES INCREASED AND DECREASED WITH TEMPERATURE —t FLUCTUATIONS IN CELLAR. 13:00 - 14:30 1.50 FISH P DECOMP ; PICK UP BHA #2, JUNK CATCHER RETRIEVAL BHA. - INSTALL WEAR BUSHING. PJSM AND BRING ALL BHA COMPONENTS TO RIG FLOOR. - MU BHA #2 PER BAKER FISHING REPRESENTATIVE AS FOLLOWS: - ITCO SPEAR WITH 2.933" GRAPPLE - (2) EXTENSIONS - STOP SUB - 'XO' TO 2 7/8" PAC - (1) JT 2 7/8" PAC DRILL PIPE - 'XO' TO 3 1/2" IF - BUMPER SUB - PUMP -OUT SUB - 'XO' BACK TO DRILL PIPE - TOTAL LENGTH = 52.64' - MAXOD =5" 1- MIN ID = 1/2" Printed 3/4/2011 10:40:06AM • America - ALASKA BP "' Page 10 ®f 17 ''` 4 Operation Summa or v Common Well Name: 05-41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 1 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) 1 Project: Prudhoe Bay ! Site: PB DS 05 Rig Name /No.: NABORS 7ES I Spud Date/Time: 8/28/1996 12:00:OOAM I Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05-41 @72.43ft (above Mean Sea Level) Date From - To Hrs ! Task Code i t NPT 1 NPT Depth Phase 1 Description of Operations (hr) 1 (ft) 14:30 - 18:30 I 4.00 FISH P '1 DECOMP RUN IN THE HOLE WITH BHA #2, JUNK CATCHER RETRIEVAL BHA, ON 4" DRILL PIPE 1 FROM DERRICK. I i ,:.,. 1- FROM 52' TO 9300'. +- UP WEIGHT = 162K LBS, DOWN WEIGHT = 148K LBS. 18:30 - 19:30 1.00 FISH P DECOMP ENGAGE AND PULL JUNK CATCHER FREE 1 FROM 4 1/2" TUBING. - ESTABLISH PARAMETERS: - 4.8,BPM AND 1870 PSI. I ∎ ` - UP WEIGHT = 162K LBS, DOWN WEIGHT `= 148K LBS. I , I- EASE DOWN AND ENGAGE JUNK CATCHER. - FROM 9309' TO 9318' DPM. - 1 BPM ND 170 PSI -SET DOWN 1 OK LBS ON FISH. - PICK UP ON FISH OBSERVED 25K LB OVERPULL. ' SLOWLY WORK PIPE INCREASING ; OVERPUL E I PIPE PULLED FREE WITH 100K LBS f OVERPULL. ' - PICK UP 15' ABOVE TUBING STUB. ' - VERIFIED "FISH ON'. - EASE DOWN AND TAG TUBING STUB 10' 1 1 I HIGH. 19:30 - 20:00 0.50 I FISH P DECOMP I RIG UP TO DISPLACE WELLBORE TO CLEAN 8.5 PPG SEAWATER. I 1- LAY DOWN 2 SINGLE JOINTS OF 4" DRILL I PIPE. 1 - DROP DART DOWN STRING. - OPEN PUMP OUT SUB. 1 P IRE IRED TO PEN SUB. 500 SQU O 120:00 - 20:30 i 0.50 FISH P DECOMP DISPLACE WELL TO CLEAN 8.5 PPG I SEAWATER. 1 - TAKE SLOW PUMP RATES. - 9290' MD AND 8588' TVD. 1- PUMP 323 BBLS WHILE RECIPROCATING ; PIPE. 1 - 9.5 BPM AND 1620 PSI. i - UP WEIGHT = 152K LBS, DOWN WEIGHT = 135K LBS. 20:30 - 22:00 1 1.50 FISH P 1 DECOMP PERFORMED A D-5 (WELL KILL) AND A D-6 (STRIPPING) DRILL WITH BOTH CREWS. - DURING THE D-5 DRILL THE CREWS CIRCULATED THROUGH THE CHOKE WITH 1 100 -150 PSI TARGET AND VARIED THE PUMP STROKES TO GET A FEEL FOR HOW THE CHOKE OPERATED_ 1 I - THE D-6 DRILL WAS A TABLE TOP DRILL. I i - CREWS WENT THROUGH THE PROCEEDURE. - TOOLPUSHER AND DRILLER HELD A QUESTION AND ANSWER SESSION WITH _ CREW. 22:00 - 00:00 2.00 FISH P DECOMP PULL OUT OF THE HOLE WITH BHA #2, JUNK 1 CATCHER RETRIEVAL BHA, LAYING DOWN I 1 DRILL PIPE. - FROM 9300' TO 6726' DPM. 1 - UP WEIGHT = 130K LBS, DOWN WEIGHT = I 117K LBS. Printed 3/4/2011 10:40:06AM Am erica `- ALAS BP .s Page 1 t of ll O pera ti on S ummary Report Common Well Name: 05-41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM i Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. 1UWI: 500292269600 Active Datum: 05-41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task Code NPT ! NPT Depth Phase Description of Operations (hr) (ft) 2/12/2011 00:00 - 03:00 3.00 FISH P r DECOMP CONTINUE TO PULL OUT OF THE HOLE WITH BHA #2, JUNK CATCHER RETRIEVAL BI-IA, LAYING DOWN DRILL PIPE. - FROM 6726' TO 899' DPM. :OUTSIDE TEMPERATURES DROPPED TO -38 1DEGF. 1- HELD DISCUSSIONS WITH RIG CREW ABOUT WORKING IN COLD TEMPERATURES. DE- RATED. LOADER 50% - TOOLPUSHER PERFORMED RISK ASSESSMENT FOR LOADER OPERATIONS I WITH LOADER OPERATOR. 03:00 - 05:00 2.00 FISH P , DECOMP CUT AND SLIP DRILL LINE. 1- CUT 117'. - SERVICE TOP DRIVE - GREASE- BLOCKS. 05:00 - 05:30 0.50 FISH P DECOMP CONTINUE TO PULL OUT OF THE HOLE WITH BHA #2, JUNK CATCHER RETRIEVAL BHA, LAYING DOWN DRILL PIPE 1- FROM 915' TO BHA #2. I I I 05:30 - 06:30 1.00 FISH , P I DECOMP. LAY DOWN BHA #2, JUNK CATCHER ;RETRIEVAL BHA, AND JUNK CATCHER. -SPEAR WAS STUCK IN JUNK CATCHER AND HAD TO BE SENT TO THE MACHINE SHOP FOR REMOVAL. 06:30 - 07:30 i 1.00 WHSUR P DECOMP i REMOVE WEAR BUSHING. - RIG UP AND PULL WEAR BUSHING. - PICK LANDING JOINT AND TUBING HANGER. - MAKE A DUMMY RUN AND MARK _ LANDING JOINT. 07:30 - 09:30 2.00 RUNCOM P RUNCMP RIG UP TO RUN 4 1/2 ", 12.6LB, 13CR-85, , VAMTOP COMPLETION. i - RIG UP SINGLE JOINT COMPENSATOR. - RIG UP TORQUE TURN EQUIPMENT. 09:30 - 12:00 2.50 RUNCOM P RUNCMP RUN 4 1/2 ", 12.6LB, 13CR-85, VAMTOP COMPLETION. - PJSM WITH RIG CREW AND NABORS CASING HAND. - PICK UP AND MAKE UP COMPLETION JEWELRY. - BACKER -LOC ALL CONNECTIONS BELOW j THE PACKER. - OPTIMUM MAKE UP TORQUE = 4440 FT -LBS. 1- UP WEIGHT = 50K LBS, DOWN WEIGHT = 50K LBS. 12:00 - 23:00 11.00 RUNCOM P RUNCMP ' CONTINUE TO RUN IN THE HOLE WITH THE 4 x1/2 ", 12.6LB, 13CR-85, VAMTOP COMPLETION. - OPTIMUM MAKE UP TORQUE = 4440 FT -LBS. - UP WEIGHT = 135K LBS, DOWN WEIGHT = 1 120K LBS. - FROM 1565 TO 9290'. Printed 3/4/2011 10:40:06AM F AlneEIE�L ALASKA BP h I?a 12 of 1 � Operation. Summary Raps Common Well Name: 05 -41 AFE No Event Type: WORKOVER (WO) I Start Date: 2/4/2011 I End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay I Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05-41 @72.43ft (above Mean Sea Level) Date j From - To Hrs Task Code ! NPT NPT Depth Phase Description of Operations (hr) (ft) _L 23:00 - 23:30 0.50 RUNCOM P RUNCMP SPACE OUT AND LAND 4 1/2", 12.6LB, 13CR -85, VAMTOP COMPLETION. - OBSERVED FIRST SHEAR ON OVERSHOT AT 9315'. - PINS SHEARED WITH 12K LBS. - OBSERVED SECOND SHEAR ON OVERSHOT AT 9322'. PINS SHEARED WITH 15K LBS. - TAGGED NO-GO ON OVERSHOT AT 9325'. - SET DOWN 1 OK LBS TO VERIFY. PICKED UPAND SPACED OUT I COMPLETION. - ADDED 9.81' PUP JT TO STRING. yyy - BOTTOM OF OVERSHOT AT 9321' I TOP OF TUBING STUB 4 BELOW OVERSHOT NO-GO ' 23:30 - 00:00 0.50 RUNCOM P RUNCMP 1 LAND TUBING HANGER. I- PICKED UP TUBING HANGER AND MADE UP TO LANDINGJOINT. - LANDED COMPLETION AND RAN IN LOCK DOWN SCREWS ON TUBING HANGER. - UP WEIGHT = 135K LBS, DOWN WEIGHT = 120KLBS. 2/13/2011 00:00 - 01:00 1.00 RUNCOM P RUNCMP RIG DOWN COMPLETION RUNNING EQUIPMENT. - LAY DOWN LANDING JOINT. - RIG DOWN POWER TONGS. - RIG UP IN PITS TO CIRCULATE. 01:00 - 03:00 2.00 RUNCOM F P T RUNCMP SPOT CORROSION INHIBITED SEAWATER AND DROP BALL AND ROD. REVERSE CIRCULATE 140 BBLS OF CLEAN SEAWATER. - 3 BPM AND 600 PSI. - REVERSE CIRCULATE 160 BBLS OF CORRSOION INHIBITED SEAWATER. - 3 BPM AND 600 PSI. I- REVERSE 10 BBLS OF CLEAN SEAWATER TO KEEP CORROSION INHIBITED SEAWATER FROM GETTING IN THE PITS. - PUMP 5 BBLS OF CLEAN SEAWATER TO FLUSH DEBRIS OFF OF BALL SEAT ON RHC-M PLUG. - INSTALLED LANDING JOINT. - DROPPED BALL AND ROD. Printed 3/4/2011 10:40:06AM , '''''''://''':::'''27./''' S ortPAm erica AI.AS KABP Page- i3 0 #f 1 7 ' Ope ration Summary Report s s, Common Well Name: 05-41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4- OOPMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM i Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05 -41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task ' Code 1 NPT NPT Depth; Phase Description of Operations (hr) (ft) ■ 03:00 - 07:00 4.00 RUNCOM P 1 RUNCMP SET HALLIBURTON'TNT PACKER AND 1 PRESSURE TEST TUBING AND PACKER. - PRESSURE UP ON TUBING TO SET 1 HALLIBURTON'TNT PACKER. - PACKER SET TO SHEAR AT 1900 PSI. DID NOT SEE POSITIVE INDICATION OF PACKER SETTING. I- PRESSURE TEST TUBING TO 3500 PSI FOR I ! 30 CHARTED MINUTES. 1 1 - FIRST TEST SENSATOR FLATTENED OUT. i - REPLACED SENSATOR AND RE -TEST. - SECOND TEST DID NOT MEET ADWOP REQUIREMENTS. 1 BLED OFF 100. PSI OVER THE ENTIRE 30 MINUTE PERIOD. - 50 PSI, BLEED IN THE FIRST 15 MIN. - 50 PSI- BLEED IN THE SECOND 15 MIN. - THIRD TEST PASSED. i - PRESSURE UP TO 250 PSI FOR 5 MIN. 1 l - GOOD TEST. - r PRESSURE UP TO 3500 PSI FOR 40 MIN - PRESSURE STABILIZED AFTER 10 I MINUTES. - 60 PSI BLEED IN THE FIRST 15 MIN. I - 10 PSI BLEED IN THE SECOND 15 MIN. j l - BLED OFF TUBING SIDE TO 1500 PSI. - PRESSURE TEST ANNULUS TO 3500 PSI, is : 1 . ' RTED MINUTES. - PRESSURE UP TO 250 PSI FOR 5 MIN. - GOOD TEST. - PRESSURE UP TO 3500 PSI FOR 30 MIN. - 40 PSI BLEED IN THE FIRST 15 MIN. - 10 PSI BLEED IN THE SECOND 15 MIN. - BLED OFF ANNULUS TO 1500 PSI. - BLED OFF TUBING AND ANNULUS TOGETHER TO 0 PSI. 1- CALLED RWO SUPERINTENDENT WITH TEST RESULTS. , - AUTHORIZED TO PROCEED. - PRESSURE UP ON ANNULUS TO SHEAR II DCK VALVE. - DCK SHEARED AT 3500 PSI. - PUMPED 5 BBLS EACH WAY TO ENSURE CIRCULATION FOR FREEZE PROTECT. Printed 3/4/2011 10:40:06AM .a t Americas = ALASKA - BF?; Page 14 of 17 i f Operation Summary Eiepo Common Well Name: 05-41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05 -41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 10:30 3.50 WHSUR P RUNCMP INSTALL AND TEST TWC. - FMC REPRESENTATIVE USED DRY ROD TO INSTALL TWC. 1- TEST TWC FROM BELOW. - PRESSURE UP TO 250 PSI FOR 5 MIN. - GOOD TEST. PRESSURE UP TO 1000 PSI FOR 10 MIN. GOOD TEST. - ATTEMPTED TO TEST TWC FROM ABOVE 2 TIMES, - PRESSURE UP TO 250 PSI FOR 5 MIN. - GOOD TEST. PRESSURE UP TO 3500 PSI. - PRESSURE BLED OFF AT 100 PSI PER MIN. h FOUND LEAK IN KILL LINE UNIBOLT. - REPLACED BRASS IN UNIBOLT. - RETEST TWC FROM ABOVE. PRESSURE UP TO 250 PSI FOR 5 MIN. - GOOD TEST. 1/ - PRESSURE UP TO 3500 PSI FOR 10 MIN. - GOOD TEST. 10:30 - 15:00 4.50 BOPSUR P RUNCMP j RtG DOWN AND PREPARE TO NIPPLE DOWN BOPE BLOW DOWN ALL LINES TO BOP STACK AND PITS. - DISCOVERED ICE PLUG IN KELLY HOSE. - RIG UP STEAM TO THAW OUT KELLY HOSE AND STAND PIPE. - PUMP OUT BOP STACK. - RIG DOWN HYDRAULIC LINES TO BOP STACK. 15:00 - 17:00 ! 2.00 BOPSUR " " P RUNCMP NIPPLE DOWN BOP STACK. -NIPPLE DOWN BOP STACK. I , - SET STACK BACK ON STUMP IN CELLAR. I I' � CONTINUE TO WORK ON THAWING OUT STAND PIPE. I- USING STEAM AND AIR TO THAW AND CLEAR STAND PIPE. ;17:00 - 20:00 3.00 WHSUR P RUNCMP NIPPLE UP ADAPTER FLANGE AND TREE. I � I CONTINUE TO WORK ON THAWING OUT ;STAND PIPE. Printed 3/4/2011 10:40:06AM � ter' - t AL AS BP agee i5 arm i � pecatuon Summary. Report Common Well Name: 05 -41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15 /2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05-41 @72.43ft (above Mean Sea Level) Date From - To 1 Firs Task , Code NPT ! NPT Depth Phase Description of Operations (hr) I I (ft) 20:00 - 22:00 ! 2.00 1 WHSUR � P RUNCMP ! PRESSURE TEST ADAPTER VOID TO 5000 PSI ■ FOR 30 CHARTED MINUTES. 1 , 1 - PRESSURE UP TO 300 PSI FOR 5 MIN. FILLED VOID WITH COLD ( -8 DEG F) FLUID. - DONE TO HELP MITIGATE TEMPERATURE EFFECTS. C PRESSURE STABILIZED AFTER 3 MIN. PRESSURE GRADUALLY INCREASED OVER TEST DURATION. r - APPROXIMATELY 3 TO 10 DEG PER MIN. j PRESSURE UP TO 5000 PSI FOR 30 MIN. - PRESSURE STABILIZED AFTER 5 MIN. I WIND INFILTRATION INTO CELLAR 1 I BECAME AN ISSUE, PRESSURE BEGAN TO DECREASE AS WIND INCREASED. - PLUGGED UP HOLES IN CELLAR TO � I BLOCK WIND. - SURROUNDED WELLHEAD WITH I � HURCULITE. - PRESSURE INCREASED SLIGHTLY. L - BUILT 20 PSI OVER LAST 15 MIN. CONTINUE TO WORK ON THAWING OUT ' I STAND PIPE. 22:00 - 00:00 2.00 WHSUR P � RUNCMP PRESSURE TEST TREE TO 5000 PSI FOR 30 CHARTED MINUTES. - FILLED TREE AND TEST LINES WITH DIESEL. - CYCLED TREE VALVES. - PRESSURE UP TO 300 PSI FOR 5 MIN. - PRESSURE DECREASED ABOUT 150 ' PSI. - PRESSURED UP TO 1000 PSI AND CHECKED FOR LEAKS. I - NO LEAKS FOUND. - CYCLED VALVES WITH PRESSURE. I - BLED ALL AIR FROM SYSTEM. I - CONTINUED TO WORK VALVES WITH PRESSURE. - PRESSURE DROP LESSENED WITH I ! REPEATED WORKING OF VALVES. - PRESSURED UP TO 300 PSI FOR 5 MIN. I - PRESSURE STABILIZED AFTER 1 MIN. - PRESSURE GRADUALLY INCREASED 50 I I PSI OVER 5 MIN. I 1 I - PRESSURED UP TO 5000 PSI FOR 30 MIN. - PRESSURE STABILIZED AFTER 5 MIN. l - PRESSURE INCREASED 20 PSI OVER NEXT 15 MIN. - PRESSURE STABILIZED AND HELD FOR NEXT 15 MIN. CONTINUE TO WORK ON THAWING OUT —i- 1 STAND PIPE. I Printed 3/4/2011 10:40:06AM lip: Amertea - ALASKA BP 16 c1 t7 t Y Operation Summary Repo Common Well Name: 05-41 AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES ' Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05-41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/14/2011 00:00 - 01:00 1.00 WHSUR P RUNCMP CONTINUE TO PRESSURE TEST TREE TO 5000 PSI FOR 30 CHARTED MINUTES. - FILLED TREE AND TEST LINES WITH DIESEL. - CYCLED TREE VALVES. - PRESSURE UP TO 300 PSI FOR 5 MIN. - PRESSURE DECREASED ABOUT 150 PSI. 1 PRESSURED UP TO 1000 PSI AND CHECKED FOR LEAKS. - NO LEAKS FOUND. - CYCLED VALVES WITH PRESSURE. - BLED. ALL AIR FROM SYSTEM. - CONTINUED TO WORK VALVES WITH PRESSURE. - PRESSURE DROP LESSENED WITH 1 REPEATED WORKING OF VALVES. - PRESSURED UP TO 300 PSI FOR 5 MIN. - PRESSURE STABILIZED AFTER 1 MIN. — PRESSURE GRADUALLY INCREASED 50 I PSI OVER 5 MIN. - PRESSURED UP TO 5000 PSI FOR 30 MIN. - PRESSURE STABILIZED AFTER 5 MIN. - PRESSURE INCREASED 20 PSI OVER NEXT 15 MIN. - PRESSURE STABILIZED AND HELD FOR NEXT 15 MIN. CONTINUE TO WORK ON THAWING OUT (STAND PIPE. 01:00 - 03:00 2.00 WHSUR P RUNCMP j PULL TWC. 1- RIG UP DSM LUBRICATOR AND TEST. - PRESSURE UP TO 300 PSI. - GOOD TEST. - PRESSURE UP TO 3500 PSI. - HAD DIFFICULTY GETTING TEST. - BUMPED PRESSURE UP 3 TIMES. - GOOD TEST ACHIEVED AFTER 3 TRIES. - PULLED AND LAVED DOWN THE TWC. 1- RIG DOWN DSM LUBRICATOR. 03:00 - 06:00 3.00 WHSUR P RUNCMP 'PUMP 65 BBLS DIESEL FREEZE PROTECT. PJSM WITH RIG CREW AND LITTLE RED HOT OIL SERVICE REPRESENTATIVES. - RIG UP LITTLE RED HOT OIL TO PUMP 1 DIESEL FREEZE PROTECT. - PRESSURE TESTED SURFACE LINES 250 PSI LOW, 3500 PSI HIGH. - REVERSE IN 65 BBLS OF 80 DEG F DIESEL. - LINE UP AND U -TUBE DIESEL BETWEEN TUBING AND ANNULUS. 06:00 - 10:00 4.00 WHSUR P RUNCMP INSTALL BPV. -RIG UP DSM LUBRICATOR AND TEST. - PRESSURE UP TO 300 PSI. -GOOD TEST. - PRESSURE UP TO 3500 PSI. -GOOD TEST - INSTALLED THE BPV. - SECURED THE WELL. Printed 3/4/2011 10:40:06AM 41Wqrth America ALASKA Bp - 2 p 17 of 1T Operation Summa Report Common Well Name: 05-41 j AFE No Event Type: WORKOVER (WO) Start Date: 2/4/2011 I End Date: 2/15/2011 X4- 00PMS -E: (1,813,000.00 ) Project: Prudhoe Bay ' Site: PB DS 05 Rig Name /No.: NABORS 7ES I Spud Date/Time: 8/28/1996 12:00:OOAM Rig Release: 2/15/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292269600 Active Datum: 05 -41 @72.43ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) (- 10:00 - 15:30 5.50 WHSUR P RUNCMP j WAITING ON WEATHER. -PHASE 3,LEVEL 3 CONDITIONS DECLARED ACROSS THE FIELD. -RIG CREW S REVIEW ED STOP PROGRAM. -RIG CREW BEGAN W ORKING ON PETROLEUM REFINING AND OIL & GAS EXTRACTION W ORKBOOKS 3, 4AND 5. 15:30 16:00 0.50 WHSUR P RUNCMP (WAITING ON WEATHER. i -PHASE 3, LEVEL 3 CONDITIONS CONTINUE. -CREW CHANGE. ARRANGE W ITH EOA IMT FOR CREW CHANGE -CONVOY W ITH RIG LOADER AND CHANGE OUT CREWS. 16:00 - 00:00 8.00 WHSUR P RUNCMP * WAITING ON WEATHER PHASE 3, LEVEL 3 CONDITIONS CONTINUE. - RIG CREW REVIEWED STOP PROGRAM. - RIG CREW BEGAN WORKING ON ■ PETROLEUM REFINING AND OIL & GAS EXTRACTION WORKBOOKS 3, 4 AND 5. 2/15/2011 00:00 - 00:30 0.50 WHSUR P 1 RUNCMP WAITING ON WEATHER. - PHASE ROADS & 2, LEVEPADS. L 3 CONDITIONS ON ALL - WEATHER IS IMPROVING. - CREW CHANGE. i I - ARRANGE WITH EOA IMT FOR CREW CHANGE. - CONVOY WITH RIG LOADER AND CHANGE OUT CREWS. 00:30 - 09:00 8.50 WHSUR P RUNCMP WAITING ON WEATHER. - PHASE 2, LEVEL 3 ON ALL ACCESS ROADS l& PADS. - EOA IMT CALLED AT 01:00. / - STILL LEVEL 3 ON ROADS AND PADS. ✓ - NO NON - EMERGENCY WORK OR TRAVEL WITHOUT APPROVAL. - PREP RIG FLOOR FOR RIG MOVE. - CLEAN Y- STRAINERS ON KOOMY UNIT. - INSPECT AND REPLACE O -RINGS ON DUTCH RISER LOCK - DOWNS. { - CHANGE OUT A GUN LINE IN THE PITS. 09:00 - 10:30 1.50 WHSUR P RUNCMP RIG DOWN. - RECIEVED THE GO -AHEAD TO RESUME OPERATIONS FROM IMT. { - RIG DOWN DSM LUBRICATOR. - RIG DOWN LITTLE RED HOT OIL SERVICE'S LINES. 10:30 12:00 1.50 WHSUR P RUNCMP �- SECURE TREE AND CELLAR FOR RIG MOVE. - REMOVED THE DOUBLE ANNULUS VALVES. ' - INSTALLED ALL OF THE FLANGES AND ;GAUGES. - INSTALLED THE TREE CAP. - SECURED THE CELLAR. RELEASED THE RIG FROM DS 05-41A @ 12:00 I HRS FOR MOVE TO DS 02 -07A. Printed 3/4/2011 10:40:06AM • • ~'-~, MICROFILMED 0310112008 DO NOT PLACE .'`...., .~~ - ~ ~ _ ;:, c~__ ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc 05-41A (PTD #2031700) UNDER EV ALUA nON for sustained casin... . . Subject: 05-41A (PTD #2031700) UNDER EVALUATION for sustained casing pressure - TxIA Communication From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Fri, 15 Joo 2007 19:21 :56 -0800 To: "GPB, FSl DS Ops Lead" <GPBFSIDSOpsLead@BP.com>, "GPB, FSl OTL" <GPBFSI0TL@BP.com>, "GPB, Area Mgr East (FSl/2/COTU/Seawater)" <GPBAreaMgrEastFS 12CS@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "Engel, Harry R" <Harry.Engel@BP.com>, ''NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "GPB, EOC Specialists" <GPBEOCSpecialists@BP.com>, James Regg <jim _regg@admin.state.ak.us>, tom _ maunder@admin.state.ak.us, Robert Fleckenstein <bob_fleckenstein@admin.state.ak.us>, "Dean, James A" <James.Dean@BP.com>, ''NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com> CC: ''NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Holt, Ryan P (ASRC)" <Ryan.Holt@BP.com>, "Roschinger, Torin T." <Torin.Roschinger@BP.com> All, Well 05-41A (PTD #2031700) has been found to have sustained casing pressure on the IA. On 06114107 the well failed a TIFL on IA pressure build up following an operator call-in of high IA pressure. The wellhead pressures were 1407/2420/40 on 06/13/07 when reported for high IA pressure. The well has been classified as Under Evaluation and may be produced under a 28-day clock. The plan forward is: 1. 0: TIFL - FAILED on BUR 2. S: Set TIP, Caliper 3. F: MIT-T to 3000 psi, CMIT-TxIA to 3000 psi, LLR if either fails A wellbore schematic has been included for reference. «05-41 A. pdf» Please call with any questions or concerns. Thank you, 5(;ANNED JUN 1 8 Z007 Paul Austin for Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: 05-41A.pdf 05-41A.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/18/2007 9:07 AM FMC GEN 5 CN\! BAKER C 72.4' 1216' 19-5/8" CSG, 40#, L-80, ID = 8,835" I 17" CSG, 26#, L-80, ID = 6.276" I 8962' Minimum ID =:. 2.377" @ 10205' TOP OF 2-7/8" LINER 4-1/2" TBG,12.6#, L-80, 9417' .0152 bpf, ID = 3.958" 1 T' CSG, 29#, L-80, 10 = 6.184" 3-1/2" LNR, 8.81#, L-80 .0087 bpf, 10 = 2.992" I MECHA NICAL HOLLOW WHIPSTOCK ÆRFORA TION SUMMA RY REF LOG: MCNL/CCL/GR ON 01/21/04 ANGLEATTOPÆRF: 91 @ 10270' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL DATE 2" 6 10270 - 10800 0 01/22/04 2" 6 11335 - 11430 0 01/22/04 2" 6 11500 - 11910 0 01/22/04 14-112" SL TD LNR, 12.6#, L-80, ID = 3.958" I 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" I COMMENTS LETlON ETRACK (05-41A) 05 1 SAFETY NOTES: ~TOCK WILL BE SELECTIVELY PERFORATED IN ~KTURE TO INITIATE PRODUCTION FROM THE TOE OF THE THE ORIGINAL SLOTTED LINER SECTION. RA TAGS WERE INSTALLED IN XN NIP AS A MARKER. X & XN NIPS OF CTD LNR ARE NOT USEABLE DUE TO MIN ID OFTHE LNR TOP PKR. . 2168' 4-1/2" CAMCO BAL-O SVLN, SSSV NIP, ID - 3.812" ST MD TVD 1 3900 3689 2 6758 6296 3 9291 8615 GAS LIFT MANDRELS TYPE VLV LATCH KBG-2-LS-MOD DMY INT KBG-2-LS-MOD DMY INT KBG-2-LS-MOD OMY INT PORT DATE o 08/21/06 o 08/21/06 o DEV 25 25 24 9348' H 4-1 12" BKR KB LNR TOP PKR, ID = 2.560" I -17" X 4-1/2" BKR S-3 PKR, ID = 3.875" (BEHIND CT LNR) -13.5" BKR DEPLOYMENT SLV, ID = 3.0" I -13-1/2" HES X NIP, ID = 2.813" I -14-1/2" HES X NIP, 10 = 3.813" (BEHIND CT LNR) -14-1/2" WLEG, ID = 3.958" (BEHIND CT LNR) 9416' HELMD I 9913' -14-1/2" PORTED JOINT (BEHIND CTLNR) I 9985' --13-1/2" HES XN NIP WI RA MARKER, 10 = 2.750" 9996' -13-1/2" X 3-3116" XO, 10 = 2.786" I MILLOUT WINDOW 10002' - 10001' -13-3/16" X 2-718" XO, ID = 2.440" I 12-3/8" TAILPIPE WI 2 ÆRFED 8TM JTS I 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" I 12-7/8" LNR, 6.16#, L-80, ,0055 bpf, 10 = 2.377" DA TE REV 8Y COMMENTS PRUDHOE BA Y UNIT WELL: 05-41 A PERMIT No: "2031700 API No: 50-029-22696-01 SEC 32, T11 N, RiSE, 2321.75' FEL & 1282.27' FNL BP Exploration (Alaska) e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 13~ OJ J RE: MWD Formation Evaluation Logs 05-41A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 05-41A: LAS Data & Digital Log Images: 50-029-22696-01 ~03·~ 170 1 CD Rom /}Ç'~ dJ! !)Q/D~ ;Z.3 ¡:;t, DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2031700 Well Name/No. PRUDHOE BAY UNIT 05-41A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22696-01-00 MD 11956 TVD 9049 Completion Date 1/23/2004 Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey ,---~,- DATA INFORMATION Types Electric or Other Logs Run: SCRC Combined GR & EWR, MGR / CCLI CNL Well Log Information: (data taken from Logs Portion of Maste -,Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments f.ø- CD -"Ð"""' þ:'- 12C30 LlC V'-rificðtiol'l 9704 119'"~ 9/:)/2'004 MWD ~ Neutron 2 Blu 9208 11840 Case 7/14/2005 Compensated Neutron Log ~D Memory GRlCCLlCNL Pdf Directional Survey 9999 11956 2/26/2004 Directional Survey 9999 11956 2/26/2004 ED D Lis 12638 Gamma Ray 9784 11908 9/3/2004 MWD, GR, EWR, ROP _.Rpt 12638 LIS Verification 9784 11955 9/3/2004 MWD, ROP, GR, DSN 12638 ~. C Lis 13241 Neutron 9208 11840 Case 7/14/2005 Compensated Neutron Log Memory GR/CCLlCNL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Y~ Chips Received? ~ ~/ Well Cored? Daily History Received? (V>N ðN Formation Tops Analysis Received? Comments: . . Permit to Drill 2031700 MD 11956 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Well Name/No. PRUDHOE BAY UNIT 05-41A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22696-01-00 9049 ~PI:;," D,,, 1/23/2004 Completion Status 1-01L Current Status 1-01L ..... ~ UIC N Date: ~ro ~~ ~~ . . SchlumbePDBP Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well 1-31/M-21 11)- O"7à 07-34A ) Cc - ð¡ ..> 15-14A ;;UN-.ÀJ.;t. Y -238 ). () 3 .. I (,¡ '1 N-08A J. ~~, ~ cq K-08A ^ \:. ~ ~ í t.( \J W-26A I c\ '\ - C:\ \ L5-09 Î tl ~~ i,).. i OWDW-NW , C c· ^- i \::. C-34 ¡ 93· 0/ ') 01-12A ';2 ~ ).. - I C'll DS05-41A j..\:¡ ~,- I -/~ 02-26C .ì- C;, \; - i2: \ C\ . Job# 10980540 11001051 10913003 10913024 10919802 10942219 11051066 11051037 10980537 10831309 10928620 10715377 10928619 RST (REVISED)" RST (REVISED)" PEX-DSI-AIT PDC-GR LDL MEM PPROF LDL RST RST RST MCNL MCNL MCNL "REVISED TO CORRECT API# ON DIGITAL DATA 07/14/05 Log Description NO. 3433 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Date BL Color CD . 04/14/05 1 1~.l~3 04/26/05 1 n;A~Y 01/16/05 1 jjA)C 06/09/05 1 /J J..J b, 09/24/04 1 06/24/05 1 06/23/05 1 04/27/05 1 1 13 .23 7 03/26/05 1 1 13 ),18 07/09/04 1 1 iJ J.JCf 04/03/05 1 1 I > )....¡ l\ 01/21/04 1 1 i3:{'-if 03/20/05 1 1 II ,14.1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: :, .\ '~1 / Ç}.JIJ l '.. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 AnCh~rage, AK 971- 032838 ! ATTN. Beth ; Ú Received by: \ --Çl~' . All I OJJJvvrJ lß~ \ _. -- .- ,~"...~ "~.¡~~'-,.~._-~-^- .f ---.'f'"~· 12.~3<¡ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: .L,-ùLin D~l1 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 19, 2004 RE: MWD Formation Evaluation Logs 05-41A, AK-MW-2860046 1 LDWG formatted Disc with verification listing. API#: 50-029-22696-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun 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 9f ff RECEIVED SEP 0 2) 2004 Alaska Oil & Gas Cons. Cot1\mÌ$Ùin Anchorage · STATE OF ALASKA ALASK AND GAS CONSERVATION COM.ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ISI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25,105 20AAC 25,110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2291' NSL, 4103' WEL, SEC. 32, T11 N, R15E, UM Top of Productive Horizon: 1017' SNL, 337' WEL, SEC. 06, T10N, R15E, UM Total Depth: 1345' SNL, 194' WEL, SEC. 06, T10N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 698262 y- 5948485 Zone- ASP4 TPI: x- 696847 y- 5945139 Zone- ASP4 Total Depth: x- 697000 y- 5944814 Zone- ASP4 18. Directional Survey ISI Yes 0 No 21. Logs Run: SGRC Combined GR & EWR, MGR I CCL / CNL One Other 5. Date Comp., Susp., or Aband. 1/23/2004 6. Date Spudded 1/15/2004 7. Date TD. Reached 1/20/2004 8. KB Elevation (ft): 72.43' 9. Plug Back Depth (MD+ TVD) 11918 + 9049 10. Total Depth (MD+TVD) 11956 + 9049 11. Depth where SSSV set (Nipple) 2168' MD 19. Water depth, if offshore N/A MSL Unique Completion (New - See Diagram) 1b. Well Class: ISI Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-170 13. API Number 50- 029-22696-01-00 14. Well Name and Number: PBU 05-41A 15. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028329 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CASING SIZE 20" 9-5/8" GRADE H-40 L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE Top BOTTOM Top BOTTOM SIZE CEMENTING RECORD Surface 110' Surface 110' 30" 260 sx Arctic Set (Approx.) 35' 3767' 35' 3569' 12-1/4" 2034 sx PF 'E', 337 sx Class 'G' 33' 9986' 33' 9051' 8-1/2" 289 sx Class 'G' 9864' 10002' 9032' 9052' 6" Uncemented Slotted Liner 9348' 11956' 8667' 9049' 4-1/8" x 3-3/4" 145 sx Class 'G' 22. WT. PER FT. 91.5# 40# 26# I 29# 12.6# 9,3# 1 6.2# 1 6.16# 7" 4-1/2" 3-1/2" x 3":3/16" x 2-7/8" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 6 spf MD TVD MD TVD 10270' - 10800' 9057' - 9058' 11335' - 11430' 9048' - 9048' 11500' - 11910' 9044' - 9049' 26. Date First Production: February 14,2004 Date of Test Hours Tested 2/24/2004 6.2 Flow Tubing Casing Pressure Press. 329 27. 24. SIZE 4-1/2", 12.6#, L-80 AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 9417' PACKER SET (MD) 9360' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MO) 2500' AMOUNT & KIND OF MATERIAL USED Freeze Protected with MeOH PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL-BBL GAs-McF WATER-BBL PRODUCTION FOR TEST PERIOD ... CALCULATED ......... 24-HoUR RATE""" OIL-BBL 2,447 GAs-McF 28,810 WATER-BBL 1,151.4 CHOKE SIZE I GAS-OIL RATIO 40° 11,775 OIL GRAVITy-API (CORR) CORE DATA . ..'., ", Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach sêp'afatesl'iéet"'if\l1eces~aty). Submit core chips; if none, state "none". None r;~c·'~:; :;7",,,":: It, "¡",.' \ ", \ ".", :' .- --":", > "~::;: '.:' : þfJAlð ,t,.' . ,~~ ¡ I/,"'-"h"". t \it2?.i2:' , 1 t:::~k::::l 12/2003 RBl>MS 8ft MAR 0 Form 10-407 Revised cOleR ~8¡.NAL· i~:_: 6. 10~~ (g~ r:;, 28. GEOLOGIC MARKER_ - 29. ..JRMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary_ If no tests were conducted, state "None". Zone 2A 11580' 9045' None ÇEB"fJ 6 J. /'1 30. List of Attachments: Summary of Daily Drilling Reports, Well Diagram Schematic, Surveys 31. I hereby certify that the fO/Oi~9 is true and correct to the best of my knowledge. Signed Terrie HUbbl~.A1\.<1. ~ Title Technical Assistant Date O;;z· ~·OL( PBU 05-41A 203-170 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Thomas McCarty, 564-4378 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ORIGINAL . . Page 1 of 12 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-41 05-41 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To . Hours ¡Task · Code NPT Phase 1/9/2004 06:00 - 00:00 18.00 MOB WAIT PRE N 0.00 N COMP 1/10/2004 00:00 - 06:00 6.00 MOB N WAIT PRE 06:00 - 07:00 1.00 MOB P PRE 07:00 - 23:30 16.50 MOB N WAIT PRE 23:30 - 00:00 0.50 MOB P PRE 1/11/2004 00:00 - 00:15 0.25 MOB P PRE 00:15-01:00 0.75 MOB P PRE 01 :00 - 01: 15 0.25 MOB P PRE 01:15-04:00 2.75 MOB P PRE 04:00 - 04: 15 0.25 MOB P PRE 04:15 -11:30 7.25 MOB P PRE 11 :30 - 00:00 12.50 MOB N WAIT PRE 1/12/2004 00:00 - 15:00 15.00 MOB N WAIT PRE 15:00 - 15:45 0.75 MOB N WAIT PRE 15:45 - 16:00 0.25 MOB P PRE 16:00 - 18:30 2.50 MOB P PRE 18:30 - 18:45 0.25 MOB P PRE 18:45 - 22:00 3.25 MOB P PRE 22:00 - 22:15 0.25 MOB P PRE 22:15 - 23:00 0.75 MOB P PRE 23:00 - 00:00 1.00 RIGU P PRE 1/13/2004 00:00 - 01 :30 1.50 RIGU P PRE 01 :30 - 07:00 5.50 BOPSUR P PRE Start: Rig Release: Rig Number: Spud Date: 8/28/1996 End: 1/12/2004 1/23/2004 N1 Description of Operations WOW Phase 1-2, Winds 20 gusting 35 mph. In excess of our maximum allowable for laying down the wind walls. Stand by on winds. The rig is currently located over well 15-33B. Phase 2 at 2200 hrs, Wind at 25-45 mph. WOW for derrick down rig move to 05-41A. Phase 2, 25-45 mph wind. Blowing snow. Fire and rig evacuation drill. Table top discussion to review scenario's and procedures for handling response. Continue to wait on weather. Winds at 07:00 are 27 gusting 42 mph. Went off WOW Standby at 23:30 hrs. Wind at 5-15 mph. Prepare to move rig off well. SAFETY MEETING. Review procedure, hazards and mitigation to move rig off of well DS 15-33B. Move rig forward off well. No problems. SAFETY MEETING. Review procedure, hazards and mitigation to lower wind walls and derrick. Lower wind walls and derrick. OK. SAFETY MEETING. Review procedure, hazards and mitigation for rig move to DS 5 with security, tool service, Nordic, SWS, BP and CPS. Move rig to DS 5. Arrive on location on DS 5. Spot rig in front of well DS 5-41. Current winds are 15 mph, gusting to 28 mph. This is above the maximum acceptable for Nordic 1. Wait on weather until the winds moderate. Wind at 20-35 mph at 0000 hrs. WOW. Rig in front of well with windwalls and mast down. Wind at 20-30 mph at 0100 and 15-30 mph at 0600. AT 15:00 winds have dropped to within exceptable limits to raise the wind walls. Monitor the winds for 1 additional hour to ensure that they remain within tolerances. Hold PJSM prior to raising derrick and wind walls. Discuss hazards and mitigation of raising derrick, wind walls, use of man rider winch. Winds are 11 mph, gusting to 17 mph. Less than our maximum allowable of 20 mph. Begin raising derrick and wind walls. Held PJSM for picking up injecter and M/U guice arch. Review procedure, hazards and their mitigation. Pick up injecter and M/U Guide arch. Stab CT into injecter and set injecter to side of rig floor. SAFETY MEETING. Review procedure, hazards and mitigation for moving rig over well. Back rig and center it over tree. ACCEPT RIG ON 05-41A AT 2300 HRS, 01/12/2004. General rig up, spot trailers, spot tanks, RIO hardline. N/U BOP STACK. Perform initial BOPE Pressue and Function testing. Send test report to AOGCC. Load 2-3/8" liner in pipe shed, drift and tally liner. Printed: 112612004 10:32:15 AM .... . Page 2 of 12 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-41 05-41 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours , , Task; Code NPT. Phase ______' .. _ ......_u_... ..n......._..__..._.._. 1/13/2004 5.50 BOPSURP 2.00 WHIP P 1.50 WHIP P PRE WEXIT WEXIT 01 :30 - 07:00 07:00 - 09:00 09:00 - 10:30 10:30 - 12:00 1.50 WHIP P WEXIT 12:00 - 12:15 0.25 WHIP P WEXIT 12:15 - 13:15 1.00 WHIP P WEXIT 13:15 - 13:30 0.25 WHIP P WEXIT 13:30 - 16:00 2.50 WHIP P WEXIT 16:00 - 16:20 0.33 WHIP P WEXIT 16:20 - 16:50 0.50 WHIP P WEXIT 16:50 - 18:45 1.92 WHIP P WEXIT 18:45 - 19:00 0.25 WHIP P WEXIT 19:00 - 20:00 1.00 WHIP P WEXIT 20:00 - 21 :45 1.75 WHIP P WEXIT Start: Rig Release: Rig Number: Spud Date: 8/28/1996 End: 1/12/2004 1/23/2004 N1 Description of Operations ...... --- ------- ______.___...._ ...____..0.... Load 290 bbls 2% KCL water in rig pits. Cut coil, change packoffs, MU WF CTC. Pull test to 35 klbs. Pump 5 bbls of KCL into empty coil. SI hard line, PT hardline to reel. Launch dart. Pump dart to catcher sub. Landed at 57.2 bbls. Retrieve dart. Pressure test inner reel valve and CTC to 3500 psi. Blow back 3 bbls from CTC with rig air system to FP coil. Line up down the kill line with both pumps. Come on line with 300 bbls of KCL from Vac truck to Kill well. Pumping at 5 bpm, 250 psi. SI pumps. Well on vac. Hold PJSM about running 2-3/8" tail pipe below WF 4-1/2" packer whipstock anchor. MU 20 joints of 2-3/8" STL tubing with 2' ported guide shoe, and first 2 joints ported at 4 holes per ft. Upper 18 joints are solid liner. Make up remainder of BHA, WF packer and setting tool, Sperry ESS, SWS MGR-CCL, MHA, NRJ to CTC. BHA total length = 649.86'. RIH with BHA #1, tail pipe, whipstock anchor, and logging tools. WF 4.5" Anchor does not have seals, to allow by-pass area for squeeze cementing past anchor. Anchor = 3.563" OD, inside 3.958" ID liner. RIH slick to 10,000'. Stop at 10,000' end of BHA depth. Log down with MGRlCCL at 60 FPM. Stop with shoe at 10,636 ft CTD. Top of WF Anchor at 10,030' CTD. No tie-in. Depth is based on CT measure with a typical -20 ft CTO at 10,000' adjustment. Up WT = 46K. Insert 5/8" AL ball to shift Divert sub. Displace ball with KCL water at 2.6 bpm, no returns. Ball on seat at 52.4 bbls. Packer set and sheared at 3950 psi. Pick up free with 44K up wt. Left liner and packer in hole. Top of 4.5" WF Anchor at 10,030' CTD. 2-3/8" shoe at 10,636' CTD. Log up off Anchor at 30 FPM with MGRlCCL. Flag CT at 9800' EOB. Log up to 9500' CTD. POH. Circ at 1 bpm with no returns. OOH. Setback injector. Held PJSM for securing well & LID BHA#1. Observe well - still on vac. Pull out BHA & close swab. LID BHA & load out SWS MGRlCCL flow thru carrier, Sperry ESS tool & WF Fury setting tool. Cap well. Observe lug orientation @ 91 L TF from Sperry memory ESS tool. Download MGRlCCL data - observed lots of noise on log. Top ofWS-R-BB Latch was located @ 10027.67' & possible 4-1/2" collars located @ 9967' & 9979'. Added 8.02' spacer to WS to position TOW - BOW @ 10009' - 10018'. (Note that next corresponding 4-1/2" collars will be +40' @ 10007' & 10019'). WF align WS tray & WS-R-BB latch for a 30deg LOHS orientation. Printed: 1/26/2004 10:32:15 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: --.-.......-..- 1/13/2004 1/14/2004 . . Page 3 of 12 BP Operations Summary Report Start: Rig Release: Rig Number: Task! Code NPT I Phase I 05-41 05-41 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date , I From - To ! Hours 21 :45 - 22:35 22:35 - 00:00 00:00-01:15 01: 15 - 01 :25 01 :25 - 03:45 03:45 - 04:00 04:00 - 04:35 04:35 - 07:00 07:00 - 09:00 09:00 - 09:45 09:45 - 10:00 10:00-11:00 11 :00 - 14:00 14:00 - 14:40 14:40 - 14:50 14:50 - 15:30 15:30 - 17:20 17:20 - 17:50 17:50 - 18:30 0.83 WHIP P 1.42 WHIP P 1.25 WHIP P 0.17 WHIP P 2.33 WHIP P 0.25 WHIP P 0.58 ZONISO P 2.42 ZONISO P 2.00 ZONISO P 0.75 ZONISO P 0.25 ZONISO P 1.00 ZONISO P 3.00 ZONISO P 0.67 ZONISO P 0.17 STWHIP P 0.67 STWHIP P 1.83 STWHIP P 0.50 STWHIP P 0.67 STWHIP N 1/12/2004 1/23/2004 N1 Spud Date: 8/28/1996 End: Description of Operations WEXIT PJSM. Load in whipstock & running tools to rig floor. Install 3 RA PIP tags in WS. M/U WF WS running BHA#2 with WS-R-BB latch (pinned to 18k#), WS tray, running tool (pinned to 11.6k#), XO, swivel, disconnect, Dailey jars, dual checks, NRJ & CTC. M/U injector. WEXIT RIH with WS running BHA#2 @ 70fph circ @ min rate. WEXIT Continue RIH with WS running BHA#2 @ 70fph circ @ min rate. Correct 24.4' @ the flag. Up wt checks @ 9838', 9928', 9978' & 10002' - 47k & run-in wt - 29k. WEXIT Gently tag WS-R-BB packer with 5fpm @ 10028' & set down 2k to 10030.4'. P/U to 46.6k to 10023'. Retag with 15fpm & set down 6k to 10030.5'. P/U to 46.6k to 10021'. Retag with 20fpm & set down 8k to 10032.6'. P/U with 4k O/pull & confirm latchup into packer. Continue pulling to 59k & shear running tool off WS. TOWS @ 10009.08' & 30degs LOHS. WEXIT POOH with WS running tool. WEXIT OOH. Setback injector. PJSM. LID BHA & load out WF running tool. Well still on vac - call for 100bbls of diesel for cement job. WEXIT M/U slick cementing BHA with nozzle, PH6 stinger XIover to circ sub & disconnect. M/U injector. WEXIT RIH with cementing BHA#3. Tag top of whipstock at 10027' and correct depth -18' to 10,009'. Pick up and flag CT 10' above whipstock. WEXIT Load well with 100 bbls of diesel to reduce fluid gradiant for cement squeeze job. Pump 100 bbls diesel down backside of coil. 2.1 bpm, 500 psi. WEXIT Rig up SWS cement equipment. WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for pumping 5 bbl cement squeeze. WEXIT PT cement line. Stage 5 bbl water ahead of cement. Stage 5.3 bbl, 15.8 ppg G cement. Stage 5 bbl water. Displace with 30 bbl Biozan and KCL water, Choke is closed. bullhead at 2.4 bpm, 1000 psi, 890 WHP. Slow to 1 bpm with cement at nozzle. Squeeze cement at 1 bpm, 120 psi, 740 WHP. Pull CT at 5 fpm while pumping away 5.3 bbls Cement. Top of Cement in 4.5" liner at 9980 ft. WEXIT POH. Pump 5.5 bbl per 1000 ft to replace CT voidage. WHP = 540 psi at start and 20 psi at surface. WEXIT Wait on cement. SWS UCA sample at 500 psi at 1440 hrs. WEXIT SAFETY MEETING. Review procedure, hazards and mitigation to M/U milling BHA. WEXIT M/U 3.80" window milling BHA with 3.80" HC diamond window mill, 3.79" diamond reamer, WF motor, MHA, 2 jts PH6 and CTC. BHA = 83.25 ft. WEXIT RIH with BHA # 4. 3.80" window milling BHA. 0.3 BPM, Full returns while RIH. First motor work at 9990 ft. 2.4 bpm, 1.6 bpm returns. First stall at 10,010 ft. Mill firm cement to 10,021 ft. Stall2 times at 10,021 ft. Top of whipstock. Correct CTD to 10,009 ft[-12 ft]. WEXIT Mill window from 10,009 - 10,009.2 ft. 2.4/1.3 bpm, WAIT WEXIT Running low on fluid. Circ diesel to tiger tank at reduced rate, while waiting for vac truck to arive with Biozan water. Printed: 1/26/2004 10:32:15 AM . . Page 4 of 12 BP Operations Summary Report Milled window from 10009.2' to 10010' with 2.5/1.6bpm, 1890/1940psi, 1k WOB & 1.4fph ave ROP. Milled to 10011' with 2.5/1.9bpm, 1950psi, 2-3k WOB & 0.7fph ave ROP. Milled to 10012' with 2.5/2.2bpm, 2080psi, 2-3k WOB & 0.9fph ave ROP. Milled to 10013' with 2.5/2.2bpm, 2200psi, 2-3k WOB & 1.5fph ave ROP. Getting metal shavings on magnets. Milled to 10013.7' with 2.5/2.2bpm, 2100psi, 2-3k WOB & 1.5fph ave ROP. Stall. P/U clean @ 43k. Establish freespin of 1675psi @ 2.5bpm. RBIH & ease back into milling & stall again. Ease back from 10013.6' & mill thru to 10014'. Exit liner into formation @ 10013.8'. WEXIT Mill 10' formation from 10014' to 10024' with 2.5/2.3bpm, 1685psi, 1-2k WOB & 15fph ave ROP. Tentative window depths are: TOWSITOW = 10009'; BOW = 10014', RA PIP Tag = 10011.3'. Backream/ream window/rat hole & make several dress/drift passes with & without pumping. Window looks clean. Meanwhile W.O flopro mud from MI plant. Swap wellbore to 8.6 ppg reconditioned flopro mud. Recovered good amount of metal shavings on magnets. Paint EOP flag @ 9800' & POOH window milling BHA#4. PJSM. LID BHA #4 & inspect mills. Window mill gauge 3.80" go /3.79" no-go & string mill gauge 3.79" go /3.78" no go. Wear on window mill face indicated center crossed the liner wall. M/U SWS CTC. Pull test and pressure test. PRE-SPUD SAFETY MEETING. Review well plan and possible hazards with personnel. Review procedure, hazards and mitigation for M/U of MWD Resistivity BHA. M/U HYC DS100 3.75 x 4.25" Bi-center bit, 2.57 deg motor and Resistivity BHA. Total length = 90.58 ft. Test Resistivity tool. RIH with MWD Res BHA #5. Shallow test tools and orienter. OK. RIH. Correct to flag at 9891 ft. [-24 ft). Check tool face, 30L. Went thru window clean with no weight loss. Start drilling in Zone 1 at 10,024'. 2.5/2.4 bpm, 3400 - 4000 psi, 40L, Drill to 10,034'. Orient TF to 90L. Drilling Zone 1, 2.5/2.4 bpm, 3400 - 3900 psi, 100L, 50 FPH, Drilled to 10,068'. Orient TF to 11 OL. Drilling Zone 1, 2.6/2.6 bpm, 3400 - 4000 psi, 120L, 50 FPH, Drilled to 10,110'. Drilling Zone 1, 2.6/2.6 bpm, 3400 - 4000 psi, 60L, 50 FPH, Drilled to 10,165'. Wiper trip to window. Clean hole. Log GR tie-in with RA tag at 10,011 ft. Pull up and tie-in with GR to BHCS/GR at 9807'. Made 2 logging passes to get valid tie-in. Shift RA Depth -7 ft to 10,004'. Top of window at 10,002 ft. Bottom of window at 10,007 ft. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-41 05-41 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 I Date From - To Hours Task ¡Code NPT Phase _________n___... 1/14/2004 18:30 - 19:05 0.58 STWHIP P WEXIT 19:05 - 20:30 1.42 STWHIP P WEXIT 20:30 - 21 :35 1.08 STWHIP P WEXIT 21:35-22:15 0.67 STWHIP P WEXIT 22:15 - 23:15 1.00 STWHIP P WEXIT 23: 15 - 00:00 0.75 STWHIP P 1/15/2004 00:00 - 02:00 2.00 STWHIP P WEXIT 02:00 - 03:00 1.00 STWHIP P WEXIT 03:00 - 05:30 2.50 STWHIP P WEXIT 05:30 - 06:00 0.50 STWHIP P WEXIT 06:00 - 06:45 0.75 DRILL P PROD1 06:45 - 07:15 0.50 DRILL P PROD1 07:15 - 08:30 1.25 DRILL P PROD1 08:30 - 10:40 2.17 DRILL P PROD1 10:40 - 11 :30 0.83 DRILL P PROD1 11 :30 - 11 :45 0.25 DRILL P PROD1 11 :45 - 12:20 0.58 DRILL P PROD1 12:20 - 12:45 0.42 DRILL P PROD1 12:45 - 14:00 1.25 DRILL P PROD1 14:00 - 15:40 1.67 DRILL P PROD1 15:40 - 16:00 0.33 DRILL P PROD1 16:00 - 18:00 2.00 DRILL P PROD1 Start: Rig Release: Rig Number: Spud Date: 8/28/1996 End: 1/12/2004 1/23/2004 N1 Description of Operations ._ - ___n_.__.___.__.__.__. --... ....-.--.--..----.--.--.--- Printed: 1/26/2004 10:32:15 AM . . BP Page 5 of 12 Operations Summary Report Legal Well Name: 05-41 Common Well Name: 05-41 Spud Date: 8/28/1996 Event Name: REENTER+COMPLETE Start: 1/12/2004 End: Contractor Name: NORDIC CALISTA Rig Release: 1/23/2004 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours' Task !code NPT I I Description of Operations Phase I I .... ___ _.......1___ 1/15/2004 18:00 - 18:30 0.50 DRILL P PROD1 PUH & orient TF to 120L. 18:30 - 19:00 0.50 DRILL P PROD1 Orient & drill to 10178' with 110-130L TF, 2.6/2.6bpm, 3530/3710psi, 45fph ave ROP. TVD @ 8983'. Geo requests drop in anglelTVD. 19:00 -19:10 0.17 DRILL P PROD1 PUH & orient TF to 90L. RBIH. 19:10 - 19:40 0.50 DRILL P PROD1 Drill to 10200' with 105L TF, 2.6/2.6bpm, 3530/3780psi, 40fph ave ROP. 19:40 - 19:55 0.25 DRILL P PROD1 PUH & orient TF to 50L. RBIH. 19:55 - 20:15 0.33 DRILL P PROD1 Drill to 10208' with 55L TF, 2.6/2.6bpm, 3430/3770psi, 25fph ave ROP. 20:15 - 20:25 0.17 DRILL P PROD1 PUH & orient TF to 15L. RBIH. 20:25 - 20:55 0.50 DRILL P PROD1 Drill to 10231' with 15L TF, 2.6/2.6bpm, 3530/3730psi, 45fph ave ROP. 20:55 - 21 :45 0.83 DRILL P PROD1 Drill & land section @ 10260' with 85-90L TF, 2.6/2.6bpm, 3530/3740psi, 40fph ave ROP. TVD @ 8985'. Observed no HOT in samples. 21:45 - 23:30 1.75 DRILL P PROD1 Paint EOP flag @ 9800' & POOH for lateral BHA. 23:30 - 00:00 0.50 DRILL P PROD1 OOH. PJSM. Set back injector. LIO bit - 1/1/1. Reset motor bend to 1.04degs. M/U new HYC 3-3/4" DS49 bit & scribe BHA. 1/16/2004 00:00 - 01:1 0 1.17 DRILL P PROD1 Download & initialize EWR tool. M/U MHA & P/U injector. 01:10-03:00 1.83 DRILL P PROD1 RIH with BHA #6. SHT - OK. RIH. Subtract 26' from CTD @ the flag. Continue RIH clean thru window. Tag TD @ 10261'- correct CTD to 10260'. 03:00 - 03:25 0.42 DRILL P PROD1 Orient TF to 90L. 03:25 - 04:30 1.08 DRILL P PROD1 Orient & drill to 10308' with 95-110L TF, 2.6/2.6bpm, 3500/3750psi, 50fph ave ROP. 04:30 - 04:35 0.08 DRILL P PROD1 Orient TF to 80L. PVT = 220bbls; lAP = 360psi; OAP = 54psi. 04:35 - 05:15 0.67 DRILL P PROD1 Drill to 10343' with 80L TF, 2.6/2.6bpm, 3500/3800psi, 50fph ave ROP. Still no HOT in samples. 05: 15 - 05:30 0.25 DRILL P PROD1 Orient 1 click & drill to 10352' with 75L TF, 2.6/2.6bpm, 3500/3800psi, 55fph ave ROP. 05:30 - 05:45 0.25 DRILL P PROD1 Orient 1 click & drill to 10359' with 65L TF, 2.6/2.6bpm, 3500/3750psi, 45fph ave ROP. 05:45 - 06:15 0.50 DRILL P PROD1 Orient 2 clicks & drill to 10381' with 50L TF, 2.6/2.6bpm, 3500/3750psi, 70fph ave ROP. 06: 15 - 07:20 1.08 DRILL P PROD1 Drilling Z1 lateral. 2.5/2.5 bpm, 3500 - 4000 psi, 90L, 70 fph, 90.5 deg. Drilled to 10,410'. 07:20 - 07:50 0.50 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 07:50 - 08:30 0.67 DRILL P PROD1 Drilling Z1, 2.5/2.5 bpm, 3500 - 4000 psi, 90L, 100 fph, 91.5 deg, Drilled to 10,473'. 08:30 - 09:15 0.75 DRILL P PROD1 Orient TF to 100L. Getting 10 deg clicks. 09:15 - 10:20 1.08 DRILL P PROD1 Drilling Z1, 2.5/2.5 bpm, 3500 - 4000 psi, 100L, 100 fph, 89 deg, Drilled to 10,560'. 10:20 - 11 :00 0.67 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 11 :00 - 11 :50 0.83 DRILL P PROD1 Drilling Z1, 2.5/2.5 bpm, 3500 - 4000 psi, 80L, 100 fph, 91.5 deg, Drilled to 10,644'. 11 :50 - 12:50 1.00 DRILL P PROD1 Orient TF to 100L. Getting 10 deg clicks. 12:50 - 13:45 0.92 DRILL P PROD1 Drilling Z1, 2.5/2.5 bpm, 3500 - 4000 psi, 100L, 60 fph, 88 deg, Drilled to 10,710'. 13:45 - 14:45 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. Wiper up to 9600'. RIH to TO. 14:45-16:15 1.50 DRILL P PROD1 Drilling Z1, 2.5/2.5 bpm, 3600 - 4000 psi, 60L, 70 fph, 88 Printed: 1/26/2004 10:32: 15 AM ..... . Page 6 of 12 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-41 05-41 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours ' Task Code NPT: Phase I --- -----..---.-.. 1/16/2004 14:45 - 16:15 1.50 DRILL P PROD1 16:15 -16:40 0.42 DRILL P PROD1 16:40 - 17:00 0.33 DRILL P PROD1 17:00 - 18:50 1.83 DRILL P PROD1 18:50 -19:10 0.33 DRILL P PROD1 19:10 -19:25 0.25 DRILL P PROD1 19:25 - 19:50 0.42 DRILL P PROD1 19:50 - 20:15 0.42 DRILL P PROD1 20: 15 - 20:20 0.08 DRILL P PROD1 20:20 - 21 :45 1.42 DRILL P PROD1 21 :45 - 22:15 0.50 DRILL P PROD1 22:15 - 22:50 0.58 DRILL P PROD1 22:50 - 23:00 0.17 DRILL P PROD1 23:00 - 23:25 0.42 DRILL P PROD1 23:25 - 23:40 0.25 DRILL P PROD1 23:40 - 00:00 0.33 DRILL P PROD1 1/17/2004 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 01 :25 0.42 DRILL P PROD1 01 :25 - 01:40 0.25 DRILL P PROD1 01:40-02:15 0.58 DRILL P PROD1 02:15 - 02:55 0.67 DRILL P PROD1 02:55 - 03:20 0.42 DRILL P PROD1 03:20 - 04:00 0.67 DRILL P PROD1 04:00 - 04:25 0.42 DRILL P PROD1 04:25 - 04:40 0.25 DRILL P PROD1 04:40 - 06:00 1.33 DRILL P PROD1 06:00 - 07:40 1.67 DRILL P PROD1 07:40 - 09:40 2.00 DRILL P PROD1 Start: 1/12/2004 Rig Release: 1/23/2004 Rig Number: N1 Spud Date: 8/28/1996 End: Description of Operations .-----..-- deg, Drilled to 10,790'. Drilling Z1, 2.5/2.5 bpm, 3600 - 4000 psi, 20L, 80 fph, 90 deg, Drilled to 10,810'. Orient TF to 80L. Getting 10 deg clicks. Lost power to Sperry shack. Wiper trip to window. Clean hole. Wiper trip up to 9600' in 4-1/2" liner. RIH clean to TD. Meanwhile fix power to Sperry shack. However lost connection to Ops cab Sperry monitors. DD relocate to Sperry Shack until connection to Ops cab monitors was fixed. Orient TF to 70L. Drill to 10818' with 50L TF, 2.6/2.6bpm, 3800/4100psi, 50fph ave ROP. Orient TF around to 120L. Drill to 10828' with 120L TF, 2.6/2.6bpm, 3800/4100psi, 40fph ave ROP. Orient TF around to 90L. Orient & drill to 10864' with 85L TF, 2.6/2.6bpm, 3650/3900psi, 45fph ave ROP. Swap well to new 8.6ppg Flopro mud with 3% L-T & 12 ppb Kla-Gard. Orient & drill to 10883' with 85L TF, 2.6/2.6bpm, 3300/3600psi, 40fph ave ROP. Orient & drill to 10901' with 50-35L TF, 2.8/2.8bpm, 3200/3550psi, 45fph ave ROP. Stacking wt. Short 100' wiper. Drill to 10912' with 55L TF, 2.9/2.9bpm, 3200/3550psi, 40fph ave ROP. Phase-1 driving conditions declared in GPB. Orient TF around to 70R. Drill to 10928' with 55R TF, 2.9/2.96bpm, 3200/3550psi, 40fph ave ROP. Orient & drill to 10965' with 70-85R TF, 2.9/2.9bpm, 3300/3750psi, 55fph ave ROP. Orient & drill to 10980' with 90-100R TF, 3.0/3.0bpm, 3330/3750psi, 55fph ave ROP. Orient & drill to 10990' with 110R TF, 3.0/3.0bpm, 3330/3650psi, 60fph ave ROP. Wiper trip clean to window. Log GR & tie-into RA PIP tag. Subtract 20' from CTD. RBIH clean to btm & tag TO @ 10971'. Orient & drill to 11010' with 110-120R TF, 3.0/3.0bpm, 3300/3650psi, 80fph ave ROP. Observe resistivity shift @ 10970' but no clear signs of fault crossing. Orient TF around to 75R Drill to 11023' with 60-75R TF, 3.0/3.0bpm, 3280/3550psi, 75fph ave ROP. Orient & drill to 11060' with 90R TF, 3.1/3.1 bpm, 3350/3850psi, 45fph ave ROP. Drilling Z1, 2.9/2.9 bpm, 3400 - 4000 psi, 90R, 91 deg, 80 fph, Drilled to 11,150'. Wiper trip clean to window. Had 15K overpull at window. Worked thru it and did wiper trip up to 9600 ft. RIH. Clean going back thru window. RIH, reamed shales from 10830-10900 ft. RIH to TD. Printed: 1/26/2004 10:32:15 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ~ . Page 7 of 12 BP Operations Summary Report 05-41 05-41 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task I Code NPT Phase 1/17/2004 09:40 - 10:00 10:00 - 11 :40 11:40 - 12:40 12:40 - 14:00 14:00 - 15:00 15:00 - 17:30 17:30 -19:15 19:15 -19:30 19:30 - 19:45 19:45 - 20:45 20:45-21:15 21:15 -21:30 21 :30 - 22:45 1/18/2004 22:45 - 00:00 00:00 - 00:50 00:50 - 01 :00 01:00-01:10 01:10-02:00 02:00 - 02:05 02:05 - 02:50 02:50 - 03:00 03:00 - 04:00 04:00 - 05:30 05:30 - 05:50 05:50 - 06:15 06: 15 - 06:25 06:25 - 07:20 07:20 - 08:10 08:10 - 08:35 08:35 - 09:30 09:30 - 11 :00 0.33 DRILL P 1.67 DRILL P 1.00 DRILL P 1.33 DRILL P 1.00 DRILL P 2.50 DRILL N 1.75 DRILL N 0.25 DRILL P 0.25 DRILL P 1.00 DRILL P 0.50 DRILL P 0.25 DRILL P 1.25 DRILL N 1.25 DRILL N 0.83 DRILL N 0.17 DRILL N 0.17 DRILL N 0.83 DRILL N 0.08 DRILL N 0.75 DRILL N 0.17 DRILL P 1.00 DRILL P 1.50 DRILL P 0.33 DRILL P 0.42 DRILL P 0.17 DRILL P 0.92 DRILL P 0.83 DRILL P 0.42 DRILL P 0.92 DRILL P 1.50 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: Rig Release: Rig Number: Spud Date: 8/28/1996 End: 1/12/2004 1/23/2004 N1 Description of Operations Orient TF to 80L. Drilling Z1, 2.9/2.9 bpm, 3400 - 4000 psi, 80L, 90 deg, 80 fph, Drilled to 11,220'. Drilling Z1, 2.9/2.9 bpm, 3400 - 4000 psi, 40L, 92 deg, 80 fph, Drilled to 11,250'. Orient TF to 90R. Trouble getting clicks. Unable to get clicks. Ream shales from 10830-10900 ft. Stacking wt when RIH at 1 0880 ft. POH for orienter failure. Circulate at 2.7 bpm out of the hole. Had extra cuttings and some window metal shavings when BHA got near surface. Layout BHA. Download RES data. Bit looks OK (1/2/1) - will be rerun. RIU hydraulic cutter to cut CT. Reverse circ 4bbls of water into coil. Held PJSM for cutting CT. Cut 600' of CT for fatigue management. Rehead & M/U new CTC. Pull/Press test. PJSM for M/U drilling BHA. M/U lateral section BHA #7 with new 1.37deg bend motor, orienter, MWD/RES & re-run Bit #4 [HYC DS49]. Scribe tools & initialize EWR tool. M/U injector. RIH with BHA #7. SHT - OK. Continue RIH BHA #7 clean thru window. Set down in shale @ 10900'. O/Pulled 15k. Backream shales from 10900' to 10800' with 2.5/2.5bpm, 2800psi & slight packing off. Orient TF to 90L. Ream/backream shales several times from 10800' to 11006' with 90-100L TF 2.8/2.8bpm & 3300psi. Orient TF to 90R. Backream/ream shales several times from 10800' to 11006' with 70-90R TF 2.9/2.9bpm & 3300psi . RIH clean & tag TD @ 10278' - correct CTD to 10250'. Orient & drill to 11264' with 100L TF, 2.8/2.8bpm, 3250/3450psi, 15fph ave ROP. Slow drilling. Orient & drill to 11286' with 90L TF, 2.8/2.8bpm, 3250/3450psi, 15fph ave ROP. Orient around to 130L. Continue drilling from 11286' with 130L TF, 2.8/2.8bpm, 3150/3350psi. Drilled to 11 ,292'. Orient TF to 100L. DrillingZ1, 2.7/2.7bpm, 3200-3900 psi, 100L, 93deg, Drilled to 11307'. Stacking wt. Coil not sliding. Wiper trip up to window. Shales in medium condition. 2 overpulls and motor work. Rest of hole was good. Log GR tie-in with RA tag at 10,004'. -19 ft CTD correction. Wiper up thru window to 9720', RIH. Went thru shales at 10900' with no motor work or wt loss. RIH clean to TD. Tag TO at 11,291 ft. Drilling Z1, 2.5/2.5 bpm, 2900 - 3700 psi, 80L, 90 deg, Printed: 1/26/2004 10:32:15 AM , ..... . BP Operations Summary Report Page 8 of 12 Legal Well Name: 05-41 Common Well Name: 05-41 Spud Date: 8/28/1996 Event Name: REENTER+COMPLETE Start: 1/12/2004 End: Contractor Name: NORDIC CALISTA Rig Release: 1/23/2004 Rig Name: NORDIC 1 Rig Number: N1 Date I Hours Task Code NPT I Phase Description of Operations I From - To I -------.--..---.-- -. 1/18/2004 09:30 - 11 :00 1.50 DRILL P PROD1 Stacking weight, added 1% Lubetex to FloPro. Drilled to 11,332 ft. 11 :00 - 12:30 1.50 DRILL P PROD1 Drilling Z1, 2.5/2.5 bpm, 2900 - 3700 psi, 80L, 90 dég, Stacking weight, Drilled to 11,390 ft. 12:30 - 12:50 0.33 DRILL P PROD1 Orient TF to 80R. 12:50 - 13:15 0.42 DRILL P PROD1 Drilling Z1, 2.8/2.8 bpm, 3370 - 4000 psi, 80L, 90 deg, Stacking weight, Drilled to 11,390 ft. 13:15-14:20 1.08 DRILL P PROD1 Wiper trip to window. Hole was clean. RIH clean to TD. Shales were clean. 14:20 - 15:30 1.17 DRILL P PROD1 Drilling Z1, 2.8/2.8 bpm, 3370 - 4000 psi, 80R, 90 deg, Stacking weight, Drilled to 11,395 ft. Unable to drill any further. Stacking weight. Coil seems to be in lock up. Swap well over to new FloPro to get better weight transfer. 15:30 - 18:15 2.75 DRILL P PROD1 Drilling Z1. 2.7/2.7 bpm, 3100 - 3900 psi, 80R, 90 deg, Good weight transfer but very slow drilling, getting several stalls, drilling with 400 psi motor work and then stalls. Drilling break at 11406 ft. Suddenly drilling at 90 FPH. Drilled to 11,416'. 18:15 - 18:35 0.33 DRILL P PROD1 Drill to 11432' with 50R TF, 2.8/2.8bpm, 3250/3580psi, 125fph ave ROP. Orient 1 click & drill to a halt @ 11437'. 18:35 - 19:05 0.50 DRILL P PROD1 Short 100' wiper. 19:05 - 19:20 0.25 DRILL P PROD1 Orient & drill to 11451' with 90R TF, 2.8/2.8bpm, 3250/3580psi, 56fph ave ROP. 19:20 - 19:50 0.50 DRILL P PROD1 Orient & drill to 11480' with 11 OR TF, 2.8/2.8bpm, 3250/3530psi, 58fph ave ROP. 19:50 - 20:00 0.17 DRILL P PROD1 Orient TF to 90R. 20:00 - 20:15 0.25 DRILL P PROD1 Drill to 11493' with 1 05R TF, 2.8/2.8bpm, 3240/3520psi, 52fph ave ROP. 20:15 - 20:30 0.25 DRILL P PROD1 Orient TF around to 80R. 20:30 - 20:40 0.17 DRILL P PROD1 Orient 1 click & drill to 11497' with 50R TF, 2.8/2.8bpm, 3300/3510psi, 34fph ave ROP. Seem to be drilling thru the 14N shale or a shale stringer from 11450'. 20:40 - 21 :00 0.33 DRILL P PROD1 Drill to 11508' with 70R TF, 2.8/2.8bpm, 3300/3540psi, 6fph ave ROP. 21 :00 - 22:25 1.42 DRILL P PROD1 Wiper trip clean to the window while Geo consults with ANC on way forward. RBIH clean to btm. Geo wants to drill down below the shale holding 87degs. 22:25 - 22:55 0.50 DRILL P PROD1 Orient & drill to 11531' with 130R TF, 2.8/2.8bpm, 3340/3610psi, 49fph ave ROP. 22:55 - 23:40 0.75 DRILL P PROD1 Orient TF around to 50R to stop drop. Geo wants 8977sstvd max. 23:40 - 00:00 0.33 DRILL P PROD1 Drill to 11550' with 65R TF, 2.8/2.8bpm, 3250/3620psi, 60fph ave ROP. 1/19/2004 00:00 - 00:10 0.17 DRILL P PROD1 Continue drilling to 11561' with 65R TF, 2.8/2.8bpm, 3250/3690psi, 75fph ave ROP. 00:10 - 00:20 0.17 DRILL P PROD1 Orient 2 clicks & drill to 11593' with 115R TF, 2.8/2.8bpm, 3250/3700psi, 160fph ave ROP. 00:20 - 02: 15 1.92 DRILL P PROD1 Tag btm @ 60R TF & stall - TF flop. Orient again to 60R & tag - TF flog again with no stall. Reorient & observe TF flop again??? Will orient to drill anywhere on the HS. 02: 15 - 02:20 0.08 DRILL P PROD1 Reorient TF to 40L. 02:20 - 02:45 0.42 DRILL P PROD1 Drill to 11593' with 40L TF, 2.8/2.8bpm, 3375/3600psi, 15fph ave ROP. Printed: 1/26/2004 10:32:15 AM .... . BP Operations Summary Report Page 9 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/19/2004 1/20/2004 05-41 05-41 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Spud Date: 8/28/1996 End: Start: 1/12/2004 Rig Release: 1/23/2004 Rig Number: N1 From - To : Hours Task ·Codé NPT Phase Description of Operations .-----.------ -..-. 02:45 - 02:55 0.17 DRILL P PROD1 Orient & drill to 11598' with HS TF, 2.8/2.8bpm, 3370/3600psi, 25fph ave ROP. 02:55 - 03:10 0.25 DRILL P PROD1 Short 100' wiper. 03:10 - 03:15 0.08 DRILL P PROD1 Orient TF to 50R. 03:15 - 05:00 1.75 DRILL P PROD1 Orient & drill to 11645' with 50-70R TF, 2.8/2.8bpm, 3350/3600psi, 55fph ave ROP. 05:00 - 05:45 0.75 DRILL P PROD1 Orient & drill to 11661' with 95R TF, 2.8/2.8bpm, 3350/3600psi, 35fph ave ROP. 05:45 - 06:30 0.75 DRILL P PROD1 Wiper trip to window. Hole was clean. 06:30 - 07:30 1.00 DRILL P PROD1 Log GR Tie-in at RA tag at 10,004'. -23.5 FT CTD. 07:30 - 08:50 1.33 DRILL P PROD1 Wiper trip to 9700' inside 4-1/2" liner. RIH clean thru window. RIH clean to TD. 08:50 - 10:00 1.17 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3500 psi, 100R, 90 deg, Drilled to 11,677'. 10:00 - 10:20 0.33 DRILL P PROD1 Orient TF to 60R. 10:20 - 12:10 1.83 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3500 psi, 60R, 87 deg, Drilled to 11,735'. 12:10 - 13:30 1.33 DRILL P PROD1 Drilling, 2.4/2.4 bpm, 2900 - 3500 psi, 100R, 90 deg, Drilled to 11,795'. 13:30 - 15:00 1.50 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to TD. 15:00 - 16:00 1.00 DRILL N WAIT PROD1 Wait on orders. Geology deciding direction of final part of well. 16:00 - 17:30 1.50 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3000 - 3500 psi, 85R, 90 deg, Drilled to 11,860 Ft. 17:30 - 19:05 1.58 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3000 - 3500 psi, 95R, 90 deg, Drilled to 11,868 Ft. Stacking wt. & not making much progress. 19:05 - 19:40 0.58 DRILL P PROD1 Wipe 100' & orient TF to 90R. Finally gotta bite on formation with motor work. 19:40 - 20:40 1.00 DRILL P PROD1 Drill without much progress to 11873' with 75R TF, 2.8/2.8bpm, 3450/3700psi. Apply -ve wt with no drill off. 20:40 - 21 :40 1.00 DRILL P PROD1 Wiper trip clean to 9700'. RBIH to 10075'. 21 :40 - 22:00 0.33 DRILL P PROD1 Log-up GR & tie into RA PIP tag. Subtract 18' from CTD. 22:00 - 22:45 0.75 DRILL P PROD1 RBIH clean to btm & tag TD @ 11864'. 22:45 - 00:00 1.25 DRILL P PROD1 Orient & drill to 11883' with 90R TF, 2.8/2.8bpm, 3450/3600psi, 15fph ave ROP. 00:00 - 00:55 0.92 DRILL P PROD1 Grind on with patience & finally hit a drilling break @ 11893'. 00:55 - 01 :20 0.42 DRILL P PROD1 Drill to 11940' with 95R TF, 2.8/2.8bpm, 3700/3900psi, 120fph ave ROP. 01 :20 - 01 :50 0.50 DRILL P PROD1 Wipe 100' & orient TF to 80R. 01 :50 - 03:25 1.58 DRILL P PROD1 Grind on & break thru @ 11958'. 03:25 - 05: 1 0 1.75 DRILL P PROD1 Drill to 11977' with 90R TF, 2.8/2.8bpm, 3700/3900psi, 20fph ave ROP. Geo calls it TD. 05:10 - 06:00 0.83 DRILL P PROD1 Wiper trip clean to 10075'. 06:00 - 06:30 0.50 DRILL P PROD1 Log-up GR & tie into RA PIP tag. -17 ft CTD correction. 06:30 - 07:30 1.00 DRILL P PROD1 Wiper trip back to bottom. Shales were very clean. Clean trip to TD. Tag TD at 11,956'. 07:30 - 10:10 2.67 DRILL P PROD1 POH while laying in 100 bbl of new FloPro with 4% LT and 12 PPG KG. 2.4 bpm, 3170 psi, full returns. Flagged CT at 9300 ft and 7200 ft EOP. POH. Circ. at 2.8 bpm to surface. 10:10 - 12:00 1.83 DRILL P PROD1 LIO MWD - RES BHA. Download RES tool. Circ. dart to check coil volume while downloading RES data. Dart landed at 54.1 bbls. Calculated coil capacity = 54.4 bbls. 12:00 - 12:30 0.50 CASE P COMP Prep rig floor to run 2-7/8" liner 12:30 - 12:45 0.25 CASE P COMP SAFETY MEETING. Review procedure, hazards and Printed: 1/26/2004 10:32: 15 AM . . BP Operations Summary Report Page 10 of 12 Legal Well Name: 05-41 Common Well Name: 05-41 Spud Date: 8/28/1996 Event Name: REENTER+COMPLETE Start: 1/12/2004 End: Contractor Name: NORDIC CALISTA Rig Release: 1/23/2004 Rig Name: NORDIC 1 Rig Number: N1 Date nJ_~~~_~_~ To : Hours I Task : Code NPT: Phase Description of Operations ..--.-------.------.-----.---- 1/20/2004 12:30 - 12:45 0.25 CASE P COMP mitigation for running liner. 12:45 - 14:30 1.75 CASE P COMP M/U TIW float shoe, 1 jt 2-7/8" liner, TIW float cllr, BKR Latch cllr, XO and 56 jts of 2-7/8", FL4S liner. Stop and fill liner. 14:30 - 17:00 2.50 CASE P COMP M/U XO, 2-7/8" STL pup jts, LSL sub, 6 jts 3-3/16" TClllnrs, XO, 3-1/2" STL pup jt, 3-1/2" XN nipple with RA marker, 19 jts 3-1/2" STL Inrs, 3-1/2" X nipple, 3-1/2" STL pup jt & Baker deployment sleeve. M/U CTLRT & MHA. 17:00 - 17:15 0.25 CASE N RREP COMP SLB replace worn depth counter on injector. 17:15 -18:15 1.00 CASE P COMP Install Baker CTC. Pull test to 35k & pressure test to 3500 psi - OK. M/U injector. 18:15 - 20:20 2.08 CASE P COMP RIH with completion liner BHA #8. 20:20 - 21 :25 1.08 CASE P COMP Drop 5/8" phenalic ball. Pump ball down coil. Slow rate at 40 bbls pumped. Ball on seat at 51.9 bbls. Pressure up to 4,000 psi and release from liner. PU and confirm liner is released. PU=38K. 21 :25 - 22:45 1.33 CASE P COMP Circulate hole clean and prepare for displacement to KCI. Off load mud. 22:45 - 00:00 1.25 CASE P COMP Displace well to 2 % KCI at 3 bpm, 2,900 psi. 1/21/2004 00:00 - 01:45 1.75 CASE P COMP Displace well to 2 % KCI. Fill pits with KCI. RU cementers. Mix 30 bbl biozan pill. 01 :45 - 02:00 0.25 CASE P COMP Hold PJSM for cement job. 02:00 - 02:40 0.67 CEMT P COMP Prime up cement pump. Batch mix cement 02:40 - 03:45 1.08 CEMT P COMP Pump 3 bbls 2% KCI. PT cement lines to 4,000 psi. Pump 30.3 bbls 15.8 ppg gas block cement, drop CT wiper dart, displace w/ 30 bbl biozan pill and 2% KCI water. Observed liner wiper plug shear at calculated volume. Displace calculated liner volume plus 1/2 the shoe track volume and shut down. Did not bump plug. 30.2 bbls of cement out of shoe. 03:45 - 05:00 1.25 CEMT P COMP Unsting from liner. POOH replacing pipe capacity+displacement only. 05:00 - 05:20 0.33 CEMT P COMP PJSM for LD liner running tools. 05:20 - 06:00 0.67 CEMT P COMP LO liner running tools. 06:00 - 11 :00 5.00 BOPSURP COMP PJSM. Perform weekly BOPE pressure & function test. PT inner reel valve - OK. Test gas alarms. AOGCC test witness waived by Chuck Scheve. Compressive strength of cement - 800psi. 11:00 -11:30 0.50 EVAL P COMP Initialize & test logging tools. P/U tool into rig floor. 11 :30 - 11 :45 0.25 EVAL P COMP PJSM on P/U & RIH CNL tools & 1-1/4" CHS tbg. 11:45-15:15 3.50 EVAL P COMP P/U logging/cleanout BHA #9 with 2-1/4" D331 mill, 2-1/8" straight motor, XO, 2jts of 1-1/4" CSH tbg, MCNLlCCLlGR logging tool carrier, XO, lower MHA, 84jts of 1-1/4" CSH tbg, XO & upper MHA. M/U injector. 15:15-16:25 1.17 EVAL P COMP RIH logging BHA#9 on CT to 9300'. 16:25 - 18:00 1.58 EVAL P COMP Log down @ 30fpm from 9300'. Meanwhile start pumping down 150kcps Flo-Pro perf pill. Reciprocate 2x across LSL sub @ 1.5bpm. Continue logging down to PBTD tagged @ 11910'. 18:00 - 18:45 0.75 EVAL P COMP Log up @ 60fpm from PBTO to 9300' while laying-in 150kcps perf pill in liner. 18:45 - 20:00 1.25 EVAL P COMP POOH. 20:00 - 20: 15 0.25 EVAL P COMP PJSM for handling CSH. 20: 15 - 22:45 2.50 EVAL P COMP Drop ball to open circ sub. LD 21 joints CSH. Stand back remaining CSH. 22:45 - 23:00 0.25 EVAL P COMP PJSM for removing RA source and LO logging tools. Printed: 1/26/2004 10:32:15 AM . . BP Operations Summary Report Page 11 of 12 Legal Well Name: 05-41 Common Well Name: 05-41 Spud Date: 8/28/1996 Event Name: REENTER+COMPLETE Start: 1/12/2004 End: Contractor Name: NORDIC CALISTA Rig Release: 1/23/2004 Rig Name: NORDIC 1 Rig Number: N1 Date From - To I Hours: Task I Code NPT I Phase Description of Operations --.-----.------.... 1/21/2004 23:00 - 23:30 0.50 EVAL P COMP Remove RA source. LD logging tools, motor, and mill. 23:30 - 00:00 0.50 EVAL P COMP RU to test liner lap. Cement compressive strength above 2000 psi. Test liner lap. Test failed. 1/22/2004 00:00 - 01 :00 1.00 EVAL P COMP Continue liner lap test. Attempted to pressure up to 2,500 psi. Pressure came up to 2,000 psi then started pumping into formation. Stopped pumping and pressure bled off immediately to 1,000 psi. Bleed off pressure. Double block all valves at surface. Ensure hole is full. Repeat test. Same results, test failed. 01 :00 - 03:00 2.00 PERF P COMP Load perf guns into pipe shed and down load MCNL data. 03:00 - 03:15 0.25 PERF P COMP PJSM for PU perf guns. 03: 15 - 04:45 1.50 PERF P COMP PU SWS 2", 6spf, 2006PJ perf guns. 04:45 - 06:30 1.75 PERF P COMP Run CSH from derrick. 06:30 - 08:15 1.75 PERF P COMP RIH with perforating BHA#10 circ 10bbls of perf pill @ min rate. Wt check @ 11900' = 41k. Tag PBTD 11909'. Retag @ same depth. Pull to P/U wt & correct CTD to @ 11918' (PBTD as per MCNL log). Pull up to ball drop position @ 11908'. 08: 15 - 08:50 0.58 PERF P COMP Load 5/8" steel ball. Blow ball into CT with 5bbls perf pill behind. Position guns @ 11912' - 2' below btm shot. Chase ball to seat @ 2.5bpm/3400psi. Slow to 1.2bpm @ 44bbls. Ball on seat after 48.3bbls away. With btm shot @ 11910', ramp up to 3000psi while slowly moving guns uphole. Observe guns fire with good pressure drop indication. Perforated interval = 11334.72' - 11430' & 11500'-11910'. 08:50 - 10:55 2.08 PERF P COMP PUH to 11119' (above top perf) & paint EOP flag @ 8500'. POOH with perf gun BHA pumping across the WHD to keep hole full. 10:55 - 13:00 2.08 PERF P COMP OOH. PJSM. SIB injector. LID 35 joints of 1-1/4" CSH tbg & RIB 15 doubles. 13:00 -13:15 0.25 PERF P COMP PJSM on LID Perf guns. 13:15 -15:00 1.75 PERF P COMP LID run #1 perf guns. ASF! Load perf guns for run #2 into pipe shed. 15:00 -15:15 0.25 PERF P COMP PJSM for P/U run #2 perf guns. 15:15 -16:15 1.00 PERF P COMP M/U 26jts of 2" HSD 6 spf PJ guns & blanks with CBF firing system. 16:15 -17:10 0.92 PERF P COMP M/U 31 jts of 1-1/4" CSH tbg. M/U injector. Zero mechanical counter. Set CTD to BHA length of 1523.4' 17:10 -18:40 1.50 PERF P COMP RIH with perforating BHA#11 to flag (@1 0008.7') circ 14bbls of perf pill @ min rate. Correct CTD by +14.7' to 10023.4'. 18:40 - 19:50 1.17 PERF P COMP RIH to 10,830'. Pull up to 10,814'. Pump 16 bbls 150K LSRV perf pill with 2% lubtex. Drop 5/8" steel ball. Chase ball w/14 bbl perf pill. Circulate ball on seat. Start moving pipe up hole. Pressure up to 3,100 psi and fire guns on depth while moving pipe at 18 fpm. Perforated interval: 10,800' - 10,270' with SWS 2" guns, 6 spf, 2006PJ charges. 19:50 - 22:00 2.17 PERF P COMP POOH. Circulate remaining perf pill out of coil. Line up to fill across the top. Unstab injector. Circulate coil. 22:00 - 22: 15 0.25 PERF P COMP PJSM for LD CSH. 22:15 - 23:20 1.08 PERF P COMP LD CSH. 23:20 - 23:45 0.42 PERF P COMP PJSM for LD perf guns. 23:45 - 00:00 0.25 PERF P COMP LD Baker disconnect and firing head. LD perf guns. 1/23/2004 00:00 - 01 :30 1.50 PERF P COMP LD perf guns. Conduct well control drill after laying down first fired gun. Printed: 1/26/2004 10:32:15AM .... . BP Operations Summary Report Legal Well Name: 05-41 Common Well Name: 05-41 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To ' Hours ¡ Task Code NPT i 01 :30 - 02:30 02:30 - 04:00 Page 12 of 12 Start: Rig Release: Rig Number: Phase 1/12/2004 1/23/2004 N1 Spud Date: 8/28/1996 End: 1/23/2004 1.00 PERF 1.50 CASE P N COMP CEMT COMP 04:00 - 06:00 2.00 CASE N CEMT COMP 06:00 - 06:15 06:15 - 07:10 0.25 CASE 0.92 CASE N N CEMT COMP CEMT COMP 07: 1 0 - 08:45 1.58 CASE N CEMT COMP 08:45 - 09:05 0.33 CASE N CEMT COMP 09:05 - 09:15 0.17 RIGD P COMP 09: 15 - 09:45 0.50 RIGD P COMP 09:45 - 10:30 0.75 RIGD P COMP 10:30 - 10:45 0.25 RIGD P POST 10:45 - 11 :30 0.75 RIGD P POST 11 :30 - 13:00 1.50 RIGD P POST 13:00 - 14:00 1.00 RIGD P POST 14:00 - 15:30 1.50 RIGD P POST Description of Operations Off load guns. PU Baker liner top packer to rig floor. PJSM for running L TP. MU seal unit, two 10' pup joints, KB liner top packer assembly, Baker disconnect, 1 jt 2 3/8" PH6, CTC. RIH. Correct to 8,500 EOP flag. +18' correction. Tag deployment sleeve at 9,381'. SO 4' and bottom out on locator at 9,385'. PT liner lap to 1,000 psi. Pressure bled off immediately to 800 psi. Bump pressure up to 1,000 psi and isolate pump. Pressure bled off again to 800 psi. Note: Unable to PT lab to more than 1,000 psi due to rupture disc in Baker GH running tool. Rupture disc rated for 1,600 psi from annulus side. Unsting seals from deployment sleeve. Drop 5/8" ball. Up wt = 39k, Dwn wt = 24k. Chase ball to seat. Slow to 0.25bpm @ 38bbls. Ball on seat @ 42.3 bbls. RIH & set down 10k @ 9386.4'. PUH & RBIH to 9384'. PU & breakover @ 9382'. Set slips with 2200psi. Slack off to 9384.5' & pick back up to up wt. P/test packer with 2000psi for 10min (to prevent CT freezing). Good test - held like a jug. Press up to 3750 psi & release from KB Packer. Slack back 10k to 9384.9' - thus seal assy is 1.5' above PBR. POOH with L TP RItools. LID L TP running tool BHA. M/U FP nozzle BHA. M/U injector. RIH nozzle BHA to 2500'. POOH freeze protecting with 60/40 MeOH. SI swab valve (23 turns). PJSM for BD CT with N2. PIT N2 lines - OK. Attempt to blow down CT with N2 - observe frozen valve in reel house. Break frozen valve & remove ice plug. Meanwhile clean out pits & tanks. PIT N2 lines - OK. Blow down CT with N2 & bleed off. PJSM. Cutoff CTC & changeout packoff & set back injector. PJSM for ND. Nipple down BOP. Nipple up & pressure test tree cap. Rig Released at 15:30 hrs on 01/23/2004. Printed: 1/26/2004 10:32:15 AM TREE = FMC GEN 5 1--14-1/2" SVLN, SSSV = 3.8.12" ¡ I 9-518" ST ~ 1 2 3 TYÆ VLV PORT DATE I I X 4-112" BAKERS-3 PKR, D=3.875" I I I /4-112" .0152 bpf, 10 =3.958" 9411' HES X NIP, ID = 3.813" I TAIL WLEG, 10 = 3.958" I 9864' 14-112" L-80, 1-1 opf, 10 =3.958" 9954' LNR 9954' 9913' 1-14-1/2" PORTED JOINT ¡ IT' 10 = 6.184" H H -------' 1-1 .01 DA TE RBI BY 09116/96 11/21100 02/21101 0811 05113102 BYlfih 06112103 CrvDlTLP KB ELEV ATION CORRECTION COMMENTS ORIGINAL COMPlE1l0N SB-SL T CAN>.! AS SIS-lG RBlISION DATE REV BY COMMENTS 06/28/03 IKAK MlN 10 CORRECTION 07122/03 TGIKAK ADPffiF PRUDHOE SAY UNIT WELL: PffiMIT I\b: APII\b: SEC 32, T11 N, R15E, 2321.75' FEL & 1282.27' FNl BP Exploration (AI;iska) . . tJ03--j 7-0 28-Jan-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 5-41A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,999.64' MD 10,002.00' MD 11,956.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) RECEIVED f"..·· ~ /, IV'" 1 ' ," .: II: . "~_..L) L \.) ~~;~¡~JL (",¡aSKS Oil 8, Gas Cons, Comm.n ¡1r.,Fl,!',:¡n, e i.' ~..,!:If,,~~~, ~-C;~ ,'\\ ~ Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 05 05-41 A . Job No. AKMW0002860046, Surveyed: 20 January, 2004 Survey Report 27 January, 2004 Your Ref: API 500292269601 Surface Coordinates: 5948484.78 N, 698261.76 E (70015' 48.0668" N, 148023' 49.2173" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 948484.78 N, 198261.76 E (Grid) Surface Coordinates relative to Structure Reference: 1258.49 N, 863.79 E (True) Kelly Bushing E/evation: 72.43ft above Mean Sea Level Kelly Bushing Elevation: 72.43ft above Project V Reference Kelly Bushing Elevation: 72.43ft above Structure Reference S¡""',t=1 ·....,y-sul"'1 t1 AI.L...L 1 N G, """ 5 e A v I~c:;e s A Halliburton Company Survey Ref: svy4155 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 05 - 05-41A Your Ref: API 500292269601 Job No. AKMW0002860046, Surveyed: 20 January, 2004 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9999.64 89.290 219.110 8979.43 9051.86 2556.57 S 2615.82 W 5945860.22 N 695714.17 E -550.50 Tie On Point 10002.00 89.340 218.700 8979.46 9051.89 2558.41 S 2617.30 W 5945858.34 N 695712.73 E 17.500 -550.58 Window Point 10029.04 92.510 214.220 8979.02 9051 .45 2580.14 S 2633.36 W 5945836.19 N 695697.25 E 20.293 -550.33 10064.12 90.740 208.380 8978.02 9050.45 2610.09 S 2651.57 W 5945805.77 N 695679.84 E 17.388 -546.85 10099.24 85.810 198.940 8979.08 9051.51 2642.20 S 2665.64 W 5945773.31 N 695666.62 E 30.306 -538.76 . 10123.20 84.410 192.950 8981.13 9053.56 2665.14 S 2672.20 W 5945750.20 N 695660.67 E 25.584 -530.19 10155.26 89.870 183.430 8982.73 9055.16 2696.79 S 2676.75 W 5945718.44 N 695656.95 E 34.189 -514.78 10177.61 87.310 178.500 8983.28 9055.71 2719.12 S 2677.12 W 5945696.11 N 695657.16 E 24.847 -501.64 10208.88 86.520 171.280 8984.96 9057.39 2750.20 S 2674.34 W 5945665.12 N 695660.76 E 23.194 -480.72 10238.34 91.190 164.580 8985.55 9057.98 2778.97 S 2668.19 W 5945636.51 N 695667.67 E 27.713 -458.48 10271.49 91.370 156.120 8984.81 9057.24 2810.16 S 2657.05 W 5945605.63 N 695679.62 E 25.520 -430.82 10293.64 89.250 151.540 8984.69 9057.12 2830.03 S 2647.29 W 5945586.02 N 695689.91 E 22.784 -411.06 10317.36 88.990 149.780 8985.06 9057.49 2850.70 S 2635.67 W 5945565.66 N 695702.07 E 7.500 -389.34 10348.19 89.160 145.900 8985.55 9057.98 2876.80 S 2619.26 W 5945540.01 N 695719.16 E 12.596 -360.54 10381.85 90.570 142.200 8985.63 9058.06 2904.04 S 2599.50 W 5945513.30 N 695739.62 E 11.763 -328.36 10412.14 90.570 138.680 8985.33 9057.76 2927.39 S 2580.22 W 5945490.47 N 695759.52 E 11.620 -298.91 10452.47 91 .450 132.690 8984.62 9057.05 2956.23 S 2552.06 W 5945462.38 N 695788.43 E 15.009 -259.07 10483.46 91.890 128.810 8983.72 9056.15 2976.44 S 2528.60 W 5945442.79 N 695812.41 E 12.595 -228.16 10518.17 88.990 125.810 8983.45 9055.88 2997.48 S 2501.00 W 5945422.49 N 695840.56 E 12.020 -193.46 10550.87 88.190 122.640 8984.26 9056.69 3015.86 S 2473.97 W 5945404.82 N 695868.06 E 9.995 -160.81 10585.96 90.310 118.760 8984.72 9057.15 3033.77 S 2443.81 W 5945387.71 N 695898.68 E 12.599 -125.95 . 10614.29 91 .630 116.470 8984.24 9056.67 3046.90 S 2418.71 W 5945375.25 N 695924.11 E 9.329 -98.00 10650.22 92.780 113.650 8982.85 9055.28 3062.10 S 2386.19 W 5945360.90 N 695957.02 E 8.471 -62.88 10682.04 87.870 112.770 8982.67 9055.10 3074.64 S 2356.96 W 5945349.14 N 695986.58 E 15.676 -31.99 10716.11 87.310 107.660 8984.11 9056.54 3086.40 S 2325.03 W 5945338.23 N 696018.81 E 15.075 0.59 10747.07 88.900 104.840 8985.13 9057.56 3095.05 S 2295.32 W 5945330.36 N 696048.73 E 10.452 29.52 10782.04 89.430 99.380 8985.64 9058.07 3102.39 S 2261.15 W 5945323.93 N 696083.09 E 15.685 61.23 10805.10 92.780 102.020 8985.20 9057.63 3106.67 S 2238.50 W 5945320.25 N 696105.84 E 18.494 81.89 10826.27 92.780 98.320 8984.17 9056.60 3110.40 S 2217.69 W 5945317.06 N 696126.74 E 17.457 100.76 10847.33 91.010 96.210 8983.47 9055.90 3113.06 S 2196.81 W 5945314.95 N 696147.68 E 13.073 119.04 10870.61 88.990 92.690 8983.47 9055.90 3114.87 S 2173.61 W 5945313.76 N 696170.93 E 17.432 138.65 10907.87 91.730 87.120 8983.24 9055.67 3114.81 S 2136.37 W 5945314.80 N 696208.15 E 16.658 168.36 10942.08 93.300 92.860 8981.74 9054.17 3114.80 S 2102.20 W 5945315.71 N 696242.30 E 17.379 195.64 10973.54 92.860 96.910 8980.04 9052.47 3117.47 S 2070.91 W 5945313.86 N 696273.65 E 12.931 222.24 11001.07 90.220 100.440 8979.30 9051.73 3121.62 S 2043.71 W 5945310.42 N 696300.95 E 16.007 246.46 27 January, 2004 - 10:13 Page 2 of 4 DritlQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 05 - 05-41A Your Ref: API 500292269601 Job No. AKMW0002860046, Surveyed: 20 January, 2004 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11029.75 90.570 104.140 8979.11 9051.54 3127.73 S 2015.69 W 5945305.06 N 696329.12 E 12.958 272.51 11063.85 90.930 108.720 8978.66 9051.09 3137.37 S 1983.00 W 5945296.28 N 696362.06 E 13.471 304.42 11098.37 89.600 113.480 8978.50 9050.93 3149.79 S 1950.80 W 5945284.71 N 696394.57 E 14.317 337.61 11125.89 89.690 117.000 8978.67 9051.10 3161.52 S 1925.92 W 5945273.64 N 696419.76 E 12.795 364.55 11156.76 89.960 120.530 8978.76 9051.19 3176.38 S 1898.86 W 5945259.50 N 696447.20 E 11 .468 395.10 . 11187.00 91.100 117.180 8978.48 9050.91 3190.97 S 1872.38 W 5945245.61 N 696474.05 E 11.701 425.02 11221.73 91.980 114.360 8977 .55 9049.98 3206.06 S 1841.12 W 5945231.35 N 696505.70 E 8.503 459.07 11246.02 94.180 111 .190 8976.25 9048.68 3215.45 S 1818.76 W 5945222.55 N 696528.30 E 15.869 482.58 11278.13 91.540 105.730 8974.64 9047.07 3225.60 S 1788.35 W 5945213.21 N 696558.96 E 18.867 512.97 11312.19 87.750 102.020 8974.85 9047.28 3233.76 S 1755.30 W 5945205.92 N 696592.22 E 15.570 544.28 11346.12 86.610 97.620 8976.52 9048.95 3239.54 S 1721.92W 5945201 .02 N 696625.74 E 13.381 574.42 11375.65 90.480 96.030 8977.27 9049.70 3243.05 S 1692.61 W 5945198.29 N 696655.13 E 14.167 599.94 11409.26 92.490 97.740 8976.40 9048.83 3247.07 S 1659.26 W 5945195.14 N 696688.58 E 7.850 629.00 11443.91 94.890 102.550 8974.17 9046.60 3253.16 S 1625.23 W 5945189.95 N 696722.75 E 15.487 659.83 11471.20 92.860 1 07.490 8972.33 9044.76 3260.22 S 1598.94 W 5945183.59 N 696749.22 E 19.531 685.07 11509.99 89.870 112.420 8971.40 9043.83 3273.45 S 1562.51 W 5945171.32 N 696785.99 E 14.860 722.13 11532.20 87.930 117.530 8971.83 9044.26 3282.82 S 1542.39 W 5945162.48 N 696806.35 E 24.605 743.84 11563.00 89.600 122.820 8972.49 9044.92 3298.29 S 1515.78 W 5945147.72 N 696833.36 E 18.006 774.41 11579.37 88.190 126.870 8972.81 9045.24 3307.64 S 1502.35 W 5945138.73 N 696847.03 E 26.192 790.76 11595.66 88.550 127.580 8973.27 9045.70 3317.49 S 1489.38 W 5945129.22 N 696860.25 E 4.885 807.04 11626.61 91.280 133.740 8973.32 9045.75 3337.64 S 1465.92 W 5945109.69 N 696884.24 E 21.768 837.91 11659.50 86.780 136.910 8973.87 9046.30 3361.02 S 1442.80 W 5945086.93 N 696907.96 E 16.734 870.44 . 11681.22 85.730 142.910 8975.29 9047.72 3377.59 S 1428.85 W 5945070.73 N 696922.34 E 27.986 891.55 11711.37 87.310 146.960 8977.13 9049.56 3402.22 S 1411 .57 W 5945046.57 N 696940.27 E 14.395 920.18 11743.16 89.520 153.830 8978.01 9050.44 3429.83 S 1395.88 W 5945019.38 N 696956.67 E 22.692 949.32 11773.42 90.400 158.590 8978.03 9050.46 3457.51 S 1383.68 W 5944992.03 N 696969.60 E 15.997 975.73 11799.07 90.220 159.650 8977.89 9050.32 3481.48 S 1374.54 W 5944968.31 N 696979.37 E 4.192 997.45 11833.29 90.310 166.170 8977.73 9050.16 3514.17S 1364.49 W 5944935.90 N 696990.28 E 19.055 1025.15 11861.53 90.310 173.740 8977.58 9050.01 3541.95 S 1359.56 W 5944908.25 N 696995.93 E 26.806 1045.80 11888.85 91.100 175.860 8977.24 9049.67 3569.16 S 1357.09 W 5944881.12 N 696999.12 E 8.281 1064.15 11917.84 90.220 179.730 8976.91 9049.34 3598.12 S 1355.97 W 5944852.20 N 697001.00 E 13.689 1082.47 11947.30 89.690 184.320 8976.93 9049.36 3627.55 S 1357.01 W 5944822.75 N 697000.73 E 15.684 1099.36 11956.00 89.690 184.320 8976.98 9049.41 3636.23 S 1357.67 W 5944814.06 N 697000.31 E 0.000 1104.05 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. 27 January, 2004 - 10:13 Page 3 of 4 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_EOA OS 05 - 05-41A Your Ref: API 500292269601 Job No. AKMW0002860046, Surveyed: 20 January, 2004 BPXA North Slope Alaska Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 127.000° (True). Magnetic Declination at Surface is 25.549° (09-Jan-04) Based upon Minimum Curvature type calculations, at a Measured Depth of 11956.00ft., The Bottom Hole Displacement is 3881.42ft., in the Direction of 200.474° (True). . Comments Measured Depth (ft) Station Coordinates TVD Northings Eastin9s (ft) (ft) (ft) Comment 9999.64 10002.00 11956.00 9051 .86 9051.89 9049.41 2556.57 S 2558.41 S 3636.23 S 2615.82 W 2617.30 W 1357.67 W Tie On Point Window Point Projected Survey Survey tool program for 05-41A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) . 0.00 0.00 11956.00 9049.41 MWD Magnetic (05-41) 27 January, 2004 - 10:13 Page 4 of 4 Ori/lQuest 3.03.05.005 (ill . ~~~~ . FRANK H. MURKOWSK/, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 1'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276·7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudheo Bay Unit PBU 05-41A BP Exploration (Alaska), Inc. Permit No: 203-170 Surface Location: 2291' NSL, 4103' WEL, Sec. 32, TIIN, RISE, UM Bottomhole Location: 1269' SNL, 175' WEL, Sec. 06, TI0N, RISE, UM Dear Mr. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ ~uedrich Commissioner BY ORDER OF THE COMMISSION DATED thisA day of October, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section (¡...l6tÆ- ¡ 0 II 0' 2-00 ~ [J Drill III Redrill 1 a. Type of work [J Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2291' NSL, 4103' WEL, SEC. 32, T11N, R15E, UM Top of Productive Horizon: 125' NSL, 1111' WEL, SEC. 31, T11 N, R15E, UM Total Depth: 1269' SNL, 175' WEL, SEC. 06, T10N, R15E, UM .. STATE OF ALASKA . ALASKA O~ND GAS CONSERVATION COM SION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class [J Exploratory [J Stratigraphic Test [J Service 5. Bond: !HI Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 11975 TVD 8968 7. Property Designation: ADL 028329 III Development Oil [J Multiple Zone [J Development Gas [J Single Zone 11. Well Name and Number: PBU 05-41A /' 12. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 8. Land Use Permit: 13. Approximate Spud Date: 11/15/03 /' 14. Distance to Nearest Property: 21,000' 9. Acres in Property: 2560 4b. Location of Well (State Base Plane Coordinates): Surface: x-698262 y-5948485 Zone-ASP4 16. Deviated Wells: Kickoff Depth 18. Casing Program Size Hole Casing Weight 4-1/8" x 3-3/4" 3-3/16' x 2-7/8" 6.2# 1 6.5# 10050 ft Maximum Hole Angle 97° 10. KB Elevation KBE = 15. Distance to Nearest Well Within Pool (Height above GL): 72.43' feet 05-22 is 580' away at 10050' /' 17. Anticipated pressure (see 20 AAC 25.035) ,/ Max. Downhole Pressure: 3250 psig. Max. Surface Pressure: 2194 psig Setting Depth Quantitybf Cement Top Bottom '. 'CIr (c.f. or sacks) MD TVD MD TVD ¡ SS ~- (including stage data) 9375' 8619' 11975' 8968' ..ar'sx Class 'G' Specifications Grade Coupling Length L-80 TCIII STL 2600' 19. PRESENTWELL CONDITION SUMMARY (To be completèdfbr RedriIIANDRe-entryOperations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): IEffective Depth TVD (ft):1 11340 9058 NI A 11340 9058 Junk (measured): 9832 Structural Conductor 110' 20" 260 sx Arcticset (Approx.) 110' 110' Surface 3732' 9-5/8" 2034 sx PF 'E', 337 sx Class 'G' 3767' 3569' Intermediate Production 9953' 7" 289 sx Class 'G' 9986' 9051' Liner 1476' 4-1/2" Uncemented Slotted Liner 9864' - 11340' 9032' - 9058' 20. Attachments !HI Filing Fee !HI BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8881' - 9057' !HI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report !HI Drilling Fluid Program !HI 20 AAC 25.050 Requirements Perforation Depth MD (ft): 9588' -11317 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mary Endacott Title CT Drilling Engineer Signature j)1Z·1L¿' ~1'1/:i{Jr £tt- Phone 564-4388 . /' '?! Commission Use Only Permit To Drill I API Number: I Permit APpr.?~I" I See cover Ie, tt"er for Number: ZQ 3 - / 7cs 50-029-22696-01-00 Date: /0/1 ?/~: :tGftIer'~~'Fnts Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Requiretí !. ,-~.j Ô ~~ ~~ HYdrOg~n Sulfide M~asures ß] Yes 0 No Directional Survey ReqUired.þ¥)Y e~D No Other: ""[ fC,;;t- B'V P e ~-o ~S DD p~ l . Date: Contact Mary Endacott, 564-4388 Date 10/0/03 Prepared By Name/Number: Terrie Hubble, 564-4628 üns ~~.A Approved By: I ~ ~ / - -..... Form 10-401 Revised 3/2003 BY ORDER OF o ~mì\ [HE COMMISSION Date /of31<73 Submit In Duplicate './ ., e BP 5-41 A CTD Sidetrack e Phase 1 Operations: Non rig Prep Work: · Drift the production tubing & liner and run a calliper survey to check mechanical integrity. · Integrity pressure test OA, IA &tbg, wellhead seals & Xmas tree valves. · Set packer with tailpipe in the slotted liner. · Sting hollow/perforatable whipstock into packer. · Downsqueeze cement past whipstock Phase 2 Operations: Mill window, Drill and Complete sidetrack. Mud Program: · Phase 1: Seawater/1 % KCI L7 · Phase 2: Mill with seawater / ~Ib biozan, drill with Solids Free Flo-Pro (8.6 ~pg) Disposal: · 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. ~~~~: . / The production liner will be solid 33/16 TCII X 2Ys" STL from a TD of;1-1,975', (-8967'ss) to 9,375'MD (-8,619'ss) within the tbg tailpipe. The liner will be cemented with8gÞbls with a planned TOC at TOL within the 4%" tailpipe. ~ Parent Well Casings 9%" 40#, L-BO, BTC 7" 29#, L-BO, Mod BTC 4 Y2" 12.6#, L-BO NSTC SLOTTED LINER Sidetrack Casings 3-3/16" 6.2#, L-BO, TCII- Prod LNR 2Vs" 6.5#, L-BO, STL - Prod LNR Burst (psi) 5750 B160 NA Collapse (psi) 3090 7020 NA /' 8520 10570 7660 11170 Well Control: · BOP diagram is attached. / · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90°. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · 5-41 A will be approximately 580' ctr-ctr away from well 5-22 at 10,050'md / · 5-41 A will be approximately 21,000' from the unit boundary, (Prudhoe Bay Unit) Logging · MWD Gamma Ray and Resistivity will be run in the open hole section. · Memory CNL will be run inside the liner. Hazards / · H2S has not recently been measured on 5-41. 27ppm is the maximum measured on the pad. . · One fault will likely be cut by the wellpath. The risk of a lost circulation event is considered low to medium. No losses in parent well. Reservoir Pressure · Res. press. is estimated to be 3250 p~at 8800'ss (7.1 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2194 psi. TREE = , WELLHEAD = FMC GEN 5 CrN 72.4' SAfETY NOTES: HORIZONTAL WELL. 2168' H4-1/2" CAMCO BAL-O SVLN, SSSV NIP, ID = 3.812" I GAS LIFT MANDRELS ST MD TVO DEV TYPE VLV LATCH PORT DATE ~ 1 3900 3689 25 KBG-2-LS-MOO INT 2 6758 6296 25 KBG-2-LS-MOD INT 3 9291 8615 24 KBG-2-LS-MOD INT . 3767' - 19-5/8" CSG, 40#, L-80, 10 = 8.835" H I T' CSG, 26#, L-80, ID = 6.276" H ¡TOP OF 7" CSG H 8962' 8962' Minimum ID:::: 3.812" @ 2168' 4-1/2" SSSV NIPPLE 4-1/2"TBG,12.6#, L-80, 1--1 .0152 bpf, ID = 3.958" 9411' I TOP OF 4-1/2" LNR H 9864' 14-1/2" LNR, 12.6#, L-80, 1--1 .0152 bpf, ID = 3.958" 9954' TOP OF 4-1/2" SLTDLNR H 9954' 17" CSG, 29#, L-80, 10 = 6.184" H 9986' 1--1 H ÆRFORA TION SUMMARY REF LOG: BHCS ON 09/08/96 ANGLE AT TOP PERF: 35 @ 9588' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 6 9588 - 9598 3-3/8" 6 9790 - 9795 o 9954 -11317 DATE 09/16/96 11/21/00 02/21/01 08/12/01 05/13/02 06/12/03 REV BY COMMENTS ORIGINAL COMPLETION SIS-SL T CONVERTED TO CANVAS SIS-LG REVISION RN/KAK CORRECTIONS BY /tlh ÆRF CORRECTIONS CMOITLP KB ELEVATION CORRECTION L 9360' 9392' 9417' 9416' ::: 4-1/2" HES X NIP, 10 = 3.813" I - 4-1/2" TUBING TAIL WLEG, 10 = 3.958" I 9913' H 4-1/2" PORTED JOINT I 1--1 H H - -..... H DATE REV BY COMMENTS 06/28/03 /KAK MIN ID CORRECTION 07/22/03 TG/KAK ADÆRF PRUDHOE BAY UNIT WELL: 05-41 ÆRMITNo: 1961410 API No: 50-029-22696-00 SEC 32, T11N, R15E, 2321.75' FEL & 1282.2T FNL BP Exploration (Alaska) BP Amoco WELLPATH þETAfLS Pbln#6 0s.41A 50029:1269601 Parent W.llpatft: 054-1 Tie on MO: 10032.01 RIg, R.f. Datum= V.S.ctlon AIIgle 127.90' ~1ff~ t¡~= .... ~=:i~ REFERENCE !NFORMAT10N Co-ordinate (NJE) Reference" We!! Centre: 05-41, True North V~~~R(~~~ ~~:~:~~~ ~r~t~~ %~~~g~~)el Measured Depth, Reference: 05-41 72.43 Calculation Method: Minimum Curvature SStTION DETAILS ÐL"'9 TFac$ Tarþt , , . i : u " .. ~! 8979.97 8980.34 ::.,~:g 8$78.62 U&4.$3 8980.15 8$78.$0 a977.73 8$.1'7.44 8976.80' 8976.00 8975.72 8973.15 8$68.11 f/~!H," 087,71 ·:N3Ø.MI 4$4&.11 -26f.I1.03 -26,84,U -2712.40 -2:7'19.$7 -2880,46 46%.17 -U$8.57 426U18 .2018.20 .182;4.:90 -1725.M ·'i4&7,10 .1447.44 111IU" --'1339.98 -2581.59 ..!l:$9$.2$ 4610.IH;: :~ot:: ~281;1.38 -291.2,44 ·:2934.41 .3G73.Ð4 :~t:~~ -3186.21 .3198.59 .3325,50 -3381.3. .;;;.;~ MD Annotatioa TVO +NI..$ +EI_W Sh"Þ" .. .. " J: .. A8700- CD a 8750 '¡ .!:! 880 1:: ~ 8850 CD 2 .... T LEGEND - - 05·41 (05-41) PJan#$ 05-41A Plan #6 Azimuths to True North Magnetic North: 25.71" Magnetic Field Strength: 57583nT Dip Angle: 80.86' Date: 812512003 Model: bggm2003 Plan: Plan #6 (05-41 fP!an#6 0&-41 A) Created By: Brij Potnj$ Date: 8/25/2003 M -50 0 50 100 150 200 250 500 Vertical Section at 127.00' [50ft/in] 8/25/2003 11 :35 AM e e BP-GDB Baker Hughes INTEQ Planning Report Date: 8/25/2003 ,. Time: 11 :36:30 Page: " 1 " Co-ordiìîate(NE) :Reference: Well: 05-41, True North Vertical (TVD) Reference: System: Mean Sea''Level Section (VS) Refereiiee: Well (0.00N,0.00E,127.00Azi) Survey Calculatioii~#hod: Minimum Curvaturë. " 'Db: Oracle BPAmoco Prudhoe Bay PB DS 05 05-41 Plan#6 05-41A Company: Field: ,'Site: Well: , ~ellpath: Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Alaska, Zone 4 Well Centre bggm2003 Map Zone: Coordinate System: Geomagnetic Model: Site: PB DS 05 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5947204.70 ft 697428.91 ft Latitude: 70 15 Longitude: 148 24 North Reference: Grid Convergence: 35.696 N 14.424 W True 1.50 deg Well: 05-41 Slot Name: 41 05-41 Well Position: +N/-S 1257.88 ft Northing: 5948484.79 ft Latitude: 70 15 48.067 N +E/-W 866.17 ft Easting : 698261.76 ft Longitude: 148 23 49.217 W Position Uncertainty: 0.00 ft Wellpath: Plan#6 05-41 A 500292269601 Current Datum: 05-41 Magnetic Data: 8/25/2003 Field Strength: 57583 nT Vertical Section: Depth From (fVD) ft 38.13 05-41 10032.01 ft Mean Sea Level 25.71 deg 80.86 deg Direction deg 127.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Height 72.43 ft +N/-S ft 0.00 Targets Map ::,:"M,ap Northing 'E~ting ftft:, 5946008.00 695837.00 5946008.00 695837.00 5945448.00 695376.00 5945125.00 695699.00 5945111.00 696042.00 5945053.00 696557.00 5945017.00 696725.00 5944700.00 697100.00 5945000.00 697260.00 5945310.00 696814.00 5945432.00 695928.00 5944900.00 696762.00 5944900.00 696762.00 5945555.00 696064.00 <-'" ,Longitude --> J)~g. Min Sec <-- Latitude --> Deg Min Sec +N/-S ft -2412.21 -2412.21 -2959.91 -3291.32 -3314.35 -3385.89 -3426.31 -3753.09 -3457.39 -3135.74 -2990.44 +E/~W ':ft -2489.28 -2489.28 -2964.89 -2650.49 -2307.96 -1794.64 -1627.64 -1261.09 -1093.24 -1530.95 -2413.48 "Name Description:'.:', Dip. "])ir. 05-41 A Polygon6.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 05-41A Fault 1 -Polygon 1 -Polygon 2 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 70 15 24.339 N 70 15 24.339 N 70 15 18.950 N 70 15 15.692 N 70 15 15.467 N 70 15 14.764 N 70 15 14.367 N 70 15 11.154 N 70 15 14.063 N 70 15 17.225 N 70 15 18.652 N 148 25 1.635 W 148 25 1.635 W 148 25 15.465 W 148 25 6.316 W 148 24 56.352 W 148 2441.419 W 148 24 36.561 W 148 24 25.898 W 148 24 21.017 W 148 24 33.751 W 148 24 59.424 W 148 24 35.574 W 148 24 35.574 W 148 24 55.376 W -3544.25 -1593.73 -3544.25 -1593.73 -2871.06 -2274.28 70 15 13.208 N 70 15 13.208 N 70 15 19.827 N 05-41A T6.6 8965.00 -3434.05 -1447.77 5945014.00 696905.00 70 15 14.292 N 148 2431.329 W 8968.00 -3553.54 -1354.88 5944897.00 697001.00 70 15 13.117 N 148 2428.627 W 8973.00 -3343.28 -1513.40 5945103.00 696837.00 70 15 15.184 N 148 24 33.239 W 8976.00 -3118.71 -1721.57 5945322.00 696623.00 70 15 17.392 N 148 24 39.296 W 8978.00 -3068.79 -2439.55 5945353.00 695904.00 70 15 17.881 N 148 25 0.182 W 8980.00 -2898.43 -2678.16 5945517.00 695661.00 70 1519.556 N 148 25 7.124 W 8985.00 -2797.02 -2730.51 5945617.00 695606.00 70 15 20.553 N 148 25 8.648 W 05-41A T6.7 05-41A T6.5 05-41A T6.4 05-41 A T6.3 05-41A T6.2 05-41A T6.1 , Company:, ,'Field: ' Site: Well: Wellpath: ~~~~~ça~~~ PB DS',05 05-41' Plan#6 05-41A Annotation !\II> TYD ft ft n..____._ ___..._..__........ ... _.. ... ....... 10032.01 8979.97 TIP 10050.00 8980.34 KOP 10070.00 8980.49 3 10110.00 8978.50 4 10178.00 8978.68 5 10296.42 8984.63 6 10396.42 8980.16 7 10424.42 8978.80 8 10674.42 8977.73 9 10874.42 8977.44 10 11124.42 8976.60 11 11324.42 8976.00 12 11424.42 8975.72 13 11689.42 8973.15 14 11764.42 8968.17 15 11814.42 8964.96 16 11975.00 8967.71 TO e BP-GDB e Baker Hughes INTEQ Planning Report . . .... .... ... ...... .. '.::o~te: 8I25/2()03~Time: .i'J1:36:30 'Page: 2 ':Co-ordinate(NE)Rererenee:~:::~' wåll: 05,41. True Nort:h,~', Vertical (T.VI)) Reference:" ."}( :~~¡~ '~ý'~tern::!'~~~~¡:Sea Leve(:. :.;.. ,: Section (VS) 'Reference:'': ','::""",: Well (O.OO,NiO;OOE.12tOOAziJ , Survey Calculation Method.: ;'~. ,. Minimuni'C~¡vatiJre ' ,])b:: 'Òr~çle~~ . ' :.-.:. ,: .. -,..-... --,...-.--- . .... - . ....-....--... ....-.. -.. --.-- ....-.. ...-....- .. ... .. - - ... .. .. Plan: Plan #6 Date Composed: 8/25/2003 Identical to Lamar's Plan #6 Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information :,~~m Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target , deg deg ft :tt ft deg/100ft deg/100ft deg/10OO deg .___._ _ ..____.._~___.. ..__~_.. ._____.__.____..____.____ ··_·~_M .. -...... .". -.-"-."-- ._-_.._~_.~---_.~-- 10032.01 88.80 220.13 8979.97 -2581.59 -2636.45 0.00 0.00 0.00 0.00 10050.00 88.80 220.70 8980.34 -2595.28 -2648.11 3.17 0.00 3.17 90.01 10070.00 90.36 219.80 8980.49 -2610.55 -2661.03 9.00 7.79 -4.50 330.00 10110.00 95.34 211.11 8978.50 -2643.04 -2684.18 25.00 12.44 -21.72 300.00 10178.00 84.37 198.11 8978.68 -2704.64 -2712.40 25.00 -16.13 -19.13 230.00 10296.42 90.00 168.99 8984.63 -2821.38 -2719.57 25.00 4.76 -24.58 280.00 10396.42 95.04 144.48 8980.16 -2912.44 -2680.46 25.00 5.04 -24.52 282.00 10424.42 90.53 139.12 8978.80 -2934.41 -2663.17 25.00 -16.12 -19.13 230.00 10674.42 89.96 109.12 8977.73 -3073.04 -2458.57 12.00 -0.23 -12.00 269.00 10874.42 90.20 85.13 8977.44 -3097.67 -2261.56 12.00 0.12 -12.00 270.60 11124.42 90.18 115.13 8976.60 -3141.12 -2018.26 12.00 -0.01 12.00 90.00 11324.42 90.16 91.13 8976.00 -3186.21 -1824.90 12.00 -0.01 -12.00 270.00 11424.42 90.16 103.13 8975.72 -3198.59 -1725.86 12.00 0.00 12.00 90.00 11689.42 90.92 134.92 8973.15 -3325.50 -1497.10 12.00 0.29 12.00 88.50 11764.42 96.69 141.85 8968.17 -3381.38 -1447.44 12.00 7.69 9.24 50.00 11814.42 90.69 141.85 8964.96 -3420.60 -1416.63 12.00 -12.00 0.00 180.00 11975.00 87.37 160.83 8967.71 -3560.81 -1339.98 12.00 -2.07 11.82 100.00 Survey MD Incl Azim'" ':,:,'" Sys TVD N/S E/W" MapN 'MapE \,:~S DLS TFO Tool ft deg deg, ft ft ft ft 'Jr'.':" de¡g/10OO deg 10032.01 88.80 220.13 8979.97 -2581.59 -2636.45 5945834.81 695694.35 -551.92 0.00 0.00 TIP 10050.00 88.80 220.70 8980.34 -2595.28 -2648.11 5945820.82 695683.06 -552.99 3.17 90.01 KOP 10070.00 90.36 219.80 8980.49 -2610.55 -2661.03 5945805.22 695670.54 -554.13 9.00 330.00 3 10075.00 90.98 218.72 8980.43 -2614.42 -2664.19 5945801.27 695667.48 -554.32 25.00 300.00 MWD 10100.00 94.10 213.29 8979.32 -2634.61 -2678.87 5945780.70 695653.34 -553.89 25.00 299.99 MWD 10110.00 95.34 211.11 8978.50 -2643.04 -2684.18 5945772.13 695648.26 -553.06 25.00 299.75 4 10125.00 92.92 208.24 8977.42 -2656.04 -2691.59 5945758.94 695641.20 -551.15 25.00 230.00 MWD 10150.00 88.88 203.47 8977.03 -2678.53 -2702.48 5945736.18 695630.90 -546.32 25.00 229.79 MWD 10175.00 84.85 198.68 8978.40 -2701.81 -2711.45 5945712.67 695622.54 -539.48 25.00 229.72 MWD 10178.00 84.37 198.11 8978.68 -2704.64 -2712.40 5945709.81 695621.67 -538.52 25.00 229.98 5 10200.00 85.34 192.67 8980.65 -2725.76 -2718.21 5945688.55 695616.42 -530.46 25.00 280.00 MWD 10225.00 86.51 186.52 8982.43 -2750.33 -2722.36 5945663.88 695612.91 -518.98 25.00 280.49 MWD 10250.00 87.71 180.37 8983.69 -2775.24 -2723.86 5945638.94 695612.07 -505.19 25.00 280.93 MWD 10275.00 88.94 174.24 8984.43 -2800.19 -2722.69 5945614.03 695613.90 -489.24 25.00 281.24 MWD e BP-GDB e Baker Hughes INTEQ Planning Report . ...... . .... ... ........ Company: BP Amoco "¡" , .. Date: 8i2512Ô03Y:::,"Tiin~: 11 :36::3o, ',", Page: 3 Field: Prudhoe Bay Co-ordlnate(NE;)' Refere~~e: Well: 05-4t, True North. '. , Site: " PB DS 05 Vertical (TVD) Referen'ce: System: Mean Sea Lève"".'"' " Well: .. 05-41 , ~ .. Section (VS) Referenee:, ", Well (0.00N,0~00E¡127.0(JAzi) ,'",ellpat~: P'àn#6 05-41A Survey Calculation Method: Minimum Curvature' ,";', :Db: Oracle . .. ..... Survey MD IncI Azlm Sys TYD N/S " E/W Y.' ,MapN rMiipE VS DLS' ' TFO Tool ft deg ,,:,'" deg, "" ' ft " ft ft ft ft ft deg/10OO deg 10296.42 90.00 168.99 8984.63 -2821.38 -2719.57 5945592.94 695617.58 -474.00 25.00 281.42 6 10300.00 90.19 168.12 8984.62 -2824.88 -2718.86 5945589.45 695618.38 -471.32 25.00 282.00 MWD 10325.00 91.48 162.00 8984.26 -2849.03 -2712.42 5945565.49 695625.45 -451.65 25.00 282.00 MWD 10350.00 92.76 155.88 8983.33 -2872.33 -2703.45 5945542.43 695635.04 -430.46 25.00 281.91 MWD 10375.00 94.01 149.75 8981.85 -2894.52 -2692.05 5945520.55 695647.01 -408.00 25.00 281.68 MWD 10396.42 95.04 144.48 8980.16 -2912.44 -2680.46 5945502.94 695659.07 -387.96 25.00 281.32 7 10400.00 94.47 143.79 8979.86 -2915.33 -2678.37 5945500.10 695661.23 -384.55 25.00 230.00 MWD 10424.42 90.53 139.12 8978.80 -2934.40 -2663.17 5945481.44 695676.93 -360.94 25.00 229.94 8 10425.00 90.52 139.05 8978.80 -2934.84 -2662.79 5945481.01 695677.32 -360.37 12.01 268.86 MWD 10450.00 90.47 136.05 8978.58 -2953.29 -2645.92 5945463.02 695694.67 -335.80 12.00 269.00 MWD 10475.00 90.42 133.05 8978.38 -2970.82 -2628.11 5945445.96 695712.93 -311.02 12.00 268.97 MWD 10500.00 90.36 130.05 8978.21 -2987.40 -2609.40 5945429.88 695732.07 -286.10 12.00 268.95 MWD 10525.00 90.31 127.05 8978.07 -3002.98 -2589.85 5945414.82 695752.02 -261.11 12.00 268.93 MWD 10550.00 90.25 124.05 8977.95 -3017 .51 -2569.52 5945400.83 695772. 73 -236.12 12.00 268.91 MWD 10575.00 90.19 121.05 8977.85 -3030.96 -2548.45 5945387.94 695794.15 -211.20 12.00 268.90 MWD 10600.00 90.13 118.05 8977.78 -3043.29 -2526.70 5945376.19 695816.21 -186.41 12.00 268.89 MWD 10625.00 90.07 115.05 8977.74 -3054.47 -2504.34 5945365.60 695838.86 -161.83 12.00 268.88 MWD 10650.00 90.01 112.05 8977.72 -3064.46 -2481.43 5945356.22 695862.02 -137.52 12.00 268.87 MWD 10674.42 89.96 109.12 8977.73 -3073.04 -2458.57 5945348.24 695885.10 -114.10 12.00 268.87 9 10675.00 89.96 109.05 8977.73 -3073.23 -2458.02 5945348.07 695885.65 -113.54 12.00 270.60 MWD 10700.00 89.99 106.06 8977.74 -3080.77 -2434.19 5945341.16 695909.67 -89.97 12.00 270.60 MWD 10725.00 90.02 103.06 8977.74 -3087.06 -2409.99 5945335.51 695934.02 -66.87 12.00 270.60 MWD 10750.00 90.05 100.06 8977.72 -3092.06 -2385.50 5945331.15 695958.64 -44.30 12.00 270.60 MWD 10775.00 90.08 97.06 8977.69 -3095.78 -2360.78 5945328.09 695983.44 -22.32 12.00 270.60 MWD 10800.00 90.11 94.06 8977.65 -3098.20 -2335.90 5945326.32 696008.38 -0.99 12.00 270.60 MWD 10825.00 90.14 91.06 8977.59 -3099.32 -2310.93 5945325.87 696033.37 19.62 12.00 270.59 MWD 10850.00 90.17 88.06 8977.52 -3099.12 -2285.94 5945326.72 696058.35 39.47 12.00 270.58 MWD 10874.42 90.20 85.13 8977 .44 -3097.67 -2261.56 5945328.81 696082.68 58.06 12.00 270.58 10 10875.00 90.20 85.20 8977 .44 -3097.62 -2260.98 5945328.88 696083.25 58.49 11.96 90.00 MWD 10900.00 90.20 88.20 8977.35 -3096.18 -2236.03 5945330.97 696108.16 77.56 12.00 90.00 MWD 10925.00 90.20 91.20 8977.26 -3096.05 -2211.03 5945331.76 696133.14 97.44 12.00 90.01 MWD 10950.00 90.20 94.20 8977.18 -3097.22 -2186.06 5945331.25 696158.13 118.09 12.00 90.02 MWD 10975.00 90.20 97.20 8977.09 -3099.70 -2161.19 5945329.42 696183.06 139.45 12.00 90.03 MWD 11000.00 90.20 100.20 8977.00 -3103.48 -2136.48 5945326.30 696207.86 161.45 12.00 90.04 MWD 11025.00 90.19 103.20 8976.92 -3108.55 -2112.00 5945321.88 696232.46 184.05 12.00 90.05 MWD 11050.00 90.19 106.20 8976.83 -3114.89 -2087.82 5945316.17 696256.80 207.18 12.00 90.06 MWD 11075.00 90.19 109.20 8976.75 -3122.49 -2064.01 5945309.21 696280.80 230.77 12.00 90.07 MWD 11100.00 90.18 112.20 8976.67 -3131.32 -2040.62 5945300.99 696304.41 254.76 12.00 90.08 MWD 11124.42 90.18 115.13 8976.60 -3141.12 -2018.26 5945291.78 696327.02 278.52 12.00 90.09 11 11125.00 90.18 115.06 8976.59 -3141.37 -2017.73 5945291.55 696327.56 279.09 11.96 270.00 MWD 11150.00 90.18 112.06 8976.52 -3151.36 -1994.82 5945282.17 696350.72 303.40 12.00 270.00 MWD 11175.00 90.18 109.06 8976.44 -3160.13 -1971.41 5945274.01 696374.35 327.38 12.00 269.99 MWD 11200.00 90.17 106.06 8976.37 -3167.67 -1947.58 5945267.10 696398.37 350.95 12.00 269.98 MWD 11225.00 90.17 103.06 8976.29 -3173.96 -1923.39 5945261.46 696422.72 374.05 12.00 269.97 MWD 11250.00 90.17 100.06 8976.22 -3178.96 -1898.90 5945257.10 696447.34 396.62 12.00 269.96 MWD 11275.00 90.17 97.06 8976.14 -3182.68 -1874.18 5945254.03 696472.14 418.60 12.00 269.95 MWD 11300.00 90.16 94.06 8976.07 -3185.10 -1849.30 5945252.27 696497.08 439.93 12.00 269.95 MWD 11324.42 90.16 91.13 8976.00 -3186.21 -1824.91 5945251.81 696521.49 460.07 12.00 269.94 12 11325.00 90.16 91.20 8976.00 -3186.22 -1824.33 5945251.81 696522.07 460.54 11.96 90.00 MWD 11350.00 90.16 94.20 8975.93 -3187.40 -1799.36 5945251.29 696547.06 481.19 12.00 90.00 MWD 11375.00 90.16 97.20 8975.86 -3189.88 -1774.48 5945249.47 696571.99 502.55 12.00 90.01 MWD 11400.00 90.16 100.20 8975.79 -3193.65 -1749.77 5945246.34 696596.79 524.56 12.00 90.02 MWD Company: BP Amoco Field: ,,' Pruc\hoe Bay Site: ' '" PBD$ 05 :::,' Well:, 05~41' "',' " m'Yellpa~þ: Plån#6 0$-41A: Survey \11) ft 11424.42 11425.00 11450.00 11475.00 11500.00 11525.00 11550.00 11575.00 11600.00 11625.00 11650.00 11675.00 11689.42 11700.00 11725.00 11750.00 11764.42 11775.00 11800.00 11814.42 11825.00 11850.00 11875.00 11900.00 11925.00 11950.00 11975.00 .. .,.-".--.-..,-...--.....,.,.,. I lie! deg 90.16 90.16 90.24 90.32 90.39 90.47 90.54 90.61 90.69 90.76 90.82 90.89 90.92 91.74 93.67 95.59 96.69 95.42 92.42 90.69 90.47 89.95 89.42 88.90 88.39 87.87 87.37 ¡\~i ß deg 103.13 103.20 106.19 109.19 112.19 115.19 118.19 121.19 124.19 127.19 130.19 133.19 134.92 135.89 138.19 140.51 141.85 141.85 141.85 141.85 143.10 146.05 149.01 151.96 154.92 157.88 160.83 e BP-GDB e Baker Hughes INTEQ Planning Report .._".,-----_........ s~s TVI) ft 8975.72 8975.72 8975.63 8975.51 8975.36 8975.17 8974.95 8974.70 8974.41 8974.10 8973.75 8973.38 8973.15 8972.91 8971.73 8969.71 8968.17 8967.06 8965.35 8964.96 8964.85 8964.76 8964.90 8965.26 8965.85 8966.67 8967.71 :\/S ft -3198.59 -3198.72 -3205.06 -3212.66 -3221.49 -3231.54 -3242.76 -3255.14 -3268.64 -3283.23 -3298.85 -3315.47 -3325.50 -3333.03 -3351.30 -3370.21 -3381.38 -3389.65 -3409.26 -3420.60 -3428.99 -3449.36 -3470.44 -3492.20 -3514.55 -3537.44 -3560.81 m , .. . . Date: 8/25/2003, Time:.: 11:36:30 '. Page:;;' 4 Co-ordinate(NE) Reference: 'Well: 05-41, True "'drth ,V~r~çal (TVD) Reference: System: Mean Sea Level "":'m,":,~ç~¡j~ (VS) Reference: 'Well (0:00N,0.00E,127.00Azi) ,,:::':'::::::,::::::::SUryëy Calculation Method: Minimum Curvature Db: Oracle . ......".,--.-,-.-. .--... t:/W ft -1725.86 -1725.29 -1701.12 -1677.30 -1653.92 -1631.03 -1608.69 -1586.98 -1565.94 -1545.64 -1526.13 -1507.47 -1497.10 -1489.68 -1472.66 -1456.43 -1447.44 -1440.95 -1425.54 -1416.63 -1410.19 -1395.70 -1382.28 -1369.97 -1358.79 -1348.79 -1339.98 :\Iap:\ ft 5945242.04 5945241.92 5945236.22 5945229.25 5945221.04 5945211.60 5945200.97 5945189.16 5945176.22 5945162.18 5945147.08 5945130.95 5945121.20 5945113.87 5945096.05 5945077.59 5945066.66 5945058.56 5945039.36 5945028.26 5945020.05 5945000.07 5944979.34 5944957.92 5944935.87 5944913.25 5944890.12 \1apE ft 696620.82 696621.39 696645.72 696669.73 696693.34 696716.48 696739.10 696761.13 696782.52 696803.19 696823.11 696842.20 696852.82 696860.44 696877.93 696894.66 696903.94 696910.65 696926.57 696935.77 696942.43 696957.45 696971.42 696984.30 696996.06 697006.66 697016.08 vs ft 546.63 547.16 570.28 593.87 617.87 642.19 666.78 691.58 716.50 741.49 766.47 791.38 805.69 816.16 840.74 865.08 878.98 889.15 913.26 927.19 937.39 961.22 984.63 1007.55 1029.93 1051.69 1072.79 I)I.S deg/1000 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 T I'() deg 90.03 88.50 88.50 88.51 88.66 88.69 88.74 88.78 50.00 50.02 50.13 50.32 180.00 180.00 180.00 100.00 100.01 100.02 100.01 Tool 13 MWD MWD MWD 88.53 88.54 88.57 88.59 88.62 MWD MWD MWD MWD MWD MWD MWD MWD 14 MWD MWD MWD 15 MWD MWD 16 MWD MWD MWD MWD 99.96 MWD 99.89 MWD 99.80 TO e Nordic 1 slim hole e All Measurements are from top of Riser 10/8/2003 I 30... Q) en .- cr I top of bag ·111 II i Ii r ~ . - Schlumberger BAG I 7 1/16" 5000psi bttm of bag 'I I r middle of slips Blind/Shears ........................ I I TOTs middle of pipes I 2" combi ram/sliDs L.............········· 7 1/16" 5000psi 0 I I 0 middle of flow cross Mud Cross Mud Cross 71/16" 5000psi I I r middle of blind/shears 2 3/8" ram ........................ I I TOTs middle of pipelslips 2" combi ram/sliDs L.............········· 7 1/16" 5000psi Flow Tee POS'5146 DATE 8/22/2003 INV# PR082003H IIWOICE / CREDIT MEMO DESCRIPTION 8/22/2003 DATE CHECK NO. PERMIT TO DRILL FEE GROSS VENDOR DISCOUNT 055146 NET OS-Lf if} H BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT Po BOX 196612 ANCHORAGS, AK995J9-6612 RECEIVE ' OCT' {) 9 Oil & Gas Cons. Go AI ska Anchorage nissiOì1 THE ATrACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. flATIONAl CITY8A.NK AShland, Ohio CONSOLIDATED COMMERCIAL ACCOUNT No. P 055146 ~ 412 PAY: TO THE ORDER OF: OIL & GAS 333 W 7TH AVENüE SUITE 100 ANCHORA,ØE;, AK Q9501~3539 8 P fi.'; ¡,.. ,11111/ ,1fI1I1 . . ~ .:J",f., t'II../ Itlll., '"'''' 1/'055 ... "'~ 1:0... W 38 'IS,: O. ¿ 18'1 ..Ie AIj!llisti{2i;::>oq~: ... .......$ ÓO.OO'" .... . NOft:1 ...L~~·~?:~··~r.·~:~~"""'''~i~:"::' ,:':" J, : '\'. '::'..:.::', ..:~\.::~...., ..;" .... "':';"'. '~':" ';:';'.:;'.--. ::'; .. ....:.... -4, ~ ....-......'..Ar..._"........, ""'~ ......... ,....,.. ............... ./ .... "''¡~'' ~.." ,... ..., . . :Ii' .. . ...... "¡,¡" -....---..... '.. .:.::: .'. ',:. .:...:. 7,'.'(, 'x, ..:.;. ...:~ ...~. .>;.. ..:.:. .:~ t· .....-....... ...................................... ". . I·... _::.' :'. :'..., "" ;'.. "'. ,'..,. ., . .~-~~ AMOUNT e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing weD ~ Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE 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). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT 05-41 A Program DEV Well bore seg D PTD#: 2031700 Field & Pool PRUDHOE BAY. PRUDHOE OIL - 640150 nitial ClasslType DEV /1-0IL GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal D Administration P~(mitfee attache.d_ . - - - - - - - - - - Y~s - - - -- 2 _Leas~ _numberappropriale _ _ . Yes 3 _Uniqueweltn_am~_a!1d Ollmb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - Y~s - - - + - - - - - - - - - - - - - - - - - 4 WeU JQcat~d In_a defil1e.dpool_ - - - - - - - - Yes - - - - - - - - -- 5 WeJIJQcat~d pr_oper _distance_ from driJling ul1itb.oul1d_ary_ _ Yß$ - - - - - 6 WeJI JQcat~d proper _distance from other wells_ _ _ . Y~s - - - - - - - - - 7 _S_utficiel1t _acreageayailable in_ dJilIiog unjt. - - - - - -- Y~s - - - -- 8 Jf.d~viated, js weJlbQre platil1cJu_ded . - - - -- - - - - _ Yßs - - - - - - 9 _Ope(ator only: affected party _ _ _ _ . . - - - - - - - - - - - - - - _ No_ - - - - 10 _Ope(ator has.appropriate_b.o!1d inJQrce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s . - - - - - - - - - - - - - - - - - - ~ - 11 P~rmit Qa!1 be lsslIed withQut co_nservaJion order. . _ _ . . _ _ _ . _ Yßs - - - - Appr Date 12 P~(mit c_ao be lSSl!ed withQut ad_mil1ist(atille_approvaJ _ _ _ Yßs - - - -- - - - - - - RPC 10/9/2003 13 Can permit be approved before 15-day wait Yes 14 Well JQcated wlthin area and_strata _authQrlzed by_l!1jectioo Ordß( # (PullO# in_ c.omm~ots)_ (For. NA - - - - tt 15 _AJI welJs_wit.htnJl4_l1Jile_area_of reyiew id~otifjed (FO( s.ervjc_e_w.e!l only). _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - - - - - - - - - - - - - - - - - - - - 16 Pre-produced iojectQr; .duratiQn_of pre-pro.ductiol) Ißs$. than_ 3 months_ (For_ser:vice well on!y) _ . NA - - - - - - 17 ACMP_ finding.of Con_stste!1cy_h_as bee_n issued_ for this p(oject - - - - - - - - - - - - - NA - - -- - - - - - Engineering 18 C_o!1ductor st(ing_pJQvided _ _ _ _ _ _ _ - - - - - - - - -- - - - - -- ____ _ ____NA - - - - 19 _S_uúace_casil1g_pJotect$. alLknown USQWs _ - - - - -- - - - - - _NA - - - - 20 CMTvotadeQu_ateJo Circul;ale_oncOl)d_uctor& SUJtq>g _ . - - - - - - - - - - - - - - - NA - - - - - - - - -- 21 _CMT vol adeQl!ateJo tie-tnJQng _striog to_suú cs.g_ _ _ _ _ _ - - - - -- - - - -- __NA - - - - - - - - - - -- 22 _GMT will Coyer.aJl kl)ow.n pro_ductiye hQrizon_s _ _ _ _ _ _ . . - - - - - - - - - - - - YßS - - - - 23 _C_asiog desig!1s ade( uale fo( C,,T, B _&_ perl1JafLost _ _ .. _ _ _ Yß$ 24 AdequateJan_kage_oJ re_ser:ve pit _ _ . _ _ _ . - - - - - - - - - . - - - . - _Y~S CTQU. _ _._ 25 Jta_re-driIL has_a_ 10.-403 fQr abandonment be~o apPJoved _ _ . - - - - - - - . . _ _ . .Yßs 101Q9/2_003._ _ _ _ _ . _ _ . 26 Adequatewellbore s.eparatio_n_proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _YßS - - - - - - - - - - - - - - - - - - -- 27 Jfdiverter Jeq_uired, dQeß it meet regulations_ _ _ . _ _ _ . . - - - - - - - - - - NA Sidet(ack. . - - - -- Appr Date 28 DJiUiog f!uid_ program schematic_& equip Jistadequatß _ __c - - - - -- ___________Xes Max MW_8, I ppg. WGA 10/10/2003 29 _BOPEs,_dothey meelreguJation _ _ _ _ - - - - - - .. _ _. YßS - - - - - - - - - - - - - 30 _BOP_E_pressratiog app(op(iate; Jestto(pul psig in_comments)_ _ . _ _ _ _ - - - -- _ _ _. _ Yes Test t~_35QO psi.MS~ 2194 psi._ e 31 C_hokemanifold complies_ wIAPtRF>-53. (May 64) . _ _ _ . - - - - - . _ Yßs 32 WQrk will OCc_U( withoutoperation_shutdown_ _ _ _ . - - - - - - -- _ _ _ _ _ _ Yßs 33 .Is pres_ence_ oJ H2$ gas_ prob_able _ _ . - - - - -- - - - - - - - -- - - - -- _ _ _ . _ No_ 34 Mecba_nlcaLcoodjtloo of wells wtthil1 80B. yerified (for_service welJ onJy) _ . NA Geology 35 P~rmit c_ao be lSSl!ed wlo_ hyÇ (ogen_ s_ulfide meas_u(es . - - - - - - - - - _ _ _ _ No_ 36 _D_ata_PJesented on pote_ntial oveJpres_sure _zones _ _ _ - - - - -- - - - - - - - - - - _NA Appr Date 37 S~tsmicanalysjs_ Qf ßballow gas_zooes_ NA - - - - - - - - - - - - - - - - - -- - - - - RPC 10/9/2003 38 _S~abed _conditioo survey (if off-sh_ore) . _ _ _ _ _ _ _ NA - - - - - - - - - - - 39 . CQnta_ct nam_elp!1QneJorweekly progress_reports [e¡cploratoryonlyl - - - - - NA Geologic Date: Engineering Date P,.", J1l ~ Commissioner Commissioner: Comm"','ooe, $ ~ IJI'CP /0/1-310 ~ "- .'\~ ~lv LvrJ e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, 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 Drtlting Services LIS Scan Utility e :<03-/70 (2,~ :5~ $Revision: 3 $ LisLib $Revision: 4 $ Wed Aug 18 15:15:10 2004 Reel Header Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/08/18 Origin.................. .STS Reel Name....... ........ . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments........ ........ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/08/18 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 5-41A 500292269601 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 18-AUG-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002860046 P. SMITH EGBIJIMBA/WH MWD RUN 2 MW0002860046 P. SMITH EGBIJIMBA/WH MWD RUN 3 MW0002860046 P. SMITH EGBIJIMBA/WH # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 32 llN 15E 2291 4103 72.43 34.30 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.250 7.000 9700.0 RECEIVED SEP 0 2; 2004 # Alaska Oil & Gas Cons. Comm~n. Anchorage REMARKS: e e 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 5-41 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 10002'MD/8979'TVDSS¡ THE BOTTOM WAS AT 10007'MD/8979'TVD. 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL¡ DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN ON 21 JANUARY 2004. THESE LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 17 AUGUST 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 - 3 REPRESENT WELL 5-41A WITH API#: 50-029-22696-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11956'MD/8977'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. RESISTIVITY ( EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP $ File Header Service name.. .......... .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/08/18 Maximum Physical Record. .65535 File Type......... ...... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 9784 . 5 9985.0 9985.0 9985.0 STOP DEPTH 11908.0 11921.5 11921. 5 11921. 5 RPS RPX ROP $ 9985._ 9985.0 10022.5 e 11921.5 11921. 5 11952.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH 9784.5 9794.0 9796.5 9798.5 9800.5 9805.5 9818.5 9976.0 9978.5 10003.0 10016.0 10032.0 10043.0 10061.0 10071.5 10085.5 10104.0 10115.5 10144.0 10162.0 10172.5 10180.5 10202.0 10224.0 10237.0 10257.5 10263.0 10283.0 10295.0 10311.5 10320.5 10324.5 10328.5 10365.5 10373.0 10377.5 10399.5 10416.0 10429.5 10454.5 10467.0 10486.0 10553.0 10560.0 10610.0 10619.0 10634.5 10638.5 10649.0 10662.0 10670.5 10720.0 10741.0 10794.0 10818.5 10826.0 10827.5 10864.5 10867.5 GR 9794.5 9804.0 9806.5 9807.5 9810.5 9815.5 9825.0 9982.0 9984.5 10007.0 10018.0 10033.5 10045.5 10061.0 10072.5 10087.5 10104.5 10118.5 10150.5 10170.5 10181.5 10189.5 10211.0 10229.0 10245.0 10265.5 10275.0 10292.5 10303.0 10321.5 10330.5 10337.0 10339.5 10378.5 10384.0 10389.5 10407.5 10427.5 10443.5 10469.0 10482.5 10500.5 10567.0 10575.5 10627.0 10634.5 10650.5 10656.0 10669.5 10682.0 10690.0 10741.5 10761.0 10812.5 10834.0 10842.0 10843.5 10877.5 10880.0 10874.5 10879.0 10883.0 10891.0 10898.0 10920.0 10949.0 10970.5 10980.0 10995.0 10999.5 11005.0 11020.5 11038.0 11040.0 11068.0 11081.0 11086.5 11105.5 11115.5 11136.0 11138.5 11148.5 11176.0 11180.0 11182.0 11200.0 11206.0 11221. 0 11225.5 11233.5 11251.0 11259.5 11267.5 11285.5 11294.5 11304.5 11393.0 11394.5 11414.5 11426.5 11437.0 11440.5 11458.0 11471.0 11479.5 11484.0 11491.0 11501.5 11511.5 11516.5 11521. 5 11531.5 11541.0 11551.0 11553.5 11557.0 11583.5 11585.5 11595.5 11599.5 11607.5 11623.5 11641. 5 11662.0 11679.5 11690.0 11699.5 10885._ 10887.5 10890.5 10899.5 10907.0 10926.0 10956.0 10978.0 10988.5 11002.5 11007.0 11011. 5 11028.0 11045.5 11046.5 11077.0 11088.5 11094.0 11113.0 11121.0 11144.0 11145.0 11156.0 11182.5 11187.5 11189.5 11210.5 11215.5 11228.0 11234.0 11240.5 11260.0 11269.5 11276.0 11292.5 11304.5 11315.0 11402.0 11403.5 11423.5 11436.5 11451.0 11455.0 11472.0 11482.0 11493.5 11497.5 11505.0 11513.5 11522.0 11528.5 11535.0 11544.5 11552.0 11561.0 11562.5 11566.5 11593.0 11594.5 11604.5 11608.0 11618.5 11634.5 11652.0 11672 .5 11686.5 11697.0 11706.5 e 11732.5 11746.5 11763.0 11776.5 11779.5 11799.5 11815.5 11824.5 11952.5 $ 11738._ 11753.5 11772.5 11786.0 11788.0 11805.0 11819.5 11827.5 11955.5 e # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 9794.5 10260.0 11254.0 MERGE BASE 10260.0 11254.0 11955.5 # 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 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9784 .5 11952.5 10868.5 4337 9784.5 11952.5 ROP MWD FT/H 0.4 1201.19 77.9648 3861 10022.5 11952.5 GR MWD API 17.07 255.67 61. 0639 3950 9784.5 11908 RPX MWD OHMM 1.12 1917.6 14.6184 3874 9985 11921.5 RPS MWD OHMM 3.12 2000 22.8911 3874 9985 11921.5 RPM MWD OHMM 0.15 2000 24.6398 3874 9985 11921.5 RPD MWD OHMM 0.09 2000 27.0821 3874 9985 11921. 5 FET MWD HOUR 0.28 16.61 2.37196 3874 9985 11921.5 First Reading For Entire File......... .9784.5 Last Reading For Entire File.......... .11952.5 File Trailer Service name..... .... ....STSLIB.001 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .04/08/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... . 4IÞSLIB. 002 e Physical EOF File Header Service name... ...... ....STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/08/18 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 RPD RPM RPS RPX FET ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 9794.5 9990.5 9990.5 9990.5 9990.5 9990.5 10024.5 STOP DEPTH 10214.5 10228.5 10228.5 10228.5 10228.5 10228.5 10260.0 # 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: 15-JAN-04 Insite 4.3 Memory 10260.0 10024.0 10260.0 84.4 92.5 # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 TOOL NUMBER 78012 178425 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.250 9700.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: Flo Pro 8.60 65.0 9.1 23000 5.8 .200 .105 65.0 130.0 MUD FILTRATE AT MT~ MUD CAKE AT MT: .220 .220 .0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing............ ........ .60 .1IN Max frames per record. ........... .Undefined Absent value.......... .... .... ....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9794.5 10260 10027.3 932 9794.5 10260 ROP MWD010 FT/H 1. 02 178.28 49.6836 472 10024.5 10260 GR MWD010 API 17.07 92.12 61.1379 544 9794.5 10214.5 RPX MWD010 OHMM 1.12 1917.6 24.5304 477 9990.5 10228.5 RPS MWD010 OHMM 6.29 2000 81.9461 477 9990.5 10228.5 RPM MWD010 OHMM 0.15 2000 91.8291 477 9990.5 10228.5 RPD MWD010 OHMM 0.09 2000 93.2604 477 9990.5 10228.5 FET MWD010 HOUR 0.63 9.18 2.61964 477 9990.5 10228.5 First Reading For Entire File....... ...9794.5 Last Reading For Entire File. ......... .10260 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/08/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name.......... ..4ItSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/08/18 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 GR FET RPD RPM RPS RPX ROP $ 3 e header data for each bit run in separate files. 2 .5000 START DEPTH 10215.0 10229.0 10229.0 10229.0 10229.0 10229.0 10260.5 STOP DEPTH 11207.5 11210.0 11210.0 11210.0 11210.0 11210.0 11254.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTRO MAG. RES IS. 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): 17-JAN-04 Insite 4.3 Memory 11254.0 10260.0 11254.0 87.3 93.3 TOOL NUMBER 78012 178425 3.750 9700.0 Flo Pro 8.60 65.0 9.2 22500 7.0 .180 .087 .240 .170 68.0 148.5 68.0 68.0 # e e 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 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10215 11254 10734.5 2079 10215 11254 ROP MWD020 FT/H 1.48 1201.19 81.2357 1988 10260.5 11254 GR MWD020 API 27.26 255.67 69.7821 1986 10215 11207.5 RPX MWD020 OHMM 3.13 32.93 11.3257 1963 10229 11210 RPS MWD020 OHMM 3.12 30.6 11.7733 1963 10229 11210 RPM MWD020 OHMM 3.2 29.52 12.2403 1963 10229 11210 RPD MWD020 OHMM 5.01 29.53 13.3324 1963 10229 11210 FET MWD020 HOUR 0.28 6.43 1. 2921 1963 10229 11210 First Reading For Entire File...... ... .10215 Last Reading For Entire File....... ... .11254 File Trailer Service name........ .... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/08/18 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...... .04/08/18 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 e Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 e header data for each bit run in separate files. 3 .5000 START DEPTH 11208.0 11210.5 11210.5 11210.5 11210.5 11210.5 11254.5 STOP DEPTH 11911 . 0 11924.5 11924.5 11924.5 11924.5 11924.5 11955.5 # 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 GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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: $ # 20-JAN-04 Insite 4.3 Memory 11956.0 11254.0 11956.0 87.3 94.9 TOOL NUMBER 93091 178425 3.750 9700.0 Flo Pro 8.60 65.0 9.0 22500 6.6 .170 .084 .160 .130 75.0 159.7 75.0 75.0 Data Format Specification Riltrd Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing. ..... .............. .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11208 11955.5 11581.8 1496 11208 11955.5 ROP MWD030 FT/H 0.4 1059.3 80.2907 1403 11254.5 11955.5 GR MWD030 API 21. 24 186.81 48.7308 1407 11208 11911 RPX MWD030 OHMM 4.78 32.83 15.2387 1429 11210.5 11924.5 RPS MWD030 OHMM 4.32 37.89 16.6247 1429 11210.5 11924.5 RPM MWD030 OHMM 4.38 51.03 17.6336 1429 11210.5 11924.5 RPD MWD030 OHMM 6.61 65.09 21.0249 1429 11210.5 11924.5 FET MWD030 HOUR 0.37 16.61 3.72124 1429 11210.5 11924.5 First Reading For Entire File......... .11208 Last Reading For Entire File.......... .11955.5 File Trailer Service name........ .... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/08/18 Maximum Physical Record. .65535 File Type.......... ..... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/08/18 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.................... .04/08/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name......... .~OWN 4IÞ Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
