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203-164
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Producer Y-23B (PTD #2031640) TTP set Date:Friday, August 26, 2022 11:52:51 AM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, August 26, 2022 11:13 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: Producer Y-23B (PTD #2031640) TTP set Mr. Regg, Producer Y-23B (PTD #2031640) is suspected to have a hole in the production casing near 1300’ causing rapid IAxOA communication after OA liquid level depress and failing MIT-OA. The well has been secured with a tubing tail plug. Pressure testing is in progress to establish well barriers. The well is now classified as NOT OPERABLE and will remain shut in and secured until well barriers are restored. Please call with questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Friday, July 29, 2022 3:11 PM To: jim.regg@alaska.gov Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer Y-23B (PTD #2031640) Sustained casing pressure OA Mr. Regg, Producer Y-23B (PTD #2031640) was reported to have sustained casing pressure (~1300 psi) on the OA by operations on 07/28/22. While gas lift was being applied to the IA in preparation for putting the well online post wellhead pack-off greenstick treatment, the OA pressure rapidly increased tracking gas lift pressure. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward 1. Downhole Diagnostics: MIT-OA / depress OA liquid level 2. Well Integrity: Evaluate repair options Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. By Samantha Carlisle at 10:03 am, Aug 03, 2022 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer Y-23B (PTD #2031640) Sustained casing pressure OA Date:Monday, August 1, 2022 10:32:36 AM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 29, 2022 3:11 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer Y-23B (PTD #2031640) Sustained casing pressure OA Mr. Regg, Producer Y-23B (PTD #2031640) was reported to have sustained casing pressure (~1300 psi) on the OA by operations on 07/28/22. While gas lift was being applied to the IA in preparation for putting the well online post wellhead pack-off greenstick treatment, the OA pressure rapidly increased tracking gas lift pressure. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward 1. Downhole Diagnostics: MIT-OA / depress OA liquid level 2. Well Integrity: Evaluate repair options Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA F kLASKA OIL AND GAS CONSERVATION COMM!. V JIM REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operation'§ iutn--''- ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ . Plug for Redrill ❑ Perforate New Pool 0 Repair Well El Re-enter Susp Well 0 Other f Vhii1 1 pqhil v 2. Operator Name BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 2036164 3. Address: P.O.Box 196612 Anchorage, Development IZ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number 50-029-21590-02-00 7. Property Designation(Lease Number): ADL 0028288 8. Well Name and Number: PBU Y-23B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071)• 10. Field/Pools. PRUDHOE BAY•PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 14955 feet Plugs measured feet true vertical 9008 feet Junk measured 14600 feet Effective Depth measured 14869 feet Packer measured See Attachment feet true vertical 9007 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD• Burst Collapse' Structural Conductor 80 20"91.5#H-40 33-113 33-113 1490 470 Surface 2777 13-3/8"72#L-80 32-2810 32-2694 4930 2670 Intermediate 6893 9-5/8"47#L-80 30-6923 30-5751 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 12860-12890 feet 12890-12920 feet 12920-12950 feet 13200-13335 feet 13400-13620 feet 13930-14050 feet 14230-14510 feet 13680-13840 9044-9043 feet 9043-9042 feet 9042-9034 feet 9030-9019 feet True vertical depth: 9045-9044 feet 9021-9018 feet 9012-9005 feet 9019-9022 4-1/2"12.6#L-80 28-11700 28-8738 Tubing(size,grade,measured and true vertical depth) Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED Treatment descriptions including volumes used and final pressure: �7 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 229 322 2636 1421 275 Subsequent to operation: 341 445 4140 1589 277 14 Attachments:(required per 20 AAC 25 070 25 071,a 25 283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development I,I Service 0 Stratigraphic ❑ l Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O.Exempt: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature jjaAi C , Phone +1 907 564 4424 Date 6/24/15 Form 10-404 Revised 5/2015 Ti_ 7-///i, it 7j4�l RBDMS ,it OF'ginal Only 2015 Packers and SSV's Attachment 203-164 SW Name Type MD TVD Depscription Y-23B PACKER 6794.89 5658.89 7" Liner Top Packer Y-23B PACKER 9024 7079.85 4-1/2" KB Packer Y-23B PACKER 9054.93 7098.97 4-1/2" KB Packer Y-23B PACKER 11643.39 8702.06 4-1/2" Baker S-3 Perm Packer Y-23B PACKER 11696.4 8735.35 5"TIW Top Packer a) 0,000000 C I- N- v to to N LD N- r- U O)) M O- co co mCO N CO 000 co V' •— O OD CO 0 U') N- O co CO 1,- CO O N Cn CO CA 00 CY) N O In CO CO 010101 (.01,-D N 1.42) O M COCOO C7 r In O r co N CD CA Z N O V 0 03 i i I I i i it O Q Cl N O C1�0 c0 CO CO CO M N N C r -0 Q • N O OO 0 00000000 • dN CO (o N 03 (/� -r Q;c:$ - N _ C) N � � N O r r N co co O 4 4 • r ti cv) LO " ON- Q) c7 (O C co N- 00 s- 11) — J N (Oa)re `- W C 0 Q U W OOu CCrYc Z zwwww OD 0 U) Z J J H TREE= .. 4-1/16"CNV W$LHEAD= MCEVOY Y-2 3 B OTE 28.1E L ANNGLE>70°@ 12240'*** MAX DON ACTUATOR= AXELSON OKE..EV== 50.6 ' BF.ELEV= 51.600' KOP= 1600' ^CONDIX.TOR Max Angle= 96°@ 12669' — — 7 , , 2209' �—�4-1/2"FTS X ice,D=3.813" Datum MD= 11919' —#' Datum ND= 8800'SS D= - LI GAS LFT MANDRELS 13-3/8 CSG,72#,L-80-BTRS,D=12.347" H 281T ND DEV TYPE VLV LATCH PORT DATE 6 3232 3011 43 IMMG DMY RK 0 12/27/03 9-5/8"X 7"BKR LNR TACK,D=7.50" —1 6780' 1----_, ~ 5 4292 3797 42 MMG DOME RK 16 05/26/15 9-5/8"X 7"BKR LTP,D=6.330" —+ 6792' i 4 5891 4999 43 MMG DOME RK 16 05/26/15 3 7490 6105 52 KBG-2 DOME BK 16 05/26/15 9-5/8"X 7' BKR LNR HGR,D=6.320" H 6798' ' '2 9040 7090 52 7 SO BK 20 05/26/15 9-5/8"VVHPSTOCK(10/24/03) —1 6923' i 10517 7993 53 KBG-2 DMY BK 0 10/09/14 9-5/8"CSG,47#,L-80 BTRS,ID=8.681" X6923 \ — ,STA#2=GL STRADDLE(COVERNG DMV @ 9045'-10/09/14) MLLOUT VVI DOW(Y-23B) 6923'-6938' •;,„.:",:t.,`,;,, , ,31% Minimum ID = 1.875" @ 11664' 1►'•- �►a_ 4-1/2" X 2-3/8" NIP REDUCER , 9024' -9062' —IBRKR45KB PKRASSY,D=1.91"(05/20/15) liF 11620' H4-1/2"HES X NP,D=3.813" ' 11640' H 7"X 4-112"S-3 PKR,D=3.875" Z 2( 11664' H4-1/2"FES X',D=3.813" 11664' -4-1/2"X 2-3/8"NP REDUCER, 6 D= 1.875"(05/17/15) 116$5' --I4-112'FES XN NP,D=3.79(OBEY®5/14/15) TOP OF 4-1/2"LNR H 11686' 11686'_I-17"BKR LNRIS TK,D=5.250" 4-1/2"TBG,12.6#,L-80 BT-M,.0152 bpf,D=3.958' H 11697' 7-X 5-BKR LTP w/ D=4.390" 1 1 693' HGR, 7"CSG,26#,L-80 BTC-M,.0383 bpi,D=6.276" H 11915' 11697' H4-1/2"1NLEG,D=3.958" 11709' H5"X 4-1/2"XO,D=3.958" PERFORATION SUMMARY REF LOG: MCCUGR ON 11/30/03 , TEN LOG: SPERRY-SUN ROP/DGWEWR WA)LOG ANGLE AT TOP PERF:93"@ 12860' Note:Refer to Production DB for historical perf data SEE SPF INTERVAL Opn/Sqz SHOT SOZ 2-7/8" 6 12860-12950 0 06/26/14 2-7/8" 6 13200-13335 0 11/30/03 2-7/8" 6 13400-13620 0 11/30/03 2-7/8" 6 13680-13840 0 11/30/03 2-78" 6 13930-14050 0 11/30/03 2-7/8" 6 14230-14510 0 11/30/03 - 1 14600' H FISH-BTM 1.98'OF PARTED TREATED R(R(6/22/12) P810 —j 14862` y.*. 4-1/2"LNR,12.6#,L-80,BT-M,.01552 bpf, ID=3.958" —1 14950' ii~' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY INT 06124/86 AUDI 2 ORIGINAL COMPLETION 05/18/15 MIC/PJC XN MR MN D CORRECTIONS WELL: Y-238 12/27/91 ICES RWO 05/20/15 ALM PJC SET GL STRDL PKR w/DMY GLM PERIAT No: 2031640 06124/01 CDR1-1 CTD SIDETRACK(Y-23A) 05/26/15 RJK/PJC GLV C/O AR No: 50-029-21590-02 12101/03 2ES/NDC SIDETRACK (Y-23B)-2 RIGS 05/28/15 PJC FE2F SYMBOL/LNR LWt TE SEC 33,T11N,R13E, 1372'FNL 8 24'FEL 02/24/15 f XW/.HMC RILL PXN,SET MP RED/XX PLUG 05/17/15 ()LH/PJC PULL/RESET NP RED/XX PLUG BP Exploration(Alaska) o CU 00 a) v V on U ID v It) �L U > 7' M C ❑ °` X " °' CO .�/{� WSW o a a 4 N Q N W CC F�•t O � -.1 CO ZP, CD . 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U * = 6 o o M C LL O p E LLI r, a- e- Ce ey- a M CO ).- a) 0000000000 c X as O N N O O N O O N O U ID 0 0 0 0 0 0 0 0 0 0 N O O) M r 6 1 )- N N- t`7 I O CO CO (n v v a• O tO M C C E m 'f) 0 CO M CO 0) N t0 CO to N N 0 0 0 C) 0 N N N N N N N N N N N N A' _La-) 1� O) O O) O) to O) 0) O) 0) T v 8 O NNNNNNNNNN ,�\ N a) 0 0 0 0 0 0 O O O O 1/V O O O 0 0 0 O O O O •, In In to N to to N to to to P = N �ea � � E of cu cs) �' g E u f 6 c a� V O uJ D: i E EeNj a Ott G- •- m N N no_ z Y m M Z. mM O 03 M N e- N O p co 01 .+�+ iII E cu , Fe- Q E N W r d J U J oo S Z i _ ^ 3 i ami o � C� a � a as e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O 3- j 10 I=J- Well History File Identifier Organizing (done) o Two-sided /I 111111I11111 " III R,CAN vr Color Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NolType: o Poor Quality Originals: o Other: NOTES: BY: ~ Date I, <"">10 (p Project Proofing Date / / '"">/0 to ().. X 30 = If) () Date I/òjolo BY: ~ Scanning Preparation BY: ~ Production Scanning Stage 1 ~ô (Count does include cover sheet) VYES Page Count from Scanned File: BY: Page Count Matches Number in sea? nin~ Preparation: ~ Date: I/ò/ofo If NO in stage 1, page(s) discrepancies were found: Stage 1 BY: Date: Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Date: Maria Comments about this file: o Rescan Needed II I II 111111/1111 III OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: Y'1f III II 111I11 "'"11I mF 151 151 + ~ 1- = TOTAL PAGES ~ å- (Count does not include cover sheet) iliA 0 151 Hili 111111111111111111I YES NO 151 'vvtP NO 151 III II 111/111" II III III 11111I1111111111 151 Quality Checked /1111111111I 1111111 10/6/2005 Well History File Cover Page.doc Pr r t.5tf 7-2:36 Regg, James B (DOA) 7.03i44, From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] (chi Sent: Saturday, October 20, 2012 2:04 PM 0 To: AK, D &C Well Integrity Coordinator; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS Well Pad YP; Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); Fowler, Craig (CH2M HILL); Charles, Marcus A; AK, D &C DHD Well Integrity Engineer Subject: OPERABLE: Y -23B (PTD #2031640) Tubing Integrity Restored All, Producer Y -23B (PTD #2031640) passed a TIFL 10/19/2012 after bringing the well online proving tubing integrity has been restored. The well has been reclassified as Operable. Please call if you have any questions. Thank You, Shane Wills filling in for SCANN) APR 0 5 2013, Gerald Murphy BP Alaska - Well Integrity Coordinator E WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator @,BP.com From: AK, D &C Well Integrity Coordinator Sent: Saturday, October 13, 2012 6:22 AM To: AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Tea Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, OPS GC1 OSM; AK, OPS GC1 Field 0 M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS Well Pad YP Cc: AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Producers Y -20A & Y -23B Sustained Casin. •ressure During TAR All, The following producers are reclassified to Under Evaluation an. hould be placed online so a warm TIFL can be performed. Y -20A (PTD #2010250) Y -23B (PTD #2031640) Thank you, Mehreen Vazir • t>n z634, 0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] �,y cal i / i t y Sent: Saturday, August 11, 2012 9:46 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS Well Pad EKG; AK, OPS Well Pad YP Cc: AK, D &C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC); Ramsay, Gavin; Brown, Don L. Subject: NOT OPERABLE: Producers with Sustained Casing Pressure During TAR All, The following producers were found to have sustained casing pressure on the IA during shutdown for turnaround activity. The immediate action is to perform a TIFL on each of the wells to evaluate for IA repressurization. If the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. K -05D (PTD #2110770) K -12B (PTD #2091430) SCANNED MAC' 0 7 ZDIS P -25 (PTD #1970260) Y -20A (PTD #2010250) �3B (PTD #203164) t All the wells listed above are reclassified as Not Operable until start-up operations commence and are stable or the well passes a pressure test confirming integrity. After start-up, the wells will be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents if integrity has not been confirmed. Please call with any questions or concerns. Thank you, Mehreen Vazir BP Alaska - Well Integrity Coordinator x WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator PBP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.Vazir@BP.com 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 20, 2010 3 \ Mr. Tom Maunder a Alaska Oil and Gas Conservation Commission 333 West 7 Avenue r ry3�►sn�' : i Anchorage, Alaska 99501 r � `" - i1Fs s 6 j 4 . : Subject: Corrosion Inhibitor Treatments of GPB Y Pad 0 I Cp 9- Dear Mr. Maunder, la Enclosed please find multiple copies of a spreadsheet with a list of wells from Y Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 12 /20/10 Corrosion Well Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Name PTD # API # cement pumped _ cement date inhibitor sealant date ft bbls ft - na gal Y -01B 2010760 50029203940200 NA 2.5 NA 8.50 4/11/2010 Y - 02A 2011730 50029203950100 NA 0.1 NA 0.85 4/11/2010 Y -03A 2042350 50029204110100 NA 2.2 NA 18.70 4/16/2010 Y -04 1791050 50029204230000 NA 1 NA 5.10 4/11/2010 Y - 05B 2081380 50029204360200 NA 3.3 NA 20.40 4/15/2010 Y - 06A 2042510 50029204310100 NA 0.7 NA 3.40 4/16/2010 Y -07A 2071050 50029205600100 14.5 2.0 0.3 NA 1.70 8/4/2010 Y -08A 1880560 50029205720100 NA 4 NA 15.30 8/5/2010 Y -09A 1970830 50029205790100 19 1.5 3.6 NA 17.00 8/4/2010 Y - 10A 2042500 50029205870100 19 3.0 8.75 NA 54.40 8/6/2010 Y - 11C 2051640 50029205130300 NA 0.1 NA 0.90 4/14/2010 Y - 13 1811120 50029206340000 NA 0.4 NA 3.40 4/15/2010 Y -14B 2011010 50029218320200 NA 3.8 NA 20.40 4/10/2010 Y -15A 2010890 50029209400100 NA 2.1 NA 11.90 4/10/2010 Y -16 1830490 50029209320000 18.8 2.0 1.7 NA 10.20 8/4/2010 Y -18 1830290 50029209160000 NA 0.8 NA 5.10 4/9/2010 Y -19 1880960 50029218570000 NA 0.2 NA 0.85 4/15/2010 Y - 20A 2010250 50029215870100 NA 1.5 NA 11.90 4/14/2010 Y - 21A 1950370 50029215740100 NA 0.1 NA 1.70 4/13/2010 Y -22A 1881150 50029215580100 NA 0.5 NA 3.40 8/4/2010 Y -23B 2031640 50029215900200 NA 1.2 NA 6.80 4/13/2010 Y -24 1861130 50029216080000 NA 1 NA 6.80 4/12/2010 Y -25A 2081400 50029218830100 NA 0.3 NA 1.70 4/18/2010 Y -26A 2010430 50029221910100 NA 0.3 NA 1.70 4/15/2010 Y -27 1900280 50029220190000 NA 0.5 NA 3.40 4/14/2010 Y -28 1910650 50029221690000 NA 3.5 NA 28.90 4/12/2010 Y -29A 1960910 50029221230100 NA 0.2 NA 1.70 4/13/2010 Y - 30 1910150 50029221350000 NA 0.5 NA 2.60 4/13/2010 Y -31 1910560 50029221610000 NA 0.5 NA 3.40 4/12/2010 Y - 32 1910410 50029221490000 NA 0.3 NA 1.70 4/18/2010 Y - 33 1910300 50029221440000 NA 0.9 NA 6.80 4/12/2010 Y - 34A 1990040 50029221780100 NA 0.9 NA 5.10 4/11/2010 Y -35A 2022370 50029221860100 NA 1.5 NA 10.20 4/15/2010 Y -36 1931310 50029224000000 NA 0.9 NA 5.95 4/10/2010 Y -37A 2020460 50029224030100 NA 0.8 NA 6.00 4/14/2010 tin Schlumbuger 205 NO. 5436 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD • MPC -04 AXBD -00061 MEMORY <GLS Lq 0 1 9 1 3 11/17/09 1 1 NK -38A AWJI -00057 MEM PROD PROFILE (r 11/04/09 1 1 14 -12 83SO -00033 PRODUCTION PROFILE 11/13/09 1 1 13 -35 B14B -00084 INJECTION PROFILE (.) -Q 11/10/09 1 1 06 -08A B14B -00082 PLUGBACK SET W /X -FLOW CHECK - 11/08/09 1 1 H -30 AV1H -00031 PRODUCTION PROFILE 11/14/09 1 1 18 -11 A 82NJ -00038 MEM CNL & SCMT 111/06/09 1 1 Y -2313 AYKP -00055 GLS - - G a 11/22109 1 1 N -24 AYS4 -00109 PRODUCTION PROFILE / - 11/08/09 1 1 02 -31A AYKP -00053 PRODUCTION PROFILE 11/15/09 1 1 03 -01 B8K5 -00014 PRODUCTION PROFILE - 11/24/09 1 1 L -213 B581-00017 INJ PROFILE W/WFL 11/19/09 1 1 W -209 AYKP -00054 INJ PROFILE W/WFL - 11/17/09 1 i X -05 AP30 -00072 PRODUCTION PROFILE - 11129/09 1 1 X -07 AYS4 -00111 PRODUCTION PROFILE Q - 11/27109 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: B1 Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • ~.. r ~ .~ -i : ~7~1~i~il~~~ 03/01/2008 DO NOT PLACE ... ~:_~^^ - a"_ ~, ~. yam.; ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc ~ . STATE OF ALASKA I 6--/S...p¡1 . 1 5 2007 Al A Oil AND GAS CONSERVATION COM SION JUN REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas CòhS, Coml11ìSSIOn D D D 1. Operations Abandon D Repair Well 0 Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 79.15 KB <' 8. Property Designation: ADLO-028288 - 11. Present Well Condition Summary: Total Depth measured 14955 I feet true vertical 9008.03 feet Effective Depth measured 14869 r feet true vertical 9006.74 - feet Casing Length Size Conductor 80 20" 91.5# H-40 Surface 2786 13-3/8" 72# L-80 Production 6893 9-5/8" 47# L-80 Liner 5135 7" 26# L-80 Liner 3264 4-1/2" 12.6# L-80 Perforation depth: Measured depth: 13200 - 13335 True Vertical depth: 9041.99 - 9034.44 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 192 SHUT-IN x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic t\ t:. v....1 'V .... LJ Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 203-1640 -- TMENT Exploratory Service 6. API Number: 50-029-21590-02-00 9. Well Name and Number: PBU Y-23B / 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool -' Plugs (measured) None Junk (measured) None ;SCANNED JUN 2 6 2007 MD 32 - 112 31 - 2817 30 - 6923 6780 11915 11686 - 14950 13400 - 13620 9029.53 - 9018.87 4-1/2" 12.6# TVD 32 - 112 31 - 2699.31 30 - 5750.66 5648.17 - 8876.31 8728.79 - 9007.96 Burst 1490 4930 6870 7240 8430 Collapse 470 2670 4760 5410 7500 13680 - 13840 9019.39 - 9022.31 13930 - 14050 9020.82 - 9017.61 L-80 30' - 11695' 4-1/2" Baker SABL-3 Packer o o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 171 342 0 o 0 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Signature 11640 o o o Tubing pressure 239 o Service WINJ WDSPl Title Data Management Engineer Phone 564-4944 Date 6/11/2007 Form 10-404 Revised 04/2000 R / GIN A I RBDMS BFl JUN 1 9 Z007 b-(Q ~ \s. Submit Original Only . . Y-238 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 14 50/50 METHANOL 206 NH4CL W/F103 FLUSH 85 NH4CL W/F-103/U-67 176 7% HCL ACID 210 9:1 MUD ACID 60.5 DIVERTER 751.5 TOTAL . . 6/2/2007 i CTU #8 with iCoil, Mill / Acid Stirn with Isolation Packer; MU and RIH with jars, ipdm and 3.70" OD 4-blade mill. Tag obstruction at 11642' ctmd. Begin milling . what is suspected to be scale. Cont' milling down to 14182' ctmd. Scale . bridges were found every 30 to 40 ft; milled through fairly easy. PUH for short trip chasing debris up to 12000'. While PUH, observed gouges and scarring on i pipe. Circulate bottoms up and attempt to determine what is damaging coil. !Cont' on WSR 06/01/07... . Si3i¿oo7!cru#áwith iCoil,MillTÄc::id ·StimwithlsolationpaC::ker;...Cont'from WSR '06/02/07... Determine that pipe gouges are due to chains slipping. Chain [tension required to prevent chains from slipping is far more than should be i necessary. Decide to POOH to replace chains. While POOH circulating at 2.3 [bpm, pipe became temporally immobile at 11292' ctmd. Continued to circulate 'and eventually worked pipe free and proceed to POOH. At surface with tools. : Mill showed minimal wear. RD unit and road to shop for chain swap. *** Job ............. . m.... :p()stp()l1~ci***mmmm . ... . m ... ...mmmmmmm .......m .. .....mm . ..................... 6/4/200T CTU #8, Mill / Acid Stirn with Isolation Packer; MIRU unit. MU and RIH with 'jars, pdm and 3.7" OD 4-blade mill. Remove scale down to 14550' ctmd while making gel sweeps.POOH.Found broken IFC connection inside iCoil head after 'milling operation during inspection before making up packer for acis [stim.Rehead iCoil Connection. ;,.-... . .. . mm . m . ..m.*:::ç()l1~il1~~ºI1Y\JªBº~(º§(º?*:*:mm." 6/5/2007 CTU #8 w/ iCoil, Acid Stirn with Isolation Packer; ... Cont' from WSR 06/04/07 '... MU 2.125" OD iCoil Electronic Pack (pressure/temp/ccl) and 3.625" OD J- [Latch Packer. Successfully test pkr set and release with pressure test at 3385' 'bKB (tied in using iCoil). RIH and tag at 11111' bKB. Suspected scale. Pump [30 bbl7% HCL pill and let acid soak. RIH past tag depth. Tag XN nipple at '11685' bKB. Can not move pkr up or down. Circulate 10 bbl 7% HCL pill and ,spot around BHA. Still unable to move.Order safelube.Still unable to move coil 'after pumping a total of 180 bbls of safe lube down Ct x T annular. Prep to pump : N2 down coil before trying to shear tool downhole.Job In Progress. '****Continue On WSR 06/06/07**** ...........................u............................._..._...·..·,.·.....·.·...··__.....".................,........."....,..............,_.....__"......"...................."..........,....,...........................--.......--......'.................................-.....................................................----..----....,... 6/6/2007ICTU #8 w/ iCOil, Acid Stirn with Isolation Packer; ... Cont' from WSR 06/05/07 i... Circulate XS 1 % KCL with SafeLube to surface and displace fluid in coil with 'N2. Still unable to pull free. Pump 5/8" ball and disconnect from pkr and i POOH. MU and RIH with jars and 2.5" GS spear. Latch pkr at 11670' ctmd. Hit : 15 up jar licks and 2 down with no movement. Decide to POOH for accelerator i and weight bars (and to cut 50' of coil to limit fatigue where we are cycling pipe - 20% pipe life). MU and RIH with accelerator, 2 weight bars, jars and 2" GS i spear. Latch into top of packer @ 11673' ctmd.Made 35 jar licks up and 9 jars ,down with no success moving packer. Decision was made to release form ! packer and suspense fishing operation to regroup for next plan of :attack.POOH.Note: Lost a peace of the prong on the g-spear while trying to fish lout packer.About 3.5" Long x 1" Wide. . . :*****ColliiIlÙe·· Ön··WsR··osio¿io¿*****·Jo¡) In Progress. 6ni¿oo7icTu#8wTiCõiCÄëïdTreãtmelli;m..:Cõlli;fromwSRosiosio7i.:::· MUand R IH Iwith 2.5" JSN. RIH to 11500' ctmd. Pump 39 stage acid schedule as per 'program. Job Postponed due to high winds. 'Continue On WSR 06/08/08 6/7/2007 Assisting for high winds 6/8/2007 CTU #8 w/ iCoil, Acid Treatment; from WSR 06/07/07....At surface, standby due to wind.MU and RIH with 2.5" JSN.RIH to 11500' ctmd. Pump acid stages as per program. Total pumped today - 166 bbls 7% HCL - 210 bbls 9:1 Mud - 43 bbls Diverter - 1840 gal n2 - 160 bbls Overflush - 45 bbls PosUlush - 35 bbls Displacement. No real diversion action on perfs - On final Overflushes after all acid WHP 290 CT start 3650 decreaseing to 3450 - FP coil with meth - SD pump- coil went on vac. POH - RDMO CTU - **** Notify PO/PCC of well status - Ready to flow acid back thru ASRC portable sep. **** Job Complete **** Well Job# LOll Description Date BL olor D P2-37A 11491392 MEM PROD PROFILE 11/15/06 1 Y-23B 11418299 MEM PROD PROFILE 09/06/06 1 NK-07A 11588698 MEM GLS 12/21/06 1 07-01 A 11555031 GAS ENTRY SURVEY 12/19/06 1 NK-08A 11485780 MEM GLS 12/20/06 1 NK-27 11588699 MEM GLS 12/22/06 1 NK-43 11513659 PRODUCTION PROFILE 12/22/06 1 DS 09-32 11555530 INJECTION PROFILE 12/16/06 1 P2-14 11539745 MEM PROD PROFILE 12/07/06 1 Y-05A 11539744 MEM INJECTION PROFILE 12/06/06 1 S-02Ä 11285936 MEM PROD PROFILE 08/17/06 1 12-32 11536184 USIT 12/05/06 1 MPS-10A 11486087 COMPOSITE WFLlLDL 12/14/06 1 Z-19A 11226013 SCMT 10/28/06 1 Y-30L 1 11588700 MEM PROD PROFILE 12/23/06 1 E-11B 11434757 DSI 10/24/06 1 E-11B 11434760 DSI 10/29/06 1 E-11 B 11434760 FMI 10/29/06 1 G-14A 11485777 MEM PROD PROFILE 11/27/06 1 G-14A 11485777 SCMT 11/27/06 1 (J\ Schlumbel'gør Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ç)ô'3 -/0LJ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. SCANNED JAN 3 f) 20D7 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 01/25/2007 NO. 4125 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay C C . . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: e e WELL LOG TRANSMITTAL )¿D3 - (Lc:~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 \·31 a4- RE: MWD Formation Evaluation Logs Y-23B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 Y-23B: LAS Data & Digital Log Images: 50-029-21590-02 1 CD Rom ~C¡@QL(ì ;;1 r;9(CLO Y -23B Reclassified to Trouble status e ~~ 203,-( f4 Subject: Y -23B Reclassified to Trouble status From: "Reeves, Donald F" <ReevesDf@bp.com> . Date: Fri,30 Dec 200507:18:44 -0900. .' ~:~~~~~Sí~~~~·~~:¥;,~Jt@:~c"G~~s~l:~'¡e~·~~~~.:· <NSUADWWelIOperationsS· isor@bp:ÿom>, PB, Wel' tEng" .j~]i,:.;.:·' rYl' rZJjbJo'S ~GP{IlWeIlsOptEng@bp'9om>, " ..... GCC.Jç,""· . gg{E;.ma· <·<·egg@adIBin.sÚÜe. .. l' CC Winton Aubert -mail)" <winton__Jfll.·ert@a9m . të.ak.us>, "q '::::;GCl.. '. . ad'· . " 'GCIWellpadLead .com>,. "GPB, Prod\~ontrdllers" PBProde>·;~1:b~rs@bp.com>~}< Johl1~:':<:john.kurz .c?m>:·/< "" .' :..... ADW W 11 lnt 1 E ·tYEn~.·.·.n.···...Y..e..·:.;...·.··.·.~..·.~"'.·..:.r......(fl)..,. .,........b..·..·..~.com~;:.,!,'..W.. .' iD$1ÖW, .i.~..<LÇonsw@b~~~~~> :.~:.. nginee' .f..:.:>,0\< . All, j-Lì.X.- Well Y-23B has been reclassified to Trouble well status. The well has fairly rapid IAxOA communication .............. and also requires gas lift to flow. A recent attempt to mitigate the IAxOA communication by re-energizing the IC pack-off failed when the well continued to communicate after being put back online post pack-off work. Because the OAP will track the lAP, please have the gas lift 81 or otherwise isolated from the IA to /' prevent future lAP & OAP buildup. Please call if you have any questions. Thanks, Donald Reeves Well Integrity Engineer - Filling in for Anna Dube 907-659-5102 907-659-5100 Pgr 1154 { '(i" ¡ í "". ''''-, ~~6ib~~;;:t:L 1 of 1 12/30/2005 10:38 AM Y-23B (PTD #2031640) Classified as Problem Well e e 1(tt'11 z{ZtIÒ~ Subject: Y-23B (PTD #2031(40) Classified as Prohlem Wcll From: "?'-JSU, AD\\' ,^.'elllntcgrity Engineer" <NSU¡\[)WWclllntcgrityEnginccr«<)ßP.eom> Hate: Sun, 18 Dee 2005 22:59:26 -0900 To: "Subekti, Herry" <Hcrry.Subekti@BP.com>, "GPB, GCI Area Mgr" <GPBGCITUf.~;ßP.com>, "Rossbcrg. R Steven" <Steven.Rossberg@ßP.com>, "NSU, ADW Well Operations Supervisor" <NSlJADWWcIlOpcrationsSupervisor@?ßP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@?,BP.com>, "AOGCC Jim Regg (E-mail)..<jim_Jcgg@)admin.state.ak.us>. "AOGCC Winton Aubert (E-mail)" <winton.ßubert(q}admin.statc.ak.lIs>, "GPB, GCl Wcllpad Lcad" <GPBGC I WellpadLead(qjBP.com>, "GPB, Prod Controllers" <GPBProdControllcrs@}BP.com>, "Kurz, John" <john.kurz@BP.com> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellJntcgrityEngineer(à.?BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com> All, d..- 'O-'T i lol( Gas lifted well Y-23B (PTD #2031640) has been found to have sustained casing pressure on the OA. The TIO's on 12/17/05 were 1220/1480/1340. The OAP was bled down and built up pressure, confirming communication. The plan forward is to evaluate the wellhead pack-oft's as the communication path. The plan forward for this well is as follows: 1. DHD: OA repressure test - FAILED 2. WIE: Eval wellhead to communication path ... '. '\ ~ 'l.úü6 . . ~~i!:.n JA~ \! ~ ~~~~ti>o~ " A wellbore schematic has been included for reference. «Y-23B.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, jlnna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: Y -23B.pdf Content- Type: application/octet-stream Content-Encoding: base64 1 of 1 12/21/20054:44 PM e Y-23B tit I SAFETY NOTES: 2209' -14-112" X NIP, ID- 3.813'" 113-3/8 CSG, 72#, L-80-STRS, ID = 12.347" GAS LIFT MANDRELS ST MD TVD LA TCH PORT DATE 6 3231 2931 RK 0 Minimum 10 = 3.725" @ 11684' 5 4292 3717 SHR RK 11/19/03 4-1/2" XN NIPPLE 4 5891 4919 OMY RK 0 3 7489 6024 OMY BK 0 2 9045 7013 OMY BK 0 14-1/2" TBG, 12.6#, L-80 IBT-M, 10 = 3.958" 2817' 1 10517 7913 43 OMY BK 0 19-5/8" X T' LNR HGR I 6780' I TOP OF WHIPSTOCK H 6923' 19-5/8" CIBP I I CHEMICAL CUT 10/09/03 I I TOP OF P&A CEMENT TOPOF 3-3/16" LNR I TOPOF7" LNR , 10022' 10053' 19-5/8" CSG, 47#, L-80-BTRS, 10 = 8.681" I 10330' 7" LNR, 26#, L-80-TC4S, .0382 bpf, 10 = 6.276" 11650' ÆRFORA TION SUMI\.1\ARY REF LOG: MCCLlGR ON 11130103 TIE-IN LOG: SÆRRY -SUN ROP/OGR/EWR MWO LOG ANGLE AT TOP PERF: 91 @ 13200' Note: Refer to Production DB for historical perf data S SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 13200-13335 0 11/30103 2-7/8" 6 13400 - 13620 0 11/30103 2-7/8" 6 13680 -13840 0 11/30/03 2-7/8" 6 13930 - 14050 0 11/30/03 2-7/8" 6 14230 - 14510 0 11/30/03 OA TE REV BY 06/24/86 12/27/91 RKH 06/24/01 11/13/03 JDM/TL COMMENTS ORIGINAL COM PLETION POST RWO COMPLETION CTD SIDETRACK ETRACK --14-112" HES X NIP, 10 - 3.813" I -17" X 4-1/2" S-3 PKR, ID '" 3.875" I --14-1/2" HES X NIP, ID'" 3.813" I -14-1/2" HES XN NIP, ID = 3.725" I -14-1/2" WLEG, ID'" 3.958" I P&A'd 2-7/8" LNR -1 11781' I I PBTD H 14862' I 1 4-1/2" LNR, 12.6#, L-80, IBT-M, ID - 3.958" I DATE REV BY COMMENTS PRUDHOE SA Y UNIT WELL: Y-23S ÆRMIT No: 2031640 API No: 50-029-21590-02 SEe 33, T11 N, R13E, 1372' SNL & 24' wa SP Exploration (Alas ka) 3ô~ DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031640 Well Name/No. PRUDHOE BAY UNIT Y-23B Operator BP EXPLORATION (ALASKA) INC $pc.J. Al.Þ 0 K ~ API No. 50-029-21590-02-00 MD 14955 ~ TVD 9008 / Completion Date 11/30/2003 / Completion Status 1-01L Current Status 1-01L UIC N -------"- -- ------- ~-- -------- --------" Mud Log No Samples No Directional Survey < ~'-~ )~ REQUIRED INFORMATION - --. --"----- -- ---- DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, RES, ASI, MGR, CCL Well Log Information: Electr Di ital Dataset CJ/Frmt Number Name C Lis 13236 See Notes (data taken from Logs Portion of Master Well Data Maint Name Interval Start Stop ~-:.. Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments --~--- --. ----~---_. 2 7232 Case 7/14/2005 PDC GR 6890 14955 Open 12/8/2003 6890 14955 Open 12/8/2003 MWD 6774 14903 Open 9/26/2005 GR EWR4 ASI PWD Rap 6774 14903 Open 9/26/2005 GR EWR4 ASI PWD ROP ----- -.- -_. Sample Set Sent Received Number Comments ~.~ Rpt Rpt ~ D Lis Rpt Directional Survey Directional Survey 13282 Induction/Resistivity 13282 LIS Verification Well Cores/Samples Information: ADDITIONAL INFOR~ON Well Cored? ~ Chips Received? - Y / N Daily History Received? fuN ~/N Formation Tops Analysis Received? ~ -~~ ---- --- - Comments: I' Compliance Reviewed By: ~ Date: J, \ ~~--- ~--~=-~ ~~-----~ .fp WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 July 28, 2005 RE: MWD Formation Evaluation Logs: Y -23B, AK-MW -2732043 1 LDWG formatted Disc with verification listing. API#: 50-029-21590-02 f I ) ~g ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OFTHE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Å~1r~~- Signed: 1JJ OW ÅO )-1 ~ Lj Schlumbergop Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well 1-31/M-21 ,q ') - 07 ).. 07-34A ) Cc ~ OJ 3 15-14A ~û4- ~J. ~ Y-23B .A (j .3 ~~ I (,¡ '1 N-08A J.~~~ ~aq K-08A :A \:/~ '- Î c..( t W-26A ,q', - c:\ \ L5-09 , q ~~ Ll '-f OWDW-NW Ice ". A..'1 ~ C-34 198 ~ 0/ ') 01-12A 'i ~ ).. - t ti \ DS 05-41A }..tJ ~,- I ~/~ 02-26C ). 0 '\; - ù \ q Job# 10980540 11001051 10913003 10913024 10919802 10942219 11051066 11051037 10980537 10831309 10928620 10715377 10928619 Log Description Date 04/14/05 04/26/05 01/16/05 06/09/05 09/24/04 06/24/05 06/23/05 04/27/05 03/26/05 07/09/04 04/03/05 01/21/04 03/20/05 RST (REVISED)* RST (REVISED)* PEX-DSI-AIT PDC-GR LDL MEM PPROF LDL RST RST RST MCNL MCNL MCNL *REVISED TO CORRECT API# ON DIGITAL DATA PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 1 \ .~ r..-f-;,J ( "~ /, /V~~ \ 07/14/05 NO. 3433 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL CD 1 1 1 1 I ~ :l.~ 3 iJ)..!'Y i 1 Á) r~ /3 :¿J b' Color .~.---. 1 1 1 1 1 1 1 1 1 J 3lJ 7 I 3 ~J8 iJ lJo/ J > ).'-/ t\ i3~'-1f 1');)..4;). Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK. 97195032838 ATTN: Beth ;,1 ä Received by: \. -(\~....... U/:;l/ ! 'WVvz/ t STATE OF ALASKA ~( ALAl ..-\ OIL AND GAS CONSERVATION COMrvl......SION REPORT OF SUNDRY WELL OPERATIONS (;"¡:::¡~ ~ .~ 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate [2] Other D ! I , .... ~ ß i!f '£..t) Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time E~~~nsion IT U & ..~ tp 200"" Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspendeq"VYeJlD J 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill NÙlÌÍb"er:- 3 [\:\'7" ("J Name' r.7 E I t r ' ~""'. (,{J,ry->;-;;," . . Development I" xp ora ory 203-1640 .....'::r~-,",. ',s·".Û$;S,r;r -.¡¡.,,~'II""'~';;:.J ~ )1" Stratigraphic r Service r 6. API Number: 50-029-21590-02-00 P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 79.15 KB 8. Property Designation: ADL-028288 11. Present Well Condition Summary: Total Depth measured 14955 true vertical 9008.03 Effective Depth measured 14869 true vertical 9006.74 Casing Conductor Surface Production Liner Liner Length 80 2786 6893 5135 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# L-80 4-1/2" 12.6# L-80 3264 Perforation depth: Measured depth: 13200 - 13335 True Vertical depth: 9041.99 - 9034.44 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 273 263 9. Well Name and Number: Y -23B 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet Plugs (measured) None feet Junk (measured) None feet feet MD TVD Burst 32 - 112 32 - 112 1490 31 - 2817 31 - 2699.31 4930 30 - 6923 30 - 5750.66 6870 6780 - 11915 5648.17 - 8876.31 7240 11686 - 14950 8728.79 - 9007.96 8430 Collapse 470 2670 4760 5410 7500 13400 -·13620 13680 - 13840 13930 - 14050 9020.82 - 9017.61 14230 - 14510 9029.53 - 9018.87 9019.39 - 9022.31 9012.02 - 9005.46 4-1/2" 12.6# L-80 30 - 11695 4-1/2" Baker SABL-3 Packer 11640 RBDMS 8~l rl ., AIlG .~ () 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 187 38 825 174 26 340 15. Well Class after proposed work: Exploratory Development I;?} 16. Well Status after proposed work: Oil it;21 Gas Ci WAGC Tubing pressure 345 240 Service WDSPL 0 GINJ WINJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal prin:i::~~~ ?i4 Form 10-404 Revised 04/2004 Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Date 8/25/2005 : 11 ·1 ~ U r\ \- Submit Original Only '{ :( Y -238 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 7/12/2005 RU CT Unit #5. wI 17,500' 1.75" 00. 38.8 bbls volume. Chrome running footage= 246K Overall running footage 445K. Job scope: Acid wash perforations wI 75 bbls HCLlXylene Job in progress.... 7/13/2005 Job in progress: Acid wash perforations wI HCLlXylene. Pump acid job per procedure. Pre-acid wash rate 1.5 bpm @ 780 psi. Post-acid wash rate 2 bpm @ 140 psi. POOH. ROMO. Turn well over to OSO to POP. ***** Job Complete***** FLUIDS PUMPED BBLS 584 KCL 265 Diesel 53 DAD Acid 902 TOTAL ,I STATE OF ALASKA .c ALASKA( _ AND GAS CONSERVATION COM~ jlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1372' SNL, 24' WEL, SEC. 33, T11N, R13E, UM Top of Productive Horizon: 2484' NSL, 832' WEL, SEC. 29, T11 N, R13E, UM Total Depth: 2823' NSL, 3643' WEL, SEC. 29, T11 N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 644792 y- 5948883 Zone- ASP4 TPI: x- 638623 y- 5952624 Zone- ASP4 Total Depth: x- 635805 y- 5952912 Zone- ASP4 18. Directional Survey IBI Yes 0 No 21. Logs Run: DIR, GR, RES, ABI, MGR, CCL One Other 5. Date Comp., Susp., or Aband. 11/30/2003 6. Date Spudded 10/26/2003 7. Date T. D. Reached 11/8/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 79.15' 9. Plug Back Depth (MD+ TVD) 14869 + 9007 Ft 10. Total Depth (MD+TVD) 14955 + 9008 Ft 11. Depth where SSSV set (Nipple) 2209' MD 19. Water depth, if offshore N/A MSL 1 b. Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-164 13. API Number 50- 029-21590-02-00 14. Well Number PBU Y -238 15. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028288 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 22. 1:~,'GAsING,' ~~".I¡i,.IßIZ~, .'1:'" :' 20" 13-3/8" 9-5/8" 7" CASING, LINER AND CEMENTING RECORD . "·S~"'·"Ð"·'· .".....,.,...', ··L··"""· '."..'.'. .'''.'' I'··'····,· ...,' ':'>:.," ç:;,·,.ING.. :.'.' e.... R.. ,:t.tiI. ,~.·",...:".,.,.,','.;I"HO '. e!: ,.:1.11: .'I<I'i. ""'.'1 i',·.,',·. ,.i "".::... 1'1.··. '...:'1."".1,1··.., ..,' :,.' ;" , I.. <,...".. . ',:. ,.....'.1. é " "'"'''~\'.''''''' ~... .,". ,",' ··"'·'''',,1 .""...:.",... ..".' ,.·:.'~""'~flj',I',. " 1"'1. ·;Z. ::"III~··"·" '.. .'" eriAcK'íl·NG RCGOCI'\I'II ",...1 1,:·.1,1 '.1' ",.. ,. ",, I',:, 1~;;'I q::I'~.V,I,I,' 'I ",""'", I ~:-I "\,1'1 ,~:V:II"",""~I,"I" ,I·,': M.,', '~:~""""dl",,;,'JI ,"" 1':, Surface 110' 26" 8 cu yds Concrete Surface 2817' 17-1/2" 3902 cu ft Permafrost Surface 6923" 12-1/4" 572 cu ft Class 'G' 6780' 11915' 8-1/2" 197 cu ft Class 'G' 11686' 14950' 6-1/8" 1443 cu ft Class 'G' I" ':, '<' 'il ',".';;'j' " I,: I '\,,~ :','." ,i:: I ';·.iVVJ'.;·"p:Eij,:,F~:;·:·:" ,'"" : .~," /1' 'I: 1'1 G~ j~II',;""i: 72# 47# 26# 12.6# L-80 L-80 L-80 L-80 4-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-7/8" Gun Diameter, 6 spf MD TVD MD TVD 13200' - 13335' 9042' - 9034' 13400' - 13620' 9030' - 9019' 13680' - 13840' 9019' - 9022' 13930' -14050' 9021' - 9018' 14230' - 14510' 9012' - 9005' 26. Date First Production: January 1, 2004 Date of Test Hours Tested PRODUCTION FOR 1/4/2004 4 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED ........ Press. 277 24-HoUR RATE"'" 1·,,.,.1:1 'I "I:;:;i¡:::':,;,,', :1.,.. ..'...',,:',.........,.,",;,........., .. ·'~9U~T,:,I?ÙL~ED·,'I'.·.il.." '24!;"I~1 PACKER SET (MD) 11640' SIZE 4-1/2", 12.6#, L-80 DEPTH SET (MD) 11697' DEPTH INTERVAL (MD) 2500' I', '¡'I' 111,1" ,', ",11.':,-:,::. 'I,",. I', : I ,::".: ";1" "I' rJ.,' '", I," ,:..1' ,:".., 'I,: ',,', I ,':",: I ,. I::' ',' ':"', ,'. ',I" I' ,~"" I ,,':,': I ?5. ... I'"" ....:' i",. 1'"",,:,,:', 1','Æ\ÇII!); '""JAAC~ jREI; IOEM,ENt,SqLJEEZE'/; ~e; IC.;, I....·. ......., " ,1,1.' ,111111''1,',1, ,:..,,1, 1,1 ':1, ,11,1,11' ',I' 'i!",1 , "",L "",II".': ,111,:1" ~I"II,'::IIII,I,II, ,,', ,"1,," ,1,':'11',' ',1,1',,1, ,', "".,1"1,,. "I, 'I, ",1,1 11,1",,,,' ¡ AMOUNT & KIND OF MATERIAL USED Freeze Protect with MeOH PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift OIL-BsL 3,859 OIL-BsL 23,154 GAs-McF 4,405 GAs-McF 26,430 WATER-BsL -0- W A TER-BsL -0- CHOKE SIZE 96° OIL GRAVITy-API (CORR) 25.3 GAS-OIL RATIO 1,141 27. CORE DATA n,... f".' B\ Ir r"'\ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attaih~~¥,Il...ò",ssary). Submit core chips; if none, state "none". None Form 1 0-407 Revised 2/2003 ORIGINAL CONTINUED ON REVERSE SIDE tRIDM\S 8Fl, JAN 0 ~ 20ß4 LV JAN 0 7 2004 Alaska Oil & Gas Cons. Commission Anchorage 2~. GEOLOGIC MARKERS( NAME MD Sag River 11915' Shublik A 11948' Shublik B 12015' Shublik C 12047' Sadlerochit 12090' HOT 12230' 29. l JRMATION TESTS Include and briefly summarize test results. List intervals tested, TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 8876' None 8897' 8940' 8959' 8984' 9050' RECE"/ED JAN 0 7 2004 Alaska Oil & Gas Cons. Lommission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~~ ~~ Title Technical Assistant 203-164 Date OJ· OC,p-oL( PBU Y -23B Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". Form 10-407 Revised 2/2003 ITEM 29: List all test information. If none, state "None". (1 n , (' , ~.. , " , Legal Name: Y -23 Common Name: Y -238 Test· Date 1 0/25/2003 11/1/2003 FIT FIT Test Type Test Depth (TMD) 6,923.0 (ft) 11,916.0 (ft) BPEXPLORATION Leak-Off Test Summary Test Depth. (TVD) 5,750.0 (ft) 8,877.0 (ft) AMW 9.50 (ppg) 8.40 (ppg) Surface Pressure 750 (psi) 560 (psi) Leak Off Pressure (BHP) 3,588 (psi) 4,434 (psi) Page 1 of 1 EMW 12.01 (ppg) 9.61 (ppg) --"'- ~--.- Printed: 11/12/2003 11 :00:09 AM ( t BP EXPLORATION Operations Summary Report Page 1 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y-23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 10/21/2003 12:00 - 17:30 5.50 MOB P PRE Prep for move to Y-pad. Move camp, shop, and pit I pump module to Y-Pad. 17:30 - 20:30 3.00 MOB P PRE Move sub structure from J-Pad to V-Pad. On location at 20:30 hours. 20:30 - 00:00 3.50 MOB P PRE Level location. Lay mats and Herculite. Spot sub base on Y-23. Lay Herculite. Spot pit I pump module. 1 0/22/2003 00:00 - 05:30 5.50 RIGU P PRE Spot sub base. Raise and pin derrick. Lay Herculite. Spot pit module, cuttings tank, and shop. Berm area around cuttings tank, pit module interconnect. R/U floor, bridle down, clean rig. 05:30 - 06:00 0.50 RIGU P PRE Pre spud safety and environmental meeting. Add 2.5 hours to rig acceptance time due to disassembly of BOP before release for summer maintenance shut down. (Rig Accepted at 08:00 10/22/2003). 06:00 - 07:00 1.00 RIGU P PRE Install secondary annulus valve. 0 psi on annulus and tubing. Well dead. 07:00 - 08:00 1.00 RIGU P DECOMP R/U DSM. Pull BPV with lubricator. 08:00 - 09:30 1.50 RIGU P DECOMP R/U lines to circulate out freeze protection diesel to cuttings tank. 09:30 - 12:00 2.50 WHSUR P DECOMP Test lines to 3,500 psi. Circulate out freeze protection at 5 bpm and 500 psi. Increase rate to 9 bpm and 950 psi. 12:00 - 13:00 1.00 WHSUR P DECOMP CIW dry rod in TWC. Test from below to 1,000 psi. No test. 13:00 - 16:00 3.00 WHSUR P DECOMP Call DSM. DSM delayed due to Nordic Rig 2 move. R/U DSM lubricator. Trouble pulling TWC. Drain tree. Retrieve rubber from seal. Pull TWC with lubricator. C/O and install TWC. Test from below to 1,000 psi. Good test. R/D DSM. 16:00 - 18:00 2.00 WHSUR P DECOMP NID tree and adapter flange. Hanger threads, 4 1/2" TDS, checked, O.K. Function all LDS, O.K. 18:00 - 20:00 2.00 BOPSURP DECOMP NIU BOPE. 20:00 - 20:30 0.50 BOPSUR P DECOMP R/U test joint. 20:30 - 23:30 3.00 BOPSURP DECOMP Test BOPE and all related valves to 250 psi low and 3,500 psi high. Witness of test waived by Lou Grimaldi of the AOGCC. 23:30 - 00:00 0.50 BOPSURP DECOMP RID test joint. 1 0/23/2003 00:00 - 01 :00 1.00 WHSUR P DECOMP R/U DSM and pull TWC with lubricator. 01 :00 - 02:00 1.00 WHSUR P DECOMP PJSM. MIU tubing hanger crossover and joint dp. Screw into tubing hanger. BOLDS. Pull hanger to floor with 1 OOK string weight. No overpull. LID tubing hanger. 02:00 - 03:00 1.00 PULL P DECOMP R/U 4 1/2" tubing handling equipment. R/U Camco control line spooling equipment. PJSM. 03:00 - 06:00 3.00 PULL P DECOMP LID 41/2", 12.6#, 13Cr-80, TDS tubing from 7,000' to 4,785'. Recover BVN, 4 stainless bands, and 28 control line clamps. RID spooling unit. 06:00 - 10:00 4.00 PULL P DECOMP LID 41/2", 13Cr-80, TDS tubing from 4,785'. Recovered a total of 174 joints tubing plus 27.68' cut joint. 10:00 - 11 :00 1.00 PULL P DECOMP RID tubing equipment, clean and clear rig floor. 11:00-12:00 1.00 BOPSURP DECOMP R/U and test lower set of pipe rams to 250 psi low and 3,500 psi high. Install wear bushing. 12:00 - 13:00 1.00 EVAL P DECOMP Service top drive. 13:00 - 14:00 1.00 EVAL N WAIT DECOMP Wait on SWS. Printed: 11/12/2003 11 :00: 18 AM ( ~. BP EXPLORATION Operations Summary Report Page 2 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y-23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1 0/23/2003 14:00 - 17:00 3.00 EVAL P DECOMP PJSM. R/U SWS. RIH with 8.5" GR/JB. Tag tubing stump at 6,978' (WLM). POOH with GR/JB. Some scale recovered in junk basket. 17:00 - 18:00 1.00 EVAL P DECOMP R/U SWS firing head and HES 9 5/8" EZSV . Include CCL. 18:00 - 19:00 1.00 EVAL P DECOMP RIH with EZSV on SWS Eline. 19:00 - 19:30 0.50 EVAL P DECOMP Log into position with CCL. Casing collar located at 6,951' (WLM). Place top of EZSV at 6,946' (WLM). Initiate firing head. At 3 minutes 40 seconds, good surface indication of fire and plug set. Log off of plug and back down to confirm bridge plug placement at 6,946' (WLM). 19:30 - 20:00 0.50 EVAL P DECOMP POOH with SWS Eline. 20:00 - 20:30 0.50 EVAL P DECOMP RID SWS equipment. 20:30 - 22:00 1.50 BOPSUR P DECOMP Pull wear bushing. N/D BOPE. 22:00 - 00:00 2.00 WHSUR P DECOMP NID tubing spool. Remove 9 5/8" packoff, Install new 95/8" packoff. N/U new tubing spool. 10/24/2003 00:00 - 01 :30 1,50 WHSUR P DECOMP NIU new tubing spool. Pressure test packoff to 3,500 psi. Good test. 01 :30 - 03:30 2.00 BOPSURP DECOMP N/U BOPE. 03:30 - 04:30 1.00 BOPSURP DECOMP R/U and pressure test 9 5/8" casing to 3,500 psi for 30 minutes. Record test. 04:30 - 07:00 2.50 STWHIP P WEXIT PJSM. PIU and M/U whip stock assembly to 83'. Upload MWD and surface check. 07:00 - 08:30 1.50 STWHIP P WEXIT PIU BHA from 83' to 1,070'. 08:30 - 09:30 1.00 STWHIP N DFAL WEXIT Attempt to circulate. BHA plugged. 09:30 - 11 :00 1.50 STWHIP N DFAL WEXIT Drop rabbit. POOH with BHA from 1,070' to 83'. 11 :00 - 14:00 3.00 STWHIP N DFAL WEXIT LID and flush tools. Found scale packed off in MWD pulser & starter mill. 14:00 - 16:00 2.00 STWHIP P WEXIT PIU BHA #2 to 45'. RIH to 320' with drill collars, circulate. RIH from 320' to 1,000' with 5" HWDP, circulate. A lot of scale coming back across shakers. 16:00 - 21 :00 5.00 STWHIP P WEXIT P/U jars; PIU 4" drill pipe from 1,032' to 6,947'. Circulate 1 1/2 dp volume every 1,500'. PIU weight 155K, S/O weight 130K, Rot weight 145K Tag top of EZSV at 6,947'. 21 :00 - 22:00 1.00 STWHIP P WEXIT Pump 30 bbl viscous spacer. Displace well to 9.5 ppg milling fluid at 220 spm and 1,500 psi. Some additional 'scale' intermittently coming across shakers during displacement. 22:00 - 00:00 2.00 STWHIP P WEXIT Pump dry job. POOH with drill pipe from 6,947' to 2,714'. 1 0/25/2003 00:00 - 01 :00 1.00 STWHIP P WEXIT POOH from 2,714' to 1,070' with drill pipe. 01 :00 - 02:30 1.50 STWHIP P WEXIT Handle BHA from 1,070'. 02:30 - 03:00 0.50 STWHIP P WEXIT MIU MWD and surface test. 03:00 - 03:30 0.50 STWHIP P WEXIT Orient MWD. MIU whip stock. 03:30 - 04:30 1.00 STWHIP P WEXIT Handle BHA to 1,070'. 04:30 - 07:30 3.00 STWHIP P WEXIT RIH with drill pipe from 1,070' to 6,946'. Fill pipe every 3,000'. PIU weight 150K, SIO weight 130K. 07:30 - 08:00 0,50 STWHIP P WEXIT Orient Whip Stock 67 deg LHS, set bottom trip anchor with 45K down weight. Shear off milling BHA from whip stock. 08:00 - 12:00 4.00 STWHIP P WEXIT Mill window in 9 5/8" casing. TOW at 6,923', BOW at 6,938'. Drill I mill to 6,956'. Torque on btm 5/7K, off btm 4K. Recovered -60 Ibs metal cuttings. 12:00 - 13:00 1.00 STWHIP P WEXIT Work window. Circulate sweep around. 13:00 - 13:30 0.50 STWHIP P WEXIT Perform FIT at 6,923' (5,750' tvd) with 9.5 ppg and 750 psi to Printed: 11/12/2003 11: 00: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( ( BP EXPLORATION Operations Summary Report Y-23 Y-23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Page 3 of 17 Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1 0/25/2003 13:00 - 13:30 0.50 STWHIP P WEXIT 12.0 ppg EMW. 13:30 -14:00 0.50 STWHIP P WEXIT Pump dry job, monitor well. Blow down surface equipment. Remove blower hose. 14:00 - 16:00 2.00 STWHIP P WEXIT POOH from 6,956' to 1,070' with drill pipe. 16:00 - 18:00 2.00 STWHIP P WEXIT C/O handling equipment. POOH and handle BHA from 1,070'. Clear floor. Upper string mill full gauge. 18:00 - 19:00 1.00 DRILL P INT1 Pull wear bushing. Flush BOPE stack and function same. Install wear bushing. 19:00 - 22:30 3.50 DRILL P INT1 PJSM. M/U BHA #4 to 1,176'. Upload MWD and surface test. 22:30 - 00:00 1.50 DRILL P INT1 P/U 5" drill pipe from 1,176' to 2,895'. Fill pipe at 2,400'. 1 0/26/2003 00:00 - 02:30 2.50 DRILL P INT1 P/U 5" drill pipe (183 joints) from 2,895' to 6,895'. Adjust clock for Day light saving time. (3.5 hours operation) 02:30 - 04:00 1.50 DRILL P INT1 Slip and cut drilling line. Service top drive. 04:00 - 04:30 0.50 DRILL P INT1 Slack off and wash through window. No problems. Tag Undergauge hole at 6,946'. Ream UG hole to 6,956'. 04:30 - 11 :00 6.50 DRILL P INT1 Directional drill from 6,956' to 7,365'. ART = 1.77 hrs, AST = 1.31 hrs, ADT = 3.08 hrs P/U weight 175K, S/O weight 140K, Rot weight 160K. Slide / Rotate 409' (6,956' - 7,365') Slide at TF 65 to 85 LHS to initiate LH turn to plan azimuth. Flow rate 575 gpm, on btm 2,150 psi, off btm 1,950 psi. WOB 10 -12 K, ROP 150 fph Rotate at 80 RPM Flow rate 575 gpm, on btm 2,450 psi, off btm 2,150 psi. Torque on btm 10/14K; Torque off btm 7K WOB 10 -12K, ROP 150 - 200 fph 11 :00 - 11 :30 0.50 DRILL N RREP INT1 POOH from 7,365' to 6,899'. Washout in fluid end of #2 pump. 11 :30 - 20:30 9.00 DRILL N RREP INT1 C/O #1fluid end on #2 pump. Test to 3,500 psi. O.K. 20:30 - 21 :00 0.50 DRILL N RREP INT1 RIH from 6,899' to 7,365'. Stage pumps up and wash last stand to bottom. 21 :00 - 00:00 3.00 DRILL P INT1 Survey. Directional drill from 7,365' to 7,586'. ART = 1.32 hrs, AST = 0.00 hrs, ADT = 1.32 hrs P/U weight 175K, S/O weight 140K, Rot weight 160K. Rotate 221' (7,365' - 7,586') Rotate at 80 RPM Flow rate 575 gpm, on btm 2,450 psi, off btm 2,150 psi. Torque on btm 12K; Torque off btm 8K WOB 10 -12K, ROP 150 - 200 fph 1 0/27/2003 00:00 - 07:30 7.50 DRILL P INT1 Directional drill from 7,586' to 8,261'. ART = 3.88 hrs, AST = 0.57 hrs, ADT = 4.45 hrs P/U weight 180K, S/O weight 135K, Rot weight 160K. Rotate/Slide 675' (7,586' - 8,261') Printed: 11/12/2003 11 :00:18 AM f ,.~. ( BP EXPLORATION Operations Summary Report Page 4 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y -23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1 0/27/2003 00:00 - 07:30 7.50 DRILL P INT1 Slide at TF 45 RHS for maintenance Flow rate 575 gpm, on btm 2,700 psi, off btm 2,350 psi. WOB 15K, ROP 100 fph Rotate at 90 RPM Flow rate 575 gpm, on btm 2,850 psi, off btm 2,550 psi. Torque on btm 14/16K; Torque off btm 10K WOB 10 -15K, ROP 100 - 200 fph Back ream 1 ream at each stand down at max rate and 125 rpm; ECD ranging from 11.1 to 11.5. 07:30 - 08:30 1.00 DRILL P INT1 CBU at 13 bpm and 2,460 psi. 08:30 - 09:30 1.00 DRILL P INT1 POOH from 8,261' to 6,889'. Had overpull of 25 - 30K at 7,825 - 7,782', and 7,169' - 7,059'. Monitor well. 09:30 - 10:00 0.50 DRILL P INT1 RIH from 6,889' to 8,261'. 10:00 - 12:00 2.00 DRILL P INT1 Directional drill from 8,261' to 8,412'. ART = 0.97 hrs, AST = 0.00 hrs, ADT = 0.97 hrs PIU weight 190K, S/O weight 135K, Rot weight 165K. Rotate 151' (8,261' - 8,412') Rotate at 100 RPM Flow rate 575 gpm, on btm 3,050 psi, off btm 2,750 psi. Torque on btm 15K; Torque off btm 13/15K WOB 15K, ROP 100 - 200 fph 12:00 - 00:00 12.00 DRILL P INT1 Directional drill from 8,412' to 9,234'. ART = 5.68 hrs, AST = 1.14 hrs, ADT = 6.82 hrs PIU weight 190K, S/O weight 140K, Rot weight 165K. Rotate/Slide 822' (8,412' - 9,234') Slide at TF 0 - 30 RHS for maintenance Flow rate 575 gpm, on btm 3,100 psi, off btm 2,900 psi. WOB 15K, ROP 90 fph Rotate at 95 RPM Flow rate 575 gpm, on btm 3,500 psi, off btm 3,250 psi. Torque on btm 10/12K; Torque off btm 9/10K WOB 12 -15K, ROP 100 - 150 fph ECD ranging from 12.2 - 12.5 1 0/28/2003 00:00 - 02:30 2.50 DRILL P INT1 Drilled 8 1/2" Directional Hole By Rotating From 9,234' to 9,419' WOB Rotating 12,000# - 15,000#, RPM 100, Motor RPM 167, Torque Off Bottom 10,000 ft 1 Ibs - On Bottom 12,000 ft 1 Ibs, Pump Rate 575 gpm, SPP Off Bottom 3,250 psi, On Bottom 3,500 psi. String Weight Up 190,000#, String Weight Down 140,000#, String Weight Rotating 165,000#- ART = 1.97 hrs. - AST = 0 hrs. 02:30 - 03:30 1.00 DRILL P INT1 Circulate Bottoms Up While Rotating And Reciprocating Drill Printed: 11/12/2003 11 :00:18 AM ( BP EXPLORATION Operations Summary Report Page 5 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y-23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 10/28/2003 02:30 - 03:30 1.00 DRILL P INT1 String - 12 BPM With 3,120 Psi. 03:30 - 05:00 1.50 DRILL P INT1 Monitor Well Bore (Static) - Pump Dry Job - POH With BHA No.4 (Wiper Trip) From 9,419' To 6,882' With No Problems During Trip To Window 05:00 - 05:30 0.50 DRILL P INT1 Service Top Drive, Traveling Blocks, And Crown Sheaves 05:30 - 06:00 0.50 DRILL P INT1 RIH With BHA No.4 From 6,882' To 9,419' With No Problems As Precaution Wash Last Stand To Bottom From 9,327' To 9,419' 06:00 - 16:00 10.00 DRILL P INT1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 9,419' to 10,046' WOB Rotating 15,000# - 20,000#, WOB Sliding 10,000# To 15,000#, RPM 100, Motor RPM 156, Torque Off Bottom 14,000 ft /Ibs - On Bottom 15,000 ft / Ibs, Pump Rate 540 gpm, SPP Off Bottom 3,430 psi, On Bottom 3,750 psi. String Weight Up 205,000#, String Weight Down 135,000#, String Weight Rotating 170,000# - ART = 5.36 hrs. - AST = .68 hrs. 16:00 - 17:30 1.50 DRILL N RREP INT1 Change Out Suction And Discharge Valves And Seats In Third Cylinder On NO.2 Mud Pump 17:30 - 18:00 0.50 DRILL P INT1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 10,046' to 10,067' 18:00 - 18:30 0.50 DRILL N RREP INT1 Change Out Discharge Cap And Gasket Third Cylinder On NO.2 Mud Pump 18:30 - 00:00 5.50 DRILL P INT1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 10,067' to 10,410' WOB Rotating 15,000# - 20,000#, WOB Sliding 10,000# To 15,000#, RPM 100, Motor RPM 156, Torque Off Bottom 12,000 ft /Ibs - On Bottom 14,000 ft / Ibs, Pump Rate 537 gpm, SPP Off Bottom 3,510 psi, On Bottom 3,800 psi. String Weight Up 205,000#, String Weight Down 140,000#, String Weight Rotating 170,000# - ART = 3.22 hrs. - AST = .64 hrs. 1 0/29/2003 00:00 - 07:00 7.00 DRILL P INT1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 10,410' To 10,819' WOB Rotating 15,000# - 20,000#, WOB Sliding 10,000# To 15,000#, RPM 100, Motor RPM 156, Torque Off Bottom 12,000 ft / Ibs - On Bottom 14,000 ft / Ibs, Pump Rate 537 gpm, SPP Off Bottom 3,510 psi, On Bottom 3,800 psi. String Weight Up 205,000#, String Weight Down 140,000#, String Weight Rotating 170,000# - ART = 4.25 hrs. - AST = .61 hrs. 07:00 - 08:00 1.00 DRILL P INT1 Circulate Bottoms Up At 12.5 BPM With 3,580 Psi. While Rotating And Reciprocating Drill String - Monitor Well Bore (Static) 08:00 - 09:30 1.50 DRILL P INT1 POH With Directional BHA No.4 From 10,819' To 9,327' With No Problems - Monitor Well Bore (Static) - Change Out Air Boot On Bell Nipple 09:30 - 10:00 0.50 DRILL P INT1 RIH With BHA No.4 From 9,327' To 10,819' With No Problems As Precaution Wash Last Stand To Bottom From 10,726' To 10,819' 10:00 - 00:00 14.00 DRILL P INT1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 10,819' To 11,800' WOB Rotating 15,000# - 20,000#, WOB Sliding 10,000# To 15,000#, RPM 90, Motor RPM 156, Torque Off Bottom 13,000 ft / Ibs - On Bottom 15,000 ft Ilbs, Pump Rate 537 gpm, SPP Off Bottom 3,830 psi, On Bottom 4,030 psi. String Weight Up 235,000#, String Weight Down 150,000#, Printed: 11/12/2003 11: 00: 18 AM ( BP EXPLORATION Operations Summary Report Page 6 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y -23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1 0/29/2003 10:00 - 00:00 14.00 DRILL P INT1 String Weight Rotating 185,000# - ART = 7.62 hrs. - AST = 2.02 hrs. 1 0/30/2003 00:00 - 01:45 1.75 DRILL P INT1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 10,819' To Casing Point At 11,916' - WOB Rotating 15,000# - 20,000#, WOB Sliding 10,000# To 15,000#, RPM 90, Motor RPM 156, Torque Off Bottom 13,000 ft /Ibs - On Bottom 15,000 ft /Ibs, Pump Rate 537 gpm, SPP Off Bottom 3,830 psi, On Bottom 4,030 psi. String Weight Up 235,000#, String Weight Down 150,000#, String Weight Rotating 185,000# - ART = 1.17 hrs. 01:45 - 03:15 1.50 DRILL P INT1 Circulate Sweep Around And Formation Sample At 12.5 BPM With 3,830 Psi. While Rotating And Reciprocating Drill String - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive 03:15 - 05:30 2.25 DRILL P INT1 POH With Directional BHA No.4 From 11,916' To 6,882' With No Problems - Monitor Well Bore (Static) 05:30 - 06:30 1.00 DRILL P INT1 Slip And Cut 85 Feet Of 1 1/4" Drilling Line 06:30 - 07:00 0.50 DRILL P INT1 Service Top Drive, Traveling Blocks, And Crown Sheaves 07:00 - 08:30 1.50 DRILL P INT1 RIH With BHA No.4 From 6,882' To 11,916' With No Problems As Precaution Wash Last Stand To Bottom From 11,846' To 11,916' 08:30 - 11 :00 2.50 DRILL P INT1 Circulate Sweep Around At 13.0 BPM With 3,820 Psi. While Rotating And Reciprocating Drill String - Monitor Well Bore (Static) - Spot Liner Running Pill - Pump Dry Job - Drop 2.25 Drift 11 :00 - 14:00 3.00 DRILL P INT1 POH Standing Back 4" Drill Pipe In Mast With BHA No.4 From 11,916' To 6,898' With No Problems - Monitor Well Bore (Static) 14:00 - 16:30 2.50 DRILL P INT1 Change Out Handling Equipment For 5" Drill Pipe - POH Standing Back 5" Drill Pipe In Mast With BHA No.4 From 6,898' To 1,178' 16:30 - 20:30 4.00 DRILL P INT1 POH Laying Down Directional BHA No.4 From 1,178' - Retrieve Drift And Lay Down Cross Over Sub, (23) Joints 5" HWDP, Daily Drilling Jars, (9) Steel Drill Collars, (3) Flex Drill Collars - Flush Out BHA With Fresh Water - Down Load Sperry Sun MWD/LWD Tools - Lay Down Hang Off Collars, MWD/LWD Tools, Float Sub, And String Stabilizer - Remove Hughes HCM 8 1/2" PDC Bit And Lay Down Sperry Sun Mud Motor - Clear Rig Floor 20:30 - 23:00 2.50 BOPSUR P INT1 Change Out 31/2" By 6" Variable Pipe Rams In Top BOP Gate To 7" Ram Blocks - Pull Wear Bushing And Install Test Plug - Rig Up Testing Equipment - Test 7" Ram Blocks To 250 Psi. Low And 3,500 Psi. High (Good Test) - Rig Down Testing Equipment And Pull Test Plug - Install Wear Bushing And Energize Lock Down Studs 23:00 - 00:00 1.00 CASE P INT1 Rig Up Power Tongs - Casing Tools And Equipment 1 0/31/2003 00:00 - 00:30 0.50 CASE P INT1 Hold Pre-Job Safety Meeting - Check Out Equipment And Tools 00:30 - 08:00 7.50 CASE P INT1 Pick Up And RIH With Shoe Track - Baker Lock Connections To Insert Landing Collar Joint NO.3 - Verify Floats Holding - RIH With 124 joints of 7" BTC-M 26 lb. L-80 Casing to 5107' - Make Up To Mark Torqued To 8,200 ftllbs. 08:00 - 08:30 0.50 CASE P INT1 Change Out Handling Equipment To 5" DP Elevators - M / U Printed: 11/12/2003 11:00:18 AM { ( BP EXPLORATION Operations Summary Report Page 7 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y -23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1 0/31 /2003 08:00 - 08:30 0.50 CASE P INT1 Baker Flex Lock Liner Hanger, ZXP Packer, Liner Tie Back Sleeve, And Running Tool - Change Out Handling Equipment And Pick Up Cross Over (2) 4" Drill Pipe Pup Joints From 5,107' To 5,165' - 7" Liner Weight At 115,000# 08:30 - 09:00 0.50 CASE C INT1 Pick Up 4" HT-40 Drill Pipe From Pipe Shed And RIH With Liner From 5,165' To 5,475'. Pushing Fluid Away 09:00 - 10:00 1.00 CASE C INT1 Monitor Well - Break Circulation At 1 BPM With 180 psi - Losses At 3 BPM 10:00-11:30 1.50 CASE C INT1 Pick Up Drill Pipe Singles And RIH Slow From 5,475' to 6,196' Still Pushing Fluid Away Keep Backside Full 11:30-13:30 2.00 CASE C INT1 Monitor Well - Change Out Flow Riser Air-Boot 13:30 - 15:00 1.50 CASE C INT1 RIH With 7" Liner From 6,196' To 6,920' (Top Of Whipstock Window) Up Weight 160,000#, Down Weight 120,000# 15:00 - 15:30 0.50 CASE C INT1 Circulate @ 2 BPM. Establish loss rate of 1 BPM. 15:30 - 17:30 2.00 CASE P INT1 RIH Thru Open Hole Section With 7" BTC-M 26 lb. L-80 Liner On 4" Drill Pipe From 6,920' To 11,890' 17:30 - 18:00 0.50 CASE P INT1 Pick Up Baker Cement Head - Install Manifold And Circulating Lines - Establish Circulation At 1 BPM With 320 Psi And Full Returns - Wash To Bottom At 11,916' 18:00-19:15 1.25 CASE P INT1 Stage Up Pumping Rates From 3.5 BPM With 800 Psi. To 5.0 BPM With 1,311 Psi. At Higher Rate, Losing Partial Returns - Reduce Rate To 3.5 BPM With Full Returns 19:15 - 21:30 2,25 CEMT P INT1 Held PJSM With All Personal Regarding Cementing Operation - Shut Down And Turn Over To Dowell - Pump 5 BBLS Water - Test Surface Lines And Equipment To 4,500 Psi. (Test Good) - Clear Lines With Mud Push Prior To Going Down Hole - Pump 25 BBLS 12.0 PPG Mud Push, Followed With 35 BBLS (169 Sacks) 15.8 PPG Class "G" Tail Cement At 5.0 BPM - Wash Up Lines To Floor - Drop Dart And Displace With 11.5 PPG LSND Mud At 5.6 BPM With 910 Psi. - Slow Rate And Latch Liner Wiper Plug With 65.7 BBLS Pumped Away - Increase Rate To 5.7 BPM Continue To Displace. As Cement Rounded The Shoe, Lost Returns Slow Rate To 2.4 BPM With Final Circulating Pressure At 602 Psi. - Bump Plug With A Total Of 259.7 BBLS Pumped Increase Pressure To 3,500 Psi. To Set Baker Liner Hanger - Bleed Off Pressure And Check Floats (Floats Held) - Cement In Place At 20:26 Hours - Rotate 15 Turns To The Right And Release From Liner - Pressure Up Down Drill Pipe To 1,000 Psi. - Pick Up To Release Pack Off From Seals And Expose Running Tool Dogs As Pressure Decreases Ramp Up Pumps To Maximum Rate At 10 BPM With 2,830 Psi. And Circulate Fluids Above Liner Top Up Hole 30 BBLS - Reduce Pump Rate To 6.4 BPM With 1,379 Psi. Slack Off String With 70,000 Ibs. To Set Baker ZXP Packer Rotate And Repeat Process Several Times (Clear Surface Indication That Packer Set) - Increase Pump Rate At 12.1 BPM With 3,550 Psi.And Continue To Circulate Bottoms Up No Cement Back To Surface As Planned - Top Of Liner At 6,780', Insert Landing Collar At 11,830', Float Collar At 11,871', Float Shoe At 11,915' 21 :30 - 22:00 0.50 CASE P INT1 Pump Dry Job - Break Down Cement Circulating Lines And Lay Down Baker Cementing Head 22:00 - 00:00 2.00 CASE P INT1 POH With Baker 7" Liner Running Tool From 6,780' -Inspect Printed: 11/12/2003 11:00:18AM { ( BP EXPLORATION Operations Summary Report Page 8 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y -23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1 0/31/2003 22:00 - 00:00 2.00 CASE P INT1 Running Tool Brass Pins Were Sheared Indicating That The ZXP Packer Did Set - Lay Down Running Tool And Clear Rig Floor 11/1/2003 00:00 - 00:30 0.50 CASE P PROD1 Clear Rig Floor Of Cross Over Subs And 7" Liner Running Tools And Equipment 00:30 - 01 :30 1.00 BOPSURP PROD1 Remove Wear Bushing - Install Test Plug 01 :30 - 02:30 1.00 BOPSUR P PROD1 Change Out 7" Pipe Rams In Top BOP Gate To 3 1/2" By 6" Variables 02:30 - 06:30 4.00 BOPSURP PROD1 Rig Up Testing Equipment - Test BOP And Related Equipment With 4" And 5" Test Joints And Floor Valves - Witness Of BOP Test Waived By AOGCC Inspector Chuck Sheave - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test 06:30 - 07:30 1.00 BOPSUR P PROD1 Held PJSM - Test 9 5/8" Casing x 7" Liner At 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) 07:30 - 10:00 2.50 DRILL P PROD1 Held PJSM - Make Up BHA NO.5 - Pick Up Sperry Sun Motor, Make Up 61/8" Security 2643 PDC Bit, Pick Up MWD/LWD Tools - Orient And Initialize MWD/LWD Tools - Pick Up (1) Flex Drill Collar - Surface Test Sperry Sun Equipment. Pick Up (2) Flex Drill Collars, Daily Mechanical Jars, Circulating Sub, And Cross Over Sub To 362' 10:00 - 13:00 3.00 DRILL P PROD1 Held PJSM - RIH With Directional Drilling Assembly BHA NO.5 Picking Up (96 Joints) 4" Drill Pipe Out Of Pipe Shed From 362' To 3,314' 13:00 - 15:30 2.50 DRILL P PROD1 Held PJSM - RIH With BHA NO.5 From 3,314' To 10,638' Filling Drill String Every 3000' 15:30 - 16:00 0.50 DRILL P PROD1 Held PJSM - Service Top Drive, Traveling Blocks, And Crown Sheaves 16:00 - 17:00 1.00 DRILL P PROD1 Cut And Slip 66 Feet Of 1 1/4" Drilling Line 17:00 - 18:00 1.00 DRILL P PROD1 Change Out Saver Sub On Can-Rig Top Drive From 4" (HT-40) Connection To 5" (4 1/2 IF) Connection 18:00 - 18:30 0.50 DRILL P PROD1 RIH With BHA NO.5 From 10,638' To 11,831' 18:30 - 19:00 0.50 DRILL P PROD1 Tag Baker Liner Wiper Plug And Insert Landing Collar At 11,831' - Drill Landing Collar And Wiper Plugs - Cement To Float Collar At 11,872' - Cement To 11,910' - WOB 2,000#, Motor RPM 180, Torque On Bottom 10,000 ft /Ibs - Pump Rate 233 gpm, SPP Off Bottom 2,180 psi, On Bottom 2,260 psi. String Weight Up 205,000#, String Weight Down 130,000#, String Weight Rotating 160,000# 19:00 - 22:30 3.50 DRILL P PROD1 Held PJSM - Change Over Mud System From 11.5 ppg LSND To 8.4 ppg. Flo-Pro - Pump 75 BBLS Spacer, 100 BBLS Water, 40 BBLS "EP Mud Lube" Spacer, 75 BBLS Spacer, Followed Up With 710 BBLS 8.4 PPG Flo-Pro Mud At 7 BPM, 1870 psi - Shut Down And Clean Under Shakers 22:30 - 23:00 0.50 DRILL P PROD1 Drill Cement, Float Shoe, And New 61/8" Hole From 11,910' To 11,935' - Pull Into Casing 23:00 - 23:30 0.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Preform FIT To 9.6 PPG EMW Closed Top Pipe Rams And Performed FIT. Strokes Pmp'd Pressure Printed: 11/12/2003 11: 00: 18 AM ( BP EXPLORATION Operations Summary Report Held Test F/1 0 minutes wi 40 Psi. Pressure Loss. MW 8.4 ppg, 7" Casing Shoe TVD 8,877' Pressure 560 psi = 9.61 PPG. EMW. Bleed Pressure To 0 Psi. - Open Top Pipe Rams PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 11,935' To 11,948' WOB Rotating 2,000# - 11,000#, WOB Sliding 2,000# To 8,000#, RPM 60, Motor RPM 224, Torque Off Bottom 4,000 ft I Ibs - On Bottom 6,000 ft /Ibs, Pump Rate 291 gpm, SPP Off Bottom 2,060 psi, On Bottom 2,190 psi. String Weight Up 190,000#, String Weight Down 150,000#, String Weight Rotating 170,000# - ART = .31 hrs. - AST = .32 hrs. PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 11,948'To 12,227' WOB Rotating 10,000#-15,000#, WOB Sliding 10,000# To 15,000#, RPM 60, Motor RPM 228, Torque Off Bottom 5,000 ft I Ibs - On Bottom 6,000 ft I Ibs, Pump Rate 297 9pm, SPP Off Bottom 2,240 psi, On Bottom 2,400 psi. String Weight Up 190,000#, String Weight Down 150,000#, String Weight Rotating 175,000# - ART = .81 hrs. - AST = 8.73 hrs. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y -23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 11/1/2003 23:00 - 23:30 0.50 DRILL P PROD1 23:30 - 00:00 0,50 DRILL P 11/2/2003 00:00 - 16:00 16.00 DRILL P 16:00 - 16:30 0.50 DRILL P PROD1 16:30 - 17:00 0.50 DRILL P PROD1 17:00 - 20:00 3.00 DRILL P PROD1 20:00 - 21 :00 1.00 DRILL P PROD1 21 :00 - 22:00 1.00 DRILL P PROD1 22:00 - 00:00 2.00 DRILL P PROD1 11/3/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Page 9 of 17 Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Description of Operations 2 6 10 12 18 22 55 psi 155 psi 260 psi 310 psi 460 psi 560 psi Lithology: 12000-12100: LS; (Shublik) white-light gray, micro to crypto-crystalline, dense, slightly shaly to silty 12100-12227 SS: (Zone 4B) very fine to medium grained, medium sorted, friable to unconsolidated, subrounded to subangular, weak silica cement. Some pyrite cement near top. Light brown oil stain with fair to good cuts. Monitor Well Bore (Static) - While Mixing Dry Job POH With Directional BHA NO.5 From 12,227' To 11,384' With No Problems Drop Dart And Open Circulation Sub - Remove Blower Hose - Monitor Well Bore (Static) - Pump Dry Job And Blow Down Surface Equipment POH With Directional BHA No.5 From 11,384' To 2,380' POH With Directional BHA No.5 Laying Down 66 joints of 4" Drill Pipe Singles From 2,380' To 362' POH With Directional BHA No.5 - Stand Back 3 1/2" HWDP, Change Out Circulation Sub, Make Up DaiJey DNT Jars. Download MWDILWD tools. LID Sperry 1.5 degree motor. Held PJSM - Make Up BHA NO.6 - Pick Up Sperry Sun Motor, Make Up 61/8" Hughes Insert Bit, Pick Up MWDILWD Tools- Orient And Initialize MWDILWD Tools. Continue Make Up BHA NO.6 - Pick Up (3) Flex Drill Collars - Printed: 11/12/2003 11: 00: 1 B AM ~, ( BP EXPLORATION Operations Summary Report Page 10 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y -23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/312003 00:00 - 01 :00 1.00 DRILL P PROD1 Surface Test Sperry Sun Equipment. Pick Up Daily Mechanical Jars, Circulating Sub, And Cross Over Sub To 362' 01 :00 - 05:00 4.00 DRILL P PROD1 Held PJSM - RIH With Directional Drilling Assembly BHA No.6 From 362' To 11,862' 05:00 - 06:00 1.00 DRILL P PROD1 Hook up Top Drive Blower hose. RIH With BHA NO.6 From 11,862' To 12,144', filling pipe every 3,000'. As Precaution Wash Last Stand To Bottom From 12,144' To 12,227' 06:00 - 12:00 6.00 DRILL P PROD1 Directional Drill from 12,227' to 12,428'. Up Weight - 205K, Down Weight - 155K, Rotating Weight - 180K, Off-Bottom Torque - 5/7, On-Bottom Torque - 7/9. AST - 2.4, ART - 0.71 12:00 -14:15 2.25 DRILL P PROD1 Directional Drill from 12,428' to 12,536'. Crossed fault and lost returns. Up Weight - 21 OK, Down Weight - 150K, Rotating Weight - 180K, Off-Bottom Torque - 6/7, On-Bottom Torque - 7/8. AST - 0.83, ART - 1.14 14:15 - 19:30 5.25 DRILL N DPRB PROD1 Monitor well. Static loss rate - 54 bbl/hr - lost 75 bbls. Mix and pump Pill #1 @ 4bpm and let soak. Monitor well. Static loss rate - 52 bbl/hr. Drill from 12,536' to 12,595'. Mix and pump Pill #2 @ 4bpm and let soak. Monitor well. Static loss rate - 56 bbl/hr. Drill from 12,595' to 12,617', Mix and pump Pill #3 @ 4bpm and let soak. Pill #1: 20 bbls of 20# per bbl CaC03 Pill #2: 40 bbls of 20# per bbl CaC03 Pill #3: 40 bbls of 20# per bbl CaC03, 5# per bbl MIX II Fine 19:30 - 00:00 4.50 DRILL N DPRB PROD1 Monitor well. Static loss rate - 52 bbl/hr. POOH from 12,617' to 11,857'. Static loss rate - 86 bbl/hr. Drop Dart and open Circ Sub. Mix and pump Pill #4 @ 5bpm. Static loss rate - 8 bbl/hr. Squeeze away 6 bbls @ 2bbl/min, 60 psi. Monitor Static loss rate - 25 bbl/hr. Pill #4: 50 bbls of 15# per bbl MIX II, 5# per bbl SafeCarb, 12# per bbl Nut Plug, 20# per bbl MI Seal Medium. Total Daily Losses - 1100 bbls 11/4/2003 00:00 - 02:30 2.50 DRILL N DPRB PROD1 Monitor Well - Static Loss Rate At 8 bblslhr Increased To 60 bbls/hr. Prepare LCM Pill NO.5 54 Barrel LCM Pill At 80 PPB Consisted Of The Following Additives: 26 PPB Nut Plug Coarse 31 PPB MI Seal Medimum 10 PPB MI Seal Fine 6 PPB MI Seal Coarse 7 PPB Mix II 02:30 - 04:00 1.50 DRILL N DPRB PROD1 Start Pumping LCM Pill NO.5 And Spot In Place - Plugged Off The Suction And Discharge Headers To The Pumps. Clean Out Suction And Discharge Headers. 04:00 - 04:45 0.75 DRILL N DPRB PROD1 Restart Pumping LCM Pill NO.5 - Displace At 5.8 bpm - 950 psi 04:45 - 06:00 1.25 DRILL N DPRB PROD1 POH From 11,862' To 10,929' - Monitor Well Static Losses At 42 bbls/hr 06:00 - 09:00 3.00 DRILL N DPRB PROD1 Monitor Well - Static Loss Rate 6 bblslhr Increased To 60 bbls/hr. Prepare LCM Pill NO.6 Printed: 11/12/2003 11:00:18AM (, ( BP EXPLORATION Operations Summary Report Page 11 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y -23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Descri ption of Operations 11/4/2003 06:00 - 09:00 3.00 DRILL N DPRB PROD1 100 Barrel LCM Pill At 100 PPB Consisted Of The Following Additives: 25 PPB Nut Plug Coarse 30 PPB MI Seal Medimum 20 PPB MI Seal Fine 15 PPB MI Seal Coarse 10 PPB Mix II 09:00 - 09:30 0.50 DRILL N DPRB PROD1 RIH From 10,929' To 11,862' 09:30 - 10:00 0.50 DRILL N DPRB PROD1 Pump LCM Pill NO.6 - Displace At 5.25 bpm - 900 psi 10:00 - 13:30 3.50 DRILL N DPRB PROD1 Monitor Well - Static Loss Rate 62 bbls/hr Increased To 78 bbls/hr. Prepare LCM Pill NO.7 100 Barrel LCM Pill At 100 PPB Consisted Of The Following Additives: 25 PPB Nut Plug Coarse 30 PPB MI Seal Medimum 20 PPB MI Seal Fine 15 PPB MI Seal Coarse 10 PPB Mix II 13:30 - 15:30 2.00 DRILL N DPRB PROD1 Pump LCM Pill NO.7 - Displace At 3 bpm - 240 psi With No Returns 15:30 - 20:00 4,50 DRILL N DPRB PROD1 Monitor Well - Static Loss Rate At 82 bbls/hr. Prepare LCM Pill NO.8 100 Barrel LCM Pill At 54 PPB Consisted Of The Following Additives: 5 PPB Nut Plug Coarse 10 PPB MI Seal Medimum 10 PPB MI Seal Fine 5 PPB MI Seal Coarse 4 PPB Mix II 10 PPB Safe Carb 20 10 PPB Safe Carb 40 20:00 - 20:30 0.50 DRILL N DPRB PROD1 Attempt To Pump Down Drill String (No Good) Drill String Plugged 20:30 - 00:00 3.50 DRILL N DPRB PROD1 POH "Wet" With BHA NO.6 From 11,862' To 8,538' - Change Out Handling Tools To 4" Drill Pipe - POH From 8,538' To 5,789' 11/5/2003 00:00 - 03:00 3.00 DRILL N DPRB PROD1 POH "Wet" With BHA No.6 From 5,789' To 362' 03:00 - 06:00 3.00 DRILL N DPRB PROD1 POH Laying Down Directional BHA No.6 From 362' - Lay Down (2) 3 1/2" HWDP (One Plugged With LCM) - Rebuild Circulation Sub - Lay Down Daily Drilling Jars, (3) Flex Drill Collars - Attempt To Pump Thru And Flush Out BHA Below Circ. Sub With Fresh Water No Good, Drain Motor And Remove Hughes STX-20GD 61/8" Bit - Down Load Sperry Sun MWD/LWD Tools - Lay Down Hang Off Collars, MWD/LWD Tools, Float Sub, Sperry Sun Mud Motor - Clear Rig Floor - Wash Off Rig Floor And Clear Same Printed: 11/12/2003 11 :00: 18 AM ( ( BP EXPLORATION Operations Summary Report Page 12 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y -23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/5/2003 03:00 - 06:00 3.00 DRILL N DPRB PROD1 *NOTE* Monitor Well - Static Loss Rate At 108 bbls/hr 06:00 - 07:30 1.50 DRILL N DPRB PROD1 Make Up BHA NO.7 - Pick Up (1) Steel Drill Collar, Make Up String Stabilizer, Cross Over, Pup Joint, Cross Over, Bit Sub, And 6 1/8" Mill Tooth Bit And RIH - Pick Up (2) Steel Drill Collars, String Stabilizer - RIH With Dailey Jars, 3 1/2" HWDP From Mast To 299' 07:30 - 15:00 7.50 DRILL N DPRB PROD1 RIH With BHA NO.7 From 299' To 8,517' - Change Out Handling Tools To 5" Drill Pipe - RIH From 8,517' To 11,915' - As A Precaution Break Circulation Every 10 Stands While Running In Hole 15:00 - 15:30 0.50 DRILL N DPRB PROD1 Monitor Well Bore Static Losses At 74 BPH 15:30 - 17:30 2.00 DRILL N DPRB PROD1 Wash And Ream Stiff BHA Thru Open Hole Section From 11,915' To 12,617'. Established Partial Returns At 12520' To 12617' 17:30 - 18:00 0.50 DRILL N DPRB PROD1 Circulate 2 Open Hole Annular Volumes At 3 BPM With 430 Psi. 18:00 - 18:30 0.50 DRILL N DPRB PROD1 POH From 12,617' To 12,452' - Make Up Head Pin, Full Opening Floor Valve, Pup Joint, And Circulating Lines 18:30 - 20:00 1.50 DRILL N DPRB PROD1 Held PJSM With All Personal Regarding MI Form-A-Plug Setting Operation - Shut Down And Turn Over To Dowell- Pump 5 BBLS Water - Test Surface Lines And Equipment To 3,500 Psi. (Test Good) - Pump 10 BBLS Hi-Vis Spacer, 60 BBLS 10.5 PPG Form-A-Plug Pill - Close Annular And Monitor Backside Pressure Thru Choke Gauges Bull Head Following Fluids Second 10 BBLS Hi-Vis Spacer, 142 BBLS Mud MUD Pumped Rate Pressure 100 BBLS 4BPM 220 PSI 107 BBLS 3BPM 210 PSI 122 BBLS 2BPM 210 PSI 136 BBLS 1BPM 120 PSI 142 BBLS Final 100 PSI Pressure Bled Off To 60 PSI In 2 Minutes - Shut Down Bleed Off Pressure Open Annular 20:00 - 20:30 0.50 DRILL N DPRB PROD1 Remove Circulating Lines, Head Pin, Full Opening Floor Valve, Pup Joint - Connect Top Drive And POH With Stand While Pumping Remaining 10 BBLS Form-A-Plug Out Of Drill String - POH From 12,452' To 11,888' - Circulate Additional 10 BBLS Fluid At 2 BPM To Clean Up Drill Pipe - Blow Down Top Drive - *NOTE* Fluid Level Fellin Stack To Top Of Annular 13 Feet Below Rotary Table In 5 Minutes - Form-A-Plug In Place At 20:40 Hours 20:30 - 00:00 3.50 DRILL N DPRB PROD1 Shut In Well Bore To Allow MI Form-A-Plug To Set Up 11/6/2003 00:00 - 03:00 3.00 DRILL N DPRB PROD1 Allow MI Form-A-Plug To Set Up - Cut Drilling Line - Service Top Drive, Traveling Blocks, Crown Sheaves - Clean Out Suction And Discharge Manifolds On Mud Pumps 03:00 - 04:00 1.00 DRILL N DPRB PROD1 Open Annular Element - Pump Down Drill String Fill Hole With 125 Barrels - Monitor Well Bore Static Losses At 82 To 90 BPH 04:00 - 05:30 1.50 DRILL N DPRB PROD1 Wash And Ream Thru Open Hole Section From 11,915' To 12,617' Printed: 11/12/2003 11 :00:1 B AM (' ( BP EXPLORATION Operations Summary Report Page 13 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y -23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/6/2003 05:30 - 06:00 0.50 DRILL N DPRB PROD1 POH With BHA No.7 From 12,617' To 11,888' With No Problems 06:00 - 07:00 1.00 DRILL N DPRB PROD1 Monitor Well Bore Static Losses At 87 BPH 07:00 - 11 :30 4.50 DRILL N DPRB PROD1 POH With BHA NO.7 From 11,888' To 8,538' - Change Out Handling Tools To 4" Drill Pipe - POH From 8,538' To 299' 11 :30 - 13:30 2.00 DRILL N DPRB PROD1 Handle BHA NO.7 - Stand Back In Mast (5) 31/2" HWDP, Dailey Jars - Lay Down (3) Steel Drill Collar, (2) String Stabilizers, (2) Cross Overs, Pup Joint, Bit Sub, And 6 1/8" Hughes Mill Tooth Bit - Clear Rig Floor 13:30 - 15:30 2.00 DRILL N DPRB PROD1 Make Up BHA NO.8 - Pick Up Sperry Sun Motor, Make Up 6 1/8" Security FM2643 Bit, Pick Up Float Sub, MWD/LWD Tools - Orient And Initialize MWD/LWD Tools - Pick Up (3) Flex Drill Collars - Surface Test Sperry Sun Equipment - RIH From Mast With Daily DNT Jars, Circulating Sub, 3 1/2" HWDP, And Cross Over Sub To 363' 15:30 - 17:00 1.50 DRILL N DPRB PROD1 Pick Up Singles From Pipe Shed And RIH With Directional Drilling Assembly BHA No.8 From 363' To 2,418' 17:00 - 20:30 3.50 DRILL N DPRB PROD1 RIH With Directional Drilling Assembly BHA No.8 From 2,418' To 11,862' - Fill Drill String Every 3,000 Feet 20:30 - 21 :00 0.50 DRILL N DPRB PROD1 Install Top Drive Blower Hose - RIH With BHA No.8 From 11,862' To 12,550' - Take Survey At 12,550' - As Precaution Wash Last Stand To Bottom From 12,550' To 12,617' 21 :00 - 00:00 3.00 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 12,617' To 12,770' WOB Rotating 2,000# - 5,000#, WOB Sliding 5,000# To 15,000#, RPM 90, Motor RPM 212, Torque Off Bottom 12,000 ft / Ibs - On Bottom 12,000 ft / Ibs, Pump Rate 275 gpm, SPP Off Bottom 1,380 psi, On Bottom 1,510 psi. String Weight Up 245,000#, String Weight Down 135,000#, String Weight Rotating 175,000# - ART = .75 hrs. - AST = .46 hrs. 11/7/2003 00:00 - 06:00 6.00 DRILL P PROD1 Drill 6 1/8" Directional Hole By Rotating And Sliding From 12,770' To 13,170' WOB Rotating 2,000# - 5,000#, WOB Sliding 5,000# To 15,000#, RPM 90, Motor RPM 212, Torque Off Bottom 12,000 ft / Ibs - On Bottom 12,000 ft /Ibs, Pump Rate 275 gpm, SPP Off Bottom 1,380 psi, On Bottom 1,510 psi. String Weight Up 245,000#, String Weight Down 135,000#, String Weight Rotating 175,000# - ART = 1.24 hrs. - AST = 2.14 hrs. *NOTE* Average Losses While Drilling At 300 Barrels Per Hour 06:00 - 07:00 1.00 DRILL P PROD1 Wiper Trip From 13,169' To 12,515' With No Problems 07:00 - 23:00 16.00 DRILL P PROD1 Drill 6 1/8" Directional Hole By Rotating And Sliding From 13,170' To 14,200' WOB Rotating 5,000# - 10,000#, WOB Sliding 5,000# To 15,000#, RPM 90 To 115, Motor RPM 212, Torque Off Bottom 12,000 ft / Ibs - On Bottom 13,000 ft / Ibs, Pump Rate 275 gpm, SPP Off Bottom 1,770 psi, On Bottom 2,150 psi. String Weight Up 230,000#, String Weight Down 135,000#, String Weight Rotating 186,000# - ART = 6.34 hrs. - AST = 3.42 hrs. 23:00 - 23:30 0.50 DRILL P PROD1 Circulate Spot Lube Tex And Glass Beads In Open Hole Section 23:30 - 00:00 0.50 DRILL P PROD1 POH Wiper Trip From 14,200' To 13,169' 11/8/2003 00:00 - 01 :00 1.00 DRILL P PROD1 POH Wiper Trip From 14,200' To 13,169' - Had 20K To 25K Printed: 11/12/2003 11: 00: 18 AM ( ( BP EXPLORATION Operations Summary Report Page 14 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y -23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/8/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Over Pull From 13,411' To 13,371'· RIH From 13,169' To 14,200' With No Problems 01 :00 - 10:30 9.50 DRILL P PROD1 Drill 6 1/8" Directional Hole By Rotating And Sliding From 14,200' To 14,955' (Drilled Into Fault At 14,950' ) - WOB Rotating 5,000# - 10,000#, WOB Sliding 5,000# To 15,000#, RPM 90 To 115, Motor RPM 212, Torque Off Bottom 12,000 ft 1 Ibs - On Bottom 13,000 ft 1 Ibs, Pump Rate 275 gpm, SPP Off Bottom 1,800 psi, On Bottom 2,000 psi. String Weight Up 230,000#, String Weight Down 135,000#, String Weight Rotating 186,000# - ART = 3.97 hrs. - AST = 1.70 hrs. 10:30 - 11 :00 0.50 DRILL P PROD1 Attempt To Regain Circulation At 14,890' While Rotating And Reciprocating Drill String (No Good) 11 :00 - 12:30 1.50 DRILL P PROD1 POH From 14,890' To 11,855' With Both Rig Pumps Keeping Backside Full 12:30 - 13:30 1.00 DRILL P PROD1 Establish Static Loss Rate At 600 Barrels Per Hour 13:30 - 15:00 1.50 DRILL P PROD1 RIH From 11,855' To 14,955' With No Problems (5 Feet Fill On Bottom) 15:00 - 18:00 3.00 DRILL P PROD1 POH Laying Down 5" Drill Pipe From 14,955' To 10,639' 18:00 - 21 :30 3.50 DRILL P PROD1 POH With Directional BHA No.8 From 10,639' To 10,272' - Change Out Handling Tools To 4" Drill Pipe - POH From 10,272' To 366' 21 :30 - 23:30 2.00 DRILL P PROD1 POH Laying Down Directional BHA No.8 From 366' - Lay Down Cross Over Sub, (5) Joints 3 1/2" HWDP, Circ. Sub, Dailey Jars, (3) Flex Drill Collars - Down Load Sperry Sun MWD/LWD Tools - Lay Down Hang Off Collars, MWDILWD Tools, Float Sub, Remove Security 61/8" FM 2643 Bit And Lay Down Mud Motor - Clear Rig Floor 23:30 - 00:00 0,50 CASE P COMP Rig Up Casing Tools And Equipment For 4 1/2" Production Liner *NOTE* BOP Test Was Waived By The AOGCC Representive Lou Grimauldi Due To Severe Losses To Well Bore 11/9/2003 00:00 - 01 :00 1,00 CASE P COMP Rig Up Casing Tools And Equipment For 4 1/2" Production Liner 01 :00 - 01 :30 0.50 CASE P COMP Hold Pre-Job Safety Meeting Regarding Liner Running Operation 01 :30 - 05:00 3.50 CASE P COMP Pick Up And RIH With Shoe Track - Baker Lock Connections To Landing Collar Joint NO.3 - Verify Floats Holding - RIH With 77 Joints Of 41/2" BTC-M 12.6 lb. L-80 Casing, Baker HMCV With Pup Joints, Joint NO.78 To 3,235' - Make Up To Mark Torqued To 3,800 ftJlbs. 05:00 - 05:15 0.25 CASE P COMP Change Out Handling Equipment To 31/2" DP Elevators - M 1 U Baker Flex-Lock Liner Hanger, ZXP Packer, Liner Tie Back Sleeve, And Running Tool - Change Out Handling Equipment To 4" P / U Cross Over, (1) 4" Drill Pipe Pup Joint To 3,286' Liner Weight When Full At 32,000 Lbs. 05:15 - 11 :00 5.75 CASE P COMP RIH With 78 Joints Of 4 1/2" BTC-M 12.6 lb. L-80 Liner On 4" And 5" Drill Pipe From 3,286' Tag Bottom At 14,955' - Place 4 1/2" Liner Float Shoe 5 Feet Off Bottom At 14,950' - While Running In The Hole Fill Drill Pipe On The Fly And Top Off Every 10 Stands 11 :00 - 12:30 1.50 CASE P COMP Held PJSM With All Personal Regarding Packer Setting Printed: 11/12/2003 11: 00: 18 AM ( ( BP EXPLORATION Operations Summary Report Page 15 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y -23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/9/2003 11 :00 - 12:30 1.50 CASE P COMP Operation - Drop Drill Pipe Wiper Plug - Displace With Sea Water At 5.0 BPM With 600 Psi. - Slow Rate And Latch Liner Wiper Plug With 126 BBLS Pumped Away - Increase Rate To 5.0 BPM Continue To Displace - Slow Rate To 3.0 BPM With Final Circulating Pressure At 250 Psi. - Bump Plug With A Total Of 174 BBLS Pumped - Increase Pressure To 900 Psi. To Set Baker Flex Lock Liner Hanger - Bleed Off Pressure - Rotate 20 Turns To The Right And Release From Liner - Pressure Up Down Drill Pipe To 500 Psi. - Pick Up To Release Pack Off From Seals And Expose Running Tool Dogs Slack Off String With 75,000 Ibs. To Set Baker ZXP Packer Rotate And Repeat Process Several Times (Good Clear Surface Indication That Liner Top Packer Set) - Top Of 4 1/2" Liner At 11,686', Landing Collar At 14,862', Float Collar At 14,904', Float Shoe At 14,948' 12:30 - 13:00 0.50 CASE P COMP Monitor Well Bore Static - Blow Down Surface Equipment 13:00 - 15:30 2.50 CASE P COMP POH With Baker 4 1/2" Liner Running Tool From 11,686' To 6,566' 15:30 -16:30 1.00 CASE P COMP Slip And Cut 102 Feet Of 1 1/4" Drilling Line 16:30 -17:00 0.50 CASE P COMP Service Top Drive, Traveling Blocks, And Crown Sheaves 17:00 - 18:30 1,50 CASE P COMP POH With Baker 4 1/2" Liner Running Tool From 6,566' To 45' 18:30 - 19:30 1.00 CASE P COMP Running Tool Brass Pins Were Sheared Indicating That The ZXP Top Packer Did Set - Service Baker Running Tool Break Out Rotating Dog Sub And Lay Down - Clear Rig Floor 19:30 - 21 :00 1.50 CASE P COMP Hold Pre-Job Safety Meeting - Rig Up And Make Up Baker HMCV Shifting Tool Assembly With 2 7/8" Fox Space Out Tubing And Pup Joints - Make Up Rotating Dog Sub, 4" Pup Joint, And Cross Overs To 122' 21 :00 - 00:00 3.00 CASE P COMP RIH With Baker HMCV Shifting Tool Assembly On 4" Drill Pipe From 122' To 9,180' 11/10/2003 00:00 - 02:30 2.50 CASE P COMP RIH With Baker HMCV Shifting Tool Assembly On 4" Drill Pipe From 9,180' To 7" X 4 1/2" Liner Top Tie Back Sleeve At 11,686' - String Up Weight At 188,000# And Down Weight At 155,000# 02:30 - 03:00 0.50 CEMT P COMP Hold Pre-Job Safety Meeting With All Personal Regarding Cementing Operation 03:00 - 05:30 2.50 CEMT P COMP Shut Down And Turn Over To Dowell - Pump 5 BBLS Water - Test Surface Lines And Equipment To 4,500 Psi. - Test Little Red Hot Oil Lines To 4,000 Psi. (Both Test Good) - Shear Baker HMCV At 1,498 Psi. - Pump 50 BBLS Water Spacer, Followed With 257 BBLS (1243 Sacks) 15.8 PPG Class "G" Tail Cement At 5.6 BPM - Pump 15 BBLS. Water Spacer - Swap Over To Little Red And Displace With 110 BBLS. Diesel At 5.0 BPM With 800 Psi. Caught Cement At 80 BBLs Away - Final Circulating Pressure At 870 Psi. - Pick Up On String Close Baker HMCV And Test To 2,000 Psi. Test Good - Cement In Place At 05:28 Hours - Bleed Drill Pipe To 700 Psi. - Fill Back Side With 22 Barrels 05:30 - 06:00 0.50 CEMT P COMP Close Annular And Reverse Circulate Diesel Out Of Drill String To Cuttings Tank At 6.4 BPM With 1,980 Psi. - 2 BBLS Cement Back To Surface 06:00 - 06:30 0.50 CEMT P COMP Break Down Cement Circulating Lines And Valves - Pick Up And Pull Shifting Tool With Cups Out Of 4 1/2" Liner Printed: 11/12/2003 11: 00: 18 AM « (' BP EXPLORATION Operations Summary Report Page 16 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y-23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 Spud Date: 6/1/1986 End: 11/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/10/2003 06:30 - 08:00 1.50 CASE P COMP Circulate Hi-Vis Sweep At 13 BPM With 2,700 Psi - Pump Dry Job And Blow Down Top Drive 08:00 - 15:30 7.50 CASE P COMP POH Laying Down 5" And 4" Drill Pipe From 11,667' To 153' 15:30 - 17:00 1.50 CASE P COMP Rig Up 2 7/8" Handling Tools And Equipment - Lay Down Cementing Stinger And Baker Shifting Tool - Clear Rig Floor 17:00 - 17:30 0.50 BOPSUR P COMP Rig Up And Pull Wear Bushing 17:30 - 18:30 1.00 EVAL P COMP Test 4 1/2" Liner X 7" Liner X 95/8" Casing At 3,500 Psi. For 30 Minutes Test Good 18:30 - 00:00 5.50 RUNCOMP COMP Hold Pre-Job Safety Meeting Regarding Tubing Running Operation - Run 41/2" Completion - Pick Up Tail Pipe Assembly Baker Lock Connections Below Baker S -3 Packer - RIH With 155 Joints Of 41/2" L-80 12.6 lb. IBT-M Tubing To 6,600' -Torque To 3,800 ftllbs. 11/11/2003 00:00 - 03:45 3.75 RUNCOMP COMP RIH With 277 Joints Of 41/2" L-80 12.6 lb. IBT-M Tubing Torqued At 3,800 ft/lbs. Tagged Bottom Of 4 1/2" Liner Tie Back Sleeve 11,693' 03:45 - 04:30 0.75 RUNCOMP COMP Space Out 4 1/2" Completion String - Lay Down 3 Joints Of 4 1/2" Tubing - Pick Up 2 Space Out Pup Joints - Pick Up Joint NO.275 - Make Up McEvoy Tubing Hanger Up Weight At 145,000 Ibs. Down Weight At 109,000 Ibs. Block Weight At 28,000 Ibs. 04:30 - 05:00 0.50 RUNCOMP COMP With WLEG 3.85 Feet Off Bottom Of Liner Tie Back Sleeve Land McEvoy Tubing Hanger - Run In Lock Down Studs 05:00 - 08:30 3.50 RUNCOMP COMP Test Surface Circulating Lines To 4,000 Psi. Test Good - Reverse Circulate Sea Water And Corrossion Inhibitor At 3 BPM With 180 Psi. 08:30 - 10:00 1.50 RUNCOMP COMP Drop Ball And Rod - Pressure Up On The Tubing To 3500 Psi To Set The Packer - Hold The Pressure For 30 Minutes On Chart Recorder For Tubing Test - Bleed The Pressure To 1500 Psi. - Pressure Annulus To 3500 Psi For 30 Minutes For Packer Test On The Chart Recorder - Bleed Off The Tubing Pressure To Shear The DCR Valve Set At 2500 Psi. 10:00 - 10:30 0.50 WHSUR P COMP Install Two Way Check Valve - Test From Below To 1,000 Psi. (Good Test) 10:30 - 12:30 2.00 BOPSURP COMP Blow Down Surface Lines And Equipment - Nipple Down BOP Stack And Related Equipment 12:30 - 14:30 2.00 WHSUR P COMP Nipple Up Tubing Head Adapter And Production Tree 14:30 - 15:30 1.00 WHSUR P COMP Test Tubing Head Adapter And Tree To 5,000 Psi. (Good Test) 15:30 - 16:30 1.00 WHSUR P COMP Rig Up DSM Lubricator And Pull Two Way Check Valve 16:30 - 17:00 0.50 WHSUR P COMP Rig Up Circulating Lines And Equipment For Pumping Freeze Protection 17:00 - 19:00 2.00 WHSUR P COMP Rig Up Little Red Hot Oil Services - Test Surface Lines At 3,000 Psi. (Test Good) - Reverse Circulate 155 BBLS Diesel Freeze Protection Down Inner Annulus At 3 BPM With 2,250 Psi. 19:00 - 20:00 1.00 WHSUR P COMP U Tube Diesel Into Tubing 20:00 - 21 :00 1.00 WHSUR P COMP Install BPV - Test From Below To 1,000 Psi (Test Good) 21 :00 - 23:00 2.00 WHSUR P COMP Break Down Surface Equipment - Remove Secondary Annulus Valve - Install Tree Cap And Gauges - Secure Well - Clean Lost Circulation Material From Rig Floor Drip Pan Area Printed: 11/12/2003 11: 00: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ( 1', BP EXPLORATION Operations Summary Report Y-23 Y-23B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/18/2003 Rig Release: 11/11/2003 Rig Number: 2 From - To Hours Task Code NPT Phase 11/11/2003 21 :00 - 23:00 2.00 WHSUR P Page 17 of 17 Spud Date: 6/1/1986 End: 11/11/2003 Description of Operations COMP Rig Released From Well Work On Y-23B At 23:00 Hours On 11/11/2003 Printed: 11/12/2003 11: 00: 18 AM 'I' ~ ( BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y-23B REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/28/2003 Rig Release: 12/1/2003 Rig Number: N1 Spud Date: 6/1/1986 End: 12/1/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/28/2003 18:00 - 20:30 2.50 MOB P PRE Rig released from H-04A @ 18:00Hrs on 11/28/2003. Prep to move rig off well. 20:30 - 20:45 0.25 MOB P PRE PJSM, Pull rig off well. Clean up location & conduct post operations pad inspection. 20:45 - 21 :00 0.25 MOB P PRE Held pre-move safety meeting with all personnel. 21 :00 - 22:45 1.75 MOB P PRE Move rig from H-04A to Y-pad. 22:45 - 23:00 0.25 MOB P PRE Conduct pre-operations pad inspection with DSO, Set spill dyke. Flowline is disconnected & BPV is set on Tbg hanger. WHP, lAP & OAP = Opsi. 23:00 - 23: 15 0.25 MOB P PRE PJSM. Review procedure, hazards & mitigation for backing rig over well. 23:15 - 23:30 0.25 MOB P PRE Back rig over well & set down. ACCEPT RIG AT 23:30 HRS ON 11/28/2003. 23:30 - 00:00 0.50 BOPSUR P PRE Winterize cellar. N/D tree cap. N/U BOPE. Meanwhile spot trailers & tanks. 11/29/2003 00:00 - 01 :00 1.00 BOPSUR PRE Continue N/U BOPE. 01 :00 - 09:30 8.50 BOPSUR PRE Perform initial BOPE pressure/function test. AOGCC test witness waived by John Crisp. Meanwhile fill rig pits with seawater. Changeout leaking variable rams & retest OK. PIT inner reel valve. 09:30 - 09:45 0.25 PULL P DECaMP PJSM with Veco crew. Review procedure, hazards & mitigation for pulling BPV. 09:45 - 10:30 0.75 PULL P DECaMP Pull BPV. Bleed off trapped gas cap. 10:30 - 11 :00 0.50 PULL P DECaMP Flowcheck well - stable. 11:00-11:15 0.25 EVAL P COMP Held pre-operations safety meeting. Review well plan, potential hazards & logging BHA M/U procedures. 11 :15 - 12:40 1.42 EVAL P COMP P/U logging BHA #1 (OAL - 63') with GR/CCL logging tool carrier, 1 jt of 2-3/8" PH6 tbg & MHA. M/U injector. 12:40 - 14:30 1.83 EVAL P COMP RIH with logging BHA #1 circ perf pill @ min rate & taking diesel FP returns to the tiger tank. Up wt check @ 11600' = 39k. Run-in wt = 21 k. 14:30 - 14:45 0.25 EVAL P COMP Log down from 11600' @ 60fpm circ perf pill @ 0.45bpm. Tagged up @ 11828'. P/U with 19k O/pull. 14:45 - 17:00 2.25 EVAL N DPRB COMP POOH with logging tools 17:00 - 18:30 1.50 EVAL N DPRB COMP OOH, Stand back injector head, LD SLB GR/CCL logging tool. Download data and evaluate tool location when tagged. PT casing to 1500 psi and no communication to IA was seen, Released pressure. 18:30 - 19:00 0.50 CLEAN N DPRB COMP PU FCO BHA #23.625' DSM, 2-7/8" WFT Motor, CS, HDC, 1 jt PH6 and DCV w/ CTC 19:00 - 21 :30 2.50 CLEAN N DPRB COMP RIH with BHA # 2 to cleanout 4-1/2" liner @ min flowrate WT Check at 11550' 20k dn; 42k up 21 :30 - 22:00 0.50 CLEAN N DPRB COMP Tagged at 11810' at 0.75bpm, PUH and increased Qp to 2.8 BP RIH and some WOB at 11810' W/R 11810' to 11830' PUH(wtcheck) 38k up, 22:00 - 00:00 2.00 CLEAN N DPRB COMP RIH W/R to bottom at 35 to 40 FPH Qp = 2.8 bpm. Some WOB at 12,192'. RIH 11/30/2003 00:00 - 00:30 0.50 CLEAN N DPRB COMP RIH to PBTD. 00:30 - 03:00 2.50 CLEAN N DPRB COMP POOH. 03:00 - 03:30 0.50 CLEAN N DPRB COMP LD clean out BHA. 03:30 - 04:15 0.75 EVAL N DPRB COMP Prepare SWS MGR/CCL logging tool. PU tool to rig floor. MU logging BHA. 04: 15 - 06:20 2.08 EVAL N DPRB COMP RIH to 11600'. Printed: 12/8/2003 11 :51 :43 AM ( ( BP EXPLORATION Operations Summary Report Page 2 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-23 Y-238 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/28/2003 Rig Release: 12/1/2003 Rig Number: N1 Spud Date: 6/1/1986 End: 12/1/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/30/2003 06:20 - 08:00 1.67 EVAL P COMP Log down from 11600' @ 60fpm circ perf pill (150k with 4% L-T) @ 0.70bpm. Tagged PBTD @ 14888'. Pull to PIU wt @ 14883' & pumped out 9bbls of perf pill out of nozzle. 08:00 - 09:00 1.00 EVAL P COMP Log up @ 60fpm from PBTD to 11600' circ @ 0.70bpm & laying-in perf pill in liner. 09:00 - 10:50 1.83 EVAL P COMP POOH with logging tools from 11600'. 10:50 - 11 :30 0.67 EVAL P COMP OOH. PJSM. SIB injector. LID GR/CCL logging BHA#3. Check for data quality - good. 11 :30 - 13:45 2.25 PERF P COMP Load 63jts of 2-7/8" HSD 6spf 34J guns & blanks into pipe shed. Meanwhile inspect injector chains. Download GR/CCL data & fax to ANC Geo. Logged PBTD @ 14869' & L TP @ 11693'. Geo okays perf picks. 13:45 - 15:20 1.58 PERF P COMP PJSM concerning picking up 2-7/8" Perf Guns and all hazards related issues 15:20 - 20:00 4.67 PERF P COMP RU to PU 2-7/8" guns. PU / RIH. JSA at crew change. Installed injector head, set counters 20:00 - 22: 15 2.25 PERF P COMP RIH with Perf BHA pumping at min rate. Wt check @ 11 ,OOOft = 45.5k u and 23.4k down. Tag PBTD. Correct depth to 14,869', -15.8' correction. 22:15 - 22:40 0.42 PERF P COMP Pull up hole to 14,520',10' below target depth. Start pumping 10 bbl perf pill while POOH. PU=46K at 14,860'. Load and launch 5/8" steel ball. Chase wI 15 bbls perf pill. 22:40 - 23:05 0.42 PERF P COMP Circulate ball down at 2.74 bpm, 1,800 psi. Slow rate to 1 bpm, 500 psi prior to ball seating. Ball on seat. Start moving pipe up hole at 10- 15 fpm. Pressure up CT to 2,900 psi. Guns fired. Lost 5 bbls after guns fired. Perforation depths wI SWS 2 7/8" 6spf, 34J charges: 13,200' - 13,335' 13,400' - 13,620' 13,680' - 13,840' 13,930; - 14,050' 14,230' - 14,510' 23:05 - 00:00 0.92 PERF P COMP POOH. Fill hole across the top. 12/1/2003 00:00 - 01 :50 1.83 PERF P COMP POOH. Hole took correct amount of fluid to fill. No losses. 01 :50 - 02:15 0.42 PERF P COMP Stand back injector. Prepare to LD perf. guns. PU tools to rig floor. 02:15 - 02:30 0.25 PERF P COMP PJSM for LD perf guns. 02:30 - 06:30 4.00 PERF P COMP LD perf guns. 06:30 - 06:45 0.25 PERF P COMP Crew change & PJSM for LID guns. 06:45 - 09:00 2.25 PERF P COMP Continue LID perf guns. ASF! Load out guns. 09:00 - 09:45 0.75 RIGD N RREP COMP Inspect overheating power pack traction motor commutator & brushes - designed to run hot instead of cold. When cold, brushes don't contact well & this leads to higher amperage & overheating. Will have to modify cooling fan/blower to increase temp. 09:45 - 10:15 0.50 RIGD P COMP MIU FP nozzle BHA. MIU injector. 10:15 -10:50 0.58 RIGD P COMP RIH nozzle BHA to 2500'. 10:50 - 11 :20 0.50 RIGD P COMP POOH freeze protecting with 60/40 MeOH. SI master valve (23 turns). 11 :20 - 11 :30 0.17 RIGD P POST PJSM for BID CT with N2. 11 :30 - 11 :35 0.08 RIGD P POST PIT N2 lines - OK. 11:35-12:15 0.67 RIGD P POST Blow down CT with N2 and bleed off. Meanwhile clean out pits & tanks. Printed: 12/8/2003 11:51:43AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ( ( BP EXPLORATION Operations Summary Report Y-23 Y -238 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/28/2003 Rig Release: 12/1/2003 Rig Number: N1 Page 3 of 3 Spud Date: 6/1/1986 End: 12/1/2003 From - To Hours Task Code NPT Phase Description of Operations 12/1/2003 12:15 - 12:45 12:45 - 15:00 0.50 RIGD P 2.25 RIGD P POST POST PJSM. Rig injector off well & UO nozzle BHA. RID injector. Clean mud pits and installed and pressure tested tree cap. Rig released at 15:00Hrs on 12-1-03. Printed: 12/8/2003 11: 51 :43 AM ') AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well Y-23 B Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 6,890.34' MD Window / Kickoff Survey: 6,923.00' MD (if applicable) Projected Survey: 14,955.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~.~~~ ~\(\ ~~~ 0\03- /&",ì ,cy.. 25-Nov-03 RECEIVED DEe 0 8 2003 Alaske Oil & Gas Cons. Commileton .A.nctt0f'8ge Halliburton Sperry..Sun North Slope Alaska BPXA PBU WOA Y Pad Y-23B Job No. AKZZ0002732043, Surveyed: 8 November, 2003 Survey Report 24 November, 2003 Your Ref: API 500292159002 Surface Coordinates: 5948883.00 N, 644791.00 E (70016' 03.9649" N, 148049'44.8778" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 948883.00 N, 144791.00 E (Grid) Surface Coordinates relative to Structure Reference: 398.95 N, 2949.54 W (True) Kelly Bushing Elevation: 79. 15ft above Mean Sea Level Kelly Bushing Elevation: 79. 15ft above Project V Reference Kelly Bushing Elevation: 79. 15ft above Structure Reference spet'a-'y-sul'1 tlFtlLLING seRVices A Halliburton Company :>::F N ·T~'VE ,,-0 "--" Survey Ref: svy4122 Halliburton Sperry-Sun Survey Report for PBU_WOA Y Pad - Y-23B Your Ref: API 500292159002 Job No. AKZZ0002732043, Surveyed: 8 November, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6890.34 44.400 313.670 5648.18 5727.33 2153.01 N 2430.96 W 5950988.86 N 642319.08 E 3103.92 Tie On Point AK-6 BP _IFR-AK 6923.00 44.420 313.620 5671.51 5750.66 2168.79 N 2447.50 W 5951004.31 N 642302.24 E 0.123 3125.50 Window Point 7002.20 47.980 307.510 5726.34 5805.49 2205.85 N 2490.93 W 5951040.53 N 642258.10 E 7.152 3180.38 7030.35 49.550 305.500 5744.90 5824.05 2218.44 N 2507.95 W 5951052.79 N 642240.84 E 7.742 3201.08 7063.83 51.630 303.200 5766.16 5845.31 2233.03 N 2529.31 W 5951066.96 N 642219.21 E 8.171 3226.56 ~ 7094.78 52.350 301.140 5785.22 5864.37 2246.01 N 2549.95 W 5951079.55 N 642198.32 E 5.737 3250.72 7124.70 52.520 299.170 5803.46 5882.61 2257.92 N 2570.45 W 5951091.06 N 642177.59 E 5.250 3274.32 7158.02 53.040 295.220 5823.62 5902.77 2270.04 N 2594.05 W 5951102.72 N 642153.77 E 9.568 3300.81 7188.03 53.020 293.060 5841.67 5920.82 2279.84 N 2615.92 W 5951112.11 N 642131.71 E 5.751 3324.79 7217.37 52.880 294.610 5859.35 5938.50 2289.31 N 2637.34 W 5951121.15 N 642110.11 E 4.243 3348.20 7251.01 52.740 294.830 5879.68 5958.83 2300.51 N 2661.68 W 5951131.89 N 642085.56 E 0.667 3375.00 7282.13 52.650 294.280 5898.54 5977.69 2310.80 N 2684.20 W 5951141.74 N 642062.85 E 1.435 3399.75 7310.52 52.570 294.340 5915.78 5994.93 2320.09 N 2704.76 W 5951150.63 N 642042.12 E 0.328 3422.31 7344.31 52.430 293.200 5936.35 6015.50 2330.89 N 2729.29 W 5951160.96 N 642017.38 E 2.708 3449.11 7375.72 52.420 292.930 5955.50 6034.65 2340.64 N 2752.19 W 5951170.27 N 641994.30 E 0.682 3474.00 7404.14 52.280 293.140 5972.86 6052.01 2349.45 N 2772.90 W 5951178.68 N 641973.42 E 0.765 3496.50 7497.76 51.780 293.310 6030.46 6109.61 2378.55 N 2840.72 W 5951206.47 N 641905.05 E 0.553 3570.28 7590.66 51.230 293.210 6088.29 6167.44 2407.27 N 2907.52 W 5951233.90 N 641837.71 E 0.598 3642.98 7682.96 50.620 292.710 6146.47 6225.62 2435.22 N 2973.50 W 5951260.57 N 641771.21 E 0.783 3714.61 7776.41 50.200 292.530 6206.02 6285.17 2462.92 N 3039.97 W 5951286.99 N 641704.22 E 0.473 3786.58 7870.57 52.010 294.900 6265.15 6344.30 2492.40 N 3107.05 W 5951315.18 N 641636.58 E 2.744 3859.85 7963.79 51.960 295.710 6322.56 6401.71 2523.80 N 3173.45 W 5951345.29 N 641569.60 E 0.687 3933.28 8056.92 51.020 295.730 6380.55 6459.70 2555.42 N 3239.10 W 5951375.64 N 641503.35 E 1.009 4006.14 --- 8150.17 50.670 296.000 6439.43 6518.58 2586.96 N 3304.17W 5951405.93 N 641437.69 E 0.437 4078.43 8243.71 50.120 294.990 6499.06 6578.21 2617.99 N 3369.21 W 5951435.70 N 641372.05 E 1.019 4150.48 8337.14 49.490 294.440 6559.36 6638.51 2647.83 N 3434.04 W 5951464.28 N 641306,66 E 0.810 4221.85 8431.21 49.220 294.650 6620.63 6699.78 2677.48 N 3498.97 W 5951492.68 N 641241.18 E 0.333 4293.22 8525.67 48.580 293.930 6682.73 6761.88 2706.76 N 3563.85 W 5951520.71 N 641175.75 E 0.888 4364.40 8618.85 48.250 293.320 6744.57 6823.72 2734.69 N 3627.70 W 5951547.41 N 641111.37 E 0.604 4434.09 8712.42 50.460 296.060 6805.53 6884.68 2764.37 N 3692.18 W 5951575.84 N 641046'.33 E 3.242 4505.07 24 November, 2003 - 16:29 Page 2 of6 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA Y Pad - Y-23B Your Ref: API 500292159002 Job No. AKZZ0002732043, Surveyed: 8 November, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8806.78 49.990 295.130 6865.90 6945.05 2795.70 N 3757.58 W 5951605.90 N 640980.34 E 0.907 4577.58 8899.58 52.060 297.410 6924.27 7003.42 2827.64 N 3822.26 W 5951636.60 N 640915.06 E 2.936 4649.67 8993.16 52.170 297.520 6981.73 7060.88 2861.70 N 3887.79 W 5951669.39 N 640848.89 E 0.150 4723.42 9086.23 51.440 298.080 7039.28 7118.43 2895.82 N 3952.49 W 5951702.26 N 640783.54 E 0.916 4796.44 9179.52 53.140 298.360 7096.34 7175.49 2930.72 N 4017.52 W 5951735.90 N 640717.85 E 1.838 4870.08 9272.99 52.740 298.4 70 7152.67 7231.82 2966.21 N 4083.12 W 5951770.12 N 640651.58 E 0.438 4944.49 -- 9364.54 51.760 298.450 7208.72 7287.87 3000.70 N 4146.76 W 5951803.39 N 640587.29 E 1.071 5016.70 9458.27 51.230 297.820 7267.07 7346.22 3035.29 N 4211.44 W 5951836.73 N 640521.96 E 0.772 5089.90 9552.31 50.510 298.140 7326.42 7405.57 3069.52 N 4275.86 W 5951869.70 N 640456.89 E 0.810 5162.71 9645.60 52.060 297.050 7384.77 7463.92 3103.23 N 4340.37 W 5951902.17 N 640391.74 E 1.895 5235.38 9738.36 51.830 297.380 7441.95 7521.10 3136.63 N 4405.33 W 5951934.31 N 640326.16 E 0.374 5308.34 9832.26 52.410 296.540 7499.60 7578.75 3170.23 N 4471.39 W 5951966.64 N 640259.46 E 0.938 5382.38 9923.73 52.760 296.440 7555.18 7634.33 3202.63 N 4536.41 W 5951997.78 N 640193.83 E 0.392 5454.98 10017.17 52.120 296.910 7612.14 7691.29 3235.88 N 4602.60 W 5952029.76 N 640127.01 E 0.793 5529.00 10110.64 51 .480 296.390 7669.94 7749.09 3268.83 N 4668.25 W 5952061.44 N 640060.74 E 0.812 5602.40 10203.08 51.240 297.400 7727.66 7806.81 3301.49 N 4732.64 W 5952092.85 N 639995.73 E 0.892 5674.53 10297.26 54.380 294.790 7784.59 7863.74 3334.45 N 4800.02 W 5952124.51 N 639927.73 E 3.998 5749.51 10390.70 54.060 296.460 7839.22 7918.37 3367.23 N 4868.36 W 5952155.97 N 639858.77 E 1 .490 5825.29 10484.62 53.600 296.580 7894.65 7973.80 3401.09 N 4936.20 W 5952188.51 N 639790.29 E 0.501 5901.06 10577.55 52.900 292.890 7950.27 8029.42 3432.24 N 5003.81 W 5952218.36 N 639722.10 E 3.269 5975.50 10670.85 52.000 292.410 8007.13 8086.28 3460.73 N 5072.07 W 5952245.53 N 639653.30 E 1.047 6049.43 10764.12 51.270 293.270 8065.02 8144.17 3489.11 N 5139.47 W 5952272.61 N 639585.37 E 1.065 6122.53 10857.55 50.560 294.840 8123.93 8203.08 3518.67 N 5205.69 W 5952300.89 N 639518.60 E 1.510 6195.05 10951.75 49.720 293.280 8184.30 8263.45 3548.15 N 5271.71 W 5952329.10 N 639452.02 E 1.553 6267.35 ----- 11044.74 50.130 292.200 8244.17 8323.32 3575.65 N 5337.33 W 5952355.33 N 639385.88 E 0.992 6338.4 7 11136.96 49.290 292.930 8303.80 8382.95 3602.64 N 5402.29 W 5952381.07 N 639320.41 E 1.093 6408.78 11231.00 48.570 292.250 8365.59 8444.74 3629.88 N 5467.75 W 5952407.04 N 639254.45 E 0.940 6479.64 11325.60 50.120 291.730 8427.22 8506.37 3656.75 N 5534.29 W 5952432.62 N 639187.40 E 1.691 6551.33 11418.82 52.580 290.660 8485.44 8564.59 3683.06 N 5602.17 W 5952457.62 N 639119.03 E 2.787 6624.01 11512.11 52.660 291.000 8542.07 8621.22 3709.42 N 5671.45 W 5952482.64 N 639049.25 E 0.302 6698.00 11604.22 51.720 291.050 8598.54 8677.69 3735.52 N 5739.38 W 5952507.44 N 638980.83 E 1.021 6770.64 11698.58 50.820 291.440 8657.57 8736.72 3762.20 N 5807.99 W 5952532.79 N 638911.72 E 1.007 6844.13 11791.43 49,890 292.150 8716.82 8795.97 3788.74 N 5874.37 W 5952558.05 N 638844.84 E 1.162 6915.55 11860.37 49.280 292.600 8761.51 8840.66 3808.72 N 5922.91 W 5952577.09 N 638795.93 E 1.015 6968.00 11914.83 49.250 289.270 8797.05 8876.20 3823.46 N 5961.44 W 5952591.09 N 638757.12 E 4.633 7009.18 24 November, 2003 - 16:29 Page 3 of6 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU _WOA Y Pad - Y-23B Your Ref: API 500292159002 Job No. AKZZ0002732043, Surveyed: 8 November, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11945.91 51.050 289.260 8816.97 8896.12 3831.33 N 5983.96 W 5952598.52 N 638734.45 E 5.792 7032.95 11975.44 50.370 287.460 8835.67 8914.82 3838.53 N 6005.65 W 5952605.30 N 638712.63 E 5.249 7055.67 12006.95 51.620 283.280 8855.51 8934.66 3845.01 N 6029.25 W 5952611.33 N 638688.90 E 11.044 7079.84 12038,34 53.080 284.440 8874.68 8953.83 3850.97 N 6053.38 W 5952616.82 N 638664.67 E 5.495 7104.27 12069.34 53.900 284.060 8893.12 8972.27 3857.10 N 6077.53 W 5952622.49 N 638640.40 E 2.823 7128.79 12100.41 56.120 283.990 8910.94 8990.09 3863.27 N 6102.23 W 5952628.18 N 638615.59 E 7.148 7153.82 ~ 12132.73 59.820 283.440 8928,08 9007.23 3869.76 N 6128.84 W 5952634.16 N 638588.86 E 11.538 7180.74 12158.88 61.930 282.910 8940.81 9019.96 3874.97 N 6151.08 W 5952638.93 N 638566.52 E 8.261 7203.14 12173.73 63.110 281.260 8947.66 9026.81 3877.72 N 6163.96 W 5952641 .44 N 638553.59 E 12.661 7216.01 12207.59 66.380 282.380 8962.10 9041 .25 3884.00 N 6193.93 W 5952647.14 N 638523.51 E 10.110 7245.89 12239.53 70.160 282.890 8973.93 9053.08 3890.49 N 6222.88 W 5952653.07 N 638494.44 E 11.927 7274.93 12268.03 75.920 282.060 8982.24 9061.39 3896.37 N 6249.48 W 5952658.44 N 638467.73 E 20.401 7301.58 12302.20 83.010 284.740 8988.48 9067.63 3904.16 N 6282.14 W 5952665.60 N 638434.93 E 22.134 7334.53 12333.76 89.570 286.880 8990.52 9069.67 3912.74 N 6312.42 W 5952673.60 N 638404.49 E 21.858 7365.65 12361.01 93.830 293.240 8989.71 9068.86 3922.07 N 6337.99 W 5952682.44 N 638378.75 E 28.078 7392.79 12394.53 91.110 290.900 8988.27 9067.42 3934.65 N 6369.02 W 5952694.42 N 638347.48 E 10.700 7426.25 12427.14 90.620 290.070 8987.78 9066.93 3946.06 N 6399.56 W 5952705.24 N 638316.72 E 2.955 7458.77 12455.87 89.070 284.150 8987.85 9067.00 3954.51 N 6427.01 W 5952713.16 N 638289.12 E 21.300 7487.26 12485.10 90.740 281,920 8987.90 9067.05 3961.10 N 6455.48 W 5952719.20 N 638260.52 E 9.531 7515.91 12521.02 92.350 279.300 8986.93 9066.08 3967.71 N 6490.77 W 5952725.13 N 638225.11 E 8.559 7550.77 12538.80 91.300 277.190 8986.37 9065.52 3970.26 N 6508.36 W 5952727.34 N 638207.48 E 13.250 7567.83 12572.12 91.850 270.970 8985.45 9064.60 3972.63 N 6541.56 W 5952729.07 N 638174.24 E 18.733 7599.04 12601.84 92.350 273.220 8984.36 9063.51 3973.72 N 6571.24 W 5952729.59 N 638144.54 E 7.750 7626.51 12633.65 94.320 271.580 8982.51 9061.66 3975.05 N 6602.97 W 5952730.31 N 638112.80 E 8.052 7655.94 - 12668.61 95.810 269.240 8979.42 9058.57 3975.30 N 6637.79 W 5952729.89 N 638077.98 E 7.913 7687,75 12700.68 95.440 269.730 8976.28 9055.43 3975.01 N 6669.70 W 5952728.99 N 638046.08 E 1.909 7716.68 12728.96 94.880 267.590 8973.74 9052.89 3974.35 N 6697.86 W 5952727.79 N 638017.94 E 7.792 7742.04 12762.64 94.760 268.190 8970.91 9050.06 3973.12 N 6731.39 W 5952725.90 N 637984.43 E 1.811 7772.06 12793.67 92.720 268.570 8968.88 9048.03 3972.24 N . 6762.34 W 5952724.43 N 637953.50 E 6.687 7799.88 12822.53 92.650 267.380 8967.53 9046.68 3971.22 N 6791.15 W 5952722.86 N 637924.72 E 4.126 7825.69 12856.19 92.780 268.340 8965.94 9045.09 3969.97 N 6824.75 W 5952720.96 N 637891.15 E 2.875 7855.75 12888.86 91.540 268.150 8964.71 9043.86 3968.97 N 6857.38 W 5952719.33 N 637858.54 E 3.840 7885.05 12917.85 91.540 268.450 8963.93 9043.08 3968.11 N 6886.35 W 5952717.92 N 637829.60 E 1.034 7911.06 13009.28 89.630 268.550 8962.99 9042.14 3965.71 N 6977.74 W 5952713.77 N 637738.27 E 2.092 7993.27 13041 .74 89.200 271.940 8963.32 9042.4 7 3965.85 N 7010.19 W 5952713.28 N 637705.82 E 10.527 8022.88 24 November, 2003 - 16:29 Page 4 of6 DrilIQuest~0~0~005 Halliburton Sperry-Sun Survey Report for PBU_WOA Y Pad - Y-23B Your Ref: API 500292159002 Job No. AKZZ0002732043, Surveyed: 8 November, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13071.83 89.690 273.330 8963.62 9042.77 3967.24 N 7040.25 W 5952714.09 N 637675.75 E 4.898 8050.81 13101.92 90.000 273.170 8963.70 9042.85 3968.94 N 7070.29 W 5952715.21 N 637645.68 E 1.159 8078.87 13133.46 90.490 272.700 8963.56 9042.71 3970.56 N 7101.79W 5952716.22 N 637614.15 E 2.153 8108.21 13166.03 90.800 274.360 8963.20 9042.35 3972.56 N 7134.29 W 5952717.60 N 637581.62 E 5.185 8138.63 13194.97 90.430 277.390 8962.89 9042.04 3975.52 N 7163.08 W 5952720.01 N 637552.78 E 10.547 8166.06 13239.51 92.900 280.050 8961.59 9040.74 3982.27 N 7207.07 W 5952725.91 N 637508.66 E 8.148 8208.91 ~~ 13289.93 94.080 282.140 8958.52 9037.67 3991.95 N 7256.46 W 5952734.64 N 637459.10 E 4.753 8257.87 13333.63 94.140 282.160 8955.39 9034.54 4001.13 N 7299.07 W 5952742.99 N 637416.32 E 0.145 8300.46 13382.72 94.510 282.150 8951.69 9030.84 4011.44 N 7346.92 W 5952752.38 N 637368.28 E 0.754 8348.29 13477.00 92.720 279.860 8945.74 9024.89 4029.39 N 7439.27 W 5952768.56 N 637275.60 E 3.079 8439.80 13568.55 92.840 280.110 8941 .30 9020.45 4045.25 N 7529.33 W 5952782.68 N 637185.25 E 0.303 8528.35 13662.20 88.890 277.720 8939.89 9019.04 4059.76 N 7621.81 W 5952795.40 N 637092.51 E 4.929 8618.55 13754.59 88.580 277.850 8941.93 9021.08 4072.27 N 7713.33 W 5952806.15 N 637000.77 E 0.364 8707.04 13795.43 88.770 276.620 8942.87 9022.02 4077.41 N 7753.83 W 5952810.51 N 636960.17 E 3.047 8746.04 13850.09 90.860 277.180 8943.05 9022.20 4083.97 N 7808.09 W 5952816,03 N 636905.80 E 3.958 8798.15 13943.02 91.170 275.930 8941.40 9020.55 4094.58 N 7900.40 W 5952824.86 N 636813.30 E 1.386 8886.58 14038.09 91.910 275.210 8938.85 9018.00 4103.81 N 7994.99 W 5952832.27 N 636718.56 E 1.086 8976.50 14132.74 91.360 275.220 8936.15 9015.30 4112.41 N 8089.20 W 5952839.05 N 636624.19 E 0.581 9065.84 14227.30 92.470 274.920 8932.99 9012.14 4120.76 N 8183.34 W 5952845.59 N 636529.91 E 1.216 9155.00 14320.85 91.670 274.960 8929.61 9008.76 4128.81 N 8276.48 W 5952851.85 N 636436.63 E 0.856 9243.12 14416.08 91.980 274.290 8926.58 9005.73 4136.48 N 8371.35 W 5952857.70 N 636341.63 E 0.775 9332.67 14462.23 89.690 275.590 8925.90 9005.05 4140.46 N 8417.32 W 5952860.79 N 636295.59 E 5.706 9376.16 14509.81 89.320 275.660 8926.31 9005.46 4145.12 N 8464.67 W 5952864.54 N 636248.16 E 0.791 9421.20 14604.44 89.630 277.910 8927.18 9006.33 4156.30 N 8558.63 W 5952873.91 N 636154.01 E 2.400 9511.36 -~...~øf/ 14699.36 91.050 277.550 8926.62 9005.77 4169.07 N 8652.68 W 5952884.86 N 636059.73 E 1.543 9602.27 14793.56 89.140 278.080 8926.46 9005.61 4181.87N 8746.00 W 5952895.87 N 635966.18 E 2.104 9692.53 14955.00 89.140 278.080 8928.88 9008.03 4204.56 N 8905.82 W 5952915.48 N 635805.95 E 0.000 9847.41 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 294.4400 (True). Magnetic Declination at Surface is 25.4170 (24-0ct-03) 24 November, 2003 - 16:29 Page 50f6 DríllQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA Y Pad - Y-23B Your Ref: APt 500292159002 Job No. AKZZ0002732043, Surveyed: 8 November, 2003 North Slope Alaska BPXA Based upon Minimum Curvature type calculations, at a Measured Depth of 14955.00ft., The Bottom Hole Displacement is 9848.45ft., in the Direction of 295.273° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment --- 6890,34 6923.00 14955.00 5727.33 5750.66 9008.03 2153.01 N 2168.79 N 4204.56 N 2430.96 W 2447.50 W 8905.82 W Tie On Point Window Point Projected Survey Survey tool proQram for Y-23B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 6890.34 0.00 5727.33 6890.34 14955.00 5727.33 BP High Accuracy Gyro (Y-23) 9008.03 AK-6 BP _IFR-AK (Y-23B) "-- 24 November, 2003 - 16:29 Page 60f6 DritlQuest 3.03.05.005 ) AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well Y-23B MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 6,890.34' MD Window / Kickoff Survey: 6,923.00' MD (if applicable) Projected Survey: 14,955.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Su rvey Manager Attachment(s) ~~~\\"'..... 1"'\ 'j , J\ ",.~~ ') t) C)3 - / (p L (I ~. 25-Nov-03 RECEIVED DEC 08 2003 iðJæka Oi! & Gas Cons. Comm_n ,Anchmege Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA Y Pad Y-23B MWD ..-.-r Survey Report 24 November, 2003 Your Ref: API 500292159002 Surface Coordinates: 5948883.00 N, 644791.00 E (70016' 03.9649" N, 148049'44.8778" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 948883.00 N, 144791.00 E (Grid) Surface Coordinates relative to Structure Reference: 398.95 N, 2949.54 W (True) Kelly Bushing Elevation: 79. 15ft above Mean Sea Level Kelly Bushing Elevation: 79. 15ft above Project V Reference Kelly Bushing Elevation: 79. 15ft above Structure Reference .-- sper'I'Y-su'1 DRILLING SERViCeS A Halliburton Company Survey Ref: svy4123 Halliburton Sperry-Sun Survey Report for PBU_WOA Y Pad - Y-23B MWD Your Ref: API 500292159002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6890.34 44.400 313.670 5648.18 5727.33 2153.01 N 2430.96 W 5950988.86 N 642319.08 E 3103.92 Tie On Point MWD Magnetic 6923.00 44.420 313.620 5671.51 5750.66 2168.79 N 2447.50 W 5951004.31 N 642302.24 E 0.123 3125.50 Window Point 7002.20 47.980 307,510 5726.34 5805.49 2205.85 N 2490.93 W 5951040.53 N 642258.10 E 7.152 3180.38 7030.35 49.550 308.580 5744.90 5824.05 2218.90 N 2507.60 W 5951053.26 N 642241.18 E 6.267 3200.96 7063.83 51.630 302.280 5766.17 5845.32 2233.86 N 2528.67 W 5951067.81 N 642219.83 E 15.805 3226.33 7094.78 52.350 301.400 5785.23 5864.38 2246.73 N 2549.39 W 5951080.28 N 642198.87 E 3.230 3250.51 '-' 7124.70 52.520 300.090 5803.47 5882.62 2258.85 N 2569.77 W 5951092.00 N 642178.26 E 3.517 3274.08 7158.02 53.040 296.060 5823.63 5902.78 2271.33 N 2593.17 W 5951104.03 N 642154.62 E 9.756 3300.55 7188.03 53.020 293.830 5841.68 5920.83 2281.44 N 2614.91 W 5951113.72 N 642132.69 E 5.937 3324.53 7217.37 52.880 295.410 5859.35 5938.50 2291.20 N 2636.20 W 5951123.07 N 642111.22 E 4.324 3347.94 7251.01 52.740 296.740 5879.69 5958.84 2302.98 N 2660.27 W 5951134.38 N 642086.93 E 3.177 3374.73 7282.13 52.650 296.220 5898.55 5977.70 2314.01 N 2682.42 W 5951144.99 N 642064.56 E 1.360 3399.47 7310.52 52.570 296.000 5915.79 5994.94 2323.94 N 2702.68 W 5951154.52 N 642044.12 E 0.677 3422.01 7344.31 52.430 296.380 5936.36 6015.51 2335.77 N 2726.73 W 5951165.89 N 642019.84 E 0.984 3448.81 7375.72 52.420 295.830 5955.51 6034.66 2346.72 N 2749.09 W 5951176.41 N 641997.28 E 1.388 3473.69 7404.14 52.280 296.190 5972.87 6052.02 2356.59 N 2769.31 W 5951185.89 N 641976.87 E 1.117 3496.18 7497.76 51.780 295.640 6030.47 6109.62 2388.85 N 2835.69 W 5951216.86 N 641909.88 E 0.707 3569.96 7590.66 51.230 295.870 6088.30 6167.45 2420.44 N 2901.18 W 5951247.19 N 641843.80 E 0.623 3642.65 7682.96 50.620 295.660 6146.48 6225.63 2451.59 N 2965.71 W 5951277.09 N 641778.68 E 0.684 3714.29 7776.41 50.200 294.810 6206.03 6285.18 2482.29 N 3030.85 W 5951306.53 N 641712.96 E 0.833 3786.29 7870.57 52.010 296.480 6265.16 6344.31 2514.02 N 3096.90 W 5951336.98 N 641646.31 E 2.366 3859.55 7963.79 51.960 297.000 6322.57 6401.72 2547.06 N 3162.49 W 5951368.76 N 641580.10 E 0.443 3932.94 8056.92 51.020 297.470 6380.55 6459.70 2580.41 N 3227.29 W 5951400.86 N 641514.68 E 1.084 4005.72 8150.17 50.670 295.560 6439.44 6518.59 2612.69 N 3291.98 W 5951431.89 N 641449.37 E 1.632 4077.98 '- 8243.71 50.120 295.190 6499.07 6578.22 2643.58 N 3357.10 W 5951461.52 N 641383.67 E 0.662 4150.04 8337.14 49.490 294.710 6559.37 6638.52 2673.68 N 3421.80 W 5951490.37 N 641318.40 E 0.780 4221.40 8431.21 49.220 295.770 6620.64 6699.79 2704.12 N 3486.36 W 5951519.56 N 641253.27 E 0.902 4292.77 8525.67 48.580 294.680 6682.74 6761.89 2734.45 N 3550.75 W 5951548.65 N 641188.31 E 1.102 4363.94 8618.85 48.250 294.4 70 6744.58 6823.73 2763.44 N 3614.14 W 5951576.41 N 641124.38E 0.392 4433.64 8712.42 50.460 297.320 6805.54 6884.69 2794.46 N 3677.98 W 5951606.20 N 641059.95 E 3.304 4504.59 8806.78 49.990 296.050 6865.91 6945.06 2827.03 N 3742.77 W 5951637.52 N 640994.54 E 1.148 4577.06 8899.58 52.060 298.970 6924.28 7003.43 2860.37 N 3806.73 W 5951669.62 N 640929.96 E 3.310 4649.08 8993.16 52.170 298.650 6981.75 7060.90 2895.96 N 3871.45 W 5951703.96 N 640864.57 E 0.294 4722.72 9086.23 51.440 300.790 7039.30 7118.45 2932.22 N 3934.96 W 5951738.99 N 640800.36 E 1.970 4795.55 9179.52 53.140 300.760 7096.36 7175.51 2969.98 N 3998.37 W 5951775.52 N 640736.24 E 1.822 4868.90 24 November, 2003 - 16:30 Page 2 of6 DrillQuest 3.03.05.005 Halliburlon Sperry-Sun Survey Report for PBU_WOA Y Pad - Y-23B MWD Your Ref: API 500292159002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9272.99 52.740 299,720 7152.69 7231.84 3007.54 N 4062.81 W 5951811.84 N 640671.09 E 0.986 4943.10 9364.54 51.760 300.910 7208.74 7287.89 3044.08 N 4125.30 W 5951847.16 N 640607.91 E 1 .484 5015.11 9458.27 51.230 294.760 7267.13 7346.28 3078.31 N 4190.10 W 5951880.14 N 640542.4 7 E 5.165 5088.27 9552.31 50.510 298.180 7326.49 7405.64 3110.80 N 4255.39 W 5951911.38 N 640476.56 E 2.923 5161.15 9645.60 52.060 297.780 7384.83 7463.98 3144.95 N 4319.67 W 5951944.28 N 640411.64 E 1.695 5233.80 9738.36 51.830 298.840 7442.01 7521.16 3179.59 N 4383.97 W 5951977.68 N 640346.68 E 0.933 5306.67 9832.26 52.410 297.040 7499.67 7578.82 3214.31 N 4449.45 W 5952011.13 N 640280.55 E 1.634 5380.64 --- 9923.73 52.760 297.450 7555.25 7634.40 3247.57 N 4514.04 W 5952043.14 N 640215.33 E 0.523 5453.21 10017.17 52.120 298.220 7612.21 7691.36 3282.15 N 4579.54 W 5952076.46 N 640149.18 E 0.946 5527.15 10110.64 51.480 298.160 7670.01 7749.16 3316.85 N 4644.28 W 5952109.91 N 640083.78 E 0.687 5600.44 10203.08 51.240 283.930 7727.91 7807.06 3342.67 N 4711.35 W 5952134.44 N 640016.23 E 12.015 5672.19 10297.26 54.380 299.080 7785.04 7864.19 3370.23 N 4780.72 W 5952160.65 N 639946.34 E 13.224 5746.74 10390.70 54.060 300.910 7839.68 7918.83 3408.12 N 4846.37 W 5952197.27 N 639879.98 E 1.625 5822.18 10484.62 53.600 295.390 7895.14 7974.29 3443.88 N 4913.17 W 5952231.74 N 639812.50 E 4.769 5897.79 10577.55 52.900 292.440 7950.75 8029.90 3474.06 N 4981.22 W 5952260.61 N 639743.88 E 2.653 5972.24 10670.85 52.000 291.000 8007.61 8086.76 3501.44 N 5049.93 W 5952286.66 N 639674.65 E 1.558 6046.12 10764.12 51.270 280.450 8065,60 8144.75 3521.24 N 5120.14 W 5952305.11 N 639604.08 E 8.898 6118.23 10857.55 50.560 278.070 8124.51 8203.66 3532.92 N 5191.70W 5952315.40 N 639532.30 E 2.118 6188.21 10951.75 49.720 291.550 8185.05 8264.20 3551.27 N 5261.33 W 5952332.42 N 639462.34 E 11.010 6259.19 11044.74 50.130 289.830 8244.92 8324.07 3576.41 N 5327.89 W 5952356.27 N 639395.30 E 1 .482 6330.19 11136.96 49.290 292.200 8304.55 8383.70 3601.62 N 5393.55 W 5952380.21 N 639329.17 E 2.161 6400.40 11231.00 48.570 295.930 8366.35 8445.50 3630.51 N 5458.27 W 5952407.85 N 639263.91 E 3.086 6471.27 11325.60 50.120 293.230 8427.99 8507.14 3660.34 N 5523.53 W 5952436.42 N 639198.09 E 2.715 6543.02 11418.82 52.580 293.080 8486.20 8565.35 3688.96 N 5590.46 W 5952463.75 N 639130.61 E 2.642 6615.80 11512.11 52.660 292.540 8542.84 8621.99 3717.70 N 5658.80 W 5952491.17 N 639061.74 E 0.468 6689.90 -- 11604.22 51 .720 292.080 8599.31 8678.46 3745.33 N 5726.12 W 5952517.50 N 638993.90 E 1.094 6762.62 11698.58 50.820 292.050 8658.34 8737.49 3772.98 N 5794.34 W 5952543.83 N 638925.16 E 0.954 6836.17 11791.43 49.890 294.570 8717.59 8796.74 3801.26 N 5859.99 W 5952570.84 N 638858.98 E 2.317 6907.64 11860.37 49.280 291.890 8762.29 8841 .44 3821.96 N 5908.21 W 5952590.61 N 638810.36 E 3.089 6960.11 11914.83 49.250 289.270 8797.83 8876.98 3836.47 N 5946.84 W 5952604.37 N 638771.47 E 3.646 7001.27 11945.91 51.050 289.260 8817.74 8896.89 3844.34 N 5969.36 W 5952611.81 N 638748.80 E 5.792 7025.04 11975.44 50.370 285.960 8836.45 8915.60 3851.25 N 5991.14 W 5952618.30 N 638726.89 E 8.950 7047.72 12006.95 51.620 281.220 8856.29 8935.44 3857.00 N 6014.93 W 5952623.59 N 638702.99 E 12.343 7071.76 12038.34 53.080 280,940 8875.46 8954.61 3861.77 N 6039.32 W 5952627.89 N 638678.52 E 4.704 7095.94 12069.34 53.900 280.940 8893.90 8973.05 3866.50 N 6063.78 W 5952632.15 N 638653.97 E 2.645 7120.17 24 November, 2003 - 16:30 Page 3 of6 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA Y Pad - Y-23B MWD Your Ref: API 500292159002 BPXA North Slope Alaska Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12100.41 56.120 283.870 8911.72 8990.87 3871.98 N 6088.64 W 5952637.15 N 638629.01 E 10.522 7145.06 12132.73 59.820 285.830 8928.86 9008.01 3879.01 N 6115.11 W 5952643.67 N 638602.41 E 12.549 7172.07 12158.88 61.930 285.540 8941.59 9020.74 3885.18 N 6137.10 W 5952649.42 N 638580.30 E 8.127 7194.64 12173.73 63.110 281.270 8948.44 9027.59 3888.23 N 6149.92 W 5952652.22 N 638567.43 E 26.717 7207.57 12207.59 66.380 282.310 8962.89 9042.04 3894.49 N 6179.89 W 5952657.90 N 638537.35 E 10.049 7237.45 12239.53 70.160 284.820 8974.71 9053.86 3901.46 N 6208.72 W 5952664.31 N 638508.38 E 13.904 7266.58 12268.03 75.920 281.790 8983.02 9062.17 3907.72 N 6235.24 W 5952670.06 N 638481.75 E 22.622 7293.31 '-- 12302.20 83.010 283.570 8989.27 9068.42 3915.09 N 6267.99 W 5952676.80 N 638448.87 E 21.371 7326.18 12333.76 89.570 282.570 8991.31 9070.46 3922.21 N 6298.65 W 5952683.33 N 638418.07 E 21.025 7357.03 12361.01 93.830 304.260 8990.49 9069.64 3932.96 N 6323.49 W 5952693.60 N 638393.03 E 81.064 7384.10 12394.53 91.110 300.240 8989.05 9068.20 3950.82 N 6351.81 W 5952710.92 N 638364.38 E 14.470 7417.27 12427.14 90.620 284.890 8988.55 9067.70 3963.30 N 6381.83 W 5952722.81 N 638334.12 E 47.090 7449.76 12455.87 89.070 282.320 8988.63 9067.78 3970.06 N 6409.75 W 5952729.03 N 638306.08 E 10.446 7477.97 12485.10 90.740 282.380 8988.68 9067.83 3976.31 N 6438.30 W 5952734.73 N 638277.41 E 5.717 7506.55 12521.02 92.350 284.270 8987.71 9066.86 3984.58 N 6473.24 W 5952742.33 N 638242.32 E 6.910 7541.78 12538,80 91.300 277.590 8987.14 9066.29 3987.95 N 6490.68 W 5952745.37 N 638224.82 E 38.012 7559.05 12572.12 91.850 271.360 8986.22 9065.37 3990.55 N 6523.86 W 5952747.32 N 638191.59 E 18.763 7590.34 12601.84 92.350 273.080 8985.14 9064.29 3991.70 N 6553.54 W 5952747.90 N 638161.89 E 6.023 7617.84 12633.65 94.320 271.210 8983.28 9062.43 3992.89 N 6585.27 W 5952748.48 N 638130.14 E 8.532 7647.22 12668.61 95.810 267.350 8980.20 9059.35 3992.45 N 6620.09 W 5952747.38 N 638095.35 E 11 .795 7678.73 12700.68 95.440 267.600 8977.05 9056.20 3991.04 N 6651.97 W 5952745.36 N 638063.49 E 1.390 7707.18 12728.96 94.880 266.930 8974.51 9053.66 3989.70 N 6680.10 W 5952743.47 N 638035.39 E 3.080 7732.23 12762.64 94.760 268.370 8971.68 9050.83 3988.32 N 6713.63 W 5952741 .45 N 638001.89 E 4.275 7762.19 12793.67 92.720 268.730 8969.66 9048.81 3987.54 N 6744.59 W 5952740.07 N 637970.96 E 6.675 7790.04 12822.53 92.650 267.390 8968.30 9047.45 3986.56 N 6773.40 W 5952738.54 N 637942.17 E 4.644 7815.87 '--' 12856.19 92.780 268.410 8966.71 9045.86 3985.33 N 6807.00 W 5952736.66 N 637908.61 E 3.051 7845.95 12888.86 91.540 269.180 8965.48 9044.63 3984.65 N 6839.64 W 5952735.35 N 637875.99 E 4.467 7875.38 12917.85 91.540 267.540 8964.70 9043.85 3983.82 N 6868.60 W 5952733.96 N 637847.04 E 5.655 7901.41 13009.28 89.630 268.550 8963.77 9042.92 3980.70 N 6959.97 W 5952729.09 N 637755.75 E 2.363 7983.30 13041 .74 89.200 272.160 8964.10 9043.25 3980.90 N 6992.42 W 5952728.67 N 637723.30 E 11.199 8012.92 13071.83 89.690 271.740 8964.39 9043.54 3981.92 N 7022.49 W 5952729.11 N 637693.22 E 2.145 8040.72 13101.92 90.000 272.780 8964.47 9043.62 3983.11 N 7052.56 W 5952729.72 N 637663.13 E 3.607 8068.59 13133.46 90.490 271.540 8964.34 9043.49 3984.30 N 7084.08 W 5952730.30 N 637631.60 E 4.227 8097.77 13166.03 90.800 271.860 8963.97 9043.12 3985.26 N 7116.63 W 5952730.64 N 637599.03 E 1.368 8127.81 13194.97 90.430 274.360 8963.66 9042.81 3986.83 N 7145.52 W 5952731.66 N 637570.11 E 8.732 8154.76 24 November, 2003 - 16:30 Page 4 of6 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU _WOA Y Pad - Y-23B MWD Your Ref: API 500292159002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13239.51 92.900 277.070 8962.36 9041.51 3991.27 N 7189.81 W 5952735.23 N 637525.75 E 8.230 8196.92 13289,93 94.080 278.820 8959.29 9038.44 3998.22 N 7239.65 W 5952741.23 N 637475.78 E 4.181 8245.17 13333.63 94.140 280.850 8956.16 9035,31 4005.67 N 7282.60 W 5952747.85 N 637432.70 E 4.635 8287.35 13382.72 94.510 281.620 8952.46 9031.61 4015.20 N 7330.61 W 5952756.46 N 637384.51 E 1.736 8335.00 13477.00 92.720 280.240 8946.52 9025.67 4033.04 N 7422.99 W 5952772.52 N 637291.81 E 2.396 8426.49 13568.55 92.840 280.080 8942.08 9021.23 4049.17 N 7513.00 W 5952786.91 N 637201.51 E 0.218 8515.10 13662.20 88.890 275.560 8940.66 9019.81 4061.91 N 7605.73 W 5952797.86 N 637108.55 E 6.409 8604.79 ~ 13754.59 88.580 277.100 8942.70 9021.85 4072.09 N 7697.53 W 5952806.28 N 637016.57 E 1.700 8692.58 13795.43 88.770 276.070 8943.64 9022.79 4076.77 N 7738.09 W 5952810.18 N 636975.93 E 2.564 8731.44 13850.09 90.860 277.310 8943.82 9022.97 4083.14 N 7792.37 W 5952815.50 N 636921.53 E 4.446 8783.49 13943.02 91.170 276.080 8942.18 9021.33 4093.97 N 7884.65 W 5952824.55 N 636829.06 E 1.365 8871.99 14038.09 91.910 274.880 8939.62 9018.77 4103.05 N 7979.25 W 5952831.81 N 636734.31 E 1 .483 8961.86 14132.74 91.360 274.850 8936.92 9016.07 4111.07 N 8073.52 W 5952838.02 N 636639.90 E 0.582 9051.01 14227.30 92.470 276.140 8933.76 9012.91 4120.12 N 8167.59 W 5952845.26 N 636545.67 E 1.799 9140.39 14320.85 91.670 274.680 8930.38 9009.53 4128.93 N 8260.66 W 5952852.28 N 636452.45 E 1.779 9228.77 14416.08 91.980 275.040 8927.35 9006.50 4137.00 N 8355.50 W 5952858.52 N 636357.48 E 0.499 9318.44 14462.23 89.690 275.860 8926.68 9005.83 4141.38 N 8401.43 W 5952862.01 N 636311.47 E 5.271 9362.07 14509.81 89.320 274.100 8927.09 9006.24 4145.51 N 8448.83 W 5952865.23 N 636264.00 E 3.780 9406.93 14604.44 89.630 274.100 8927.95 9007.10 4152.27 N 8543.21 W 5952870.18 N 636169.50 E 0.328 9495.66 14699.36 91.050 274.600 8927.39 9006.54 4159.47 N 8637.85 W 5952875.56 N 636074.74 E 1.586 9584.80 14793.56 89.140 273.740 8927,23 9006.38 4166.32 N 8731.80 W 5952880.60 N 635980.68 E 2.224 9673.16 14955.00 89.140 273.740 8929.66 9008.81 4176.85 N 8892.88 W 5952888.03 N 635819.43 E 0.000 9824.16 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. ---' Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 294.440° (True). Magnetic Declination at Surface is 25.417° (24-0ct-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 14955.00ft., The Bottom Hole Displacement is 9824.93ft., in the Direction of 295.159° (True). 24 November, 2003 - 16:30 Page 50f6 DrillQuest 3.03.05.005 North Slope Alaska Comments Measured Depth (ft) 6890.34 6923.00 14955.00 Halliburton Sperry-Sun Survey Report for PBU_WOA Y Pad - Y-23B MWD Your Ref: AP/500292159002 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5727.33 5750.66 9008.81 Comment 2153.01 N 2168.79 N 4176.85 N 2430.96 W 2447.50 W 8892.88 W Tie On Point Window Point Projected Survey .~ Survey tool proQram for Y-23B MWD Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 6890.34 0.00 5727.33 24 November, 2003 - 16:30 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 6890.34 14955.00 5727.33 BP High Accuracy Gyro (Y-23) 9008.81 MWD Magnetic (Y-23B MWD) - Page 60f6 DrillQuest 3.03.05.005 ìrJC,Æ q/7,f/¡"OO! . STATE OF ALASKA ALASKA G.)AND GAS CONSERVATION COrvl¡,".~SION PERMIT TO DRILL 20 AAC 25.005 1b. Current Well Class D Exploratory D Stratigraphic Test D Service 5. Bond: Ia Blanket 0 Single Well Bond No. 2S 100302630-277 6. Proposed Depth: MD 16186' TVD 9040' 7. Property Designation: ADL 028288 1,9. ,;!':...·.·.~.ae$~~~:W¡eLIi:CC)~PIWI<PN..:$!q,MKð~RY!,(Tq··Þeê9mpl~i~~.for:R~~ril:II:~~Ø¡~~~~ÒtrY'ØperªtiQQs) . I,,' ... Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): IEffective Depth TVD (ft):1 11781' 8985' None 11748' 8984' Casing '..' ;·'LeI19th CementVol!.J01e MD Structural Conductor Surface Intermediate Production Liner o Drill iii Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1372' SNL, 24' WEL, SEC. 33, T11N, R13E, UM Top of Productive Horizon: 2535' NSL, 1084'WEL, SEC. 29, T11N, R13E, UM Total Depth: 3203' NSL, 4818' WEL, SEC. 29, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-644792 16. Deviated Wells: . Kickoff Depth 18. . C~~ing;Pr?Qrart" , Size' Hole Casing 8-1/2" 7" 6-1/8" 4-1/2" y- 5948883 Zone-ASP4 6763 ft Maximum Hole Angle , l~peCifi~ati~n'~ Grade Coupling L-80 BTC-M L-80 IBT-M Weight 26# 12.6# 110' 2817' 10330' 20" 13-3/8" 9-5/8" Liner 1071' 1559' 3-1/2" x 3-3/16" x 2-7/8" 7" Perforation Depth MD (ft): 11368' -11748' iii Development Oil D Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU Y-23B / 12. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 8. Land Use Permit: 13. Approximate Spud Date: 10/20/03 14. Distance to Nearest Property: 18,281' 9. Acres in Property: 2560 10. KB Elevation Plan KBE 15. Distance to Nearest Well Within Pool /" (Height above GL): = 80.1 feet Y-25 is 1319' away at 13033' MD 17. Anticipated pressure (see 20 AAC 25.035) 950 Max. Downhole Pressure: 3265 psig. Max. Surface Pressure: 2368 psig / . ,I ..' .'.I"$ettiQg,'.~ept ;}!,,·I, I"'" ···"qual1ti~Y'qfCem~nt '. ' , Top. .i, .....,' ..',. .. .', ..' ,,:SoUo'm:: .. .. ..,'.. ... (c;f,'or.sacks). ,"," Length MD TVD MD TVD (including stafJe data) 5303' 6613' 5499' 11915' 8890' 197 cu ft Class 'G' ./ 4420' 11765' 8734' 16186' 9040' Uncemented Slotted Liner :-,;,;'1,,:: I 1,'1': I "¡':I," Junk (measured): None TVD 8 yards Concrete 3902 cu ft Permafrost 572 cu ft Class 'G' 110' 2817' 10330' 110' 2701' 8310' 400 cu ft Class 'G' Uncemented Slotted Liner 10053' - 11124" 10222' - 11781' 8117' - 8857' 8235' - 8985' Perforation Depth TVD (ft): 8970' - 8984' 20. Attachments 181 Filing Fee 0 BOP Sketch Ia Drilling Program 0 Time vs Depth Plot 181 Property Plat 0 Diverter Sketch 0 Seabed Report 181 Drilling Fluid Program 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bi Isaacson Title Senior Drilling Engineer Signature r ~ J -: \ 0 '4. '".: , Permit To Drill API Number: Number: 203 ~ /6 C) 50-029-21590-02-00 Conditions of Approval: Samples Required Hydrogen Sulfide Measures Other: T €':. \- {?o pe fe .~ 5'00 p .\l. o Shallow Hazard Analysis 18120 MC 25.050 Requirements Date: .,-tfi"I/ Contact Rob Tirpack, 564-4166 Date 1/1.403 Prepared By Name/Number: Terrie Hubble, 564-4628 Phone 564-5521 Commission Use Only Permit ~~epr ~~.. . . See cover letter for Date: )j <r ..~ other requirements DYes I8J No Mud Lo Required'-', ':...." ~ >OYés"'~'No r8I Yes 0 No Directional SurveyRèquired"'~ Yes" DNa 'íE· 4 ' ,k1 Approved Bv: ¡t. ~ 1- <?~o (i', ~~~~ L~~~~g~~~~'ON Date ~29/~ Form 10-401 Revised 3120~ i\ I 0 II ~ M Sabmit In Duplicate ) ) IWell Name: IV-23B Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: x = 644,791 Y = 5,948,883 / 1372' FNL 25' FEL Sec. 33, T11N, R13E Umiat ,. X = 638,370 Y = 5,952,670 TVDss 8990' 2745' FNL 1084' FEL Sec. 29, T11N, R13E Umiat ./ X = 634,622 Y = 5,953,270 TVDss 8960' 2077' FNL 461' FWL Sec. 29, T11N, R13E Umiat / Target Location: Ivishak Zone 48 Bottom Hole Location: I AFE Number: 1 P8D4P2129 I 1 Estimated Start Date: 110/20/03 I RiQ: I Nabors 2ES / I OperatinQ days to complete: 126.0 I MD: 116,186' 11TVD: 19040' 1 1 GL: 151 .6' 1 KB: 128.5' I I KBE: 180.1' I Well DesiQn (conventional, slim hole, etc.): 12 String Horizontal Sidetrack 1 Objective: 1 Ivishak Zone 48 Formation Markers (Sperry wp04) Formation Tops MD TVD TVDss WS1 6,715' 5,601' 5,521' CM3 6,985' 5,789' 5,709' CM2 7,739' 6,265' 6,185' CM1 8,937' 7,018' 6,938' THRZ 9,407' 7,313' 7,233' LCU 9,764' 7,537' 7,457' T JG 9,808' 7,565' 7,485' T JF 10,440' 7,962' 7,882' T JE 10,628' 8,080' 8,000' T JD 11,087' 8,368' 8,288' T JC 11,370' 8,546' 8,466' T JB 11,610' 8,697' 8,617' T JA 11,719' 8,765' 8,685' TSG 11,915' 8,888' 8,808' TSHA 11,959' 8,916' 8,836' TSHB 12,021' 8,954' 8,874' TSHC 12,051' 8,972' 8,892' TSAD 12,101' 9,000' 8,920' HOT 12,225' 9,050' 8,970' TD 16,186' 9,040' 8,960' owe N/A 9,090' 9,010' TD Criteria: Based on 2500-2800' of Zone 48 with low water saturations (7+ ohms) Y -23B Permit to Drill Comments 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing \\.~ 7.0 ppg EMW 7.0 ppg EMW 7.0 ppg EMW 7.0 ppg EMW 7.0 ppg EMW 7.0 ppg EMW 7.0 ppg EMW Page 1 ') ) Directional - Sperry wp04 KOP: 16,763' MD Maximum Hole Angle: -510 in 8-1/2" hole -950 in 6-1/8" horizontal section There are no close approach issues. / The closest well to V -23B is V -25. The center to center distance is 1319'. This happens at 13,033' MD in Y-23B and at 13,418' MD in Y-25. MWD+IFR+Casandra 18,281' at top of Zone 4B Close Approach Well: Survey Program: Nearest Property Line: CasinglTubing Program Hole Size Csgrrbg O.D. WtlFt Gr,de Conn Length Top Btm ./ MDrrVD MDrrVD 8-1/2" 7" 26# L-80 BTC-M 5303' 6,613'/5,499' 11,915'/8,890' 6-1 /8" 4-1/2" -Slotted 12.6# L-80 IBT-M 4420' 11,765'/8,734' 16,186'/9,040' Tubing 4-1/2" 12.6# L-80 IBT-M 11,738' GL 11,765'/8,734' Mud Program Section Milling Mud Properties: LSND I Whip Stock Window 9 5/8" 1 Density (ppg) Viscosity PV YP 10 sec gel MBT PH API FI 9.8 40 - 60 14-18 40+ 15-20 6-8 9.0 - 9.5 8 Intermediate Mud Properties: LSND I 8-1/2" hole section 1 Density/{,g) 10-Sec Gel PV YP 10 sec gel MBT PH API FI (~ 40 - 60 12-14 15-21 15-20 6-8 9.0- 9.5 <6 Production Mud Properties: Flo-Pro 1 6-1/8" hole section 1 Density (ppg) TauO PV YP LSYP MBT pH API FI 8.3 - 8.6 3-7 7 -11 30 - 35 8-14 <6 9.0 - 9.5 4-6 Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GR- Real time Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - over entire interval, samples described Drilling: Dir/GR/Res/ABI- Real time Open Hole: None Cased Hole: None Y-23B Permit to Drill Page 2 ) ) Cement Pro~ram Casing Size I 7" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: Based on 80' shoe track and 1000' of 7" X 8-1/2" open hole with 40% excess Tail TOC: 10,915' MO I Total Cement Volume: Lead None ----; , ) Tail 35 bbls. 197 ft3.ffi9ßaCks Class G @ 15.8 PPé.~3/saCk Casing Size 14.5" 12.6#, L-80 Production Liner I Production liner will be slotted, uncemented pipe. / Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 3206 psi (7.0 ppg @ 8808' TVOss) 2325 psi (.10 psi/ft gas gradient to surface) 213 bbls with a 12.0 ppg FIT Rams test to 3,500 psi/250 psi. /' Annular test to 2,500 psi/250 psi 3500 psi surface pressure 12.0 ppg FIT after drilling 20' outside window æSi (7.0 ppg @ 8970' TVOss) 36... ·psi (.10 psi/ft gas gradient to S..Urface) ñite with 9.6ppg FIT / Rams test to 3,500 psi/250 psi. / Annular test to 2,500 psi/250 psi 3500 psi surface pressure 9.6 ppg EMW FIT 8.4 ppg Seawater /6.8 ppg ~iesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Y-23B Permit to Drill Page 3 ) Sidetrack and Complete Procedure Summary Pre-Rig Work: 1. Drift and tag liner crossover at 11,161' MD. 2. Fluid pack tubing and IA. c¡ I t.[ I 0 ~ 3. P&A the slotted and solid liner with cement from PBTD to -9900' MD. 4. Drift tubing and tag TOC. 5. Chemical cut the tubing at 7000' MD. 6. Circulate to seawater and Freeze protect. 7. Test the 9-5/8" casing pack-off and tubing hanger seals to 5000 psi for 30 minutes. Function all Lock Down Screws. 8. Remove the wellhouse. If necessary, level the pad. Please provide total well preparation cost on the handover form. Ria Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace we/II to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing from above pre-rig cut. // 5. RU e-line. Run GR/JB for 9-5/8",47# casing to top of tubing stub. 6. MU 9-5/8", 47# bridge plug on e-line with CCL. RIH and set at 6780' MD, set as needed to avoid cutting a casing collar. / 7. Pressure test casing to 3500 psi for 30 minutes. / 8. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 9. Swap over to 9.0 ppg milling fluid. / 10. Mill window in 9-5/8" casing at 6763' MD, plus 20' past middle of window. Perform FIT. POOH. 11. MU 8-1/2" drilling assembly with Dir/GR and RIH. Kick off and drill the 8-1/2" intermediate interval, building and turning at 4°11 09~ to a 510 hold angle. 12. Increase mud weight to~p prior to cutting HRZ. /' 13. Increase mud weight to 1.4 pg prior to cutting the Kingak. 14. Drill ahead to casing pOI 'Top Sag River to an estimated depth of 11,915' MD. 15. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 6,610' /. MD. Displace cement with mud. POOH. 16. MU 6-1/8" BHA with Dir/GR/Res/ABI and RIH to the landing collar. 17. Pressure test wellbore to 3500 psi for 30 minutes. ' 18. Drill shoe track. Swap over to 8.6 ppg mud and drill 20' of new formation. Perform FIT. / 19. Drill the 6-1/8" production interval building at 12°/100' to horizontal, targeting Z4B Ivishak. Drill ahead to an estimated TO of 16,186' MD /" 20. Run a 4-1/2" solid and slotted liner throughout the 6-1/8" wellbore and back into the 7" drilling liner to 11,765' MD. Release from TOL. 21. Displace well to clean seawater. // 22. Run 4-1/2", 12.6#, L-80 completion tying into the 4-1/2" liner top. 23. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 24. Set and test TWC. 25. NO BOPE. NU and test the tree to 5000 psi. 26. Freeze protect the well to -2200' and secure the well. 27. RDMO / Post-Ria Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod I RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Y-23B Permit to Drill Page 4 ') ) Y-23B Drilling Program Job 1: MIRU Hazards and Contingencies > No wells will require shut-in for the rig move onto Y-23B. However, Y-OB is -35' to the West, and Y -29 is -41' to the East. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters will be usej,at all times. > Y~Pad is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: Y -29 15ppm Y -33 30 ppm Y -30 20ppm Y -25 20 ppm The maximum level recorded of H2S on the pad was 110 ppm on Y..23A in 03/2002. þ;> Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP . ·M?m~,~~}~y,,:. ., ~,»:,~):",w..:}*,,.;,,»~y,.__~'i;~. ~J!J,M1':'»}¡»m'''~~'"~~ Job 2: De-complete Well Hazards and Contingencies > The lower section of this well should be isolated by 2 barriers - the coil sidetrack will be cemented during pre-rig operations, the production packer on the outside of the tubing and seawater to surface. Monitor the well to ensure the fluid column is static, prior to pulling the completion. > Note and record required PU weight to pull tubing at cut point. > NORM test all retrieved well head and completion equipment. > Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP ......................~.................~....... ..... ...·11:mlualm:'nwilwHlwn ·..·..·"+"u~.III:IIII::':LII'II:_~~IIIII:II..I:<III II:n_\:1:III::I:-UIIIIIII I;·:.~~",,';'¡'¡-· - Job 4: Window Mill Hazards and Contingencies > Position bridge plug to avoid cutting a casing collar while milling the window. > Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP I' '''''¡'i. _U:_ilL~'''' .~. .1. I. II. .u~ Y -23B Permit to Drill Page 5 ') ') Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies > The intermediate section will kick off in mid West Sak 1 and drill the entire Coleville, HRZ, and Kingak intervals to the top of Sag River. Previous V-Pad wells drilled the Kingak with 9.8 to 10.2ppg mud weights. For this well, due to the long tangent at 510 inclination at a 2950 azimuth, maintain mud weight at 11.4 ppg, from the top of Kingak to the 7" liner point. Follow all shale drilling practices to minimize potential problems. > There are three (3) fault crossings in the intermediate section, listed in the table below. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. There are no LCM restrictions in the intermediate hole section. Fault Formation MD Intersect TVD Intersect Est. Throw Direction #1 #2 #3 Colville HRZ Kingak (JE) 7,800' 9,625' 10,750' 6,304' 7,448' 8,168' 10-15' 30' 15-20' WNW W NW MD Uncertainty +1- 200' +1- 165' +1- 165' > There are no close approach issues while drilling the intermediate hole section. > KICK TOLERANCE:).~~the worst-case scenario of 9.6 ppg pore pressure at the Sag River depth, a fracture gradie~~f ~.O ppg at the 7 5/8" casing window, and 11.2 ppg mud in the hole, the kick tolerance i~IS. Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" ~:«»!:>t(:+I«)Ho '\- T -::II:::::::i~:_:I~_::um~:I'.::_1::!::mI::1I:~I::lIm:II:1I__~111:1:':11I- _Lt.I:I._::\II.\':m:m:::.OIlI!~I:mml:l:m+;,:,,"'!_mo~:1<: ::::....-.:·......M"..."'.~.....m.~......~~~~ Job 6: Install 7" Intermediate Liner Hazards and Contingencies > Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. > Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP ~....M.I¡U.:I....,.....,..~··:....... ~ ..-¡¡nl,l"¡·'-'T;~H-..~.¡¡~.I .1.....,;,"'.I.¡~III;,¡..;lu I.._lm·wu·llua:I,I W¡_.....I..;.;..,m..¡II; 11 ;.tll·~; I . "11...1111I; ~I.¡ 11,....111 ~u 11.1: Y-23B Permit to Drill Page 6 ) ) Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ A pump out sub will be run in the BHA to aid in placing LCM material. ~ There are four (4) fault crossings in the production section, listed below. Lost circulation is considered medium risk. Follow the lost circulation decision tree for production hole drilling. Fault Formation MD Intersect TVD Intersect Est. Throw Direction MD Uncertainty +/- 110' +/- 165' +/- 110' +/- 165' #4 Zone 4B 12,150' 9,023' 20-25 W #5 Zone 4B 12,950' 9,058' 10 SW #6 Zone 4B 14,140' 9,034' 20 SW #7 Zone 4B 14,950' 9,014' 10 SW ~ There are no close approach issues while drilling the production hole section. ~ KICK TOLERANCJ:: In the worst-case scenario of 8.8 ppg pore pressure in the Ivishak, a fracture grad!.~.fI(··óf ).6 ppg at the 7" casing window, and 8.6 ppg mud in the hole, the kick tOlerance, i.s"'I~f~. l.__..~ Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP ·,.õ~~ III~:~!!i_I__~~~~·~:: .~~_llm·~'I'.I__~:I. .n" Job 9: Install 4 Y2" Slotted Production Liner Hazards and Contingencies ~ The completion design is to run a 4 Y2", 12.6#, L-80 slotted liner throughout the production interval. Solid liner will be placed across intervals of lower resistivity / higher water saturation, as determined by the subsurface team. ~ Differential sticking is a concern. The 8.6ppg Flo-Pro will be -600psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4 Y2" liner will need to be run to extend -150' back up into the 5 1/2" intermediate liner. '_'ILI_r~illlI".m o}'-'''lrWlt: .L:::-IIT-rll:=W·:;;"'ILII~·.lLIal,'.I._r· '-~H ~--;;;;~'II__:I_I_ ,,<':"''<:1'.:1111.'. _~':'Imw-_...'" Ilr:l: I::I_:_.:__~I~···'!'I::oM__I_ _t'I~:X·:,,---~"····"·"~ :I!I. ..._ Y-23B Permit to Drill Page 7 -) ) Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP ¡;;:.;.a,~~II:,~,II,aacc.rl'll.m,W,'IC~,I~_.~,~I,;~,_I:"""""""·:':~··Y~~·~~·' ~--, ....'1"":::::~.::;;:;;;;~,.. _IC.:::::,:::::,~,II:,m:,!_:1 Ilmllmlml~llm::II,I,II;~~,I,I',III::LM:,I:llc:m:m,m\:.a:clllm,D\laa:::lC::I,"IIIUI,:,II,II,r:,la:H:C:-;II,mcm:,IIIC Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No wells will require shut-in for the rig move off of Y-238. However, V-DB is -35' to the West, and V-29 is -41' to the East. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP V-238 Permit to Drill Page 8 ) ) Y-23B Well Summary of Drillina Hazards / POST THIS NOTICE IN THE DOGHOUSE Intermediate Hole Section: · There are no close approach issues. · Differential sticking has been experienced in the past. Keep pipe moving at all times. · There are three (3) fault crossings expected in the intermediate hole section. · Lost circulation while drilling the intermediate hole has not been problematic at Y-Pad. In the event of lost circulation, consult the LCM Decision Tree. · The intermediate hole section will be drilled with a recommended mud weight of 11.4 ppg to ensure shale stability in the Kingak. · Kick tolerance is 213 bbls with a 12.0 ppg FIT. Production Hole Section: · There are four (4) fault crossings expected in the production hole section. · Lost circulation risk is medium. Use LCM Decision Tree in the event of losses. · Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. . Kick tolerance is Infinite. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULI3HJE)- H2S · This drill-sit~/hotA"t esignated as an H2S drill site. Recent tests indicate a very low ~~ntration of H2S. As a precaution, Standard Operating Procedures for- H2S precautions should be followed at all times. CONSULT THE Y-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Y-23B Permit to Drill Page 9 ) TREE = Wa.LHEAD = A CflJl\ TOR = Kï3. ï~LEV''; .. i3F~ ËLEV''';" KOP= ,""... ................ , ...."., ,~~~~~1eI = Datum MD = DatumlVD = 4"C~ tvCEVOY AXELSON .. ·ää.fW' 37.& 1600' .."..,.. ...... . .... . ,.~ (ë).~~.5?~' 11323' 8800' SS Y-23A /. l- SAFETY f\OlES: CI-ROMETBG. WELL EXCEB:>S 700@ 11300' AN) GOES HORIZONTAL@ 11526'. " I 2198' H4-1/2" OTISSSSV LAN)ING NIP, ID =3.813" I 113-3/8 CSG, 72#, L80-BTRS, ID= 12.347" H 281T rJ ~ Minimum D = 2.37" @ 11161' 3-3/16" X 2-7/8" XO L ST rvÐ lVD 6 3203 2904 5 5782 4832 4 7598 6152 3 8762 7023 2 9456 7573 1 9915 7929 GAS LIFT MANtRa.s DEV TYPE V L V LATCH FORT DATE 43 C'AtvCO RK 1/4" 07/01/01 42 C'A tvCO RK 20/64" 07/01/01 43 C'A tvCO RK DV 03/18/01 39 C'AtvCO RK DV 03/18/01 37 C'AtvCO RK DV 03/18/01 43 C'AtvCO RK DV 03/18/01 z I I 9942' H4-1/2" PARKERSWS NIP, ID = 3.813" 1 :8: ----1 9950' H 9-5/8" x 4-1/2" OTB M-iR PKR, ID = 3.85" I I 10010' H4-1/2" PARKERSWS NIP, ID = 3.813" I U I 10022' H 3-3/4" BKR DEROY SL V, ID = 3.00" 1 I 10027' H3-1/2" X3-3f16" XO, ID=2.80" I II I H4-1/2" PARKERSWN NIP, ID = 3.725" I I 10059' 10072' H4-1/2 PKR WLEG, D = 3.958" 1 10072' H ELMDrr - LOGGED 01/1 0192 I ITOPOF7" LlI'ER H 10053' I 01 4-1/2" TBG, 12.6#, 13Cr- TOO, .0152 bpf, ID = 3.958"1~ 10072' 1 19-5/8" CSG, 47#, L80-BTRS, ID = 8.681" l-i 10330' µ ~ 7" MLLOUT WINDOW 11124'-11130' ÆRFORA TON SUM\IIARY REF LOG: INTED GRlRESIST 06122/01 ANGLE AT TOP PERF: 83 @ 11368' Note: Refer to Production DB for historical perf data SIZE SIT INTffiVAL Opn/Sqz DA lE 2-718" SLTD 11368- 11748 0 06/24/01 I 11161' H3-3f16"X2-7/8"XO,ID=2.37" I ~~ 1 11368' HTOPOF2-7/8"SLTDLNR,ID=2.37" 1 ~ "'J 1 11748' HPBTD (PAO<OFF BUSHING), ID = 125" .....:.........., , ~ ' '..... .......... .......... ..... ..... ....., ..... ..... ...... 11781' I 17" LI\R, 26#, L80- TeA5, .0382 bpf, ID= 6.276" H 11650' I ~. . 12-7/8"SLTDLNR, 6.16#, L-80 STL. .0058bpf,ID= 2.37" H 11748' I DAlE FßfBY OOM\llENTS [)ð.lE FßfBY COMrÆNTS FRLDHOE SAY UNT 06124/86 ORlGINð. L COMR.ETION 05'17/01 JM/TH CMT PLl.X3 Wa.L: Y -23A 12/27/91 RKH POST RWO OO~ETION 07/21/01 CHlTP OORRECfIONS PERMIT No: 201-028 06124/01 CTD SIDETRACK 08/12/01 PCRIKA K REMOV E C8v1ENTB:> PERFS A PI No: 50-029-21590-01 01/15'01 SIS-rvÐ INITIAL RB:>RA W 08/16101 GC/KA K PERF CORROC11Qf\S 137Z SI'l. & 24' WEL, Sec. 33, 1N 11N, RGE 13E 05'16101 RNIlP CORRECTIOf\S BP Exploration (Alaska) / ~"'" 19-5/8" Whipstock - 6763'1-- ~ , I I 19-5/8" CIBP - 6780' r-- . CUT 7000' I ~ I y 14-1/2" X Nipple - 2200'1 L-80 IBT, ID 3,958" I ITop of 7",26# Liner - 6613' 19-5/8" X 4-112" Packer - 9,950'1 ITop of 3-3/16" Liner - 10,022' 7" LINER I LBO-8TRS, 10 8,681" 10330' ÆRFORA TION SUMMARY LOG: !NTEQ GRJRESIST 06/22/01 ANGLE AT TOP PERF: to Production DB for INTERVAL Opn/Sqz 11368 - 11748 saz data DATE 06/25/05 ,0382 DATE REV OOMMEl'ifS ORIGINAL COMPLETION RWO cm SIDETRACK PGS Proposed Sidetrack B Proposed Co letion .. GLM Design: #6 - ' TVD - 4-1/2" X 1-1/2" - SV #5 -' TVD - 4-1/2" X 1-1/2" - SV #4 - ' TYD - 4-1/2" X 1-1/2" - SY #3 - ' TVD - 4-1/2" X 1-1/2" - DY #2 - ' TVD - 4-1/2" X 1-1/2" -DV #1 - ' TVD - 4-1/2" X 1" -DY Tul:,)ing T?il: -10' Pup Joint -KNipple (3.813") -10' Pup Joint -Packer Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG 17" X 4-1/2" $-3 Packer - 11,716' I 14-1/2" Liner Hanger/ZXP -11,766' I 17",26# Uner-11,91S' -------------n __________......___lJ I Solid and Slotted 4-1/2" Liner - 16,186'1 4 I 11161' X 2-7/8" XO, 10 2,37" I 11781' I COMMENTS OA TE REV BY UNIT No: 201-028 API No: 50-029-21590-02 1372' SNl 8. 24' WEL, TN BP e e SOHJO ALASKA PETROLfUH COMPANY WELLHEAD LOCATION DATA 1) WELL Y-23 2) Pad Y( 33-11-13) --ll (A-J ~{? C x s; 644791 y s; 5948883 ç'.2c--33' . 3) Wellhead Location 1372' SNL. 24' WEL LAT. 70°-16'-03.97" LON G. 14 8 ° - 4 9 ' - 4 4 . 87 " 4) Bearing.of Gyro Marker 5) Local Benchmark Elevation' 6) Top Edge of Cellar * 7) Base Flange Elevation 8) Kelly Bushing Elevation ~ Base Flange and Kelly Bushing NOT Installed This Date. SW CUR . (True) . 50.05 Ft. AMSL 49.91 Ft. AMSL 51.61 Ft. AMSL 88.81 Ft. AMSL Y-3 NOTES: \ " 1) Items 1 and 2 should be filled in by the Drilling Supervisor on the rig when a new well spuds in. 2) The surveyor should fill in Items 3. ~. 5 and 6. 3) 4) 5) The cOQpleted form should be returned to Drilling Dept. for distribution. The bearing of the Gyro ~~rker is required as a True. not a ~~gnetic bearing. District Field Engineer - 2 District Drilling f.nginccr/Dailling Engineer - 1 Slope - to ~ig for Posting - 2 ~ell Record Clerk. r.eology - 1 Yell files Engineering ^s~ociate. Drilling - Original Petroleum Engin~ering. SFO -) [Uen H. ¡.:i11er Elevations measured by the Drilling Supervisor. ......"" ...... OF A¿ "~ ...~~......... 4n.... ;A..."i~... '*...':1-~. '''''"49TH .."'9.. -*: - ..* f"· ..t;1... ..;-p,.. .... ~ ....: ,.. ..... i-š'1.1..:..._ ,-a. GA L M~;l . ~." . ~ -.. LS· 5121." j'. . ~ -. ..- e,t- ' .~~Å.........· ~~v~1T -, ~essi0n3\ \.'8.. . ",-......... Base Flang~ and telly Bushing CIR(ULATJ01:: February 3, 1986 . nata " ~ c ~ .s 0. ¿s " " 1:: " - ::; 8100- 2 f-< COMPANY OCT AILS REFERENCE INFORMATION BP Amoco C.akulation Method: Minimum Curvature Error Sysœm: ISCWSA Scan Method: Trav Cylinder North En'öJ.' Surface: Elliptical + Casing Wamin~ Method: Rules Based FORMATION TOP DETAILS No. TVDPath MDPath Formation I 560!.l1 671451 WSI 2 5789.11 698454 CM3 3 6265.11 7738.69 CM2 4 7018.1 I 8937.47 CM1 5 7313.11 9407.12 THRZ 6 7537.11 9763.73 LCU 7 7565. II 9808.3 1 TJG 8 7962. II 10440.34 TJF 9 8080.11 10628.20 DE 10 8368.11 1 1086.70 TJD lJ 8546.11 11370.08 TIC 12 8697.11 11610.47 TJB 13 8765.11 lJ718.73 TJA 14 8888.11 lJ914.55 TSGR 15 8916.1 I lJ 959.2 1 TSHA 16 8954. II 12021.04 TSHE 17 8972. II 12050.86 TSHC 18 9000.11 12100.73 TSAD 19 9050. II 12224.49 HOT 5400- , ,.:.. WSl SM Dir 12/100': 6763' MD. 5636. 18'TVD 8M Dir4/100' : 6783' MD. 5650.5'TVD EndDir : 7lJO.79'MD.5870.71'TVD 6300 9000- 9900- SURVEY PROGRAM Depth Pm Depth To Survey/Plan 6763.00 1618626 Planned: Y~23B wp04 V7 Plan: Y ~23B wpM (Y ·23!PJan Y H23B) Tool MWD+JFR+MS Created By: Ken Allen Che-cked: Date: 9/1112003 Date Dat~;~ Reviewed: WELL DETAILS Name +N/-S <f.Ef·W Not1hing Eastffig Lalilwk Loogíiude Slot Y-23 399.85 ·2950,60 59488ID.32 64479L01 70"16'03H68N J48"49'44JV6W 23 TARGET DETAILS ,..,~ TVD +N/-8 +E!·W Northing Easting Shape Pcint Polygon Po,," fuìnt Point Pcint Point Po,," SECTION DETAILS See MD Ine Azi TVD +N/-S +EJ-W DLeg TFace VSec Target I 6763.00 43.81 314.03 5636.18 209!.l3 -2366.56 J 0.00 0.00 3019.62 2 6783.00 44.80 310.90 5650.50 2100.56 -2376.86 12.00 -66.80 3032.90 3 7IIO.79 51.09 295.36 5870.71 2231.36 -2580.27 4.00 -66.80 3272.20 4 11914.55 51.09 295.36 8888. 1 1 3832.26 -5957.92 0.00 0.00 7009.55 Y-23B TSGR 5 1 1934.55 51.09 295.36 8900.67 3838.92 -5971.98 0.00 0.00 7025.11 6 12022.75 52.88 282.1I 8955.14 3861.06 -6037.56 12.00 -84.40 7093.97 7 12050.93 52.88 282.1I 8972.15 3865.77 -6059.53 0.00 0.00 7115.92 8 12363.87 90.00 275.96 9070.11 3909.77 -6347.53 12.00 -10.12 7396.33 ¥-23B Land 9 12363.88 90.00 275.96 9070.11 3909.77 -6347.53 12.00 89.88 7396.33 10 12607.79 90.00 275.96 9070. lJ 3935.10 -6590.13 0.00 0.00 7627.67 11 12611.78 90.00 276.12 9070. II 3935.52 -6594.10 4.00 90.00 7631.46 ¥-23B flat 12 12667.89 92.24 276.12 9069.01 3941.50 -6649.87 4.00 -0.03 7684.71 13 13757.74 92.24 276.12 9026.34 4057.58 -7732.68 0.00 0.00 8718.55 14 13820.32 90.00 275.01 9025.11 4063.65 -7794.95 4.00 -153.69 8777.74 ¥ -23B T2 15 13861.65 88.35 275.01 9025.71 4067.26 -7836.12 4.00 179.92 8816.72 16 14478.64 88.35 275.01 9043.51 4121.14 ·8450.49 0.00 0.00 9398.35 17 14597.56 93.00 276.00 9042.11 4132.55 -8568.82 4.00 11.98 9510.80 Y-22A T4 18 14736.55 94.83 281.26 9032.6 1 4153.34 -8705.86 4.00 70.58 9644.17 19 15110.73 94.83 281.26 900 1.08 4226.15 -9071.53 0.00 0.00 10007.20 20 15370.53 90.00 290.47 8990.11 4297.05 -9320.86 4.00 11 7.46 10263.52 ¥ -22A T5 21 15463.71 86.27 290.47 8993.14 4329.62 -9408.09 4.00 -180.00 10356.41 22 16186.26 86.27 290.47 9040.11 4581.80 -10083.58 0.00 0.00 1l075.71 ¥-22A T6 CASING DETAILS No. TVD MD Name Size 8888. II 9040. II 11914.55 7" 16186.25 41/2" 7.000 4.500 Start Dir 12/100' : 11934.55' MD, 89OQ.67'TVD End Dir : 12022.75' MD, 8955.14' TVD 8M Dir 12/lúO': 12050.93' MD, 8972.151'VD EndDir: 12363.88'MD,9070.1l'TVD Start Dir4/100': 12607.79' MD, 9010.1l'TVD End Dir : 12667.89' MD, 9069.01' TVD Srart D1r4/10û': 13751.74' MD, 9026.34'TVD End Dir : 13861.65' MD, 9025.11' TVD Total Depth: 16186.26' MD, 9040.1l'TVD ~J Y-23Bwp04 t ! ¡ ! I ! I r ¡ I I j ¡ ¡ ! j 7200 Vertical Section at 294.44' [900ft/in] , I 1170C L--oMPANY DETAILS Bf> Amoco MmÌt11llm Curvature ISCWSA ThwCyiìnderNorth Elliptica1 + Casing Rules 8æJed REFERENCE [NFORM.... TION FORMATION TOP DETAILS No. TVDPath MDPath Formation I 5601.11 6714.51 WSl 2 5789.11 6984.54 CM3 3 6265.il 7738.69 CM2 4 7018.11 8937.47 CMl 5 7313.11 9407.12 THRZ 6 7537.11 9763.73 LCU 7 7565.11 9808.31 TJG 8 7962.11 10440.34 TJF 9 8080.11 10628.20 TJE 10 8368.11 11086.70 TJD II 8546.11 11370.08 TJC 12 8697.il 11610.47 TJB 13 8765.11 11718.73 TJA 14 8888.11 11914.55 TSGR 15 8916.11 11959.21 TSHA 16 8954.11 12021.04 TSHB 17 8972.11 12050.86 TSHC 18 9000.11 12100.73 TSAD 19 9050.11 12224.49 HOT CASING DETAILS No. TVD MD Name Size 8888.11 11914.55 7" 7.000 9040.11 16186.25 4112" 4.500 Total Depth: 16186.26' MD, 9040.11' TVD EndDir: 15463.71'MD,8993.14'TVD Start Di, 41100' : 15110.73' MD, 9001.08'TVD End Dir : 14736.55' MD, 9032.61' TVD Start Dir41100': 14478.64' MD, 9043.51'TVD 540(}- " ;j3 8 ~ +' ~ " z 7- ::á g '" 1800 SURVEY PROGRAM Depth Fm Depth To SurveyiPltm 6763.00 16186.26 Planned: Y -23B wp04 V7 Pian: Y M23B wp04 (YM23/Plan Y M23B) Tool MWD+lFR+MS Created By: Ken Allen Date: 9/J7/2003 Checked: Date Reviewed: Date WELL DETAILS Name +NI..s +EI·W Northing Eastìr¡g ùtrimœ Longiiwk- Slot Y~23 399.85 -2950.60 594888332 64419LOT7G¢!6'U3.%$N 148"49'44.87ôW23 TARGET DETAILS N"", SECTION DETAILS See MD Inc Azi TVD +NI-S +EI-W DLeg TFee. VSee Target 1 6763.00 43.81 314.03 5636.18 209 l.l 3 -2366.56 0.00 0.00 3019.62 2 6783.00 44.80 310.90 5650.50 2100.56 -2376.86 12.00 -66.80 3032.90 3 7ilO.79 51.09 295.36 5870.71 2231.36 -2580.27 4.00 -66.80 3272.20 4 11914.55 51.09 295.36 8888.11 3832.26 -5957.92 0.00 0.00 7009.55 ¥-23B TSGR 5 11934.55 51.09 295.36 8900.67 3838.92 -5971.98 0.00 0.00 7025.11 6 12022.75 52.88 282.11 8955.14 3861.06 -6037.56 12.00 -84.40 7093.97 7 12050.93 52.88 282.il 8972.15 3865.77 .6059.53 0.00 0.00 7115.92 8 12363.87 90.00 275.96 9070.11 3909.77 -6347.53 12.00 -10.12 7396.33 ¥-23B Land 9 12363.88 90.00 275.96 9070.11 3909.77 -6347.53 12.00 89.88 7396.33 10 12607.79 90.00 275.96 9070.11 3935.10 -6590.13 0.00 0.00 7627.67 11 12611.78 90.00 276.12 9070.11 3935.52 -6594.10 4.00 90.00 7631.46 ¥ -23B flat 12 12667.89 92.24 276.12 9069.01 3941.50 -6649.87 4.00 -0.03 7684.71 13 13757.74 92.24 276.12 9026.34 4057.58 .7732.68 0.00 0.00 8718.55 14 13820.32 90.00 275.01 9025.11 4063.65 -7794,95 4.00 ~ 153.69 8777.74 ¥-23B T2 15 13861.65 88.35 275.01 9025.71 4067.26 -7836.12 4.00 179.92 8816.72 16 14478.64 88.35 275.01 9043.51 4121.14 -8450.49 0.00 0.00 9398.35 17 14597.56 93.00 276.00 9042.11 4132.55 ·8568.82 4.00 11.98 9510.80 ¥-22A T4 18 14736.55 94.83 281.26 9032.61 4153.34 "8705.86 4.00 70.58 9644.17 19 15110.73 94.83 281.26 9001.08 4226.15 -9071.53 0.00 0.00 10007.20 20 15370.53 90.00 290.47 8990.11 4297.05 -9320.86 4.00 117.46 10263.52 Y-22A T5 21 15463.71 86.27 290.47 8993.14 4329,62 -9408.09 4.00 -180.00 10356.41 22 16186.26 86.27 290.47 9040.11 4581.80 -10083.58 0.00 0.00 11075.71 Y-22A T6 Y.23 (¥-23A) ¥-23 (Y-23) I 1 I~OO 9000 ~OO If 6000 ~ '<5"00 r§' ;A~ e Site: PB Y Pad Well: Y-23 Wellpath: Plan Y-23B Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB Y Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft BP KW A Planning Report Method: Map Zone: Coordinate System: Geomagnetic Model: 5948541.48 ft 647748.73 ft Latitude: 70 16 Longitude: 148 48 North Rèference: Grid Convergence: Well: Y-23 Slot Name: Y-23 Well Position: +N/-S 399.85 ft Northing: 5948883.32 ft Latitude: +EI-W -2950.60 ft Easting: 644791.07 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan Y-23B Current Datum: 80.11' Magnetic Data: 2/18/2003 Field Strength: 57532 nT Vertical Section: Depth From (TVD) ft 31.11 Plan: Y-23B wp04 Principal: Yes Casing Points 11914.55 8888.11 7.000 16186.25 9040.11 4.500 Formations 6714.51 5601.11 WS1 6984.54 5789.11 CM3 7738.69 6265.11 CM2 8937.47 7018.11 CM1 9407.12 7313.11 THRZ 9763.73 7537.11 LeU 9808.31 7565.11 TJG 10440.34 7962.11 TJF 10628.20 8080.11 TJE 11086.70 8368.11 TJD 11370.08 8546.11 TJC 11610.47 8697.11 TJB 11718.73 8765.11 TJA 11914.55 8888.11 TSGR 11959.21 8916.11 TSHA 12021.04 8954.11 TSHB 12050.86 8972.11 TSHC 12100.73 9000.11 TSAD 12224.49 9050.11 HOT 8.500 7" 6.125 41/2" Height 80.11 ft Drilled From: Tie-on Depth: Above System Datum: DecUnation: Mag Dip Angle: +EI-W ft 0.00 +N/-S ft 0.00 Date Composed: Version: Tied-to: e 80.11' Well (0.00N,O.00E,294.44Azi) Minimum Curvature Db: Oracle Alaska, Zone 4 Well Centre bggm2003 0.041 N 18.991 W True 1.12 deg 23 70 16 3.968 N 148 49 44.876 W Y-23APB2 6763.00 ft Mean Sea Level 25.87 deg 80.79 deg Direction deg 294.44 2/19/2003 7 From: Definitive Path 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 e BP KW A Planning Report e ! WelIpath: Plan Y-23B Survey Oracle Targets Map Map <- Latitude --> <- Longitude --> Name Description TVD +N/-S +E/-W Northing Eastlng Deg Mln Sec Deg Mln See Dip. Dir. ft ft ft ft ft Y-23B TSGR 8888.11 3832.26 -5957.92 5952599.98 638761.00 70 1641.635 N 148 52 38.383 W Y -23B Poly 8888.11 3979.64 -5768.04 5952750.98 638948.00 70 1643.086 N 148 52 32.856 W -Polygon 1 8888.11 3979.64 -5768.04 5952750.98 638948.00 70 16 43.086 N 148 52 32.856 W -Polygon 2 8888.11 4180.99 -6511.36 5952937.98 638201.00 70 16 45.060 N 148 52 54.509 W -Polygon 3 8888.11 4197.23 -7355.26 5952937.98 637357.00 70 16 45.212 N 148 53 19.087 W -Polygon 4 8888.11 4305.27 -8915.59 5953015.98 635795.00 70 16 46.258 N 148 54 4.533 W -Polygon 5 8888.11 4732.21 -10154.71 5953418.98 634548.00 70 16 50.442 N 148 54 40.638 W -Polygon 6 8888.11 4517.18 -10207.86 5953202.98 634499.00 70 1648.326 N 148 54 42.177 W -Polygon 7 8888.11 4030.86 -8949.88 5952740.98 635766.00 70 1643.559 N 148 54 5.522 W -Polygon 8 8888.11 3825.51 -6439.17 5952583.98 638280.00 70 1641.565 N 148 5252.398 W -Polygon 9 8888.11 3659.47 -5971.25 5952426.98 638751.00 70 16 39.935 N 148 52 38.767 W -Polygon 10 8888.11 3725.44 -5812.94 5952495.98 638908.00 70 1640.586 N 148 52 34.158 W Y-22A T5 8990.11 4297.05 -9320.86 5952999.98 635390.00 70 1646.173 N 148 54 16.336 W Y-23B T2 9025.11 4063.65 -7794.95 5952795.98 636920.00 70 16 43.894 N 148 53 31.888 W Y-22A T6 9040.11 4581.80 -10083.58 5953269.98 634622.00 70 1648.963 N 148 54 38.560 W Y-22A T4 9042.11 4132.55 -8568.82 5952849.98 636145.00 70 1644.564 N 148 53 54.428 W Y-23B Land 9070.11 3909.77 -6347.53 5952669.98 638370.00 70 16 42.394 N 148 52 49.731 W Y-23B flat 9070.11 3935.52 -6594.10 5952690.98 638123.00 70 16 42.645 N 148 5256.912 W Plan Section Information MD Iuel +N/-S »"'$ ft deg ft de9.(1.()Q'ft 6763.00 43.81 314.03 5636.18 2091.13 -2366.56 0.00 0.00 0.00 0.00 6783.00 44.80 310.90 5650.50 2100.56 -2376.86 12.00 4.94 -15.66 -66.80 7110.79 51.09 295.36 5870.71 2231.36 -2580.27 4.00 1.92 -4.74 -66.80 11914.55 51.09 295.36 8888.11 3832.26 -5957.92 0.00 0.00 0.00 0.00 Y-23B TSGR 11934.55 51.09 295.36 8900.67 3838.92 -5971.98 0.00 0.00 0.00 0.00 12022.75 52.88 282.11 8955.14 3861.06 -6037.56 12.00 2.03 -15.03 -84.40 12050.93 52.88 282.11 8972.15 3865.77 -6059.53 0.00 0.00 0.00 0.00 12363.87 90.00 275.96 9070.11 3909.77 -6347.53 12.00 11.86 -1.96 -10.12 Y-23B Land 12363.88 90.00 275.96 9070.11 3909.77 -6347.53 12.00 0.02 12.00 89.88 12607.79 90.00 275.96 9070.11 3935.10 -6590.13 0.00 0.00 0.00 0.00 12611.78 90.00 276.12 9070.11 3935.52 -6594.10 4.00 0.00 4.00 90.00 Y-23B flat 12667.89 92.24 276.12 9069.01 3941.50 -6649.87 4.00 4.00 0.00 -0.03 13757.74 92.24 276.12 9026.34 4057.58 -7732.68 0.00 0.00 0.00 0.00 13820.32 90.00 275.01 9025.11 4063.65 -7794.95 4.00 -3.59 -1.77 -153.69 Y-23B T2 13861.65 88.35 275.01 9025.71 4067.26 -7836.12 4.00 -4.00 0.01 179.92 14478.64 88.35 275.01 9043.51 4121.14 -8450.49 0.00 0.00 0.00 0.00 14597.56 93.00 276.00 9042.11 4132.55 -8568.82 4.00 3.91 0.83 11.98 Y-22A T4 14736.55 94.83 281.26 9032.61 4153.34 -8705.86 4.00 1.32 3.79 70.58 15110.73 94.83 281.26 9001.08 4226.15 -9071.53 0.00 0.00 0.00 0.00 15370.53 90.00 290.47 8990.11 4297.05 -9320.86 4.00 -1.86 3.55 117.46 Y-22A T5 15463.71 86.27 290.47 8993.14 4329.62 -9408.09 4.00 -4.00 0.00 -180.00 16186.26 86.27 290.47 9040.11 4581.80 -10083.58 0.00 0.00 0.00 0.00 Y-22A T6 e BP e KW A Planning Report Date: 9/1712003 Time: 14:24:52 Page: 3 Co-ordlnate(NE) Reference: Well: Y-23, True North Vertical (TVD) Reference: 80.11' 80.1 Section (VS) Reference: Well (0.OON,O.00E,294.44Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Survey Ind deg 6714.51 43.53 314.09 5601.11 5521.00 5950905.57 642409.41 2988.09 0.00 0.00 WS1 6763.00 43.81 314.03 5636.18 5556.07 5950928.39 642384.91 3019.62 0.58 351.70 MWD+IFR+MS 6775.00 44.39 312.14 5644.80 5564.69 5950933.97 642378.71 3027.53 12.00 293.20 MWD+IFR+MS 6783.00 44.80 310.90 5650.50 5570.39 5950937.61 642374.43 3032.90 12.00 294.56 MWD+IFR+MS 6800.00 45.07 310.02 5662.53 5582.42 5950945.23 642365.15 3044.44 4.00 293.20 MWD+IFR+MS 6900.00 46.80 305.00 5732.10 5651.99 5950987.80 642307.33 3114.40 4.00 293.83 MWD+IFR+MS 6984.54 48.42 300.98 5789.11 5709.00 5951020.74 642254.33 3176.12 4.00 297.32 CM3 7000.00 48.73 300.27 5799.34 5719.23 5951026.45 642244.24 3187.64 4.00 300.03 MWD+IFR+MS 7100.00 50.85 295.82 5863.91 5783.80 5951061.00 642176.18 3263.82 4.00 300.50 MWD+IFR+MS 7110.79 51.09 295.36 5870.71 5790.60 5951064.47 642168.56 3272.20 4.00 303.37 MWD+IFR+MS 7200.00 51.09 295.36 5926.74 5846.63 5951092.99 642105.27 3341.61 0.00 0.00 MWD+IFR+MS 7300.00 51.09 295.36 5989.56 5909.45 5951124.95 642034.34 3419.41 0.00 0.00 MWD+IFR+MS 7400.00 51.09 295.36 6052.37 5972.26 5951156.92 641963.40 3497.21 0.00 0.00 MWD+IFR+MS 7500.00 51.09 295.36 6115.18 6035.07 5951188.88 641892.47 3575.01 0.00 0.00 MWD+IFR+MS 7600.00 51.09 295.36 6178.00 6097.89 5951220.84 641821.53 3652.81 0.00 0.00 MWD+IFR+MS 7700.00 51.09 295.36 6240.81 6160.70 5951252.81 641750.60 3730.61 0.00 0.00 MWD+IFR+MS 7738.69 51.09 295.36 6265.11 6185.00 5951265.18 641723.16 3760.71 0.00 0.00 CM2 7800.00 51.09 295.36 6303.62 6223.51 5951284.77 641679.66 3808.41 0.00 0.00 MWD+IFR+MS 7900.00 51.09 295.36 6366.44 6286.33 5951316.74 641608.73 3886.21 0.00 0.00 MWD+IFR+MS 8000.00 51.09 295.36 6429.25 6349.14 5951348.70 641537.79 3964.01 0.00 0.00 MWD+IFR+MS 8100.00 51.09 295.36 6492.06 6411.95 5951380.67 641466.86 4041.81 0.00 0.00 MWD+IFR+MS 8200.00 51.09 295.36 6554.88 6474.77 5951412.63 641395.92 4119.61 0.00 0.00 MWD+IFR+MS 8300.00 51.09 295.36 6617.69 6537.58 5951444.60 641324.99 4197.42 0.00 0.00 MWD+IFR+MS 8400.00 51.09 295.36 6680.50 6600.39 5951476.56 641254.05 4275.22 0.00 0.00 MWD+IFR+MS 8500.00 51.09 295.36 6743.32 6663.21 5951508.53 641183.12 4353.02 0.00 0.00 MWD+IFR+MS 8600.00 51.09 295.36 6806.13 6726.02 5951540.49 641112.18 4430.82 0.00 0.00 MWD+IFR+MS 8700.00 51.09 295.36 6868.94 6788.83 5951572.46 641041.25 4508.62 0.00 0.00 MWD+IFR+MS 8800.00 51.09 295.36 6931.76 6851.65 5951604.42 640970.31 4586.42 0.00 0.00 MWD+IFR+MS 8900.00 51.09 295.36 6994.57 6914.46 5951636.39 640899.38 4664.22 0.00 0.00 MWD+IFR+MS 8937.47 51.09 295.36 7018.11 6938.00 5951648.37 640872.79 4693.37 0.00 0.00 CM1 9000.00 51.09 295.36 7057.38 6977.27 5951668.35 640828.44 4742.02 0.00 0.00 MWD+IFR+MS 9100.00 51.09 295.36 7120.20 7040.09 5951700.32 640757.51 4819.82 0.00 0.00 MWD+IFR+MS 9200.00 51.09 295.36 7183.01 7102.90 5951732.28 640686.57 4897.62 0.00 0.00 MWD+IFR+MS 9300.00 51.09 295.36 7245.82 7165.71 5951764.25 640615.63 4975.42 0.00 0.00 MWD+IFR+MS 9400.00 51.09 295.36 7308.64 7228.53 5951796.21 640544.70 5053.22 0.00 0.00 MWD+IFR+MS 9407.12 51.09 295.36 7313.11 7233.00 5951798.49 640539.65 5058.76 0.00 0.00 THRZ 9500.00 51.09 295.36 7371.45 7291.34 5951828.18 640473.76 5131.02 0.00 0.00 MWD+IFR+MS 9600.00 51.09 295.36 7434.26 7354.15 5951860.14 640402.83 5208.82 0.00 0.00 MWD+IFR+MS 9700.00 51.09 295.36 7497.08 7416.97 5951892.11 640331.89 5286.62 0.00 0.00 MWD+IFR+MS 9763.73 51.09 295.36 7537.11 7457.00 5951912.48 640286.69 5336.21 0.00 0.00 LCU 9800.00 51.09 295.36 7559.89 7479.78 5951924.07 640260.96 5364.42 0.00 0.00 MWD+IFR+MS 9808.31 51.09 295.36 7565.11 7485.00 5951926.73 640255.06 5370.89 0.00 0.00 TJG 9900.00 51.09 295.36 7622.70 7542.59 5951956.04 640190.02 5442.22 0.00 0.00 MWD+IFR+MS 10000.00 51.09 295.36 7685.52 7605.41 5951988.00 640119.09 5520.02 0.00 0.00 MWD+IFR+MS 10100.00 51.09 295.36 7748.33 7668.22 5952019.97 640048.15 5597.82 0.00 0.00 MWD+IFR+MS 10200.00 51.09 295.36 7811.14 7731.03 5952051.93 639977.22 5675.62 0.00 0.00 MWD+IFR+MS 10300.00 51.09 295.36 7873.96 7793.85 5952083.90 639906.28 5753.42 0.00 0.00 MWD+IFR+MS 10400.00 51.09 295.36 7936.77 7856.66 5952115.86 639835.35 5831.22 0.00 0.00 MWD+IFR+MS 10440.34 51.09 295.36 7962.11 7882.00 5952128.76 639806.73 5862.61 0.00 0.00 TJF 10500.00 51.09 295.36 7999.58 7919.47 5952147.83 639764.41 5909.03 0.00 0.00 MWD+IFR+MS 10600.00 51.09 295.36 8062.40 7982.29 5952179.79 639693.48 5986.83 0.00 0.00 MWD+IFR+MS 10628.20 51.09 295.36 8080.11 8000.00 5952188.80 639673.47 6008.76 0.00 0.00 TJE 10700.00 51.09 295.36 8125.21 8045.10 5952211.76 639622.54 6064.63 0.00 0.00 MWD+IFR+MS e BP e KW A Planning Report Pate: ·.··.·9/17/2003 Time: Co-ordinate(NE) Reference: Well: Vertical (TVD) Reference: 80.11' Section (VS) Reference: Well (0.00N,O.00E,294.44Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Survey 10800.00 51.09 295.36 8188.02 8107.91 5952243.72 639551.61 6142.43 0.00 0.00 MWD+IFR+MS 10900.00 51.09 295.36 8250.84 8170.73 5952275.69 639480.67 6220.23 0.00 0.00 MWD+IFR+MS 11000.00 51.09 295.36 8313.65 8233.54 5952307.65 639409.74 6298.03 0.00 0.00 MWD+IFR+MS 11086.70 51.09 295.36 8368.11 8288.00 5952335.36 639348.24 6365.48 0.00 0.00 TJD 11100.00 51.09 295.36 8376.46 8296.35 5952339.62 639338.80 6375.83 0.00 0.00 MWD+IFR+MS 11200.00 51.09 295.36 8439.28 8359.17 5952371.58 639267.87 6453.63 0.00 0.00 MWD+IFR+MS 11300.00 51.09 295.36 8502.09 8421.98 5952403.54 639196.93 6531.43 0.00 0.00 MWD+IFR+MS 11370.08 51.09 295.36 8546.11 8466.00 5952425.95 639147.22 6585.95 0.00 0.00 TJC 11400.00 51.09 295.36 8564.90 8484.79 5952435.51 639125.99 6609.23 0.00 0.00 MWD+IFR+MS 11500.00 51.09 295.36 8627.72 8547.61 5952467.47 639055.06 6687.03 0.00 0.00 MWD+IFR+MS 11600.00 51.09 295.36 8690.53 8610.42 5952499.44 638984.12 6764.83 0.00 0.00 MWD+IFR+MS 11610.47 51.09 295.36 8697.11 8617.00 5952502.79 638976.70 6772.98 0.00 0.00 TJB 11700.00 51.09 295.36 8753.34 8673.23 5952531.40 638913.19 6842.63 0.00 0.00 MWD+IFR+MS 11718.73 51.09 295.36 8765.11 8685.00 5952537.39 638899.90 6857.20 0.00 0.00 TJA 11800.00 51.09 295.36 8816.16 8736.05 5952563.37 638842.25 6920.43 0.00 0.00 MWD+IFR+MS 11900.00 51.09 295.36 8878.97 8798.86 5952595.33 638771.32 6998.23 0.00 0.00 MWD+IFR+MS 11914.55 51.09 295.36 8888.11 8808.00 5952599.98 638761.00 7009.55 0.00 0.00 Y-23B TSGR 11934.55 51.09 295.36 8900.67 8820.56 5952606.38 638746.81 7025.11 0.00 0.00 MWD+IFR+MS 11950.00 51.29 292.99 8910.36 8830.25 5952611.09 638735.74 7037.15 12.00 275.60 MWD+IFR+MS 11959.21 51.44 291.59 8916.11 8836.00 5952613.70 638729.03 7044.34 12.00 277.09 TSHA 11975.00 51.72 289.20 8925.92 8845.81 5952617.78 638717.36 7056.68 12.00 277.96 MWD+IFR+MS 12000.00 52.28 285.46 8941.32 8861.21 5952623.28 638698.45 7076.22 12.00 279.45 MWD+IFR+MS 12021.04 52.83 282.36 8954.11 8874.00 5952626.98 638682.16 7092.64 12.00 281.75 TSHB 12022.75 52.88 282.11 8955.14 8875.03 5952627.24 638680.83 7093.97 12.00 283.64 MWD+IFR+MS 12050.86 52.88 282.11 8972.11 8892.00 5952631.52 638658.82 7115.87 0.00 0.00 TSHC 12050.93 52.88 282.11 8972.15 8892.04 5952631.53 638658.77 7115.92 0.00 0.00 MWD+IFR+MS 12075.00 55.73 281.49 8986.19 8906.08 5952635.16 638639.57 7134.99 12.00 349.88 MWD+IFR+MS 12100.00 58.68 280.90 8999.73 8919.62 5952638.84 638618.88 7155.45 12.00 350.24 MWD+IFR+MS 12100.73 58.77 280.88 9000.11 8920.00 5952638.95 638618.27 7156.05 12.00 350.56 TSAD 12125.00 61.64 280.34 9012.17 8932.06 5952642.42 638597.50 7176.50 12.00 350.57 MWD+IFR+MS 12150.00 64.61 279.81 9023.47 8943.36 5952645.90 638575.47 7198.10 12.00 350.84 MWD+IFR+MS 12175.00 67.57 279.31 9033.60 8953.49 5952649.26 638552.87 7220.19 12.00 351.08 MWD+IFR+MS 12200.00 70.54 278.83 9042.54 8962.43 5952652.49 638529.75 7242.70 12.00 351.28 MWD+IFR+MS 12224.49 73.44 278.37 9050.11 8970.00 5952655.53 638506.66 7265.10 12.00 351.46 HOT 12225.00 73.50 278.36 9050.25 8970.14 5952655.59 638506.18 7265.57 12.00 351.60 MWD+IFR+MS 12250.00 76.47 277.91 9056.73 8976.62 5952658.55 638482.22 7288.74 12.00 351.60 MWD+IFR+MS 12275.00 79.44 277.47 9061.94 8981.83 5952661.35 638457.94 7312.15 12.00 351.72 MWD+IFR+MS 12300.00 82.41 277.04 9065.89 8985.78 5952664.00 638433.40 7335.74 12.00 351.81 MWD+IFR+MS 12325.00 85.38 276.61 9068.54 8988.43 5952666.47 638408.67 7359.43 12.00 351.88 MWD+IFR+MS 12350.00 88.35 276.19 9069.91 8989.80 5952668.78 638383.82 7383.16 12.00 351.92 MWD+IFR+MS 12363.87 90.00 275.96 9070.11 8990.00 5952669.98 638370.00 7396.33 12.00 351.94 Y-23B Land 12363.88 90.00 275.96 9070.11 8990.00 5952669.98 638370.00 7396.33 12.00 89.88 MWD+IFR+MS 12400.00 90.00 275.96 9070.11 8990.00 5952673.04 638334.00 7430.59 0.00 0.00 MWD+IFR+MS 12500.00 90.00 275.96 9070.11 8990.00 5952681.51 638234.37 7525.44 0.00 0.00 MWD+IFR+MS 12607.79 90.00 275.96 9070.11 8990.00 5952690.64 638126.97 7627.67 0.00 0.00 MWD+IFR+MS 12611.78 90.00 276.12 9070.11 8990.00 5952690.98 638123.00 7631.46 4.00 90.00 Y -23B flat 12667.89 92.24 276.12 9069.01 8988.90 5952695.89 638067.13 7684.71 4.00 359.97 MWD+IFR+MS 12700.00 92.24 276.12 9067.75 8987.64 5952698.69 638035.16 7715.17 0.00 0.00 MWD+IFR+MS 12800.00 92.24 276.12 9063.84 8983.73 5952707.43 637935.63 7810.03 0.00 0.00 MWD+IFR+MS 12900.00 92.24 276.12 9059.92 8979.81 5952716.17 637836.10 7904.89 0.00 0.00 MWD+IFR+MS 13000.00 92.24 276.12 9056.01 8975.90 5952724.91 637736.57 7999.75 0.00 0.00 MWD+IFR+MS 13100.00 92.24 276.12 9052.09 8971.98 5952733.64 637637.03 8094.61 0.00 0.00 MWD+IFR+MS e BP e KW A Planning Report Company: BP Amoco Date: 9/1712003 Time: 14:24:52 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-23, True North Site: PB Y Pad Vertical (TVD) Reference: 80.11' 80.1 Well: Y-23 Section (VS) Reference: Well (0.00N,O.00E.294.44Azi) Wellpath: Plan Y -23B Survey Calculation Method: Minimum Curvature Db: Oracle Survey Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool deg deg ft ft ft ft ft deg/10Oft deg 13200.00 92.24 276.12 9048.18 8968.07 5952742.38 637537.50 8189.47 0.00 0.00 MWD+IFR+MS 13300.00 92.24 276.12 9044.26 8964.15 5952751.12 637437.97 8284.33 0.00 0.00 MWD+IFR+MS 13400.00 92.24 276.12 9040.34 8960.23 5952759.86 637338.43 8379.19 0.00 0.00 MWD+IFR+MS 13500.00 92.24 276.12 9036.43 8956.32 5952768.59 637238.90 8474.05 0.00 0.00 MWD+IFR+MS 13600.00 92.24 276.12 9032.51 8952.40 5952777.33 637139.37 8568.91 0.00 0.00 MWD+IFR+MS 13700.00 92.24 276.12 9028.60 8948.49 5952786.07 637039.84 8663.77 0.00 0.00 MWD+IFR+MS 13757.74 92.24 276.12 9026.34 8946.23 5952791.11 636982.37 8718.55 0.00 0.00 MWD+IFR+MS 13800.00 90.73 275.37 9025.24 8945.13 5952794.53 636940.26 8758.56 4.00 206.31 MWD+IFR+MS 13820.32 90.00 275.01 9025.11 8945.00 5952795.98 636920.00 8777.74 4.00 206.29 Y-23B T2 13861.65 88.35 275.01 9025.71 8945.60 5952798.80 636878.77 8816.72 4.00 179.92 MWD+IFR+MS 13900.00 88.35 275.01 9026.81 8946.70 5952801.41 636840.53 8852.87 0.00 180.00 MWD+IFR+MS 14000.00 88.35 275.01 9029.70 8949.59 5952808.23 636740.81 8947.14 0.00 180.00 MWD+IFR+MS 14100.00 88.35 275.01 9032.58 8952.47 5952815.04 636641.09 9041.41 0.00 180.00 MWD+IFR+MS 14200.00 88.35 275.01 9035.47 8955.36 5952821.86 636541.38 9135.68 0.00 180.00 MWD+IFR+MS 14300.00 88.35 275.01 9038.35 8958.24 5952828.68 636441.66 9229.95 0.00 180.00 MWD+IFR+MS 14400.00 88.35 275.01 9041.24 8961.13 5952835.49 636341.94 9324.22 0.00 180.00 MWD+IFR+MS 14478.64 88.35 275.01 9043.51 8963.40 5952840.85 636263.52 9398.35 0.00 180.00 MWD+IFR+MS 14500.00 89.18 275.19 9043.97 8963.86 5952842.34 636242.22 9418.50 4.00 11.98 MWD+IFR+MS 14597.56 93.00 276.00 9042.11 8962.00 5952849.98 636145.00 9510.80 4.00 11.98 Y-22A T4 14600.00 93.03 276.09 9041.98 8961.87 5952850.19 636142.58 9513.11 4.00 70.58 MWD+IFR+MS 14700.00 94.35 279.88 9035.54 8955.43 5952862.14 636043.53 9608.80 4.00 70.59 MWD+IFR+MS 14736.55 94.83 281.26 9032.61 8952.50 5952868.13 636007.60 9644.17 4.00 70.83 MWD+IFR+MS 14800.00 94.83 281.26 9027.26 8947.15 5952879.28 635945.37 9705.73 0.00 0.00 MWD+IFR+MS 14900.00 94.83 281.26 9018.84 8938.73 5952896.86 635847.29 9802.75 0.00 0.00 MWD+IFR+MS 15000.00 94.83 281.26 9010.41 8930.30 5952914.43 635749.22 9899.77 0.00 0.00 MWD+IFR+MS 15100.00 94.83 281.26 9001.99 8921.88 5952932.00 635651.14 9996.79 0.00 0.00 MWD+IFR+MS 15110.73 94.83 281.26 9001.08 8920.97 5952933.89 635640.63 10007.20 0.00 0.00 MWD+IFR+MS 15200.00 93.18 284.43 8994.85 8914.74 5952952.01 635553.46 10094.42 4.00 117 .46 MWD+IFR+MS 15300.00 91.32 287.98 8990.92 8910.81 5952978.05 635457.01 10193.30 4.00 117.68 MWD+IFR+MS 15370.53 90.00 290.47 8990.11 8910.00 5952999.98 635390.00 10263.52 4.00 117.82 Y -22A T5 15400.00 88.82 290.47 8990.41 8910.30 5953009.75 635362.20 10292.92 4.00 180.00 MWD+IFR+MS 15463.71 86.27 290.47 8993.14 8913.03 5953030.86 635302.16 10356.41 4.00 180.00 MWD+IFR+MS 15500.00 86.27 290.47 8995.50 8915.39 5953042.87 635268.00 10392.54 0.00 0.00 MWD+IFR+MS 15600.00 86.27 290.47 9002.00 8921.89 5953075.96 635173.87 10492.09 0.00 0.00 MWD+IFR+MS 15700.00 86.27 290.47 9008.50 8928.39 5953109.06 635079.73 10591.64 0.00 0.00 MWD+IFR+MS 15800.00 86.27 290.47 9015.00 8934.89 5953142.15 634985.60 10691.19 0.00 0.00 MWD+IFR+MS 15900.00 86.27 290.47 9021.50 8941.39 5953175.24 634891.47 10790.74 0.00 0.00 MWD+IFR+MS 16000.00 86.27 290.47 9028.00 8947.89 5953208.34 634797.33 10890.29 0.00 0.00 MWD+IFR+MS 16100.00 86.27 290.47 9034.50 8954.39 5953241.43 634703.20 10989.84 0.00 0.00 MWD+IFR+MS 16186.26 86.27 290.47 9040.11 8960.00 5953269.98 634622.00 11075.71 0.00 0.00 Y-22A T6 ANTI-COLLlSION SETTINGS COMPANY DETAILS SURVEY PROGRAM WELL DETAILS N= +NI·S +E/-W Northing Easting Latitude Longitude Slot Y-23 399.85 -2950.60 5948883.32 644791.07 70Q16'03.968N 148Q49'44.876W 23 -320 -300 -250 -200 -150 -100 -SO -0 270 -SO -100 -150 -200 -250 -300 -320 Interpolation Method:MD Depth Range From: 6763.00 Maximwn Range: 1815.51 SP Amoco Depth Fm Depth To Survey/Plan 6763.00 16186.26 Planned: Y-23B wp04 V7 MWD+IFR+MS Tool Interval: 25.00 To: 16186.26 Reference: Plan: Y-23B wp04 Calculation Method: Minimum Curvature Error System: ¡SCWSA Scan Method: TravCylinderNorth Error Surface: Elliptical + Casing Warning Method: Rules Based o WELLPATH DETAILS FTOm Colour ToMD PlanY-23B 0 300 Parent Wellpath: ¥-23APB2 300 600 Tie on MD: 6763.00 600 900 Rig: Ref. Datum: 80.11' 80.lIft 900 1200 V.Section Drigm Drigm Starting 1200 1500 Anglo +N/-S +EI-W From TVD 1500 2000 294.44° 0.00 0.00 31.11 2000 2500 2500 3000 3000 3500 3500 4000 LEGEND 4000 4500 Test P-26 (fest P.26), Major Risk P·26 (P-26), Major Risk 4500 5000 Y -06 (y -06), Major Risk 5000 6000 - Y-22(Y-22),MajorRisk - ¥-23 (Y-23), NOERRORS o 6000 8000 - Y -23 (Y -23A), NOERRORS - Y-23 (Y-23APB1),NOERRORS 8000 9000 - Y -23 (Y -23APB2), NOERRORS 9000 10000 - Y-25(Y-25),MajorRisk e - PlanY-23B 10000 12000 - Y-23Bwp04 2000 15000 90 e SECTION DETAILS S'" MD In< Azi TYO +N/-S +EI-W DLeg TFace VS'" Target 1 6163.00 43.81 314.03 5636.18 2091.13 -2366.56 0.00 0.00 3019.62 2 6183.00 44.80 310.90 565050 2100.56 -2316.86 12.00 -66.80 3032.90 3 1110.19 51.09 29536 5810.11 2231.36 -2580.27 4.00 -66.80 321220 4 11914.55 51.09 29536 8888.11 3832.26 -5951.92 0.00 0.00 100955 Y -23B TSGR 5 11934.55 51.09 29536 8900.61 3838.92 -5971.98 0.00 0.00 1025.11 6 12022.15 52.88 282.11 8955.14 3861.06 -6031.56 12.00 -84.40 1093.91 7 12050.93 52.88 282.11 8912.15 3865.11 -6059.53 0.00 0.00 1115.92 , 12363.81 90.00 215.96 9010.11 3909.11 -6341.53 12.00 -10.12 1396.33 Y-23B Land 9 12363.88 90.00 275.96 9010.11 3909.77 -6341.53 12.00 89.88 7396.33 10 12601.79 90.00 275.96 9010.11 3935.10 -6590.13 0.00 0.00 1621.61 11 12611.78 90.00 276.12 9070.11 3935.52 -6594.10 4.00 90.00 1631.46 Y-23Bflal 12 12667.89 9224 276.12 9069.01 3941.50 -6649.87 4.00 -0.03 1684.11 13 13751.74 9224 276.12 902634 4057.58 -1132.68 0.00 0.00 8718.55 14 13820.32 90.00 275.oI 9025.11 4063.65 -1794.95 4.00 -153.69 8771.14 Y-23B T2 15 13861.65 8835 215.oI 9025.71 4061.26 -1836.12 4.00 119.92 8816.12 16 14478.64 8835 215.01 9043.51 4121.14 -8450.49 0.00 0.00 939835 17 14591.56 93.00 216.00 9042.11 4132.55 -8568.82 4.00 11.98 9510.80 Y-22A T4 18 14136.55 94.83 28126 9032.61 4153.34 -8105.86 4.00 70.58 9644.11 19 15110.13 94.83 28126 9001.08 4226.15 -9071.53 0.00 0.00 1000120 20 15370.53 90.00 290.41 8990.11 4297.05 -9320.86 4.00 111.46 10263.52 Y-22A T5 21 15463.11 8627 290.41 8993.14 4329.62 -9408.09 4.00 -180.00 10356.41 22 1618626 8621 290.41 9040.11 4581.80 -10083.58 0.00 0.00 11015.11 Y-22A 1'6 P055140 DATE 8/22/2003 INV# PR082003C INVOICE / CREDIT MEMO THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. DESCRIPTION PERMIT TO DRILL FEE TOTAL ~ DATE 8/22/2003 1 I CHECK NO. 055140 GROSS VENDOR DISCOUNT NET y. d3ß 4: ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 .. - ¿;1~::;~:::·::i~.. ~;·e~i~;~~~~~~;::f~~~ii·~\~~~\~;~:~ 11-0 5 5 ~ ~ 0 II- I: 0 ~ ~ 20 38 Ii 5 I: 0 ~ 2 í' 8 Ii b II!! H e e Rev: 07/10/02 C\jody\templates e e TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) Pll..OT (PH) "CLUE" The permit is for a new wen bore segment of existing well ---' Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for wen (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE 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 e:xception. (Companv Name) assumes the liability of any protest to tbe spacing . exception tbat may occur. An dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from wbere samples are first caught and 10' sample intervals tbrough target zones. Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT Y-23B Program DEV Well bore seg D PTD#: 2031640 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 nitial ClasslType DEV 11-01L GeoArea 890 Unit 11650 OnlOff Shore ~ Annular Disposal 0 Administration pj;!(mit fee attacheJJ_ - - - - - - - - - - Yj;!S __ ~ - - - - - - 2 _Leasj;!nUlJ1berapRropriate _ _ - - - - - - Yj;!s_ - - - - - - 3 _U_n[que weltn.amj;!_a[ld Ol!mb_e( _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - Yj;!S_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 4 WeJUQcatj;!d ina d_efineJJppoL - - - - _ Yes_ - - - - - 5 WeJUQcatj;!d proper _d [stan ce_ from driJling unitbound_ary_ _ - Yj;!s_ - - - - - - 6 WellJQcatj;!d pcoperd[stance from Qther wells_ - - - - Y_es _ _ _ _ _ _ - - - - - - - - -- 7 Sutficient9.crea~e_aYail9.ble [n_drilliog unit _ - - - - - Yj;!$- - - - - - 8 Jfdj;!viated. js_ weJlbQre plaUncJu_ded _ - - - - - - Yj;!$ __ - - - - 9 _Qpecator only affected party _ _ _ _ - - - - - - - YeL_ _ __ - - - - 10 _Qpecator has_apprppr[ateJ~9nd [nJQrce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - Yj;!s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 11 pj;!(mit ca[l be [s$l!ed wjthQut conservaJion order _ _ - - - - - - - YeL_ - - - - - - - - - - - Appr Date 12 Permit ca[l be lS$l!ed witbo_ut adrnini¡;t(atille_apprpvaJ _ _ _ _ _ _ _ - Yj;!$ - - - - - - - - - - RPC 9/29/2003 13 Can permit be approved before 15-day wait Yes 14 WellJQcatj;!d within area and_strata authorized by_lnjectipo Ordj;!( # (put 10# inc_omments)_(For_ NA _ _ _ _ - - - - - - - e 15 _AJI wells_within Jl4J1Jite_area_of (eyiew idj;!oUfied (Fp( ¡;ervjc_ewe[l onlYL _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ - _ _ _ - - _ _ - - _ - - - - - 16 Pre-produced i[ljector; _dur9.tiQn_of pre--proJJuctipo te$s than. 3 lJ1onths_ (For_seryice well QnJy) _ NAd____ - - - - - 17 ACMPFindjngof CQm;i~tençy_ha$ bee_nissued_ forJbi$ proiect _ - - -- _ _ _ _NA - - - - - - Engineering 18 _C9ndu_ctor ¡;t(ing_prQv[ded _ _ _ _ _ - - - - - _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ __ - - - - - 19 S_udacecasing_prQtecís alLknown USDW¡; _ _ _ _ _ - - - - - - - - - _ _ _NA _ _ _ _ _ _ _ _ _ _ _ __ 20 _CMTvptadequate_to circutate_onconductoc& ¡;urfC$g _ _ - - - - - - - - NA____ _ - - - - - -- 21 CMT v_ol adeql!ateJo tie-[nJQng _string tosud ç¡;g_ _ - - - - - - - - - _ _NA _ _ _ __ 22 CMTwil! coyer all known-Pfo_ductiye bQrizon_s_ - - - - - - - - - -- - - - - No _ Sloìte_d. - - - - - -- 23 _C_asing de_signs ad_eCluaJe fp( C,_T~ B&_permafr_ost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - Yj;!s _ _ _ _ __ - - - - - - - 24 AJJequ<lteJan_kage_or re_serye pit _ - - - - -- - - - - - _ _ _ Yj;!s _ _ _ _ _ _ _ !'Jabors_2ES. - - - - -- 25 JtaJe-d(ilt bas_a_ 10-403 for <lbandonme_nt bej;!O aPproved _ Yj;!s __ 9/4103. - - - -- - - - - - 26 AJJequ<lteJ^!:ellQore ~epªratjo_n_pro-pp¡;eJJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj;!s _ _ _ _ - - _ - - - - - - - - - - - - - - - - - - - - 27 Rdiverter req_uired, does iLmef!t reguJations_ _ _ _ _ _ _ . . - - - - - - - - - - - - NA _ _ _ _ _ _ _ Sidetrack. . - - - -- Appr Date 28 _Drilliog fluid_ program schelJ1atic_& e(Luip Jistadequate _ _ _ _ _ _ . _ _ _ _ _ _ - - - - - - _ _ _ Yj;!s _ _ . . _ _ _ MaxMWt1,A_ppg. _ _ WGA 9/29/2003 29 _BOPEs._d_othey meelreguJation _ . - - - - -- - - - - .. Yj;!s.. _ _ _. _ _ _ _. _ _ _.. - - - - - 30 BOPEpre_s$ ra!iog approp(iate;test lo-<put p¡;ig in_colJ1lJ1ent¡;}_ . - - - - - Yj;!$- _. . _ _ Testto _3500_ Rsi.MS~ 2366 psi. - 31 C_hokemanifold compJies w/APIR~-53 (May 64) _ - - - - - - - - - Yj;!$ - - - - - - 32 Work will pcc_ur withpYLoperatjon _shutdown_ _ _ - - - - - Yj;!s __ - - - - - - 33 J~ pre~ençe_ of H2S gas_ RroQable. _ _ _ . - - - - - No - - - -- !'Jot H2S pad. 34 Meçha_n[calcpl)dJUo[l pt wells within ,A.OR verified (for_s_ervjçe welJ only) _ _ _NA Geology 35 _Pj;!rmit can be iS$l!ed wlo_ hydrogen_ s_ulfide rJ1eas_uœs _ _ _ . - - - - -- .. _ No_ 36 _D_ata_presented on_Rote_ntial pveJPres_surj;!_zoneJ>_ _ _ _ _ _ _ _ _ _ - - - - - NA Appr Date 37 Sj;!ismicanalysJs_ of shaJlow gaszpoes . NA _ __ - - - - - - - - - - - - - - - - - - - - RPC 9/29/2003 38 Sf!aQedcondjtioo Sl!rvey(if off-$hp(e} _ _ . _ _ _ _ . _ _ _ . . _ _ _ . _ _ _ . . _ _ _ . . _ _ _ . . NA 39 _ CQnta_ct namelphon.eJor_wef!kly progre~Heports [exploratory _o[llyl . _ _ _ _ . _NA_ _ Geologic Date: Engineering Date Public 9r Commissioner Commissioner: Commissioner ,[ ff ~ ß3 D-rs ?/ if? / "3 ~ ~ ~ e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. $Revision: 3 $ LisLib $Revision: 4 $ Thu Jul 28 07:30:48 2005 ~Q)- 1'1 tf 1)~8 L Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name......... ....LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments...... ..... ..... .STS LIS Writing Library. Scientific Technical Services Tape Header Service name...... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/28 Origin. . . . . . . . : . . . . . . . . . . STS Tape Name........... .... .UNKNOWN Continuation Number. .... .01 Previous Tape Name... ....UNKNOWN Comments...... .......... .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA Y-23B 500292159002 BP Exploration (Alaska) Inc. Sperry Drilling Services 28-JUL-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002732043 J. SACK R. BORDES / MWD RUN 3 MW0002732043 J. SACK R. BORDES / MWD RUN 4 MW0002732043 T. GALVIN J. RALL / D. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0002732043 T. GALVIN J. RALL / D. MWD RUN 6 MW0002732043 J. SACK R. BORDES / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 11N 13E 1372 24 MSL 0) 79.15 51.61 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 6923.0 6.125 7.000 11915.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE EXITS THE Y-23 WELLBORE AT 6923'MD / 5750'TVD, BY MEANS OF A WHIPSTOCK. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND PRESSURE WHILE DRILLING (PWD). THE PURPOSE OF MWD RUN 2 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. NO DATA WERE ACQUIRED DURING MWD RUN 1. 5. MWD RUNS 4-6 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND AT-BIT INCLINATION (ABI). 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN Y-23B ON 9 JUNE 2005. THESE PDC DATA WERE PROVIDED BY D.DORTCH (SIS/BP) ON 19 JULY 2005. MWD DATA ARE CONSIDERED SECONDARY DEPTH CONTROL (SDC). LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 2-6 REPRESENT WELL Y-23B WITH API#:50-029-21590-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14955'MD/9008'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP ~ SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name....... ... ...STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/07/28 Maximum Physical Record..65535 File Type. .............. .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 6774.0 6926.0 11907.0 11907.0 11907.0 11907.0 11907.0 STOP DEPTH 14903.5 14957.0 14910.5 14910.5 14910.5 14910.5 14910.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 6774.0 6804.0 6833.0 6840.0 6843.5 6853.5 6860.5 6867.5 6870.5 6889.5 6897.5 6902.5 6905.5 6909.5 6918.0 6922.0 6924.0 6939.5 6950.0 6953.5 6960.5 6965.5 6976.5 6988.0 6998.5 7016.0 7019.0 7028.0 7039.5 7049.5 7055.5 7060.5 7070.5 7077.5 7080.5 7083.5 7090.5 7096.0 7111. 5 7118.5 7120.0 7127.0 7135.0 7138.0 7141.5 7145.5 GR 6771 . 0 6801.0 6833.5 6840.5 6843.5 6852.5 6858.5 6864.5 6867.5 6887.0 6894.5 6900.0 6903.5 6908.5 6916.0 6920.5 6921. 5 6939.0 6948.5 6954.0 6961. 0 6964.5 6975.5 6987.0 6996.0 7015.5 7018.0 7025.0 7037.0 7048.0 7054.0 7059.5 7071.0 7076.0 7078.0 7082.0 7089.0 7094.5 7109.0 7117.0 7118.5 7125.5 7132.0 7134.5 7139.5 7142.5 7167.5 7173.0 7182.5 7198.0 7203.5 7209.5 7223.0 14957.0 $ 7165.0 7171.0 7180.0 7197.0 7201.0 7209.5 7221.0 14955.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 2 3 4 5 6 MERGE TOP 6771.0 6956.0 11916.0 12227.0 12617.0 MERGE BASE 6956.0 11916.0 12227.0 12617.0 14955.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.. ...... ..........0 Data Specification Block Type.....O Logging Direction........ ........ . Down Optical log depth units.... ...... .Feet Data Reference Point...... ........Undefined Frame Spacing....... .......... ....60 .1IN Max frames per record........... ..Undefined Absent value..ò......... ......... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6774 14957 10865.5 16367 6774 14957 ROP MWD FT/H 0.49 384.01 127.294 16063 6926 14957 GR MWD API 14.07 535.82 95.8243 16260 6774 14903.5 RPX MWD OHMM 0.47 2000 14.2068 6008 11907 14910.5 RPS MWD OHMM 0.2 1579.99 10.2234 6008 11907 14910.5 RPM MWD OHMM 0.17 1923.09 10.9101 6008 11907 14910.5 RPD MWD OHMM 0.17 2000 21.443 6008 11907 14910.5 FET MWD HOUR 0.22 75.95 2.68036 6008 11907 14910.5 First Reading For Entire File......... .6774 Last Reading For Entire File......... ..14957 File Trailer Service name..... ....... .STSLIB.001 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation..... ..05/07/28 Maximum Physical Record. .65535 File Type........... .... .LO Next File Name.... ...... .STSLIB.002 Physical EOF File Header Service name... ......... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .05/07/28 Maximum Physical Record. .65535 File Type......... ...... .LO Previous File Name. ..... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 6771 . 0 6924.0 STOP DEPTH 6906.0 6956.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: 25-0CT-03 Insite 66.37 Memory 6956.0 6923.0 6956.0 .0 .0 TOOL NUMBER 126027 8.500 6923.0 LSND 9.50 63.0 10.3 1550 3.9 .000 .000 .000 .000 .0 100.0 .0 .0 MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type.....O Logging Direction..... ........... . Down Optical log depth units. ....... ...Feet Data Reference Point... .......... .Undefined Frame Spacing...... .... ...........60 .1IN Max frames per record.... .........Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6771 6956 6863.5 371 6771 6956 ROP MWD020 FT/H 2.5 88.13 29.8369 65 6924 6956 GR MWD020 API 36.96 69.51 49.3811 271 6771 6906 First Reading For Entire File..... .... .6771 Last Reading For Entire File....... ....6956 File Trailer Service name........ .... .STSLIB.002 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .05/07/28 Maximum Physical Record. .65535 File Type........... .... .LO Next File Name....... ... .STSLIB.003 Physical EOF File Header Service name......... ....STSLIB.003 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation... ....05/07/28 Maximum Physical Record. .65535 File Type........... .... .LO Previous File Name... ....STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 3 header data for each bit run in separate files. 3 .5000 # FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 6906.5 6956.5 STOP DEPTH 11879.5 11916.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. ............... ..0 Data Specification Block Type.....O Logging Direction.... .............Down Optical log depth units...... .....Feet Data Reference Point............. .Undefined Frame Spacing....... ..... ... ..... .60 .1IN Max frames per record.............Undefined Absent value. ................ .....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 30-0CT-03 Insite 66.37 Memory 11916.0 6956.0 11916.0 48.0 54.4 TOOL NUMBER 126027 8.500 6923.0 LSND 11.50 46.0 9.4 1550 3.6 .000 .000 .000 .000 .0 168.0 .0 .0 Name Service Order DEPT Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 Rap MWD030 GR MWD030 FT/H API 4 4 1 68 1 68 4 8 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6906.5 11916 9411.25 10020 6906.5 11916 ROP MWD030 FT/H 2.95 384.01 129.267 9920 6956.5 11916 GR MWD030 API 37.17 397.46 126.837 9947 6906.5 11879.5 First Reading For Entire File..........6906.5 Last Reading For Entire File... ........11916 File Trailer Service name..... ....... .STSLIB.003 Service Sub Level Name... Version Number.. ....... ..1.0.0 Date of Generation...... .05/07/28 Maximum Physical Record. .65535 File Type. ....:.... .... ..LO Next File Name...... .... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation... ....05/07/28 Maximum Physical Record. .65535 File Type......... ...... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS FET RPD RPX RPM Rap $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 11880.0 11905.0 11905.0 11905.0 11905.0 11905.0 11916.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG STOP DEPTH 12175.0 12182.0 12182.0 12182.0 12182.0 12182.0 12227.0 02-NOV-03 Insite 66.37 Memory 12227.0 11916.0 12227.0 MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY {HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... .... ...........0 Data Specification Block Type.....O Logging Direction......... .... ....Down Optical log depth units......... ..Feet Data Reference Point............. .Undefined Frame Spacing...... .............. .60 .1IN Max frames per record.. ..... .... ..Undefined Absent value.. ...... .... ..........-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 49.3 61. 9 TOOL NUMBER 91360 156401 6.125 11915.0 FLO-PRO 8.50 46.0 9.3 3800 5.6 1.100 .560 .900 1. 500 65.0 133.0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11880 12227 12053.5 695 11880 12227 ROP MWD040 FT/H 0.49 283.66 38.2985 622 11916.5 12227 GR MWD040 API 18.31 535.82 107.241 591 11880 12175 RPX MWD040 OHMM 0.47 2000 88.0701 555 11905 12182 RPS MWD040 OHMM 0.2 1579.99 41.4957 555 11905 12182 RPM RPD FET MWD040 OHMM MWD040 OHMM MWD040 HOUR 0.17 0.17 1.45 1923.09 2000 70.25 First Reading For Entire File... .......11880 Last Reading For Entire File.......... .12227 File Trailer Service name. ........... .STSLIB.004 Service Sub Level Name. . . Version Number.. ........ .1.0.0 Date of Generation...... .05/07/28 Maximum Physical Record..65535 File Type. ........... ....LO Next File Name....... ....STSLIB.005 Physical EOF File Header Service name... ......... .STSLIB.005 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation... ....05/07/28 Maximum Physical Record. .65535 File Type...... ......... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM FET RPD ROP $ 5 40.1944 136.873 5.69937 555 555 555 11905 11905 11905 12182 12182 12182 header data for each bit run in separate files. 5 .5000 START DEPTH 12175.5 12182.5 12182.5 12182.5 12182.5 12182.5 12227.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 12565.5 12572.5 12572.5 12572.5 12572.5 12572.5 12617.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 03-NOV-03 Insite 66.37 Memory 12617.0 12227.0 12617.0 63.1 93.8 TOOL NUMBER 91360 156401 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............... ...0 Data Specification Block Type.....O Logging Direction......... ....... . Down Optical log depth units......... ..Feet Data Reference Point. ............ .Undefined Frame Spacing. ............. .......60 .1IN Max frames per record........... ..Undefined Absent value........ ... ......... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 6.125 11915.0 Flo-pro 8.40 43.0 9.3 3700 5.0 1.100 .550 .900 1. 500 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT MWD050 FT/H MWD050 API MWD050 OHMM MWD050 OHMM MWD050 OHMM MWD050 OHMM MWD050 HOUR Min 12175.5 0.92 15.92 3.96 3.69 3.48 3.96 0.56 Max 12617 305.08 95.12 12.85 11.58 11.21 11.35 18.22 First Reading For Entire File...... ... .12175.5 Last Reading For Entire File... ...... ..12617 Mean 12396.3 88.6855 32.4582 5.96653 5.60273 5.48795 5.84169 3.33132 Nsam 884 780 781 781 781 781 781 781 65.0 137.0 65.0 65.0 First Reading 12175.5 12227.5 12175.5 12182.5 12182.5 12182.5 12182.5 12182.5 Last Reading 12617 12617 12565.5 12572.5 12572.5 12572.5 12572.5 12572.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation. ..... .05/07/28 Maximum Physical Record..65535 File Type............ ....LO Next File Name......... ..STSLIB.006 Physical EOF File Header Service name........... ..STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/07/28 Maximum Physical Record. .65535 File Type............ ....LO Previous File Name..... ..STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 6 header data for each bit run in separate files. 6 .5000 START DEPTH 12566.0 12573.0 12573.0 12573.0 12573.0 12573.0 12617.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 14901. 5 14908.5 14908.5 14908.5 14908.5 14908.5 14955.0 06-NOV-03 Insite 66.37 Memory 14955.0 12617.0 14955.0 88.6 95.8 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 91360 156401 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS 6.125 11915.0 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... ........... ..0 Data Specification Block Type.....O Logging Direction........... ......Down Optical log depth units........ ...Feet Data Reference Point.. ........... .Undefined Frame Spacing... .......... ....... .60 .1IN Max frames per record....... ......Undefined Absent value........ .......... ....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Sea Water 8.40 28.0 7.0 o .0 .270 .190 .270 .270 70.0 100.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12566 14955 13760.5 4779 12566 14955 ROP MWD060 FT/H 3.85 367.94 142.765 4676 12617.5 14955 GR MWD060 API 14.07 163.79 41.6072 4672 12566 14901. 5 RPX MWD060 OHMM 2.78 28.73 6.8099 4672 12573 14908.5 RPS MWD060 OHMM 3.32 33.95 7.28089 4672 12573 14908.5 RPM MWD060 OHMM 3.54 89.5 8.33775 4672 12573 14908.5 RPD MWD060 OHMM 4.81 96.35 10.3387 4672 12573 14908.5 FET MWD060 HOUR 0.22 75.95 2.2129 4672 12573 14908.5 First Reading For Entire File......... .12566 Last Reading For Entire File..... .... ..14955 File Trailer Service name........ .....STSLIB.006 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation.... ...05/07/28 ~ Maximum Physical Record..65535 File Type.............. ..LO Next File Name...... ... ..STSLIB.007 Physical EOF Tape Trailer Service name........ .... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............ ....UNKNOWN Continuation Number... ...01 Next Tape Name....... ....UNKNOWN Comments.. ...... ....... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.... .... ... ..LISTPE Date.................... .05/07/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. ..... ........ .UNKNOWN Continuation Number.... ..01 Next Reel Name.......... .UNKNOWN Comments..... ........... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
