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Home My WebLink About206-027CAUTION: 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Injector L-214A (PTD #2060270) OA pressure decrease Date:Thursday, May 8, 2025 7:12:12 AM Attachments:TIOChart.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, May 5, 2025 9:00 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Injector L-214A (PTD #2060270) OA pressure decrease Mr. Wallace, Injector L-214A (PTD #2060270) recently exhibited an OA pressure decrease that cannot be explained by corresponding injection rates or temperatures. We are going to perform a non- witnessed MIT-IA to verify the production casing integrity. If the MIT-IA brings to light any production casing integrity concerns, we will notify you. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. We] I: L-214 4,000 3,900 3,800 3,700 3,GM 3,500 3,400 3,300 3,200 3,100 3,000 2,900 2,800 2,700 2,600 2,500 2,400 2,300 2,200 2,100 2,000 1,900 1,300 1,700 1,fi00 1,500 1,400 1,300 1,200 1,100 1,000 900 800 700 GOD 500 400 300 200 100 ED12125 o2J19125 C112125 03+19125 04/09/25 0V16+25 0412125 0CM25 300 290 230 270 26D 250 240 230 220 210 200 190 130 170 1fi0 3 15o m m 140 130 120 110 100 90 80 70 fio 50 40 30 20 10 TIO Plot f Tubing — On ■ Bleed * Operable + Not Oper ♦ Under Eval Man. IA —� Man. OA Man. OOA Man. OOOA O Man. WHT MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 10, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-214A PRUDHOE BAY UN ORIN L-214A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/10/2022 L-214A 50-029-23258-01-00 206-027-0 W SPT 4421 2060270 1500 1490 1490 1488 1488 310 314 314 314 4YRTST P Guy Cook 5/9/2022 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN L- 214A Inspection Date: Tubing OA Packer Depth 41 2256 2196 2174IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220508164232 BBL Pumped:5.4 BBL Returned:4 Friday, June 10, 2022 Page 1 of 1 9 9 9 9 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.10 15:07:29 -08'00' MEMORANDA State of Alaska Alaska Oil and Gas Conservation Commission f/ DATE: Tuesday,May 15,2018 TO: Jim Regg -41q Z4( P.I.Supervisor I SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. L-214A FROM: Austin McLeod PRUDHOE BAY UN ORIN L-214A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,:6. — NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN L- API Well Number 50-029-23258-01-00 Inspector Name: Austin McLeod 214A Permit Number: 206-027-0 Inspection Date: 5/8/2018 Insp Num: mitSAM180508154500 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-214A Type Inj O• TVD 4421 . Tubing 1028 1036 1031 , 1028 PTD 2060270 Type Test SPT Test psi 1500 - IA 110 2500 - 2457 - 2437 - BBL Pumped: 4.2 BBL Returned: 4.2 - OA 204 207 • 207 • 207 Interval 4YRTST P/F P Notes: MIT-IA tested to 2500 psi as per operators request.Matt Herrera accompanied me. SCANNED JUN 0 12018 Tuesday,May 15,2018 Page 1 of 1 • 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. - ~~, ~ Well History File Identifier Organizing (done) RE CAN Color Items: r~Greyscale Items: ~ P~ ^ Poor Quality Originals: ^ Other: NOTES: ~.,~,aea iuuiiiimiiuii DIGITAL DATA ~iskettes, No. ^ Other, No/Type: . Re,~,.~eeaea uumiiuiuuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: ~ Maria ~ Date: ~~ ~1p~ /s/ ~ V Project Proofing III 111111 11111 I I III BY: Maria Date: /s/ Scanning Preparation ~_ x 30 = ~ + ~ =TOTAL PAGES-- _3 (Count does not include cover sheet) BY: Maria Date: (~/~ D ~' /s/ Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~/S'D ~ lsl p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II ~I N I II II I I III ReScanned III II'I~I VIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III III IIII II P 10/6/2005 Well History File Cover Page.doc 04/28/11 Schlemberger NO. 5729 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 15 -09A BBKA -00096 PRODUCTION PROFILE ( 4 13 — j -3 gy! 03/14/11 1 .. 0 1 17-06 BBKA -00094 INJECTION PROFILE 0 Z ( 6 1 'v 03/10/11 1 t. t' ' 1 C -12B BAUJ -00064 MEM PRODUCTION PROFILE �.(') 03/08/11 1 a Q ;1 1 G -23B BLPO -00079 MEM PRODUCTION PROFILE q a, 16 -08A BJGT -00022 GLS 1' 4 19 s f a! 03/07/11 03/07/11 1 A S'S 1 02 -18B BLPO -00087 MEM CBL dQ 4 ---( (p 03/25/11 fa g- 1 1 J -22A BJGT -00023 CBL • eq. -- 03/10/11 __ • _i: 1 1 L -210 BLPO -00086 MEM INJECTION PROFILE ' / , - 03/23/11 1 a 1 V -105 BLPO -00091 MEM INJECTION PROFILE .-. a 03/29/11 1 �± 1 V -220 BBSK -00065 INJECTION PROFILE/WFL ��j , 4 , . � T: 1 V -212 BD88 -00096 MEM INJECTION PROFILE • ✓ • 04/03/11 1 C 1 L -214A BCRJ -00073 INJECTION PROFILE 1 z - "'i.P! 03/18/11 1 �•• % 1 V -223 BAUJ -00071 MEM INJECTION PROFILE, „ I , 03/19/11 1 El 'I'S 1 V -217 BAUJ -00077 MEM INJECTI a N PROFILE 1 2 r _ 1 3-05/0-29 BG4H -00043 LDL O 03/20/11 1` 1 1-47A/M-20 BLPO - 00092 MEM PRODUCTION PROFILE ,. -- - i,' 04/03/11 1 1- 25A/K -22 BBSK -00057 CBL r — (� 03/13/11 n. 7 1 S -01C BCUE -00113 MEM CBL - .' - 04/18/110 11 -30 BD88 -00097 MEM INJECTION PROFILE `4- - 04/18/11 1 � _ . a � 1 04 -11A AWJI -00134 1I■111404IIL79;slail K43 AL�n1, r isITILT 1 P2 -41 BG4H -00044 PRODUCTION PROFILE i . c — ° >e) 5` 03/22/11 1 D -26B BMSA -00009 SCMT a6( — 03/24/11 ,an Lj6 1 02 -18B BLP0.00087 MEM PRODUCTION PROFILE ,t. 03/24/11 1 . A _ 1 Z -20 BP5G -00010 GLS / lir-(p t) 03/29/11 1 as 69 1 Y -29A BCUE -00122 MEM LDL r 9 ep ® (-A / 03/20/11 1 9 ® 9 - 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP 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 otk r, s �lt1R 21311 • 11/01/10 Sciderler NO. 5637 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATM Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 0 Log Description Date BL Color CD MPG -13 BCRJ -00038 X -FLOW CHECK/IBPSET RECORD — 09/15/10 1 1 MPS-43 AYKP -00104 SCMT 08126/10 1 1 Pt -09 BCRJ -00036 PRODUCTION PROFILE 09/12110 1 1 W -37A BOSS -M48 MEM PRODUCTION PROFILE — 09111/10 1 W -31A AZ2F -00064 MEM PRODUCTION PROFILE 09/16/10 1 06 -19A AWJI-00112 MEM PRODUCTION PROFILE 09119110 1 1 12 -OSALl SAUJ -00050 MEM PRODUCTION PROFILE 09/20/10 1 1 P1 -16 BCRJ-00049 INJECTION PROFILE 10/06110 1 1 04 -03 BCRD -00059 PRODUCTION PROFILE 09/27110 1 1 • P -03A AZ2F -00065 MEM INJECTION PROFILE / — 10106110 1 1 G -196 AWJI-00114 MEM PRODUCTION PROF ILE 10/04/10 1 1 -a5-82A— —809840"3- IIASIA PRO --- 49192149 Y -36 BD88 -00058 MEM GLS ROFILE 10109 1 1 3- 03/J -33 BCZ2 -00025 PRODUCTION P 09111110 1 1 L -214A BAUJ-00043 MEM INJECTION PROFILE 09/13/10 1 1 H -01A AWJI -00118 MEM PRODUCTION PROFILE 10114110 1 i 16.06B BBUO -00023 PRODUCTION PROFILE BP CORRECTION 06/08/10 i 1 H -38 AZ2F -00068 MEM PRODUCTION PROFILE 10116110 1 1 P2-44 BCRD -00063 PRODUCTION PROFILE 10115/10 1 (/ 7 B -13B AYKP -00091 CH EDIT PDC-GR {SCMT) .i 07102170 09 �O 1 02 -22B 10AKA0069 OH MWD /LWD EDIT 07107/10 2 1 W -196 BCRJ -00034 CH EDIT PDC -GR (SCMT) 09/07110 1 1 OWDW -SE APBPD3WELL RST REDO•PRINTS 08123110 1 OWDW - NW BBSK - 00033 RST 09124/10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: SP 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 Nov Nib C Nov ag ",, MEMORANDUM Toy Jim Regg P.I. Supervisor ~~ ~~~S~l~ FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 09, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC L-214A PRUDHOE BAY LTN ORIN L-214A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UN GRIN L-214A API Well Number: s0-029-23258-01-00 Insp Num: mitJCr100s24070s28 Permit Number: 206-027-0 Rel Insp Num: Inspector Name: John Crisp Inspection Date: 5/20/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel-l-~ L-z14A Type Inj. ~ G TVD aazl ~ IA T ao P.T D~2060270 TypeTest SPT ,Test ps~ 1500 OA ~ zsoo 340 2aso 340 zaoo 340 Interval aYRTST p~F P ,Tubing ]sso ls~o ]s7o Is~o Notes: 4.5 bbls pumped for test. No problems witnessed. < ,. Wednesday, June 09, 2010 Page 1 of 1 • i _~ ~_ ~~ ~ ~. ~, ..~ . ~~ ._~x ~.~s ,~ t z~~~ii~°..i' MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc P2-23 (PTD# 1940320), 04-10 (PTD#60420), 09-25 (PTD# 1840280), GC-PTD# 189068... Page 1 of 4 Regg, James B (DOA) From: Regg, James B (DOA) I~e~ ~ ~t ~ ~fv Sent: Wednesday, June 09, 2010 11:04 AM " L- Z i4A 2~~--UZ7 To: Brooks, Phoebe L (DOA) Subject: FW: P2-23 (PTD# 1940320), 04-10 (PTD# 1760420), 09-25 (PTD# 1840280), GC-1 E (PTD# 1890680), H-03 (PTD# 1710190), L-214A (PTD# 2060270), NGI-08 (PTD# 1760520), V-224 (PTD# 2081540), V-227 (PTD# 2091160), WGI-04 (PTD# 1790500) Attachments: Injector Vy1.4 TIO Plot and Injection Plot.doc,~ change to gas L- Z 14-A _.... __ They are a bit sloppy with naming - TIO data appears to be for L-214A but. attachment named V-214 Jim Regg AOGCC 333 W.7th Avenue, Suite 100 ~ r, r~ Anchorage, AK 99501 A t-~ ~~ ~~~, ~ .r ~-~~ 907-793-1236 ~•w #~t~tYj :. 9 ! ~~ From: Regg, James B (DOA) Sent: Wednesday, June 09, 2010 10:54 AM To: Crisp, John H (DOA) Subject: FW: P2-23 (PTD# 1940320), 04-10 (PTD# 1760420), 09-25 (PTD# 1840280), GC-lE (PTD# 1890680), H-03 (PTD# 1710190), L-214A (PTD# 2060270), NGI-08 (PTD# 1760520), V-224 (PTD# 2081540), V-227 (PTD# 2091160), WGI-04 (PTD# 1790500) FYI; based on TIO data (attached), I am going to have Phoebe change your MIT inspection rpt to reflect gas injection Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brooks, Phoebe L (DOA) Sent: Wednesday, June 09, 2010 7:45 AM To: Regg, James 6 (DOA) Subject: FW: P2-23 (PTD# 1940320), 04-10 (PTD# 1760420), 09-25 (PTD# 1840280), GC-1E (PTD# 1890680), H-03 (PTD# 1710190), L-214A (PTD# 2060270), NGI-08 (PTD# 1760520), V-224 (PTD# 2081540), V-227 (PTD# 2091160), WGI-04 (PTD# 1790500) Hi Jim, I received some additional information about the type of injection far well L-214A and they are sticking with Gas...should i change John's report to reflect Gas as well? Phoebe Brooks Statistical Technician ii Alaska Oil and Gas Conservation Commission 6/9/2010 P2-23 (PTD# 1940320), 04-10 (PTD#60420), 09-25 (PTD# 1840280), GC-PTD# 189068... Page 2 of 4 Phone: 907-793-1242 Fax: 907-276-7542 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Tuesday, June 08, 2010 10:00 PM To: Brooks, Phoebe L (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: RE: P2-23 (PTD# 1940320), 04-10 (PTD# 1760420), 09-25 (PTD# 1840280), GC-lE (PTD# 1890680), H-03 (PTD# 1710190), L-214A (PTD# 2060270), NGI-08 (PTD# 1760520), V-224 (PTD# 2081540), V-227 (PTD# 2091160), WGI-04 (PTD# 1790500) Hi Phoebe, I have confirmed it was on gas with the optimization engineer. The well was swapped from water injection to gas on 3/1/2010. Gas was injected from 3/2/2010 until 411/2010, shut in until 4/22/2010, then continued gas injection through today. am including a TIO and Injection plot, where you can see a definite change of the injection pressure on the tubing after the swap to gas. If I can be of further assistance, please let me know. Regards, Jerry Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Tuesday, June 08, 2010 10:50 AM To: AK, D&C Well Integrity Coordinator Subject: RE: P2-23 (PTD# 1940320), 04-10 (PTD# 1760420), 09-25 (PTD# 1840280), GC-1E (PTD# 1890680), H-03 (PTD# 1710190), L-214A (PTD# 2060270), NGI-08 (PTD# 1760520), V-224 (PTD# 2081540), V-227 (PTD# 2091160), WGI-04 (PTD# 1790500) Thanks Jerry. Phaebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Tuesday, June 08, 2010 10:39 AM To: Brooks, Phoebe L (DOA) Subject: RE: P2-23 (PTD# 1940320), 04-10 (PTD# 1760420), 09-25 (PTD# 1840280), GC-lE (PTD# 1890680), H-03 (PTD# 1710190), L-214A (PTD# 2060270), NGI-08 (PTD# 1760520), V-224 (PTD# 2081540), V-227 (PTD# 2091160), WGI-04 (PTD# 1790500) Phoebe, L-214A (PTD #2060270) was placed on gas injection on 4/22/2010. The MIT-IA test was 5/20/2010. 6/9/2010 P2-23 (PTD# 1940320), 04-10 (PTD#60420), 09-25 (PTD# 1840280), GC-PTD# 189068... Page 3 of 4 Please let me know if I can be of further assistance. Regards, Jerry Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Tuesday, June 08, 2010 7:33 AM To: AK, D&C Well Integrity Coordinator Subject: RE: P2-23 (PTD# 1940320), 04-10 (PTD# 1760420), 09-25 (PTD# 1840280), GC-1E (PTD# 1890680), H-03 (PTD# 1710190), L-214A (PTD# 2060270), NGI-08 (PTD# 1760520), V-224 (PTD# 2081540), V-227 (PTD# 2091160), WGI-04 (PTD# 1790500) Torin, Will you please verify the type of injection for well L-214A, PTD #2060270? The inspector notated water, your report has Gas. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone:907-793-1242 Fax: 907-276-7542 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Monday, May 31, 2010 4:43 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: AK, D&C Well Integrity Coordinator Subject: P2-23 (PTD# 1940320), 04-10 (PTD# 1760420), 09-25 (PTD# 1840280), GC-1E (PTD# 1890680), H-03 (PTD# 1710190), L-214A (PTD# 2060270), NGI-08 (PTD# 1760520), V-224 (PTD# 2081540), V-227 (PTD# 2091160), WGI-04 (PTD# 1790500) Jim, Tom, and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: P2-23 (PTD# 1940320) 04-10 (PTD# 1760420) 09-25 (PTD# 1840280) GC-1 E (PTD# 1890680) 6/9/2010 P2-23 (PTD# 1940320), 04-10 (PTD#60420), 09-25 (PTD# 1840280), GC-(PTD# 189068... Page 4 of 4 H-03 (PTD# 1710190) L-214A (PTD# 2060270) NGI-08 (PTD# 1760520) V-224 (PTD# 2081540) V-227 (PTD# 2091160) WGI-04 (PTD# 1790500) «May 2010 MIT Forms 05-31-10.zip» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 6/9/2010 Injector L-214A (PTD #2060270) TIO Plot _ Well= L-214 4,000 3,OM -~- Tbg -!- IA 2.000 --~ OA .....«.««+~~ OOA OOOA 1,000 On 02,'13!10 02127110 00113!10 03!27!10 04/10110 04/24!10 05108/10 05122110 06105!10 Injector L-214A (PTD #2060270) Injection Plot Well: L-214 ~ 3,000 2,500 2.000 `'~-` ~ WHIP 2 iJ00 1,500 -~o SW E °- ° PW 1,500 -` 1,000 ,=, f~l 1,000 '`-'~-~'"- ~` G I - ~ •' ~--'"`~ r, Other ~`` ~ 500 On 500 02/13110 02127110 03113110 03127110 04110110 04/24/10 05108110 05122110 06105110 AfdbRd vn a uas cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Both 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job Log Description Date BL Color CD MPI -13 AWJI -00055 'a 10/18/09 1 1 MPC -07 AXBD -00057 MEM PROD PROFILE Fib L• yPaill 10/24/09 1 1 04 -11 A AWL8 -00040 I 1Iralle,A e a�� 10/24/09 1 1 V -220 AYS4 -00100 INJECTION PROFILE T 10/04/09 1 1 L -220 B1JJ -00035 MEM INJ PROFILE REVISED z. -F i A, 07/30/09 1 1 V -221 AXBD -00037 MEM INJ PROFILE (REVISED) C 006 /09 ,6 07/28/09 1 1 �i L -214A AP30 -00064 INJ PROFILE/RST A l 4 10/06/09 1 1 S -228 AYTU -00052 INJECTION PROFILE U i iq 0 �3 z- 10/27/09 1 1 14 -07 8581 -00016 PROD PROFILE i 1 10/27/09 1 1 07 -05 AYS4 -00105 SCMT —0 10/28/09 1 1 R -28 AWL8 -00041 USIT -a 10/26/09 1 1 2- 08/K -16 AZCM -00046 PRODUCTION PROFILE 01 $9 n' 10/30/09 1 1 PSI -05 B14B -00080 TEMP WARMBACK SURVEY 1-- C aoZ 1R9 /1,90,, 11/03/09 1 1 C -128 B2WY -00030 MCNL �j•S:W• 09/19/09 1 1 U -05A 09AKA0074 OH MWD /LWD EDIT T -0 Ti c iall 08/19/09 2 1 01 -18A 09AKA0151 OH MWD/LWD EDIT a��! 08/27/09 4 1 H -09 ANHY -00110 RST j'r 09/20/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center 1.R2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. q-, j 7 Zr' Anchorage, AK 99503 -2838 `v n LJ BP Exploration (Alaska) Inc. ~~ Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~~vr~"~&y~~~i~,~ ~ . _ . ~41ti~~ August 14, 2009 • bp ~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T 0 5 2009 ~las~Ca ~lil ~e Gas Cons. Corr~ni~~ion Anchoraae ~o~- o~~ ~-~~~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • ~ BP Exploration (Alaska ) Inc. Surtace Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date L pad 8N 3/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date CoROSion inhibRor Corrosion inhibitod sealant date ft bbls ft na af ~-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 62 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-t05 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 1-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 ~-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 3162 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/2712009 1-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6l27l2009 L-219 2077480 50029233760000 suAace NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 osi2sio8 ~chl~rml~erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII -Inh 1t 6. ~L. '/J 6r'~~~1:.^L~`tif . r6 j ~6~~.j C,~. 1 n..~.. N0.4908 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 17-12 11978484 PRODUCTION PROFILE - 09/19/08 1~ 1 P2-27 12017505 PRODUCTION PROFILE ~ _ 09!08/08 1 1 18-05A 11999048 FREE POINT INDICATOR LOG 09/16/08 1 1 E-36 12034922 SCMT _ '~ 09/13/08 1 1 06-13A 12066547 MEM PROD PROFILE b(p- ~C7 09/05/08 1 1 12-09 12083409 MEM DENSITY LOG ~(~ - ( 09/06/08 1 1 13-14 11978482 PROD PROFILE ~ - ~ 09/13/08 1 1 L-214A 11970843 INJECTION PROFILE C~'t, ~. 09/05/08 1 1 L-210 12031511 INJECTION PROFILE 09/02/08 1 1 L-216 11970842 INJECTION PROFILE - ~ _ 09/04/08 1 1 V-221 12034920 INJECTION PROFILE ~ 09/09/08 1 1 L-205L4 40016965 OH MWD/LWD EDIT 06/26/08 (2 PRINTS & 1 CD HAND DELIVERED SEPARATELY) DI CACC A!`Il I.IA\IIII G11l~C ~C n~InT ~ BP Exploration (Alaska) Ina _ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: I, ? (.~ 3 Sq Alaska Data & Consulting Services 2525 Gambell Street, Sui 400 Anchorage, AK 9~-2 8 _ ATTN: Beth 4( Received by: • r. ~' ~ ;~~ DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060270 Well Name/No. PRUDHOE BAY UN ORIN L-214A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23258-01-00 MD 7652 TVD 4825 Completion Date 3/1/2006 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: LWD: DIR / GR / RES /DEN / NEU, USIT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt~ Number Name D Asc Directional Survey Rpt, Directional Survey ~r~L~/ Sonic "j ED C Pds 14133 ~~o iC ~'~D C Lis 15256~Induction/Resistivity Q-Cog 15256 Induction/Resistivity 15256 Induction/Resistivity Well Cores/Samples Information: Interval Name Start Stop ADDITIONAL INFORM~ION Well Cored? Y fM\V Chips Received? ~Ttd-- Analysis kL~V Received? Comments: (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 6443 7652 Open 5/19/2006 6443 7652 Open 5/19!2006 5 Blu 1 6360 7520 Case 6/14/2006 USIT,GR,CCL 16-Mar-2006 1 6360 7520 Case 9/12/2006 USIT,GR,CCL 16-Mar-2006 103 7651 Open 7/3/2007 LIS Veri, FET, ROP, NPHI w/Graphics PDF, and TIF 25 Blu 6501 7652 Open 7!3/2007 MD Virison Service 14-Mar- 2006 25 Blu 6501 7652 Open 7/3/2007 TVD Virison Service 14- Mar-2006 Sample Set Sent Received Number Comments Daily History Received? L,y"' Formation Tops Q/ N DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060270 Well Name/No. PRUDHOE BAY UN ORIN L-214A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23258-01-00 MD 7652 TVD 4825 Completion Date 3!1/2006 Completion Status WAGIN Current Status WAGIN UI/C~`~Y Compliance Reviewed By: --- _ -- _ _ _ --- -____._ _ Date: _ ~ ~ _ ~~Vu ~ onoz/o7 r" Schtu~a~erg~r Schlumberger-DCS 2525 Gambelt St, Suite 400 Anchorage, AK 89503-2838 ATTN: Beth Well Job # Log Description N0.4326 Company: Alaska Oi18 Gas Cons Comm Attn: Christine Mahnken 333 Weat 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Date BL Color CD L-214A 40013220 OH EDIT MWD/LWD 03114/06 2 1 L-217 40013757 OH EDIT MWD/LWD 07N0/06 2 1 L-250L2 40012593 OH EDIT MWD/LWD 11124!05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: u~zc ~~ - ~` ~ tsas~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: =~r Ss Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # REGE11/ED SEP 1 2 2006 '*+MilDliiF 1i/1{ Q A~y~~p,y~~,. ~/1Atu~Y~A1 Nllal~~ Log Description NO. 3947 Company: Alaska Oil & Gas Cons Comm AHn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Date BL Color CD S-03 11223120 PPROF & RST WFL 06/13106 1 L-214 11054295 CH EDIT OF PDC FROM UBI 05127105 1 L-214A 11217230. CH EDIT OF PDC FROM USIT 03119106 1 L-210 10687666 CH EDIT OF PDC FROM USIT 01114/04 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO BP Exploration (Alaska)Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 995084254 Date Delivered: Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~~~ ~~~y ~~~ ~ ~~! ~~.~ 08,28/00 • Scb~ger Sehlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503.2838 ATTN: Beth ~ ~~~ . ~'`~~ l.J ~" Well Job # Log Description NO. 3838 Company: Alaska Oil ti Gas Cons Comm ANn: Christine Mahnken 333 West 7th Ave, Sufte 100 Anchorage, AK 99507 Field: Orion Borealis Date BL Color CD L-200L~ 40010090 OH LDWG EDIT OF MWD/LWD 02/18104 2 7 Z-108 11225977 SCMT 06/04/06 1 L-214A 11217230 USIT 03/16/06 1 L•215 10913049 USIT 09/28/08 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ! / f°~ ~ (~ i Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ 7 Received by: ~ l~ 1 ~"°'~ REG'EIVED ~Ik~ Qii & t~~s Gons. C,mm~~issi~n Anchorage os/os/os • • MEMORANDUM To: .Tim Regg _ r P.I. Supervisor ~ ~ ~j" % ~;~ ~ ±~° FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 24, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA} INC L-214A PRUDHOE BAY iJN GRIN L-214A Src: Inspector NON-CONFIDENTIAL abb. oat Reviewed By: P.I. Suprv ~`~' Comm Well Name: PRUDHOE BAY UN ORIN L-214 Insp Num: mitJCr060524055326 Rel Insp Num API Well Number Permit Number: 50-029-23258-01-00 206-027-0 Inspector Name: John Crisp Inspection Date: 5/20/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I L-214A Type Inj. W ,W , 'r i 4421 ~ jA I 80 2000 ~ 1970 ~ 1960 ~ P.T. ~ 2060270 TypeTOSt I SPT ~ Test psi ~ 1500 OA ; 300 ~ 540 ~ 530 j 520 ~ Interval IIQITAL p~ P Tubing ~ I I80 i 1180 ~ 1180 1180 ~ Notes Wednesday, May 24, 2006 Page 1 of 1 • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Well No L-214A Installation/Rig Nabors 9ES Dispatched To: AOGCC -Librarian Date Dispatched: 8-May-O6 Dispatched By: Mauricio Perdomo Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: James H. Johnson Received By: ~` ~'~ BP Exploration (Alaska) Inc. (,~ ~ ~a,,~ ~ Petrotechnical Data Center (LR2-11 %e ~ ~ V~ V 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnso'hC~bp.com LWD Log Delivery V1.1,10-02-03 e~® U ~~ STATE OF ALASKA ALAS IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~,w .~ _~ 2~J~ F, i; t"1~tlIT1jSSl03~ 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAAC2s.,os 2oAAC2s.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: "` ' ` '~ ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 3/18/2006 12. Permit to Drill Number 206-027 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/13/2006 13. API Number 50-029-23258-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 3/14/2006 14. Well Name and Number: PBU L-214A FEL, SEC. 34, T12N, R11 E, UM 2430 FSL, 3515 Top of Productive Horizon: 2602' FSL, 1632' FWL, SEC. 35, T12N, R11 E, UM g_ KB Elevation (ft): 78.9' 15. Field /Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Total Depth: 2663' FSL, 1923' FWL, SEC. 35, T12N, R11 E, UM 9. Plug Back Depth (MD+TVD) 7572 + 4763 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583400 y- 5978154 Zone- ASP4 10. Total Depth (MD+TVD) 7652 + 4825 Ft 16. Property Designation: ADL 028238 TPI: x- 588546 y- 5978385 Zone- ASP4 Total Depth: x- 588835 Y- 5978450 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: th if ff h 1 W t d f P f t 20 Thi k 18. Directional Survey ®Yes ^ No , ore a er ep o s 9. N/A MSL ness o erma ros c . 1900 (Approx.) 21. Logs Run: LWD: DIR / GR / RES /DEN / NEU, USIT ASING, LINER AND EMENTING ECORD CASING ETTWG EPTN MD ETTtNG EPTH TVD HOLE OUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 109' Surface 109' 42" 260 sx Arctic Set Ap rox.) 13-3/8" 68# L-80 29' 3872' 29' 2715' 16" 957 sx Arcticset Lite, 605 sx'G' 9-5/8" 47# L-80 26' 6501' 26' 4004' 12-1 /4" 484 sx Class 'G', 491 sx Class 'G' 7" 26# L-80 6349' 7650' 3925' 4824' 8-1/2" 281 sx Class 'G' 23. Perforations open to Production (MD +TVD of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 7438' 7141' & 7239' & 7344' MD TVD MD TVD 7168' - 7218' 4442' - 4482' 7256' - 7290' 4512' - 4540' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7308' - 7326' 4554' - 4569' 7443' 7502' 4663' 4709' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED - - Freeze Protect w/ 207 Bbls of Diesel 26• PRODUCTION TEST Date First Production: April 19, 2006 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit cog-„chips; If none, state "none". ~~ l (' ~~r9,~1/yl~o rv~ None ..r~~ ~ ~~~ ~r~~. ~~Fi ~ ~ 2~~6 7 07 c~-1 JA~~..J V F1~! ~ / Form 10-407 Revised 12/2003 ~ ~ ~ f'~ ~ h~j~N~IED ON REVERSE SIDE 28. GEOLOGIC MARKS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Ugnu 4332' 2944' None Ugnu MA 6540' 4024' Ugnu M61 6629' 4068' Ugnu M62 6759' 4140' Ugnu MC 6895' 4234' Top Schrader Bluff NA 6985' 4301' Schrader Bluff NB 7004' 4316' Schrader Bluff NC 7044' 4346' Schrader Bluff NE 7055' 4354' Schrader Bluff NF 7120' 4404' Schrader Bluff OA 7166' 4441' Schrader Bluff OBa 7256' 4512' Schrader Bluff OBb 7308' 4554' Schrader Bluff OBc 7377' 4610' Schrader Bluff OBd 7444' 4663' Schrader Bluff OBe 7520' 4723' Schrader Bluff OBf 7586' 4774' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date / ''~1 Q(p PBU L-214A 206-027 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. orirringEngineer: Scott Ko/stad, 564-5347 INSTRUCTIONS GeNeRn~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 4b: TPI (Top of Producing Interval). Irene 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. Irene 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Irene 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 3/20/2006 12: i 1:45 PM BP EXPLORATION Operations Summary Report Page 1 of 7 Legal Well Common W Event Nam Contractor Rig Name: Date ; Name: ell Name: e: Name: From - To L-214 L-214A REENTE NABOBS NABOBS Hours R+COM ALASK 9ES Task PLET A DRI Code I E LLING NPT Start I Rig Rig Phase ! Spud Date: 5/15/2005 : 3/9/2006 End: 3/18/2006 Release: 3/i 8/2006 Number: Description of Operations 3/9/2006 00:00 - 02:00 2.00 MOB P PRE PJSM on rig move. Pull pits away from sub base. 02:00 - 03:00 1.00 MOB P PRE Rig down cattle chute. 03:00 - 04:00 1.00 MOB P PRE Unpin and lower derrick. 04:00 - 06:00 2.00 MOB P PRE Move sub off of V-112i. Position rig to leave V-Pad. 06:00 - 09:00 3.00 MOB P PRE Move rig from V-Pad to L-Pad. 09:00 - 12:00 3.00 MOB P PRE Set matting boards and lay herculite. Spot rig on L-214Ai 12:00 - 13:00 1.00 MOB P PRE Position and spot mud complex. 13:00 - 14:00 1.00 MOB P PRE Raise derrick and cattle chute. Start taking on heated seawater. Accept rig for operations on L-214Ai C~ 14:00 hr 3/9/2006. 14:00 - 17:00 3.00 RIGU P DECOMP Bridle down, pin blocks, secure bridle line in derrick. Remove beam over Iron Roughneck. Rig up floor. 17:00 - 18:30 1.50 KILL P DECOMP Rig up lines for pumping out freeze cap. Set cuttings tank by mud complex. 18:30 - 19:00 0.50 KILL P DECOMP Hold Pre-Spud meeting with all personnel 19:00 - 20:30 1.50 DHB P DECOMP Attempt to retrieve BPV. Ice above BPV several inches. Heat up wellhead. Retrieve BPV - OK. Tbg - 0 psi, Tbg ann - 0 psi. 20:30 - 23:00 2.50 KILL P DECOMP Fill and pressure test surface lines to 3,500 psi - OK. Reverse circulate with 8.5 ppg, 180 deg seawater down tubing annulus and take diesel returns from tubing through choke C~ 3 bpm, 310 psi. Shut down, wait 15 minutes, line up to pump down tubing. Displace annulus diesel ~ 3 bpm, 135 psi. Recovered total of 150 bbls diesel plus 25 bbls of diesel/seawater mix. 23:00 - 00:00 1.00 KILL P DECOMP Circulate complete tubing and annulus volume with 8.5 ppg heated seawater @ 4 bpm, 180 psi. 3/10/2006 00:00 - 00:30 0.50 KILL P DECOMP Continue circulate with 8.5 ppg heated seawater. Shut down pumps, check for flow - no flow. 00:30 - 01:00 0.50 DHB P DECOMP Install 2-way check valve with dry rod. Test same to 1,000 psi from below - OK. 01:00 - 01:30 0.50 DHB P DECOMP Blow down, rig down surface lines. 01:30 - 04:00 2.50 WHSUR P DECOMP Bleed off pressure from metal to metal seal void. Nipple down tree adapter flange and tree. 04:00 -04:30 0.50 WHSUR P DECOMP Inspect tubing hanger threads. Function test tubing spool lock-down screws - OK. 04:30 - 12:00 7.50 BOPSU P DECOMP Nipple up BOPE. Removed 13-5/8" x 11"adaptor spool from BOP. Install 13-5/8" x 13-5/8" mud cross spacer spool. 12:00 - 13:00 1.00 BOPSU P DECOMP Rig up to test ROPE 13:00 - 16:30 3.50 BOPSU P DECOMP Test BOPE to 250 psi low, 4,000 psi high. Annular to 250 psi low, 3,500 psi high. Accumulator Drill/Test. Witnessing of test waived by AOGCC rep Chuck Scheve. Test witnessed by BP WSL Brian Buzby, NAD TP Bill Bixby. 16:30 - 17:00 0.50 BOPSU P DECOMP Rig down BOPE test equipment. 17:00 - 18:30 1.50 DHB P DECOMP Pull 2-way check valve with lubricator. 18:30 - 19:30 1.00 PULL P DECOMP Make up crossovers from tubing hanger to 4" drill pipe. Pull tubing hanger to rig floor with pick up weight of 100k. 19:30 - 20:00 0.50 PULL P DECOMP Circulate bottoms up C~3 588 gpm, 575 psi. No gas or oil to surface. 20:00 - 21:00 1.00 PULL P DECOMP Finish rigging up Haliburton spool and tubing equipment. 21:00 - 21:30 0.50 PULL P DECOMP Well U-tubing up tubing. Circulate bottoms up while mixing dry job. 21:30 - 22:00 0.50 PULL P DECOMP Lay down drill pipe joint, crossovers. Lay down tubing hanger. 22:00 - 00:00 2.00 PULL P DECOMP POH laying down 4.5" 12.6# L-80 TCII tubing. Remove and count clamps, spooling up wire as pipe is pulled Printed: 3/20/2006 12:11:50 PM BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214A Spud Date: 5/15/2005 REENTER+COMPLETE Start: 3/9/2006 End: 3/18/2006 NABORS ALASKA DRILLING I Rig Release: 3/18/2006 NABORS 9ES Rig Number: Date ~! From - To Hours Task Code NPT 3/11 /2006 ~ 00:00 - 09:30 9.50 PULL P 09:30 - 11:00 1.50 PULL P 11:00 - 11:30 0.50 CLEAN P 11:30 - 12:00 0.50 WHSUR P 12:00 - 15:00 3.00 CLEAN P 15:00 - 16:30 ' 1.50 CLEAN P 16:30 - 17:00 0.50 CLEAN P 17:00 - 18:00 1.00 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 19:00 0.50 CLEAN P 19:00 - 23:30 4.50 CLEAN P 23:30 - 00:00 I 0.501 CLEAN I P 3/12/2006 100:00 - 01:00 ~ 1.001 CLEAN P 01:00 - 03:00 2.00 CLEAN P 03:00 - 04:00 1.00 CLEAN P 04:00 - 04:30 0.50 CLEAN P 04:30 - 05:30 1.00 PXA P 05:30 - 08:30 I 3.001 PXA I P 08:30 - 09:00 I 0.50 I PXA I P 09:00 - 10:00 1.00 STWHIP P 10:00 - 11:00 1.00 STWHIP P 11:00 - 12:00 1.00 STWHIP P 12:00 - 16:00 4.00 STWHIP P 16:00 - 16:30 I 0.501 STWHIPI P 16:30- 17:00 I 0.501 STWHIPIP 17:00 - 00:00 I 7.001 STWHIPI P 3/13/2006 100:00 - 01:15 I 1.251 STWHIPI P 01:15 - 05:30 I 4.251 STWHIPI P 05:30 - 07:00 I 1.501 STWHIPI P Phase ! Description of Operations -i - __ -_ _ __ ---- -- DECOMP Continue POH with 4.5" 12.6# L-80 TCII tubing from 6,400' to surface. Recovered total of 159 joints plus 21.89' of cut-off 'i joint. Recovered all pins, clamps, and I Wire. Clean cut on '~ tubing and I Wire. DECOMP Rig down tubing equipment, clear rig floor. DECOMP Pick up Baker tools to rig floor. DECOMP Install wear bushing. DECOMP Pick up and RIH with 21 joints 4" HWDP, 60 joints 4" drill pipe to 2,529'. DECOMP POH from 2,529' to surface. DECOMP Pick up, make up Baker mill assembly BHA #1 for hole gauge run. DECOMP Pick up 9 6-1/2" steal drill collars. II DECOMP RIH with BHA #1 on 4" HWDP to 1,026'. DECOMP Service topdrive, traveling blocks, and drawworks. DECOMP Continue RIH with BHA #1, picking up 4" drill pipe from 1,026' to 6,130'. DECOMP Continue RIH with BHA #1, running 4" drill pipe out of derrick from 6,130" to 6,800'. DECOMP Wash from 6,800' to top of cut tubing C~ 6,818'. Circulate bottoms up ~ 500 gpm, 1,760 psi, 60 rpm, 8k TO, PU - 150k, SO - 88k, RT - 115k, MW - 8.5 ppg. DECOMP POH with BHA #1 from 6,818' to 1,025'. DECOMP Stand back HWDP and drill collars. ~ DECOMP Lay down BHA #1. DECOMP PJSM with Baker and Schlumberger on setting WL bridge plug. Rig up SLB wireline and bridge plug. DECOMP RIH with Baker bridge plug on wireline to plug and abandon L-2141. Set EZSV bridge plug @ 6,520'. POH with wireline, rig down same. DECOMP Test EZSV bridge plug and 9-5/8" casing to 4,000 psi - 15 minutes - 0 pressure loss. WEXIT PJSM on BHA. Pick up, make up whipstock BHA #2. WEXIT RIH with BHA #2 on 6-1/2" drill collars and 4" HWDP. WEXIT Shallow hole test MWD C~3 565 gpm, 1,045 psi - OK. WEXIT RIH with BHA #2 on 4" drill pipe from 1,025' to top of EZSV (~ 6,523' drill pipe measurement. WEXIT Orient 63 deg left of high side. PU - 140k, SO - 90k. Set down 20k to set bottom anchor. Pick up 10k over string weight to ', verify anchor set. Slack off and set down 35k to shear out. Whipstock set with top of window @ 6,501', bottom of window ~ 6,518'. WEXIT Displace well from 8.5 ppg seawater to 9.4 ppg LSND mud C~ 585 gpm, 1,320 psi. WEXIT Mill 47# 9-5/8" casing window from 6;501' to 6,511'. 588 gpm, 1,570 psi, 90 rpm, 6k TO OFF, 9k TO ON, 7k WOB. PU - 140k, SO - 90k. WEXIT Continue milling 47# 9-5/8" casing window from 6,511 to 6 518". 588 gpm, 1,570 psi, 90 rpm, 6k TO OFF, 9k TO ON, 7k WOB. PU - 130k, SO - 90k. WEXIT Drili 20' new hole from 6,518' to 6,538'. 588 gpm, 1,670 psi, 105 rpm, 8.5k TO. WEXIT Pull above window and work back through several times. Printed: 3/20/2006 12:11:50 PM BP EXPLORATfON Page 3 of 7 Operations Summary Report Legal Well Name: L-214 Common W ell Name: L-214A Spud Date: 5/15/2005 Event Nam e: REENTE R+COM PLET E Start : 3/9/2006 End: 3/18/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 3/18/2006 Rig Name: NABOB S 9ES Rig Number: Date 'I From - To 'Hours I, Task Code NPT ~ Phase ! Description of Operations i ~ - - - - -- _ - -- - - - - 3/13/2006 05:30 - 07:00 i 1.50 STWHIP P WEXIT Circulate high vis sweep surface to surface ~ 585 gpm, 1,650 ~ psi, 100 rpm, 9k TO. 07:00 - 07:30 0.50 STWHIP P WEXIT Perform FIT. TMD - 6,818', TVD - 4,012', PSI - 338 psi, MW - 9.4 ppg, EMW - 11.0 ppg. 07:30 - 10:00 2.50 STWHIP P WEXIT Monitor well, 9.4 ppg MW, pump dry job. POH from 6,500' to 380'. 10:00 - 11:00 1.00 STWHIP P WEXIT PJSM. Lay down 9 6-1/2" drill collars. 11:00 - 12:00 1.00 STWHIP P WEXIT Lay down window milling assembly BHA #2. Upper mill "in gauge". 12:00 - 13:00 1.00 STWHIP P WEXIT Pick up ported sub and flush out BOP stack. 13:00 - 15:00 2.00 STWHIP P WEXIT PJSM on nuclear source. Pick up directional drilling BHA #3 15:00 - 15:30 0.50 STWHIP P WEXIT RIH with BHA #3 on 7 stands 4" HWDP and 2 stands 4" drill pipe from 256' to 1,090'. 15:30 - 16:00 0.50 STWHIP P WEXIT Shallow hole test MWD C3 585 gpm, 1,060 psi - OK. 16:00 - 18:00 2.00 STWHIP P WEXIT Continue RIH with BHA #4 on 4" drill pipe from 1,090' to 6,440'. 18:00 - 18:30 0.50 STWHIP P WEXIT Service topdrive, crown section, traveling blocks, and drawworks. 18:30 - 19:00 0.50 STWHIP P WEXIT RIH 1 stand. Orient 63 deg left of high side, shut down pump and go through window without problem. PU - 140k, SO - 85k without pump @ window. Acquire slow pump rates. 19:00 - 00:00 5.00 DRILL P PROD1 Directionally drill from 6,538' to 6,822' - 100% sliding. GPM - 585 gpm, PSI OFF - 2,010 psi, PSI ON - 2,150 psi, RPM - 60 rpm, TQ OFF - 7.5k, WOB - 5k, PU - 140k, SO - 85k, RT - 109k. AST - 1.51 hrs, ART - 0.0 hrs. Backream each stand, survey every 30'. 3/14/2006 00:00 - 06:00 6.00 DRILL P PROD1 Directionally drill from 6,822' to 7,652' (TD). GPM - 585 gpm, PSI OFF - 2,330 psi, PSI ON - 2,590 psi, RPM - 80 rpm, TO OFF - 9.3k, TO ON - 10.5k, WOB - 5-10k, PU - 153k, SO - 90k, RT - 122k. Backream each stand, survey every 30'. AST - 1.92, ART - 2.28 06:00 - 06:30 0.50 DRILL P PROD1 Circulate an open hole volume at 585 gpm, 100 rpm, 2,400 psi. MW in - 9.4 ppg, MW out - 9.4 ppg. 06:30 - 09:30 3.00 DRILL P PROD1 MAD pass log the well from TD to 6,520' - 585 gpm, 2,380 psi, 70 rpm, TO - 9.5k, PU - 153k, SO - 86k, RT - 122k. 09:30 - 10:00 0.50 DRILL P PROD1 Orient and pull the BHA through the window to 6,440'. 10:00 - 11:00 1.00 DRILL P PROD1 Circulate a high vise sweep from surface to surface - 585 gpm, 2,170 psi, 70 rpm, TO - 8.5k, PU - 150k, SO - 75k, MW in - 9.4 ppg, MW out - 9.4 ppg. 11:00 - 13:30 2.50 DRILL P PROD1 Monitor the well -stable. POH standing back 4" DP from 6,440' to the top of the HWDP at 902'. 13:30 - 14:30 1.00 DRILL P PROD1 Slip and cut 81' of drilling line. 14:30 - 17:00 2.50 DRILL P PROD1 Hold PJSM for LD BHA#3 and removal of nuclear source. Stand back the 4" HWDP. LD the jar stand, xo, 2 x nm flex dc's. Remove nuclear source and LD the ADN, MWD, ARC, nm stab, motor and bit. 8.5" DSX147gvw bit graded: 1-1-CT-A-X-I-BT-TD. 17:00 - 17:30 0.50 DRILL P PROD1 Clear and clean the floor. Function the blind/shear rams. 17:30 - 18:30 1.00 CASE P RUNPRD RU the casing handling tools to run 7" 26# L-80 BTC liner. Bring cement head to the rig floor. 18:30 - 23:00 4.50 CASE P RUNPRD Hold PJSM. PU and RIH with 7" 26# L-80 BTC liner. Checked the floats after running in the hole with the shoe tract.- holding. Each connection of the shoe tract was Bakerloc'd. Continue RIH with 7" Liner utilizing BOL 2000 NM thread lubricant Printed: 3/20/2006 12:11:50 PM BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: L-214 Common W ell Name: L-214A Spud Date: 5/15/2005 Event Nam e: REENTE R+COM PLET E Start : 3/9/2006 End: 3/18/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 3/18/2006 Rig Name: NABOB S 9ES Rig Number: Date From - To Hours ! Task Code NPT ' Phase Description of Operations - 3/14/2006 ~ 18:30 - 23:00 4.50 CASE P i RUNPRD torqued to mark with 8,500 ft-Ibs. MU and RIH with the HMC liner hanger, ZXP packer and setting tool to 1,314'. Ran a total of 55 centralizers and 27 stop rings. 23:00 - 00:00 1.00 CASE P RUNPRD Changeout handing equipment to 4" DP. Clear and clean the floor of casing running tools. Crossover to 4" DP. 3/15/2006 ' 00:00 - 00:30 0.50 CASE P RUNPRD Circulate liner volume to ensure pipe is full and to verify circulation through the float equipment -good. 1 00:30 -04:00 3.50 CASE P RUNPRD RIH with 7" 26# L-80 BTC liner on 4" HWDP and 4" DP from 1,314' filling pipe every 10 stands. i 04:00 - 05:30 1.50 CASE P RUNPRD Circulate and condition the mud prior to going into the open hole while staging up the pumps to 6 bpm, 540 psi. 05:30 - 06:00 0.50 CASE P RUNPRD MU and LD the cement head prior to going into the open hole. 06;00 - 06:30 0.50 CASE P RUNPRD RiH through the window to 6,642' -hit restriction. 06;30 - 09:30 3.00 CASE P RUNPRD Wash and work the pipe from 6,642' to 6,863' -pipe moving freely 09:30 - 10:30 1.00 CASE P RUNPRD RIH from 6,863' to 7,628'. MU cement head and single. RIH and tag bottom at 7,652'. 10:30 - 11:30 1.00 CEMT P RUNPRD Circulate and condition the mud prior to cementing operations. Stage up the pumps to 6 bpm, 712 psi. Batch up the cement. Hold PJSM for cementing operations. 11:30 - 12:50 1.33 CEMT P RUNPRD Line up to Schlumberger and pump 5 bbls of fresh water. Shut in and pressure test the lines to 4,000 psi -good. Pump 25 bbls of 8.33 ppg CW 100 preflush at 5 bpm while reciprocating, ICP - 685 psi, FCP - 710 psi. Pump 80 bbls of 12.0 ppg Mudpush II spacer at 5 bpm while reciprocating, ICP - 567 psi, FCP - 110 psi. Pump 60 bbls of 15.8 ppg GasBlok Class G slurry + adds at 5 bpm while reciprocating, ICP - 242 psi, FCP - 240 psi. Wash through the "T" on the rig floor with 5 bbls of fresh water. Line up to the rig, drop the dart and displace the cement with 9.4 ppg brine. Displace with the rig at 6 bpm while reciprocating and catch the falling cement after 28 bbls pumped. Drop the rate to 5 bpm and continue displacement until 53 bbls pumped, ICP - 450 psi, FCP - 590 psi. Drop the rate to 3.8 bpm to pick up the plug, ICP - 380 psi. Pick up the plug with 62 bbls pumped -stop reciprocation and spot the liner on depth. Continue displacement and bump the plug on strokes with 109.5 bbls of 9.4 ppg brine - 98% efficiency. CIP - 1250 hours. 12:50 - 13:10 0.33 CASE P RUNPRD Pressure up to 3,000 psi to set the HMC hanger -good indication of set. Slack off 50k and increase the pressure to 4,200 psi to set the ZXP packer -good indication of set. Hold pressure for 5 minutes -good. Bleed off the pressure and check the floats -holding. PU 75k and apply 10 turns to the right to release the running tool. Pressure up to 1,000 psi and PU to expose the dog sub and observe pressure loss. Bring the rate up to 6 bpm, 925 psi to clear the top of the liner of cement with 20 bbls of 9.4 ppg brine pumped. Rotate with 10 rpm and set down 50k on the ZXP packer to ensure set. Repeat several times to ensure ZXP packer is set. 13:10 - 14:00 0.83 CASE P RUNPRD Displace the well over to 9.4 ppg brine - 13 bpm, 2,000 psi - 20 bbls of cement circulated to surface. 14:00 - 15:30 1.50 CASE P RUNPRD Break out and LD the cement head in the mouse hole. Blow down the surface lines and clean the cement out of the possum Printed: 3/20/2006 12:11:50 PM BP EXPLORATION Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Operations Summary Report Page 5 of 7 L-214 L-214A Spud Date: 5/15/2005 REENTER+COMPLETE Start: 3/9/2006 End: 3/18/2006 NABOBS ALASKA DRILLING I Rig Release: 3/18/2006 NABOBS 9ES Rig Number: Date ~ From - To Hours Task 3/15/2006 14:00 - 15:30 1.50 CASE 15:30 - 19:00 3.50 CASE 19:00 - 21:30 2.50 CEMT 21:30 - 22:30 1.00 CASE 22:30 - 00:00 1.50 PERFO 3/16/2006 00:00 - 03:00 3.00 PERFO 03:00 - 06:00 3.00 PERFO 06:00 - 08:00 2.00 PERFO 08:00 - 08:30 0.50 PERFO I Code NPT ~ Phase ' Description of Operations P _ RUNPRD _ __ bellies. P RUNPRD POH from 6,349' standing back the 4" DP and 4" HWDP. LD the running tool P RUNPRD While waiting on cement to reach 1,000 psi compressive strength, service and lubricate the rig and top drive, clean the mud pits, changeout the rotator seal on the draw-works P RUNPRD Line up to pressure test the 9-5/8" x 7" casinglliner. Pressure test the casinglliner to 4,000 psi. Chart and hold for 30 minutes -good. Bleed off pressure and blow down the surface equipment. P OTHCMP Load the perforating guns in the shed and RU to DPC perforate the well. ' P OTHCMP Hold PJSM with the rig crew and Schlumberger. PU and RIH with 4.5" 5SPF PowerJet perforating guns, Slimpulse MW D, 7 stands of 4" HWDP, i0' pup, 15' pup, and 1 stand of 4" DP to ~ 1,108'. Screw into the pipe with the top drive and shallow test the MW D -good. P OTHCMP RIH with perforating guns on 4" DP from 1,108' and tag up on the insert landing collar at 7,570' MD. P OTHCMP Correlate depth with the Slimpulse tool and log the lower RA tag and the formation to verify perforating depths. Position the perforating guns with the bottom shot on depth at 7,502'. ' P OTHCMP Hold PJSM for firing the guns. Go through the E-fire sequence and fire the guns on depth -good indication at the surface of the guns firing. Lost 11 bbls of 9.4 ppg brine after perforating the well. 08:30 - 09:00 0.50 PERFO P 09:00 - 10:00 1.00 PERFO P 10:00 - 12:00 2.00 PERFO P 12:00 - 15:30 3.50 PERFO P 15:30 - 18:30 3.00 PERFO P 18:30 - 19:30 1.00 PERFO P 19:30 - 20:30 1.00 PERFO P 20:30 - 00:00 3.50 EVAL P 3/17/2006 100:00 - 01:00 01:00 - 05:30 1.00 EVAL P 4.50 EVAL P 4.5" 5SPF PowerJet Perforation Intervals: 7,168' - 7,218' 7,256' - 7,290' 7,308' - 7,326' 7,443' - 7,502' OTHCMP Monitor the well -slight losses. POH above the top shot to 7,124'. OTHCMP Circulate a bottoms up - 264 gpm, 810 psi, PU - 150k, SO - 80k, 9.4 ppg brine going in and coming out of the well. Lost 5 bbls of 9.4 ppg brine while~circulating. OTHCMP Monitor the well -slight tosses. POH LDDP from 7,124' to 6,000'. Lost 25 bbls of 9.4 ppg brine since perforating the well. OTHCMP Continue to POH LDDP from 6,000' to 1,083'. OTHCMP Hold PJSM for LD perf guns. LD the 4" HWDP, Slimpulse, bumper sub and perforating guns from 1,083' -all guns fired. OTHCMP RD handling equipment. Clear and clean the floor. OTHCMP RIH with 10 stands of 4" DP from the derrick. LD 30 joints of 4" DP. OTHCMP Install 7" Lubricator extension. Hold PJSM for wireline work. Make 6.05" GR/JB runs to clean the well. Lost 22 bbls of 9.4 ppg brine since 1200 -Total losses to the well - 47 bbls of 9.4 ppg brine OTHCMP Complete 2 runs with the 6.05" GR/JB with no junk. RD GR/JB. OTHCMP RU USIT and RIH to log the cement quality across the 7" Liner.RD Schlumberger E-line and LD tools Printed: 3/20/2006 12:11:50 PM BP EXPLORATION Operations Summary Report Page 6 of 7 Legal Well Name: L-214 Common Well Name: L-214A Spud Date: 5/15/2005 Event Name: REENTER+COMPLETE Start: 3/9/2006 End: 3/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/18/2006 Rig Name: NABOBS 9ES Rig Number: Date ;From - To Hours !i Task 'Code'! NPT Phase Description of Operations 7/2006 05:30 - 07:00 1.50 BUNCO -- -'-_ - - -- -_ _ _ - - - I~P RUNCMP RU tubing handling equipment. Pull wear ring. Make dummy run with hanger -good. 07:00.- 21:30 14.50 RUNCOI~ RUNCMP PU and RIH with 227 joints of 3.5" 9.2# L-80 TCII Straddle Packer completion + jewelry utilizing Jet Lube Seal Guard lubricant and a torque of 2,300 ft-Ibs. All connections 'torque turned' and charted on computer. The connections below the lower packer have been Bakerlok'd. W LEG - 7,438' X Nipple (2.813" ID} - 7,426' X Nipple (2.813" ID) - 7,405' 3.5" x 1.5" MMG-W WFM - 7,381' X Nipple w/ RHC-M plug (2.813" ID) - 7,365' 7" x 3.5" Premier Packer - 7,344' 3.5" x 1.5" MMG-W WFM - 7,320' 3.5" x 1.5" MMG-W WFM - 7,260' 7" x 3.5" Premier Packer - 7,239' X Nipple (2.813" ID) - 7,227' RA tag in centralizer - 7,222' 3.5" x 1.5" MMG-W WFM - 7,208' 3.5" x 1.5" MMG-W WFM - 7,157' 7" x 3.5" Premier Packer - 7,141' X Nipple (2.813" ID) - 7,130' 3.5" x 1.5" MMG GLM w/DCR SV - 7,102' X Nipple (2.813" ID) - 2,799' 21:30 - 22:00 0.50 BUNCO RUNCMP MU hanger and landing joint - PU - 93k, SO - 62k. 22:00 - 23:30 1.50 BUNCO WAIT RUNCMP RD and LD tubing handling equipment while waiting on brine trucks to arrive on location due to weather delays -Phase 2 / Level 2 23:30 - 00:00 0.50 BUNCO RUNCMP Land tubing on hanger and RILDS -torqued to 450 ft-Ibs, Gland nuts torqued to 350 ft-Ibs. Lost 3 bbls of 9.4 ppg brine to the well for the day. 3/18/2006 00:00 - 06:00 6.00 BUNCO RUNCMP RU and reverse circulate clean 9.4 ppg brine surface to surface followed by corrosion inhibited brine. 06:00 - 11:00 5.00 BUNCO RUNCMP RD landing joint and drop the 1-5/16" ball and rod and allow to seat. Blow down surface lines. Pressure up to 4,200 psi and observe good surface indications of packers setting. Attempt to hold presure for 30 minutes -pressure dropped 800 psi. Apply 3,000 psi to the tubing and pressure test the annulus to 4,000 psi to confirm packer set -chart and hold for 30 minutes - good. Bleed the annulus to 0 psi and then bleed the tubing pressure to 0 psi. Attempt several times to pressure test the tubing to 4,000 psi without success. Attempt to get the ball and ~'~~ rod to seat back in the RHC-M plug. Test the tubing to 4,000 ~ psi -chart and hold for 30 minutes -good. Bleed pressure on ~~ _~ the tubing to 0 psi. Pressure up on the annulus to 2,350 psi and observe the DCR valve shear. Blow down the choke and kill lines. Dry rod install the TWC and test from below with 1,000 psi -good. 11:00 - 13:30 2.50 BOPSU P RUNCMP ND BOPE. 13:30 - 15:00 1.50 WHSUR P RUNCMP Clean and NU the tree. Test packoff to 5,000 psi -good. 15:00 - 16:30 1.50 WHSUR P RUNCMP RU DSM and open the actuator valve with hydraulic press. Printed: 3/20/2006 12:17:50 PM BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: L-214 Common Well Name: L-214A Spud Date: 5/15/2005 Event Name: REENTER+COMPLETE Start: 3/9/2006 End: 3/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/18/2006 Rig Name: NABOBS 9ES Rig Number: Date ,From - To Hours ~ Task ~ Code i NPT Phase Description of Operations 3/18/2006 15:00 - 16:30 1.50 WHSUR P RUNCMP Test the tree to 5,000 psi -good. RU and pull the TWC with DSM lubricator. 16:30 - 21:00 4.50 WHSUR i P RUNCMP PJSM. RU LRHOS to freeze protect the well with diesel. Pressure test the lines to 3,000 psi -good. Pump 207 bbls of ! diesel freeze protection fluid at 2.5 bpm, 800 psi. Shut down and allow the diesel to u-tube into the tubing. 21:00 - 23:00 2.00 WHSUR P RUNCMP Install BPV with DSM and test from below to 1,000 psi -good. Remove the double annulus valves and install VR plugs. RD DSM and LRHOS. Secure the tree and the cellar for the rig move. 23:00 - 00:00 1.00 WHSUR , P RUNCMP RD and prepare the rig floor for a derrick down move to I-100. Rig released to I-100 at 2400 hours 3/18/06 Printed: 3/20/2006 12:11:50 PM by . ~.. _ .. ~ Schlurnberger ~- ~-~.~ 4H ~u Report Date: March 22, 200E Client: BP Exploration Alaski Field: Prudhoe Bay Unit - WOA Structure I Slot: L-PAD / S-W we11: L-214 Borehole: L-214A UwuAPgt: 500292325801 Survey Name I Date: L-214A /March 15, 200E Tort I AHD 1 DDI 1 ERD ratio: 185.046° / 5479.51 ft / 6.206 / 1.131 Gdd Coordinate System: NAD27 Alaska State Planes, Zone 04, US Fee Location LaULong: N 70 21 1.008, W 14919 22.364 Location Grid NIE YIX: N 5978154.310 ftUS, E 583400.480 ftU: Grid Convergence Angle: +0.63769163° rceport Vertical Section Azimuth: 88.690° Vertical Section Origin: N 0.000 ft, E 0.000 fl TVD Reference Datum: Rotary Table TVD Reference Elevation: 78.90 ft relative to MSL Sea Bed 1 Ground Level Elevation: 50.40 ft relative to MSL Magnetic Declination: 24.293° Total Field Strength: 57578.840 nT Magnetic Dip: 80.853° Declination Date: March 15, 200E Magnetic Declination Model: BGGM 2005 North Reference: TNe North Total Corr Mag North -> True North: +24.293° Local Coordinates Referenced To: Well Head Comments Measured InGination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longhude Depth Section Departure ft de d ft ft k ft k ft k d 100 k ftUS ftUS ~~~~ Ftlt U.W U.UU U.UU -/B.YU U.UU U.UU U.VV U.W U.W U.VV V.uu aaror~.a~ :ro 7gw.yo ~~ rV c~ ~.wu rr era ~a cc.ava First GYD-GC-SS 100.00 0.22 276.22 21.10 100.00 -0.19 0.19 0.19 0.02 -0.19 0.22 5978154.33 583400.29 N 70 21 1.008 W 14919 22.375 200.00 0.24 315.38 121.10 200.00 -0.52 0.58 0.56 0.19 -0.53 0.16 5978154.49 583399.95 N 70 21 1.010 W 14919 22.385 300.00 1.20 344.19 221.09 299.99 -0.93 1.82 1.66 1.35 -0.96 1.00 5978155.65 583399.50 N 70 21 1.021 W 14919 22.397 400.00 4.24 24.55 320.97 399.87 0.42 6.42 5.73 5.72 0.29 3.42 5978160.03 583400.71 N 70 21 1.064 W 14919 22.361 500.00 8.65 42.65 420.32 499.22 7.26 17.56 16.17 14.62 6.92 4.80 5978169.00 583407.24 N 70 21 1.151 W 14919 22.167 600.00 13.48 59.43 518.46 597.36 22.66 36.62 34.17 26.09 22.07 5.76 5978180.64 583422.25 N 70 21 1.264 W 14919 21.724 Last GYD-GCBs 700.00 17.82 69.70 614.75 693.65 47.31 63.52 59.61 37.33 46.47 5.13 5978192.15 583446.53 N 70 21 1.375 W 14919 21.011 First MWD+IFR+MS 761.24 21.31 76.88 672.45 751.35 67.07 84.00 78.92 43.11 66.10 6.91 5978198.15 583466.09 N 70 21 1.432 W 14919 20.437 856.18 25.18 81.15 759.68 838.58 104.00 121.45 114.44 50.14 102.88 4.44 5978205.58 583502.78 N 70 21 1.501 W 14919 19.363 952.65 26.70 83.76 846.43 :925.33 145.94 163.64 155.04 55.65 144.70 1.97 5978211.56 583544.54 N 70 21 1.555 W 14919 1046.45 30.44 86.58 928.79 1007.69 190.70 208.49 198.47 59.36 189.39 4.24 5978215.77 583589.18 1 N 70 21 1.591 W 149191 1140.15 33.72 87.35 1008.18 1087.08 240.43 258.24 246.98 61.98 239.08 3.53 5978218.94 583638.83 N 70 21 1.617 W 149191 1235.68 34.28 84.63 1087.38 1166.28 293.78 311.66 299.65 65.72 292.35 1.70 5978223.27 583692.06 N 70 21 1.654 W 1491913.825 1330.95 35.90 86.00 1165.33 1244.23 348.45 366.42 353.96 70.18 346:93 1.89 5978228.34 583746.58 N 70 21 1.698 W 1491912.230 1423.76 38.07 85.81 1239.46 1318.36 404.21 422.25 409.40 74.17 402.62 2.34 5978232.95 583802.21 N 70 21 1.737 W 1491910.603 1517.65 39.30 87.00 1312.75 1391.65 462.85 480.93 467.71 77.84 461.19 1.53 5978237.27 583860.73 N 70 21 1.773 W 14919 8.891 1612.03 41.31 87.21 1384.72 1463.62 523.87 541.98 528.39 80.92 522.16 2.13 5978241.03 583921.66 N 70 21 1.803 W 14919 7.109 1706.83 43.30 87.02 1454.83 1533.73 587.65 605.79 591.89 84.14 585.88 2.10 5978244.95 583985.33 N 70 21 1.835 W 14919 5.247 1804.33 42.13 87.20 1526.47 1605.37 653.77 671.92 657.78 87.47 651.94 1.21 5978249.02 584051.34 N 70 21 1.868 W 14919 3.317 1898.78 42.34 89.08 1596.40 1675.30 717.24 735.41 720.96 89.53 715.38 1.36 5978251.79 584114.76 N 70 21 1.888 W 149191.462 1993.31 42.58 91.01 1666.14 1745.04 781.03 799.22 784.31 89.48 779.19 1.40 5978252.44 584178.55 N 70 21 1.887 W 14918 59.597 2085.82 45.21 91.87 1732.80 1811.70 845.09 863.35 847.87 87.85 843.31 2.92 5978251.54 584242.68 N 70 21 1.871 W 14918 57.724 2182.61 48.86 92.86 1798.76 1877.66 915.76 934.17 917.99 84.91 914.06 3.84 5978249.38 584313.45 N 70 21 1.842 W 14918 55.656 SurveyEditor Ver SP 1.0 Bld( doc4Ox_56) S-W\L-214\L-214A\L-214A Generated 4/24/2006 2:31 PM Page 1 of 4 Comments Measured inclination Azimuth Sub-Sea TVD ND Vertical Along Nole Closure NS EW DLS Northing Easting Latitude Longkude Oepth Section Departure k d d ft ft ft k k k k de If00ft kUS ftUS L"1/b.Ltf 53.liti aL.su 7ti7U./3 lasa.os `JtS/.tSb IuUt1.4:S aBa.oL 81.0/ yao.La ~.GU as/aLVO.aa .70Y38,.00 IY rucr ~.oiv vv rVa roo~.~w 2370.26 59.18 90.65 1909.25 1988.15 1066.86 1085.53 1068.29 79.67 1065,32 5.99 5978245.83 584464.74 N 70 21 1.791 W 14918 51.236 2463.99 59.57 91.10 1957.00 2035.90 1147.46 1166.18 1148.64 78.44 1145,96 0.59 5978245.49 584545.39 N 70 21 1.778 W 1491848.879 2556.68 60.63 91.51 2003.20 2082.10 1227.72 1246.53 1228.68 76.61 1226.29 1.21 5978244.55 584625.73 N 70 21 1.760 W 149 1846.531 2651.98 60.80 91.23 2049.82 2128.72 1310.75 1329.66 1311.51 74.62 f 309,39 0.31 5978243.49 584708.83 N 70 21 1.741 W 149 1844.103 2746.55 61.64 88.08 2095.36 2174.26 1393.61 1412.54 1394.29 75.13 1392.26 3.05 5978244.92 584791.69 N 70 21 1.745 W 149 18 41.681 2840.54 60.50 89.02 2140.82 2219.72 1475.87 1494.80 1476.51 77.22 1474.49 1.50 5978247.92 584873.88 N 70 21 1.766 W 14918 39.278 2935.20 59.91 90.70 2187.86 2266.76 1558.00 1576.94 1558.56 77.42 1556.63 1.66 5978249.04 584956.01 N 70 21 1.768 W 1491836.877 3030.00 61.08 88.69 2234.56 2313.46 1640.48 1659.44 1640.98 77.87 1639.13 2.22 5978250.41 585038.49 N 70 21 1.772 W 1491834.466 3123.48 61.65 88.79 2279.35 2358.25 1722.53 1741.49 1723.00 79.67 1721.16 0.62 5978253.12 585120.48 N 70 21 1.789 W 14918 32.069 3217.09 62.54 88.23 2323.16 2402.06 1805.25 f 824.21 1805.71 81.82 1803.85 1.09 5978256.20 5$5203.14 N 70 21 1.810 W 14918 3312.95 62.53 86.69 2367.38 2446.28 1890.28 1909.27 1890.76 85.59 1888.82 1.43 5978260.91 585288.05 N 70 21 1.847 W 14918 3407.31 62.24 87.34 2411.12 2490.02 1973.86 1992.88 1974.37 89.95 1972.32 0.68 5978266.19 585371.49 N 70 21 1.890 W 14918 24.729 3500.76 59.94 87.81 2456.29 2535.19 2055.64 2074.68 2056.17 93.41 2054.04 2.50 5978270.57 585453.16 N 70 21 1.924 W 14918 22.340 3595.50 61.40 89.47 2502.70 2581.60 2138.23 2157.27 2138.74 95.36 2136.61 2.17 5978273.44 585535.69 N 70 21 1.943 W 1491819.927 3689.44 60.96 87.99 2547.98 2626.88 2220.53 2239.57 2221.02 97.19 2218.89 1.46 5978276.17 585617.94 N 70 21 1.960 W 14918 17.522 3783.71 61.02 89.36 2593.70 2672.60 2302.97 2322.02 2303.44 99.09 2301.31 1.27 5978279.00 585700.32 N 70 21 1.979 W 1491815,114 3826.45 61.59 89.15 2614.22 2693.12 2340.46 2359.51 2340.91 99.58 2338.79 1.40 5978279.90 585737.80 N 70 21 1.984 W 1491814,018 ( Inc only + Trend) 3894.41 59.44 89.62 2647.67 2726.57 2399.61 2418.66 2400.04 100.22 2397.95 3.22 5978281.20 585796.94 N 70 21 1.990 W 1491812.290 3989.29 58.53 90.30 2696.56 2775.46 2480.90 2499.97 2481.29 100.28 2479.26 1.14 5978282.16 585878.24 N 70 21 1.990 W 14918 9.913 4085.58 60.85 91.75 2745.15 2824.05 2563.95 2583.10 2564.27 98.78 2562.36 2.74 5978281.59 585961.35 N 70 21 1.975 W 149 18 7.484 4779.75 61.19 91.53 2790.78 2869.68 2646.22 205.47 2646.47 96.42 2644.71 0.41 5978280.15 586043.70 N 70 21 1.951 W 14918 5.078 4273.98 60.27 90.84 2836.85 2915.75 2728.34 2747.67 2728.53 94.72 2726.89 1.17 5978279.36 586125.89 N 70 21 1.934 W 14918 2.676 4368.86 62.08 91.87 2882.60 2961.50 2811.37 2830.79 2811.51 92.75 2809.98 2.13 5978278.31 586208.99 N 70 21 1.915 W 14918 0.248 4462.58 61.23 91.84 2927.09 3005.99 2893.73 2913.28 2893.83 90.08 2892.42 0.91 5978276.56 586291.45 N 70 21 1.888 W 14917 57.839 4557.83 60.40 91.56 2973.54 3052.44 2976.77 2996.43 2976.83 87.61 2975.54 0.91 5978275.02 586374.59 N 70 21 1.864 W 14917 55.409 4653.01 59.91 91.79 3020.91 3099.81 3059.21 3078.99 3059.25 85.20 3058.07 0.56 5978273.52 586457.12 N 70 21 1.839 W 14917 52.998 4746.96 61.66 93.12 3066.76 3145.66 3141.03 3160.98 3141.05 81.68 3139.98 2.24 5978270.92 586539.06 N 70 21 1.805 W 1491750.604 4841.24 60.67 92.93 3112.23 3191.13 3223.38 3243.57 3223.39 77.32 3222.46 1.06 5978267.48 586621.57 N 70 21 1.769 W 14917 4 4935.88 59.47 93.26 3159.45 3238.35 3305.16 3325.59 3305.16 72.89 3304.35 1.30 5978263.96 586703.51 N 70 21 1.717 W 14917 5030.47 59.69 93.42 3207.34 3286.24 3386.46 3407.16 3386.47 68.14 3385.78 0.27 5978260.12 586784.98 N 70 21 1.670 W 14917 4 . 5124.41 59.50 92.14 3254.89 3333.79 3467.27 3488.18 3467.30 64.21 3466.71 1.19 5978257.09 586865.93 N 70 21 1.631 W 149 17 41.056 5218.55 61.10 92.26 3301.53 3380.43 3548.89 3569.95 3548.94 61.07 3548.42 1.70 5978254.86 586947.66 N 70 21 1.600 W 149 17 38.668 5312.50 61.83 91.60 3346.41 3425.31 3631.29 3652.49 3631.37 58.29 3630.91 0.99 5978253.00 587030.17 N 70 21 1.572 W 1491736.257 5407.89 61.02 91.94 3392.04 3470.94 3714.94 3736.26 3715.05 55.70 3714.64 0.91 5978251.34 587113.92 N 70 21 1.547 W 14917 33.8E 0 5501.83 60.06 89.94 3438.24 3517.14 3796.66 3818.05 3796.80 54.35 3796.41 2.12 5978250.90 587195.69 N 70 21 1.533 W 14917 31.420 5596.80 62.08 89.95 3484.18 3563.08 3879.76 3901.16 3879.91 54.43 3879.53 2.13 5978251.91 587278.79 N 70 21 1.533 W 14917 28.991 5690.29 61.02 90.00 3528.72 3607.62 3961.93 3983.36 3962.10 54.47 3961.72 1.13 5978252.86 587360.98 N 70 21 1.533 W 14917 26.589 5783.58 61.43 91.19 3573.62 3652.52 4043.66 4065.13 4043.84 53.62 4043.49 1.20 5978252.92 587442.74 N 70 21 1.524 W 14917 24.200 5878.44 62.93 89.92 3617.89 3696.79 4127.50 4149.02 4127.71 52.81 4127.38 1.98 5978253.05 587526.62 N 70 21 1.516 W 14917 21.748 5972.90 62.02 89.40 3661.55 3740.45 4211.26 4232.79 4211.48 53.31 421 f .14 f .08 5978254.47 587610.37 N 70 21 1.520 W 14917 19.300 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-W\L-214\L-214A\L-214A Generated 4/24/2006 2:31 PM Page 2 of 4 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latkude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS 6067.81 61.58 87.68 3706.40 3785.30 4294.90 4316.43 4295.11 55.44 4294.75 1.66 5978257.53 587693.95 N 70 21 1.541 W 14917 16.856 6161.37 60.73 87.92 3751.54 3830.44 4376.84 4398.38 4377.04 58.58 4376.64 0.94 5978261.59 587775.79 N 70 21 1.571 W 1491714.463 6254.63 59.64 87.36 3797.91 3876.81 4457.74 4479.30 4457.92 61.91 4457.49 1.28 5978265.82 587856.58 N 70 21 1.604 W 1491712.100 MWD+IFR+MS 6349.56 58.81 87.68 3846.48 3925.38 4539.28 4560.86 4539.45 65.44 4538.97 0.92 5978270.26 587938.02 N 70 21 1.638 W 14917 9.719 Tie-In Survey 6443.99 58.86 86.41 3895.35 3974.25 4620.05 4641.66 4620.19 69.61 4619.67 1.15 5978275.32 588018.65 N 70 21 1.678 W 14917 7.361 Top Window (Blind) 6501.00 58.54 86.10 3924.96 4003.86 4668.72 4690.37 4668.84 72.79 4668.27 0.73 5978279.04 588067.22 N 70 21 1.709 W 14917 5.940 Base Window (Blind) 6518.00 59.48 83.99 3933.72 4012.62 4683.26 4704.94 4683.38 74.05 4682.79 11.99 5978280.46 588081.72 N 70 21 1.722 W 14917 5.516 Inc + Trend 6564.51 60.18 80.95 3957.10 4036.00 4723.23 4745.15 4723.31 79.32 4722.65 5.85 5978286.18 588121.51 N 70 21 1.773 W 14917 4.351 Inc + Trend 6596.26 60.56 78.88 3972.80 4051.70 4750.50 4772.75 4750.56 84.16 4749.82 5.79 5978291.31 588148.62 N 70 21 1.821 W 14917 3.557 Inc + Trend 6628.31 61.05 76.79 3988.43 4067.33 4777.97 4800.73 4778.01 90.05 4777.16 5.89 5978297.51 588175.90 N 70 21 1.878 W 14917 2.757 Inc + Trend 6660.36 59.04 74.70 4004.43 4083.33 4805.03 4828.49 4805.05 96.88 4804.08 8.44 5978304.64 588202.73 N 70 21 1.945 W 14917 First MWD+IFR+MS 6691.82 56.01 72.64 4021.32 4100.22 4830.67 4855.03 4830.67 104.34 4829.54 11.10 5978312.38 588228.11 N 70 21 2.019 W 14917 6723.90 53.56 70.14 4039.82 4118.72 4855.69 4881.23 4855.69 112.69 4854.38 9.94 5978321.01 588252.85 N 70 21 2.101 W 14917 0.500 6755.98 51.12 70.84 4059.42 4138.32 4879.81 4906.63 4879.82 121.17 4878.31 7.80 5978329.75 588276.68 N 70 21 2.184 W 14916 59.801 6787.05 48.33 71.60 4079.51 4158.41 4902.42 4930.33 4902.45 128.81 4900.75 9.17 5978337.64 588299.03 N 70 21 2.259 W 14916 59.145 6819.08 45.86 74.52 4101.31 4180.21 4925.00 4953.79 4925.06 135.65 4923.19 10.20 5978344.73 588321.39 N 70 21 2.326 W 14916 58.489 6851.17 44.44 79.56 4123.95 4202.85 4947.27 4976.53 4947.34 140.76 4945.34 11.98 5978350.09 588343.48 N 70 21 2.376 W 149 16 57.841 6883.85 43.61 83.93 4147.45 4226.35 4969.80 4999.24 4969.89 144.03 4967.80 9.63 5978353.60 588365.91 N 70 21 2.408 W 14916 57.185 6914.88 41.88 87.26 4170.24 4249.14 4990.82 5020.29 4990.92 145.66 4988.80 9.17 5978355.46 588386.88 N 70 21 2.424 W 14916 56.571 6946.95 41.52 86.99 4194.19 4273.09 5012.15 5041.63 5012.25 146.73 5010.10 1.25 5978356.77 588408.17 N 70 21 2.434 W 14916 55.949 6978.76 41.86 84.33 4217.95 4296.85 5033.27 5062.78 5033.38 148.33 5031.19 5.66 5978358.61 588429.24 N 70 21 2.450 W 149 16 55.332 7010.49 41.68 82.84 4241.61 4320.51 5054.32 5083.92 5054.44 150.69 5052.20 3.18 5978361.20 588450.21 N 70 21 2.473 W 14916 54.718 7042.90 40.82 79.57 4265.98 4344.88 5075.50 5105.28 5075.65 153.95 5073.31 7.16 5978364.70 588471.29 N 70 21 2.505 W 14916 54.101 7074.34 40.31 77.88 4289.87 4368.77 5095.64 5125.73 5095.81 157.95 5093.36 3.85 5978368.91 588491.29 N 70 21 2.544 W 14916 53.515 7106.81 38.04 74.98 4315.04 4393.94 5115.68 5146.24 5115.88 162.75 5113.30 8.98 5978373.93 588511.17 N 70 21 2.591 W 14916 52.933 7138.17 37.86 75.03 4339.77 4418.67 5134.42 5165.52 5134.66 167.74 5131.92 0.58 5978379.13 588529.74 N 70 21 2.640 W 14916 52.388 7169.81 37.94 75.08 4364.73 4443.63 5153.31 5184.96 5153.60 172.75 5150.70 0.27 5978384.35 588548.46 N 70 21 2.689 W 14916 51.839 7201.74 37.70 74.97 4389.96 4468.86 5172.33 5204.54 5172.67 177.81 5169.62 0.78 5978389.62 588567.31 N 70 21 2.739 W 14916 51.286 7233.63 36.29 76.67 4415.43 4494.33 5191.04 5223.73 5191.43 182.51 5188.22 5.46 5978394.53 588585.86 N 70 21 2.785 W 14916 5 7266.28 36.19 77.11 4441.76 4520.66 5209.93 5243.03 5210.37 186.89 5207.02 0.85 5978399.12 588604.60 N 70 21 2.828 W 14916 7297.34 36.24 76.46 4466.82 4545.72 5227.88 5261.38 5228.37 191.09 5224.88 1.25 5978403.51 588622.42 N 70 21 2.869 W 14916 49.671 7327.63 35.87 75.98 4491.31 4570.21 5245.29 5279.20 5245.83 195.33 5242.20 1.54 5978407.95 588639.68 N 70 21 2.911 W 14916 49.165 7359.16 36.13 76.52 4516.82 4595.72 5263.39 5297.74 5263.99 199.74 5260.20 1.30 5978412.55 588657.63 N 70 21 2.954 W 1491648.639 7390.75 37.42 76.09 4542.12 4621.02 5281.86 5316.65 5282.52 204.21 5278.57 4.16 5978417.24 588675.96 N 70 21 2.998 W 14916 48.101 7422.85 37.37 74.46 4567.62 4646.52 5300.82 5336.14 5301.55 209.17 5297.42 3.09 5978422.40 588694.75 N 70 21 3.046 W 14916 47.550 7453.89 37.29 76.83 4592.30 4671.20 5319.16 5354.96 5319.96 213.84 5315.66 4.64 5978427.27 588712.93 N 70 21 3.092 W 14916 47.017 7486.75 37.97 79.35 4618.33 4697.23 5338.87 5375.03 5339.74 217.97 5335.28 5.12 5978431.62 588732.51 N 70 21 3.133 W 1491646.444 7518.67 39.32 82.04 4643.26 4722.16 5358.61 5394.96 5359.52 221.19 5354.95 6.75 5978435.06 588752.14 N 70 21 3.164 W 14916 45.869 7550.13 39.41 82.36 4667.58 4746.48 5378.44 5414.91 5379.38 223.90 5374.72 0.71 5978437.98 588771.87 N 70 21 3.191 W 14916 45.291 Last MWD+IFR+MS 7588.25 39.34 81.42 4697.05 4775.95 5402.45 5439.09 5403.45 227.31 5398.66 1.58 5978441.66 588795.77 N 70 21 3.224 W 1491644.591 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-W\L-214\L-214A\L-214A Generated 4/24/2006 2:31 PM Page 3 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latkude Longitude Depth Section Departure ft d de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS TD (Projecteo) /00L.UU 3`J~.34 tS7.4Z 4/40.30 4tSZ5.16 ~44L.D4 94/yAl 0443A3 L33 A4 D430.OG U.uv aara4wo. ~3 ~ooo3a.ov ~~ rv c ~ o.coa vv rya w wa.•rw Survey Type: Definitive Survey NOTES: GYD-GC-SS - (Gyrodata -gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) Inc + Trend - (Inclinometer + known azi trend -- Inclination only surveys in near-vertical hole-where formation dip and experience enables direction of drift to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. ) MWD + IFR + MS - (In-field referenced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance incUnation accuracy. ) Legal Description: Surface : 2430 FSL 3515 FEL S34 T12N R11 E UM BHL : 2661 FSL 3356 FEL S35 T12N R11E UM Northing (Y) [ftUS] Easting (X) [ftUS] 5978154.31 583400.48 5978448.13 588835.66 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-1ML-214\L-214A\L-214A Generated 4/24/2006 2:31 PM Page 4 of 4 TREE = 4-1 /16" CNV WELLHEAD = FMC ACTUATOR = NA KB. ELEV = 78.9' BF. ELEV = 50.4' KOP = 300' Max Angle = 63 @ 3217' Datum MD = 7214' Datum TVD = 4400' SS 13-3/8" CSG, 68#, L-80 -j 3872 BTC, ID = 12.415" 9-5/8" CSG, 40#, 6279 L-80, ID = 8.835" 9-518" MILLOUT WINDOW (L-214A) 6501' - 6518' WH~STOCK (03/12/06) 6501 EZSV (03/12/06) ~-j 6520 Minimum ID = 2.813" @ 2799' 3-1/2" HES X NfPPLE 9-5/8" CSG, 47#, -~ 7253, L-80, ID = 8.681" 3-1/2" TBG, 9.2#, L-80 7493 TCII, ID = 2.992" 7" LNR, 29#, 13CR 7622 VAM TOP, ID = 6.059" SAFEfY 24' ~-14-1/2" x 3-112" XO, ID = 2.992" 1017' 13-318" TAM PORT COLLAR 2799' 3-1/2" HES X NIP, ID = 2.813" L-214A 6349 -j 9-5/8" X 7" BKR ZXP LNR TOP PKR & HMC LNR HNGR, ID = 6.290" 6535 7" RA TAG PRODUCTION GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 7102 4390 38 MMG DMY RKP 0 04/11 /06 WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 7157 4434 38 MMG-W DMY RK 0 03117/06 4 7208 4474 37 MMG-W P-15 RK 8 04/16(06 3 7260 4516 36 MMG-W DMY RK 0 03/17/06 2 7320 4565 36 MMG-W P-15 RK 11 04/16!06 1 7381 4613 37 MMG-W P-15 RK 10 04/16/06 7104' -~MARKERJOINTwlRA TAG (7" LNR) 7130 ~ /2" HES X NIP, ID = 2.813" 7141' 7" X 3-1 J2" BKR PRMR PKR, ID = 2.870" 7222' --13-1/2" RA TAG 7227 3-1 /2" HES X NIP, ID = 2.813" 7239' 7" X 3-1/2" BKR PRMR PKR ID = 2.870" PERFORATION SUMMARY REF LOG: ANA DRILL LWD ON 03/14/06 ANGLEATTOPPERF: 38 @ 7168' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 7168 - 7218 O 03/16/06 4-1/2" 5 7256 - 7290 O 03/16/06 4-112" 5 7308 - 7326 O 03/16/06 4-1/2" 5 7443 - 7502 G 03/16/06 `3-1/2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" 7344' -I 7" X 3-1 /2" BKR PRMR PKR, ID = 2.870" 73~ 3-1/2" HES X NIP, ID = 2.813" 7405 -~ 3-1 /2" HES X N~, ID = 2.813" 7426' 3-1/2" HES X N~', ID = 2.813" 7426 3-1/2" PX PLUG (4116/06) 7438 3-1/Z" WLEG, ID = 2.992" ELMD TT NOT LOGGED PBTD 7572' 7" LNR, 26#, L-80 BTC, .0383 bpf, ID = 6.276" 7650 DATE REV BY COMMENTS DATE REV BY COMMENTS 06/03/05 TA ORIGINAL COMPLETION 04/16/06 TWS/PJC 3-1/2" PX PLUG @ 7426' 03/19!06 N9ES SIDETRACK(L-214A} 12/05/05 MJA/TLH DRLG-DRAFT CORRECTIONS 03!24/06 SRKiTLH DRLG DRAFT CORRECTIONS 04/11/06 TWS/PJC GLV GO 04!16!06 KSB/PJC GLV GO ORION UNfT WELL: L-214A PERMIT No: 2060270 API No: 50-029-23258-01 SEC 34, T12N, R11 E, 2430' FSL & 3515' FEL BP Exploration (Alaska) SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Orion Well ...................... L-214A API number ...............: 50-029-23258-01 Engineer .................. St. Amour Rig :...................... Nabors 9ES STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent.......: DF above permanent.......: Mean Sea Level Driller's Pipe Tally 53.35 ft N/A (Top Drive) 78.90 ft ----- Vertical section origin---------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/W-)......... 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 77.81 degrees 14-Mar-2006 09:37:10 Page 1 of 3 Spud date ................. 12-Mar-06 Last survey date.........: 14-Mar-06 Total accepted surveys...: 37 MD of first survey.......: 6443.99 ft MD of last survey........: 7652.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............. 10-Mar-2006 Magnetic field strength..: 1151.58 HCNT Magnetic dec (+E/W-).....: 24.30 degrees Magnetic dip .............. 80.85 degrees ----- MWD survey Reference Reference G ............... Reference H ......:........ Reference Dip ............. Tolerance of G...........: Tolerance of H............ Tolerance of Dip.........: ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.30 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.30 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction Criteria --------- 1002.68 meal 1151.58 HCNT 80.85 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees • • ®~ _ ~ ~,~ SCHLUMBERGER Survey Report 14 -Mar-2006 09:37:10 Page 2 of 3 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 1 -------- 6443.99 ------ 58.86 ------- 86.41 ------ 0.00 -------- 3974.25 -------- 4530.21 ------- 69.61 --------- 4619.67 -------- 4620.19 ------- 89.14 ----- 0.00 ----- TIP ---- None -- 2 6501.00 58.54 86.10 57.01 4003.87 4578.39 72.79 4668.28 4668.85 89.11 0.73 BP_B lind 3 6518.00 59.48 83.99 17.00 4012.62 4592.85 74.05 4682.80 4683.38 89.09 11.99 BP_B lind 4 6564.51 60.18 80.95 46.51 4036.00 4632.92 79.32 4722.65 4723.32 89.04 5.85 BP_B lind 5 6596.26 60.56 78.88 31.75 4051.70 4660.49 84.16 4749.82 4750.57 88.98 5.79 BP B lind 6 6628.31 61.05 76.79 32.05 4067.33 4688.47 90.05 4777.17 4778.02 88.92 5.89 BP_B lind 7 6660.36 59.04 74.70 32.05 4083.34 4716.22 96.89 4804.08 4805.06 88.84 8.44 BP_B lind • 8 6691.82 56.01 72.64 31.46 4100.23 4742.68 104.34 4829.55 4830.67 88.76 11.10 MWD IFR MS None 9 6723.90 53.56 70.14 32.08 4118.73 4768.73 112.69 4854.38 4855.69 88.67 9.94 MWD IFR MS None 10 6755.98 51.12 70.84 32.08 4138.33 4793.91 121.18 4878.32 4879.82 88.58 7.80. MWD IFR MS None 11 6787.05 48.33 71.60 31.07 4158.41 4817.46 128.81 4900.76 4902.45 88.49 9.17 MWD IFR MS None 12 6819.08 45.86 74.52 32.03 4180.22 4840.83 135.65 4923.19 4925.06 88.42 10.20 MWD IFR MS None 13 6851.17 44.44 79.56 32.09 4202.85 4863.56 140.77 4945.34 4947.35 88.37 11.98 MWD IFR MS None 14 6883.85 43.61 83.93 32.68 4226.36 4886.21 144.03 4967.81 4969.90 88.34 9.63 MWD IFR MS None 15 6914.88 41.88 87.26 31.03 4249.15 4907.07 145.66 4988.80 4990.93 88.33 9.17 MWD IFR MS None 16 6946.95 41.52 86.99 32.07 4273.09 4928.12 146.73 5010.11 5012.25 88.32 1.25 MWD IFR MS None 17 6978.76 41.86 84.33 31.81 4296.85 4949.08 148.33 5031.20 5033.38 88.31 5.66 MWD IFR MS None 18 7010.49 41.68 82.84 31.73 4320.51 4970.11 150.69 5052.20 5054.45 88.29 3.18 MWD IFR MS None 19 7042.90 40.82 79.57 32.41 4344.88 4991.43 153.95 5073.31 5075.65 88.26 7.16 MWD IFR MS None 20 7074.34 40.31 77.88 31.44 4368.77 5011.87 157.95 5093.36 5095.81 88.22 3.85 MWD IFR MS None 21 7106.81 38.04 74.98 32.47 4393.94 5032.37 162.75 5113.30 5115.89 88.18 8.98 MWD_IFR _MS None • 22 7138.17 37.86 75.03 31.36 4418.67 5051.64 167.74 5131.93 5134.67 88.13 0.58 MWD IFR MS None 23 7169.81 37.94 75.08 31.64 4443.64 5071.05 172.75 5150.71 5153.60 88.08 0.27 MWD IFR MS None 24 7201.74 37.70 74.97 31.93 4468.86 5090.61 177.81 5169.62 5172.68 88.03 0.78 MWD IFR MS None 25 7233.63 36.29 76.67 31.89 4494.33 5109.78 182.51 5188.22 5191.43 87.99 5.46 MWD IFR MS None 26 7266.28 36.19 77.11 32.65 4520.66 5129.08 186.89 5207.02 5210.37 87.94 0.85 MWD IFR MS None 27 7297.34 36.24 76.46 31.06 4545.72 5147.43 191.09 5224.89 5228.38 87.91 1.25 MWD IFR MS None 28 7327.63 35.87 75.98 30.29 4570.21 5165.25 195.33 5242.20 5245.84 87.87 1.54 MWD IFR MS None 29 7359.16 36.13 76.52 31.53 4595.72 5183.77 199.74 5260.20 5263.99 87.83 1.30 MWD IFR MS None 30 7390.75 37.42 76.09 31.59 4621.02 5202.68 204.22 5278.58 5282.52 87.78 4.16 MWD IFR MS None SCHLUMBERGER Survey Report 14-Mar-2006 09:37:10 Page 3 of 3 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 7422.85 37.37 74.46 32.10 4646.52 5222.15 209.17 5297.43 5301.56 87.74 3.09 MWD IFR MS None 32 7453.89 37.29 76.83 31.04 4671.21 5240.96 213.84 5315.66 5319.96 87.70 4.64 MWD IFR MS None 33 7486.75 37.97 79.35 32.86 4697.23 5261.02 217.97 5335.29 5339.74 87.66 5.12 MWD IFR MS None 34 7518.67 39.32 82.04 31.92 4722.16 5280.92 221.19 5354.96 5359.52 87.63 6.75 MWD IFR MS None 35 7550.13 39.41 82.36 31.46 4746.49 5300.82 223.90 5374.73 5379.39 87.61 0.71 MWD IFR MS None 36 7588.25 39.34 81.42 38.12 4775.95 5324.94 227.31 5398.67 5403.45 87.59 1.58 MWD_IFR MS None 37 7652.00 39.34 81.42 63.75 4825.26 5365.27 233.34 5438.63 5443.63 87.54 0.00 Projected to • TD [(c)2006 IDEAL ID10_2C_01] • ~~ 9 ~ ~ ~ „~~g ~~ FRANK H. MURKOWSKI, GOVERNOR v x ~ ~arr~ ~ ~' ~~ O~ ~ tl[~7 333 W. T" AVENUE, SUITE 100 COI~TST' RQATI011T COrII-II5SIOrT ANCHORAGE, ALASKA 99501-3539 a' PHONE (907) 279-1433 Robert Tirpack BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 FAX (907) 276-7542 Re: Prudhoe Bay Field, PBU L-214A BP Exploration (Alaska), Inc. Permit No: 206-027 Surface Location: 2430' FSL, 3515' FEL, SEC. 34, T12N, R11E, UM Bottomhole Location: 2679' FSL, 1948' FWL, SEC. 35, T12N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Chairman DATED this~~day of February, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 ~U1P~z`ti~''~d+~~' FEB 1 4 2006 Alaska Oil & Gas Cans. Clut>ntnissian Anrhnrene 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory , ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU L-214A ~~ ~~ ~°S 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 7700 TVD 4867 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 2430' FSL 3515' FEL SEC 34 T12N R11 E UM 7. Property Designation: ADL 028238 Schrader Bluff , , . , , , Top of Productive Horizon: 2615' FSL, 1682' FWL, SEC. 35, T12N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: y March 7, 2006 Total Depth: 2679' FSL, 1948' FWL, SEC. 35, T12N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 7650' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583400 - 5978154 Zone- ASP4 10. KB Elevation Plan (Height above GL): 78.g feet 15. Distance to Nearest Well Within Pool: 140' to L-214 16. Deviated Wells: Kickoff Depth: 6500 feet Maximum Hole Angle: 60 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2140 Surface: 1666 18. Casin Pro ram: S f~atlona To - Settln D th • B ottom Guantl of Cement c.f. orsacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 1322' 6378' 3940' 7700' 4867 31 sx Class 'G' ~- 19. PRESEfUT WELL CONDITION S UMMARY (To be completed f or Reddll and Re-entry Operations) Total Depth MD (ft): 7640 Total Depth TVD (ft): 4726 Plugs (measured): None Effective Depth MD (ft): 7640 Effective Depth TVD (ft): 4726 Junk (measured): None Casin Len h Size Cement Volume MD TVD Conductor /Structural 109' 20" 60 sx Arctic Set A rox. 109' 109' Surface 3843' 13-3/8" 57 sx Arcticset Lite, 605 sx'G' 3872' 2715' Intermediate 7227' 9-5/8" 84 sx Class'G', 491 sx Class 'G' 7253' 4445' Liner 494' 7" Ex anded Slotted Liner Screens 7128' - 7622' 4359' - 4713' Perforation Depth MD (ft): 7257' - 7612' Perforation Depth TVD (ft): 4448' - 4705' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Scott Kolstad, 564-5347 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/NUmber. Si nature ~ ,~ Phone 564-4166 Date ~ ~G ~ Terrie Hubble, 564-4628 Commission Use Oni Permit To Drill Number: -G 2 API Number: 50- 029-23258-01-00 Permit Approval Date: 1~/ S Ofo See cover letter for other requirements Conditions of Approval: / If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ~eST ~jD P (: 'j'"O ~-OC~O ~ ~ Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes~No ? H,S Measures: Yes ^ No Directional Survey Req'd:~es ^ No Other: /vl _' T ~ e..e, w.. ~t,'t' q_ r,Ga, (,c~"~j Gc~ ~ ro~ we Y' t-c~ . ~e„r '?,~ /~~ ZS. v3 5 C ~~ C ~ ~ J c~.~~~'~-~e ~o Irocedvr~.c ~ s ~~~e d /~ D /' APPROVED BY THE COMMISSION Date ~' p ,COMMISSIONER Form 10-401 Revised 12/2005 ;" ~TM ~ ~~/ ~,,./ SuDmlt rn vupncate • • Variance Request -~ Issue Compliance with AOGCC testing requirements for BOP rams after they have been used in the normal coarse of operations. Re uest The AOGCC is in the process of developing a guideline document clarifing the intent of the regulations pertaining to function pressure testing ram type BOP's. BPXA requests a variance #o the provisions of 20 AAC 25.035 (e}(10}C regarding the #unction pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be function pressure tested before the next wellbore en#ry. This is nova new regulation. The intent of this regulation is to ensure that ram type equipment has integrity after it has been utilized in a wellbore...for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "if BOP sealing ram type equipment has been used, it must be function pressure-tested, before the next wellbare entry, to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e}(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d){4} THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS: 20 AAC 25.286(e)(1} WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Aubert at the AOGCC. The test requirement in the regulation is intended to apply to ram type equipment only. The AOGCC understands that ram type BOP's are utilized for purposes other than well control in the normal coarse of operations. The regulations allowing a variance are at 20 AAC 25.035{h) PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036(f) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285(h) TUBING WORKOVERS; 20 AAC 25.286(g) WORKSTRING SERVICE OPERATIONS...which says generally: 20 AAC 25.035(h}... Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at feast an equally effective means of well control; • • Well Name: L-214Ai Well Plan Summary T e of Well roducer or in'ector : Injector Surface Location: Former Slot L-SW 2,430' FSL, X = 583,400 3,515' FEL, Sec. 34, T12N, R11 E , Y = 5,978,154 L-214Ai Target 1 Top OBa: 2615' FSL, 3597' FEL, Sec. 35, T12N, R11 E X = 588,595 Y = 5,978,399 Z = 4,435' TVDss L-214Ai BHL: 2,679' FSL, 3,332' FEL, Sec. 35, T12N, R11 E X = 588,860 Y = x,978,466 Z = 4,788' TVDss AFE Number: ORD4P9198 Ri Nabors E GL: 49.4' KB: 28.5' Estimated Start Date: March 7, 2006 ~ O eratin da s to com lete: 10 TD: 7,700' MD TVD: 4,867' Max Inc: 60° KBE: 78.9' Well Design: I Single string sidetrack out of 9 5/8" casing. Schrader Injector with 3-~/2" TCII Completion. Current Well Information General Distance to Nearest Property: 7,650' at top OBd sand to the nearest PBU property line Distance to Nearest Well in Pool: 140' to L-214i at the top of the OA sand (top OA will be the closest approach interval w/ water injection between the two wells) API Number: 50-029-23258-00 Well Type: Development -Orion Schrader Injector Current Status: buckled tubing below the production packer /~ Conductor: 20" X 34", 215.5 Ib/ft, A53 ERW set at 109' RKB BHP: 2,140 psi @ 4,740' TVDss (8.7 ppg EMW). Normal pressure gradient. BHT: 90°F @ 4,740' TVDss estimated '/a Mile Wellbore Near Wellbore Mechanical Integrity Summary: L-102 is 570' from L-214Ai at the top of the reservoir. L-102 had a planned TOC of 5,500' MD, which is 500' MD above the top of the Schrader Bluff. There were no problems reported during the pumping of the L-102 cement job. There were no losses and the plug was bumped on schedule. L-201 has two horizontal laterals which are with-in ~/a mile of L-214Ai. The OBd lateral is 1050' away and the OA lateral is 960'. L-201 had a planned TOC of 4700', which is 700' above the top of the Ma. There were no problems reported during the pumping of the L-201 cement job. There were no losses, the casing was reciprocated, and the plug was bumped on schedule. No near Wellbore integrity issues. L- 1 ~z ~ L- 1~4, L - Zn I ~ L - Z! c~~ L - Z I ¢ zoz.o~L z.~IZ3~ Zd4d4G to3~y~ Z~So$z L-214Ai Permit to Drill Page 1 • ~ Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation TVDss feet Yes/No Psi EMW NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re uired from surface to TD for all new wells UG3 Fault to ;above KOP -3270 +/-5' 1472 8.7 UG1 above KOP -3625 +/-5' Possible Heavy oil 3870 - 3935' ss 1631 8.7 Ma -3945 +/-5' Hea 9 0i SS 5 1780 8.7 Mb1 -3985 +/-5' No -Water 1810 8.7 Mb2 -4065 +/-5' No -Water 1845 8.7 MC -4155 +/-5' No -Water 1885 8.7 Fault -4200 +/-50' 1905 8.7 Na -4215 +/-10' No 1915 8.7 Nb -4240 +/-10' No 1925 8.7 Nc -4275 +/-10' Yes 1945 8.7 OA -4365 +/-10' Yes 1990 8.8 OBa -4435 +/-10' Yes 2030 8.8 OBb -4480 +/-10' .Yes 2050 8.8 OBc -4535 +/-10' Yes 2060 8.7 OBd -4585 +/-10' Yes 2090 8.8 OBe -4640 +/-10' Yes 2100 8.7 OBf -4690 +/-10' Yes 2120 8.7 OBf_Base -4735 +/-10' Yes 2140 8.7 T.D. -4788 Well TD Criteria Injection Well T.D. is -185' MD below the Top (ie ??ft TVD, ??ft Rathole, etc.) OBe marker. Comments Formation pressures in L-214A OA, OBa, OBb, and OBd were assumed to be slightly higher than regional due to ~4 months of water injection in the L-2141 original hole injector completion. Overpressure, if any, is expected to be very minor in L-214A as a result of Polygon 2A fault block L-201 drainage area O sand pressure depletion resulting from 1 1/2 years of L-201 multilateral production (i.e., L-201 voidage will have likely resulted in greater pressure depletion than would have been locally replaced by L-2141 iniection). ~ L-214Ai Permit to Drill Page 2 • • Casina/Tubina Program Hole Size Csg / Tb O.D. WUFt Grade Conn Burst si Collapse si Length Top MD /TVDrkb Bottom MD /TVDrkb 8-1 /2" 7" 26# L-80 BTC-M 7240 5410 1322' 6378' / 3940' 7,700' / 4867' Tubin 3 ~h" 9.30# L-80 TCII 10,160 10,530 7563' Surface 7,563' / 4,609' Mud Program: 8-1/2" Production Hole Mud Properties: Freshwater Mud (LSNDI Interval De t Funnel Vis PV YP FL H Chlorides MBT Window to casing oint .4 .~' 38-50 12-18 26-35 4-6 9.0-9.5 <600 < 20 Survey and Logging Program: 8-1/2" Hole Section: Surveys to be IFR +Multi-Station corrected O en Hole: LW D: Dir / GR / Res real time, Den / Neu recorded Cased Hole: USIT Log Surface and Anti-Collision Issues Surface Shut-in Wells: Nearb Well L-102 L-104 L-123 L-106 Distance to L- 214Ai 15' 15' 30' 45' L-102 and L-104 will require surface shut-in and well house removal in order to move over well L-214Ai. L-123 should only be a conductor only. L-106 should be evaluated to see if well house removal is required. Close Approach Shut-in Wells: L-102 failed a major risk anti-collision scan and will have a down hole plug set until drilling past the close approach depth. Close Approach Well List: Well Name Ctr-Ctr Distance Reference MD Allowable Deviation Precautionar Comment L-102 95-ft 7,662-ft 69-ft Shut in L-102 Cement Calculations Casin Size: 7" 26 Ib/f' Basis: Lead: N/A Lead TOC:N/A Tail: 1,200' of op annulus. Tail TOC: ,35 Total Cement Volu 80 en hole with 40% excess, F MD Wash 25 bbls of CW100 3 acer 75 bbls of Viscosii Tail 49 bbls, 277 cuft, Temp BHST ~ 90° F. BH track, 150' liner lap, plus 200' DP x cgs acer wei hted to 10.5 Mud h I /sks 15.8 Ib/gal Class G + adds - cu 80° F estimated by Schlumberger L-214Ai Permit to Drill Page 3 • ~ Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. BOP ~ equipment will be tested to 4,000 psi. Due to MASP not exceeding 3,000psi it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency for L-214Ai will be 14 days, function test every 7 days. ~' BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7" Liner Test: • Integrity Test - 8-1/2" hole: • Kick Tolerance: • Planned completion fluid: Disposal 2,140 psi -Base of Schrader (8.7 ppg @ 4,740' TVDss) 1,666 psi -Based on a full column of gas @ 0.10 psi/ft 4,000 psi/250 psi Rams ~,,. 2,500 psi/250 psi Annular 4,000 psi 11.0 ppg minimum EMW FIT 20' - 50' from 9-5/8" window Infinite with an 11.0 ppg EMW FIT Estimated 9.0 ppg Brine / 6.8 ppg Diesel • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. L-214Ai Permit to Drill Page 4 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in the target fault block is expected to be normal pressured at 8.5-8.7 ppg EMW. This pressure could be slightly higher due to water injection from L-214i. II. Lost Circulation/Breathing A. Lost circulation is not expected this well. B. Breathing is not expected on this well. III. Kick Tolerance/Integrity Testing ,/~ ~> A. The Kick Tolerance while drilling the 8-1/2" Production hole is I~INIT with 9.4 ppg mud, 11.0 ppg FIT and an 8.8 ppg pore pressure. B. 8-1 /2" hole Integrity Testing -11.0 ppg EMW FIT IV. Hydrogen Sulfide L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followedsat all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TD: L-106 5 ppm / L-201 5 ppm (11/14/2004) L-107 30 ppm V. Faults A. L-214Ai will intersect Fault 1 in the lower Mb2 to upper Nc sand section. This fault was penetrated in both L-214 OH and in L-102 in the Nc interval, but is not imaged on 3-D seismic. The t 70' MD penetration depth uncertainty results from L-214A intersecting the fault at a azimuth low angle. This low angle of intersection can yield a large intersection depth error if either the side tract well trajectory, or the fault dip or azimuth angles, are even slightly different from prognosis. The fault was crossed in Nb section in L-214i original hole w/ no drilling or lost circulation problems. No losses are expected to be associated with the fault. Details are listed below for reference: Fault #1 (lower Mc): 6,955" MD -4,200' TVDss Throw: 20' S-SW ±70 MD uncertainty CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION L-214Ai Permit to Drill Page 5 • • L-214Ai Drill and Complete Procedure Summary Pre-Rig Work: 1. Integrity testing of existing well head, tubing, and IA. 2. CT cement squeeze to P&A existing expandable sand screen completion. 3. Chemical cut tubing. 4. Install BPV. 5. If necessary, level the pad and prepare location for rig move. 6. Prepare neighboring wells for the rig move and simops production. 7. Set down hole plug in L-102. 8. Remove well houses and level the pad as necessary. Rig Operations: 1. MIRU Nabors 9ES. 2. Pull BPV. RU to tree. Circulate out freeze protection. 3. Install TWC. ND tree. NU and test ROPE. ~ 4. Pull existing tubing from above chemical cut. LD tubing and Inspect tubing for rerunning. 5. PU mills and DP. Drift past whipstock setting depth. TOH. 6. RU eline. Set CIBP above tubing stub. 7. PU whipstock. RIH on DP and set. Displace well to milling fluid. Mill window in 9 5/8" casing. POOH. 8. MU 8-1/2" drilling assembly with MWD/GR/Res/Den/Neu and RIH. Perform FIT-test" 9. Drill ahead to t70' below the base of the OBf sand. Target TD at 7,700' MD. ~ 10. Circulate and condition hole, POOH to run liner. 11. Run and cement the 7" liner. POOH and LD liner running tools. ~ 12. Test the 7" liner to 4,000 psi for 30 minutes. 13. PU SLB 4 ~h" perf guns. 14. DPC perforate. 15. RU eline. Run USIT log in the 7" liner to confirm cement bond and TOC. ~ 16. Run the 3-'/z", L-80 TCII completion with three 7" x 3-'/2" straddle packer assembly, injection mandrels and PIP tag. ~" 17. Run in the lockdown screws and pressure up to set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve. 18. Install TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 19. Freeze protect the well to 2,200' TVD. Install BPV in tubing hanger. Install a VR plug in the 9-5/8"x 4-~h" annulus valve and secure the well. Assure that IA/OA are both protected with two barriers. 20. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tail pipe. 2. Install injection valves. L-214Ai Permit to Drill Page 6 ~ '~ ... I PLANT - N f ~ 34 35 15'00'00" I GRID ~ _ -N ~` L-PAD _ _. ~ ~ ~ T __ _ ..._,__ ~_ ____ ____.., __ . __ ._.. _ _ _ _ .. _-_ . PROJECT AREA T12N T11 N L , ~- < w L-PAD ~ 3 2 ^ N-L (NWE-1) VICINITY MAP N.T.S. LEGEND L-1111 ^ N-A (NWE-2) L-113 ~ RENAMED CONDUCTOR L-114 ^ L-so ^ L-124 ~ L_1121 ^ EXISTING CONDUCTOR L-02 '~ L-121 ^ ^ L-122 L-110 ^ ^ L-2111 L-SI ^ L-116 ^ ^ 1-1151 ^ L-117 ` OF ,1 °°° C. ry L-109 ^ L-SL ^ ^ L-118 ~P~° ° ° ° ~SL ° °• ~ ° °°9 ~ o~ ~0°49~ L-01 ^ ^ L-200 °°°°°°°°°°°°°°°°°°°°°°°°°°°°° L-107 ^ L-03 ^ sKro ~ ^ L-202 ^ L-2121 i1 ^ L-SPARE ° ° ° ° ° L-213i^ ~ ~ ^L-203 gyp, °° I~ICI1ord 1=. AIIisOn L-1081^ L-1051 ^ L-106 ^ ^ 1-2161 ^ L-1031 ^ L-2151 ~ ° ' ° 1 0608 °°° ~~~333"' ° ° L-1231 ^ ~ ^ L-201 °°°°°~ L-104 / ii i ~ IOWPa- L-2141 i L- o L-102 ^g ^ L-120 ' SURVEYOR S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ANO THAT THIS PLAT REPRESENTS A SURVEY DIRECT U D 90°x° SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE -- _ .. ,- CORRECT AS OF JANUARY 14, 2005. // WELL N0. L-2141 REVISION NOTE THIS AS-BUILT DRAWING IS A REISSUE OF A PREVIOUS AS-BUILT DRAWING FOR CONDUCTOR SLOT S-W. SLOT S-W IS BEING RENAMED TO L-2141. NOTES 1. DATE OF SURVEY: JUNE 20-21, 2002. 2. REFERENCE FIELD BOOK: W002-08 PAGES 16-19. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 4. BASIS OF HORIZONTAL LOCATION IS L-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS L-PAD OPERATOR MONUMENTS. ELEVATIONS ARE BP MSL DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999907827. LOCATED WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION DMS POSITION D.DD) BOX ELEV. OFFSETS L 1 Y= 5,978,154.31 N= 9,819.77 70'21'01.008" 70.3502800' 50 4' 2 430' FSL -2 41 X= 583,400.48 E= 5,369.63 149'19'22.369" 149.3228803' . 3,515' FEL r. xooert "~"'°"' JACOBS L, IfI~I1I cNEGKED:FEN71E b~ 0 I ~ DA~~ 1/14/05 U DRAWING: GPB WOA L-PAD ((~~ FR805 WOL Ot-00 sHEEr: ® ~U~OO ~o Boa NG~ AS-BUILT CONDUCTOR NAME CHANGE 0 1 14 05 ISSUm FOR INFORNA710N ~ JAIF vxaems uo wn sw.E s SCALE: 1 OF 1 ,a, „~ ,,,,E 1'= 150' WELL L-SW TO L-2141 N0. DALE REN90N BY CHK Ate. w,.aA by Schlumberger L-214A (P3) Pro posal Report Date: November 2, 2005 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 77.810° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.890 ft, E 488.560 ft Structure 1 Slot: L-PAD I S-W ~~u y TVD Reference Datum: Rotary Table Well: Borehole: L-214 $ia~'~~ Plan L-214A ~ea TVD Reference Elevation: 78.90 ft relative to MSL Sea Bed 1 Ground Level Elevation: 49.40 ft relative to MSL UWIIAPI#: 500292325801 Magnetic Decination: 24.401 ° Survey Name 1 Date: L-214A (P3) /November 2, 2005 Total Field Strength: 57577.738 nT Tort 1 AHD 1 DDI 1 ERD ratio: 156.737° / 5505.48 ft / 6.135 / 1.131 Magnetic Dip: 80.849° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: December 01, 2005 Location LaUlong: N 70.35027993, W 149.32288035 Magnetic Declination Model: BGGM 2005 Location Grid NIE YIX: N 5978154.310 ftUS, E 583400.480 ftUS North Reference: True North Grid Convergence Angle: +0.63769163° Total Corr Mag North a True North: +24.401 ° Grid Scale Factor: 0.99990790 Local Coordinates Referenced To: Structure Reference Point • Measured Vertical Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Lathude Longitude Depth Section ft d d ft ft ft ft ft d 100 ft d d 100 ft d 100 ft ftUS ftUS iie-ui ouivey owao.a~ ao. oo oo.4i 38:10.3 J~r4.G~ 403U.N /U.4`J 51V25 .LZ l.lb -l4U.r4V V.Vb -1.34 Dy/tlZrb.UZ b25tlUltl.bb N /U.3bU46b3tl W 14`J.Ytfb3//`J1 Top Whipstock 6500.00 58. 54 86.10 3924.44 4003.34 4577.54 73.62 5155 .98 0.74 -60.OOG -0.57 -0.55 5978278.67 588066.37 N 70.35047382 W 149.28499021 Base Whipstock 6516.00 59. 52 84.17 3932.68 4011.58 4591.14 74.78 5169. 65 12.00 O.OOG 6.09 -12.06 5978279.98 588080.03 N 70.35047698 W 149.28487925 KOP Crv 6/100 6528.00 59. 52 84.17 3938.77 4017.67 4601.42 75.83 5179. 93 0.00 -90.OOG 0.00 0.00 5978281.15 588090.30 N 70.35047982 W 149.28479572 Ma 6540.29 59. 52 83.32 3945.00 4023.90 4611.95 76.98 5190. 46 6.00 -89.57G 0.02 -6.96 5978282.42 588100.81 N 70.35048295 W 149.28471027 6600.00 59. 61 79.16 3975.26 4054.16 4663.33 84.82 5241. 33 6.00 -87.46G 0.16 -6.96 5978290.82 588151.58 N 70.35050427 W 149.28429729 Mb1 6621.25 59. 68 77.69 3986.00 4064.90 4681.67 88.50 5259. 29 6.00 -86.72G 0.30 -6.94 5978294.69 588169.51 N 70.35051429 W 149.28415141 Crv 6/100 6628.00 59. 70 77.22 3989.40 4068.30 4687.49 89.77 5264. 98 6.00 -178.80G 0.36 -6.94 5978296.02 588175.18 N 70.35051773 W 149.28410526 6700.00 55. 38 77.11 4028.04 4106.94 4748.22 103.26 5324. 20 6.00 -178.74G -6.00 -0.15 5978310.16 588234.24 N 70.35055447 W 149.28362443 Mb2 6754.07 52. 14 77.02 4060.00 4138.90 4791.82 113.02 5366. 70 6.00 -178.69G -6.00 -0.17 5978320.39 588276.62 N 70.35058105 W 149.28327937 6800.00 49. 38 76.94 4089.05 4167.95 4827.39 121.03 5401. 35 6.00 -178.64G -6.00 -0.18 5978328.79 588311.18 N 70.35060287 W 149.28299800 Mc 6895.86 43. 63 76.74 4155.00 4233.90 4896.89 136.85 5469. 04 6.00 -178.50G -6.00 -0.21 5978345.36 588378.69 N 70.35064596 W 149.28 9 6900.00 43. 38 76.73 4158.00 4236.90 4899.74 137.50 5471. 81 6.00 -178.49G -6.00 -0.23 5978346.04 588381.45 N 70.35064774 W 149.2 7 Na 6988.45 38. 08 76.50 4225.00 4303.90 4957.42 150.85 5527. 94 6.00 -178.32G -6.00 -0.26 5978360.01 588437.42 N 70.35068409 W 149.28 14 End Crv 6994.20 37. 73 76.49 4229.54 4308.44 4960.96 151.68 5531. 38 6.00 O.OOG -6.00 -0.29 5978360.87 588440.85 N 70.35068634 W 149.28194224 Nb 7020.07 37. 73 76.49 4250.00 4328.90 4976.79 155.38 5546. 78 0.00 O.OOG 0.00 0.00 5978364.74 588456.20 N 70.35069642 W 149.28181723 OA 7165.48 37. 73 76.49 4365.00 4443.90 5065.76 176.17 5633. 31 0.00 O.OOG 0.00 0.00 5978386.48 588542.49 N 70.35075304 W 149.28111465 L-214A Tgt 1 7254.00 37. 73 76.49 4435.00 4513.90 5119.91 188.83 5685. 98 0.00 O.OOG 0.00 0.00 5978399.72 588595.01 N 70.35078751 W 149.28068699 OBa 7254.01 37. 73 76.49 4435.01 4513.91 5119.92 188.83 5685. 98 0.00 O.OOG 0.00 0.00 5978399.72 588595.02 N 70.35078752 W 149.28068692 OBb 7310.90 37. 73 76.49 4480.00 4558.90 5154.73 196.96 5719. 84 0.00 O.OOG 0.00 0.00 5978408.23 588628.78 N 70.35080967 W 149.28041206 OBc 7380.44 37. 73 76.49 4535.00 4613.90 5197.28 206.91 5761. 22 0.00 O.OOG 0.00 0.00 5978418.63 588670.05 N 70.35083675 W 149.28007604 OBd 7443.67 37. 73 76.49 4585.00 4663.90 5235.96 215.95 5798. 84 0.00 O.OOG 0.00 0.00 5978428.09 588707.56 N 70.35086137 W 149.27977056 OBe 7513.21 37. 73 76.49 4640.00 4718.90 5278.51 225.89 5840. 23 0.00 O.OOG 0.00 0.00 5978438.49 588748.83 N 70.35088845 W 149.27943454 OBf 7576.43 37. 73 76.49 4690.00 4768.90 5317.19 234.93 5877. 85 0.00 O.OOG 0.00 0.00 5978447.94 588786.34 N 70.35091306 W 149.27912906 OBf Base 7633.33 37. 73 76.49 4735.00 4813.90 5352.01 243.07 5911. 71 0.00 O.OOG 0.00 0.00 5978456.45 588820.11 N 70.35093522 W 149.27885413 ~ TD / 7" Csg 7700.35 37. 73 76.49 4788.00 4866.90 5393.01 252.65 5951. 59 0.00 O.OOG 0.00 0.00 5978466.47 588859.88 N 70.35096131 W 149.27853032 WeIlDesign Ver SP 1.0 Bld( doc40x_56) S-W\L-214\Plan L-214A\L-214A (P3) Generated 11/2/2005 9:49 AM Page 1 of 1 wFi.l. UcrAas ANTI-COLLISION SETTINGS t'oMFnNV UGlnus suevl!r reocRnlf Nwlw~ -N'-J .F,-W' N~xaxin% fuuu% Im'nlxk I...n%nluk %I,n lil'Am.nv~ Ucplh lln Ihplh l.. ~I cy 7'bnl I.~,~I Inrerpolafion Methud:MD Inrenal: 25.00 I -!IJ x!%`) 1U']9 :Y7%IsJ 31 <%iJIx~J% ]II"!I''ll!Ilr%N IJU IY"'itivl4 Nn D2pl11 RaI1g2 FrOnl: 6500.00 rJ: 7(17.1.-~) c'ul.ulutl,~n McNxxl: Miolmwn l'llnnwt~ 1.<UIrUU '6]1.J~1 I'lawxvl:I-_'IJ,\~rINN \''I HI INU M1tasimum Range: 9G-1 9U RLferenca: Plan: L-IIJA \cp0-l P.rn,r s>'unn: 151'WSn . un M.Ib~xl: lra~'('yluxler N,~nll I~:m,r Nmlacc: I:Ilipocel - t'a.m% \\'~nunp Metlx.l: Rules Ii~.a~~l 60 50 25 00 0 2 0 00 25 150 160 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [SOftlin] olour To MD - 500 - 1000 - 1500 - 2000 - 2500 3000 - 3500 - 4000 - 4500 - 5000 - 5500 - 0000 - 7000 8000 - 9000 - 11000 12000 13000 - 14000 -- 15000 Itr.X Un An 'IYU -N:-~ -1:~-W I1I:'N Trace VNa Tagn, ~%.c2 N6.IW JIXII.91 72.SX1 4G711.Ui U.W 11.(X1 JG6%c4 2 Gc211.IX1 cX.7G %3.29 1111212 ]a.J% J61{7.IIS 12.W JSC,W 46%c.dl 1 fifi211.IX1 5X.95 762% JINn1.UN %9.fi5 JI]I.I% 6 W -W.W J77U.35 4 G941.ra iN.s3 77.17 J2%].5J 14%.J1 51119.112 G.W 17%.12 50211.59 f 7246.15 3M 53 77.17 15111.911 IN7.9i 51YL.al U.W U.UII 51'/5.41 L214A'I %I G 751 L2G 3N-c3 77.17 171%.311 .2:1.61 si 3A2 U.W 0.W 53sN.111 7 7G74.4v 3%.51 77.17 i%JG3NI !J i.l9 5452.5c (1.1X1 (1.1X1 545%.15 I'Iwl I -! IJA ~IXrz"!u5wn ram%wxlgUm: L-z1a iw .n MU: b5d1.W W%: I?Ib Rel: Uwwn: cU.4 -25.5 7c.Wfi \'\i~li~m lhx%iu (XI%IV 4anm% N'r J'~ ~i 1111 Ii INI _-.:u I I:I ~F.NU Sperry-Sun Anticoliision Report Company: BP Amoco Date: 11/15/2005 Time: 18:30:17 Page: 1 Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NE) Reference: W eIL' L-214, True North Reference Well: L-214 Vertical (TVD) Reference: 50.4 + 25.5 75.9 Reference Wellpath: Plan L-214A Db: OraGe GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are TllifeYd~Te~ls in this fRIUlCipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 6500.00 to 7674.49 ft Scan Method: Trav Cylinder North Maximum Radius: 964.90 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/31/2005 Validated: No Version: 2 Planned From To Survey Toolcode Tool Name ft ft 97.00 697.00 Survey #1 GYD GC SS (97.00-697.00) (0) GYD-GC-SS Gyrodata gyro single shots 758.24 6500.00 Survey #2 M WD+IFR+MS (758.24-7582.33) Qq~ND+IFR+MS MWD + 1FR + Multi Station 6500.00 7674.49 Planned: L-2 14A wp04 V9 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 3869.00 2712.30 13.375 16.000 13 3/8" 6500.00 4001.91 9.625 12.250 9 5/8" 7670.00 4842.49 7.000 8.500 7" Summary <---------- Offset Wellpath -- ----------a Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation ft ft ft ft ft Warning r PB L Pad L-01 L-01 V14 Out of range PB L Pad L-03 L-03 V5 Out of range PB L Pad L-102 L-102 V2 7662.34 7700.00 95.10 25.99 69.11 Pass: Minor 1/200 PB L Pad L-102 L-102P61 V10 Out of range PB L Pad L-102 L-102PB2 V2 Out of range PB L Pad L-103 L-103 V23 Out of range PB L Pad L-104 L-104 V7 Out of range PB L Pad L-105 L-105 V4 Out of range PB L Pad L-106 L-106 V14 Out of range PB L Pad L-107 L-107 V14 Out of range PB L Pad L-108 L-108 V18 Out of range PB L Pad L-109 L-109 V12 Out of range PB L Pad L-116 L-116 V10 Out of range PB L Pad L-119 L-119 V9 Out of range PB L Pad L-120 L-120 V8 Out of range PB L Pad L-200 L-200 V7 Out of range PB L Pad L-200 L-200L1 V3 Out of range PB L Pad L-200 L-200L2 V6 Out of range PB L Pad L-201 L-201 V6 Out of range PB L Pad L-201 L-201 L1 V9 7671.46 10250.00 918.84 208.36 710.48 Pass: Major Risk PB L Pad L-201 L-201 L1 PB1 V10 7671.46 10250.00 918.84 208.36 710.48 Pass: Major Risk PB L Pad L-201 L-201 L2 V5 7665.12 10400.00 776.30 204.32 571.98 Pass: Major Risk PB L Pad L-201 L-201 L3 V2 Out of range PB L Pad L-201 L-201 L3P61 V6 Out of range PB L Pad L-201 L-201 PB1 V12 Out of range PB L Pad L-201 L-201 PB2 V3 Out of range PB L Pad L-202 L-202 V5 Out of range PB L Pad L-202 L-202L1 V7 Out of range PB L Pad L-202 L-202L2 V6 Out of range PB L Pad L-202 L-202L3 V6 Out of range PB L Pad L-210 L-210 V6 Out of range PB L Pad L-210 L-210PB1 V8 Out of range PB L Pad L-212 L-212 V11 Out of range PB L Pad L-212 L-212P61 V9 Out of range PB L Pad L-212 L-212PB2 V2 Out of range PB L Pad L-214 L-214 V9 6500.00 6500.00 0.00 0.00 0.00 FAIL: NOERRORS PB L Pad L-215 L-215 V7 Out of range PB L Pad L-215 L-215PB1 V4 Out of range PB L Pad L-215 L-215P62 V2 Out of range PB L Pad L-216 L-216 V6 Out of range PB L Pad L-250 L-250 V3 Out of range TREE= 4-1/16" CM/ WELLHEJAD = ACTUATOR = FMC .. NA KB. ELEV.- _ 78.9' BF. ELEV - ... .........._50.4' KOP _ 300'. Max Angle = 63 @ 5878' Datum MD = xxxx' Datum TVD = _ xxxx' SS 13-3l8" CSG, 68#, L-80 BTC, ID = 12.415" 9-5/8" CSG, 40#, L-80, ID = 8.835" I 3872' I Minimum iD = 2.813" @ 7309' 3-1 /2" HES X NIPPLE $405` ~- ~4-112" JOINTw/RA MARKER 6525' 9-5/8" SHORT JOINT w /RA TAG 6938' 4-1l2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 6958 4250 53 MMG DMY RK 0 07/27/05 WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 7257 4448 45 KBUG DMY BK 0 06/03!05 3 7282 4466 45 KBUG DMY BK 0 06!03/05 2 7381 4536 44 KBUG DMY BK 0 06/03/05 1 7407 4556 44 KBUG DMY BK 0 06/03/05 7032' -j4-1/2" BKR CMD SLIDING SLV, ID = 3.813" 7043' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" ~ 7077' TBG PUNCH (07/08/05) 7078' - 7082' 9-5/8" CSG, 47#, L-80, ID = 8.681" EXPANDABLE SLOTTED SCREEN SUMMARY REF LOG: SWS USfr ON 05/31105 ANGLE AT TOP PERF: 45 @ 7257' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 7" ESS 7257 - 7314 O 05(30105 7" ESS 7359 - 7434 O 05/30/05 7" ESS 7554 - 7612 O 05/30/05 3-1/2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" ~-~ 7493 S NOTES: **7" CHROME LNR** L -214 0 05 VIDEO LOG DETERMINED POSSIBLE 7BG DAMAGE @ 7084' 1017' ~-I 13-3/8" TAM PORT COLLAR ~ ~ I I I I I I ~ ~ 1 I I I 7" LNR, 29#, 13CR VAM TOP, ID = 6.059" 7622' ' 7063' H 9-5/8" X 4-1/2" WFD HELLCAT PKR, ID = 3.933" 7077' 4-1/2" X 3-1/2" XO, ID = 2.992" 7128' 9-5/8" X 7" BKR MLZXP LTP, ID = 6.059" 730 3-112" HES X NIP, ID = 2.813" 7314' 7" WFD EXPANSION ZONAL ISO JOINT, ID = 6.01" 7320' 3-112" WFD SNGL GAUGE MANDREL,ID = 2.98" 734$' 7" X 3-1/2" WFD HELLCAT PKR, ID = 2.992" 7360' 4-1/2" X 3-112" XO, ID = 2.88" 7433' (-13-1/2" HES X NIP, ID = 2.813" 7434' H 7" WFD IXPANSION ZONAL ISO JOINT, ID = 6.01" 7438' 3-1 /2" WFD DUA L GA UGE MANDREL, ID = 2.98" 7469' 7" X 3-1/2" WFD ULTRAPAK PKR, ID= 2.98" 7473' 4-1/2" X 3-1/2" XO, ID = 2.992" 7485' 3-1/2" HES X NIP, ID = 2.813" 7493' -~3-1/2"WLEG,ID=2.98" ELMD TT NOT LOGG~ 7519' H 7" WFD IXPANSION ZONAL ISO JOINT, ID = 6.01" DATE REV BY COMMENTS DATE REV BY COMMEMS 06/03!05 TA ORIGINAL COMPLETION 07/08/05 /TLH TBG PUNCH 08102!05 RWL/TLH GLV C/O 12105/05 MJAlTLH DRLG DRAFT CORRECTIONS ORION UN(f WELL: L-214 PERMIT No: 2050520 API No: 50-029-23258-00 SEC 34, T12N, R11 E, 2430' FSL & 3515' FEL BP Exploration (Alaska} ~ L -214A i ~ S ~~ Proposed Completion I 1017' I 13-3/8" CSG, 68#, L-80,ID = 12.415" ~-~ 3872' Willed Window (~ -6500' 3-1/2" TBG, 9.3#, L-80 TGII, .0087 bpf, ID = 2.992" I> 3 1/2" x 7" Baker Premier Packer -7150' Water Flood Mandrels TBD • 3 1/2" x 7" Baker Premier Packer -7250' A tt„~ .: t ,,~ ~ Water Flood Mandrels TBD • 3 1/2" x 7" Baker Premier Packer -7390' ~ 3-1/2" TBG, 9.2#/9.3#, L-80 TGII, .0087 bpf, ID = 2.992" -7420' ,. I ~ w ~ I • , .~ I .• g• s - 7" CSG, 26#, L-80 BTGMOD, ID = 6.276" -7700' P.. ~, DATE REV BY COMMB~ITS DATE REV BY COMMENTS 06/03/05 TA ORIGINAL COMPLETION 08/02/05 RWL/TLH GLV GO Proposed Completion ORION UNff WELL: L-214Ai PERMff No: xxxxxx API No: 50-029-23258-xxx SC-C 34, T12N, R11 E, 2430' FSL & 3515' FEL BP 6cploration (Alaska) X520 '09S5t~..L229~..titb • b •'090002 5 2 T :~ a $ b1104 , OW3W X0566 ~b'a6e~o ,~~ $ ._ _' e~Selb Hues ~e,..:._ 4oub tiSZ ZSZL/g-sgf j~ a3 O 3H1 01 ,t H., „~Ioa40 P~e~aa~se Z l99_g ~ 566 ~b , 3JyaOH~Nb, W„ 5 L eW 219961 pNi ~b NO11baO7dX3 d8 3788nH 7 311ia31 • • • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ / " 2 l L~j~ PTD# ~~, 7 Development I7~ Service Exploratory Stratigraphic Test Non-Conventiona Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after ~Com any Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\jody\transmittal checklist • • ~n O O ~ ~ ~ _ to ~ ~ ~ ,. ~ ~ ~ ~ - o ~ 4 , ~ a ~ ~ ~~ O fn ~ .. , , WI a ; ~ ~' i ~; ~ ~ ~ ~ of a. , ~ v. o, , W I o ccoo, w, O N ~' c , a m N. vi of .a m. ui o $ ~ ~ ~ oo a, ~ , ° f6 ~ ~ , ~ ~ , ~- Qy ~ ~ ~ w ~~ O, O, Y' O O, U, ~~ tF', ~ N; C, _~ N, Z II ~ N• ~ j, LA~ N' ~ ~~ O, ~ ~, ~ ~ o~ N o; °' ; ~ ~ e' ~; ~ ~, o ~ z ; Q, J, , a' Z , ~,. g, , ~, , z' ~, , ~j ; w~ , ~ ~ ~ ~ N, N, ~ N~ N, ~ ~ 4Y dA N~ N' N. N, N, N, ~ ~ ~ N~ N~ N~ tA~ - N' N, N, N, N, N, 4) N, f/Y N~ N~ ~ N, d, N, a, (/D a, a, a, a, N, UY N. 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