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201-238
lIT je Project Well History File CO\¡ JPage 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. é]"Ol-~~ Well History File Identifier Organizing 1""11"\ RESCAN 0 Two-Sided 0 Rescan Needed 0 Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: DIGITAL DATA vzt' Diskettes. No. I OVERSIZED (Scannable) 0 Maps: 0 Other. Norrype 0 Other items scannable by large scanner OVERSIZED (Non-Scannable) 0 Logs of various kinds NOTES: B'(: BEVERL'( ROBIN VINCENT SHER (L~ARI.0vIf~OY 0 Other DATE:q%/df 151 VV1f Project Proofing Scanning Preparation / x 30 = -3 0 + DATE:LfIs/ 6,/-/51 l3 = TOTAL PAGES DAlE LJ/s!ClfS, WlP ~ vnp 8'(, BEVERL'( ROBltJ VINCENT SHERY~A::;)wINDY BY BEVERl Y ROBIN VINCENT SHER'(~It~O ( Production Scanning B'(: PAGE COUNT FROM SCANNED FILE: Lr:~3 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION:, : ~ES - NO BEVERL'( ROB'N VINCENT SHER'(Ð,ND" DATE:<! ~ Dtf 151 \ /'VI P IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO Stage 1 Stage 2 BY: BEVERlo( ROBIN VINCENT SHER'(l MARIA WIND'( DATE, IS/ (SCAP,'IIrIG IS COMPlE IE A T THIS pOlm urJlESS SPECiAl AT IENTlON IS REQUIRED Ot AN IrJDIVlDUAl PAGE BASIS DuE TO QUAl/IY, GRAYSCALE OR COLOR IMAGES) ReScanned '11'.'" ..I,' ;/ "''1 . I ',I'" - .',11 ~II, IIII',n} ',' ,""""'J ''i!JI!J)/''f,'(/ RESCANNED BO(: BEVERLY ROBIN VINCENT SHERYL MARIA WINDo( DATE: IS/ General Noles or Comments about Ihis file: Quality Checked ,,1',,11 I 12/10/02Rev.3~ OTSc..3nn"3d wf)d OPERABLE: Producer L -104 (PTD #1,2380) Tubing Integrity Restored • Page 1 ‹ ,(2._ Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] ,� (6(Zslit � Sent: Saturday, August 13, 2011 10:40 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Reynolds, Charles (ALASKA); Oakley, Ray (PRA) Subject: OPERABLE: Producer L -104 (PTD #2012380) Tubing Integrity Restored All, Producer L -104 (PTD #2012380) passed a TIFL on 08/12/2011 after the orifice gas lift valve was changed out. The passing TIFL verifies tubing integrity and the well has been reclassified as Operable. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Saturday, July 30, 2011 2:18 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Da el, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SO IONS LLC) Subject: UNDER EVALUATION: Producer L -104 (PTD #2012380) Evaluate for IA Communication All, Producer L -104 (PTD # 2012380) was found to have T IA communication during the proration from July 15 -18. The well failed a cold TIFL on 07/26/2011. T' e well is reclassified as Under Evaluation. The well maybe brought online to continue diagnostic oper- ons. Plan forward: 1. DHD: TIFL well with well online 2. WIE: Depending on results of TIFL, ev- uate well for mechanical integrity test A TIO plot and wellbore schematic h- e been included for reference. « File: Producer L -104 (PTD #20 380) TIO Plot.doc » Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator 8/25/2011 UNDER EVALUATION: Producer L -(PTD #2012380) Evaluate for TxIA runication Page 1 of 3 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] ` ��r y e.) Z/l( Sent: Tuesday, August 02, 2011 8:45 AM To: Regg, James B (DOA) Subject: FW: L -104 casing specs. for 5.5" 15.5 ppf L -80 Attachments: 2375_001. pdf Jim, Here is a scanned copy of the Baker Tech book with the 5.5" 15.5 ppf N -80 data from the Baker Tech facts which gives the min. internal yield as 7000 psi. Please see Andrea's response below. Is this adequate, or will you need more? A 0 3 2011 Jerry Murphy ` BPXA Well Integrity Coordinator From: Hughes, Andrea Sent: Tuesday, August 02, 2011 8:17 AM To: AK, D &C Well Integrity Coordinator Subject: RE: L -104 casing specs. for 5.5" 15.5 ppf L -80 Jerry, I found a copy of the Baker Tech Facts and have attached a scanned copy of the page for you. For all practical purposes L -80 and N -80 have the same burst/collapse pressure, but L -80 is better suited for H2S service. Let me now i is isn't what you were looking for. --- Thanks, Andrea Hughes From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, August 01, 2011 4:28 PM To: AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: Producer L -104 (PTD #2012380) Evaluate for TxIA Communication 5.5" L80 15.5ppf casing does not show up in any of my resources; do you have a published min. internal -- yield pressure? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, July 30, 2011 2:18 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; 8/2/2011 UNDER EVALUATION: Producer L -(PTD #2012380) Evaluate for TxIA c,munication Page 2 of 3 , Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer L -104 (PTD #2012380) Evaluate for TxIA Communication All, Producer L -104 (PTD # 2012380) was found to have TxIA communication during the proration from July 15 -18. The well failed a cold TIFL on 07 1 The well is reclassified as Under Evaluation. The well maybe brought online to continue dia• • c operations. Plan forward: 1. DHD: TIFL well with well online 2. WIE: Depending on results of TIFL, evaluate well for mechanical integrity test A TIO plot and wellbore schematic have been included for reference. «Producer L -104 (PTD #2012380) TIO Plot.doc» «L -104 (PTD #2012380) wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, July 18, 2011 3:53 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (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 0 &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 sustained 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 #2031700) P1 -04 (PTD #1930630) L -104 (PTD #2012380) V -04 (PTD #2061340) V -103 (PTD #2021860) W -36 (PTD #1881060) Y -04 (PTD #1791050) 8/2/2011 UNDER EVALUATION: Producer L (PTD #2012380) Evaluate for TxIA emunication Page 3 of 3 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 Well Integrity Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator @BP.com 8/2/2011 Page 6.18 Page 6 -19 Dimensional Data and Minimum Dimensional Data and Minimum Performance Properties of Casing Performance Properties of Casing Coining or Joint 0D I Col• Internal Yield Pressure (psi)" Joint Yield Strength (10 lb)" Wall __. Thick. Drill Round or Bored Grade Resis- Plain End Round Thread i d Coupled Threaded 00 ) Weight noes ID Die I Buttress Other Pin ID lance or Buttress Strength "`Round Thread I Other' ((n.) 1 9/419 (91.) (in.) (In,) M.) (I (II) )I ) Extreme short Long Thread (100018) (mm) ( (18111) 1 (mm) ' (mm) (mm) (mm) (mm) {m Line Shod Long 5713(23) , /45.1 5.500(8)(25) 1397 6.050(27) 153.7 6043 {30) - 153.5 3'55 4,040 4,610 4,810 4,810 4,810 248 202 217 230(23) 229(7) 122(25) 5.750(1) 4,890(25) 130(8) 248 {9a} 248(98) } K'55 4,040 4,810 4,810 4,610 4,810 248 222 239 248(9) 236(8) 1 229(7) €48,1 291(23) 248(9a,b) 248(30,27) 4.825 5.900(4) 1 4,8701)70(1) (4} 248(2831) 130(6) 122(25) 153)2 1 189,8(9) : 1237 15 .275 4,950 6.050 6.000(7) 4,870 C - 4.960 6.560 339 339(90) 294(1) 5.98 125.7 1182 ' 153.7 152.4 123.18 N 80 75 4,990 7,000 362 361(9a) 421(4) 361(2728) 5.12 1 5.860(10) 4 9,620 497 497(9 827) 497{28,31) 332)7) • 488 1205 P' 5,620 199.7 5.862(17) 495017) iii I 148.9 125 f 6.051{98)(31) j ( 153,7 8.075(9a) 1 i 'r. 154,3 5. 905{28) )508 _., ....... _,_..„ . , __ -._,, 5.500(8,251 1392 6.043(30) 6. 4 27 J 55 4,910 5,320 5320 5320 5320 273 229 247 ' 262(23) 253(7) � 143(8) ( 144 {25) 273(90) 213(98) 1 5. I 6.55 4,910 5320 5,320 5.320 5,320 273 252 272 273(9) 332 {23) 339(21) 143(8) 144(25) 273)94,9) 1422 273(3027) 253(7) 273(28,31) 5.761(23) 0.75 6.070 7,250 7,250 7,250 372 327 259(8) 337((1) 242(9e) ) ( 5.781(1) 4.8190) 372(9a) 379b) 4 R -00 6,280 7, 3 740 7,740 7,740 397 348 273(8) 355(1) 350(23) 5. 4,81 57(21 36817) 258c) 4.767 499 222 209(8) ) 219(25) 39 17.0 304 4992 121, 8.050 6,0 {7) 4,817(8,23) 397(98) 397(27) 397(28) 772 24.3 4.653 537 1524 12 4 C -95 6;9 30 9,190 9,190 9,160 i 471 374 287(8) 307(23) 375 (21) (10) ( 5.500(8625) 6.056(9) 4.711 037(7) 268(90) 248(8) 118,2 139,7 1537 027 250(25) 471(9a) 471(98) 5.860(19) 4.892(7) P•119 7880 (0,640 16.840 10.640 546 445 562(x) 444(1} 437 {23) 124.3 - 446(21) 506(7) 287(8) ( 5, 8 0 21 8 7) 4.817(25) 319(90) 289(25) 546(90,8) 546(30,22) 546(28)(31) 546(27) 1489 122'4 11.150 8300 14,510 744 736(19) 744(90,8) 408(90 6.075 691(7) 391(8) 394(25) 1 6,051(6b.31) i 5.953(28) - . 1512 I ., ,r3 4'' r t ,� ' ate, : , : . r L� 4 ., r., �,'s,., q v x: ", tom s, € 'e` ? d 4 y,�'� -.,,� * �� v: { ,� iy �, i . 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' v r .% PBU L -104 PTD #2012380 7/30/2011 TIO Pressures Plot Well: L -104 4,000 J i 3.000 • -;- T6g —U- IA 2,000 —4-- OA 00A -4--- 0 00A On 1,000 04/30/11 05/07/11 05/14/11 05/21/11 05/28/11 06/04/11 06/11/11 06/18/11 06/25/11 07/02/11 07/09/11 07/16/11 07/23/11 07/30/11 • TREE = 3-1/8" 5M CM/ • SAFETY NOT• WELLHEAD = 11" FMC ACTUATOR = L 04 K. ELEV = 24' BE ELEV =79' KOP = 1032' Max Angle = 64 @ 3205' Datum MD = 9969' Datum - ND = 6600' SS I I 1892' H3-1/2" HES X NIPPLE, D= 2.813 I 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 1--1 3015' 1--- Minimum ID = 2.813" @ 1892' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3-1/2" HES X NIPPLE L I 7 2061 2011 27 KBG2-9 DMY INTO 0 01/12/05 6 3027 2655 62 KBG2-9 DOME INTO 16 11/01/07 5 4561 3399 57 KBG2-9 DMY INTO 0 01/12/05 4 5937 4095 59 KBG2-9 DOME INTG 16 11/01/07 3 7298 4808 57 KBG2-9 DOME INTO 16 11/01/07 2 8550 5496 49 KBG2-9 DOME INTG 16 11/01/07 1 9566 6297 23 KBG2-9 SO INTG 22 11/01/07 I F HES X NIP, ID = 2.813" 1 13-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" H 9661' 1 I 9640' 1_4 BKR LOC SEAL ASSY, ID = 3.00" I 1 5-1/2" CSG, 15,5#, L-80, OTC, ID = 4.950" H 9661' 1 1 I 9642' H TOP OF BKR PBR, ID = 4.00" 1 AID - 7000 15-1/2" X 3-1/2" X0 H 9661' 1--- 9658' I_IBTM OF 4" BKR SEAL ASSY, ID = 3.00" 1 9691' 1-13-1/2" HES X NIP, ID = 2.813"1 PERFORATION SUMMARY 9711' H3-1/2" HES X NIP, ID = 2.813" 1 REF LOG: SCMT ON 02/11/02 ANGLE AT TOP PERE: 16 @ 9860' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE L 9811' I-115' PUP JT W/ RA TAG1 2-1/2" 6 9860 - 9900 0 02/27/01 1 10035' H15' PUP JT W/ RA TAG1 AN, I ??? H FISH (IWO SS BANDS) 1 1 PBTD (ELM) H 10245' ry " 4 13-1/2" CSG, 9.2#, L-80, NSCT, ID = 2.992" H 10391' DATE REV BY COMMENTS - DATE REV BY COMMENTS BOREALIS UNIT 01/30102 DAC/KK ORIGINAL COMPLETION 11/01/07 DAV/TLHGLV C/O WELL: L-104 01/14/05 JC/PJC RWO PERMIT No: 2012380 02/28/01 TMN/KK PERFS & PBTD CORRECTION API No: 50-029-23060-00 04/08/03 DRS/TP TVD/MD CORRECTIONS SEC 34, T12N, R11E 2425' NSL & 3529' WEL 10/01/07 JJL/TLH PLUG PULLED 9/16/06 10/14/07 KSB/SV GLV C/O 10/09/07 BP Exploration (Alaska) Producers with sustained casing pressuon IA during proration • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @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 sustained casing pressure on the IA during the proration and shutdown activity July 15 -18. The immediate action is to perform m 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 #2031700) P1 -04 PT' c 930630 L -104 (PTD #2012380 V -04 (PTD #2061340) V -103 (PTD #2021860) ` " ' W JUL E t 201 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 Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 7/19/2011 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99515-6612 August 14, 2009 ~.~,~'4~~~~~ ~f;l ~~ `~; ;y ~~vJ bp ~~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T 0~ 2009 ~-iss~Ca ~ii ~ Gas Cans. Camr~ission Anchorage a,al` ~-3~ ~~ ~a~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~ Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploretion (Alaska ) Inc. Surtace Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10~04) 1 o~P L pad B/13/2009 Well Name PTD # API # Inftial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbis ft na al L-01 2p10720 50029230110000 NA 6 NA 612 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/20~9 L-100 1980550 5002922B580100 NA 62 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 12 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-i 10 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-715 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 1-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 5002923i470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.6 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 iVA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 102 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 5~29233120000 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6l27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 162 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 L-104 (PTD#2012380} sustained~ing pressure • Page 1 of I Regg, James B (DOA) From: Winslow, Jack L [Lyonsw@BP.comJ ~i~~ ~U1j ~~1 Sent: Monday, October 01, 2007 2:14 PM ~` ~~ t To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr West (GC2/WRD); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Oakley, Ray (PRA); Robertson, Daniel B (Alaska) Cc: NSU, ADW Well Integrity Engineer; Lau, John, Jack Subject: L-104 (PTD#2012380} sustained casing pressure Attachments: L-104.pdf . All, L-104 has been found to have sustained casing pressure on the IA. The wellhead pressures were 320/2040/300 on 09/28/07. DHD performed a subsequent TIFL which failed by flow to surface on 09/29!07. This well has been reclassified to Under Evaluation due to TxIA communication. The plan forward is as follows: 1. TIFL - FA{LED 2. S: Set DGLVs 3. D: Re-TIFL 4. SP: Run LGLVs per GLE A wellbore schematic has been included for reference. «L-104. pdf» Thank you - Jack L, Wir~slaw (for Anna Dube} Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 10/1/2007 TREE = 3-1'8" 5M CN\,' ~~t~ELLHEAD = 11" FMC ACTtiArOR- .m -«~-.. - ,~ NA . .- - .-„n, . .~. ~~. ELEV = n m~ e,R.. . .-.. za' ~ ~ ~~_. ELEV = _._ ~_.~. KUr= 7~' '032' dJ~ax Angle = ",- _,. ` Uaturr iL1D = 64 ~ 32'35' -, 99x9' batum T1Jb = 66~J0' SS 7-5rs" CSG, 29.7#: L-80, ID = 6,875" I-I 3015' i11IfT3UCT1 ~ = ~ 'l' PERFORATIC3N SUMMARY REF LOG: SCMT ON 02/ 11 •`D2 ANGLE AT TGP PERF: 16 @ 98&G` Note: Refer #a Production dB for historical perf data SIZE SPF (NTERI/AL Opr~?Syz DATE 2-1l2° 6 986©- 9940 01 02r"27101 ~3-1%2" T6G; 9.2#, L-8©, IBT-M, .0087 bpf, ID = 2.892" ' 9661' 5-112° CSG; 15.5#, L-80, BTG, ID = 4.95{7" 9661' 5-112" X 3-1%2" X~ 9669' v'A5 LIFT` MANDRELS ST {14D TVD DEV TYPE VLV LATCH PORT DATE 7 2061 2€311 27 KBG2-9 bMY INTG 0 01? 12?05 6 3027 2655 62 KBG2-9 DOME INTG 16 E?827?05 5 4561 3399 57 KBG2-9 DMY INTG 0 01? 12?05 4 5937 40195 59 KBG2-9 DOME INTG 16 Go,'27/G5 3 7238 48€18 57 i~Bt,2-9 [X7f4'}E INTG i6 08`27,-05 2 8550 5496 49 KBG2-9 503 INTG 24 G'H?27?05 1 9566 6297 23 KBG2-9 DMY INTG R 012:06?C4 9620' , ~ 3-1 r"L" HES X N1P: CD = 2.813" 9£40' BKR LOC SEAL ASSY. ID = 3.rJ©" i `~ TOP {1F BKR PBR, ID = 4.00" 9&6' BTN1 OF 4" BKR SEAL ASSY, ID ='s:JO" 9699' 3-112" HES X N1P, ID = 2.813„ 9719' 3-1i2" NES X NIP; ED = 2.813" 9711' 3-112° PX PLUG (7r'14106)~ $`~ `¢' 15' (~)P JT V1r.- RA TAG 9 #1$35' --~ 15' FiJP JT fN; RA TAG( ??? -FISH (T'u'd0 SS BANbSj P3TD (ELMj ~-~ 3-112" GSG, 9.2#; 1.80. NSCT, ID = 2.9x2" --~ °~ DATE REV BY Ct~l1MENTS 0}11301fl2 DACIKS< OR[GI~1Al CC3M~'L~TION ...`...V._..®~ 011/141(15 JCIPJC Wt,I {12128101 TIL9N'KK PE€~T=S & PBTD CORRECTION .a~-...........® .® !l~>?08103 DP.SrTP .. CI~Di?t4~J CORRECTIt7NS 02(C}6it?4 G.i€3;'TLP iaLV ~;fO OZ%1 C1;t35 RMN,''P.1<; c7i.E~ C;iO QATE REl•' BY COP~IMENTS Q8;`27%05 L1"fRrTL.H GLl,~ 010 0714OEi TEL;P,IC; SE'' 3-1!'L" PX PL liG E3C'REALIS UNIT L'~JELL: 1.-' {74 PER~,+1}T Nc;: ~Lt?1238(? API Na: 5f1-029-2;3{}ti;l-{7% SEC 34, T12N, R11 E 2425' NSL & 3:129' t'VEL sP ploratlort $ala~~a} ~: -• '1$92' I-13-1.`2" HES X NIPPLE: ID = 2.813 . . .. MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker. doc STATE OF ALASKA RECEI\/E ALASKA Oil AND GAS CONSERVATION COMMISSION JAN 2 0 Z005 REPORT OF SUNDRY WELL OPERAIJ~ti~Gas 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 79.1. 8. Property Designation: ADL 028238 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structu ral Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): B Repair Well 0 Plug Perforations 0 Stimulate 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 10400 7096 10245 6945 feet feet feet feet Size 80' 2986. 20" 7-5/8". 10365. 5-1/2" X 3-1/2" 9860. - 9900' 6574. - 6613. Tubing Size (size, grade, and measured depth): 0 Other 0 Time Extension 4. Current Well Class: B Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 201-238 6. API Number: 50-029-23060-00-00 9. Well Name and Number: PBU L-104 10. Field / Pool(s): Prudhoe Bay Field / Borealis Pool Plugs (measured) None Junk (measured) None MD TVD Burst Collapse 109' 109' 1490 470 3015. 2651' 6890 4790 10391' 7087' 7000 4990 SCANNE.D" 2 Of "ìon~ ;~J .1 l. u,. 3-1/2.', 9.2# L-80 9657. Packers and SSSV (type and measured depth): 3-1/2" HES .X' Nipple 12. Stimulation or cement squeeze summary: Intervals treated (measured): 1892. Treatment description including volumes used and final pressure: RBDMS BFl JAN 21 2005 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run B Daily Report of Well Operations B Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure 15. Well Class after proposed work: 0 Exploratory B Development 0 Service 16. Well Status after proposed work: BOil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. '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 Shane Gagliardi. 564-5251 N/A Printed Name Terrie Hubble Signature ~ Wi q., {)1 ~ Form 10-404 Revised 04/2004 Title Technical Assistant Phone Date Ö( {to/ OS Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 OR1G" J~ , "/~\ BP~...'EXPLORATION Qpe~~_~C)I'I$.'$..tI.mlt1l~r'M,Aepørt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -1 04 L -1 04 WORKOVER NABORS ALASKA DRILLING I NABORS 9ES . Date From.~To HOUrs Task Code NPT 1/5/2005 20:00 - 00:00 4.00 MOB P 1/6/2005 00:00 - 02:30 2.50 MOB P 02:30 - 03:00 0.50 MOB P 03:00 - 04:30 1.50 RIGU P 04:30 - 06:30 2.00 KILL P 06:30 - 10:00 3.50 KILL P Phasè PRE PRE PRE PRE DECOMP DECOMP 10:00 - 10:30 0.50 KILL P DECOMP 10:30 - 12:00 1.50 WHSUR P DECOMP 12:00 - 13:30 1.50 BOPSURP DECOMP 13:30 - 17:00 3.50 BOPSUR P DECOMP 17:00 - 17:30 0.50 BOPSUP P DECOMP 17:30 - 19:00 1.50 BOPSUR P DECOMP 19:00 - 19:30 0.50 PULL P DECOMP 19:30 - 22:30 3.00 PULL P DECOMP 22:30 - 23:00 0.50 PULL P DECOMP 23:00 - 00:00 1.00 PULL P DECOMP 117/2005 00:00 - 12:00 12.00 PULL P DECOMP 12:00 - 18:30 6.50 PULL P DECOMP Start: 1/3/2005 Rig Release: 1/12/2005 Rig Number: Spud Date: 1/17/2002 End: 1/5/2005 Blow down steam and water lines in pits, dicconnect service lines, move pits around pad and position on L-104, pull Sub off well and move around pad to L-104. Set mats and herculite for sub, spot and level sub on L-104 Set mats, spot pits and cuttings tank. Hook up service lines and power to pits, take on seawater. Accept Rig at 03:30 hrs. 1/6/2005 Hook up Choke and mud lines, install secondary valves on lA, rig up circulating lines to wellhead. Rig up DSM lubricator, pull BPV, zero pressure on tubing and annulus. Test circulating lines to 2,000 psi, reverse 22 bbls diesel from tubing, pump down tubing and displace 30 bbls diesel from annulus, pump 50 bbl soap pill down tubing and displace well to clean seawater @ 4 bpm, 955 psi. Zero pressure on tubing and annulus. Blow down lines, Install TWC and test from below to 1,000 psi. Nipple down tree and adapter flange, inspect lifting threads on tubing hanger. Nipple up BOP, riser and mouse hole. Rig up testing equipment and test BOP to 250 psi low, 3,500 psi high, as per Nabors testing procedure, John Spaulding with AOGCC waived witness of BOP test. Rig down test equipment, blow down choke manifold and kill lines. Rig up Lubricator and pull TWC, rig down lubricator. Make up landing joint and back out lock down srews. Un-seat tubing hanger, and attempt to pull seal assembly from PBR, string moved approximetly 3' initially with a hook load of 175k while pumping 2 bpm @ 340 psi, contiuned working string to maximum pull of 195k and increaseing pump rate to 9 bpm @ 3,100 psi, made no progress with pumps off, with seal assembly completly out of PBR, string weight droped to 105K. Circulate bottoms up @ 5 bpm, 1,225 psi, rig up casing tools and control line spooling unit. Back out landing joint, and lay down tubing hanger, and four pup joints. POH laying down 3.5" tubing, after pulling 25 joints the next two joints were missing the SS bands, while pulling joint #28 the control line quit coming up as pipe was pulled, drained the stack to see if the line was balled up in the stack, looked good. Continued laying down tubing, attached a strap and the tugger to the control line and pull up as pipe is being pulled. Continue POH laying down 3.5" tubing and control line, pulled joint #70 control line parted, continue pulling to SSSV and lay down same, control line was waded up on top of SSSV, recovered a total of 54 SS bands, 28 bands left in hole. Continue Laying down 3.5" tubing. Continue POH laying down 3.5" tubing, recovered a total of 304 joints 3.5" tubing, 4 pup joints, SSSV, 3 GLM, Sliding sleeve and Baker seal assembly. Tubing string will not be re-run due to pin damage on approximetly 90% of the 304 joints layed down. Printed: 1/17/2005 9:04:03 AM t-, BPEXPLOBAIION Qpe~éttiøn~,.SI.,lÞ'l.rnary,Rèport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -1 04 L -104 WORKOVER NABORS ALASKA DRILLING I NABORS 9ES Start: 1/3/2005 Rig Release: 1/12/2005 Rig Number: Spud Date: 1/17/2002 End: 1/5/2005 HOlJr~' Task Descriptio[1.'ofOþeratioriS 117/2005 18:30 - 19:00 0.50 PULL P DECOMP 19:00 - 19:30 0.50 PULL P DECOMP 19:30 - 20:00 0.50 BOPSUR P DECOMP 20:00 - 00:00 4.00 CLEAN N DPRB CLEAN 1/8/2005 00:00 - 05:30 5.50 CLEAN N DPRB CLEAN 05:30 - 07:30 2.00 CLEAN N DPRB CLEAN 07:30 - 10:30 3.00 CLEAN N DPRB CLEAN 10:30 - 13:00 2.50 CLEAN N DPRB CLEAN 13:00 - 14:00 1.00 CLEAN N DPRB CLEAN 14:00 - 14:30 0.50 CLEAN N DPRB CLEAN 14:30 - 15:30 1.00 RUNCOMP RUNCMP 15:30 - 17:00 1.50 RUNCOMP RUNCMP 17:00 - 00:00 7.00 RUNCOI\IN WAIT RUNCMP 1/9/2005 00:00 - 00:00 24.00 RUNCOI\IN WAIT RUNCMP 1/10/2005 00:00 - 00:00 24.00 RUNCOI\IN WAIT RUNCMP 1/11/2005 00:00 - 08:30 8.50 RUNCOI\IN WAIT RUNCMP 08:30 - 20:00 11.50 RUNCOMP RUNCMP 20:00 - 21 :30 1.50 HUNCOMP RUNCMP 21 :30 - 22:30 1.00 RUNCOMP RUNCMP 22:30 - 00:00 1.50 RUNCOMP RUNCMP Rig down tubing handling equipment and clean floor. Rig up and flush stack, pumping @ 350 gpm, blow down top drive. Rig up test equipment, install test plug and test lower pipe rams to 250 psi low, 3,500 psi high, rig down testing equipment. Rig up Schlumberger slick line, and RIH with 4.75" gauge ring, junk basket, had problems getting tools in the top of the 5.5", drained stack and worked tools into top of 5.5", sat down at 70' worked junk basket, POH recovered 3 pieces of control line approximately 6" long and 1 SS band. Run #2, tools ran in to a depth of 230' POH, recovered 1 SS band, Run #3 & #4 at depths of 460',670' recovered nothing. Run #5 tools ran to a depth of 1,260' POH, recovered 2 SS bands and 6" piece of control line. Run #6 RIH to a depth of 2,035' POH, recovered 4 SS bands and 2" of control line, Run # 7 RIH to a depth 2,730' POH recovered 1 SS band and 2" of control line. Run #8 RIH to the top of the PBR @ 9,634' (slick line), POH, recovered approximately 6-7' of control line (short pieces 1" to l' long) and approximately 3 to Sibs of SS bands 1/2" to 2" pieces. Made a total of 8 GR/JB runs. RIH with 4.00" brush to 5.5" x 3.5" XO @ 9661'. Recovered piece of band & metal filings on 1 st run; clean on 2nd run. Made two GR/JB runs to 9661'. Small amount of debris on 1st run; clean on second. RU & RIH wI 2.25" LIB to 9680'. POH. Inconclusive. RIH wI 2.25" Bailer to 9690'. No recovery. RD slick line equipment. Make dummy run wI hanger. RU tbg tools. Start RIH wI seal assembly on 3.5" IBT-Mod tbg. GPB in Phase 3 conditions. WOW. Phase 3 conditions. Changed crews out @ noon. Received fuel, potable water, & rig water by convoy. WOW. Phase 3 conditions. WOW. Phase 3 conditions. Weather conditions down graded to Phase 2. RIH with 3.5" 9.2# L-80 IBT-M completion, make up torque = 2,400 ftIlbs, pickup joint # 307 & #308 makeup head pin and circulating hose, tag top of PBR with seal assembly @ 9642', pumping 1 bpm, 120 psi, pressure increased to 190 psi as seals entered PBR. Up wt = 11 Ok, dn wt = 75k Pickup 2' above top of PBR and pump 10 bbl high vis sweep, to clean up any debris left in hole @ 252 gpm, 2070 psi. Confirm top of PBR by pumping at 1 bpm saw pressure increase, shut down pumps, slack off and fully insert seal assembly in PBR. for space out, pull out of PBR. Rig up and reverse circulate 82 bbls of clean seawater, followed by 61 bbls sewater treated with corrosion inhibitor, spot with 54 bbls additional clean seawater @ 3 bpm ,700 psi. POH lay down joints #308,#307,#306, make up one 19.82' space out pup, and tubing hanger, make up head pin and Printed: 1/17/2005 9:04:03 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -1 04 L-104 WORKOVER NABORS ALASKA DRILLING I NABORS 9ES Start: 1/3/2005 Rig Release: 1/12/2005 Rig Number: Spud Date: 1/17/2002 End: 1/5/2005 Date From~To Hours Task Code NPT Descriptionqf0þerations 1/11/2005 22:30 - 00:00 1.50 RUNCOMP RUNCMP circulating hose on land tubing, Circulate down @ 1 bpm to verify seal entry in PBR, bleed of pressure, drain stack and land tubing, RILDStorque to 450 ftllbs. Pressure up to 3,500 psi on tubing hold for 30 min record on chart, bleed tubing pressure to 1,500 psi, pressure up on annulus to 3,500 psi hold for 30 min record on chart, bleed annulus pressure to zero, bleed tubing pressure to zero, pressure up on annulus to shear DCK shear valve in # 5 GLM, valve sheared @ 2,600 psi, pump 3 bbls through valve. Back out landing joint, install TWC and test from below to 1 ,000 psi. Drain Stack, blow down lines remove mouse hole, nipple down BOP. Nipple up adapter flange and tree. test to 5000 psi. Rig up DSM lubricator and pull TWC Rig up Little Red, test lines to 2,500 psi, freeze protect tubing and annulus with 45 bbls heated diesel @ 2 bpm, 1,350 psi. U-tube diesel. Install BPV with lubricator, test from below to 1,000 psi. Rig down Little Red, blow down lines, remove secondary valve on IA and install flange, secure well. 1/12/2005 00:00 - 02:00 2.00 RUNCOMP RUNCMP 02:00 - 02:30 0.50 RUNCOMP RUNCMP 02:30 - 03:30 1.00 BOPSUR P OTHCMP 03:30 - 04:30 1.00 WHSUR P WHDTRE 04:30 - 05:30 1.00 WHSUR P WHDTRE 05:30 - 07:00 1.50 WHSUR P WHDTRE 07:00 - 08:00 1.00 WHSUR P WHDTRE 08:00 - 09:00 1.00 WHSUR P WHDTRE Release Rig @ 09:00 hrs 1/12/2005 Printed: 1/17/2005 9:04:03 AM I 1 TREE = 3-1/8" 5M CIW WELLHEA D = 11" FMC . . . . . . . . . . . . . . . .. . . . . . . . , ACTUA TOR = NA 'KB~ELEV=" 24' n. <, ." ",.. ..."""." ' . " BF. ELEV = 79' 'KóÞ';' " "1032' ~x '~n~íë.~,' .. 64 @)~~~' Datum MD = 9969' batum iVb = '6600; SS 17-5/8" CSG, 29.7#, L-80, ID = 6.875" 1-1 3015' Minimum ID = 2.813" @ 1892' 3-1/2" H ES X Nipple PERFORATION SUMMARY REF LOG: SCMT ON 02111/02 ANGLE AT TOP PERF: 16 @ 9860' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 9860 - 9900 0 02127/01 L-1 04 41 I . L 13-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 1-1 9661' ~ I I I 5-1/2" CSG, 15.5#, L-80, BTC, ID = 4.950" 1-1 9661' r J 15-1/2" X 3-1/2" XO l-t 9661' 1 1 PBTD (ELM) 1-1 10245' I ~ 13-1/2" CSG, 9.2#, L-80, NSCT, 10 = 2.992" I--{ 10391' ~ DA TE REV BY DATE 01/30/02 02/17/02 02/28/01 04/08/03 02/06/04 01/09/05 REV BY COMMENTS DAC/KK ORIGINAL COM PLErION DTRltlh GL V UPDATE TMNlKK ÆRFS & PBTD CORRECTION DRSrrp lV D/MD CORRECTIONS GJBrrLP GL V C/O TA/BB RWO ~ ST MD 7 2061 6 3027 5 4561 4 5937 3 7298 2 8550 1 9565 ~I ~ I I I I I,!", SAFETY NOTES: HAD TO PULL TBG TO REPLACE CONTROL LINE. LEFT 2 55 BANDS IN HOLE. 1892' 1,,3-1/2" HES X NIPPLE, ID = 2.813" GAS LIFT MANDRELS lVD DEV TYÆ VLV LATCH PORT 2011 27 KBG2-9 DMY INTG 2655 62 KBG2-9 DMY INTG 3398 57 KBG2-9 RP-Sh INTG 4094 59 KBG2-9 DMY INTG 4808 57 KBG2-9 DMY INTG 5495 49 KBG2-9 DMY INTG 6295 23 KBG2-9 DMY INTG DATE 01/12/05 01/12/05 01/12/05 01/12/05 01/12/05 01/12/05 01/12/05 9619' 9639' Ij3-1/2" HES X NIPPLE, ID = 2.813" LJSKR LOC SEAL ASSY, 10 = 2.990"1 1-1 TOP OF BKR PBR, ID = 4.00" 1 IjBTM OF 3.5" BKR SEAL ASSY, ID = 2.990" 1 1-t3-1/2" HES XNIP, ID = 2.813" I 9642' 9657' 9691' 9711' 1-13-1/2" HES XNIP, ID = 2.813" 1 9811' 1-115' PUP JTW/ RA TAG 1 I 10035' 1-115' PUP JTW/ RA TAG I COMMENTS BOREA LIS UNIT WELL: L-104 ÆRMIT No: 2012380 API No: 50-029-23060-00 SEC 34, T12N, R11 E 2425' NSL & 3529' WEL BP Exploration (Alaska) ] ,1 I"~/I' ì"\ r \ (/' "'- ( - c.~ ',,' "- /~ \,"':; \J ,--{ DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permit to Drill 2012380 Well Name/No. PRUDHOE BAY UNIT L-104 Operator BP EXPLORATION (ALASKA) INC C 4.' 7) )" l}.~ / ' ~ <"¡I..J 1.- API No. 50-029-23060-00-00 MD 10400 TVD 7096 -- Completion Date 2/27/2002 Completion Status 1-01L Current Status 1-01L UIC N - - - --- ----- ------- ------- - -- -------------- - - -- ---- ----- -- ----- - - - -- --- REQUIRED INFORMATION ------- ----- ----- - -- ---- - - - - -- - -- -- D_irecti~~al survey(~)__-_.." Mud Log No Samples No -- - - ---- - ---- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Type Med/Frmt Number Name - - --- --- ---- Cfõ629 ED C Neutron ED C '"ÍÓ629 Density --------------- Log Log Run Scale Media No --- --- ---- 1 Interval OH I Start Stop CH ----------- 108 10400 Case 3/5/2002 Received Comments 108 10400 Case 3/5/2002 . - -- - . - --- -------- - -- -- ---- - ----- ------ - - --- --- ---- - Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y í\~ì Daily History Received? \ÜN (~/N Chips Received? Y/N Formation Tops Analysis Received? YLH-- - --------------- ----- --------- -. - ---. - -. --------- --- -- ----- Comments: ~:m:I;;n::::eW~~B;:- -- - --- ----Jt;-- -------- Date: --'~-nI1/) -).~~- ~(=-_.- . -- , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well IS! Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2425' NSL. 3529'.W~L, SEC. 34, T12N, R11E, UM, ... !>...-,,<~r¡ ~.: .:s:-":,".:.~;,"L~'-~' At top of produc~lve Interval .' ..il,-,,: "/¿:' _. : . r: ',of' ~. 1~~~~~f~è~t~24, EWL, SEC. 35, T12N, R11E, UM ~" . ;_1~[:- -- ,~'. ~,,:,~.t 1296 NSL, 2958 EWL, SEC. 35, T12N, R11E, UM ',.~." . ...', ~r- 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial N'ó.' .. KBE = 79.10 ADL 028238 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 1/17/2002 1/26/2002 2/27/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10400 7096 FT 10245 6945 FT IS! Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU Classification of Service Well 7. Permit Number 201-238 8. API Number 50- 029-23060-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number L-104 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2314' MD 1900' (Approx.) 23. CASING SIZE 20" 7-5/8" 5-1/2" 3-1/2" CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE 29' 1091 30" 29' 3015' 9- 7/8" 26' 9661' 6-3/4" 9661' 103911 6-3/4" CEMENTING RECORD ~60 sx Arctic Set (Approx.) 349 sx AS Lite, 231 sx Class 'GI 165 sx LiteCrete, 192 sx Class 'G' J5-1/2" x 3-1/2" Cementing Program) WT. PER FT. 92# 29.7# 15.5# 9.2# GRADE H-40 L-80 L-80 L-80 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6 spf MD TVD 9860' - 9900' 6574' - 6613' 25. SIZE 3-1/2",9.2#. L-80 MD TVD AMOUNT PUllED TUelNG RECORD DEPTH SET (MD) 9661' PACKER SET (MD) ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2400' Freeze Protect with 112 Bbls Dead Crude 26. 27. Date First Production March 29,2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR Oil-Bel TEST PERIOD GAs-McF WATER-Bel Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oil-Bel GAs-McF WATER-BeL CHOKE SIZE GAS-Oil RATIO OIL GRAVITY-API (CORR) 28. CORE DATA ReCEIVCD Brief description of lithology. porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. ~."~'I 0 ¡ ,"'.1 . ¡ "\ 1 , 1- "',,", I ,.¡ .", l t...' ~: "" J I ~,.; 1 ¡ J i ~._\~ Form 10-407 Rev. 07-01-80 RBOMS BFL APR 4 2002 Al88Oi1&G8Cons.COO1missiof1 A.~ APF? C ':'(''-0 l..' L.vL,L. Submit In Duplicate 29. Geologic Markers 30. Formation Tests Ma rker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered and Depth Depth gravity, GOR. and time of each phase. Schrader Bluff M 5624' 3944' Schrader Bluff N 6174' 4218' Schrader Bluff 0 6512' 4392' Base Schraderl Top Colville 7242' 4778' Mudstone CM1 8824' 5683' HRZ 9554' 6286' Kalubik 9775' 6493' RECEIVED Kuparuk D 9857' 65711 Kuparuk C 9859' 6573' APR 4 2002 LCU I Kuparuk B 10015' 67231 NlllraElIGllCona.CœmiasiorI AndIorage Kuparuk A 10154' 6857' Miluveach I Base Kuparuk 102421 6942' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the fo~oin: is true and correct to the best of my knowledge Signed Terrie Hubble ~~ ~ Title Technical Assistant L-104 201-238 Well Number Permit No. I Approval No. Date DY 'D 3>-0 ~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection. steam injection, air injection, salt water disposal, water supply for injection, observation. injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection. Gas Injection. Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: L-104 Common Name: L-104 Test Date 1/21/2002 Test Type LOT Test Depth (TMD) 3,026,0 (ft) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) 2,549.0 (ft) AMW 9,30 (ppg) Surface Pressure 499 (psi) Leak Off Pressure (BHP) 1,730 (psi) Page 1 of 1 EMW 13 07 (ppg) Primed 214/2ú02 10 32 35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operations Summary Report L -1 04 L -1 04 DRILL +COMPLETE NABORS NABORS 9ES Start: 1/17/2002 Rig Release: 1/30/2002 Rig Number: 9-ES Page 1 of 6 Spud Date: 1/17/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 1/17/2002 06:00 - 10:00 4,00 MOB P !PRE Prepare rig for move, Move pits. Move Rig & spot Sub over L-104, Lay mats and herculite, Spot pits Hook up mud and elec, lines. RIG ACCEPTED @ 10:00 HRS, 1/17/2002 10:00 - 15:00 5,00 RIGU P PRE Take on water, put valves on conductor.M/U Riser, mix spud mud, prepare BHA in shed. 15:00-16:00 1.00 RIGU P PRE M/U Jars and Drill Collars and stand back in Derrick. 16:00 - 16:30 0,50 BOPSURP SURF Function Test Diverter System, Witness waived by Chuck Sheve, AOGCC, 16:30 - 17:30 1,00 DRILL P SURF MIU BHA #1 17:30 - 18:00 0,50 DRILL P SURF Pre - Spud Meeting with Rig Team, 18:00 - 19:00 1,00 DRILL P SURF Fill Hole wI water & check all equipment for leaks. 19:00 - 00'00 5,00 DRILL P SURF SPUD at 107'. Directional Drill 9 7/8" Hole to 448', WOB = 5 to 20K. 600 GPM @ 1280 psi. TO = 2 5K, P/U = 54K. SIO = 54K, ROT = 58K ART = 2 Hrs, AST = 0,5 Hrs, 1 I 18/2002 00:00 - 11 :00 11.00 DRILL P SURF Drill 9 7/8" directional hole from 448' to 1841'. 600 GPM @ 2280 psi. TO = 5200 P/U = 84K SIO = 76K ROT = 77K AST = 4.75 Hrs, ART = 4 Hrs. 11:00-12:00 1,00 DRILL P SURF CBU 12:00 - 14:00 2,00 DRILL P SURF POH Pull 15 to 20 Over @ 1561',1467',1300' & 1100'. 14:00 - 16:00 2,00 DRILL P SURF CIO Bit & RIH. Wash & ream last stand to bottom @ 1841'. 16:00 - 23:00 7,00 DRILL P SURF Drill 9 7/8" Directional Hole from 1841' to 3026', TD per Geologist. 600 GPM @ 2900 psi. TO = 5K, P/U = 93K. SIO = 79K, ROT = 86K. AST = 2,7 Hrs, ART= 1,8 HRS 23:00 - 00:00 1,00 DRILL P SURF Circulate & Condition Mud, 1/19/2002 00'00 - 01 :00 1,00 DRILL P SURF Circ Sweep, Pump lube pill, pump slug, 01 :00 - 08:00 7,00 DRILL P SURF POH, Pulling tight - 25 to 30 over & swabbing, MIU Top Drive and pump out of hole to 1282' Cont. POH standing back HWDP & DC's 08:00 - 09:00 1,00 DRILL P SURF LID MWD, Stab, Lead DC & Bit. 09:00 - 10,00 1 00 DRILL P SURF M/U 97/8" Porcupine HO BHA #3. 10:00 - 11 :00 1,00 DRILL N WAIT SURF Wait on Super Suckers ( Phase 2 conditions) 11 :00 - 12:00 1 00 DRILL P SURF RIH wI BHA #3 to 1034', 12:00 - 17:00 5,00 DRILL P SURF MIU Top Drive, Circulate bottoms up, Cont RIH, ream tight spots @ 1040', 1480', Cont. RIH to 2063', M/U TD CBU & clean hole, Ream tight spot @2200' cont RIH to 2820', Ream to TD @ 3026', 17:00 - 19:30 2 50 DRILL P SURF Circulate wleghted sweep. 600 GPM @ 2450 psi, Rotating @ 130 RPM, Spot Casing running pill & pump slug 19'30 - 22:00 2,50 DRILL P SURF POH, Hole in good condition 22'00 - 23'00 1,00 DRILL P SURF UD BHA # 3 23:00 - 00.00 1,00 CASE P SURF R/U to run 7 5/8" Surface Casing, 1/20/2002 00'00 - 00,30 0,50 CASE P SURF RU casing tools, Chk mandrel hanger lands on landing ring - OK, 00 30 - 00 45 0,25 CASE P SURF PJSM prior to runmng casing, 00"45 - 05'30 4 75 CASE P SURF Run ì2 jts 7 5/8" 29 ì# L-80 BTC Mod casing with TAM port collar at 983', shoe at 3015' 05'30 - 06 00 0,50 CASE P SURF LD casing fill-up tool MU hanger and landing joint Land casing on MLS landing profile, Pipe went to bottom wlo problems 06 00 - 07 30 1 50 CEMT P SURF Circ and cond mud (reduce FV to 45) while reciprocating pipe - OK PJSM with Peak drivers while C & C mud, PrInted 2/4/2002 1 (I 32 41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operations Summary Report Page 2 of6 L -1 04 L-104 DRILL +COMPLETE NABORS NABORS 9ES Start: 1/17/2002 Rig Release: 1/30/2002 Rig Number: 9-ES Spud Date: 1/17/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 1/20/2002 07:30 - 07:45 0.25 CEMT P SURF PJSM with crew, service companies prior to pumping cement. 07:45 - 08: 15 0,50 CEMT P SURF Pump 5 bbl CW 100. Test lines to 3500 psi. Pump 5 bbl CW 100 followed by 75 bbl Mudpush XL at 10.2 ppg. Launch bottom plug. 08: 15 - 09:30 1,25 CEMT P SURF Pump 275 bbl (349 sx) Arcticset III Lite lead at 10,7 ppg followed by 50 bbl (240 sx) Class G tail at 15,8 - 16,0 ppg, 09:30 - 09:45 0,251 CEMT P SURF Kick top plug out with 10 bbl water, Switch to rig pump and displace cement. Started getting 10,7 ppg lead slurry back 42 bbl prior to bumping plug. Bump plug with 500 psi over at 1780 stks away - OK. Bleed off pressure, Floats holding. CIP 0945 hrs, 100 % Returns throughout the job, Reciprocated Casing until ¡ Tail Cmt rounded corner 09.45 - 12:00 2,25 CEMT P SURF Flush Diverter Stack, RID Cement head. LID Landing Jt., RID & off load csg equip, 12:00 - 14:30 2,50 BOPSUR P SURF NID Diverter Assembly, 114:30 - 15:30 1,00 WHSUR P PROD1 NIU FMC GEN - 5, Lower Split Uinihead. Test metal I metal seal to 1000 psi. 15:30 - 19:30 4.00 BOPSURP PROD1 NIU 135/8", 5M BOP. Nipple & Riser. 19:30 - 20:00 0,50 BOPSUR P PROD1 Install Test Plug, R/U to test BOPE 20:00 - 00:00 4.00 BOPSUR P PROD 1 Test BOPE to 250 14500 psi. Annular to 250 I 3500 psi. 1/21 12002 00:00 - 00:30 0,50 BOPSUR P PROD1 Complete BOP Test - RID test equip, Pull test plug, install wear bushing, 00'30 - 01 :30 1.00 DRILL P PROD 1 Service Top Drive. replace grabber ram dies. 01:30 - 10'30 9,00 DRILL P PROD 1 P/U 4' DP RIH I POH & stand back In derrick, 10:30 - 13:30 3,00 DRILL P PROD1 MIU BHA # 4, Load sources in LWD. Flow check - OK 13:30-14:00 0,50 DRILL P PROD 1 RIH picking up singles from shed Pass Tam Collar @ 983' No Problems, 14:00 - 15.00 1,00 DRILL P I PROD 1 Hold "Trip" and "Stripping" Drills, 15.00 - 16:30 1,50 DRILL P PROD 1 Continue RIH P/U singles to 2888'. 16.30-17:30 1,00 DRILL P PROD 1 Break circulation, Test 75/8" Casing to 3500 psi for 30 minutes, 17:30 - 19:45 2,25 DRILL P PROD 1 Drill Float Clr. Hard Cmt. & float shoe, Clean out to 3026', 19:45 - 20:00 0,25 DRILL P PROD1 Drill 20' of new hole to 3046', 20:00 - 21 :00 1,00 DRILL P PROD1 Displace hole wI new 9.3 ppg. LSND Mud, 21 :00 - 21 :30 0,50 DRILL P PROD1 Perform LOT. 499 psi wI 9,3 ppg mud in hole = 13,06 ppg, EMW LOT 21 :30 - 00:00 2,50 DRILL P PROD1 Directional Drill 6 3/4" Hole from 3046' to 3355', 300 gpm @ 1800 psi TO = 3K RPM = 50 1/22/2002 00:00 - 15:00 15,00 DRILL P I PROD 1 Cont drill ahead 6 3/4 hole drctnl, 3355 - 5784 ft, parameters normal. No loss I gains WOB 10, RPM 50. SPM 101, GPM 300. PRESS 2900, TO 4000 Up 108, Dn 77, Rot 87 AST = 1 3 hrs, ART = 9 hrs 15:00 - 16:00 1 00 DRILL P PROD 1 Clrc sweep, pump wt pill. no abnormal cuttings return, shaker clean, 16'00 - 2030 4 50 DRILL P PROD1 Flow check poh for wiper tnp to shoe, Pull 10 - 25 Kover, constant pull Reclp I work all stds free to 5500 ft, Begin swabbing, can not fill hole Pump I back ream to 4050 ft, Hi tork and overpull Work free, Regain clrc I pipe movement Pr,ntea 2/4/ ¿ûú2 , (I :<2 4' AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/22/2002 1/23/2002 1/24/2002 1/25/2002 1/26/2002 BP EXPLORATION Operations Summary Report L -1 04 L -1 04 DRILL +COMPLETE NABORS NABORS 9ES Page 30f6 Start: 1/17/2002 Rig Release: 1/30/2002 Rig Number: 9-ES Spud Date: 1/17/2002 End: From - To Hours Activity! Code NPT Phase 16:00 - 20:30 20:30 - 21 :30 21 :30 - 00:00 00:00 - 00:30 00:30 - 03:00 103:00 - 17:30 I i 117:30 - 18:30 I 18:30 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02 30 - 04:30 04'30 - 06'00 06:00 - 09:00 09,00 - 00:00 I I 00'00 - 14,30 1430 - 15:30 1530 - 17:30 17,30 - 19:00 : 19'00 - 20,00 20'00 - 00 00 100:00 - 15:30 1530 - 17'00 4.50 DRILL P 1,00 DRILL P PROD 1 PROD 1 2,50 DRILL P PROD1 0,50 DRILL P 2,50 DRILL P PROD 1 PROD1 14,50 DRILL P PROD 1 1,00 DRILL P PROD1 4,50 DRILL P PROD 1 1,00 DRILL 1.50 DRILL 1,00 DRILL 2,00 DRILL 1.50 DRILL 3,00 DRILL P P P P P P PROD 1 PROD1 PROD1 PROD 1 PROD1 PROD1 15,00 DRILL P PROD1 14,50 DRILL P PROD1 1,00 DRILL P 2,00 DRILL P 1,50 DRILL P PROD1 PROD1 PROD 1 1,00 DRILL P 4 00 DRILL P PROD1 PROD1 15,50 DRILL P PROD1 1 50 DRILL P I PROD 1 Description of Operations Full returns. Pump wt pill. follow with hi vis, High cuttings return at shaker, Some large pieces coal. Cont recip / circ, work free, Clean returns at shaker. Flow check, resume poh to 3015 ft inside 7 5/8 shoe, Back reaming necessary to poh entire interval. Service top drive Rih 4" dp to 5410 ft, Wash I ream to 5504 ft, taking 2 - 3000 on bit for drill off, Resume rih to 5700 ft, No further difficulties. Precautionary wash to btm 5784 ft, No fill. Flow check, commence dnll ahead 5784 - 7467 ft, No loss/ gains WOB 10. RPM 100, SPM 101, GPM 300, PRESS 2850, TO 7000 Up 111, Dn 80, Rot 94 AST = 1,1 hrs. ART = 8,35 hrs Pump and circ sweep to surface, shaker clean, No abnormal cuttings returns, Flow check, poh for bit. Tight at 6800, 6220, 6150. 5920 ft, Slight swabbing these depths, work free. gain proper hole fill, No losses, Flow check, Handle bha, download source, Cont download source ( LWD ), break out / grade bit. Make up motor blade, bit #4, load source ( LWD ) Flow check, follow bha #5 with 4" dp to 7 5/8 shoe 3015 ft, Slip / cut drlg line, Service top drive, Flow check, rih 4" dp to 6598 ft, wash / ream 6598 - 6668 ft, Resume nh, precautionary wash 90 ft to btm, No fill. Flow check, commence drill ahead 6 3/4 drctnl hole 7467 - 8838 ft, No gain I losses, WOB 10, RPM 70, SPM 101, GPM 300, PRESS 3150, TO 7500 Up 150, Dn 98. Rot 120 AST = 2 hrs, ART = 8,5 hrs Dnll ahead 6 3/4 drctnl hole, 8838 - 9432 ft. Clrc btms up, shaker clean, Displace well with 10 3 ppg, pump wt pill. Flow check, poh for wiper trip to 7280 ft, Hole conditions normal Flow check, rih, precautionary wash 90 ft to btm, no fill Resume dnll ahead 9432 - 9678 ft, No gain /Iosses WOB 14 RPM 70. SPM 100, GPM 296, PRESS 3000, TQ 6000 Up 171 Dn115, Rot 138 lAST = 3 hrs, ART = 11 14 hrs Cont dnll ahead 6 3/4 hole drctnl, 9678 to TD at 10400 ft Confirm with on site geologist I Clrc I cond mud. pump sweep, no abnormal cuttings returns. I Pr,nlea 21~/2002 10 j? ~1 ~M BP EXPLORATION Operations Summary Report Page 4 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/26/2002 1/27/2002 1/28/2002 L -1 04 L -1 04 DRILL +COMPLETE NABORS NABORS 9ES Start: 1/17/2002 Rig Release: 1/30/2002 Rig Number: 9-ES Spud Date: 1/17/2002 End: From - To Hours Activity Code NPT Phase Description of Operations 15:30 - 17:00 1.50 DRILL P PROD1 shaker clean Pump wt pill for wiper trip, 17,00 - 20:00 3,00 I DRILL IP PROD1 Flow check. poh to 7 5/8 shoe at 3015 ft. Slight swabbing I various intervals. work free, 15 K overpull at 6168 ft, Remainder hole good condition, 20:00 - 21 :30 1.50 DRILL P PROD 1 Service top drive. slip I cut drlg line, 121 :30 - 00:00 2,50 DRILL P PROD 1 Flow check, Rih. 15K dn drag at 4858. 5163 ft, Resume rih to 5500 ft, 00:00 - 01 :00 1,00 DRILL P PROD1 Cont RIH. Work thru tight spot at 8900'. RIH to 10400', 01 :00 - 03:00 2,00 DRILL P PROD1 Clrc and sweep hole clean for casing, Spot casing lubricant pill on bottom. Pump pill. 03:00 - 04:30 1,50 DRILL P PROD1 Monitor well - OK. POH 23 stds & rack back, Hole condition good, 04'30 - 10:00 5,50 DRILL P ,PROD1 POH LD 240 jts DP, 1 ° 00 - 10: 15 0 25 DRILL P I PROD 1 PJSM prior to unloading nuclear source from MWD. 10.15-13:00 2.75 DRILL P PROD 1 Stand back HWDP, Unload source, LD BHA, Break bit off motor. Clear floor, 13:00 - 14:30 1.50 CASE P COMP RU to run 3,5/5.5" casing, MU hanger on to landmg Joint and check spaceout in wellhead, 14:30 - 14:45 0,25 CASE P COMP PJSM prior to running casing, 14:45-17:30 I 2,75 CASE P COMP MU 3,5" shoe track & chk floats, Run 21 jts 3,5" casing & jewelry per programme, MU Baker casing seal receptacle, 17:30 - 19:30 2,00 CASE P COMP Run 5,5" casing per programme down to 7 5/8" shoe at +1- 3000', 19:30 - 20:00 0,00 CASE P COMP I Break circ and pump 1,5 casing vols. Saw minor loss when establishing circ but full returns once circulating, 20:00 - 00:00 4,00 CASE P COMP Cont RIH with 5,5" casing, When crossover point between 3,5" & 5 5" reached approx 5700' MD. started losing fluid, 140 jts in 100:00 - 08:00 hole at midnight. 8,00 CASE P COMP Cont running 3.5/5,5" casing. Getting no returns when running, I MU hanger and landing joint. Land casing, Lost 111 bbls mud while running casing, 08:00 - 09:30 1 50 CASE P COMP Work pipe and break clrc and stage up from 1 bpm to 5 bpm trying to establish circulation & get returns. No success at any pump rate - total losses. Work mandrel hanger back down on seat & park, Cont circ at 1 BPM while RU cementers and spotting vac trucks, Fluid lost while circ was 205 bbl. 1°9:30 - 09:45 0,25 CASE P COMP PJSM with crew, service co reps. drivers for cement job & displacement. 0945 - 10.45 1 00 CEMT P COMP Batch up tall slurry. 10.45 - 11:15 0,50 CEMT P COMP Pump 5 bbl CW100 preflush @ 8,3 ppg, Test lines to 4000 psi. Pump 20 bbl CW1 00 followed by 40 bbl Mudpush XL spacer @ 109 ppg. 11'15-12:00 ° 75 CEMT P COMP Pump 75 bbl LiteCrete lead slurry at 11 5 ppg followed by 40 bbl Class G tall slurry at 158 ppg, Final rate - 4,5 bpm @ 1350 pSI Stili no returns while pumpmg, 1 2 00 - 1 2' 1 5 I 0 25 CEMT P COMP Attempt to load combi btmltop Weatherford plugs m head Had I difficulty gettmg plugs below mlets on head, 12'15 - 12 30 0 25 CEMT P ICOMP Kick plug out of head with 2 5 bbl seawater SD and verify plug left head - OK Resume displacement. #1 rig pump started airing up Attempt to get good discharge pressure without success, Switch to #2 pump and continue displacement out of rig brine tanks Pr ,nlt?j "2/J/20ú'2 10 32 41 AM BP EXPLORATION Operations Summary Report Page 5 of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -104 L -1 04 DRILL +COMPLETE NABORS NABORS 9ES Start: 1/17/2002 Rig Release: 1/30/2002 Rig Number: 9-ES Spud Date: 1/17/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 1/28/2002 12:30 - 14:00 1.50 CEMT P CaMP Continue displacing cement with brine monitoring pit volumes and following recommended rate reduction schedule per DS, Stop displacement when volume indicates calc displacement + 12 bbl pumped, Bleed off pressure, Floats holding, 14:00 - 15:45 1,75 WHSUR P CaMP Conrer with Anch DS & DE on way forward while installing packoff assembly in wellhead. Test same to 5000 psi - OK. Agree to resume displacement to see if plug will bump. 15:45 - 16:30 0.75 CEMT P CaMP Resume displacement. Pressure continues to increase. indicating good cement rise in annulus. Continue displacement and bump plug with 2000 psi (500 psi over circ pressure), 116:30 - 18:30 Bleed off pressure. Floats holding. 2,00 RUNCOrvP CaMP RU 3 1/2" tubing running equp't. Make dummy run with hanger and landing joint - OK, 18:30 - 00:00 5,50 RUNCOrvP COMP MU seal assembly, sliding sleeve, i jt. #1 GLM with shear 4,00 RUNCO~ valve Run 3 1/2" tubing per programme, 1/29/2002 00:00 - 04:00 CaMP Continue RIH with 3 1/2" tubing to SVLN, 231 jts, 04:00 - 04:30 0,50 RUNCOtIIP CaMP Close BOP and pressure test casing to 3000 psi. I 04:30 - 08:00 3,50 RUNCOIVP CaMP MU SVLN assembly, Hook up control line & lock 5000 psi in same, Cont RIH with tubing, When RIH with jt 279. ctrlline lost pressure suddenly, 0800-10:00 2,00 RUNCOIVN DFAL CaMP POH racking back 3 1/2" tubing to SVLN, Control line crimped and flattened in 3 places @ jt 245, 243. 242 plus bands missing from jts 249, 235, Test control line @ surf & had obvious leak(s). Test dummy in SVLN to 5000 psi - OK, Swap out control line spools, 10:00 - 13:30 3,50 RUNCOIVN DFAL CaMP RIH with tubing from derrick. banding control line on other side of pipe & attaching bands in middle of each joint. 13,30 -15:30 2,00 RUNCOrvP CaMP Run remaining joints of 3 1/2" tubing from pipeshed, 304 joints run excluding spaceout. 15:30 - 18:00 2.50 RUNCOrvP CaMP Circ down @ 1 BPM and see seal assembly enter top of PBR. Stop circ and sting fully into PBR. POH and space out with pups to put seal assembly 1-2' from fully inserted, MU tubing hanger and hook up control line to same, Test penetration to 5000 psi - OK, 18:00 - 20:00 2 00 RUNCOrvP CaMP Circ in clean seawater to annulus. corrosion inhibitor around seal assembly to bottom GLM, clean seawater to tubing, 20:00 - 21 :00 1,00 RUNCOrvP CaMP Circ in to top of PBR to verify space out, SD pump, sting in and land tubing hanger. Check hanger landed and RILDS, RD Camco/Schlum & clear floor 21 00 - 23:00 2,00 RUNCOrvP CaMP Hook up test pump, Pressure test surface lines to 5000 psi - OK, Test tubing to 4500 psi for 30 mln - good test. Bleed tubing pressure to 2000 psi and pressure test annulus to 4500 pSI for ICOMP 30 min - good test. Bleed tubing pressure down and shear DCK-3 shear valve with 2500 psi differential. 23,00 - 23,30 0,50 RUNCOrvP Back out LJ RD test lines, Clear floor, 23 30 - 00 00 0 50 WHSUR P CaMP Run In TWC and set in tubing hanger. 1/30/2002 00'00 - 00' 30 0 50 RUNCOrvP CaMP Test twc to 2800 psi. blow dn lines 00 30 - 03'00 2 50 BOPSUR P COMP Nipple dn bope 1 all components, 03 00 - 06:00 3 00 WHSUR P COMP Nipple up prod tree test all seals to 5000 pSI. Test control lines All tests successful 06 00 - 07:00 1 00 WHSUR P CaMP Pull rwc with dsm, 0700 - 10,30 3 50 CHEM P CaMP RU to hot oil equip to freeze protect. test lines. rev circ 112 Pr,nr,;.d 2W2002 10 32 J 1 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date BP EXPLORATION Operations Summary Report Page 6 of 6 L -1 04 L -1 04 DRILL +COMPLETE NABORS NABORS 9ES Start: 1/17/2002 Rig Release: 1/30/2002 Rig Number: 9-ES Spud Date: 1/17/2002 End: 1/30/2002 07:00 - 10:30 From - To Hours Activity Code NPT Phase CaMP 10:30 - 12:00 Description of Operations 3,50 CHEM P bbls hot oil 1,3 bpm at 1600 psi. "U" tube, equalize fluid columns, SET BPV, SECURE WELL, RELEASE NABORS RIG 9 ES. THIS DATE 1/30/02 1200 HRS 1,50 WHSUR P CaMP Pr,nlE-oJ 2/41;¿Liú2 10 32 ~1 AM Well: Field: API: Permit: L -104 Prudhoe Bay 50-029-23060-00 201-238 Rig Accept: 01/17/02 Rig Spud: 01/17/02 Rig Release: 01/30/02 Drilling Rig: Nabors 9ES POST RIG WORK 02/09/02 RIG UP WIRELlNE FOR DRIFT & TAG. 02/10/02 PULLED DSSSV @ 2294' SLM. PULLED 111 BOTTOM LATCH RP SHEAR VALVE FROM GLM #1 @ 9548' SLM. SET BTM LATCH DUMMY GLV IN GLM #1, HIT CEMENT AT 9900', BAILED DOWN TO 9960' SLM AND RAN MRT TEMP. RECORDER TO SAME DEPTH FOR A TEMP OF 156 DEG.(SAME MRT SHOWED A TEMP OF 172 DEG @ 9672' SLM)?? WELL LEFT SHUT IN. 02/11/02 RIH WI PSPIMRT, TAGGED TD @ 9905' (SOFT BTM). LOG PRESI TEMP & JEWELRY LOG UP TO 2200'. POOH CHANGE TO SCMT-BB STRING (44'), RIH TO TD & LOG CEMENT UP TO 9450' , PRESSURE UP WELLBORE TO 4000#, LOG SAME SECTION. LOG REPEAT PASS OVER TOC FOUND @ 9630', POOH, RD POST JOB INSPECTION, NOTIFY DSO OF WELL STATUS & DEPARTURE, LET WELL SI, MO. 02/21/02 1ST RIH RAN 2.511 HSD 6 SPF PF 30' GUN. TAGGED SOFT AT APPROX. 9750 FT. UNABLE TO GET DOWN DEEPER TO PERFORATING ZONE. POOH. JOB ABORTED. 02/25/02 CALL OUT GREASE CREW TO OPEN SSV, COMPUTER SYSTEMS ARE DOWN, NO CONTROL OF SSV. RIH WITH WEATHERFORD 2.125" MOTOR AND 2.75" 3-BLADE CEMENT MILL. CLEAN FROM 9700' TO TD @ 10245'. DID NOT SEE ANY SIGNIFICANT MOTOR WORK. PUMPED 20 BBL BIOZAN SWEEP OFF BOTTOM. POOH @ 80°0. FREEZE PROTECTED TBG. TO 2500' WITH 60/40 METHANOL. RIG DOWN. LEFT WELL SI. 02/26/02 DRIFTED TUBING AND TAGGED PBTD @ 10232' SLM WITH A 10' LONG 2.5" DUMMY GUN TARGET DEPTH = 9926'. WELL LEFT SHUT IN. 02/27/02 PERF 9860-9900 WITH 2.5" HSD 2506 POWERFLOW (BH CHARGES) 6SPF 60 DEG PHASING EHD 0.66", PENE 4.8". TAGGED TD WITH GUN 1 AT 10246'. WHPIIAPIOAP BEFORE GUN 1 5010/200, AFTER GUN 2 20010/200 (NO CHANGE IN WHT). ALL SHOTS FIRED. ATTEMPT STATIC WITH PBMS. PRESS DATA UNSTABLE AFTER 1 HR, TEMP = 158 F. SLlCKLlNE TO RUN STATIC IN AM. PAD OPER NOTIFIED OF WELL STATUS. 02/28/02 PERFORM SUCCESSFUL STATIC SURVEY.SET X CATCHER SUB. STATIC RESULTS MD TVDSS 10,071 6700 9,967 6600 9,863 6500 9,967 6600 PRESS. TEMP DEG E 3294 160 3256 158 3207 156 3260 158 03/01/02 SET SPMG IN STA # 1, LITTLE RED MITIA ( PASSED ), PULLED CATCHER SUB. SET FRAC SLEEVE ( 2.85 OD - 2.20 ID - 24" LONG) @ 2295' SLM. 1-104, Post Drilling Work Page 2 ) 03/02/02 PRESSURE TEST LINES TO 8500 PSI. PUMP 100 BBL YF125LG DATA FRAC @ 25 BPM (DISPLACE TO PERFS @ 10 BPM). CALC TC=6.3 MIN FLUID EFF=48°,~. ADJUST PAD TO 100 BBLS. START DH WI 100 BBL YF125LG PAD. RAMP FROM 1 TO 6 PPA 16/20 C-LlTE SAND. PUMP 6,7,8,9 PPA FLAT STAGES. PRESSURED OUT 113 BBLS INTO 9 PPA STAGE. 132,321# PROP PUMPED. 107,043# PROP BEHIND PIPE. LEFT -25,278# IN WELL BORE. ATTEMPTED TO CIRC DIESEL AROUND WELL HEAD. REMOVED TREESAVER(CUPSINTACn. MIRU DS CTU#3. MU 2" JS NOZZLE. RIH. WORK THROUGH ICE PLUG IN THE P-SUB. START FCO W/2% XSL KCL & 2# BIOZAN. 03/03/02 CLEAN OUT TO 9980' CTDM, POOH WASHING JEWELRY ON THE WAY OUT. FREEZE PROTECT TO 3500' WITH 60/40 MEOH. SET CATCHER SUB.PULL SPMG FROM ST# 1 @ 9546' WLM. 03/04/02 SET LGLV'S IN ST#S 2 AND 3. SET SIOGLV IN ST # 1. 03/05/02 RAN 3 112" GR TO 9644' SLM & SET DOWN, BEAT DOWN FOR 5 MINS, PULL BIND, HIT ONE OIL JAR LICK, TOOLS CAME FREE, REPEAT, SAME RESULTS. DID NOT HAVE CATCHER SUB, GR HAD SMALL PIECE OF BRASS SHEAR STOCK WEDGED IN DOG RETAINER PRVENTING DOGS ON GR FROM LATCHING. 03/06/02 RAN 31/2" GR & SET DOWN @ 9577' SLM, WORK GR TO 9581' SLM. GR HAD BRASS SHEAR STOCK MARKINGS ON ALL SIDES PREVENTING GR FROM REACHING THE CATCHER SUB. RAN 3 1/2" WIREBRUSH WI 1 3/4" PUMP BAILER BELOW TO 9694' SLM, WORK BRUSH & BAILER. BAILER FULL OF FRAC SAND. WIREBRUSH HAD WIRE MESH TANGLED ON IT. DISCUSS JOB WI COMPANY REP, RUN 1 3/4" PUMP BAILER WI 2.25 SWAGE ON TOP & SET DOWN @ 9574' SLM, RET FULL BAILER OF FRAC SAND ONLY. WELL LEFT SHUT-IN. 03/28/02 MIRU DS CTU #3. WELL IS SI, RIH W/2.5" JS NOZZLE. RIH. FCO TO 9709.5', TAG X-LOCK CATCHER SUB @ 9709.5'. MU BAKER MHA AND RIH. LATCH FISH @ 9711.7'. START POOH, HAVE TROUBLE WICHAINS SLIPPING - HAVE LITTLE RED COME & PUMP 90 BBLS DIESEL DOWN IA. 03/29/02 BREAK FREEZE IN LUBRICATOR, TAG UP. 3-1/2" CATCHER SUB WAS RETRIEVED. TURN WELL OVER TO APC TESTERS. ÞJ\JADRILL SCHLUHBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay / Borealis \lIJe 11 . . . . . . . . . . . . . . . . . . . . .: L - 104 A PIn u.mbe r . . . . . . . . . . . . . . .: 5 0 - 02 9 - 2 3 060 - 0 0 Engineer. . . . . . . . . . . . . . . . .: St. lvnour Rig: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- l-1ethod for posi t ions. . . . .: r-linimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent da twn. . . . . . . . . .: Mean Sea Level Depth reference..........: Drillers Pipe Tally GL above permanent.......: 50.60 ft KB above permanent.......: N/A OF above permanent.......: 79.10 ft ----- Vertical section origin---------------- La tit ude (+ N:' S -) . . . . . . . . . : 0 . 00 f t Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- La tit ude (+ N / S -) . . . . . . . . . : - 999 .25 f t Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 99.75 degrees [ (c) 2002 Anadr i 11 IDE.;L I D6_1C_1 0] 27-Jan-2002 00:20:05 Spud date. . . . . . . . . . . . . . . . : Last survey date.. . . . . . . . : Total accepted surveys...: r'lD of first surve:/.......: r-m of last survey........: Page 1 of 5 17-Jan-02 26-Jan-02 113 0.00 ft 10400.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2000 Magnetic date...... . . . . . .: 17-Dec-2001 Magnetic field strength..: 1149.06 HCNT Magnetic dec (+E/W-).....: 26.15 degrees l-1agnetic dip... ..........: 80.75 degrees ----- HWD Reference Refer-ence Reference '1'01 erance Tolerance Tolerance survey Reference G.............. : H.............. : Dip. . . . . . . . . . . . : of G...........: of H...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.39 HCNT 80.76 degrees (+/-) 2.50 mGal (+/-) 6.00 HCN'T (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.14 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.14 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degreE: 0.00 A1\J~.DR ILL SCHLUNBERGER Su rvey Repo:r: t -------- -------- Seq I-Ieasured # depth ( f t ) -------- -------- 1 2 3 4 5 0.00 135.20 193.63 293.90 385.90 6 7 B 9 10 477.04 568.73 6~,9. 86 751.91 845.10 11 12 13 14 15 939.22 1032.35 1125.95 1218.99 1313.05 16 17 18 19 20 1406.35 1495.84 1591.77 1686.90 1781.00 21 22 23 24 25 1873.86 1967.95 2061.23 2155.29 2247.72 26 27 28 29 30 2341.66 2434.70 2528.83 2622.44 2715.73 ------ ------ 1ncl angle (deg) ------ ------ 0.00 0.35 0.51 0.54 0.64 2.02 3.57 4.25 5.29 5.96 6.76 7.99 9.58 9.85 11.36 14.06 16.92 16.22 18.51 20.51 23.36 24.63 27.79 30.65 34.47 38.52 41.15 46.44 52.76 57.75 ------- ------- Azimuth angle (deg) ------- ------- 0.00 283.81 283.81 283.81 141.43 136.05 143.41 145.21 150.46 152.43 153.66 138.30 119.19 107.83 101.04 96.55 96.97 95.33 100.63 100.25 100.78 98.34 99.59 98.68 98.66 96.28 96.84 100.57 101.62 100.56 ------ ------ Course length ( f t ) ------ ------ 0.00 135.20 58.43 100.27 92.00 91.14 91.69 91.13 92.05 93.19 94.12 93.13 93.60 93.04 94.06 93.30 89.49 95.93 95.13 94.10 92.86 94.09 93.28 94.06 92.43 93.94 93.04 94.13 93.61 93.29 -------- -------- TVD depth ( f t ) -------- -------- 0.00 135.20 193.63 293.89 385.89 477.00 568.58 659.50 751.23 843.97 937.51 1029.88 1122.40 1214.11 1306.57 1397.57 1483.80 1575.75 1666.54 1755.24 1841.37 1927.32 2011.00 2093.09 2170.97 2246.48 2317.92 2385.85 2446.49 2499.65 27-Jan-2002 00:20:05 -------- -------- Vertical section ( f t ) -------- -------- 0.00 -0.41 -0.85 -1.77 -1.81 -0.14 3.23 7.65 12.73 18.38 24.61 32.90 45.34 60.52 77.75 98.25 122.12 149.42 177.77 209.19 243.87 282.13 323.31 369.22 418.95 474.75 534.25 599.34 670.57 747.18 ---------------- ---------------- Displ +N/S- 1ft) Displ +E/IIJ- ( f t) ---------------- ---------------- 0.00 0.10 0.20 0.4.2 0.12 -1.4.3 -4.89 -9.94 -16.43 -24.46 -33.75 -43.50 -52.16 -58.37 -62.61 -65.66 -68.48 -71.42 -75.44 -81.13 -87.47 -93.80 -100.25 -107.52 -115.02 -122.22 -129.04 -138.99 -152.73 -167.45 0.00 -0.40 -0.83 -1.72 -1.82 -0.39 2.44 6.05 10.09 14.45 19.17 25.91 37.04 51.37 68.13 88.41 112.14 139.34 167.41 198.32 232.42 270.14 310.83 356.16 405.32 460.71 519.91 584.24 654.16 7'29.36 Page --------------- --------------- Total displ ( f t) .Z\t Azim (deg) --------------- --------------- 0.00 0.41 0.85 1.77 1. 82 1.48 5.46 11.64 19.28 28.41 38.82 50.63 63.97 77.76 92.53 110.12 131.40 156.57 183.62 214.27 248.33 285.97 326.59 372.03 421.33 476.64 535.68 600.55 671.75 748.34 0.00 283.81 283.81 283.81 273.91 195.16 153.50 148.65 148.44 149.42 150.41 149.22 144.62 138.65 132.58 126.60 121.41 117.14 114.26 112.25 110.62 109.15 107.88 106.80 105.84 104.86 103.94 103.38 103.14 102.93 2 of 5 DLS (deg/ 100 f) 0.00 0.26 0.27 0.03 1. 21 1 t::~, . ..JL 1. 73 0.76 1.22 0.75 0.86 2.48 3.53 2.08 2.08 3.08 3.20 0.88 2.92 2.13 3.08 1.71 3.44 3.0B 4.13 4.57 2.85 6.25 6.81 5.43 ------ ------ Srv"'/ tool type Tool qual type ------ ------ TIP r'fWD Inc. Only HWD_IFE_HSA MWD_IFE_HSA IvIWD_I FR_HS.~. MWD_IFR_MSA r11l'lD_IFR_MSA 1'111'10_1 FR_HSA rvfWD_I FF._1v1SA fvIWD_I FR_r-ISA rv1WD- I FR_HSA HWD_IFR_HS.~. HWD_I FR_IvISÞ. HWD_1 FR_MS.i\ r-MD_1 FR_HSÞ. r-1WD_IFR_HSA rv1WD- I FR_rvISÞ. rvIWD- I FR_MSA rv1WD_I FR_rv1SA r1WD_I FR_HSA HWD_IFR_MSA NWD_IFR_MS.Z\ I-HrJD_I FR_NSA MWD_1 FR_t>1SA IvIWD- I FR_NSi\ r'IWD_1 FR_HSA r,IWD- I FR_t>1SA r-'IWD - I FR_r-1SA MV'JD- I FP_HSA t-'IWD_I FR_MSÞ. þJ\jADRILL SCHLUJ.1BERGER Survey Report -------- -------- Seq r1easurecl # depth ( f t ) 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 -------- -------- 2808.36 2902.54 2963.71 3110.27 3204.58 3299.83 3392.79 3485.88 3579.33 3672.76 3765.14 3858.09 3952.46 4045.21 4138.54 4231.71 4326.04 4419.51 4513.55 4605.92 4699.55 4792.93 4885.92 4979.82 5073.04 5166.88 5259.36 5352.52 5446.67 5540.40 ------ ------ Incl angle (deg) ------ ------ 59.31 59.27 61.40 62.83 63.60 63.28 62.52 62.20 62.15 62.45 62.44 61.99 60.81 61.28 58.79 58.29 57.90 57.86 57.63 57.45 57.14 59.29 59.46 59.14 58.94 59.90 59.30 58.58 59.83 60.99 ------- ------- ------ - - - --- Azimuth Course angle length ( deg ) ( f t ) ------- ------- 99.02 99.08 98.52 100.07 100.33 101.05 101.38 102.24 102.29 103.24 102.23 101.82 100.57 100.75 99.71 99.12 98.19 98.28 97.88 98.73 98.37 97.93 97.37 97.58 97.84 98.24 97.35 97.52 97.70 99.32 ------ ------ 92.63 94.18 61.17 146.56 94.31 95.25 92.96 93.09 93.45 93.43 92.38 92.95 94.37 92.75 93.33 93.17 94.33 93.47 94.04 92.37 93.63 93.38 92.99 93.90 93.22 93.84 92.48 93.16 94.15 93.73 -------- -------- TVD depth ( f t ) -------- -------- 2548.00 2596.10 2626.37 2694.92 2737.42 2780.01 2822.36 2865.55 2909.17 2952.60 2995.33 3038.66 3083.84 3128.74 3175.35 3223.98 3273.83 3323.53 3373.72 3423.29 3473.88 3523.07 3570.44 3618.38 3666.34 3714.07 3760.87 3808.94 3857.14 3903.42 27-Jan-2002 00:20:05 -------- -------- ve:ctical section ( f t ) -------- -------- 826.18 907.15 960.29 1089.82 1174.01 1259.19 1341.92 1424.33 1506.90 1589.50 1671.29 1753.46 1836.28 1917.43 1998.27 2077.75 2157.81 2236.94 2316.44 2394.35 2473.12 2552.46 2632.43 2713.10 2792.99 2873.74 2953.46 3033.20 3114.01 3195.49 ---------------- ---------------- Displ +N/S- ( f t) Oispl +E/W- ( f t ) ---------------- ---------------- -180.88 -193.61 -201.74 -222.67 -237.58 -253.39 -269.48 -286.36 -303.91 -322.19 -340.25 -357.38 -373.47 -388.48 -402.85 -415.85 -427.90 -439.24 -450.42 -461.68 -473.39 -484.64 -495.29 -505.80 -516.52 -527.82 -538.64 -548.97 -559.68 -571.74 807.21 887.17 939.70 1067.53 1150.39 1234.11 1315.28 1396.00 1476.76 1557.44 1637.32 1717.75 1799.02 1878.7E: 1958.34 2036.74 2115.91 2194.25 2272.99 2350.11 2428.02 2506.59 2585.90 2665.95 2745.17 2825.16 2904.19 2983.32 3063.48 3144.08 Page --------------- --------------- Total displ ( f t ) At Azim --------------- (cleg) --------------- 827.23 908.06 961.11 1090.51 1174.67 1259.85 1342.60 1425.07 1507.71 1590.41 1672.30 1754.53 1837.38 1918.52 1999.34 2078.76 2158.74 2237.78 2317.19 2395.03 2473.74 2553.01 2632.90 2713.51 2793.34 2874.04 2953.72 3033.41 3114.19 3195.65 102.63 102.31 102.12 101.78 101.67 101.60 101.58 101.59 101.63 101.69 101.74 101.75 101.73 101.68 101.62 101.54 101.43 101.32 101.21 101.11 101.03 100.94 100.84 100.74 100.66 100.58 100.51 100.43 100.35 100.31 3 of 5 DLS (deÇJ/ 100 f) 2.20 0.07 3.57 1.35 0.85 0.75 0.88 0.89 0.07 0.96 0.97 0.62 1.71 0.53 2.84 0.76 0.93 0.09 0.43 0.80 0.46 2.34 0.55 0.39 0.32 1. 09 1.05 0.79 1.34 1.95 ------ ------ S r V)' tool type 'T'oo 1 qual type ------ ------ 1-fWD_IFR_HSA IvIWO_IFR_HSA 1.'IWO_I FR_1'lSA 1'.1WD_IFR_HSÞ. rvfWD_I FR_HSÞ. 1vfWD- I FR_HSJ>. 1"1WD- I FP._HSA 1vl\'\IO_I FR_1'lSA 1>1WD_I FP._NSA tIfWD_I FR_NSJ>. I'IWO_I FP._NSA I.IWO_I FR_HSA 1vIWD_I FR_1.ISA I1WD_I FP._MSA I'-1WD_I FR_HS.:'. 1>1WD_I FR_IvISA I>1WD_IFP._IvISA MWD_IFR_HSA 1vn,.ro_I FR_IvIS.ù. I'-1WD_IFR_I'IISA I1WD_I FR._HSA 1vIWD_I FR_I1SA t-IWD_I FR_I~lSA I~D_IFR_f'.lSÞ. 1''WD_I FR_IvlSÞ. 11\^lD_I FR_I'IISA 1>1WD- I FR_MSA HWD_I FR_IvtS.LI. HWD_IFR_MSA HWD_I FR_r'ISA ,~NÞ.DR I LL SCHLLTNBERGER Su r'lley Repor t Seq If -------- -------- [1easured depth ( f t ) -------- -------- 61 62 63 64 65 5634.63 5727.90 5821.10 5914.85 6009.13 66 67 6102.66 6196.67 6291.05 6384.80 6478.59 68 69 70 71 72 73 74 75 6571.16 6664.48 6757.13 6849.04 6942.56 76 77 78 79 80 7036.01 7130.22 7225.44 7317.79 7410.76 81 82 83 84 85 7505.48 7598.37 7691.93 7785.85 7879.69 86 87 88 89 90 7972.79 8067.08 8160.47 8253.52 8347.09 ------ ------ Incl angle (deg) ------ ------ 61.36 61.59 61.46 59.96 58.97 58.54 58.14 58.92 59.46 59.36 59.27 58.59 57.88 57.81 57.73 57.85 57.59 57.20 57.34 58.14 59.73 59.16 58.74 58.22 57.69 56.83 56.46 55.85 55.34 54.77 ------- ------- ,".zimuth angle (deg) ------- ------- 99.50 100.74 101.94 103.06 11) 4 . 2 9 104.87 104.13 101.66 100.77 98.41 98.50 99.65 99.25 97.95 98.55 98.20 97.23 97.23 98.71 97.96 97.80 96.04 97.02 95.57 95.32 95.62 96.03 95.44 95.01 94.56 ------ ------ Course length (ft) ------ ------ 94.23 93.27 93.20 93.75 94.28 93.53 94.01 94.38 93.75 93.79 92.57 93.32 92.65 91.91 93.52 93.45 94.21 95.22 92.35 92.97 94.72 92.89 93.56 93.92 93.84 93.10 94.29 93.39 93.05 93.57 -------- -------- 'TVD depth ( f t ) -------- -------- 3948.85 3993.40 4037.83 4083.70 4131.60 4180.11 4229.46 4278.73 4326.75 4374.49 4421.73 4469.89 4518.66 4567.58 4617.46 4667.27 4717.58 4768.89 4818.82 4868.45 4917.32 4964.55 5012.81 5061.91 5111.70 5162.05 5213.89 5265.91 5318.48 ~d72.08 27-Jan-2002 00:20:05 -------- -------- Vertical section ( f t ) -------- -------- 3278.05 3359.99 3441.88 3523.55 3604.56 3684.24 3763.98 3844.35 3924.84 4005.57 4085.16 4165.08 4243.85 4321.65 4400.73 4479.77 4559.37 4639.51 4717.16 4795.75 4876.84 4956.73 5(136.75 5116.67 5195.98 5274.07 5352.65 5430.02 5506.55 5582.96 ---------------- ---------------- Displ HJ./ S- ( f t) Displ +E/W- ( f t ) ---------------- ---------------- -585.24 -599.64 -615.75 -633.44 -652.63 -672.76 -692.80 -710.75 -726.41 -739.86 -751.57 -764.17 -777.10 -788.74 -800.09 -811.61 -822.30 -832.40 -843.17 -854.56 -865.68 -875.33 -884.44 -893.22 -900.77 -908.23 -916.22 -923.98 -930.97 -937.37 3225.53 3306.20 3386.52 3466.34 3545.25 3622.63 3700.10 3778.56 3857.54 3937.14 4015.89 4094.82 4172.52 4249.45 4327.74 4405.97 4484.90 4564.47 4641.41 4719.19 4799.56 4878.96 4958.60 5038.17 5117.35 5195.31 5273.66 5350.83 5427.29 5503.72 Page --------------- --------------- Total displ ( f t ) At .~.z irn --------------- (deg) --------------- 3278.19 3360.14 3442.04 3523.75 3604.82 3684.57 3764.40 3844.83 3925.34 4006.06 4085.61 4165.51 4244.27 4322.03 4401.08 4480.10 4559.66 4639.75 4717.37 4795.94 4877.00 4956.86 5036.85 5116.74 5196.03 5274.10 5352.66 5430.02 5506.55 5582.97 100.28 100.28 100.31 100.36 100.43 100.52 100.61 100.65 100.66 100.64 100.60 100.57 100.55 100.52 100.47 100.44 100.39 100.34 1C10.30 100.26 100.22 100.17 100.11 100.05 99.98 99.92 99.86 99.80 99.73 99.67 4 of 5 DLS (deg/ 100f) 0.43 1.19 1.14 1.91 1.54 0.70 0.79 2.38 1.00 2.17 0.13 1.28 0.85 1.20 0.55 0.34 0.91 0.41 1.36 1.10 1.68 1.74 1.00 1.43 0.61 0.96 0.53 0.84 0.67 0.73 ------ ------ S r V'.I tool type Tool qual type ------ ------ HWD_IFR_HSA [-fWD_I FR_HSA MWD_I FR_t-1SA HWD- I F'R_NSÞ. ['IWD_I FR_NSA I.fWD- I FR_HSA HWD- I FR_I.lSA 1-1WD_IFR._NSÞ. [-IWD_I FR_[-ISÞ. t-'IWD_I FR_HSA t-IWD- I FP._NSA [-IWD_I FR_HSA [-IWD_I FR_[vISA ['1WD_I FR_[-ISA ['IWD_IFR_HSA 1-1WD_I FR_[-ISÞ. [.IWD- I FR_I.'ISA HWD_IFR_NSÞ. [-IWD- I FR_HSÞ. NWD_I FR_HS.i\ [vIWD- I FR._HSA HWD_IFR._NSA Iv1WD- I FP._HSA ["IWD_I FR_YvISA [-IWD_I FR_HSA [v1WD- I FR_[.1SÞ. Y-I\II/D- I FR_I-1SÞ. ['lfwTI- I FP._I-1SA IvfWD- I FR_[.1SP-. [-fWD_I FR_NSA ANADRILL SCHLUT-1BERGER Survey Report Seq # 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 -------- -------- r'1easured depth ( f t ) -------- -------- 91 92 93 94 95 8440.53 8533.59 8626.89 8722.07 8813.34 8908.49 9001.84 9095.88 9188.72 9281.64 9375.99 9468.33 9560.96 9652.93 9747.11 9841.14 9934.92 10027.92 10120.88 10212.56 111 10305.53 112 10345.12 ------ ------ Incl angle (deg) ------ ------ 52.82 50.19 48.24 46.30 44.38 41.78 38.33 36.14 33.30 31.66 29.24 26.81 23.18 20.73 18.05 16.25 16.07 15.96 15.31 14.72 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 94.76 96.05 95.42 95.70 96.61 97.40 99.40 101.42 105.56 105.03 103.74 103.91 105.06 106.80 106.84 107.46 107.66 107.35 106.41 106.28 13.87 108.14 13.51 108.54 Final Projected Survey: 113 10400.00 13.50 108.54 ------ ------ 93.44 93.06 93.30 95.18 91.27 95.15 93.35 94.04 92.84 92.92 94.35 92.34 92.63 91.97 94.18 94.03 93.78 93.00 92.96 91.68 92.97 39.59 54.88 [(c)2002 Anadrill IDEAL ID6_1C_10J -------- -------- TVD depth ( f t ) -------- -------- 5427.27 5485.19 5546.13 5610.71 5674.86 5744.36 5815.80 5890.67 5966.98 6045.37 6126.70 6208.20 6292.15 6377.44 6466.27 6556.11 6646.19 6735.58 6825.10 6913.65 7003.74 7042.21 7095.57 27-Jan-2002 00:20:05 -------- -------- ver:tical section ( f t) -------- -------- 5658.06 5730.6E 5801.14 5870.8ï :,935.65 6000.56 6060.60 6117.49 6170.23 6219.89 6267.54 6310.81 6349.81 6384.00 6415.02 6442.52 6468.38 6493.80 6518.66 6542.25 ---------------- ---------------- Displ +N/S- ( f t) Displ +E/W- ( f t ) ---------------- ---------------- -943.49 -950.34 -957.40 -964.17 -971.12 -979.04 -987.77 -99B.03 -1010.29 -1023.46 -1035.35 -1045.72 -1055.48 -1064.89 -1073.94 -1082.10 -1089.98 -1097.70 -1104.97 -1111.66 5578.86 5651.36 5721.65 5791.23 5855.77 5920.27 5979.69 6035.65 6087.06 6135.18 6181.49 6223.62 6261.51 6294.58 6324.50 6351.00 6375.88 6400.35 6424.32 6447.12 Page --------------- --------------- 'rota 1 displ ( f t ) .i\t Azim --------------- (deg) --------------- 56513.08 573CJ.71 5801.20 5870.95 593:,.75 6000.68 6060.73 6117.61 6170.33 6219.96 6267.60 6310.86 6349.85 6384.02 6415.04 6442.52 6468.38 6493.80 6518.66 6542.25 6565.01 -1118.44 6469.04 6565.02 6574.28 -1121.39 6477.94 6574.28 6586.94 -1125.46 6490.09 6586.95 99.60 99.55 99.50 99.45 99.42 99.39 99.38 99.39 99.42 99.47 99.51 99.54 99.57 99.60 99.64 99.67 99.70 99.73 99.76 99.ï8 99.81 99.82 99.84 S of 5 DLS (deg/ 100f) 2.09 3.03 2.15 2.05 2.22 2.79 3.94 2.67 3.97 1.79 2.66 2.63 3.95 2.76 2.85 1.92 0.20 0.15 0.75 0.64 1.04 0.94 0.02 ------ ------ S r V'}' tool t i1)e Tool qual type ------ ------ [-rWD_I FR_HSi\ HWD_I FR_HSÞ. NWD- I FR_['1SÞ. HWD - I FR_[-1SA HWD_IFR_NSA f-rWD_I FR_MSA [,rWD_IFR_MSA [,rWD_I FR_MSA [1WD_IFR_NSA [v1WD_I FR_MSA f1WD_IFP._HSA [IfWD_I FR_NSA [v1WD- I FR_NSA [.rWD_I FR_HSA HWD- I FR_[-1SA MvJD_I FR_NSA ["IWD- I FR_NS? rv1WD_I FR_HSA [vIWD_I FR_HSA t-'IWD_I FR_HSA [.IWD_I FR_[-ISA MWD_IFR_MS.q Projected Schlwnbergep Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well Job# L-104 aOI-d<-~Ç( L-106 ~OJ-d.¿;>',"-~ S-105 d 00 - /5 .;t L-120 L-120 dOri-OOCo L.120 22110 22111 22086 22086 22086 Log Description SCMT SCMT PROD PROFILEIDEFT/GLS PP IMP DATA MD VISION RESISTIVITY TVD VISION RESISTIVITY PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (AIŒ,I<O) Inc, Petrotectnicol Dato Center W2- 1 900 E Bemon Blvd, Anchorage AK 99508-425L1 Dote Delivered: RECEIVED r. ~ :\ P f') r. 1)002 ,,",,\, , L '- L AlœksOil & Ga& CtnIð.Commision Anchorage Date 02111/02 02110/02 02128/02 02109/02 02109/02 02109/02 3/20/2002 NO. 1910 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Color CD Sepia BL 2 2 ScrrlumtJerger DeS .3940 Arctic Blvci Suite 300 Anchorage AK 9950;5-,5789 Ann Sherrie R8C8iV8ð-h (j 0°12f"--~ SchllHRberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie -- Well Job # ì.\o L-104 IV) L-104 '"'ð L-104 ~ L-104 If L-104 22073 22073 22073 22073 22073 Log Description PP IMP DIN (PDC) MD VISION RESISTIVITY TVD VISION RESISTIVITY MD VISION DIN TVD VISION DIN PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Explorotion (Aloska) Inc, Petrotectnlcol Dota Center LR2- 1 900 E Benson Blvci. Anchoroge AK 99508-4254 Dote Delivered RECEIVED r.!.~ 8' 0 ~ "002 .["'1:, V L Alaska Oif & ~ Cons. CorrImiseion Anchorage Date 01/26/02 01/26/02 01/26/02 01/26/02 01/26/02 2/26/2002 NO. 1842 Company: Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color CD Sepia BL Schlurnberger DeS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 l\T1N: Sh¿.rrie Received~ ~ \ ~~~~E :F ~~~~~~!Æ / ALASKA OIL AND GAS / CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Sr. Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit L-I04 BP Exploration (Alaska), Inc. Permit No: 201-238 Sur Loc: 2425' NSL, 3529' WEL, Sec. 34, TI2N, RIlE, OM Btmhole Loc. 1297' NSL, 2250', WEL, Sec. 35, TI2N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced \vell. The pennit to drill does not exempt you from obtaining additional permits required by la\v from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Prudhoe Bay Unit L-l 04. Blo\vout prevention equipment (BOPE) must be tested in accordance \vith 20 AAC 25 035. Sufficient notice (approximately 24 hours) n1ust be given to allo\v a representative of the Con11TIission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, G 11",,~ k L;J.. - i ,2..-/ .1'1 , 1) Cammy Oechsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 14th day of December, 2001 jjc/Enclosures cc: Department of Fish & Game, Habitat Section \\'/0 encl. Department of Environmental Conservation w/o encl. ALAS. STATE OF ALASKA )Oll AND GAS CONSERVATION COI PERMIT TO DRILL 20 AAC 25.005 )¡SSION ~" \j,I' J..t{ 0 \ ß-\ ~(I:, 1 a. Type of work III Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2425' NSL, 3529' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 1322' NSL, 2399' WEL, SEC. 35, T12N, R11 E, UM At total depth 1297' NSL, 2250' WEL, SEC. 35, T12N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028240.1297' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casing Weight Grade CouDling 20" 91.5# H-40 Weld 7-5/8" 29.7# L-80 BTC 5-1/2" 15.5# L-80 BTC-M 3-1/2" 9.2# L-80 IBT-M Length 80' 2857' 9730' 740' 0 Exploratory 0 Stratigraphic Test III Development Oil 0 Service 0 Development Gas [jJ Single Zon~ð I) 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 77' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) û~t~¡;,YI J:.;:. ADL 028238,l) 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number ~~,:..: . L-104 9. Approximate spud date 01/02102 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10431' MD / 7063' TVD 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 59 Maximum surface 2766 psig, At total depth (TVD) 6506' / 3416 psig Setting Depth TQD Botom MD TVD MD TVD Surface Surface 801 80' Surface Surface 2857' 2577' Surface Surface 9730' 6401' 9730' 640 l' 10431' 7063' 11. Type Bond (See 20 AAC 25.025) 1 b. Type of well Number 2S 100302630-277 Hole 30" 9-7/8" 6-3/4" 6-3/4" Quantitv of Cement (include stage data) ~60 sx Arctic Set (Approx.) 283 sx AS Lite, 197 sx Class 'G' 180 sx LiteCrete, 160 sx Class 'G' (5-1/2" x 3-1/2" CementinQ Program) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED DEC 0 5 Z001 true vertical Alaska Oil & Gas Con&. Commissior; Anchorage Perforation depth: measured 20. Attachments III Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Neil MiiJe, 564-5119 Prepared By NamelNumber: Terrie Hubble, 564-4628 21. I hereby certify that the foreg I~ is true ancþêor~ct to the best of my ~nowl~~ge . Signed Lowell Crane (~'1I\l"'C""~ ¡C.f..L- TitlQ Senior Dnlllng Engineer Date I Z - Y - ~ I Commission Use Only Permit Number . API Number /ZL:' l- .Z;32~, 50- (Y2~t.~ 2- 3C'0C' -- e,e:.., Conditions of Approval: Samples Required 0 Yes lXI No Hydrogen Sulfide Measures 0 Yes ø No Required Working Pressure for BOPE 0 2K 0 3K ~_al's't~~rS\ \0ÇJ,?~~\- ~~ Approved By Cammy Oechsli Commissioner Form 10-401 Rev. 12-01-85 0 R 1 GIN A L (\ppr9('al 8~e See cover letter \ . ~. \ J. \ for other requirements Mud Log Required 0 Yes ~No Directional Survey Required I8(Yes 0 No D4K D5K D10K D15K 0 3.5K psi for CTU by order of the commission Date , ~. r~. 0 ) Submit In Triplicate I Well Name: IL-104 Drill and Complete Plan Summary I Type of Well (service 1 producer 1 injector): I Producer Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: X ::: 583,386.63' Y::: 5,978,149.77' 2425' FSL (2853' FNL), 35291 FEL (1750' FWL), Sec. 34, T12N, R11 E X::: 589,810' Y::: 5,977,120' 1322' FSL (3957' FNL), 23991 FEL (2880' FWL), Sec. 35, T12N, R11 E X ::: 589,958' Y::: 5,977,097' 1297' FSL (3981' FNL), 2250' FEL (3028' FWL), Sec. 35, T12N, R11 E I AFE Number: 15M4016 I Estimated Start Date: 11/2/2002 I I MD: 110,431' I 1 TVD: 17063' I I Ri~: 1 Nabors 9ES I OperatinQ days to complete: 113.6 1 BF/MS: 148.8' 1 1 RKB: 177.0' I Well DesiQn (conventional, slimhole, etc.): 1 Microbore (Iongstring) I Objective: 1 Kuparuk Formation Mud Program: 9-7/8" Surface Hole (O-2857'): Densitv (ppg) 8.5 - 8.6 9.3 - 9.5 9.6 max Viscosity (seconds) 300 200-250 200 - 250 Initial below Permafrost interval TD Fresh Water Surface Hole Mud Yield Point API FL PH (lb/100ftt!) (mls/30min) 50 - 70 15 - 20 30 - 45 15 - 20 30 - 45 15 - 20 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5 6 3,4" Intermediate 1 Production Hole (2857' - 10431 '): Interval Density Tau 0 VP PV (ppg) 9.3-9.5 Upper Interval Top of HRZ 4-7 20-25 10.3 5-8 20-25 L -104 Draft Drilling Program Fresh Water LSND API HTHP Fi Itrate Fi Itrate 4-6 pH 8-14 8.5-9.5 8-14 8.5-9.5 3-5 <10 by HRZ Page 1 Hydraulics: Surface Hole: 97/8" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-2,000 500 4" 17.5# 130 1900 10.2 N/A 18,18,18,12 .856 2,000'-2,857' 550 4" 17.5# 150 2400 10.2 N/A 18,18,18,12 .856 Production Hole: 6 3¡á" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 2857'-5500' 285 4" 17.5# 210 1700 - 1900 10.0 N/A 14,15,15 .495 5500' - 275 4" 17.5# 200 2200 - 2600 11.1 N/A 5x12 .552 10,431 ' Directional: Ver. Anadrill P4 Slot L-SV KOP: 300' Maximum Hole Angle: Close Approach Wells: Survey Proqram: Logging Program: Surface Intermediate/Production Hole Formation Markers: Formation Tops MDbkb SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 (N sands) WS1 (0 sands) Obf Base CM2 (Colville) THRZ BHRZ (Kalubik) L-104 Draft Drilling Program 590 at 2877' MD All wells pass major risk criteria. Standard MWD surveys (IFR+MSA Correction) Drilling: MWD / GR Open Hole: Gas Detection Cased Hole: None Drilling: MWD / GR / Res / Den /Neu Open Hole: Gas Detection, Cuttings samples Cased Hole: US IT cement evaluation (contingency) TVDss 1465' 1618' 1775' 1970' 2140' 2469' 2792' 3199' 3725' 3927' 4188' 4418' 4725' 5234' 6246' 6421' Hydrocarbon Bearing Hydrocarbon Bearing, 2000 psi, 8.6 ppg EMW Page 2 K-1 TKUP Kuparuk C LCU Kuparuk B Kuparuck A TMLV (Miluveach) TD Criteria 6440' 6506' 6506' Hvd¡"ocarbon Bearin.g. 10.1 PP9 EMVV 6841' 6991' 150' below Miluveach top CasinfllTubing Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tbq O.D. MDrrVD MDrrVD bkb 30" Insulated 20" 91.5# H-40 WLD 80' GL 80/80 9-7/8" 7 5/8" 29.7# L-80 STC 2857' GL 2857'/2577' 6-3/4" 5-1/211 15.5# L-80 STC-m 9730' GL 9730'/6401' 6-3/4" 3-1/2" 9.2# L-80 1ST-mod 740' 9730'/6401' 10431/7063' Tubing 3-1/211 9.2# L-80 1ST-mod 8302' GL 9730'/6401' InteQrity Testin.fl: Test Point Depth Surface Casing Shoe 20' min from surface shoe Test Type LOT EMW 13.5 ppg target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. The production cement calculation assumes cement will be required to cover 500' above the top of the Schrader with 1000 psi compressive strength and covering the entire Kuparuk interval with 2000 psi compressive strength cement. If logs indicate the Schrader not to be oil bearing, the program will be amended to provide 2000 psi compressive strength cement above the top of the Kuparuk only. Casinq Size 17-5/8" Surface I Basis: Lead: Based on 1874' of annulus in the permafrost @ 250% excess and 233' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 750' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2107' MD (2065' TVDbkb) Total Cement Volume: Lead 224 bbl / 1256fe / 283 sks of Dowell ARTICSET Lite at 10.7 ppg and 4.44 dIsk. Tail 41 bbl I 230 fe / 197 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 dIsk. L -104 Draft Drilling Program Page 3 Casing Size 5-1/2"x3-1/2" Production Longstring Basis: Lead: Based on TOG 500' above the top of the Schrader Bluff formation + 30% excess and Base of cement 1000' above top of Kuparuk formation at 8928' (5732' TVDbkb). Tail: Based on TOG 1000' above top of Kuparuk formation + 30% excess + 80' shoe track volume. Total Cement Volume: L-104 Draft Drilling Program Lead 81 bbl I 455ff! I 180s of Dowell LiteGrete at 11.5 ppg and 2.56 disk. Tail 33 bbl I 185 ft~ I 160 sks of Dowell Premium 'G' (KUP Latex Design) at 15.8 ppg and 1.17 disk. Page 4 Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: Sands (MDT pressure L-116) . Maximum surface pressure: 2766 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) 10.1 ppg EMW (3416 psi) @ 6506' TVDss - Kuparuk . Planned BOP test pressure: 4000 psi (for future frac stimulation treatments) . Planned completion fluid: 8.6 ppg filtered seawater / 6.8 ppg Diesel Disposal: . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. H2S: . H2S has not been recorded on L-Pad wells. As a precaution Standard Operating Procedures for H2S should be followed at all times. L-104 Draft Drilling Program Page 5 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor will be installed prior to RU. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and lor well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: 1. MIRU Nabors 9ES on Slot SV. 2. Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2857' MD I 2577' TVD. An intermediate Ibit trip to surface will be performed prior to exiting the Permafrost. The actual surface hole TD will be +1-100' TVD below the top of the SV1 sand. POH LD BHA. 4. Run and cement the 7-5/8", 29.7# surface casing back to surface. A port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 5. ND diverter spool and NU casing I tubing head. NU BOPE and test to 4000 psi. 7 !JJJ 6. MU 6-3/4" drilling assembly with MWD/GR/NEU/DENS/RES and RIH to float collar. Test the Ø5/8" casing to 4000 psi for 30 minutes. 7 ib 7. Drill out shoe joints and displace well to 9.3 ppg LSND drilling fluid. Drill new formation to 20' below 9'~ 5/8" shoe and perform Leak Off Test. 8. Drill to .:!:100' above the HRZ, ensure mud is condition to 1036 ppg and perform short trip as needed. During this time hold the 'Pre-Reservoir' meeting highlighting kick tolerance and detection. Drill ahead to -150' of rat hole into the Miluveach formation. Condition hole for running longstring and POOH. 9. Run and cement the tapered production casing as required from TD to 500' above the Schrader. Displace the casing with seawater during cementing operations and freeze protect the 5 Y2" x 7-5/8" annulus as required. (Annular Disposal Requirement - Prior to freeze protecting annulus, perform second leak off test below the 7 518" shoe. Record on chart and submit to town.) 1 O. Test the casing to 4000 psi for 30 min. 11. Run the 3-1/2", 9.2#, L-80 gas lift completion assembly. Circulate around corrosion inhibitor. Sting seal assembly into tieback receptacle and test to 4000 psi for 30 minutes both the tubing and annulus. Release tubing pressure and shear RP valve. 12. Install TWC and test from below to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 13. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to freeze protect both the tubing and annulus to -2600' TVD. 14. Rig down and move off. L-104 Drilling Program Page 7 Job 1: MIRU Hazards and Contingencies .,. L-Pad is not designated as an H2S site. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~GJ#W) . . \"-\D6 \... -\';Jb QCt., «.\'V'-c;.,\ Iöï):-.-r-c... \~'I~ . ,. The closest surface location 115 patr ~ will be -30' wellhead to wellhead. The well IS not perforated and will not requirè-a--surface shut-in. .,.. Due to the elevated landing ring height on L-Pad, the BOP stack will need to be run with a double flange on bottom (13-5/8" x 11") Reference RPs Operational Specifics "'''''''''' ~..'-.-...... "-' ..,.....-.. y......-..... ~ ....'~ ......-...,.,... ."'''''''''. ...-...... "~""-...." _..........- ~"",_""......, ....... ..~ ........,.,.. -.......... U '~"""'~""'N_""""'"'''' ... .........'.A_~- -... ... -..... ~...........~...._.."... -..... ........, .,.- ...... ..-... -'''''''''~' -. ...... ...-....-...,. .-. ..-...- --.- _"_m......."... '4-"""--""'" -....... Job 2: Drillina Surface Hole Hazards and Contingencies .,. No faults are expected to be penetrated by L-1 04 in the surface interval. ,.. Drilling Close Approach: All wells pass BP Close Approach Guidelines. The nearest close approach well is L -106 (not yet drilled) which will have a center-center distance of 30' from surface to 500' MD. The next close approach is L-107 which has a center to center distance of 71' at 1042' MD. All well pass under Major Risk Rules. .,. Gas hydrates have been observed on the last six surface holes drilled on L-Pad from the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation ;.. Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) Reference RPs Operational Specifics -"'---"'-~__-""_4"-_--_"'_'--".""_-~---~- ---.. --"'--'-.'-"" - . _"""_".""~"_"',,~-- Job 3: Install surface CasinQ Hazards and Contingencies .,. It is critical that cement is circulated to surface for well integrity. Plan 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 7-5/8" port collar will be positioned at :!:1 OOO'MD to allow a secondary circulation as required. ., "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement. 2. Cement - Top of tail >500' TVD above shoe, (using 30% excess.) 3. Casing - Shoe set -100' TVD below SV1 sand. Reference RPs Operational Specifics L-104 Draft Drilling Program Page 7 Job 7: DrillinCl Production Hole Hazards and Contingencies .,. KICK TOLERANCE: The reservoir pressure of the Kuparuk has been determined to be 10.01 ppg. In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.7 ppg at the surface casing shoe, 10.4 ppg mud in the hole the kick tolerance is 25 bbls. LOT's of 13.5ppg (L-01), 15.4ppg (L-116), 15.6 ppg (L-114), 13.7ppg (L- 110), 13.8ppg (L-107) and 13.2ppg (L-115) have been recorded in offset L-Pad wells. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 12.7 ppg. ,. A fault is expected to be penetrated by L-104 at the top of the Schrader at -3890' TVDss. The throw is -100' down to the west. This is not considered a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. ,. A majority of the L-Pad development will have "kick tolerances" in the 25 bbl range or less. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. .,. There are no "Close Approach" issues with the production hole interval of L-104. Reference RPs Operational Specifics ----"'-'-"'----'-"---"---'."-".........-.- Job 9: Case & Cement Production Hole Hazards and Contingencies .,. The 5-1/2" casing will be cemented to 1000' above the Kuparuk sand; the upper most expected hydrocarbon bearing zone. The top of the hydrocarbon interval should be verified with the LWD resistivity log. ,. If losses are encountered while running the production casing, be prepared to treat with barafiber when circulating on bottom prior to the cement displacement. Consider increasing cement volume if 1 OOC}~ returns are not established. ,. After freeze protecting the 5 112" x 7-5/8" casing annulus to 2200' with 36 bbls of dead crude, the hydrostatic pressure will be assuming a diesel column to 2127' TVD, with 1000' of 15.8 ppg cement above the top of Kuparuk at 5732' TVD and 10.3 ppg mud to 2127' TVD, the hydrostatic pressure will be equivalent to 10.0 ppg or 3437 psi. This is roughly the same as the reservoir pressure of 3416 psi at the top of Kuparuk. (If cement is brought up to provide coverage of the Schrader Bluff formation the underbalance concern will be negated.) It is essential that freeze protection of the 7" annulus be performed only after the UCA indicates 500 psi compressive strength is indicated. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) ,. Ensure a minimum hydrostatic equivalent of 10.3 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ,. The well will be under-balanced after displacing the cement with Sea Water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. .,. The X- Nipples, with I.D. of 2.813" is the tightest tolerance for the Weatherford Dual- Plug system, (tapered cement plugs to be used in the 5 ~'2" X 3 1'2" tapered casing string.) Caliper and confirm the I.D. of all X-Nipples prior to make-up to ensure conformity with proposed design. The By-Pass plug head has been milled down to an O.D. of 2.5". Caliper to confirm, prior to use. L-104 Draft Drilling Program Page 8 Reference RPs Operational Specifics ~, ......,..- ,.....-.~ -..... __.n... ,.. -' ~....... ...-..~ ~"". -~- ~ .......,. ..._........._.......~ .., ~.. ~ -.... .........-............... .. ..-....... -.. -.....".. -' ...... ......... ",,,. ....-"..--. ..-.-..... ...... ....... .-,._._-.....-.........-............~ ..,. -.- -. .,. .._....._................................._-~.. ...W-....~.. ... -~.. . ............. -... -' ~ _'_'0 ........... '''''' ... Job 12: Run Completion Hazards and Contingencies ,. No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics .-...-..---..-. ............-... ............-..--...........-. , -.........-........--- "'-"-""'''''''''''''........-........-_c_..........--....-...-..........-..........................--""'''''''''''-''''-''''-'----''',,__'''.__r Job 13: ND/NU/Release RiQ Hazards and Contingencies .,. No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics _._~_.._..._.,-~-_........ -.......' ,......,-....'_"_""""'" .....-.......... "-.........--.........-......-,.-...............-",,,.- ...~_._.....~, '_"",,,,,,,_,,,~,,,,._---_....__._.........._..__........._............,,.- -_..._-_.............._................~._- L-104 Draft Drilling Program Page 9 bp 0 I KBE KOP Bid 1/100 Cry 2/100 Bid 2 5/100 SV5 Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name / Date: Tort / AHD I DDII ERD ratio: Grid Coordinate System: location latlLong: location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: Station ID MD (ft) 0,00 300,00 400,00 500,00 600,00 700,00 800,00 900,00 1000,00 1100,00 1200 00 1300,00 1345,76 1400,00 1500,00 1556,82 1600,00 1700,00 L-104 (P4) report.xls L-104 Proposed Well Profile - Geodetic Report November 27,2001 BP Exploration Alaska Prudhoe Bay Unit - WOA (Drill Pads) - d ~:;~~1L-104 . -rho stu Y L-104 FeISlbllv., L-104 (P4) / November 27,2001 108,59r /6676,43 ft /6.028/ O,94~ NAD27 Alaska State Planes, Zone 4, US Feel N 70,35027063, W 149,3229958i N 5978150,750 ftUS, E 583386,290 hU~ -+{),63758280° 0,99990790 Incl (°) 0.00 0.00 1.00 2.00 3.00 4.00 5,00 5.39 6.40 7.81 9.43 11,18 12.00 13,36 15,86 17,28 18,36 20,86 Azim (°) 165,00 165,00 165,00 165,00 165,00 165,00 165.00 143,18 126.29 114.72 106.87 101,37 99,39 99,39 99,39 TVD (ft) 0.00 300.00 399.99 499.96 599.86 699.68 799.37 898.96 998.44 1097.68 1196.55 1294.93 1339.76 1392.68 1489.44 99,39 1543.90 99,39 1585.01 99,39 1679.20 VSec (ft) 0.00 0.00 0.37 1.46 3.29 5.84 9.13 14.36 22.76 34.32 49.01 66.83 76.02 87.92 113.14 129.34 142.55 176.10 N/.S (ft) 0.00 0.00 -0.84 -3.37 -7.58 -13.48 -21.06 -29.03 -36.09 -42.23 -47.45 -51.74 -53.39 -55.33 -59.44 -62.09 -64.24 -69.72 Page 1 of 3 Survey I DlS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: local Coordinates Referenced To: DIy E/.W (ft) 0.00 0.00 0.23 0.90 2.03 3.61 5.64 9.58 16.89 27.56 41.58 58.92 67.96 79.71 104.58 120.57 133.60 166.70 I DLS (0/100ft) 0.00 0.00 1.00 1.00 1.00 Schlumberger Minimum Curvature / Lubinski 99.750° N 0.000 ft, E 0,000 ft KB 78.9 ft relative to MSL 44.100 ft relative to MSL 26.144° 57469,206 nT 80,760° January 07,2002 BGGM 2001 True North +26.144° Well Head Grid Coordinates Northing Easting (ftUS) (ftUS) 5978150.75 583386.29 5978150.75 583386.29 5978149,91 583386.53 5978147.39 583387.23 5978143,19 583388.40 1.00 1.00 2.00 2.00 2.00 5978137.31 5978129,76 5978121.83 5978114.85 5978108,83 583390.05 583392.16 583396.19 583403.58 583414.32 583428.39 583445.78 583454.83 583466.60 583491.52 Geographic Coordinates latitude I Longitude N 70.35027063 W 149.32299587 N 70.35027063 W 149,32299587 N 70.35026834 W 149.32299400 N 70.35026142 W 149.32298856 N 70.35024992 W 149.32297939 N 70.35023381 W 149.32296656 N 70.35021310 W 149.32295008 N 70.35019132 W 149.32291810 N 70.35017204 W 149.32285876 N 70.35015526 W 149.32277214 N 70.35014100 W 149.32265833 N 70.35012928 W 149.32251756 N 70.35012477 W 149.32244418 N 70.35011947 W 149.32234879 N 70.35010824 W 149.32214690 2.50 5978090.01 583507.53 N 70,35010100 W 149.32201710 2.50 5978088.01 583520.58 N 70,35009513 W 149.32191132 2.50 5978082.90 583553.74 N 70.35008016 W 149.32164262 2.00 2.00 2.00 2.50 2.50 5978103.77 5978099.67 5978098.12 5978096.32 5978092.48 11/27/2001-9:58 AM Grid Coordinates Geographic Coordinates I Station ID MD Incl Azim TVD VSec N/-S E/.W I DlS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftU5) (ftU5) SV4 1718.97 21.33 99.39 1696.90 182,93 -70.83 173,44 2.50 5978081,86 583560.49 N 70,35007712 W 149.32158791 1800.00 23.36 99.39 1771.84 213,73 -75.86 203,83 2.50 5978077,17 583590.93 N 70.35006338 W 149.32134121 End Bid 1862,53 24.92 99.39 1828.90 239,30 -80.03 229,05 2.50 5978073,28 583616.19 N 70.35005199 W 149,32113648 Base Permafrost 1890.09 24.92 99.39 1853.90 250,91 -81 .92 240.51 0.00 5978071,52 583627.67 N 70.35004682 W 149.32104345 Bid 1.5/100 1917.66 24,92 99.39 1878.90 262.53 -83,82 251.97 0.00 5978069.75 583639.15 N 70.35004163 W 149.32095042 2000.00 26.15 99.39 1953.19 298.02 -89,61 286.99 1.50 5978064.35 583674.23 N 70.35002581 W 149,32066613 Bid 3/100 2017.66 26.42 99.39 1969.03 305,84 -90.88 294,71 1.50 5978063,16 583681.97 N 70.35002234 W 149.32060347 2100.00 28.89 99.39 2041.96 344,06 -97.12 332.41 3.00 5978057,34 583719.73 N 70.35000529 W 149.32029743 SV3 2107.94 29,13 99.39 2048,90 347.90 -97.75 336,21 3.00 5978056,76 583723.54 N 70.35000357 W 149.32026658 Bid 4/100 2117,66 29.42 99.39 2057.38 352,66 -98.52 340,90 3.00 5978056,04 583728.23 N 70.35000146 W 149.32022851 2200,00 32.71 99.39 2127.90 395,14 -105.45 382,81 4.00 5978049.58 583770.21 N 70.34998252 W 149.31988829 2300,00 36.71 99.39 2210.09 452,07 -114.74 438,98 4.00 5978040.91 583826.48 N 70.34995714 W 149.31943232 SV2 2311,03 37,15 99.39 2218.90 458.70 -115,82 445.52 4.00 5978039.91 583833.03 N 70.34995419 W 149.31937923 2400,00 40,71 99,39 2288.10 514.60 -124.94 500.67 4.00 5978031.40 583888,27 N 70.34992926 W 149.31893154 2500,00 44,71 99,39 2361.56 582.42 -136.00 567.58 4.00 5978021.09 583955.29 N 70,34989903 W 149.31838838 2600,00 48,71 99,39 2430.11 655.20 -147.88 639.39 4.00 5978010.01 584027.23 N 70.34986656 W 149.31780546 2700,00 52.71 99,39 2493.42 732.58 -160.50 715.73 4.00 5977998.24 584103.69 N 70.34983207 W 149.31718576 SV1 2794,05 56.47 99,39 2547.90 809,22 -173.00 791.35 4.00 5977986.58 584179.44 N 70.34979790 W 149.31657190 2800,00 56.71 99.39 2551.18 814,18 -173.81 796.25 4.00 5977985.83 584184.35 N 70.34979568 W 149.31653213 End Bid 2877,36 59.81 9939 2591.87 879.96 -184,54 861. 15 4.00 5977975.82 584249.36 N 70.34976635 W 149.31600530 7-5/8" Csg Pt 2877.42 59,81 99,39 2591.90 880.02 -184.55 861.21 0.00 5977975.81 584249.42 N 70.34976632 W 149.31600481 UG4A 3432,19 59.81 99,39 2870.90 1359,52 -262.76 1334.29 0.00 5977902.88 584723,30 N 70,34955247 W 149.31216459 UG3 4241,47 59.81 99,39 3277,90 2059,00 -376.84 2024.42 0.00 5977796.49 585414.59 N 70.34924039 W 149.30656263 UG1 5287,38 59.81 99,39 3803.90 2962.99 -524.29 2916.33 0.00 5977658.99 586308.00 N 70.34883677 W 149.29932301 Ma 5689,04 59.81 99.39 4005.90 3310.15 -580.91 3258.85 0.00 5977606.19 586651.10 N 70.34868170 W 149,29654286 WS2 6208,01 59,81 99.39 4266.90 3758.71 -654.08 3701.41 0.00 5977537.96 587094.40 N 70.34848125 W 149.29295077 WS1 6665.35 59,81 99,39 4496.90 4154,00 -718.55 4091.41 0,00 5977477.84 587485,06 N 70.34830457 W 149.28978534 Obf Base 7275,79 59,81 99,39 4803.90 4681,61 -804.60 4611,97 0.00 5977397.59 588006.49 N 70,34806866 W 149.28556032 Drp 2/100 7966,62 59.81 99.39 5151.33 5278,71 -901.99 5201.09 0.00 5977306.77 588596.60 N 70.34780155 W 149.28077896 8000,00 59.14 99,39 5168.28 5307,46 -906.68 5229.45 2.00 5977302,40 588625.01 N 70.34778868 W 149.28054879 8100,00 57.14 99,39 5221.07 5392,39 -920.54 5313.24 2.00 5977289.47 588708.94 N 70.34775066 W 149.27986876 8200,00 55.14 99.39 5276.78 5475.42 -934.08 5395.17 2.00 5977276.85 588791,01 N 70.34771351 W 149.27920382 CM2 8262,23 53,89 99,39 5312.90 5526,09 -942.34 5445.16 2.00 5977269.14 588841,09 N 70,34769084 W 149.27879810 8300,00 53,14 99,39 5335.36 5556,46 -947.30 5475,12 2.00 5977264,52 588871.10 N 70.34767723 W 149.27855495 8400,00 51.14 99,39 5396,73 5635.41 -960.17 5553.01 2.00 5977252.52 588949.12 N 70.34764192 W 149.27792281 L-104 (P4) report xis Page 2 of 3 11/27/2001-9:58 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S E/-W I DLS Northing Easting Latitude I longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftU5) (ftU5) 8500,00 49.14 99.39 5460.82 5712.16 -972.69 5628.74 2.00 5977240.84 589024.97 N 70.34760756 W 149,27730819 8600,00 47,14 99.39 5527.55 5786.63 -984,84 5702.21 2.00 5977229,51 589098.57 N 70.34757422 W 149,27671192 8700.00 45.14 99.39 5596.83 5858.73 -996.60 5773.35 2.00 5977218.54 589169.83 N 70.34754194 W 149.27613456 8800.00 43.14 99.39 5668.60 5928.37 -1007.96 5842.05 2.00 5977207.95 589238.64 N 70.34751076 W 149.27557701 8900,00 41.14 99.39 5742.74 5995.46 -1018,90 5908.24 2.00 5977197.75 589304.95 N 70.34748073 W 149.27503983 9000.00 39.14 99.39 5819.19 6059.92 -1029.42 5971.84 2.00 5977187.94 589368.65 N 70.34745185 W 149.27452367 9100,00 37.14 99.39 5897.83 6121.67 -1039.49 6032.77 2.00 5977178.55 589429.68 N 70.34742421 W 149.27402918 9200.00 35.14 99.39 5978.59 6180.64 -1049.11 6090.95 2.00 5977169.58 589487.96 N 70,34739780 W 149.27355701 9300.00 33,14 99.39 6061.35 6236.76 -1058.27 6146.32 2.00 5977161.03 589543.43 N 70,34737265 W 149.27310764 9400.00 31.14 99.39 6146.02 6289.95 -1066.94 6198.80 2.00 5977152.95 589595.99 N 70,34734885 W 149,27268173 9500,00 29.14 99.39 6232.50 6340.16 -1075.13 6248.34 2.00 5977145.31 589645.62 N 70,34732636 W 149.27227969 9600,00 27.14 99,39 6320.67 6387.32 -1082.83 6294,87 2.00 5977138.13 589692.23 N 70,34730522 W 149,27190207 Top HRZ 9604,75 27.04 99,39 6324.90 6389.48 -1083.18 6297.00 2.00 5977137,80 589694.36 N 70,34730426 W 149.27188478 9700.00 25.14 99,39 6410.44 6431.37 -1090.01 6338.33 2.00 5977131.43 589735.76 N 70,34728551 W 149.27154936 Base HRZ 9798,05 23.18 99,39 6499.90 6471.50 -1096.56 6377.92 2.00 5977125.33 589775.42 N 70,34726752 W 149.27122807 9800,00 23.14 99.39 6501,69 6472.27 -1096.69 6378.68 2.00 5977125.20 589776.18 N 70.34726716 W 149.27122190 K-1 9818,69 22.77 99.39 6518.90 6479.55 -1097.88 6385.87 2.00 5977124.09 589783.38 N 70.34726390 W 149.27116355 End Drp 9856,97 22.00 99.39 6554.30 6494.13 -1100.25 6400.25 2.00 5977121.88 589797,78 N 70.34725739 W 149.27104685 Top Kuparuk / C 9889.96 22.00 99.39 6584.89 6506.49 -1102.27 6412.44 0.00 5977120.00 589809,99 N 70.34725184 W 149.27094792 Target! Drp 2/100 9889,97 22.00 99.39 6584.90 6506.49 -1102,27 6412.45 0.00 5977120.00 589810,00 N 70.34725184 W 149.27094784 9900,00 21.80 99.39 6594.20 6510.23 -1102.88 6416.13 2,00 5977119.43 589813,69 N 70,34725017 W 149.27091797 10000,00 19,80 99.39 6687.68 6545.74 -1108.67 6451.17 2.00 5977114.03 589848,79 N 70,34723427 W 149.27063360 10100.00 17,80 99.39 6782.34 6577.96 -1113.93 6482.96 2.00 5977109.13 589880,63 N 70,34721982 W 149.27037561 10200.00 15,80 99.39 6878.07 6606.86 -1118.65 6511.47 2.00 5977104.73 589909,19 N 70,34720686 W 149.27014424 End Drp 10243.38 14,93 99.39 6919.90 6618.36 -1120.52 6522.81 2,00 5977102.98 589920,55 N 70,34720172 W 149.27005221 TMLV 10243.39 14,93 99.39 6919.91 6618.36 -1120.52 6522,82 0,00 5977102.98 589920,56 N 70,34720172 W 149.27005212 TD / 5-1/2" Csg PI 10393.38 14,93 99.39 7064.83 6657.01 -1126.83 6560,95 0,00 5977097,10 589958,75 N 70,34718439 W 149.26974268 LeQal Description: Surface: 2426 FSL 3530 FEL S34 T12N R 11 E UM Target: 1321 FSL 2399 FEL S35 T12N R11E UM BHL: 1297 FSL 2251 FEL S35 T12N R11E UM NorthinQ (Y) rftUSl EastinQ (X) rftUSl 5978150.75 583386.29 5977120.00 589810.00 5977097,10 589958.75 L-104 (P4) report.xls Page 3 of 3 11/27/2001-9:58 AM brJ ~, :~- .,~l ..~- 0- - +-' Q) - Q)...J - (/) 2000 - g~ 0 Q) N > II 2 c ro ~4= _0 ..c ~ 4000 - ë.~ Q) - 000 -~ ro .. .~ Q5 ~o:: > > Q) ~ 6000- ~ W .= 8000 - I -4000 1- -. r- -~.- VERTICAL SECTION VIEW Client: BP Exploration Alaska ~,¡ e 11 : Field: L-I04 (P~) Prudhoe 8éij' Unic - ~'JO.:" Structure: L- f'ad Seccion At: 99.7:, deg Dace: tlo'l02rnber 27. 2001 KOPBld1/100::'(¡(IMD :\ljI)T\oü (.(li): 1t,:> 1)1)' :s2 O']¡;¡)Einur-:- Crv ~100 6(11) MD i-:.':t TV ) ~ I)) 1r.::.O(I' :'1' ~ .j-:r..;.111"-: Bid 2.!>JtOØ ';>.I,; MD 1}' (o TVO 'i ÙO' 99 JÇt' oiL i¿ ']~þ:.IIlu..e Bid 3/1002(0'1' '.4D I';';'" TIIO .d J.!' ~) :~ÇI' ;..2 JÜ,; d-:r.:u1ur.: Bid 1 5/100 '918 "'0 1.;1Ý T'IO 2~ 9:: ~ :\~" ¿¡: L':» ¡J-:p~llIJI'; End Bid '.;0; ¡ MO 1&29 ïVO 2~ Çtl" ~..ç. J';'" :s.:: ?~,~ d~t';tnul'': Bid "'100 :', I'; '.40 2(';,7 PIa .!9 ~.l: ~9 j"!' oÜ J~ 3 .].;¡:.;.n'Jf.: Er.d Bid l87? MD ?~.~..~ r.'D ~'j ö1. ~~.. ".\.;,' ::..1 ðtll) a';~'~"IJ"':. 7.S/a" Cog PI ;017 '.40 2~.~2 1'\10 ~.~ '=": 9';'!~ ;¡: 1)1,)(, ¡]-=,. 'wlul,: Hold Angle 59.81° -- -- --. --- -- --- -- -- - --- - ---- -- .- --- .-- -- _n -- .-- -- Drp2J10CJ ;~-4t; MD ';)1::.1 ï'oID fl181' -:rŸ :~y'::a? ~.U~a,:p~I'ur.t: --------- Hold Angle 14.93" I -2000 I 0 I 2000 I 4000 I 6000 End Drp ,~õ:: 7 MO t~.-:-4 T'~'D 12 (II)' Çt-:- 3';" :t.Z r,;J.';aJ tJ.;~ :t'llli.t: T "~I Drp 2/100 . '='b~-41) '"~D t.~,8., T"vÜ '2¿ r))' '='~ )~' ~ i--:'(II) ':I.;t'~I~UI'.t: ~\.~ Ero d Drp IÜ¡J:\ MtJ t~'~~1) ïVO 1 J ç.~' 9'~:\~'::.! t~f., l/j .]r.~'illlJl'~ TD 15-1/~' Cog PI 1 r)r},~) '.1(1 1(1I)~. T'.D 1 J Ç(\' ,~.;. :\'j' &.? I;.t';::, 7 dr. ¡:. ",nUl'=: I 8000 Vertical Section Departure at 99.75 deg from (0.0, 0.0). (1 in = 2000 feet) Schlumberuer I 10000 ~)r) (tf}IIØ C) 1000 - ^ ^ ^ I .- œ: 0 z -1000 - I .- => 0 en V V V -2000 - -3000 - 0 I KOP Bid 11100 )(r/) 'JD 3(11) TVO (' (11)8 1E,~ f)/'J8 ~ I)'" 0 E 0- . -4 ú.~--.ro:---=:::. \] Bid 1 ~'IOO 1~'~ ~'D '8'~ P:D 24 ç.28 9~ :,,,,- a~ ¡,., s n,} E Bid 3"00 ~')18 JJO '%'~ T'.'O i(. .1}8 ç.ç¡ J~' 1.": 91~ i'~~E I 0 1000 I Cry 2J10Q ~I){I ~D 79~ TVD 50 1)')" 1 ~~ (~I)' .3.2' t'1 :. t E Client: t'}"",ll: Field: Str.uctuU2: S':a Ie: Date: PLAN VIEW BP Exploration Alasv.a L-IO.J (P~) Prudhoe Bay Unit - WOA L-pad 1 i n = 1 (II) I) f t 2 7 - r J 0 'i - ¿ 0 (I 1 4000 I 2000 I Bid 2 ~'IOO 1 }'4~1 '.AO 1141) 1\'0 12 (II"J" ':r;. :1';1' :s: ~13 ~ ~Ifj E End Bid \¡ù;J ~'O '8:'. TVD :.'J ç¡;?" ç.9 ~~';': U ~1)3 l,'~E 7.5/8" Cog PI ~r371 "-"D :~I~:! TVD ~ ':' 8" 9? :\~ 1Z 113~::; 81:'.' E 3000 5000 True North 1.lag Dee ( E 26.1<1 ':' ) Drp 2'1(10 7ç.i)7 '.40 5'~1 1'',10 ~'~131 ÇI?JI!':!l ~I:' 3 ~:!(I' E Bid "'100 71 1'=' '.4D 21)~,7 1"'.'0 2~ J2' Ç1ÇI J9" ~l 9~~ :uIE I 1000 End Bid 2~ 77 ~'O ,~,~:' T'~I) ~~f3I: ':I~ 3t;1' ill 'f35~, B'='1 E I 2000 «< WEST I 3000 I 4000 EAST »> &,~ .~ -" End DIp 9~'~.7 '.[1 t :.:.-, T...,D ':'(11)' ~~ ~~; 31 '1(11) S f..HII) E Schlumberger 6000 Targ.!' Drp 2'100 Ç-t'?t)f.tO Eo~t33 r.'D ;lll)(I" ~... :(~ 3;: 111)::: ~Il E - ..- .'-4 ------ ---- -CO "\¡ End Drp 1(1].13 Þ.Uj t;.~.("(1 T'JD 1J ç.~ ~.~ :iç.' 3..? '1:t"1 ~ H;n~ I 5000 TD' ~-I'2- C'g PI 1(((~) t.tO i' )IJ~ T'\¡ü - 1.1 ç.)' ~? ~~: lZ 11.:!7 ::: f,~.I)' E I 6000 7000 . - 1000 -0 - -1000 --2000 --3000 I 7000 Schlumberger A.nticollision Report !"s~;;';)~P;~g~an~ fo~-ö~Ìïniti~--;'\;"pa-th-- .-----.-___.__n_.m' .-. -- --..-. - -- Date: 12/26/2000 \alidated: No \'ersion: 5 Planned From To Sune, Toolcode ft ft . ¡.- . -,'-' ,-- ---- --- ,- - ,-_. - I 28,50 500,00 Planned: Plan #4 V1 500,00 10393,38 Planned: Plan #4 V1 Compan): BP Amoco ! Field: Prudhoe Bay 'I Reference Site: PB L Pad Reference Well: L-104 : Rei...." "',lIpath, Plan L-1Q4 I-N'~ ~Gi'-o'-~~~ i'~~:\'~ \; sing' ~~~~defi-;;;¡i~;I~c-;¡o~'~'~~;~~;¡~~;i~ ~ ,- I Interpolation l\Iethod: MD Intenal: 50.00 ft Depth Range: 28,50 to 10393,38 ft I\la:\imum Radius: 2000,00 ft -----. .--.--.. -. ----- .. - ... ----- -- .-.--. - --- - - . Date: 11/27/2001 Time: 10:34:19 Page: Co-ordinate(N E) Reference: Vertical (T\'D) Reference: Well: L-104. True North L-10478.9 - - . , ,. -, . .. .' Db.: , . ~y_base, I ----- - ---- -~;~:~~~:~:I~'---- ~f~aI~'~~s~ PLANÑ-ED--PR-OGRA'M-! Scan Method: Trav Cylinder North Error Surfacl': Ellipse + Casing - -----.-- - -.- -. - - - - -- - - - -- . - - . -- - - - -..- -------. ---- --.- --- -. - -- - Tool Name -.- -.- -.. -.-- ---. - -- . ..---- -.-- .--.---- ---..-..-- . - --- --- - - --- - . - -...- _. --. - -- .--- ---..---- ---.-.---- ,-.--...- - "-- --- ------. .-. --0- GYD-GC-SS MWD+IFR+MS Gyrodata gyro single shots MWD + IFR + Multi Station -.----- - ----..---- --...-- -.- -- Casing Points !'!\ID n'D tt ft I 2877.42 2591,89 ,10393,00 7064,16 Hole Size in Diameter in Name 9,875 6,750 75/8" 5 1/2" 7,625 5.500 --- .---'- - - - . .... -, ." -- -.-- -.--....-. --- - ------ -- --.--.- -.--- Summar) !~--------------- Offsl:'t Wellpath --------------> ' , Site Well Wellpath !--EX-ÑWE#1-- ------ÑWE1~ã1- .------ -Ñ-WEï:01'V3 --, EX NWE#1 NWE1-01 NWE1-01A VO i EX NWE#1 NWE 1-02 NWE 1-02 V2 I PB L Pad L-01 L-01 V14 PB L Pad L-106 Plan L-106 V8 Plan: PI , PB L Pad L-107 L-107 V14 I' PBLPad L-110 L-110V11 PB L Pad L-114 L-114 V14 PB L Pad L-115 L-115 V7 , PB L Pad L-116 L-116 V10 I PBLPad L-117 L-117V11 .. - - - -. - . .. -. - - -- - -. -- - --. -.. -- - - I .__1 - -. --- -... - -- -- - _n_._- -- --..-.--. - --- - -..--.---- . - - -- --- _n. ----- - --..- Reference Offo;et Or-Or No-Go AIIO\\oable 1\ I D 1\1 D Distance Area De, iation \\ arning ft ft ft ft ft --- .-- -.. ----- -. - ...-.... ,------ - -.--- -----.--- --- -.---- ----..--.-- -- 299.99 300,00 475,73 5,08 470.66 Pass: Major Risk 299.99 300.00 475,73 5,08 470.66 Pass: Major Risk 913,84 950,00 397,70 15,08 382,62 Pass: Major Risk 847,76 850,00 132,93 12.65 120,28 Pass: Major Risk 499,75 500,00 30,88 10.39 20.48 Pass: Major Risk 1042,09 1050,00 71,33 16,52 54.82 Pass: Major Risk 499.97 500.00 251,09 8,78 242.31 Pass: Major Risk 797.48 800.00 325,20 11,64 313,59 Pass: Major Risk 687,73 700.00 289,69 10.71 279,00 Pass: Major Risk 747.73 750,00 222.16 10.93 211,30 Pass: Major Risk 396.88 400,00 285,89 6,26 279,63 Pass: Major Risk .. - .- - ---.-- -- -- - ---.----- Target L-I 04 Target ~ +E -\\' IÌ -49-L48 505,55 494,48 -505.55 \\~Il: L-I04 ) Basl:'d on: Plalilll:'d Prügram \'èrtll:'al Dèplh: 650600 il bt'lo\\' ~kan SI:'J Ll:'wl Local +N -5: -1101.94 ft Local +E -\\': 641~ 49 il LongilUdt': 149jI6'15,41~\\' Northmg fI 59776~O,O(l 59776~O,OO 59766~O,OO 59766~0 00 Easlmg fI 5S93 10.00 590310.00 5903 1(1,00 5893 10,00 Polygon I Slit', PB L Pad Dnllmg Targt't Coni. Cèlllrt' Locallon' 1\ lap Northing: :'9771 ~O,¡)O ft 1\ lap Easling : 589811),00 fl Lallludt': 70j~0':,0 I ú7N +N -5 IÌ 505,55 494,48 -505,S5 -494,48 t 3 4 ---"--'----- ---.--.---. - ----- -. -- --- - ----.-- - - --- ------- -.---- -.-.------..-..- ---' -'-----' ---"-. -._- .'- -.- - - .- --- --- ---"" --- - ... -. ------ - --"-- - -- --,.. - [I -21][1 - 4- IJ I] . - .-- - --' -- --... - --- - -..- . - -.-"'- --- - t, I] [I - -- - -. --- .-- - -- .- - -- , I I I : I I I -¡3[11] I 1 I I ' -I~Ol] i 1 ! I 1 I 1 I I I i ' 1 ¡ - 1 21 [II] I 1 1 ! I I ; I - 1 4- I] [I -I tlÛO -181]0 - 21000 ,'1 I~' I I I I~ I '~ I 0 1=1 I~ C) c., ~:1 ',~ ~ '--..J l) ¡= I (=1 ',--.J I~J 1,=1 l) '-' , I,') 1,_, ", If] co i~ C"J J '--0 CD C) C"oJ J r ¡ ¡,l U~I \...£' 1,...0 '--D I,.D '--LI 1- 1- I ',1 It', '(1 .. 1 I..,", ) ) Borealis L-104 Proposed Completion TREE: 3.1."8" - 5M CIW L.80 WELLHEAD: "" - 5M FMC G5 Cellar Elevation = 47' RKB - MSL "' 77' I It 3-1/2" Camco B-61 SSSVLN with 2,813" bore. I 2600' I 7-5/8",29.7 H/ft, L-80, BTC I 2857' I~ ... L 3-1/2" x 1" Gas Lift Mandrels with handling pups installed, 1---- -- _n__- -- -G~S -~IFT-MANDRRŠ- .-- - --- --- ---_u_--- 1--- -~_.- .- - ~_!~-~~-- -_:-~J~--- ~-~~!'~~~_:~~~-:-X~.!.~~--~Y.P~--~-~ 1 1 2 3 TBD 5300' 3500' KBG-2-9 , KBG-2-9 I KBG-2-9 DV DV RP L '"------------- 1_____- -- - - - -- --------------- - ~ 3-1/2" 9,21t IBT Mod L-80. Tubing L C) 3-1/2" Baker 'CMU" one JOint above PBR 5-1/2", 15.5 #/ft, L-80, BTC-Mod "-- ......- 3-1/2" Seal Stack Assembly -..- 3-112" seal bore in 17' PBR 7 5-1/2" x 3-1/2" XO Plug Back Depth \10,346' ~ ., 3-1/2" .X' Landing Nipple with 2,813" seal bore . 3-1/2" 'X' Landing Nipple with 2,813" seal bore +1- 150' above Kuparuk 3-1/2",9.2 H/ft, L-80,IBT Mod \10,431 ' ~ Date 2/21/01 Rev By LRC Comments Borealis WELL: L-104 API NO: 50-029-????? Proposed Seal Bore Completion BP Alaska Drilling & Wells L-104 Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates were observed in all offset wells. These are expected to be encountered near the base of the Permafrost at 1850' and near the TD hole section as well. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity and yield point is maintained to avoid stuck pipe situations. Production Hole Section: . The production section will be drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the HRZ shale. Read the Shale Drilling Recommended Practice. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. . FAULTS: The well trajectory is expected to intersect a fault while drilling L-104, in the base of the Ugnu/Top Schrader @ -3890' TVDss. The throw is estimated @ -100' and is not considered a high risk for loss circulation. Consult Lost Circulation Decision Tree for recommended LCM treatments. . KICK TOLERANCE: With 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.7 ppg at the surface casing shoe, 10.3 ppg mud in the hole, the kick tolerance is 25 bbls. (Offset wells have shown fracture gradient of 13.5 ppg to 15.6 ppg at the surface shoe depth.) . A majority of the L-Pad development "Microbores" will have "kick tolerances" in the 25-40 bbl range. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. ReProduction test data for l-Pad wells brought on indicate no H2S is present. As a precaution Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page I of 1 Closest Well Proximity to L-104 is L-106 ~ Subject: Closest Well Proximity to L-104 is L-106 Date: Thu, 13 Dec 2001 14:12:46 -0600 From: "Magee, D Neill! <MageeDN@BP.com> To: "'Tom Maunderlll <tom_maunder@admin.state.ak.us> Missed that.. That's the planned adjacent well, L-106 which has not yet been drilled. Regards, Neil -----Original Message----- From: Tom Maunder [mailto:tom maunder@ladmin.state.ak.usl Sent: Thursday, December 13, 2001 11 :03 AM To: Neil Magee Subject: L-104 Neil, In your hazards analysis for L-104 on page 7 in the first section the reference is to L-104. What is the correct reference? Thanks Tom 1 of 1 12/13/0111:14 AM H 198749 DATE 09/28/01 CHECK NO. 00198749 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 092701 CK092701M PYMT '.::OMMENTS: HANDLING INST: 100.00 100.00 Per~it to Drill 7ee S/H - Terri Hubble X4628 RECE\\lED OEC r 5 2001 '(\ 0\\ & Gas cons. CQ\1\\1\\SI\O f:\\as~ ~nc.'oœge L- - \ C1--\ E ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100_00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND. OHIO No.H 198749 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00198749 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 09/28/01 AMOUNT $100.00 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 Q~ßßfv\ \ . ---~ III ~ g 8 ? 1.. ~ III I: 0 ~ ~ 2 0 jag 5 I: 0 0 a L. ~ ~ ~ III CHECK 1 STANDARD LETTER DEVELOPMENT j DEVELOPMENT REDRlLL EXPLORA TION INJECTION \VELL INJECTION "'ELL REDRILL TRANS1VUT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME $d L - Ie '-I CHECK "1lAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DjŠ'~OSAL ~NO ANNULAR DISPOSAL <-) YES ANNULAR DISPOSAL THIS "'ELL "CLUE" The permit is for a new wellbore segment of existing well ---' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(0, 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 (SO -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-) YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved, subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. "'-,..""'" " /~5¿< WELL PERMIT CHECK~IST - - C,..OMPANY . ß~~')é WELL NAME ì~ - /{~:,y PROGRAM: exp - d-:v ~'redrll- serv - well bore seg _ann. disposal para req- FIELD & POOL i; ~ <-I( ~>/~~ t:Þ' INIT CLASS ~ v I 1 f:../ L- GEOL AREA f§l C UNIT# //')/)¡-; S?"~, ON/OFF SHORE (">: /\.. c, ADMINISTRATION 1. Permit fee attached. '.' . . <- : .,' ., ~f' ';' . . "i, " ,',<; .. . (Y ',N 2. Lease number appropnate. ~~- .~\,"!'4', r...:- (' ~ .I~ . 7.v. '. ., ~N 3. Unique well name and number. .. . . . . . . . . . . . . . . . C,!:.....'N 4. Well located in a defined pool.* . . . . . . . . . . . . . . . æ"N 5. Well located proper distance from drilling unit boundary. ., . c;y, N 6. Well located proper distance from other wells. . . . . . . . . . C;L:.- N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . ~"'N 8. If deviated, is wellbòre plat induded.. . . . . .. . .. . . . , . . (j;.~ N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . l~ ,N 10. Oper~tor has ~ppropria~e bond in force.. . . . . . . . . . . . . C~ N 11. Permit can be Issued without conservation order. . . . . . . . {2.(.-, N AP~~ DATE 12. Permit can,be issued without administrative approval.. . . . . l:::¥., N ft"\ /2./1,[:'11 13. Can permit be approved before 15-daywait.. ........,. (:i'IN ENGINEERING 14. Conductor string provided. . . , , . . . . . . . . . . . . . . 11 N 15. Surface casing protects all known USDWs. . . . . . . . ,ýl N 16. CMT vol adequate to circulate on conductor & suñ csg. . . . ~ N i~': ':: ',..~ '.I '..~, ,,' I 17. CMT vol adequate to tie-in long string to surf csg. . . . .. .. . . y $f 18. CMT will cover all known productive horizons. . . . . . . . . . ,Iý~ N 19. Casing designs adequate for C~ T, B & permafrost. . . . . . . If N ... I 20. Adequate tankage or reserve pit., . . . . . . . . . . . . . . . Y N t.,~: ' 21. If a re-drill, has a 10-403 for abandonment been approved. . . Y, N,. ,',''/ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . ,;'t..o' N 23. If diverter required, does it meet regulations. . . . . . . . . . ,y N 24. Drilling fluid program schematic & equip list adequate. . . . . Y N 25. BOPEs, do they meet regulation, , , . . . .' . . . . . . . . . "(., N 26. BOPE press rating appropriate; test to :'¡ ?"I'):"I psig. ~ N k Þ-.s, V Q. c... -\ ~ :) 1 <0 ~ ~.; I 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . Y N 28. Work will occur without operation shutdown. . . , . . . . . . . '{! ~ 29. Is presence of H2S gas probable.. . . . . . , . . . . . . . . . Y 'N"' 30. Permit can be issued wlo hydrogen sulfide measures. . . . . (]/ N 31 D t t d t t. I ~ e~ R¿('--k-I 1-é;5-t:/> '" ' / r- ,??<-ot;,S' r<'!-.I-::> ./Ò '. / P"P'j ~/.1'''t'/. , a. a ~resen e . on po en la overpressure zones, . . , . . . 'I. L-' (; oJ 1/ t/ (j - 32. Seismic analysIs of shallow gas zones, . . . . . . . . .~.. I N APijR DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . , Y N .../6l> /2 ,d. 6 ( 34. Contact name/phone for weekly progress reports [exp/~ ry only] Y N ANNULAR DISPOSAL35. With proper cementing records. this plan . (A) will contain waste in a suitable receiving zone; . . , . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 2~ MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENÇ3INEERING: UIC/Annular COMMISSION: RÞð ~ \#-Aft- WM --- 8~' S /J5r-- +~~~7ìVll:>(,~, - JM~'~¥o/ \2..1'41 OJ tjt~, , ,9~;~,:, f !f)?v/.. {~:3 GEOLOGY APPR DATE Y N Y N c:\msoffice\wordian\diana\checklist (rev. 11/01/100) -:)u..I"'hc..¿o- /C'~'4..þ~ ,..A,,- A"Dc.. 02:8.:: 3""1" -1-...._/ '-;~dul:hl.....:.... -~,-.k-"'q,,L a. h.../ -¡.]) ..'~ .~Dt:.. c>-:-3 z.. 3S,..':j£> ,/ ¡J J- *" ø~,..q i-<-Ji..</c. ~ -&..-L- K'J'.:¿¿..,-~L I'~~; ¿,,¿,,-C/ ¡ /i~,,( ':'1,-- --/I~ C~-r ~ f ,- ~, 1- c 0 Z 0 -t ~ ::0 r ~ . I " 1\ t ,':. . -t m '4.~()() \S ~ ,c..~ \ to-( ~ -\ ' ..J Z -t J: en :Þ :::0 m :Þ /~Ù\C~'~~0 ~/' ..-' Commentsllnstructions: (:£, ---;¡~ &7~¡~ f;~ 1c...!,.,¿?::cJ Cc:d. r:- i-; '-"54: I ¿'-''-'L h ~(:'þl.;;"l¡"rl'<{ .!LHt...::I,LJ{LI.I' --11,-- ~.,h~t...~'~ ':¿L~ r<-$C"-.;\/;""""il'~ ""l..¿/--è. 1$ C.:..L-~'\..s.:'c!oe..:~-I U . ¡) '-:,.1 - J -" eC.---,-I-' l: ..-fl~ /-.;!;iL K,--.;.Z. n.J.: K.'/' ú~- (.)// 1:'_:,<.,17 LL,I,-,-c.j.... if;, 15~ /.. 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