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Home My WebLink About203-185MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, December 11, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-114A PRUDHOE BAY UN BORE V-114A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/11/2025 V-114A 50-029-23178-01-00 203-185-0 W SPT 6563 2031850 2760 1760 1763 1760 1761 450 466 466 467 REQVAR P Guy Cook 11/5/2025 2 year MIT-IA to 1.2 maximum anticipater injection pressure per AA AIO 24A.002. The pwi header pressure was 2300 psi. The test was 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 BORE V- 114A Inspection Date: Tubing OA Packer Depth 64 2995 2959 2951IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC251105133528 BBL Pumped:2.2 BBL Returned:2.1 Thursday, December 11, 2025 Page 1 of 1          Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 V-114A 203185 500292317801 5 12/31/2023 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-114A PRUDHOE BAY UN BORE V-114A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/12/2024 V-114A 50-029-23178-01-00 203-185-0 W SPT 6563 2031850 2700 1331 1334 1330 1330 413 427 427 428 REQVAR P Austin McLeod 11/12/2023 Two year to 1.2x MAIP. AIO 24.002. 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 BORE V- 114A Inspection Date: Tubing OA Packer Depth 58 3000 2973 2968IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM231113192722 BBL Pumped:2.1 BBL Returned:2.1 Friday, January 12, 2024 Page 1 of 1            MEMORANDUM TO: Jim Regg � P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 23, 2021 SUBJECT: Mechanical Integrity Tests Hilcocp North Slope, LLC V -I 14A PRUDHOE BAY UN BORE V-1 14A Src: Inspector Reviewed By P.I. Supry d Comm Well Name PRUDHOE BAY UN BORE V- API Well Number 50-029-23178-01-00 Inspector Name: Austin McLeod 114A 203-185-0 11/7/2021 Permit Number: Inspection Date: Insp Num: mitSAM211108194748 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V -114A Type Inj W ',TVD 6563 Tubing 1567 1574 - 1578 - 1575 - - - PTD 2031850 ;Type Test SPT Nest psi 2520 - IA 67 2806 2781 2777 - BBL Pumped: 2.2 'BBL Returned 2.1 OA 423 — -J 436 437 437 Interval - - REQVAR iP/F i P ✓' Notes: 2 Year to 1.2x max anticipated (2100). AIO 24A.002. Tuesday, November 23, 2021 Page 1 of 1 Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Friday, January 8, 2021 12:49 PM To: Oliver Sternicki Cc: Rixse, Melvin G (CED); Alaska NS - PB - Field Well Integrity Subject: Re: V-1 14A (PTD# 203185 ) request for temporary MI service for evaluation of TxIA communication. Oliver, Your request for 45 days MI for monitoring and evaluation is approved. Regards, Chris From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, December 22, 2020, 1:50 PM To: Wallace, Chris D (CED) Cc: Rixse, Melvin G (CED); Alaska NS - PB - Field Well Integrity Subject: V -114A (PTD# 203185 ) request for temporary MI service for evaluation of TxIA communication. Chris, Well V -114A (PTD# 203185) currently operates under AIO 24A.002 for produced water injection only due to TxIA communication when on miscible injection (MI). We request permission to place V -114A on MI for a 45 day under eval period to monitor for IA repressurization. We would like to use this eval period to determine if well work completed on 12/21/20 has repaired the TxIA communication when on MI or reduced it to a suitable rate where an administrative approval request would be considered to return the well to WAG service. Annulus pressures will be maintained below 2100, 1000 psi (IA, OA). 12/22/2020 MIT -IA passed to 2462 psi with the well offline. 12/21/2020 "Extended Packing' DGLVs installed in GLM #1-6. IA loaded with 9.8 ppg brine. 3/23/2020 Nitrogen PPPOT-T passed to 2100 psi. 11/4/2019 AOGCC Witnessed MIT -IA passed to 2462 psi. 1/21/2016 Nitrogen MIT -T passed to 4000 psi. Let me know if you have any questions. Regards, Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com Wallace, Chris D (CED) From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, December 22, 2020 1:50 PM To: Wallace, Chris D (CED) Cc: Rixse, Melvin G (CED); Alaska NS - PB - Field Well Integrity Subject: V-1 14A (PTD# 203185 ) request for temporary MI service for evaluation of TxIA communication. -- Chris, Well V -114A (PTD# 203185) currently operates under AIO 24A.002 for produced water injection only due to TxIA communication when on miscible injection (MI). We request permission to place V -114A on MI for a 45 day under eval period to monitor for IA repressurization. We would like to use this eval period to determine if well work completed on 12/21/20 has repaired the TxIA communication when on MI or reduced it to a suitable rate where an administrative approval request would be considered to return the well to WAG service. Annulus pressures will be maintained below 2100, 1000 psi (IA, OA). 12/22/2020 MIT -IA passed to 2462 psi with the well offline. 12/21/2020 "Extended Packing" DGLVs installed in GLM #1-6. IA loaded with 9.8 ppg brine. 3/23/2020 Nitrogen PPPOT-T passed to 2100 psi. 11/4/2019 AOGCC Witnessed MIT -IA passed to 2462 psi. 1/21/2016 Nitrogen MIT -T passed to 4000 psi. Let me know if you have any questions. Regards, Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hiIcorp.com MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 5, 2019 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. V -114A PRUDHOE BAY UN BORE V -I 14A Ste: Inspector Reviewed By: Q� P.I. Supry ✓ `97 NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V- API Well Number 50-029-23178-01-00 Inspector Name: Lou Laubenstein 114A Permit Number: 203-185-0 Inspection Date: 11/4/2019 Insp Num: mitLOL191105104347 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V -114A " TypetBBLReturned: D 6563 Tubing 1254 1254 1254 1254 ' PTD 2031850 ` Typet psi 1641 IA 270 2502 2467 2462 ' BBL Pumped: 2 ' 1.9 OA 487 494 ' 494Interval REQVAR P ✓ Notes: MIT -IA to 1.2 times maximum anticipated injection pressure per AA 24A.002. They are calling the max injection pressure 1375psi due to past rates but asked the question if the test pressure should really going off of header pressure seeing as that is the highest posible pressure it will see. Thursday, December 5, 2019 Page I of 1 z MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, November 13, 2019 Pd. Supervisor 1/15117 SUBJECT: Mechanical Integrity Tests HE Exploration (Alaska) Inc. V -114A FROM: Lou Laubensteln PRUDHOE BAY UN BORE V-114A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry Tf--P— NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V- API Well Number 50-029-23178-01-00 Inspector Name: Lou Laubenstein 114A 203-185-0 11/5/2019 - Permit Number: Inspection Date: Insp Num: mitLOL191105104347 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-1 14A ' Type Inj W TVD 6563 Tubing 1254 1254 - t254n2462 PTD 2031850 Type Test SPT Test psi 1641 IA 270 2502 - 2467 BBL Pumped: 2 BBL Returned: 1.9 OA 487 494 -494 Interval REQVAR P/F P Notes: MIT -]A to 1.2 times maximum anticipated injection pressure per AA 24A.002. They are calling the max injection pressure 1375psi due to past rates but asked the question if the test pressure should really going off of header pressure seeing as that is the highest posible pressure it will see. Wednesday, November 13, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim jtegg 2 DATE: Wednesday,November 08,2017 P.I.Supervisor 1 \a //1 '`1 8H SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. V-114A FROM: Bob Noble PRUDHOE BAY UN BORE V-114A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv�//�--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V- API Well Number 50-029-23178-01-00 Inspector Name: Bob Noble 114A Permit Number: 203-185-0 Inspection Date: 11/7/2017 ✓ Insp Num: mitRCN171108053108 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-114A Type Inj W `TVD 6563 Tubing 1320 • 1318 1314 -1 1313` PTD 2031850 Type Test SPT Test psi 2064 IA 945 2482 - 2468 - 2458 BBL Pumped: 1.4 " BBL Returned: 1.3 - OA 395 400 401 - 401 - Interval REQVAR P/F P Notes: AA 24A.002 for TxtA communication.Test to 1.2 times max injection pressure.Max inject pressure is 1720 psi. SCANNED 2 1) Wednesday,November 08,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Friday,January 15, 2016 1:26 PM To: 'AK, D&C Well Integrity Coordinator' Subject: RE: Permission to Place Injector V-114A (PTD #2031850) on MI for Tubing by Inner Annulus Diagnostics Whitney, Your request is approved for up to 28 days MI for diagnostics and monitoring. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue ® ��6 Anchorage,AK 99501 �1o""_ ,r JUN 0 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace analaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator@bp.com] Sent: Friday, January 15, 2016 12:59 PM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: Permission to Place Injector V-114A (PTD #2031850) on MI for Tubing by Inner Annulus Diagnostics Chris, As per our earlier conversation, Injector V-114A(PTD#2031850) currently operates under Administrative Approval Area Injection Order(A10) 24A.002 for continued operations on produced water after showing signs of tubing by inner annulus communication on miscible injection (MI). The AA was approved December 10, 2007. Leak detect logs were unable to pinpoint the leak location however gas lift valve#1 was pulled and reset on October 26, 2008. BP requests permission to deviate from the AA and place the well on MI for up to 28 days to evaluate if changing out the gas lift valve fixed the previously noted tubing by inner annulus communication. If communication has been mitigated, BP will pursue cancellation of the current AA. Please advise if a different course of action should be taken or recommend an alternative plan forward if this does not meet expectations. A copy of the AA and Wellbore Schematic have been attached for reference. Thank you, 1 STATE OF ALASKA • 0 • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 203-185 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-23178-01-00 7. Property Designation(Lease Number): ADL 0028240 8. Well Name and Number: BRLS V-114A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,BOREALIS OIL 11.Present Well Condition Summary: Total Depth: measured 11444 feet Plugs measured feet RECEIVED true vertical 6730 feet Junk measured feet Effective Depth: measured 11345 feet Packer measured 7969 feet DEC 0 8 2015 true vertical 6736 feet Packer true vertical 6563.04 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 2918 9-5/8"40#L-80 28-2946 28-2687 5750 3090 Intermediate 8195 7"26#L-80 26-8221 26-6662 7240 5410 Production Liner 3411 4-1/2"12.6#L-80 8021 -11432 6584-6731 8430 7500 Perforation Depth: Measured depth: 8286-8316 feet 9630-9655 feet 9655-9680 feet 9800-9825 feet 9825-9875 feet 9875-9920 11100-11335 feet True vertical depth: 6683-6691 feet 6720-6724 feet 6724-6727 feet 6743-6746 feet 6746-6749 feet 6749-6750 6740-6736 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 24-8025 24-6586 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): I �, Treatment descriptions including volumes used and final pressure: �� 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 2935 820 1581 Subsequent to operation: 1218 840 1357 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development ❑ Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ® WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature .4J / Phone +1 907 564 4424 Date 12/4/15 Form 10-404 Revised 5/2015 14-1--- /Z/a 3/15 ,*(2,4p/.7, RBDMSSc_ y y Z015 Submit Original Only • • Packers and SSV's Attachment BRLS V-114A SW Name Type MD TVD Depscription V-114A TBG PACKER 7969 6563.04 4-1/2" Baker S-3 Perm Packer V-114A PACKER 8029 6587.57 4-1/2" Baker ZXP Packer 0 0 0 . a_ c Co e ? / / / ? i / f '0 2 $ $E _\ 72 � \ o % f o \ O� \ I / § 0_ o , o o o o 0% 6 0 » a 7 \ a n co < ƒ c E e 0 5 a -1 0 / / >, 0. R �8 ? 0 m ® O7m \ / e \ 0 � a ® 00 k LI 00e0 0 0 0 0w / � / \ 2 tce / 7 < / \ 0 9 < 0 N. 0 J i - \ \ / E Toa = / co o, > \ k 05 0 0)\ r, * - k I- 0) emt - En 0 2 0 2 O _% c \ / / k /\ ,- / \ \ 2 Cl) k / \ \ a < °.§ c o 0 2 k 4:k rx 0 x \ 7 \ f / k ? 7 / / / / 2 2 \ r r F \ / Cl) » 5 co f COo R 0 < TREE= 4-1/16'QW I WELLI-EAD= FMC 410 SAFETY NOTES:H2S READINGS AVERAGE 125 ppm ,JACTUATOR= N/A V-1 1 4A WHEN ON MI.WELL REQUIRES A SSSV WHEN ON KB. BEV= 81.8 MI. WELL ANGLE>70°@ 8233'. BF.ELEV= 55.9' KOP= 300' Max Angle= 94'@ 11396' Cetum MD= 8151' I I 2212' —4-1/7 HES X NP,ID=3.813" Datum TVD= 6600'SS 9-5/8'CSG,40#,L-80,D=8.835"j— 2946' A k GAS LFT MANDRELS T. ST M) TVD DEV TY FE VLV LATCH PORT DATE b 6 2852 2684 30 KBG-2 DMY BK 0 03/13/04 5 3654 3311 32 KBG-2 DMY BK 0 11/30/03 4 4732 4208 33 KBG-2 DMY BK 0 03/13/04 Minimum ID = 3.813" @ 2212' 3 5807 5041 32 KBG-2 DMY BK 0 03/13/04 2 6509 5702 36 KBG-2 DMY BK 0 03/13/04 HES X NIPPLE 1 7150 6196 51 KBG-2 OMY BK 0 10/26/08 I i 7948' —4-1/2'HES X NP,0=3.813' 7969 _H7'X 4-1/2'BKR S-3 PKR,ID=3 875' I I r 7992' —4-1/2"HES X NP,0=3.813' I I 8013' —14-1/2'HES X NP,13=3.813" II 8021' H5"X 7"BAKER HAAC LNR HGR 4-1/2'TBG, 12.6#,L-80,.0152 bpf,13=3.958' -- 8025' / \ 8025' j—I4-1/2"WLEG,0 4.000" / 8041' --5"X 4-1/2'X0,ID=3 950' 7'WINDOW 8221'-8233' 9-5/8'W- STOCK — 8221' 9288' —1PUP JT W/RA TAG I 9793' 1—IAJPJT W/RA 14-,G-1 9-5/8'FES EZSV 1— 8239' 1 1 I I 10340' H PUP JT VV/RA TAG 7'CSG,24-,L-80, .0383 bpf,13=6.276'1-- 8533' ild PERFORATION SUR/MARY REF LOG: ANGLE AT TOP PEW: 74°@ 8286' Note:Refer to Roduction DB for historical perf data SIZE SPF HTERVAL Opn/Sqz DATE 2-7/8" 6 8286-8316 0 11/03/15 8. 2-1/2" 6 9630-9680 o 10/17/04 PBTD H 11345' N .., 2-1/2" 6 9800-9920 0 10/17/04 4- 7'SOLID LM,12.6#,L-80, .0152 bpf,0=3.958' --pii-4-2- n 2-1/2" 4 11100- 11335 0 11/20/03 DATE 1 REV BY CORSE:NTS DATE REV BY 000443gTS BOREALIS UNIT 11/22/03 1JCIPA/TLP IMTIAL COMPLETION 02/15/11 M3/JM) ADDED SSSV SAI-t I Y NOTE WELL. V-114A 11/30/03 . JLJ/TLP GLV GO 01/19/12 TA4C1\43 ADDED I-QS SAFETY NOTE PERMIT Nb.1031850 03/24/04 JLJ/TLH GLV ao 11/06/15 LL/JM) A DPERFS(11/03/15) All No: 50-029-23178-01 10/17/04 DBAATLP 4-1/2"TBG,ADD PEWS SEC 11,T11N,R11E,4049'NSL&1789'W13_ 10/17/08 DTR/PJC GLV 00(09/05/08) 11/10/081 KDOSV GLV(70(10/26/08) BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: gg DATE: Friday,October 09,2015 P.I.Supervisor \ e/et (Oh(S SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC V-114A FROM: Chuck Scheve PRUDHOE BAY UN BORE V-114A Petroleum Inspector Src: Inspector Reviewed B� P.I.Supry /a— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V- API Well Number 50-029-23178-01-00 Inspector Name: Chuck Scheve 114A Permit Number: 203-185-0 Inspection Date: 10/2/2015 Insp Num: mitCSl51002155150 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well T V-114A Type Inj 1-W TVD ( 6563 " Tubing 1573 - 1575 " 1575 1582 - PTD iI 2031850 - Type Test SPT Test psit 1641 _ IA 363 2720 2674 2668 Interval REQVAR P/F P OA 369 377 - 378 - i 377 - 1 — L —�. Notes: Tested Per A10 24A.002 Friday,October 09,2015 Page 1 of 1 2C009 t} WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. DATA LOGGED S/5/2015 K BENDER To: AOGCC 1.1 E+.:: D Makana Bender 333 W. 7th Ave AUG 0 4 201:i Suite 100 Anchorage, Alaska 99501 , , . (907) 793-1225 �'�)('1A't } RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2-1 900 Benson Blvd. Anchorage, AK 99508 gancpdcObp.com and 401 ProActive Diagnostic Services, Inc. t116 Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 09-Jul-15 V-114A BL/CD 50-029-23178-01 2) MA42,07.4k.,(1)Signed : O Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Ach,ves\MasterTemplateFiles\Templates\Distribution\TransmtttalSheets\BP_Tran,mit docx e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q 0 3 - L q 5 Well History File Identifier Organizing (done) D Two-sided II 111111111" 111111 D Rescan Needed 1111111111111111 1/1 RESCAN DIGITAL DATA ~iskettes, No. a D Other, NofType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: Date W3 of fb Date JJ-taD)os- 3 D Other:: BY: (;;) 151 mP Project Proofing 11111111111111 1/1/1 BY: ~ 151 VVlf BY: + :JLL = TOTAL PAGES II '1= _ ~nt does not include cover sheet) 151 Scanning Preparation Date: Production Scanning Stage 1 Page Count from Scanned File: I / .5" (Count does include co~eet) Page Count Matches Number in sca~nin¡ prep.ara~~: V YES BY: ~ Date: 1d-/dD!OS Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 111111111111111/1/1 151 NIMP NO BY: Maria Date: 151 11111111111111 111/1 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 111/1 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, November 04, 2011 TO: Jim Regg P.I. Supervisor ell 1( � J I ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V -1 I4A FROM: Jeff Jones PRUDHOE BAY UN BORE V -114A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry - NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN BORE V -114 API Well Number: 50- 029 - 23178 -01 -00 Inspector Name: JeffJones A Insp Num: mitJJ111103163903 Permit Number: 203 - 185 - Inspection Date: 10/28/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v -114A Type Inj. w , TVD r 6563 IA 410 2490 - 2440 2430 - P.T.D 2031850 • TypeTest SPT Test psi 1640 - OA 398 405 - 406 407 Interval REQVAR pj' P Tubing 1760 1740 1725 1722 Notes: 2 year MIT for AA 24A.002. 1.8 BBLS methanol pumped. 1 well inspected; no exceptions noted. , yyi�d _ 7 ( ..` Friday, November 04, 2011 Page 1 of 1 MEMORANDUM TO: Jim Re P.I. 5upgr~visor ~~ ~~ ~~ ~ d ( FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 02, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-114A PRUDHOE BAY UN BORE V-114A Src: Inspector NON-CONFIDENTIAL Reviewed Bye P.I. Suprv J~~~ Comm Well Name: PRUDHOE BAY UN BORE V-114 API Well Number: 50-029-23178-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS091030155344 permit Number: 203-185-0 Inspection Date: 10/29/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~V-114A ~~i ~ -T-----~ Well ~ Type Irij. I W T~ ~ ~- -- - ~ 2031850 t SPT /~T T ~------T 6563 ~ jA ; ll40~ 2700 ----- ~-- --- 1640 /' QA 520 540 /~ ~ ~ _.... 2660 ~ 2660 ---!-- f 540 540 - P.T Di` _ e CS TCSt Sl i i YP i P _ i _ - ~ - - ~ -- -- __ ~ - ~ ~ - REQVAR P Interval P/F _ zzoo z2oo Tubin g~---- ----- I -!--- zzoo zzoo - -_-~--- Notes• Test required by AA#24A.002 - -------- ~ ~1~ c ~~;~~~~~~ ~ ~S ~~ Monday, November 02, 2009 Page 1 of 1 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 N 9 +{A ~ ~ { L..~~~ s '~:;x ~`~. L 4s.` ~ :' ~ ;l I- `~ ~ ~ bp ~~~~~ Y ~~ OCT 0 5 2~09 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, Ab~dca ail ~ Gas Cons. ~ammia~in~ Anchorapa ~3 -(~S' ~/^~l~'f'l~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- 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 • i BP Exploration (Alaska ) inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Finai top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-Ot 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 2t.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-1o6A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-1o9 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5l10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA t3.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-201 2012220 50029230540000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 v-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-2t1 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 ~A 2080200 50029233830000 NA 1.75 NA #5 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9!7/2008 04/14/09 llEr~~~1J~5~~s~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth }' `''~~ ~Pn ,. y.(~~++,~ ur~wM"U k~a i J LU U;! N0.5188 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wcll ~wti k ~_ / t °„r~) ,n~'~~ (: , . W-18 11968978 RST _r vase 12/22/08 OL 1 GOIOr GU 1 07-026 AXBD-00013 MCNL 02/1?J09 1 1 K-05C AWJB-00016 MCNL (.- 12/30/08 1 1 F-18A AYLF-00020 CEMENT IMAGE LOG ~ J ~- 03/19/09 1 1 J-09A AP30-00024 STP CROSS FLOW CHECK L ~ ~ 03/25/09 1 1 X-05 AYTO-00014 PFCS CALIPER LOG) _ C 04/09/09 1 1 O-04A AYTU-00023 _ LDL & PLUG SET jni5 - s 04/02/09 1 1 04-40 AYTU-00025 USIT ~ ~- 04/10/09 1 1 06-14B AVYO-00021 SCMT '~- 04/01/09 1 1 Z-016 AVYO-00025 INJECTION PROFILE --/p ~~ 04/11/09 1 1 L3-15 AYTU-00023 -._ _ PRODUCTION PROFILE ~ ` 04/06/09 1 1 11-30 AXBD-00021 MEM PROD PROFILE j c~ _ °~-~ 04/14/09 1 1 3-03/J-33 AZ4D-00013 RST WANJ PROFILE - / ~a 04/05/09 1 1 3-17F/K-30 BIJJ-00006 MEM INJECTION PROFILE - (~ j 04/03/09 1 1 3-49A/M-40 V-114A AXBD-00019 AVY500032 MEM INJECTION PROFILE: INJECTION PROFILE ~ j fhb 04/07/09 04/02/09 1 1 1 1 -- - - i lJ I ' ~' THESE 2 WELLS WERE DELIVERED SEPARETLY TO MEET COMPLIANCE TRANS # 5185 E-36A AYTU-00006 OH MWD/LWD EDIT (IFLEX) j _~'.~- ~~9 01/14/09 1 1 MPS-43 AXML-00020 OH LDWG EDIT 12/29/08 2 1 PLEASE ACKNOWLEDGE RE CEIPT BY SIGNI NG AND RETURNING O rrr...~cas _,- NE COPY EACH TO: ' BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503 838 ATTN: Beth Received by:_ • r~ ~J STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL ~P~RATtOt~S ~~ 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ Stimulate ~ Other ~ Bright Water Performed: Alter Casing ~ - Pull Tubing Perforate New Pool ~ Waiver ~ Time Extension ~ Treatment Change Approved Program ~' Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Welf Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ~ 203-1850 - 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-23178-01-00 - 7. KB Elevation (ft): 9. Well Name and Number: 81.8 KB V-114A - 8. Property Designation: 10. Field/Pool(s): ADLO-028240 ~ Prudhoe Bay Field/ Borealis Oil Pool 11. Present Well Condition Summary: Total Depth measured ; 11444 - feet Plugs (measured) None true vertical r 6729.68 ~ feet Junk (measured) None ,y Effective Depth measured 11345 ~ feet true vertical 6735.86 ~ feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 29 - 109 29 - 109 1490 470 Surface 2918 9-5/8" 40# L-80 28 - 2946 28 - 2687 5750 3090 Production 8195 7' 26# L-80 26 - 8221 26 - 6662 7240 5410 Liner 3411 4-1/2" 12.6# L-80 8021 - 11432 6584 - 6730 8430 7500 Perforation depth: Measured depth: See Attachment - _ _ _ _ True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 24 - 8025 0 0 - Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 7969 4-1/2" Baker ZXP Packer 8029 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13• Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development " Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~ WAG ~`' GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 9/24/2008 Form 10-404 Revi ed 04/2 6 ..~ ~ ~__, ~ l ~ ~ Submit Original Only l8 ~-~ _ ~~ V-114A 203-1850 PERF ATTACHMENT • Sw Name O eration Date Perf O eration Code Meas De th To Meas Depth Base Tvd De th To Tvd De th Base V-114A 11 /20/03 PER 11,100. 11,335. 6,739.7 6,736.13 V-114A 10/14/04 APF 9,875. 9,920. 6,748.55 6,750.41 V-114A 10/15/04 APF 9,825. 9,875. 6,745.63 6,748.55 V-114A 10/16/04 APF 9,655. 9,680. 6,723.66 6,727.16 V-114A 10!16/04 APF 9,800. 9,825. 6,742.99 6,745.63 V-114A 10/17/04 APF 9,630. 9,655. 6,720.35 6,723.66 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • V-114A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ACTIVITYDATE ~ SUM,MARY ~ 8/11/2008: Started the Bright Water Injection at 10:45 am at a rate of 44 GPH (EC9360A) Surfactant and started pumping (EC9378A) Polymer at 11.45 am at a rate of 76 '; GPH. Water in~e_rtinn rate is at 5000 BPD at 18 0 psis 8/11/2008 Protechnics SpectraFlood Services -Tracer for Britewater project. ......_.. ..... 8/12/2008 Continue to pump Bright Water (EC9378A) Polymer at 76 GPH and (EC9360A) Surfactant at a rate of 44 GPH. Water Iniection rate at 5000 BPD at 1850 psi. 8/13/2008 Continue with Bright Water chemical injection with the rate of (EC9378A) i Polymer 76 GPH and (EC9360A) Surfactant 44 GPH. Water Injection rate of ', :5000 BPD at 1900 psi. 8/14/2008; Continue to pump BrightWater chemical into well at 44GPH(EC9360A) 'Surfactant and 76GPH (EC9378A) Polymer with an injection rate of 5000 BWPD. 8/15/2008; Continue to pump BrightWater chemical into well--EC9360A Surfactant at 44 :GPH and EC9378A Polymer at 77 GPH with water injection rate at 5000 psi, :well a head pressure of 2000 psi _._.... ...,._ ._M...~_ __.... 8/16/2008 Pump BrightWater chemical into well--EC9360A(Surfactant)~at 44 GPH and EC9378A(Polymer) at 77 GPH. Stop pumping Polymer at 0300 am due to ;injection water rate went from 5000 BWPD down to 2500 BWPD. Water injection :rate dropped further. Pumped Surfactant until) 0500 am then shut down ;pumping. 75-80% of BW volume pumped away. GC2 having problems with :water pumps, there was a TAPS pro-ration, and the plant could not promise continued water injection. Job completed FLUIDS PUMPED GALLONS 5706 Dispersant 8233 Polymer 13939 Total • • =-~ MICROFILMED 03/01/2008 DO NOT PLACE .::<,` -~~ ~~"` - ~~ ANY NEW MATERIAL. UNDER THIS PAGE F:1LaserFichelCbrPgs_InsertslMicrofilm_Marker. doc 1•aa a i viii / iVi • i i ~< 1 `i i L ri V/ i V/v~~ L U.~~: L Regg, James B (DOA) ~ ~ ~/ ..- 1 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comJ ~~-~j`1 II~Z J~,_7 Sent: Wednesday, November 07, 2007 1:58 PM t To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: MIT Forms for V-114A (PTD #2031850}, Attachments: MIT PBU V-114A 11-03-07.x1s; MIT PBU 14-17A 11-04-07.x1s; MIT PBU L-105 11-03-07.x1s; MIT PBU PSI-01 11-04-07.x1s Jim, Tom and Bob, Please see the attached MIT forms for the following wells: V-114A PTD #2031850 ITIA for upcoming AA request 14-17A (PTD #2030010) MITIA for 4-year regulatory compliance L-105 (PTD #2020580) MITIA and LLR-OA for AA compliance PSI-01 (PTD #2021450) MITIA for 4-year regulatory compliance «MIT PBU V-114A 11-03-07.x1s» «MIT PBU 14-17A 11-04-07.x1s» «MIT PBU L-105 11-03-07.x1s» «MIT PBU PSI-01 11-04-07.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 _...,, .~_- z .. . __ . 11 /7/2007 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: WinTon_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD !UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / V pad 11 /03/07 Anna Dube ~~,~~~ „~7I~7 ~~~~ ~rb3 Packer Deplli Pretest Initial 15 Min. 30 Min. Wetl V-1 i4A ;'Type Inj. W TVD 6563' Tubing 24D0 2400 2400 2400 Interval O P.T.D. 2031850 Type test P Test psi 4000 Casing 1080 4000 3940 3940 PIF P Notes: MIT-IA for upcoming AA request. OA 550 550 550 550 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing PIF Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA TYPE INJ Codes D = Grilling Waste G =Gas I = Jndustrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A -Temperature P,nomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 = Four Vear Cycte V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL9l1/OS M17PBU V-114A 11-03-OZxls • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@adrnin.state ak.us; Jim_Regg@adminstate.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. ~~ CI ~!'~`, "~ FIELD /UNIT /PAD: I Prudhoe Bay /PBU / L pad ~ ~~ ~~ DATE: 11 /04/07 ~ OPERATOR REP: Anna Dube AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well L-105 Type Inj. W TVD 6248 Tubing 1850 1850 1850 1850 Interval O P.T.D. 2020580 Type test P ~ Test psi '4000 Casing 420 14000 3960 3940 P/F P -~ Notes: MIT-IA for AA compliance OA 880 850 860 880 A-k~ Z`1-, C%Oq- Well L-105 Type Inj. W TVD 6248 Tubing 1710 1710 1710 1710 Interval O P.T.D. 2020580 Type lest P Test psi ;,3000 Casing 20 30 30 30 P/F Notes: LLR-OA for AA compliance = .38 gpm- OA 880 3000 3000 3000 Well Type Inj. ND Tubing Interval P.T.D. Type test Tesl psi Casing P/F Notes: OA Welt Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Tesl psi Casing PJF Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling `JJaste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe m notes) ~~% ~4- ~OCX(- ~,~'~/t,~(si,~ ~~~~ ~ u~:u~ :~) ~,yl•2ctc~~ i l,'~..ZT-c-~l~ ~ 3wc~r s. Mt7 Report Farm BFL 9/1/05 MIT PBU L-105 11-03-07.x1s RE: Y=J..l-4 (PTD #2031850) IA r.'. ssurization \!-ll4-A ~ Regg, James B (DOA) . Page 1 of 1 From: NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.cOm]r,7a9¡6{O Sent: Tuesday, September 04,200712:19 PM 'f..,~ l 7 To: Rossberg, R Steven; NSU, ADW Well Operations Supervisor; Regg, James B (DOA); Maunder, Thomas E (DOA); Engel, Harry R Cc: NSU, ADWWI Tech; Lau, John, Jack; NSU, ADWWelllntegrity Engineer; GPB, Area MgrWest (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; Oakley, Ray (PRA) Subject: RE:.\t-4-'ttt(PTD #2031850) IA repressurization r&\ v- \14 A Jim and Tom, \,LI\4-A- Well'l:.:U4 is currently on MI injection. The GC2 Facility will be initiating a 16 day shutdown on 9/5/07. The plan is to v swap this well to water after the shutdown, put it on water injection, and conduct an AOGCC witnessed MITIA at that time. Please let me know if you have any concerns or questions. Thank you, fl-nna CDu6e æ P.. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 SCANNED SEP 1 12007 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, August 29,20078:16 AM To: NSU, ADW Well Integrity Engineer; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); Rossberg, R Steven; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; 'AOGCC Jim Regg (E-mail).;NSU.ADWWL&CompletionSupervisor;GPB.GC2WellpadLead;·tom_maunder@admin.state.ak.us·; Oakley, Ray (PRA) Cc: NSU, ADW WI Tech; Lau, John, Jack Subject: V-114 (PTD #2031850) IA repressurization Hello Jim and Tom, Well V-114 (PTD #2031850) is exhibiting indications of possible TxlA communication. The field Operator bled the IA from 2040 psi to 1000 psi on 08/17/07 with gas and diesel returns. IA repressurization was -100 psi/day. Also, the IA has exhibited pressure spikes on a few occasions over the course of the past 3 months, subsequent to the MI rate being increased in May. The current plan forward is to perform an MITIA to evaluate the TxlA communication. During this evaluation the well will remain on injection and the IA will be monitored for repressurization. Attached is a TIO plot and wellbore schematic for reference. Please call with any questions. « File: V-114 TIO plotJPG» «File: V-114A.pdf» Thank you - Jack L. Winslow (for Anna Dube) Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 9/5/2007 V -114 (PTD #2031850) IA repress.ation Regg, James B (DOA) . Page 1 of 1 From: \2ær1 1J IZ1/ù 7 Sent: To: NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Wednesday, August 29,20078:16 AM NSU, ADWWelllntegrity Engineer; GPB, GC2 OTL; GPB, Area MgrWest (GC2/WRD); Rossberg, R Steven; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; Regg, James B (DOA); NSU, ADW WL & Completion Supervisor; GPB, GC2 Wellpad Lead; Maunder, Thomas E (DOA); Oakley, Ray (PRA) Cc: NSU, ADW WI Tech; Lau, John, Jack Subject: ~(PTD #2031850) IA repressurization Attachments: ~TIO plotJPG; V-114A.pdf ft)Ll V-1I4 A Hello Jim and Tom, Well ~PTD #2031850) is exhibiting indications of possible TxlA communication. The field Operator bled the IA from 2040 psi to 1000 psi on 08/17/07 with gas and diesel returns. IA repressurization was -100 psi/day. Also, the IA has exhibited pressure spikes on a few occasions over the course of the past 3 months, subsequent to the MI rate being increased in May. The current plan forward is to perform an MITIA to evaluate the TxlA communication. During this evaluation the well will remain on injection and the IA will be monitored for repressurization. Attached is a TIO plot and wellbore schematic for reference. Please call with any questions. «V-114 TIO plotJPG» «V-114A.pdf» Thank you - 5CANNED SEP 0 7 2007 Jack 1. Winslow (for Anna Dube) Well Integrity Engineer office - 659-5102 pager-659-5100, 1154 ~~ ú':¡ Bf (J(LCt LVìA~b.~ <51 '2~ I 0 7 a. At,( c1j re e£J.-]v --fk:: r þ'~ì'\eøJ C<ffX'{)Q(J... .fdr d-14~ Itcc¿.j.ès. ' re p~SSI/V{~ .U'tJ be. ~ tr?~1 s'f<er 8/29/2007 I 4-1/16" CNV FMC NIA 81.8' 55.9' 300' V-114A 8151' 6600' SS 1 9-5/8" CSG, 40#, L-80. ID = 8.835" I NOTES: 2212' 14-1/2" HES X NIP, ID = 3.813" I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 6 2852 2684 30 KBG-2 DMY BK 0 03/13/04 5 3654 3311 32 KBG-2 DMY BK 0 11/30/03 4 4732 4208 33 KBG-2 DMY BK 0 03/13/04 3 5807 5041 32 KBG-2 DMY BK 0 03/13/04 2 6509 5702 36 KBG-2 DMY BK 0 03/13/04 1 7150 6196 51 KBG-2 DMY BK 0 03/13/04 Minimum ID = 3.813" @ 2212' HES X NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 8025' I TOP OF 7" BAKER WHIPSTOCK f- 8221' ~ I 9-5/8" HES EZSV I 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" I 8533' ÆRFORA nON SUMMA RY REF LOG: ANGLEATTOPPERF: @ 9630' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-112" 6 9630 - 9680 0 10/17/04 2-1/2" 6 9800 - 9920 0 10/17/04 2-1/2" 4 11100 - 11335 0 11/20/03 7948' 7969' 7992' 8013' 8021' 8025' 4-1/2" HES X NIP, ID = 3.813" - 7" X 4-1/2" BAKER S-3 PKR, 10 = 3.875" -4-1/2" HES X NIP, 10 = 3.813" I -4-1/2" HES X NIP, 10= 3.813" I - 5" X T' BAKER HMC LNR HGR -14-1/2" WLEG, ID = 4.000" I 8041' -15" X 4-1/2" XO, ID = 3.950" I I 7" WIN DOW 8221' - 8233' 9288' -PUPJTW/RA TAG I 9793' -1 PUP JT W/ RA TAG I 10340' -1 PUPJTW/ RA TAG I I PBTD 11345' 4-1/2" SOLID LNR, 12.6 #, L-80, 10 = 3.958" I DATE 11/22/03 11/30/03 03/24/04 10/17/04 COMMENTS REV BY COMMENTS JDMITLP INITIAL COMPLETION JLJITLP GL V C/O JLJ/TLH GL V C/O DBMlTLP 4-1/2" TBG, ADD ÆRFS DATE REV BY 11432' BOREA LIS UNIT WELL: V-114A PERMIT No: 2031850 AP! No: 50-029-23178-01 SEC 11, T11 N, R11 E, 4049' NSL & 1789' WEL BP Exploration (Alaska) . STATE OF ALASKA ALAS Oil AND GAS CONSERVATION COMM.N REPORT OF SUNDRY WELL OPERATIONS o o o 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 81.8 KB 8. Property Designation: ADLO-028240 11. Present Well Condition Summary: Total Depth measured 11444 feet true vertical 6729.68 feet Effective Depth measured 11345 feet true vertical 6735.86 feet Casing Length Size MD Conductor 80' 20" 91.5# H-40 29' - 1 09' Surface 2918' 9-5/8" 40# L-80 28' 2946' Production 8195' 7" 26# L-80 26' 8221' Liner 3411' 4-1/2" 12.6# L-80 8021' - 11432' Perforation depth: Measured depth: 9630' - 11335' True Vertical depth: 6720' - 6739' - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# ~! I' IU06 Alaska Oil & . Con'\ Cr"", . . A '. . """'01I$810n n¡;jW(age Stimulate 0 Other 0 Convert to WAG WaiverD Time Extension 0 Re-enter Suspended Well D 5. Permit to Drill Number: 203-1850 Exploratory Service p 6. API Number: 50-029-23178-01-00 9. Well Name and Number: PBU V-114A 10. Field/Pool(s): PRUDHOE BAY Field/ BOREALIS OIL Pool Plugs (measured) None Junk (measured) None TVD 29' - 109' 28 - 2687' 26' - 6662' 6584' - 6730' Burst 1490 5750 7240 8430 Collapse 470 3090 5410 7500 - - L-80 24' - 8025' 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer o o Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 7969 8029 o o c c ~.' Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 2656 320 o 15601 0 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG P Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations X Oil-Bbl o o 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Tubing pressure 998 2809 Service p WINJ WDSPl Title Data Engineer Signature Phone 564-4944 Date 11/28/2006 8Ft {) '.~ 2006 Submit Original Only . . V-114A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY Well converted to WAG from WI Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well /}63- 185- S-03 ;91- ¡'to V-114A (REVISED) S-111 L-123 , V-114A PB1 :;}()3-HJM V-114A PB2 '20;.1 i&f!L.. W-207 PB1 a/")~-O~ 11057082 40009730 11058510 10987558 40009730 40009730 40008886 --~ :~~~ ~~~-'¡~~~tJ ct"B" Ö'?'" ~l- l..·~L 4"'~ "J,,-iH;;>. ;_A)ã11m¡$S~Qn }\J1i~~ Job# Log Description PERF/SBHP OH LDWG EDIT OF MWD/LWD USIT USIT OH LDWG EDIT OF MWD/LWD OH LDWG EDIT OF MWDILWD OH LDWG EDIT OF MWD/LWD 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: ~ I !J9--J Dl.P SCA,Nì\!EC' FE8 2: E 2005 01103/06 12/15/03 OS/28/05 01/01/06 11/03/03 12/15/03 04104103 02113/06 NO. 3680 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage. AK 99501 Field: Polaris Borealis Aurora Date BL Color CD ~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth R~"od b~O j dì ~ -" Schlumberger RECEIVED Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth JAN 0 9 2006 "'OI&GasCœs.Ca~1 Anduage Well Job# Log Description S-215 V-114A } ·V-114A r1\2fo.r V-114A ~ U~ 11084269 INJECTION PROFILE 40009730 OH LDWG EDIT OF MWD/LWD 40009730 MD VISION SERVICE 40009730 TVD VISION SERVICE 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: , '" ,., ú.:t 8CAtiNEt JAN rø ~ ?r\(\ß _ w",iJ 07/04/05 12/15/03 12/15/03 12/15/03 01106/06 NO. 3656 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Borealis j.p3 -I t1J5 Date BL CD Color -- Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 :::t~ ) ..~ ~ Ì- þ..a<- DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031850 Well Name/No. PRUDHOE BAY UN BORE V-114A Operator BP EXPLORATION (ALASKA) INC MD 11444/, TVD 6730"" Completion Date 11/22/2003./ Completion Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, AZM, DENS, NEU, RES, PWD, AIM, USIT, Sonic Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name I~D ~ F D Asc I~ ! ~ D Asc t~:, I ~:~:, g ED C Pds C Las C Pdf C Las C Pdf ! ED ,¡ ED ED ED Current Status 1WINJ 5/J-fÑl J ( ð't-,¿ 01>- API No. 50-029-23178-01-00 ~ Directional ~ Yes ~ (data taken from Logs Portion of Master Well Data Maint Log Log Scale Media Run No Interval Start Stop Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey 12326 Cement Evaluation o 8000 12326 Cement Evaluation 5 8000 Cement Evaluation 5 Blu 8000 12327 Cement Evaluation 15 2250 12327 Cement Evaluation 15 2250 Cement Evaluation 15 Col 2250 12488 See Notes 12488 See Notes 12488 See Notes 12488 See Notes 12488 Temperature 7114 7114 7114 7114 o o 11444 o 11444 o 8544 OH/ CH . Received Comments 12/1/2003 Text, Word & Excel surveys I 12/1/2003 12/1/2003 PB1 - Text, Word & Excel surveys Open Open Open o o 8544 Open 12/1/2003 10677 Open 12/1/2003 10677 Open 12/1/2003 11335 Case 12/22/2003 11335 Case 12/22/2003 11335 Case 12/22/2003 8200 Case 12/22/2003 8200 Case 12/22/2003 8200 Case 12/22/2003 8283 8283 8283 8283 8283 Case 3/22/2004 Case 3/22/2004 Case 3/22/2004 Case 3/22/2004 Case 3/22/2004 PB1 PB2 - Text, Word & Excel I surveys PB2 Cement Bond Log, Slim Sonic - GR Cement Bond Log, Slim Sonic - GR I Cement Bond Log, Slim I Sonic - GR n ^,..O. ~O). Ultrasonic Imaging Tool, USIT/GR/CCL . PB1 Ultrasonic Imaging Tool, USIT/GRlCCL - PB1 ! Ultrasonic Imaging Tool, I US IT /GR/CCL - PB1 J). Nor ¡o" > Jewelry Log Jewelry Log Jewelry Log i I Jewelry Log Ji Temperature Log . DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031850 Well Name/No. PRUDHOE BAY UN BORE V-114A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23178-01-00 MD 11444 TVD 6730 JlI ED C Las 12488 Temperature I ED C ~df 12488 See Notes ED C Las 12488 See Notes I LO~""-t1I..~ '"~, '--~m~ ::""III;:¡tion Well Cores/Samples Information: Completion Date 11/22/2003 Completion Status 1WINJ ~ L, "- 5 tt ..L.- o 7752 7752 BIll- 8000 ~-- Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? ø Chips Received? ~ Analysis ~ Received? Daily History Received? Formation Tops Comments: bH (:)~ ~ ,',r'h , I>L ~ ~~ -~ -- Date: ~ ~~-- . -~.._~"._- Compliance Reviewed By: Current Status 1WINJ UIC Y 8283 Case 3/22/2004 Temperature Log 8147 Case 3/22/2004 Static Survey 8147 Case 3/22/2004 Static Survey 11335 Case 9/27/200.4 .cEMEJ:,IT ROND LOG, SLlM...wNJ£-GR ì _J Sample Set Number Comments . @/N @N tJ (2- 7 ~f) J¡ ./lJ: ~(;l/':.- It ~ '1-0 2- ;203 -I' , ,2;,''''1,3' 09/27/04 Schlumberger NO. 3219 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm -Attrt.-it!JU'" L.111c1~UII - 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Orion Polaris Color CD Well Job# Log Description Date BL ~ I).. -114A 10662970 SCMT 11/17/03 1 '"-~ V-213 10877764 USIT 07/25/04 1 V-213 10877764 CH EDIT PDC-GR USIT} 07/25/04 1 L-211 10679059 US IT 03/12/04 1 9~ ·211 10679059 CH EDIT PDC-GR USIT 03/12/04 1 ,;/ W-215 10662954 USIT 09/20/03 1 W·215 10662954 CH EDIT PDC-GR USIT) 09/20/03 1 W·215 40009586 OH EDIT MWD DATA 09/09-16/03 2 1 /"'" W-215 PB1 40009586 OH EDIT MWD GR DATA 09/09·10/03 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: 9~71of I I ."" . ' . . @1i@lirE rmrE @n @@rYl@ / æ) U W U Lb lJ1J If flU l1lJlJ Q¿) ~ /JU FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA OIL AND GAS / CONSERVATION COMMISSION / Jf OJ -{~~ 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bruce Smith Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay V-114A Sundry Number: 304-401 Dear Mr. Smith: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested BY ORDER OF THE COMMISSION DATED this /~ay of November, 2004 Enc!. ""' ~ , I STATE OF ALASKA . ALAS OIL AND GAS CONSERVATION CcW1lSSION APPLICATION FOR SUNDRY APPROVAIlY \t 2004 20 AAC 25 280 ... , ,: .. f> ,. 1. Type of Request: D D D PerforateD Wái-.ierD'i Annular Disposal D Abandon Suspend Operation Shutdown Alter Casing D Repair Well D Plug Perforations D StimulateD Time ExtensionD OtherŒ] Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 Convert to WAG Inj 2. Operator 4. Current Well Class: 5. Permit to Drill ~ber: Name: BP Exploration (Alaska), Inc. 203-1850 Development D Exploratory D 3. Address: P.O. Box 196612 // 6. API Number / Anchorage, Ak 99519-6612 Stratigraphic D Service Œ] 50-029-23178-01-00 7. KB Elevation (ft): 9. Well Name and Number: / 81.80 KB V-114A 8. Property Designation: 10. Field/Pool(s): ADL-028240 Prudhoe Bay Field / Borealis Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): I Total Depth TVD (ft): I Effective Depth MD (ft): I Effective Depth TVD (ft): Plugs (md): Junk (md): 11444 6729.7 11345 6654.1 None None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 80 20" 91.5# H-40 29 - 109 29.0 - 109.0 1490 470 Liner 3411 4-1/2" 12.6# L·80 8021 - 11432 6584.4 - 6730.6 8430 7500 Production 8195 7" 26# L-80 26 - 8221 26.0 - 6661.6 7240 5410 Surface 2918 9-5/8" 40# L-80 28 - 2946 28.0 - 2686.7 5750 3090 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9630 - 9655 6720.35 - 6723.7 4.5 " 12.6 # L-80 24 - 8025 9655 - 9680 6723.66 - 6727.2 9800 - 9825 6742.99 - 6745.6 9825 - 9875 6745.63 - 6748.6 9875 - 9920 6748.55 - 6750.4 11100 - 11335 6739.7 - 6736.1 Packers and SSSV Type: Packers and SSSV MD (ft): 4-1/2" Baker S-3 Perm Packer 7969 4-1/2" Baker ZXP Packer 8029 12. Attachments: Description Summary of Proposal D 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D ExploratoryD DevelopmentD ServiceŒl 14. Estimated Date for November 17, 2004 15. Well Status after proposed work: Commencina Operation: Oil 0 GasD Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG ŒI GINJO WINJO WDSPLO Commission Representative: Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bruce Smith Printed Name Wuce Smith Á:::rÁ Title Petroleum Engineer Signature ~ "l..J Phone 564-5093 11/3/04 Commission Use Onlv I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 'dDLJ- Yol Plug Integrity 0 BOP TestD Mechanciallntegrity Test 0 Location Clearance 0 D"e, P~B 12. ~b t,(!lJ«a" ckf'il-- y.t~.M "-Ii ""¿ jç, \}! cu ved. S"b,eq"rl;"''/?¡tOM ~~ (J ~ ¡µ-elf ~ ~ t.«, m}¡ . BY ORDER OF Date: //htídC¡ APproved(' t) > ~ . .. THE COMMISSION V '--v~ , f f , . RBDMS BFL NOV J 6 Q ~ I GIN A L RBDMS BFL NOV 1 6 2004 SUBMIT IN DUPLICATE Form 10-403 Revised 06/2004 ." ·~NOTES: I .-'iRËE~" 4-1/16" CrN . V-114A WELLHEAD = FMC ACTUA TOR = NIA KB. B...EV = 81.8' BF. B...EV = 55.9' KOP= 300' Max Angle = 94 @ 11396' I I 2212' 4-1/2" HES X NIP, ID = 3.813" I Datum MD = 8151' I Datum lVD = 6600' SS I 9-5/8" CSG, 40#, L-80, ID = 8.835" I 2946' ~ GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LA TCH PORT DATE 6 2852 2684 30 KBG-2 DMY BK 0 03/13/04 5 3654 3311 32 KBG-2 DMY BK 0 11/30/03 l 4 4732 4208 33 KBG-2 DMY BK 0 03/13/04 3 5807 5041 32 KBG-2 DMY BK 0 03/13/04 2 6509 5702 36 KBG-2 DMY BK 0 03/13/04 1 7150 6196 51 KBG-2 DMY BK 0 03/13/04 I I 7948' 1-14-1/2" HES X NIP, ID = 3.813" I Minimum IC = 3.813" @ 2212' ~ 7969' -i 7" X 4-1/2" BAKER S-3 PKR, ID = 3.875" I HES X NIPPLE ¡.ö I I 7992' -14-1/2" HES X NIP, ID = 3.813" I I I I I 8013' -14-1/2" HES X NIP, ID = 3.813" I - I 8021' -i 5" X 7" BAKER HMC LNR HGR I l_ 8025' 8025' -i4-1/2" WLEG, ID = 4.000" I -1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I I 8041' -15" X 4-1/2" XO, ID = 3.950" I I I 7" WINDOW 8221' - 8233' I I TOP OF 7" BAKER WHIPSTOCK H 8221' I ~I ~ 9288' HPUPJTW/ RA TAG I 9793' HPUPJTW/ RA TAG I I 9-5/8" HES EZSV H 8239' ~ ~ 10340' HPUPJTW/ RA TAG I I I 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" I 8533' I J ~ ÆRFORA TION SUMMARY :)¡ REF LOG: ANGLE AT TOP PERF: @ 9630' I PBTD I 11345' Note: Refer to Production DB for historical perf data '9' SIZE SPF INTERVAL Opn/Sqz DATE I 4-1/2" SOLID LNR, 12.6 #, L-80, ID = 3.958" I 11432' 2-1/2" 6 9630 - 9680 0 10/17/04 I 2-1/2" 6 9800 - 9920 0 10/17/04 2-1/2" 4 11100 - 11335 0 11/20/03 DATE REV BY COMMENTS DATE REV BY COMMENTS BOREA LIS UNIT 11/22/03 JDMITLP INITIAL COM PLETION WB...L: V-114A 11/30/03 JLJITLP GL V C/O ÆRMIT No: 2031850 03/24/04 JLJ/TLH GL V C/O API No: 50-029-23178-01 10/17/04 DBMlTLP 4-1/2" TBG, ADD ÆRFS SEC 11, T11 N, R11 E, 4049' NSL & 1789' WEL , i . BP Exploration (Alaska) , \ e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Repair Well 0 PluQ PerforationsD Stimulate 0 OtherO Abandon 0 Alter Casing D Pull TubingD Perforate New Pool D WaiverD Time ExtensionD Change Approved Program D Operation ShutdownD Perforate IKI Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D ExploratoryD 203-1850 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceŒl 50-029-23178-01-00 7. KB Elevation (ft): 9. Well Name and Number: 81.80 V-114A 8. Property Designation: 10. Field/Pool(s): ADL-028240 Prudhoe Bay Field 1 Borealis Oil Pool 11. Present Well Condition Summary: Total Depth measured 11444 feet true vertical 6729.7 feet Plugs (measured) None Effective Depth measured 11345 feet Junk (measured) None true vertical 6735.9 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 29 - 109 29.0 - 109.0 1490 470 Liner 3411 4-1/2" 12.6# L-80 8021 - 11432 6584.4 - 6730.6 8430 7500 Production 8195 7" 26# L-80 26 - 8221 26.0 - 6661.6 7240 5410 Surface 2918 9-5/8" 40# L-80 28 - 2946 28.0 - 2686.7 5750 3090 Perforation deDth: Measured depth: 9630 - 9655,9655 - 9680, 9800 - 9825,9825 - 9875, 9875 - 9920, 11100 - 11335 True vertical depth: 6720.35 - 6723.66,6723.66 - 6727.16,6742.99 - 6745.63,6745.63 - 6748.55, 6748.55 - 6750.41,6739.7 - 6736.13 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 24 - 8025 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 7969 4-1/2" Baker ZXP Packer @ 8029 ,- 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaoe Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 -1216 300 2480 Subsequent to operation: 0 0 -3058 280 1600 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒI Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations_ ! ailD GasD WAGD GINJD WINJŒ! WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact Garry Catron NIA Printed Name Garry Catron Title Production Technical Assistant Signature _91 ,,_ , C,·& Phone 564-4657 Date 11/9/04 j( U RBDMS BFL NOV 1 2 7004 Form 10-404 Revised 4/2004 e e V-114A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/14/04 MIRU CTU #5. MU/RIH WI PDS TEMPIGRICCL WI 2.875" DRIFT. LOG TEMP SURVEY FROM SURFACE TO 11127' MD. SIT DOWN @ 11127' MD. LOG JEWELRY UP FROM TD TO 7000' MD. POOH. CORRELATE MEMORY LOG TO USIT LOG DATED 2/1/04. MUIRIH WI GUN #1, PERFORATE 9900' TO 9920' WI 2.5" 2506 PJ GUNS. MUIRIH WI GUN #2, PERF 9875'-9.900. CONTINUED. 10/15/04 CONTINUED FROM 10/14/04 WSR. POOHILAYDOWN GUN #2. MUIRIH WI GUN #3, 2.5" 6SPF, SHOOT 9850'-9875'. POOH. MUIRIH WI PDS GR/CCL. RIH TO PBTD @ 11330' CTMD (11339' CORRECTED). DID NOT SEE OBSTRUCTION NOTED IN PREVIOUS LOGGING RUN. LOGGED COIL FLAG FROM 10450' TO 9700'. POOH. MU/RIH WI GUN #4: 25 FT OF 2.5" 6 SPF 2506PJ, SHOOT 9825'-9850'. POOH. MU/RIH WI GUN #5: 25' OF 2.5" 6 SPF. CONTINUED ON 10/16/04 WSR 10/16/04 CONTINUED FROM 10/15/04 WSR. RIH WI GUN #5: 25' OF 2.5" 6 SPF: SHOOT 9800'- 9825'. POOH. PERFORM WEEKLY BOP TEST. MUIRIH WI PDS GR/CCL. LOG FROM 9900' TO 9200' AND FLAG COIL. POOH. MUIRIH WI GUN #6: 25' OF 2.5" 6 SPF 2506 PJ'S: SHOOT 9655'-9680'. POOH. PT MHA. CONTINUED ON 10/17/04 WSR. 10/17/04 CONTINUED FROM 10/16/04 WSR. MUIRIH WI GUN #7, 2.5" X 25' 6SPF: SHOOTING 9630'-9655'. POOH. FP WELLBORE TO 2500' WITH WATER/METH. UNABLE TO PUT WELL ON INJECTION AS FLOWLINE IS BLINDED. NOTICED PINK FLUID DRIPPING OUT OF CONDUCTOR - LOOKS LIKE DYE WATER FROM RIG SURFACE CASING CEMENT JOB. NOTIFIED WIE AND PAD OPERATOR. RDMO. ***JOB COMPLETE*** FLUIDS PUMPED BBLS 494 Methonal/W ater 40 XS 1% KCL 534 TOTAL Page 1 TREE = Wa.LH D = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 4-1/16" CrN FMC NIA 81.8' 55.9' 300' 94 @ 11396' 8151' 6600' SS e V-114A ~NOTES: 2212' 4-1/2" HES X NIP, ID = 3.813" I 9-5/8" CSG, 40#, L-80, ID = 8.835" I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LA TCH PORT DATE 6 2852 2684 30 KBG-2 DMY BK 0 03/13/04 5 3654 3311 32 KBG-2 DMY BK 0 11/30/03 4 4732 4208 33 KBG-2 DMY BK 0 03/13/04 3 5807 5041 32 KBG-2 DMY BK 0 03/13/04 2 6509 5702 36 KBG-2 DMY BK 0 03/13/04 1 7150 6196 51 KBG-2 DMY BK 0 03/13/04 7948' -14-1/2" HES X NIP, ID = 3.813" 7969' -f7" X 4-1/2" BAKER S-3 PKR, ID = 3.875" 7992' -f4-1/2" HES X NIP, ID = 3.813" I 8013' -f4-1/2" HES X NIP, ID = 3.813" I 8021' -l5" X 7" BAKER HMC LNR HGR 8025' -14-1/2" WLEG, ID = 4.000" I 9-5/8" HES EZSV 8041' -l5" X 4-1/2" XO, ID = 3.950" I I 7" WINDOW 8221' - 8233' Minimum IC = 3.813" @ 2212' HES X NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 8025' TOP OF 7" BAKER WHIPSTOCK 8221' 9288' -f PUP JT W/ RA TAG I 9793' -lPUPJTW/ RA TAG I 10340' -lPUPJTW/ RA TAG I I 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" I 8533' PERFORA TION SUMMARY REF LOG: ANGLE AT TOP ÆRF: @ 9630' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2-1/2" 6 9630 - 9680 0 10/17104 2-1/2" 6 9800 - 9920 0 10/17/04 2-1/2" 411100-11335 0 11/20/03 1 PBTD I 11345' 4-1/2" SOLID LNR, 12.6 #, L-80, ID = 3.958" I 11432' DATE 11/22/03 11/30/03 03/24/04 10/17/04 REV BY COMMENTS JDMITLP INITIAL COMPLETION JLJITLP GL V C/O JLJITLH GL V C/O DBtvVTLP 4-1/2" TBG, ADD PERFS DATE REV BY COMMENTS BOREALIS UNIT WELL: V-114A PERMIT No: 2031850 APt No: 50-029-23178-01 SEe 11, T11 N, R11 E, 4049' NSL & 1789' WEL BP Exploration (Alaska) " .... . STATE OF ALASKA . ALASKTolL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: PluQ PerforationsD Stimulate 0 OtherOO Abandon 0 Repair Well 0 Convert to Injector Alter Casing D Pull TubingD Perforate New Pool D WaiverD Time ExtensionD Change Approved Program D Operation ShutdownD Perforate D Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D ExploratoryD 203-1850 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceŒ 50-029-23178-01-00 7. KB Elevation (It): 9. Well Name and Number: 81.80 V-114A 8. Property Designation: 10. Field/Pool(s): ADL-028240 Prudhoe Bay Field I Borealis Oil Pool 11. Present Well Condition Summary: Total Depth measured 11444 feet true vertical 6729.7 feet Plugs (measured) None Effective Depth measured 11345 feet Junk (measured) None true vertical 6735.9 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 29 - 109 29.0 - 109.0 1490 470 Liner 3411 4-1/2" 12.6# L-80 8021 - 11432 6584.4 - 6730.6 8430 7500 Production 8195 7" 26# L-80 26 - 8221 26.0 - 6661.6 7240 5410 Surface 2918 9-5/8" 40# L-80 28 - 2946 28.0 - 2686.7 5750 3090 Perforation depth: Measured depth: 11100 -11335 RECEIVED True vertical depth: 6739.7 - 6736.13 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 24 - 8025 SEP 2 1 2004 Packers & sssv (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 7969 Alaska Oil & Gas Cens. Commission 4-1/2" Baker ZXP Packer @ 8029 Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 25 0.04 251 0 227 Subsequent to operation: 0 0 817 0 2363 14. Attachments: 15. Well Class alter proposed work: ExploratoryD DevelopmentD ServiceŒ Copies of Logs and Surveys run _ 16. Well Status alter proposed work: Daily Report of Well Operations. ! OilD GasD WAGD GINJD WINJ ŒI WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact Garry Catron 304-080 Printed Name Garry Catron Title Production Technical Assistant Signature ØI1n. ~ Phone 564-4657 Date 9/20104 (\ .- Form 10-404 Revised 4/2004 OR\G\NAL :.~uws :l SEP ~. J. . . V-114A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/15/04 First day of injection BBLS FLUIDS PUMPED o :TOTAL No Fluids Pumped Page 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: ~~ S~:;~isor K~1 ~lldD4 DATE: Wednesday, August 04, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-114A PRUDHOE BAY UN BORE V-114A ¿)P3~}'ð'Š FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: (·1 P.I. Suprv ~ ß II 04- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN BORE V-1I4 API Well Number: 50-029-23178-01-00 Inspector Name: Lou Grimaldi ^ Insp Num: mitLG040715092853 Permit Number: 203-185-0 Inspection Date: 7/15/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V-1l4A Type Inj. P TVD 6730 IA 240 2340 2290 2280 P.T. 2031850 TypeTest SPT Test psi 1640.75 OA 460 530 530 530 Interval INITAL P/F p Tubing 1760 1760 1760 1760 Notes: Post MI swap Wednesday, August 04, 2004 Page 1 of 1 _ STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD, GR, AZM, DENS, NEU, RES, PWD, AIM, USIT, Sonic (.;ASING, LINER AND CEMENTING RECORD SETTING. DEPTH MP ··.~ETTING DEW T\(þ HOCE lOP jOTTOM Top I BorrollA S,ZË Surface 108' Surface 108' 30" 28' 2946' 28' 2687' 12-1/4" 26' 8221' 26' 6662' 8-3/4" 8021' 11432' 6584' 6745' 6-1/8" o GINJ 181 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4649' NSL, 1789' WEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 1685' NSL, 1400' WEL, SEC. 11, T11N, R11E, UM Total Depth: 2607' NSL, 1660' EWL, SEC. 12, T11N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590515 y- 5969896 Zone- ASP4 TPI: x- 590942 y- 5966938 Zone- ASP4 Total Depth: x- 593989 y- 5967897 Zone- ASP4 18. Directional Survey 181 Yes 0 No 22. CASING SIZE WT/PER FT. 91.5# 40# 26# 12.6# GRADE H-40 L-80 L-80 L-80 20" 9-5/8" 7" 4-1/2" 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 2-1/2" Gun Diameter, 4 spf MD TVD MD TVD 11100' - 11335' 6740' - 6736' 26. Date First Production: March 28, 2004 Date of Test Hours Tested PRODUCTION FOR TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ~ Press. 24-HoUR RATE""" One Other 5. Date Comp., Susp., or Aband. 11/22/2003 6. Date Spudded 10/31/2003 7. Date T.D. Reached 11/14/2003 8. KB Elevation (ft): KBE = 81.80' 9. Plug Back Depth (MD+ TVD) 11345 + 6736 10. Total Depth (MD+TVD) 11444 + 6730 11. Depth where SSSV set (Nipple) 2212' MD 19. Water depth, if offshore NIA MSL 24. SIZE 4-1/2", 12.6#, L-80 Revised: 03/30/04, Put on Injection 1b. Well Class: o Development 0 Exploratory o Stratigraphic Test 181 Service 12. Permit to Drill Number 203-185 13. API Number 50- 029-23178-01-00 14. Well Name and Number: PBU V-114A 15. Field I Pool(s): Prudhoe Bay Field I Borealis Pool Ft Ft 16. Property Designation: ADL 028240 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) ~ ~ AMOUNT PUllED -- 260 sx Arctic Set (Approx.) 525 sx AS Lite, 336 sx Class 'G' 402 sx Class 'G', 150 sx Class 'G' 402 sx Class 'G', 374 sx Class 'G' TUBING ReCORD DEPTH SET (MD) 8025' PACKER SET (MD) 7969' 25. ACID, rlV\v I UI"iC, veMENT ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8239' Set EZSV with Whipstock on Top 3850' Freeze Protect with 130 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection Oll-BBl GAs-McF WATER-BBl Oll-BBl GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 O R I G t t\llJ. I I ( \ t, , CONTINUED ON REVERSE SIDE ~afl APR "'v ~v - 28. GEOLOGIC MARKERS - 29. .... FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 3189' Ugnu M Sands 4540' Schrader Bluff N Sands 4868' Schrader Bluff 0 Sands 5055' Base Schrader Bluff I top Colville 5479' HRZ 7589' Kalubik 7938' Kupark D 8212' Kuparuk C 8281' Kuparuk C (Inverted) 8710' Kuparuk C 9250' Kuparuk C (Inverted) 11384' 2898' None 4035' 4308' 4465' 4825' 6405' 6550' 6658' 6682' 6691' 6704' 6734' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore99ing is true and correct to the best of my knowledge. Signed Terrie Hubble /01f\Ï t7 J-lIlf1See Title Technical Assistant Date 03-3' -D<j PBU V-114A 203-185 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Neil Magee, 564-5119 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ORfGI ì~ ( e e WELL: FIELD: API: PERMIT: V -114A PRUDHOE BAY UNIT 50-029-23178-01-00 203-185 ACCEPT: SPUD: RELEASE: RIG: 10/21/03 10/31/03 11/22/03 NABORS 9ES POST RIG WORK 11/22/03 RIH WI 41/2" OK-6 WI 1 1/4" JDC. PULLED SHEAR VALVE IN STA #5. 11/25/03 VALVE CREW REMOVED BPV. PULL BALL & ROD @ 7988' SLM. PULL RHC PLUG BODY @ 7993' SLM. DRIFT WI 3.5" CENT TO 8348' SLM. STOPPED DUE TO DEVIATION.(HAW) 11/29/03 SET SS C-SUB @ 7246' SLM. PULL DGLV FROM STA #2 @ 6491' SLM. PULL DGLV FROM STA #3 @ 5789' SLM. PULL DGLV FROM STA #4 @ 4715' SLM. 11/30/03 PULL DGLV FROM STA #6 @ 2832' SLM. SET LGLV/BK(16/64" TRO 1550#) IN STA #6. SET LGLV/BK(16/64" TRO 1557#) IN STA #4. SET LGLV/BK(16/64" TRO 1549#) IN STA #3. SET LGLV/BK(16/64" TRO 1535#) IN STA #2. SET 24/64" OGLV/BK IN STA #1 @ 7135' SLM. PULL C- SUB. RDMO. 01/24/04 TIIIO = 140/14010, TEMP = SI. TUBING FL FOR E-LlNE. AIL SPOOL PIECE HAS IN-LINE CHECK VALVE. OTHER IA CASING VALVE HAS BUTTONHEAD FITTING. STUNG INTO FITTING FOR PRESSURE READ. THERE IS A FLANGE WITH JEWELRY FOR THE IA CASING VALVE IN THE WELLHOUSE. TUBING FL @ 40'. 02/01/04 CORRELATED TO SLB CBL LOG RAN 11/17/03. RIH WI WELL TEC TRACTOR/USIT (3.625" X 56.5') HAD TROUBLE GETTING PAST THE GLM AT 2852'. BEGAN TRACTORING AT 7455'. LOGGED FROM 11208' TO 7880'. USIT MOTOR STOPPED A FEW TIMES DUE TO DOGLEG SEVERITY. ESTIMATED TOC = 9625'. DID NOT RUN GAMMA RAY I CCL DUE TO OVERALL TOOL LENGTH. USED ACOUSTICAL COLLARS TO CORRELATE WITH. DID NOT TAG TD. LEFT WELL SI. 02/03/04 T/I/O= 501250/200, POP WELL USING 10 BBLS NEAT MEOH FOLLOWED BY 100BBLS OF HOT 180 DEG. DSL. FOLLOWED BY 10 BBLS OF NEAT MEOH. T/I/O= 575/1500/500 FINALS. (PRE- PRODUCED INJECTOR.) 02/22/04 RIH WI STATIC GAUGE. RAN INTO HYDRATES @ 167' SLM. 02/23/04 RIH WI 2.95" G.RING. SAT DOWN @ 167' SLM. WORKED G. RING TO 332' SLM. RIH WI 21/8" X 10' DRIVE BAILER. SAT DOWN @ 332' SLM. BAILER HAD HYDRATES. RDMO. 02/27/04 T/I/O=1300/1250/200. TBG HYDRATE THAW. PUMPED 5 BBL NEAT SPEAR & 344 BBLS SW @ 200 DEG F. DOWN IA TO THAW HYDRATES IN TBG FOLLOWED BY 44 BBLS DSL @ 180 DEG F. FOR IA FREEZE PROTECT. RU TO TBG. PUMPED 2 BBLS OF NEAT UP FLOWLINE, 10 BBLSL OF NEAT & 28 BBLS OF DIESEL DOWN TBG. RDMO T/I/O=2160/1550/160 V-114A, Post Drilling Work Page 2 e e 03/12/04 DRIFT W/ 3.50" CENT,SAMPLE BAILER TO 8283' SLM,MfT BAILER (74 DEGREES DEVIATION) RUN PDS SBHPS & JEWELRY LOG FROM 8270' SLM TO SURFACE. SET 4-1/2" XC-SUB @ 7931' SLM. 03/13/04 PULL OGLV/BK FROM STA #1 @ 7135' SLM. PULL LGLV/BK FROM STA #2 @ 6494' SLM. PULL LGLV/BK FROM STA #3 @ 5791' SLM. PULL LGLV/BK FROM STA #4 @ 4715' SLM. PULL LGLV/BK FROM STA #6 @ 2833' SLM. SET DGLV/BK IN STA #6. SET DGLV/BK IN STA # 4 SET DGLV/BK IN STA # 3. SET DGLV/BK IN STA # 2 SET DGLV/BK @ STA # 1. MITIA TO 3500 PSI. 3RD TEST PASSED. LOST 70 PSI 1ST 15 MIN. 0 PSI 2ND 15 MIN. PULL XC-SUB. RDMO. T/I/O 600/750/0. ASSIST SLlCKLlNE W/ LOAD & TEST. MIT IA TO 3500 PSI.-PASSED- ON 3RD ATTEMPT POST DV SET. PUMPED 130 BBLS OF INHIBITED 60/40 METH/WATER DOWN IA. SLlCKLlNE SET DV. PRESSURE UP IA W/ 1.1 BBLS INHIBITED 60/40 METH/WATER.,START TEST, (1600/3500/150), 1ST 15 MINS LOST 70 PSI, (1300/3430/150), 2ND 15 MINS LOST 110 PSI FOR A TOTAL OF 180 PSI IN 30 MINS, (1050/3320/150), FAIL, REPRESSURED lA, START 2ND TEST, (1050/3500/150), 1ST 15 MINS LOST 100 PSI, (1000/3400/150), 2ND 15 MINS LOST 150 PSI FOR A TOTAL OF 250 PSI IN 30 MINS, (1000/3250/150), FAIL REPRESSURE lA, START 3RD TEST, (1000/3500/150), 1 ST 15 MINS LOST 70 PSI, (950/3430/150),2ND 15 MINS LOST 0 PSI FOR A TOTAL OF 70 PSI IN 30 MINS, (950/3430/150), PASS BLEED IA RDMOL, FINAL WHP'S 950/800/150 UPON DEPARTURE. SLlCKLlNE STILL ON WELL. 03/23/04 THE HYDRAULIC LINE FOR V-114 SSV FROM WELL V-109 HAS BEEN DISCONNECTED. THESE TWO WELLS ARE NO LONGER TWINNED. 03/24/04 THE CHECK VALVE IS ROLLED AND THE CHOKE FLIPPED OVER IN THE PROPER DIRECTION. 03/28/04 HEADER TIED IN. WELL IS NOW ON PRODUCED WATER INJECTION. lREE= WELL t-EA 0 = AC1UA TOR = KB. ELBI = BF. ELBI - KOP= rv1ax Angle = Datum rvÐ = Datum 1V0- 4-1/16" CIW FMC N/A 81.8' 55.9' 300' 94 @ 11396' 8151' 6600' SS V-114A 9-5/8" CSG, 40#, L-80, 10 = 8.835" Minimum ID = 3.813" @ 2212' HES X NIPPLE TOP OF 7' BAKER WHPSTOO< 8221' 9-5/8" HE'S EZSV I 7" CSG, 26#, L-80, .0383 bpf, 10 = 6.276" I 8533' ÆRFORA 1l0N SlJI'v1MARY RIT LOG: ANGLE AT TOP PERF: 92 @ 11100' Note: Refer to Production DB for historical perf data SIZE SFT NTERVAL Opn/Sqz DATE 2-1/2" 4 11100 - 11335 0 11/20/03 DATE 11r..!2103 11130103 03124104 RBI BY COrvTlt1ENTS JDM/TLP INITIAL COMPLETION JLJIlLP GLV 00 JLJIlLH GLV 00 2212' 4-1/2" HE'S X NIP, 10 - 3.813" ~ GAS LIFT MANOR8...S ST MO 1V0 DEV TYPE VLV LA TCH PORT DATE 6 2852 2684 30 KBG-2 Drv1Y BK 0 03/13/04 5 3654 3311 32 KBG-2 Drv1Y BK 0 11/30/03 4 4732 4208 33 KBG-2 Drv1Y BK 0 03/13/04 3 5807 5041 32 KBG-2 Drv1Y BK 0 03/13/04 2 6509 5702 36 KBG-2 Drv1Y BK 0 03/13/04 1 7150 6196 51 KBG-2 Drv1Y BK 0 03/13/04 7948' 4-1/2" rES X NIP, 10 = 3.813" 7969' -17" X 4-1/2" BAKER S-3 A<R, 10 - 3.875" 7992' -14-1/2" HES X NIP, 10 = 3.813" I 8013' -14-1/2" HES X NIP, 10 = 3.813" I 8021' -5" X 7" BAKER HIVC LNR HGR 8025' -4-1/2" WLB3, 10 = 4.000" I 8041' -5" X4-1/2"XO, 10= 3.950" I 7"WINDOW 8221' -8233' 9288' -RJPJTW/RA TAG I 9793' RJPJTW/RA TAG 10340' RJPJT W/ RA TAG I PBTD I 11345' 4-1/2" SOLD LNR, 12.6 #, L-80, D -3.958" I DAlE REV BY COMI'vENTS 11432' FRLOHOE SA Y UNIT WELL: V-114A PERMIT No: 2031850 A R No: 50-029-23178-01 SEe 11, T11 N, R11 E, 4049' NSL & 1789' WEL BP Exploration (Alaska) It WELL LOG TRANSMITTAL e 803 - )g5 ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7"'Street Suite # 700 Anchorage. Alaska 99501 RE: Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TyPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Open Hole 1 1 1 Res. Eva!. CH 1 1 1 V-114A 3-12-04 Mech. CH },~J-J8g Caliper Survey Signed: -<--"'k:\.~ ( ;~~0 '-~ ("¡ ~ /~/'v" ....... -.. '- Date: RECEIVED Print Name: t;1~p ?:) °004 ~ ,I ,., \ "- ..... L.. !\i.1:\ßka Oi! &: Gas Cons. Commision Þ.!icltorage PRoACTivE DiAGNOSTic SERviCES, INC., PO Box 1 "569 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memOlylog.com Website: www,memorylog.com ",-...,~., '.. - ("'" . ...::> "'V'" "'" \'.1(\(.::-,,_ '{'-",...:")\..'.)\' "","--,':) µJ GA tJl7/l.-LJoL/- e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 /' 6. API Number / StratigraphicD Service ŒI 50-029-23178-01-00 9. Well Name and Number: V-114A 10. Field/Pool(s): Prudhoe Ba Field I Borealis Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 6729.7 11345 6654.1 S~ MD nD . -- 1. Type of Request: 0 0 Abandon Suspend Alter Casinç D Repair Well D Change Approved Program D Pull Tubing D 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 81.80 KB 8. Property Designation: ADL-028240 3. Address: 11. Total Depth MD (ft): 11444 Casing Length Conductor Liner 80 3411 8195 2918 20" 91.5# H-40 4-1/2" 12.6# L-80 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 6740 6736.1 Production Surface Perforation Depth MD (ft): 11100 - 11335 Packers and SSSV Type: 4-112" Baker S-3 Perm Packer 4-112" Baker ZXP Packer 12. Attachments: Description Summary of Proposal Œ] Detailed Operations Program 0 ~'ISketch 0 I Operation Shutdown Pluç Perforations Perforate New Pool D D D PerforateD waiverD Annular DisposalD StimulateD Time ExtensionD OtherŒ] Re-enter Suspended WellD Conversion to Injector 5. Permit to Drill Number: 203-1850 /'" 4. Current Well Class: Development D Exploratory D Plugs (md): Junk (md): None Collapse None Burst to bottom to bottom 29 109 29.0 109.0 1490 470 8021 11432 6584.4 6730.6 8430 7500 26 8221 26.0 6661.6 7240 5410 28 2946 28.0 2686.7 5750 3090 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # L-80 24 8025 Packers and SSSV MD (ft): 7969 8029 13. Well Class after proposed work: Exploratory 0 / Development 0 ServiceŒ] 14. Estimated Date for Commencin 0 eration: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: Printed Name Signature ~. ruce. Smith I . '1.<...."'-V !J....~..>\ . 15. Well Status after proposed work: Oil D GasD WAG D GINJO PluggedD AbandonedD WINJŒ / WDSPLO Prepared by Garry Catron 564-4657. Contact Bruce Smith Title Phone Petroleum En ineer 564-5093 3404 ommlsslon Use Onl Plug Integrity D Conditions of approval: Notify Commission so that a representative may witness Location Clearance D Approved Other: Subsequen Form 1 0-403 Revised 12/2003 Mechanciallntegrity Test cgI o q t G t ~\J Þ\ L. BY ORDER OF THE COMMISSION Date: { ( ~BFl APRq 1r1M SUBMIT IN DUPLICATE bp ... ,\'f.'II. -....~ ~...- ~..- ~....- ~~ ~,.. ·j'·'I\~ ". e e To: Doug Cismoski/John Smart GPB Well Ops Team Leaders Date: February 10, 2004 From: Bruce W. Smith GPB Borealis Development Engineer Subject: V-114ai Conversion (Kuparuk C Sands) AFE: BRD5M4127 Est. Cost: $~ lOR: 1500 New Well Priority: New Well Priority 1.0 This well is a pre-produced injector. Please perform conversion from pre-produced to water injector. The well is tied-in and ready for conversion. It is suggested that this work could be completed at the same time as the V-lOO patch repair. Please Bruce W. Smith (W:564-5093, - H:345-2948, Cell 440-8008) with any questions. 1. S Dummy off GL V, MIT i,/ Last test: New completion, never tested. Max Deviation: 92.92° @ 8515' MD Perf deviation: 89.8° @ 10100' MD Min. ID: 3.813"X nipple @ 2212' MD Last TD tag: None initial entry Last Downhole Ops: None initial entry Latest H2S value:Nottested (new well). Offset well V-101 '10' ppm on 11/01/03. Wellbore Fluids: Freeze protected tubing & IA to 3500' with diesel. BHT & BHP: V-lOli 158°F & 3015 psia @ 6600' TVDSS Reference Log: Schlumberger Vision 11-14-03 Note: Simops on going Construction, drilling. cc: w/a: Well File Steve Deckert Bruce W. Smith NS Wells Tech Aide Gil Buehler ec: G Anc Wellwork 1REE= WELL I-EA D = ACTUATOR = 1<8. ELEV = BF. ELEV = KOP= I\i1ax Angle = Datum MJ = Datum lVD = 4-1/16" CrN FMC N/A 81.8' 55.9' 300' 94 @ 11396' 8151' 6600' SS V-114A 9-5/8" CSG, 40#, L-80, ID = 8.835" Minimum ID = 3,813" @ 2212' HES X NIPPLE TOP OF T' BAKER WHPSTOO< 8221' 9-5/8" HES EZSV 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 8533' ÆRFORA nON SU\IIMI\ RY REF LOO: ANGLE AT TOP PERF: 92@ 11100' Note: Refer to Production œ for historical perf data SIZE SA" NTERVAL Opn/Sqz DATE 2-1/2" 4 11100-11335 0 11/20/03 . SAFETY NOTES: 2212' 4-1/2" HES X NIP, ID - 3.813" GAS LIFT Ml\NDR8..S ST MD lVD DEV TYPE VLV LATCH PORT DATE 6 2852 2684 30 KBG-2 DOrvE BK 16 11/30/03 5 3654 3311 32 KBG-2 D\4Y BK 11/30/03 4 4732 4208 33 KBG-2 DOrvE BK 16 11/30/03 3 5807 5041 32 KBG-2 DOrvE BK 16 11/30/03 2 6509 5702 36 KBG-2 DOrvE BK 16 11/21/03 1 7150 6196 51 KBG-2 S/O BK 24 11/30/03 7948' 4-1/2" I-ES X NIP, ID = 3.813" 7969' 7992' 4-1/2" I-ES X NIP, ID - 3.813" 8013' 4-1/2" I-ESX NIP, ID =3.813" 8021' 8025' 4-1/2" WLEG, ID = 4.000" 8041' 5" X 4-1/2" XO, ID= 3.950" 7"WINDOW 8221' - 8233' 9288' RJPJTW/RA TAG 9793' RJPJTW/RA TAG 10340' RJP JT WI RA TA G 11345' 4-1/2" SOLD LNR, 12.6 #, L-80, D = 3.958" 11432' D<\ TE REV BY COIIIMENTS 11/22103 J[]\//TLP INITIAL COMPLETION 11130103 JLJ/1LP GLV C/O D<\ 1£ REV BY COMrvENTS FRLDHOE BA Y UNIT WELL: V-114A PERMIT No: 2031850 AA No: 50-029-23178-01 SEe 11, T11 N, R11 E 4049' NSL & 1789' WEL BPExploration (Alaska) ,'1 , . STATE OF ALASKA a RE" C'" E'···VED ALASKA AND GAS CONSERVATION COM~ION . I WELL COMPLETION OR RECOMPLETION REPORT AND LOG DEC 2 92003 .... n '" I"'A_A 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended o WAG ""uo 'w' . '""'''''''~. 20AAC 25.105 20AAC 25.110 o Devel<An61uUall! Exploratory OGINJ !HI WINJ o WDSPL No. of Completions One Other o Stratigraphic !HI Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 11/22/2003./ 203-185 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10/31/2003 50- 029-23178-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Number Surface: 11/14/2003 PBU V-114A 4649' NSL, 1789' WEL, SEC. 11, T11 N, R11 E, UM 8. Elevation in feet (indicate KB, DF, etc.) 15. Field and Pool Top of Productive Horizon: 1685' NSL, 1400' WEL, SEC. 11, T11N, R11E, UM KBE = 81.80' Prudhoe Bay Field I Borealis Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2607' NSL, 1660' EWL, SEC. 12, T11N, R11E, UM 11345 + 6736 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Lease Designation and Serial No. Surface: x- 590515 y- 5969896 Zone- ASP4 11444 + 6730 Ft ADL 028240 TPI: x- 590942 y- 5966938 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 593989 y- 5967897 Zone- ASP4 (Nipple) 2212' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey aYes ONo N/A MSL 1900' (Approx.) 21. Logs Run: MWD, GR, AZM, DENS, NEU, RES, PWD, AIM, US IT, Sonic 22. CASING, LINER AND CEMENTING RECORD iÇ$~~(l , Ii vCIIIN' DEÞ1'H. ·.·...·..~~'..i. i .·.··.·.··'i i., i. i Wl"·Pi;R.f";r.....'.,·. . GAAQ: rop 6C>TJ'OM i' '.'. ~·ii:n 'i. ,.,.~...~.,.. 20" 91.5# H-40 Surface 108' 30" 1260 sx Arctic Set lApprox.) 9-5/8" 40# L-80 28' 2946' 12-1/4" 525 sx AS Lite, 336 sx Class 'G' 7" 26# L-80 26' 8221' 8-314" 402 sx Class 'G', 150 sx Class 'G' 4-1/2" 12.6# L-80 8021' 11432' 6-1/8" 1402 sx Class 'G', 374 sx Class 'G' 23. Perforations open to Production (MD + TVD of To,e and 214. 'i . ,····,i·.··T '.A'...... ......,. Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4spf 4-1/2", 12.6#, L-80 8025' 7969' MD TVD MD TVD 11100' - 11335' 6740' - 6736' 125. , (,0'\819. "'-. 'FTC,' '-""""""''''''~;'''''''''''''~ ..·.i .i..,." 'i . , DEPTH INTERVAL (MD) 'i·'I'· I AMOUNT & KIND OF MATERIAL USED t ",..¡.~ <: 8239' Set EZSV with Whipstock on Top ¡ l\L;~~~ ¡;J . 3850' Freeze Protect with 130 Bbls of Diesel b:§;;.J 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet NIA Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BSL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... OIL-BSL GAs-McF WATER-BSL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~ f?~1 3 L 1m ' Ø"Jt. Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE ~¡; -<. 28. GEOLOGIC MARKERS 29. . RMATlON TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 3189' Ugnu M Sands 4540' Schrader Bluff N Sands 4868' Schrader Bluff 0 Sands 5055' Base Schrader Bluff I top Colville 5479' HRZ 7589' Kalubik 7938' Kupark D 8212' Kuparuk C 8281' Kuparuk C (Inverted) 8710' Kuparuk C 9250' Kuparuk C (Inverted) 11384' 2898' None 4035' 4308' 4465' 4825' 6405' 6550' 6658' 6682' 6691' 6704' 6734' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ ' Title Technical Assistant Date jZ/Z9!z PBU V-114A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Neil Magee, 564-5119 203-185 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Name: V-114 Common Name: V-114 Test Date 10/25/2003 11/5/2003 i Test Type Test Depth (TMD) 2,946_0 (ft) 8,225.0 (ft) -------.- LOT FIT BP Leak-Off Test Summary Test Depth (TVD) 2,687.0 (ft) 6,663.0 (ft) AMW Surface Pressure ---...... ..-.-.-...---.---- 9.70 (ppg) 9.30 (ppg) 650 (psi) 1,310 (psi) I .---..-.--¡ : Le!'lkgffuPr~ss_~..!:~.(BHP) ¡ 2,004 (psi) 4,529 (psi) " Page 1 of 1 ... ..-.-......-....-.-..- ...----.---.----- EMW 14.36 (ppg) 13.08 (ppg) Printed: 11/24/2003 8:32:35 AM .... Page 1 of 28 BP Operations Summary Report Legal Well Name: V-114 Common Well Name: V-114 Event Name: DRILL +COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES I . Date I From - To : Hours Task 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 Start: Rig Release: Rig Number: I Code' NPT ¡ Phase I ____...d....__. -------- -- -- -... 10/20/2003 19:00 - 20:30 1.50 MOB P PRE 20:30 - 00:00 3.50 MOB P PRE 1 0/21/2003 00:00 - 02:00 2.00 MOB P PRE 02:00 - 07:00 5.00 MOB P PRE 07:00 - 12:00 5.00 RIGU P PRE 12:00 - 00:00 12.00 RIGU P PRE 1 0/22/2003 00:00 - 01 :30 1.50 RIGU P PRE 01 :30 - 02:00 0.50 RIGU P PRE 02:00 - 03:00 1.00 RIGU P PRE 03:00 - 03:30 0.50 RIGU P PRE 03:30 - 04:00 0.50 RIGU P PRE 04:00 - 06:00 2.00 DRILL P SURF 06:00 - 06:30 SURF 0.50 DRILL P 06:30 - 16:30 SURF 10.00 DRILL P 16:30 - 17:00 0.50 DRILL P SURF 17:00 - 19:00 SURF 2.00 DRILL P Description of Operations PJSM. RID & prepare to move Camp, Shop & Pit module. Move camp, shop & pit module from W-209i to V-pad location. Continue rigging down. Lay down 9ES derrick & prepare sub-base for rig move. Continue rigging down 9ES & prepare for rig move. Held PJSM with Rig Crew, Peak, Tool Services & all personnel involved in the rig move. Move rig off W-209i well slot & off W-Pad location onto Spine road. Rig in transit, arrived on V-Pad @ 07:00 hrs with no problems. Move rig's sub base over V-114 conductor, lay herculite around same. Held PJSM. Raise derrick. Spot and level rig. Spot pit module & cuttings tank. Hook-up power,water, steam and mud lines. Accept Rig at 12:00 hrs on October 21, 2003. Continue rigging up 9ES for drilling operations. Mix spud mud, N/U Bell-nipple on pre-install 21-1/4" Diverter. Load Pipe Shed with 4" DP & BHA tools. P/U & rack back 25 stands of 4" DP in derrick + 7 stands of 4" HWDP + drilling jars & one stand of 7" NMDC. Slip & cut 88' of drill line. Re-set & test C-O-M. Held Pre-Spud meeting with Nabors rig crew & all service company personnel. M/U 12-1/4" Drilling assembly. Adjust mud-motor to 1.50 deg bend. Orient MWD/Mud-motor. Function test 21-1/4" Diverter system (20 seconds to close element) ** Lou Grimaldi with the AOGCC waived witnessing the 21-1/4" Diverter test **. Fill up hole with water. Check for leaks on Diverter & Flow line-OK. Clean out 20" conductor to 108'. SPUD WELL @ 04:00 HRS. Drill 12-1/4" hole from 108' to 353' (Start sliding @ 321'). WOB = 5-20k. RPM = 75 + Mud-motor (Motor factor = 0.2216 rpm/gal) GPM = 610 w/1000 psi w/170 psi DIFF Torque off Btm = 950 FtLb. Torque on Btm = 2500-4000 FtLb P/U 53K. S/O 53K. ROT 53K. CBU from 353'. POOH two stands & P/U drill jars. Trip back to bottom with no problems. Drill 12-1/4" directional hole from 353' to 1559'. Slide as required to build angle & maintain azimuth. WOB = 30-35K RPM = 80 + Mud-motor (Motor factor = 0.2216 rpm/gal) Torque off Btm = 2000 FtLb Torque on Btm = 6000 FtLb GPM = 670 @ 2580 psi w/ 200-250 psi Diff. P/U 82K S/O 71K ROT 74K Pump Lo-Vis sweep & circulate hole clean (2.5 Btm-up) from 1559' @ 670 gpm w/ 2580 psi. Reciprocate & rotate drill string while circulating. POOH for bit change. Had a few mild intermittent tight spots with 1 0-20k overpull. Worked drill string back down through each tight spot & pulled back up through same with no problems. Hole in good shape. Printed: 11/24/2003 8:32:44 AM .. ~ ..., BP Operations Summary Report V-114 V-114 DRILL +COMPLETE Start: 10/20/2003 NABORS ALASKA DRILLING I Rig Release: 11/22/2003 NABORS 9ES Rig Number: 9ES _ i From - To ~~~rs· .~ask I CO~I_~PTt~~ase ____. ..... .D~s~r.i~tion of Operations 19:00 - 19:30 0.50 DRILL P SURF Break off bit. M/U new Hughes MXC1. 19:30 - 20:00 0.50 DRILL P SURF Clean rig floor of excess mud generated from trip out. 20:00 - 21 :00 1.00 DRILL P SURF TlH with 12-1/4" Steerable Drilling assembly to 1466' with no problems. M/U TDS. Establish circulation. Precautionary wash to bottom @ 1559'. Drill 12-1/4" directional hole from 1559'-1869'. Slide as required to build angle & maintain azimuth. WOB = 30-35K RPM = 80 + Mud-motor (Motor factor = 0.2216 rpm/gal) Torque off Btm = 2100 FtLb Torque on Btm = 6400 FtLb GPM = 670 @ 2610 psi w/ 275 psi Diff. P/U 85K S/O 75K ROT 77K AST/24 Hrs = 6.86 hrs ART/24 Hrs = 2.87 hrs Drilling Time last 24 Hrs= 9.73 hrs Drill 12-1/4" directional hole from 1869'-2959' (9-5/8" csg point). Slide as required to build angle & maintain azimuth. WOB = 30-45K. RPM = 80 + Mud-motor (Motor factor = 0.2216 rpm/gal) Torque off Btm = 3200 FtLb. Torque on Btm = 7000-9000 FtLb. GPM = 670 @ 3340 psi w/ 200-275 psi Diff. P/U 98k S/O 75k ROT 88k Note: Encounter hydrates while drilling from 2270'-2680'. Drilled through same with no problems. AST Hrs = 1 hrs ART Hrs = 2 hrs Circulate & condition mud prior to making wiper trip. CBU x 3 at 650 gpm & 100 RPM. Monitor well. POOH with no problems (10-15k intermittent drag) to 1890', hole pulling tight. Unable to work past this depth. TIH to 1930'. M/U TDS & backream up to 1550'- previous bit run. 650 gpm, 2500 psi. POOH without pumping from 1550' to 1280'. Hole started swabbing - unable to work past tight spot @ 1280'. M/U TDS & establish circulation. Backream from 1280' to 950'. Pump & pull up to 500'. Stand back HWDP, Jars & drill collars. Clean off balled up stabilizer. TIH. Tag up on obstruction @ 940'. M/U TDS into 4" DP. Establish circulation. Stage up mud pumps to 225 gpm & apply 45 RPM to drill string. Work bit past obstruction. Continue TIH. Encountered excessive drag @ 1890'. Work drill string down to 2015' tagging up solid on obstruction. M/U TDS. Establish circulation. Ream down breaking through obstruction @ 2056'. TIH to 2567', tag up. M/U TDS. Establish circulation. Ream down to 2587'. Circulate & work drill string from 2587'-2496' for 15 minutes to clean up hole. Finish TIH to 2868' with no problems. M/U TDS. Establish circulation. Wash to bottom @ 2959'. Circulate & condition mud/hole with 650 gpm @ 3060 psi. Reciprocate & rotate drill string (90-100 RPM) while circulating. Had a lot of cuttings & dehydrated looking mud come across shakers on bottoms up. After getting bottoms-up, pumped a 40 bbl Super-Sweep & circulated hole clean. Very little increase in Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date --..-....-. 10/22/2003 21 :00 - 00:00 3.00 DRILL P SURF 1 0/23/2003 00:00 - 05:00 5.00 DRILL P SURF 05:00 - 06:30 1.50 DRILL P SURF 06:30 - 11 :00 4.50 DRILL P SURF 11 :00 - 13:00 2.00 DRILL P SURF 13:00 - 14:00 1.00 DRILL P SURF 14:00 - 19:00 5.00 DRILL P SURF 19:00 - 20:30 1.50 DRILL P SURF Page 2 of 28 Spud Date: 10/22/2003 End: 11/22/2003 --.---- Printed: 11/24/2003 8:32:44 AM , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ~ ~ Page 3 of 28 BP Operations Summary Report V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES ! Phase ! Date From - To ¡ Hours Task Code NPT _n ..._____._ _ ._ .... on _...__ 10/23/2003 19:00 - 20:30 20:30 - 21 :30 21 :30 - 22:00 22:00 - 00:00 10/24/2003 00:00 - 01 :00 01 :00 - 02:30 02:30 - 04:00 04:00 - 11 :00 11:00-13:00 13:00 -13:15 13:15 -13:35 13:35 - 14:40 14:40 - 14:50 14:50 - 15:30 15:30 - 17:30 17:30 - 19:30 19:30 - 20:30 20:30 - 22:30 22:30 - 23:00 - . 1.50 DRILL P SURF 1.00 DRILL P SURF 0.50 DRILL P 2.00 DRILL P SURF SURF 1.00 DRILL P 1.50 DRILL P SURF SURF 1.50 CASE P SURF 7.00 CASE P SURF 2.00 CEMT P SURF 0.25 CEMT P SURF 0.33 CEMT P SURF 1.08 CEMT P SURF 0.17 CEMT P SURF 0.67 CEMT P SURF 2.00 CEMT P SURF 2.00 DIVRTR P 1.00 WHSUR P INT1 INT1 2.00 BOPSUF P 0.50 BOPSUF P INT1 INT1 Start: Rig Release: Rig Number: Spud Date: 10/22/2003 End: 11/22/2003 10/20/2003 11/22/2003 9ES Description of Operations ..--..-- ...--.-.-...---- -.------- cuttings noticed when the Super-Sweep came across shale shakers. P/U 98k S/O 81 k Rot Wt 88k POOH to run 9-5/8" surface casing. Pulled 6 stands with no problems to 2190'. Hole started swabbing & pulling tight. M/U TDS & establish circulation. Backream up to 2100' with 650 gpm @ 2575 psi + 90-100 RPM. Had excessive torque F/ 2150-2115'. At 2115' torque decreased to normal rate. TIH 4 stands to 2493' too check hole conditions-OK. Backream from 2493' to 1733'. Attempt to pull pipe with no pumps. Hole swabbing. Pump & pull up to 1276'. POOH with no pumps from 1276' to the top of BHA @ 905'-midnight depth. POOH with BHA from 905'. UD 12-1/4" BHA. Clear Rig Floor of excess drilling tools & equipment. P/U 9-5/8" casing landing joint with casing hanger assembly. Make dummy run. UD same. Change elevator bails. R/U 9-5/8" casing running equipment. M/U Franks Fill-up tool to TDS. M/U 9-5/8" shoe track. Check floats - OK. Run 70 jts of 9 5/8" 40# L-80 BTC casing filling every joint. Circ 2 jts down from 2345' to 2425' to move mud in annulus & started taking weight. Work & circ 4 jts casing down to 2580' - acting as if something caught alongside pipe, not below. Able to run casing to bottom from 2580' without circulating. MU hanger & landing jt & land casing - OK. Shoe at 2946' MD. Circ and condition mud - reduce FV to -70 sec for cement job. Circ at 10-12 bpm with no losses. PJSM for cement job with crew and all service company personnel. Switch to cementers. Pump 5 bbl water. Test lines to 3500 psi. Pump 5 bbl water followed by 75 bbl Mudpush II spacer at 10.1 ppg. 5 bpm @ 200 psi. Release bottom plug. Mix & pump 400 bbls (525 sx) ArcticSet Lite lead slurry at 10.7 ppg. 7 bpm @ 200 psi. Switch to tail surry - mix & pump 70 bbls (325 sx) Class G tail at 15.8 ppg. 6 bpm @ 400 psi. Kick out top plug with 10 bbl water from DS. Switch to rig pump and displace cement with 208 bbl mud at 10 bpm with final displacement pressure of 800 psi. Slow to 3 bpm for last 10 bbls of displacement. Bump plug with 1800 psi. Able to reciprocate casing throughout cement job until half way through displacement. Got back 125 bbls of good lead cement. CIP at 1520 hrs. Bleed off pressure. Floats holding. Flush flow line & Diverter. RID cement head. UD 9-5/8" casing Landing Joint. RID casing running equipment. Clean out rotary table drip pan & shale shakers. N/D bell-nipple & 21-1/4" Diverter system. Install FMC Gen-5 11" Unihead system on 9-5/8" casing hanger mandrel & test to 1000 psi. Test was API. N/U 11" 5m x 13-5/8" 5m DSA + 13-5/8" 5m BOP's & all surface related equipment. M/U BOP test plug on 4" drill pipe & RIH. RlU BOP test equipment. Printed: 11/24/2003 8:32:44 AM " Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Page 4 of 28 BP Operations Summary Report Start: Rig Release: Rig Number: NPT I Phase V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Task: Code From - To ¡Hours 1.00 BOPSU P 10/24/2003 23:00 - 00:00 10/25/2003 00:00 - 02:00 2.00 BOPSU P 02:00 - 02:30 0.50 WHSUR P INT1 02:30 - 08:00 5.50 DRILL P INT1 08:00 - 10:00 2.00 DRILL P INT1 10:00 - 11 :00 1.00 DRILL P INT1 11 :00 - 12:30 1.50 DRILL N DFAL INT1 12:30 - 14:00 1.50 DRILL N DFAL INT1 14:00 - 14:30 0.50 DRILL N DFAL INT1 14:30 - 15:00 0.50 DRILL P INT1 15:00 - 16:30 1.50 DRILL P INT1 16:30 - 17:30 1.00 CASE P INT1 17:30 -18:00 0.50 DRILL P INT1 18:00 -19:15 1.25 DRILL P INT1 19:15 - 19:30 0.25 DRILL P INT1 19:30 - 20:00 0.50 DRILL P INT1 20:00 - 20:30 0.50 DRILL P INT1 20:30 - 21 :00 0.50 DRILL P INT1 21 :00 - 00:00 3.00 DRILL P INT1 INT1 INT1 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 Description of Operations -..--.-..-------..- Start testing BOPE to 250 psi low/4000 psi high. Plan to test all rams, lines, valves and choke manifold. Test annular to 250 psi low/3500 psi high. Witness of BOP test waived by Lou Grimaldi with AOGCC. Finish testing BOPE to 250 psi low/4000 psi high. Test all rams, lines, valves C/K manifold, TDS valves. Test annular to 250 psi low/3500 psi high. All test were API. Witness of BOP test waived by Lou Grimaldi with AOGCC. Pull test plug. Run & install wear bushing in wellhead. UD 4" drill pipe test joint. P/U a total of 117 joints of 4" drill pipe & rack in derrick. Clean off rig floor. M/U a new 8-3/4" DS70 bit + PDM w/1.5 deg bend + XO + NM Stab + LWD/MWD/ADN. Held PJSM regarding loading RA source in LWD. Load source & finish M/U 8-3/4" BHA. Attempt to test MWD. Unable to pump at the required rate due to a restriction somewhere in the drill string. POOH to LWD. PJSM on unloading RA source. Remove source. LID LWD/MWD & Mud-motor. M/U 8-3/4" BHA. P/U fresh Mud-motor + MWD/LWD tools. PJSM on source loading. Load source. M/U BHA & first stand of 4" HWDP. M/U TDS. Establish circulation. Test MWD & Mud-motor. Everything working OK. Finish M/U BHA. TIH with 8-3/4" Steerable drilling assembly to 2620' (P/U 54 Jts of 4" DP). M/U TDS. Break circulation. Close BOP & test 9-5/8" casing to 3500 psi for 30 minutes. Test was API. Manually bled-off pressure to zero. Open BOP. TIH from 2620' to 2864'. Tag-up on float collar. M/U TDS. Establish circulation. Drill float collar @ 2864'. Drill out 9-5/8" shoe track (firm cement) & drill float shoe @ 2947'. Clean out 12-1/4" rathole to 2959'. Drill 8-3/4" Directional Hole from 2959' to 2979'. WOB = 10-15k RPM = 50 + Mud-motor ( Mud-motor factor = 0.500 rpm/gal ) Torque on btm = 3900-4300 FtLb GPM = 500 w/1875 psi. ART = 0.25 Hrs Pump a 40 bbl HV spacer & displace hole with 9.7 ppg LSND mud. Reciprocate & rotate (80 rpm) drill string while circulating (504 gpm @ 1300 psi). Perform Leak-off test: Pressure up on formation & obtained a leak-off pressure of 650 psi with 9.7 ppg mud. 9-5/8" casing shoe TVD = 2687'. EMW = 14.35 ppg. Place bit outside of 9-5/8" casing shoe @ 2947'. Stage pumps to maximum circulating rate of 590 gpm to establish a baseline ECD of 10.46 ppg Drill 8-3/4" directional hole from 2979 to 3366'. Slide as required to maintain angle & azimuth. Printed: 11/24/2003 8:32:44 AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ~ ~ Page 5 of 28 BP Operations Summary Report V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES ¡ , I Date ¡ From - To Hours i Task ¡Code NPT Phase ! . . ---.- --. ---- - ..- .-- .---.... ...- -. - ---. 1 0/25/2003 21 :00 - 00:00 3.00 DRILL P INT1 10/26/2003 00:00 - 00:00 10/27/2003 00:00 - 03:00 03:00 - 06:00 24.00 DRILL P 3.00 DRILL P 3.00 DRILL P INT1 INT1 INT1 Start: Rig Release: Rig Number: I Spud Date: 10/22/2003 End: 11/22/2003 10/20/2003 11/22/2003 9ES Description of Operations .--.-..----.-...-..--..--- ... WOB = 10-20k RPM = 80 + Mud-motor (Motor factor = 0.500 rpm/gal) Torque off Btm = 2600 FtLb Torque on Btm = 4000 FtLb GPM = 590 @ 2100 psi w/200-300 psi Diff. P/U 101 k S/O 80k ROT 95k AST/24 Hrs = 0.25 hrs ART/24 Hrs = 1.50 hrs Drilling Time last 24 Hrs= 2.0 hrs Drill 8-314" directional hole from 3366' to 6882'. Slide as required to maintain inclination & azimuth. WOB = 15-25k RPM = 80 + Mud-motor (Motor factor = 0.500 rpm/gal) Torque off Btm = 4300 FtLb Torque on Btm = 7200 FtLb GPM = 590 @ 3320 psi w/ 300-340 psi Diff. P/U 153k S/O 120k ROT 136k Backream every stand at 590 gpm and 100 rpm, reducing flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Calculated ECD @ 6882' = 10.47 --- Actual ECD = 10.68 From 6387' sliding between 40' and 70' per stand. Start building angle to a planned 58 degrees and turning to the left decreasing azimuth from 213 degrees to a planned azimuth of 170 degrees needed by 7430' as per well plan. Note: At around 6820' the ADN tool malfunctioning (intermittently stopping & starting). AST last 24 hrs. = 5.75 hrs. ART last 24 hrs. = 9.6 hrs. Conn/Survey hrs. = 9.65 hrs Drilling Time last 25 Hrs= 15.35 hrs Drill 8-3/4" directional hole from 6882' to 7206' MD/6288' TVD. Slide as required to maintain inclination & azimuth. WOB = 15-25k RPM = 80 + Mud-motor (Motor factor = 0.500 rpm/gal) Torque off Btm = 4300 FtLb Torque on Btm = 7200 FtLb GPM = 590 @ 3320 psi w/ 300-340 psi Diff. P/U 154k S/O 124k ROT 138k ART = 0.75 Hrs AST = 1.55 Hrs. Backream every stand at 590 gpm and 100 rpm, reducing flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Calculated ECD @ 7206' = 10.47 ---Actual ECD = 10.70 ADN tool (s/n 286) not working at all. NOTE: Crossed fault @ 6944' MD/6120' TVD. Top of HRZ estimated to be @ +/- 6340' KBTVD Continue sliding from 6882' @ 40'-70' per stand. Building angle to a planned 58 degrees and decreasing azimuth from 213 degrees to a planned azimuth of 170 degrees needed by 7430' as per well plan. Rack back one stand (No room to work drill string). Circulate & Printed: 11/24/2003 8:32:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ..., Page 6 of 28 BP Operations Summary Report V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: ; Task t Code NPT! Phase I ì _._.___.... .n ... _ From - To ; Hours 3.00 DRILL P Date 10/27/2003 03:00 - 06:00 06:00 - 09:00 09:00 - 09:30 09:30 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 13:30 13:30 -15:00 15:00 - 16:00 16:00 - 17:30 17:30 - 17:45 17:45 - 20:00 20:00 - 21 :00 21 :00 - 00:00 10/28/2003 00:00 - 08:00 --- . 3.00 DRILL N 0.50 DRILL N 1.00 DRILL N 1.50 DRILL N 1.00 DRILL N 0.50 DRILL N 1.50 DRILL N 1.00 DRILL N 1.50 DRILL P 0.25 DRILL N 2.25 DRILL N 1.00 DRILL N 3.00 DRILL P 8.00 DRILL P ----.--- DFAL INT1 DFAL INT1 DFAL INT1 DFAL INT1 DFAL INT1 DFAL INT1 DFAL INT1 DFAL INT1 INT1 DFAL INT1 DFAL INT1 DFAL INT1 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 Description of Operations - -.--.... .- .------ ......---- INT1 condition (590 gpm @ 3490 psi) mud/hole prior to POOH (Trip for ADN tool). Increase mud weight while C & C mud with 11 ppg Spike fluid from a 9.7 ppg to 10.2 ppg before POOH. Riciprocate & rotate (80 rpm) drill string while circulating from 7195'-7101'. POOH (Trip for ADN tool) from 7195' to 3250' with no problems. Max drag was 10k. At 3250' hole swabbing. Work drill string down to 3366' & attempt to pull. Hole swabbing. M/U TDS. Establish circulation. Backream from 3366' to 9-5/8" csg shoe @ 2946' with 500 gpm @ 1800 psi & 80 rpm. Circulate bottoms-up x 2.5 with 590 gpm @ 2180 psi & 80 rpm. Flow check well-OK. Pump slug. Calculated ECD @ 2946' = 10.9 --- Actual ECD = 11.02 Note: Observed Hydrates breaking out of the mud while POOH. INT1 POOH from 2946' with drill string to top of BHA. Held PJSM. Continue POOH with BHA to LWD tool. Remove RA source. Finish POOH. LID ADN + MWD/LWD tools & bit. Clean & clear rig floor of excess drilling equipment & mud residue generated from trip. M/U BHA #4. P/U fresh MWD/LWD/ADN tools. Load RA source, TIH w/ DC's, HWDP & Ghost Reamer. Shallow Test Anadrill Tools. Everything working OK. TIH with 8-3/4" Steerable Drilling Assembly on 4" drill pipe to 2946'. Slip & cut 59' of drill line. Reset & test C-O-M. Service TDS. Circulate @ 570 gpm + 80 rpm & obtained benchmark ECD reading of 11.05 ppg. Continue TIH to 7101' with no problems. Hole in good shape. M/U TDS. Establish circulation. Precautionary wash/ream to bottom @ 7206' with no problems. Circulate bottoms-up to clean hole before drilling ahead. Calculated ECD @ 7206' = 11.17 --- Actual ECD = 11.47 Drill 8-3/4" directional hole from 7206' to 7476. Slide as required to maintain inclination & azimuth. WOB = 15-25k RPM = 80 + Mud-motor (Motor factor = 0.500 rpm/gal) Torque off Btm = 6000 FtLb Torque on Btm = 8500 FtLb GPM = 580 @ 3530 psi w/ 300-320 psi Diff. P/U 162k S/O 117k ROT 139k ART = 0.84 Hrs AST = 0.68 Hrs. Conn/Survey hrs. = 2.18 hrs Drilling Time last 24 Hrs= 3.82 hrs Backream every stand at 590 gpm and 100 rpm, reducing flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Calculated ECD @ 7206' = 10.99 --- Actual ECD = 11.10 INT1 NOTE: Top of HRZ @ 7319' MD/6355' KBTVD Drill 8-3/4" directional hole from 7476' to 8340'. Slide as required to maintain inclination & azimuth. WOB = 15-25k Printed: 11/24/2003 8:32:44 AM ~ ,., BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES I i From - To : Hours: Task! Code NPT ..._ ..n. _ ..-. -......----- ------.--. --... 10/28/2003 00:00 - 08:00 8.00 DRILL P INT1 08:00 - 09:00 1.00 DRILL P INT1 09:00 - 09: 15 09:15 - 13:30 0.25 DRILL P 4.25 DRILL P INT1 INT1 13:30 - 14:00 0.50 DRILL P INT1 14:00 - 15:30 1.50 DRILL P INT1 15:30 - 16:00 0.50 DRILL P INT1 16:00 - 17:00 1.00 DRILL C INT1 17:00 - 18:00 1.00 REMCM C INT1 18:00 - 19:30 1.50 REMCM C INT1 19:30 - 20:00 0.50 REMCM C INT1 20:00 - 21 :00 1.00 REMCM C INT1 21 :00 - 22:30 1.50 REMCM C INT1 22:30 - 00:00 1.50 REMCM C INT1 1 0/29/2003 00:00 - 01 :30 1.50 REMCM C INT1 01 :30 - 03:30 2.00 REMCM C INT1 03:30 - 03:45 0.25 REMCM C INT1 03:45 - 04:30 0.75 REMCM C INT1 04:30 - 05:00 0.50 REMCM C INT1 Page 7 of 28 Start: Rig Release: Rig Number: Spud Date: 10/22/2003 End: 11/22/2003 10/20/2003 11/22/2003 9ES Phase Description of Operations -.---.--..- . -----..------.---. RPM = 80 + Mud-motor (Motor factor = 0.500 rpm/gal) Torque off Btm = 8-8.2k FtLb, Torque on Btm = 1 0-11k FtLb GPM = 550 @ 3830 psi w/ 300-320 psi Diff. P/U 171k S/O 121k ROT 140k Backream every stand at 580 gpm and 100 rpm, reducing flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Calculated ECD @ 8340' = 10.89 --- Actual ECD = 11.28 ART = 6.00 Hrs AST = 0.36 Hrs. Drilling Time last 24 Hrs= 6.36 hrs NOTE: Base of HRZ @ 7782'MD /6598' KBTVD Top of K-1 @ 7863'MD /6641' KBTVD NOTE: Kuparuk is wet and well is to be plugged back and sidetracked to a new BHL. Pump Hi-vis sweep surface to surface. 100 rpm, 580 gpm @ 3850 psi. Continue circulating an additional bottoms up. 171 klbs up, 121 klbs down, 140 klbs rotate. Calculated ECD = 10.89 ppg, Actual ECD = 10.91 ppg Monitor well - static POH wet 15 stands to 7008'.5-15 klbs drags through this interval. Pump dry job and continue POH, intermittent areas of 5-10 klb drag. 180 klbs up, 125 klbs off bottom. Monitored well at the csg shoe and again before pulling the BHA through the BOP - static with some hydrates breaking out. PJSM with Schlumberger and all rig personnel on laying down the BHA and unloading RA sources. Stand back jar and collar stand. PJSM. Unload RA source. LD BHA. Clean and clear rig floor. Rig service - top drive, drawworks and disc brake. RU 3-1/2" tbg equipment to make up stinger assembly. MU muleshoe/plug catcher assembly. RIH with 24 jts of 3-1/2" 9.3# NSCT tbg. RD tbg equipment. Continue RIH with 3-1/2" tbg stinger on 4" DP to csg shoe at 2946'. Circulate and condition mud at the csg shoe. 70 klbs up, 63 klbs down. Continue RIH with 3-1/2" tbg stinger on 4" DP. Cont RIH with cementing stinger on DP. Wash to bottom at 8340'. Circ & cond mud - 550 gpm @ 3150 psi. PJSM prior to pumping first cement abandonment plug. Pump 13.5 bbl water ahead. Test lines to 3500 psi. Pump 44 bbls (215 sx) Class 'G' slurry at 15.8 ppg. Pump 1.5 bbl water behind plug to balance and displace with 75 bbl mud at 7 bpm dropping to 2 bpm for last 20 bbls. Calc plug 8340'-7890'. RD cement line & head pin. Pull up out of cement plug to Printed: 11/24/2003 8:32:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ,., BP Operations Summary Report V-114 V-114 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To ' Hours I Task ¡Code ..- _.h._ , - "".------.- .-. 04:30 - 05:00 0.50 REMCM C 05:00 - 06:30 1.50 REMCM C 06:30 - 07:30 1.00 REMCM C 07:30 - 08:15 0.75 REMCM C 08:15 - 09:00 0.75 REMCM C Date -- . ..-- . 10/29/2003 Start: Rig Release: Rig Number: NPT I Phase! ..---.- INT1 INT1 INT1 INT1 INT1 09:00 - 09:30 0.50 REMCM C INT1 09:30 - 10:00 0.50 REMCM C INT1 10:00 - 13:00 3.00 REMCM C INT1 13:00 - 14:00 1.00 REMCM C INT1 14:00 - 16:00 2.00 REMCM C INT1 16:00 - 17:30 1.50 REMCM C INT1 17:30 - 18:00 0.50 REMCM C INT1 18:00-19:15 1.25 REMCM C INT1 19:15 -19:30 0.25 REMCM C INT1 19:30 - 21 :00 1.50 REMCM C INT1 21 :00 - 22:00 1.00 REMCM C INT1 22:00 - 22:30 0.50 REMCM C INT1 22:30 - 23:00 0.50 REMCM C INT1 23:00 - 00:00 1.00 REMCM C INT1 10/30/2003 00:00 - 04:00 4.00 REMCM C INT1 04:00 - 04:30 0.50 REMCM C INT1 04:30 - 05:15 0.75 REMCM C INT1 05: 15 - 06:30 1.25 REMCM C INT1 06:30 - 06:45 0.25 REMCM C INT1 06:45 - 07:15 0.50 REMCM C INT1 07:15 - 08:30 1.25 REMCM C INT1 Page 8 of 28 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 Description of Operations ---. --.-..--..----.. ..-- - -. ..----- 7700'. Calc Top of cement plug at 7890'. Circ at 590 gpm @ 2800 psi. Circ out cement contaminated mud. Monitor well. POH to 5700' for laying Form-a-Plug. Circ & thin mud prior to pumping FAP. MW in/out 10.2 ppg. Switch to cementers. Pump 20 bb110.2 ppg viscosified mud spacer followed by 20 bbl Form-a-Plug at 10.7 ppg. Follow with 2 bbl spacer to balance and displace with 49 bbl mud to put plug in place from 5700'-5500'. Kelly up. Pull up out of plug 3 stands at 60 fpm while pumping 3/4 bpm to push FAP out of DP. POH 2 more stands (5 total). Circ 1 DP vol at 500 gpm to clear cement from pipe. Pump wiper dart to plug catcher at 300 gpm to wipe DP & stinger. POH with DP and cement stinger. RU 3-1/2" tbg equipment. Stand back tbg stinger in derrick. Recover wiper dart from cementing sub. MU muleshoe and plug catcher. RIH with 3-1/2" tbg stands and 36 jts of tbg from pipe shed. RD tbg equipment. Continue RIH with tbg stinger on DP to 5200' Wash down to 5500', 450 gpm @ 1300 psi CBU at 5500',450 gpm @ 1350 psi. Good Form-A-Plug returns on bottoms up. Circulate and condition mud for cement plug #2. PJSM with DS, MI, Veco and all rig personnel on pumping plug #2. Pump 5 bbls water ahead, test lines to 3500 psi. Continue pumping 10.5 bbls water ahead. Pump 145 bbls (705 sx) 15.8 ppg Class G slurry. Pump 1.5 bbls water beheind to balance and dip lace with 32 bbls mud at 7 bpm dropping to 2 bpm for last 20 bbls. Calc plug 5500'-4000'. RD cement line & head pin. Pull up out of cement plug to 3700'. Calc Top of cement plug at 4000'. Circulate 3 x DP volume to clean residual cement from string. 500 gpm @ 1150 psi POH to csg shoe at 2946' WOC. Rig maint. - CO valves and seats on both pumps WOC. Rig Maint. - Cut and slip drilling line. Chg out valves and seats on both mud pumps. RIH to 3500' Continue RIH washing down at 350 gpm @ 620 psi. Tag cement at 3698'. Circulate and condition mud to prior to laying cement kick-off plug #3. PJSM with cementers, rig crew, truck drivers on laying cement plug. Switch lines over to cementers. Test lines to 3500 psi. Pump 11.5 bbl water followed by 88 bbl (495 sx) Class 'G' densified slurry at 17.0 ppg. Plug length calculated from 3698'-2750'. Pump 1.5 bbl water behind and displace with 20 bbl mud. POH above calc top of plug slow 12 stands to 2570'. Circ and clear cement from hole and pipe. Printed: 11/24/2003 8:32:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date BP Operations Summary Report Page 9 of 28 V-114 V-114 DRILL +COMPLETE Start: 10/20/2003 NABORS ALASKA DRILLING I Rig Release: 11/22/2003 NABORS 9ES Rig Number: 9ES From - To I Hours: Task: Code i NPT ! Phase I 1 0/30/2003 08:30 - 09:30 1.00 REMCM C INT1 09:30 - 10:00 0.50 REMCM C INT1 10:00 - 13:30 3.50 REMCM C INT1 13:30 - 14:00 0.50 REMCM C INT1 14:00 - 15:00 1.00 BOPSU INT1 15:00 - 17:30 2.50 BOPSU INT1 17:30 - 18:00 0.50 BOPSU INT1 18:00 - 19:00 1.00 STKOH INT1 19:00 - 20:00 1.00 STKOH INT1 20:00 - 00:00 4.00 STKOH INT1 10/31/2003 00:00-01:00 1.00 STKOH P INT1 01 :00 - 01 :30 0.50 STKOH P INT1 01 :30 - 02:30 1.00 STKOH P INT1 02:30 - 02:45 0.25 STKOH P INT1 02:45 - 03:30 0.75 STKOH P INT1 03:30 - 04:00 0.50 STKOH P INT1 04:00 - 05:30 1.50 STKOH P INT1 05:30 - 06:00 0.50 STKOH P INT1 06:00 - 06:30 0.50 STKOH P INT1 06:30 - 08:00 1.50 STKOH P INT1 08:00 - 08:30 0.50 STKOH P INT1 08:30 - 00:00 15.50 STKOH P INT1 Spud Date: 10/22/2003 End: 11/22/2003 Description of Operations Circulate 2 X DP volume at 500 gpm to clean cement from DP and stinger. Drop wiper dart and pump to catcher at 300 gpm. POH to cement stringer. RU 3-1/2" tbg equipment. LD 3-1/2" tbg stinger. Retrieve wiper dart. RD tbg equipment. Clean and clear rig floor. Flush stack with ported sub. RU BOPE test equipment. Test BOPE 250 psi low, 4000 psi high. Test Annular preventer to 250 psi low, 3500 psi high. Witness of BOP test waived by Chuck Scheve AOGCC. RD test equipment. Install wear bushing. Blow down all lines MU BHA #5, 8-3/4" cleanout assembly RIH to 2517' MU top drive and wash down from 2517'. Tag cement at 2583'. Drill cement from 2583' to 2796'. WOB = 15-20k RPM = 80 Torque off Btm = 2-4k FtLb, Torque on Btm = 3-4k FtLb GPM = 500 @ 1650 psi 90 klbs up, 75 klbs down, 83 klbs rotate Drill cement from 2796' to 2983'. ROP increased appeared to have sidetracked off of kick-off plug. WOB = 15-20k RPM = 80 Torque off Btm = 2.4k FtLb, Torque on Btm = 3.5-4k FtLb GPM = 500 @ 1660 psi 92 klbs up, 96 klbs down, 80 klbs rotate CBU, 600 gpm, 2175 psi, 100 rpm Pump 30 bbl viscosified spacer then displace to new 9.7 ppg LSND mud. 400 gpm @ 995 psi Monitor well - static POH to PU directional BHA. Monitor well prior to pulling DC's into BOP stack. Stand back HWDP and DC's. LD Jars. Break out bit. PU 8-3/4" directional BHA. PJSM with Anadrill and all rig personnel on loading RA source. Load RA source. Continue MU BHA #6. Shallow test MWD. RIH to 2902" MU top drive and wash down to 2983'. Establish basline ECD's Drill 8-3/4" directional hole from 2983' to 5919'. Slide as required to maintain inclination & azimuth. WOB = 10-20k RPM = 80 Torque off Btm =5-6k FtLb, Torque on Btm = 8.5k FtLb GPM = 590 @ 3545 psi w/ 280-300 psi Diff. P/U 150k S/O 103k ROT 122k Backream every stand at 590 gpm and 80 rpm, reducing flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Printed: 11/24/2003 8:32:44 AM BP Operations Summary Report legal Well Name: V-114 Common Well Name: V-114 Event Name: DRill +COMPlETE Contractor Name: NABORS ALASKA DRilLING I Rig Name: NABORS 9ES I I ! Date ..~rom - To ' Hours! Task ¡ Code NPT. Pha~e_l 10/31/2003 08:30-00:00 15.50 STKOH P INT1 11/1/2003 00:00 - 00:00 24.00 STKOH P 11/2/2003 00:00 - 10:30 10.50 STKOH P 10:30 - 12:30 2.00 STKOH P Page 10 of 28 Start: Rig Release: Rig Number: Spud Date: 10/22/2003 End: 11/22/2003 10/20/2003 11/22/2003 9ES Description of Operations Calculated ECD@ 5919' = 10.78, Actual ECD = 11.12 ART = 4.97 Hrs AST = 1.85 Hrs. Drilling Time last 24 Hrs= 6.82 hrs INT1 Base of Obf @ 5479' MD /4824' TVD Top of CM2 @ 5888' MD / 5173' TVD Drill 8-3/4" directional hole from 5919' to 7851'. Slide as required to maintain inclination & azimuth. WOB = 15-20k RPM = 80 Torque off Btm =5-6k FtLb, Torque on Btm = 7.2k FtLb GPM = 550 @ 4016 psi on Btm, 3748 psi off Btm P/U 164k S/O 117k ROT 136k Above the tangent section (-7500') backream every stand at 550 gpm and 80 rpm, through the tangent section increase RPM's to 100 while backreaming. Reduced flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Calculated ECD @ 7851' = 11.03, Actual ECD = 11.40 -200 above the top of the HRZ (7527' MD) increase mud weight to 10.3 ppg ART = 4.65 Hrs AST = 11.77 Hrs. Drilling Time last 24 Hrs= 16.42 hrs INT1 Fault #1 @ 6263' MD / 5496' TVD Top HRZ @ 7527' MD /6379' TVD Drill 8-3/4" directional hole from 7851' to 8544'. Slide as required to maintain inclination & azimuth. WOB = 10-20k RPM = 80 Torque off Stm =7k FtLb, Torque on Btm = 8.6k FtLb GPM = 535 @ 3790 psi on Btm, 3470 psi off Btm P/U 178k S/O 114k ROT 138k Sackream every stand at 535 gpm and 100 rpm, reducing flow rate to 450 gpm on down stroke. Circulate hi-vis sweep every 400' or as needed to aid in hole cleaning. Calculated ECD @ 7851' = 10.93, Actual ECD = 11.22 ART = 7.51 Hrs AST = 0.68 Hrs. Drilling Time last 24 Hrs= 8.19 hrs INT1 Top Kuparuk D @ 8212' MD /6658' TVD Top Kuparuk C4 @ 8249' MD / 6672' TVD Top Kuparuk BJCU @ 8413' MD /6737' TVD Circulate hole clean. Pump hi-vis sweep surface to surface. Circulate bottoms up X 3. Reciprocated DP at 110 RPM Printed: 11/24/2003 8:32:44 AM / -- ~ - Page 11 of 28 BP Operations Summary Report Legal Well Name: V-114 Common Well Name: V-114 Event Name: DRILL +COMPLETE Start: 10/20/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2003 Rig Name: NABORS 9ES Rig Number: 9ES , I· I I ' I Date ¡ From - To I Hours I Task i Code I NPT I Phase I Description of Operations .-. ..--.. .-.. ..-- ..--.. .--- ---- -.-.-- --- .- --...--'- .-....--... -- --... -... --.. -- .--. -.- .--.. -.--. --...- 10:30 - 12:30 2.00 STKOH P INT1 570 gpm @ 3780 psi P/U 160k S/O 116k ROT 135k 11/2/2003 12:30 - 12:45 12:45 - 15:30 0.25 STKOH P 2.75 STKOH P INT1 INT1 15:30 - 15:45 0.25 STKOH P INT1 15:45 - 18:00 2.25 STKOH P INT1 18:00 -19:30 1.50 STKOH P INT1 19:30 - 19:45 19:45 - 00:00 0.25 STKOH P 4.25 STKOH P INT1 INT1 11/3/2003 00:00 - 01 :30 1.50 STKOH P INT1 01 :30 - 03:15 1.75 STKOH P INT1 03:15 - 03:30 0.25 BOPSUF INT1 03:30 - 04:00 0.50 BOPSUF P INT1 04:00 - 05:30 1.50 BOPSUF P INT1 05:30 - 07:45 2.25 CASE P INT1 07:45 - 08:00 0.25 CASE P INT1 08:00 - 12:30 4_50 CASE P INT1 12:30 - 13:00 0.50 CASE P INT1 13:00 - 00:00 11.00 CASE P INT1 Spud Date: 10/22/2003 End: 11/22/2003 ---"" - Calculated ECD = 10.91 ppg Actual ECD prior to POH = 11.19 ppg Monitor well - static POH to csg shoe at 2946'.5-15 klb intermittent drag throughout short trip. P/U 185k S/O 120 Monitor well - static RIH to TD @ 8544'. Fill pipe at 5702'. Some hydrates breaking out of the mud at the bell nipple. Circulate hole clean. Reduced rate to 425 gpm and 110 rpm due to increased ECD's. After first bottoms up increased rate to 550 gpm and 110 rpm. Reciprocated DP at 110 RPM 550 gpm @ 3865 psi P/U 193k S/O 112k ROT 139k Calculated ECD = 11.06 ppg Actual ECD prior to POH = 11.20 ppg Spotted 50 bbllube pill on bottom prior to POH Monitor well - static POH to above HRZ. Pump dry job. Continue POH to HWDP Monitor well at csg shoe - NO FLOW, hydrates breaking out at bell nipple Stand back HWDP. LD Jars Monitor well at jars - No flow, hydrates breaking out at bell nipple. LD DC's. Unload RA source. LD BHA Clean and clear rig floor PJSM With all rig personnel on changing out BOP rams. Pull Wear bushing. Flush the stack. Install test plug Install 7" upper pipe rams. Test door seals to 250/3500 psi Change out bails and install fill-up tool. RU csg equipment. MU csg hanger and make dummy run. PJSM with Nabors Casing and all rig personnel, on running 7" csg. MU 7" 26# shoe track, fill csg and check float euipment. Run 7" csg to 9-5/8" csg shoe. Fill every jt. and break circ for 5 min. every 25 jts down to 9 5/8" shoe. Stage pumps up to 6 bpm @ 337 psi. Circulate 1.5 times annular volume at 9 5/8" casing shoe_ 105 klbs up, 90 klbs down_ Continue running 7" csg. Fill each jt, break circulation for 5 minutes every 5 jts, circulate for 15 minutes every 15 jts. and CBU every 30 jts. Decreased running speed from 1 minute per jt to 1.5 minutes per jt below 4500'. Correct displacement Printed: 11/24/2003 8:32:44 AM BP Operations Summary Report Legal Well Name: V-114 Common Well Name: V-114 Event Name: DRILL +COMPLETE Start: 10/20/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2003 Rig Name: NABORS 9ES Rig Number: 9ES Date J Fro~_~:o I Hour~ Task: Code· NPT ¡Phase t Description of Operations 11/3/2003 13:00 - 00:00 11.00 CASE P INT1 throughout csg job - no losses. 11/4/2003 00:00 - 01 :30 1.50 CASE P INT1 Continue running 7", 26# casing 01 :30 - 02:00 0.50 CASE P INT1 Land casing. RD fill-up tool. Blow down top drive. RU cement head Circulate and condition hole for cement job. Circulate 2 bottoms up at 7 bpm @ 802 psi while reciprocating DP. 250 klbs up, 128 klbs down. 02:00 - 03:15 1.25 CEMT P INT1 03:15 - 03:22 03:22 - 03:39 0.12 CEMT P 0.28 CEMT P INT1 INT1 03:39 - 04:22 0.72 CEMT P INT1 04:22 - 04:30 0.13 CEMT P INT1 04:30 - 05:30 1.00 CEMT P INT1 05:30 - 06:30 1.00 CEMT P INT1 06:30 - 08:00 1.50 CASE P INT1 08:00 - 09:00 1.00 WHSUR P INT1 09:00 - 10:30 1.50 BOPSU P PROD1 10:30 - 13:00 2.50 STWHIP P PROD1 13:00 -13:15 0.25 STWHIP P PROD1 13:15-15:30 2.25 STWHIP P PROD1 15:30 - 16:00 0.50 STWHIP P PROD1 16:00 - 16:30 0.50 STWHIP P PROD1 16:30 - 18:30 2.00 STWHIP P PROD1 18:30 - 23:15 4.75 STWHIP P PROD1 Page 12 of 28 Spud Date: 10/22/2003 End: 11/22/2003 Hold PJSM with Schlumberger and all rig personnel on cementing while circulating. Air up and batch up cement trucks Pump 5 bbls water and pressure test cement lines to 4000 psi. Continue pumping 40 bbls 11.3 ppg alpha spacer. Drop Bottom plug. Pump 129 bbls (405 sxs) 13.5 ppg Class 'G' lead cement. 5 bpm @ 480 psi. Switch to tail cement and pump 31 bbls (155 sxs) 15.8 ppg Class 'G' tail cement. 3 bpm @ 110 psi Shut down and flush cement lines with water to a 'T' on the rig floor. Drop top plug. Switch to rig pumps and displace with mud. Pumping schedule: 7 bpm @ 300 psi for 200 bbls 6 bpm @ 525 psi for 70 bbls 4 bpm @ 1250 psi for 30 bbls Reduced rate to 2 bpm to bump, FCP = 1110 psi. Bump plugs on calculated strokes and pressure up to 3500 psi for csg test. Casing reciprocated 8' while cementing, landed 307 bbls into displacement, with tail cement around the shoe. CIP @ 05:30 Pressure test casing to 3500 psi for 30 minutes. Bleed down pressure, floats holding. Blow down lines. RD casing equipment. Change out bails. Clean and clear rig floor. Install 7" packoff, RILDS and test to 5000 psi Install 3-1/2" X 6" variable pipe rams. Test door seals to 3500 psi. Install wear bushing. RU SWS. Run GRlCCL gauge ring/junk basket log and depth correlate PJSM with SWS, HES and all rig personnel on handling bridge plug setting tool. MU bridge plug. RIH and log on depth with CCLlGR. Set 7" EZSV bridge plug at 8236' E-Líne depth. POH with wireline. RD SWS. Knock ice from derrick MU whipstock BHA. RIH with HWDP. Shallow test MWD. RIH to 8126'. Fill DP at 4000' and 7000'. Inject 25 bbls of 10.3 ppg mud down the 7" X 9-5/8" annulus. ICP = 1800 psi, Injection pressure 1200 psi at 2 bpm, SIP = Printed: 11/24/2003 8:32:44 AM BP Operations Summary Report Legal Well Name: V-114 Common Well Name: V-114 Event Name: DRILL +COMPLETE Start: 10/20/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2003 Rig Name: NABORS 9ES Rig Number: 9ES Date I From - To I Hours' Task I Code I NPT ¡Phase I ._ ... _------i---__..__.. .__~.___------'-__...__.. 11/4/2003 18:30 - 23:15 23:15 - 23:30 23:30 - 00:00 4.75 STWHIP P 0.25 STWHIP P 0.50 STWHIP P PROD1 PROD1 PROD1 11/5/2003 00:00 - 04:45 4.75 STWHIP P PROD1 04:45 - 05:30 0.75 STWHIP P PROD1 05:30 - 07:00 1.50 STWHIP P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 09:30 1.50 STWHIP P PROD1 09:30 - 10:00 0.50 STWHIP P PROD1 10:00 - 12:30 2.50 STWHIP P PROD1 12:30 - 14:30 2.00 STWHIP P PROD1 14:30 -15:30 1.00 STWHIP P PROD1 15:30 - 16:00 0.50 BOPSU P PROD1 16:00 - 16:30 0.50 BOPSU P PROD1 16:30 - 19:30 3.00 BOPSU P PROD1 19:30 - 20:00 0.50 BOPSU P PROD1 20:00 - 21 :30 1.50 DRILL P PROD1 21 :30 - 22:00 0.50 DRILL P PROD1 22:00 - 22:30 0.50 DRILL P PROD1 22:30 - 23:00 0.50 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 Page 13 of 28 Spud Date: 10/22/2003 End: 11/22/2003 Description of Operations -....- 675 psi for a 15.1 ppg EMW. Orient tool face to 19 Left. TIH and tag bridge plug at 8239' MD, 175 klbs up, 100 klbs down. Set down 20 klbs on bridge plug to set whipstock anchors. PU and confirm set. Set down 35 klbs to shear lug. Whip stock set at 19L, TOW will be 8221'. Mill window from 8221 to 8233'. Drill additional new hole to 8248' for FIT. WOB = 15-17k RPM = 130 Torque off Btm =10k FtLb, Torque on Btm = 11 k FtLb GPM = 287 @ 2200 psi on Btm, 1950 psi off Btm P/U 175k S/O 97k ROT 130k TOW @ 8221' MD BOW @ 8233' MD Work through window with no problems. Approximately 200 Ibs of metal returns. Circulate 50 bbl hi-vis sweep with 7 Ibs of MI "Super Sweep" material surface to surface. 290 gpm @ 2384 psi Displace well to new 9.3 ppg Flo-Pro mud. 290 gpm @ 2384 psi Perform FIT to 13.1 ppg EMW. Blow down lines and monitor well. Pump a pill and POH to 4600'. At 4600' DP started pulling wet, experiencing problems with the Flo-Pro mud, increased viscosity and ammonia vapors in the pits. Well will be displace to new Flo-Pro mud, supplied by MI at no cost, when the directional BHA is on bottom. Circulate bottoms up to condition mud. Stage pumps to 300 gpm @ 1370 psi. Continue POH. Monitor well at HWDP - static. Stand back HWDP. LD milling BHA. Clean and clear rig floor. Cut and slip 101' of drilling line. Flush BOP stack with ported sub. CO saver sub. Pull wear bushing. Install test plug. Test BOPE to 250 psi low and 5000 psi high. Test annular to 250 psi low and 3500 psi high. Witness of test waived by Lou Grimaldi with AOGCC. Injected 64 bbls dead crude down the 9-5/8" X 7" annulus to freeze protect. ICP = 1200 psi @ 0.5 bpm, FCP = 1300 psi @ 2 bpm. SIP = 1000 psi Pull test plug and install wear bushing PU 6-1/8" directional BHA and orient. PJSM with Anadrill and all rig personnel on loading RA source. Load source in ADN collar. Continue PU 6-1/8" BHA. PU 6 jts of DP from pipe shed. Shallow test MWD Continue RIH picking up DP from pipe shed. Printed: 11/2412003 8:32:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date __m...... 11/6/2003 11/7/2003 11/8/2003 ..... .... Page 14 of 28 BP Operations Summary Report Start: Rig Release: Rig Number: N~~J.~~ase V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES --.- , i From - To ¡Hours · Task !, Code , ! u.. 00:00 - 01 :30 01 :30 - 04:00 04:00 - 04:30 04:30 - 06:00 06:00 - 00:00 00:00 - 17:30 17:30 - 19:00 19:00 - 00:00 00:00 - 00:30 00:30 - 02:00 --- --. ..n . ____ 1.50 DRILL P 2.50 DRILL P 0.50 DRILL P PROD1 PROD1 PROD1 1.50 DRILL N FLUD PROD1 18.00 DRILL P PROD1 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 Description of Operations . -----.. .---. Continue RIH with single jts of DP from pipe shed. Continue RIH with stands from derrick. Stage pumps to 250 gpm @ 1900 psi. Orient 19L to exit window. RIH to 8238' exiting window with no problems. CBU to condition hole. Displace to new 9.3 ppg Flo-Pro mud. 275 gpm @ 1990 psi Drill 6-1/8" directional hole from 8248' to 8646'. Slide as required to build angle into horizontal section and maintain azimuth. WOB = 5-10k RPM = 50 Torque off Btm = 4.2k FtLb, Torque on Btm = 9k FtLb GPM = 257 @ 2001 psi on Btm, 1876 psi off Btm P/U 153k S/O 114k ROT 130k Strart backreaming every stand below 8472', after BHA exited window. 257 gpm and 50 rpm, reducing flow rate to 225 gpm on down stroke. Adding mud lubes as required to obtain 150-200 psi differential pressure. Calculated ECD @ 8607' = 10.65, Actual ECD = 10.90 ART = 0.13 Hrs AST = 12.36 Hrs. Drilling Time last 24 Hrs= 12.49 hrs PROD1 Drill 6-1/8" directional hole from 8646' to 9126'. Slide as required to maintain inclination and azimuth. WOB = 5-20k RPM = 60 Torque off Btm = 5k FtLb, Torque on Btm = 7k FtLb GPM = 275 @ 2260 psi on Btm, 2200 psi off Btm P/U 148k S/O 112k ROT 129k 17.50 DRILL P Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 9073' = 11.15, Actual ECD = 11.21 ART = 4.57 Hrs AST = 7.65 Hrs. Drilling Time last 24 Hrs= 12.22 hrs 1.50 DRILL N Intermintent problems with AIM starting at 11 :20 DFAL PROD1 AIM failure. Circulate a sweep surface to surface plus 2 bottoms up to condition hole for trip. Reciprocate DP at 80 rpm and 290 gpm @ 2542 psi. Calculated ECD Prior to POH = 11.15, Actual ECD = 11.15 DFAL PROD1 Monitor well - static. POH to 8333', orient to 19L to pass through window. Continue POH through window no problems, Monitor well @ TOW - static. Continue POH to 450' DFAL PROD1 PJSM with Anadrill and all rig personnel on unloadinglloading RA source and LD/PU BHA. DFAL PROD1 Monitor well prior to pulling BHA. Stand back BHA. Unload RA source. LD MWD and motor. 5.00 DRILL N 0.50 DRILL N 1.50 DRILL N Printed: 11/24/2003 8:32:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/8/2003 02:00 - 04:30 04:30 - 05:00 05:00 - 08:30 08:30 - 20:00 1 ..... a Page 15 of 28 BP Operations Summary Report 2.50 DRILL N DFAL PROD1 DFAL PROD1 DFAL PROD1 PROD1 V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES I Ii' .. !rom - ~~ ! Hours I Task_.:_~~~_:.I.__~_~~_;n~hase i 0.50 DRILL N 3.50 DRILL N 11.50 DRILL P 20:00 - 20:30 0.50 DRILL N RREP PROD1 20:30 - 21 :30 1.00 DRILL N RREP PROD1 21 :30 - 00:00 2.50 DRILL N RREP PROD1 11/9/2003 00:00 - 01 :30 1.50 DRILL N RREP PROD1 01 :30 - 02:30 1.00 DRILL N RREP PROD1 02:30 - 05:00 2.50 DRILL P PROD1 05:00 - 12:30 Start: Rig Release: Rig Number: Spud Date: 10/22/2003 End: 11/22/2003 10/20/2003 11/22/2003 9ES Description of Operations .........--.-- ...--..--.-...------.--.- MU bit and MWD, orient. Load RA source. RIH with BHA. Shallow test MWD. Service top drive. RIH with 6-1/8" directional BHA to 9032'. MU top drive and wash to bottom at 9126' Drill 6-1/8" directional hole from 9126' to 9407'. Slide as required to maintain inclination and azimuth. WOB = 5-20k RPM = 60 Torque off Btm = 5.5k FtLb, Torque on Btm = 7k FtLb GPM = 275 @ 2375 psi on Btm, 2300 psi off Btm P/U 155k S/O 109k ROT 133k Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD = 10.75, Actual ECD = 10.81 ART = 0.28 Hrs AST = 7.18 Hrs. Drilling Time last 24 Hrs= 7.46 hrs Experiencing electrical problems with the top drive at 20:00 Circulate while trouble shooting top drive failure. Unable to determine the problem will pull up inside of csg to continue working on the problem. POH from 9407' to TOW. Monitor well - static. Trouble shoot and repair top drive. Repair top drive, electrical connections in the SCR room. Test top drive - OK Stage pumps to 275 gpm. Orient toolface to 19L. RIH to 9312', pass through window with no problems. Wash to bottom at 9407' . Drill 6-1/8" directional hole from 9407' to 9440'. Sliding to drop angle, lining up to cross fault #1 at -9800' WOB = 5-20k RPM = 60 Torque off Btm = 5.5k FtLb, Torque on Btm = 7k FtLb GPM = 275 @ 2340 psi on Btm, 2040 psi off Btm P/U 148k S/O 112k ROT 133k Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD = 10.75, Actual ECD = 10.81 7.50 DRILL P At 9440' partial loss of returns PROD1 Losses 10-20 bph static and 140 bph at drilling rate of 275 gpm. Mix 40 bbl LCM pill with 15 Ib/bbl Safe-Carb 20, 15 Ib/bbl Safe-Carb 40 and 15 Ib/bbl Safe Carb 250. Pump at 180 gpm until the pill is at the bit then slow the rate to 75 gpm. Losses still at 10-20 bph static. Printed: 11/24/2003 8:32:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: " a \ .... BP Operations Summary Report Page 16 of 28 V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 Start: Rig Release: Rig Number: Date , i From - To Hours: Task ! Code! NPT Phase , , Description of Operations 11/9/2003 05:00 - 12:30 12:30 - 14:00 14:00 - 15:30 15:30 - 16:00 16:00 - 00:00 11/10/2003 00:00 - 12:00 12:00 - 21 :30 7.50 DRILL P PROD1 1.50 DRILL P Continue circulating at 75 gpm while decreasing the mud weight from 9.3 ppg to 9.2 ppg. PROD1 POH to 9305'. Spot 52 bbl LCM pill with 25 Ib/bbl MIX II fine and 15 Ib/bbl MIX II course. Losses slowed to 35 bph at 87 gpm while spotting pill. Monitor well with no pumps for 15 min. - static. 1.50 DRILL P Continue POH to 8471 " hole taking correct displacement. P/U 168k S/O 122k PROD1 Stage pumps 1 bpm every 5 min. monitoring losses. Pushed away 14-15 bbls of the LCM pill while staging up the pumps. o losses @ 7bpm, 294 gpm @ 1929 psi Monitor well with no pumps - static. PROD1 RIH, stage pumps and wash to bottom at 9440' PROD1 Drill 6-1/8" directional hole from 9440' to 9558'. Sliding to drop angle, lining up to cross fault #1 at -9800' WOB = 5-20k RPM = 60 Torque off Btm = 5.8k FtLb, Torque on Btm = 6.5k FtLb GPM = 275 @ 2020 psi on Btm, 1920 psi off Btm P/U 157k S/O 106k ROT 130k 0.50 DRILL P 8.00 DRILL P Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Stringing in 4 sxs/hr MIX II fine Calculated ECD = 10.58, Actual ECD = 10.61 ART = 0.27 Hrs AST = 5.46 Hrs. Drilling Time last 24 Hrs= 5.72 hrs 12.00 DRILL P Dynamic losses 14-18 bph while drilling Losses last 24 hrs. = 478 bbls Total losses for well = 478 bbls PROD1 Drill 6-1/8" directional hole from 9558' to 9606'. Sliding 100% unable to drop inclination required to line up for fault #1 at -9800'. Time drill from 9606' to 9648' to drop inclination. WOB = 1-7k RPM = 60 Torque off Btm = 5.5k FtLb, Torque on Btm = 6.5k FtLb GPM = 275 @ 2000 psi on Btm, 1880 psi off Btm P/U 156k S/O 114k ROT 133k Dynamic losses while drilling increasing from 18 bph to 20-36 bph. Stringing in 6-7 sxs/hr MIX II course and 4-5 sxs/hr Safe-Carb 200. 9.50 DRILL P Calculated ECD = 10.59, Actual ECD = 10.66 PROD1 Drill 6-1/8" directional hole from 9648' to 10341'. Slide as required to maintain inclination and azimuth. Maintain ROP below 300 ftlhr to ensure LWD data quality. WOB = 10-15k Printed: 11/24/2003 8:32:44 AM ...... .. BP Operations Summary Report Page 17 of 28 Legal Well Name: V-114 Common Well Name: V-114 Event Name: DRILL +COMPLETE Start: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 9ES Rig Number: Date I From - To : Hours: Task Code NPT' Phase , 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 Description of Operations 11/10/2003 12:00 - 21:30 9.50 DRILL P PROD1 RPM = 60 Torque off Btm = 6.5k FtLb, Torque on Btm = 8k FtLb GPM = 275 @ 2170 psi on Btm, 1980 psi off Btm P/U 163k S/O 111k ROT 134k Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD = 10.55, Actual ECD = 10.76 21 :30 - 22:00 0.50 DRILL P Dynamic losses while drilling 10-15 bph. Stringing in 6-7 sxs/hr MIX II course and 4-5 sxs/hr Safe-Carb 200. PROD1 Losses increased to 60 bph. Reduced pump rate, LCM material at 4-5 sxs/hr MIX II fine and 3-4 sxs/hr MIX II course. Losses slowed to 10 bph PROD1 Drill 6-1/8" directional hole from 10341' to 10433'. Slide as required to maintain inclination and azimuth. Maintain ROP below 300 ftIhr to ensure LWD data quality. WOB = 15-30k RPM = 60 Torque off Btm = 7.5k FtLb, Torque on Btm = 9.2k FtLb GPM = 245 @ 1980 psi on Btm, 1780 psi off Btm P/U 164k S/O 106k ROT 132k 22:00 - 00:00 2.00 DRILL P Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD = 10.55, Actual ECD = 10.58 ART = 3.99 Hrs AST = 12.90 Hrs. Drilling Time last 24 Hrs= 16.89 hrs 11/11/2003 00:00 - 08:30 8.50 DRILL P Dynamic losses 10-15 bph while drilling Stringing in 4-5 sxs/hr MIX II fine and 3-4 sxs/hr MIX II course Losses last 24 hrs. = 447 bbls Total losses for well = 925 bbls PROD1 Drill 6-1/8" directional hole from 10433' to 10677'. Slide as required to maintain inclination and azimuth. Maintain ROP below 300 ftIhr to ensure LWD data quality. Taking surveys every 30'. WOB = 10-20k RPM = 60 Torque off Btm = 7.2k FtLb, Torque on Btm = 10k FtLb GPM = 260 @ 2050 psi on Btm, 1880 psi off Btm P/U 165k S/O 108k ROT 134k Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD = 10.37, Actual ECD = 10.47 Losses while drilling 15-32 bph Stringing in 4-5 sxs/hr MIX II tine and 3-4 sxs/hr MIX II course. Printed: 11/24/2003 8:32:44 AM /~ .... - BP Operations Summary Report Legal Well Name: V-114 Common Well Name: V-114 Event Name: DRILL +COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date I From - To ! Hours ¡Task ¡ Code . - ---..-. 11/11/2003 00:00 - 08:30 8.50 DRILL P Page 18 of 28 Start: Rig Release: Rig Number: NPT I Phase 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 .....--- PROD1 08:30 - 10:00 1.50 DRILL P PROD1 10:00 - 10:30 0.50 DRILL P PROD1 10:30 - 12:00 1.50 STKOH P PROD1 12:00 - 00:00 12.00 DRILL P PROD1 11/12/2003 00:00 - 02:00 Description of Operations ----... . n._ ----- ... - .. Well flowing back 4-8 bbl on connections. Monitor well until no flow back (Taking about 5 minutes before well becomes static). NOTE: C-4 interval very thin (Top C-4 @ 10600' MD/6733' TVD) & the Kuparuk D missing. Drilled into the Kalubik Pump a Hi-vis sweep surface to surface & circulate an additional 2 x Btms-up from 10677' @ 260 gpm w/1900 psi. Backream from 10677' to 10380'. Orient TF to low side for open hole side track. Start trenching from 1 0380' -10400'. Drill 6-1/8" directional hole from 10400' to 10713'. Slide as required to maintain inclination and azimuth. Maintain ROP below 300 ftlhr to ensure LWD data quality. Taking surveys every 30'. WOB = 10-20k RPM = 60 Torque off Btm = 7.6k FtLb, Torque on Btm = 10k FtLb GPM = 277 @ 2170 psi on Btm, 1940 psi off Btm P/U 165k S/O 108k ROT 134k Backream every stand at 277 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD = 10.54, Actual ECD = 10.63 Losses while drilling 10-30 bph Stringing in 4-5 sxs/hr MIX II fine and 3-4 sxs/hr MIX II course. Well flowing back 4-8 bbl on connections. Monitor well until no flow back (Taking about 5 minutes before well becomes static). Note: At +/- 10626' having problems with the MWD tool. Signal (Date Transfer) in & out. Change mud pumps. Tool started working. Checked mud pump strainers. Suction strainer had +/- 25% blockage. AST = 8.15 Hrs ART = 4.96 Hrs Survey & Connection = 8.89 hrs. Drilling Time last 24 Hrs= 13.11 hrs Losses last 24 hrs. = 598 bbls T otallosses for well = 1523 bbls PROD1 Drill 6-1/8" directional hole from 10713' to 10833'. Slide as required to maintain inclination and azimuth. Note: At 10677' encountered 45 bph losses increasing to 125 bph by 10780' WOB = 10-20k RPM = 60 Torque off Btm = 7.6k FtLb, Torque on Btm = 10k FtLb GPM = 277 @ 2170 psi on Btm, 1940 psi off Btm P/U 165k S/O 108k ROT 134k 2.00 DRILL P Backream every stand at 277 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD = 10.54, Actual ECD = 10.63 Losses while drilling 30-125 bph Printed: 11/24/2003 8:32:44 AM /--., ...... BP Operations Summary Report Legal Well Name: V-114 Common Well Name: V-114 Event Name: DRILL +COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date L~~om - TO.!. Hours! Task 11/12/2003 00:00 - 02:00 2.00 DRILL P Page 19 of 28 Start: Rig Release: Rig Number: Phase í ! 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 PROD1 Stop drilling. Circulate at a reduced rate of 190 gpm. String in Cedar Fiber at 6.6 ppb for 127 bbl + MIX II fine and MIX II course LCM. Continue circulating. Fluid losses decreased from 125 bph to 34 bph. PROD1 Continue drilling 6-1/8" hole. Slide up from 10833' to 10840'. Lost ADN & PWD data from LWD tool. AST = 0.50 Hrs ART = 1.78 Hrs Survey & Connection = 0.72 hrs. Drilling Time last 24 Hrs= 2.28 hrs Circulate & reciprocate drill string. Trouble shoot LWD problem. Unable to rectify data transfer problem. Circulate & condition mud/hole prior to POOH. Spot LCM pill in open hole @ 9438'. Monitor well until no flow back observed (5 minutes). POOH. Encounter tight hole at 10800', 10700', 10263'. Worked drill string through same. Continue POOH to 7" window with no problems. Place circulating sub @ 8221'. DFAL PROD1 Establish circulation. Orient TF to 19L. Drop ball-rod. Pressure up to 2300 psi & open circulating sub. Circulate 55 bbl @ 500 gpm x 1800 psi. Stop Circulating. Pull bit above the top of whipstock @ 8221'. Continue circulating (290 bbl) @ 500 gpm x 1800 psi. Rotate drill string with 60 rpm while circulating. Shut down pumps. Monitor well-static. Pump slug. POOH from 8221' to top of BHA. Held PJSM regarding unloading RA source & BHA handling. Continue POOH with BHA to LWD. Unload RA Source. LID LWD/MWD, mud-motor & bit. Clean & clear rig floor. Pull wear bushing. Flush stack. Install BOP test plug. RlU to test BOP's with 4" drill pipe. Test BOP's: Test Annular BOP to 250/3500 psi. Test all pipe rams, Blind/Shear rams + all surface related equipment to 250/5000 psi. All test were API. BOP test witnessed by Jeff Jones -AOGCC. RID BOP test equipment. Blow down all surface lines. Install wear bushing. Held PJSM with rig crew & SWS personnel regarding e-line logging operations. RlU SWS e-line logging equipment. SWS RIH with USIT logging tool to 8200'. Log up with USIT. Fluid losses to well = 3-5 bph. ! Code I NPT _._._...1 ...---.- PROD1 02:00 - 03:00 1.00 DRILL P 03:00 - 04:00 1.00 DRILL P 04:00 - 04:30 0.50 DRILL N DFAL PROD1 04:30 - 07:30 3.00 DRILL N DFAL PROD1 07:30 - 09:30 2.00 DRILL N DFAL PROD1 09:30 - 11 :00 1.50 DRILL N 11 :00 - 14:00 3.00 DRILL N DFAL PROD1 14:00 -14:15 0.25 DRILL N DFAL PROD1 14:15 - 16:00 1.75 DRILL N DFAL PROD1 16:00 - 16:30 0.50 DRILL N DFAL PROD1 16:30 - 17:30 1.00 BOPSUR P PROD1 17:30 - 2.1:00 3.50 BOPSUR P PROD1 21 :00 - 21 :30 0.50 BOPSUR P PROD1 21 :30 - 21:45 0.25 EVAL P PROD1 21:45-22:15 0.50 EVAL P PROD1 22:15 - 00:00 1.75 EVAL P PROD1 Description of Operations . -------.----- ...-..-. -.- --- -------... Stringing in 4-5 sxs/hr MIX II fine and 3-4 sxs/hr MIX II course. Well flowing back 4-8 bbl on connections. Monitor well until no flow back (Taking about 5 minutes before well becomes static). Losses last 24 hrs. = 300 bbls T otallosses for well = 1823 bbls PROD1 Continue logging 7" casing with US IT tool from 8200' to 2250. USIT tool indicates good isolation & cement bond around 7" casing. TOC @ 2450' (Log placed in drop box for Jim Young Pad Engineer). POOH from 2250'. R/D SWS e-line equipment. 11/13/2003 00:00 - 03:30 3.50 EVAL P Printed: 11/24/2003 8:32:44 AM .... - BP Operations Summary Report legal Well Name: V-114 Common Well Name: V-114 Event Name: DRill +COMPlETE Contractor Name: NABORS ALASKA DRilLING I Rig Name: NABORS 9ES ._._.~~~_om.~.:o · Hours ; ~~~k 11/13/2003 03:30 - 05:30 2.00 DRILL h' Code I NPT 1. Phase N DFAL PROD1 05:30 - 08:30 3.00 DRILL N DFAL PROD1 08:30 - 09:30 1.00 DRILL N DFAL PROD1 09:30 - 11 :00 1.50 DRILL N DFAL PROD1 11 :00 - 12:30 1.50 DRILL N DFAL PROD1 12:30 - 13:00 0.50 DRILL N DFAL PROD1 13:00 - 00:00 11.00 DRILL P PROD1 Page 20 of 28 Start: Rig Release: Rig Number: I Spud Date: 10/22/2003 End: 11/22/2003 10/20/2003 11/22/2003 9ES Description of Operations ..--....-. .-... - ..-- ____n M/U 6-1/8"Steerable drilling assembly. P/U fresh mud-motor, MWD/LWD. Orient mud-motor & MWD. PJSM. Load RA source. Surface test MWD. TIH with 6-1/8" Drilling Assembly on 4" drill pipe to 8200'. Only getting half the drill pipe displacement volume back while TIH. Break circulation. Stage pumps to 260 gpm. Fluid losses @ 35 bph. CBU from 8200'. Stop pumps. Slip & cut 75' drill line. Re-set & check C-O-M. Service TDS (Monitor well on trip tank). Orient TF 19L. Slide bit through 7" window @ 8221' with no problems & continue TIH to 10360'. Establish circulation. Stage pumps to 275 gpm w/1820 psi. Orient TF Low Side & slide through open hole side track. Take survey to confirm - OK. Continue RIH to 10780'. Precautionary wash last stand to bottom @ 10,840'. CBU prior to drilling. Circulating fluid losses at 35-40 bph. Drill 6-1/8" directional hole from 10840' to 11212'. Slide as required to maintain inclination and azimuth. Taking surveys every 30'. NOTE: Anadrill AIM Tool failed @ 10,850'. Decision made to Drill Ahead. WOB = 10-20k RPM = 60 Torque off Btm = 7k FtLb, Torque on Btm = 10k FtLb GPM = 275 @ 2120 psi on Btm, 1920psi off Btm P/U 171 k S/O 99k ROT 134k AST = 1.85 Hrs ART = 4.52 Hrs Survey & Connection = 4.63 hrs. On bottom Drilling Time last 24 Hrs= 6.37 hrs Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD = 10.22, Actual ECD = 10.46 Losses while drilling @ 20-30 bph Losses last 24 hrs. = 365 bbls Total losses for well = 2188 bbls Stringing in 4-5 sxs/hr MIX II fine and 3-4 sxs/hr MIX II course. Well flowing back 2-4 bbl on connections. Monitor well until no flow back (Taking about 2-3 minutes before well becomes static). PROD1 Drill 6-1/8" directional hole from 11212' to 11444'. Slide as required to maintain inclination and azimuth. Taking surveys every 30'. WOB = 10-20k RPM = 60 Torque off Btm = 7k FtLb, Torque on Btm = 10k FtLb GPM = 260 @ 1990 psi on Btm, 1760psi off Btm P/U 171 k S/O 104k ROT 135k 11/14/2003 00:00 - 08:00 8.00 DRILL P Printed: 11/24/2003 8:32:44 AM Legal Well Name: V-114 Common Well Name: V-114 Event Name: DRILL +COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date I From - To : Hours! Task .-------. 11/14/2003 00:00 - 08:00 08:00 - 10:30 10:30 - 13:30 13:30 - 15:30 15:30 - 16:00 16:00 - 18:30 18:30 - 20:30 20:30 - 22:00 22:00 - 00:00 11/15/2003 00:00 - 00:30 00:30 - 00:45 00:45 - 03:00 '.... BP Operations Summary Report Page 21 of 28 Start: Rig Release: Rig Number: . Code I NPT : Phase I Spud Date: 10/22/2003 End: 11/22/2003 10/20/2003 11/22/2003 9ES Description of Operations -.. ..-.--.----.... .------- ... ..--- ..-----..-- --.-----.- ... .. ....- 8.00 DRILL P PROD1 Backream every stand at 260 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD = 10.22, Actual ECD = 10.44 AST = 3.75 Hrs ART = 1.79 Hrs Survey & Connection = 2.46 hrs. On bottom Drilling Time last 24 Hrs= 5.54 hrs Note: Top of C-4 came in at 11384' MD/6734' TVD Losses while drilling = 20-30 bph 2.50 DRILL P Stringing in 4-5 sxs/hr MIX II fine and 3-4 sxs/hr MIX II course. Well flowing back 2-4 bbl on connections. Monitor well until no flow back (Taking about 2-3 minutes before well becomes static). PROD1 Pump 40 bbl sweep. Circulate hole clean from 11444' (895 bbl total circulation) @ 270 gpm w/1840 psi & 80 rpm. PROD1 Flow check. Well static. POOH to 7" window @ 8221' with no problems. Note: Hole not taking proper amount of mud for the 1 st 16 stands pulled due to hole breathing. Flow checked well @ 9900' & @ 8221". Well static. PROD1 TIH to 10360' with no problems. PROD1 M/U TDS. Establish circulation. Stage pumps to 260 gpm w/ 1725 psi. Orient TF Low Side & slide through open hole side track. Take survey to confirm - OK. Continue TIH to 11366'. Precautionary wash last stand to bottom @ 11444'. PROD1 Pump 40 bbl HV sweep. Circulate surface to surface + 2 bottoms up to condition hole. Spot 120 bblliner running pill in open hole. Reciprocate drill string & rotate @ 80 rpm + 263 gpm @ 1790 psi. 3.00 DRILL P 2.00 DRILL P 0.50 DRILL P 2.50 DRILL P 2.00 DRILL P Calculated ECD Prior to POOH = 10.38, Actual ECD = 10.42 PROD1 Flow check well. Well static. POOH to 7" window with no problems. Place circulating sub @ 8221'. Break circulation & orient TF 19L Max drag was 20-25k. PROD1 Drop ball-rod. Pressure up to 2300 psi & open circulating sub. Circulate 55 bbl @ 475 gpm x 1575 psi. Stop Circulating. Pull bit above the top of whipstock @ 8221'. Continue circulating (290 bbl) @ 475 gpm x 1575 psi. Rotate drill string with 80 rpm while circulating. Shut down pumps. Monitor well-static. Pump slug. PROD1 POOH from 8221' to 1800'. 1.50 DRILL P 2.00 DRILL P 0.50 DRILL P 0.25 DRILL P Losses last 24 hrs. = 434 bbls Total losses for well = 2622 bbls PROD1 POOH from 1800' to top of BHA LID Jars. PROD1 SAFETY--- Held PJSM with Rig Crew & Anadrill MWD personnel regarding safe handling procedures of RA Source. PROD1 Continue POOH with BHA to LWD. Unload RA Source. LID LWD/MWD, mud-motor & bit Clear rig floor. 2.25 DRILL P Printed: 11/24/2003 8:32:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ..... - BP Operations Summary Report Start: Rig Release: Rig Number: NPT I Phase I V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES ---- . I Code .-- P P COMP COMP Date From - To ' Hours; Task ..... -.... . ---- ..--..------.. ---.--- 11/15/2003 03:00 - 04:00 04:00 - 04:30 04:30 - 10:00 10:00 - 10:30 1.00 CASE 0.50 CASE 5.50 CASE P COMP 0.50 CASE P COMP 10:30 - 11 :00 0.50 CASE P COMP 11:00-15:00 4.00 CASE P COMP 15:00 - 15:30 0.50 CASE P COMP 15:30 - 16:00 0.50 CASE P COMP 16:00 - 18:00 2.00 CASE P COMP 18:00 - 18:30 0.50 CASE P COMP 18:30 - 21:00 2.50 CASE P COMP 21 :00 - 21 :30 21 :30 - 22:30 0.50 CEMT P COMP 1.00 CEMT P COMP Page 22 of 28 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 ----.--.. Description of Operations ..--.-.---. ........---.--- . ...-- RIU 4.5" Liner equipment. SAFETY--- Held PJSM with Rig Crew, Baker Service Rep & Nabors Casing Hand regarding Liner Running procedures. Static mud losses = 4 bph. M/U 4.5" liner shoe track. Check floats - OK. Run 81 joints 4.5" 12.6# IBT-M Production Liner @ 1.5 minutes/Joint. Averge M/U Torque using B-O-L 2000 pipe dope = 3200 FtLb. Fill up on every joint. M/U a Baker Type 7" x 5" "HMC" Hydraulic set liner hanger complete with ZXP packer & 6' tie-back extension with Baker C-2 running tool & rotating dog sub on the 4.5" liner assembly. Total liner assembly length = 3407.63'. Liner string wt = 36k. Establish circulation. Stage pumps to 3 bpm @ 140 psi. Circulate one liner volume (51 bbl). P/U 75k S/O 65k. Continue RIH with 4.5" Liner on 4" drill pipe at 1 minute/Stand to 8168'. Fill drill pipe every 10 stands & break circulation. M/U a 4" x 15' drill pipe Pup Jt on Baker's Top-Drive Cementing Head loaded with drill pipe wiper plug. UD & set aside. M/U TDS. Establish circulation. Circulate drill pipe & liner volume @ 5 bpm w/ 550 psi. P/U 144k S/O 115k. Continue RIH w/4.5" Liner on 4" drill pipe to 11431' @ 1.5 minutes/Stand with no problems. Fill drill pipe every 10 stands & break circulation. P/U Baker's Top-Drive Cement Head & M/U into 4" drill pipe. Hook up cement & circulating lines. Establish circulation. Stage pumps to 6 bpm. Wash to bottom @ 11444'. Hole trying to pack-off. Reciprocate string 12'-15' & reduce pump rate to 3 bpm & gradually increasing to 4.5 bpm w/ 900 psi for the the 1 st 240 bbl pumped with 20 bph fluid losses. Increase pump rate to 6 bpm @ for the next 410 bbl w/ 1060 psi with 80 bph initial fluid losses decreasing to 50 bph. P/U 174k S/O 96k. Note: While circulating held PJSM with rig crew, MI & Dowell personnel regarding liner cementing operations. Batch mix 87 bbl Class "G" 15.8 ppg cement slurry. Stop pumping. Line up Dowell. Pump 5 bbl CW100. Test cement line to 4500 psi. Continue pumping 10 bbl CW100 + 35 bbl of 10.3 ppg MudPush spacer + 86 bbl of 15.8 ppg "G" Cement slurry. Shut down. Line up & flush cement line with water. Release Drill Pipe wiper plug. Switch over to rig pumps. Start displacement. Pump 51 bbl of 9.3 ppg KCL Perf pill followed by 9.2 ppg FloPro drilling mud @ 5.5 bpm w/ 750 psi. Reciprocating liner string 12'-15' with no problems, everything looking good. After pumping a total of 55 bbl into displacement (12 bbl of cement out from shoe) the hole packed-off, shut down pump with 1850 psi on gauge. Liner stuck 10' off bottom @ 11434'. Attempt to work down with no success. Slack off maximum weight on liner. Continue displacing cement @ 3 bpm w/ 2700 psi & no returns. The drill pipe wiper plug latched up on schedule (78 bbl total) into liner wiper plug (+/- 1100 psi to shear). Bump plug (129 bbl total) on schedule with 3500 psi (Liner hanger pinned to set @ 2700 psi). Held pressure for 5 Printed: 11/24/2003 8:32:44 AM BP Page 23 of 28 Operations Summary Report Legal Well Name: V-114 Common Well Name: V-114 Spud Date: 10/22/2003 Event Name: DRILL +COMPLETE Start: 10/20/2003 End: 11/22/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2003 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task ¡code NPT Phase Description of Operations 11/15/2003 21 :30 - 22:30 1.00 CEMT P COMP minutes. Release pressure & check floats. Floats holding. Cement in place at 22:13 hrs on Nov 15, 2003. Note: Regained partial returns the last 7.5 bbl of displacement. 22:30 - 00:00 1.50 CEMT P COMP P/U to 85k. Release liner hanger running tool with 20 rounds of RH rotation. Pressure up to 1000 psi. P/U drill pipe work string 4' & unsting from hanger, had decrease in pressure. Increase pump rate to 12 bpm w/2190 psi (Mud losses while pumping = +/- 20 bph). Circulate bottoms-up from Top of 4.5" liner @ 8024'. On bottoms-up observed 40 bbl of comtaminated mud ( PH & color indicated contamination with MudPush spacer). Note: Lost 35k Wt when pulled up out off liner hanger. Losses last 24 hrs. = 518 bbls Total losses for well = 3140 bbls 11/16/2003 00:00 - 00:30 0.50 CEMT P COMP Monitor well after circulating hole clean above 4.5" liner top @ 8024'. Well flowing back at 12 bph for a total of 4 bbl. Shut in well. No pressure build up. Open well. Monitor another 15 minutes. Well static. 00:30 - 01 :30 1.00 CASE P COMP R/D cement hose. UD Baker's Top-Drive cementing head & related equipment. Monitor well on trip tank. Well static. 01 :30 - 04:30 3.00 CASE P COMP Pump slug. POOH to 3360'. Rack back a total of 86 stands in derrick. 04:30 - 07:30 3.00 CASE P COMP Continue POOH. UD 87 joints of excess 4" drill pipe. Rack back 7 stands of 4" HWDP in derrick. UD Baker C-2 liner hanger running tool. 07:30 - 09:30 2.00 CASE P COMP Slip & cut 59' of drill line. Re-set & check C-O-M. Inspect brakes & service TDS. 09:30 - 11 :30 2.00 CLEAN N DPRB COMP M/U 7" casing scraper asssembly consisting of the following componets: 2-7/8" muleshoe + 1 Jt 2-7/8" Pac drill pipe + 2 XO Subs + 7" casing scraper + XO to 4" drill pipe = 43.71'. 11 :30 - 14:00 2.50 CLEAN N DPRB COMP TIH with 7" casing scraper assembly on 4" drill pipe to 7979'. 14:00 - 15:30 1.50 CLEAN N DPRB COMP M/U TDS. Establish circulation w/ 3 bpm @ 175 psi. Wash down & tag the top of 4.5" liner with the 7" casing scraper @ 8024' placing the end of 2-7/8" tail pipe inside 4.5" liner @ 8059'. Pull 2-7/8" tail pipe up above 4.5" liner top. Pump a 40 bbl HV sweep & increase pump rate to 11.7 bpm w/1520 psi. Circulate a total of 450 bbl. Fluid losses while circulating = 60 bph. Flow check well. Well static. Pump slug. 15:30 - 19:00 3.50 CLEAN N DPRB COMP POOH with drill string to 7" Casing scraper assembly. 19:00 - 19:30 0.50 CLEAN N DPRB COMP UD 7" Casing scraper & 2-7/8" tail pipe. 19:30 - 20:00 0.50 CLEAN N DPRB COMP RIU drill floor for picking up 2-7/8" Pac drill pipe. 20:00 - 20:30 0.50 CLEAN N DPRB COMP SAFETY--- Held PJSM regarding picking up & handling 2-7/8" drill pipe. 20:30 - 00:00 3.50 CLEAN N DPRB COMP P/U 2-7/8" Pac drill pipe from pipe shed & RIH with same. Losses last 24 hrs. = 84 bbls Total losses for well = 3224 bbls 11/17/2003 00:00 - 01 :00 1.00 CLEAN N DPRB COMP Continue P/U 111 Jts of 2-7/8" Pac DP & TIH to 3418'. 01 :00 - 02:00 1.00 CLEAN N DPRB COMP Circulate 2X Btms up w/ 400 gpm @ 2900 psi. Ehcountered 6 bph fluid losses while circulating. 02:00 - 05:00 3.00 CLEAN N DPRB COMP Flow check. Well static. POOH. Rack back 37 stands 2 7/8'" PAC DP. Printed: 1112412003 8:32:44 AM .. ~ BP Page 24 of 28 Operations Summary Report Legal Well Name: V-114 Common Well Name: V-114 Spud Date: 10/22/2003 Event Name: DRILL +COMPLETE Start: 10/20/2003 End: 11/22/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2003 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours ¡Task Code NPT' Phase i Description of Operations ----.-- --..- ... .___n.__.__ ---..----... -.....-... ..... .... --..-- _._~-- 11/17/2003 05:00 - 05:30 0.50 EVAL N DPRB COMP Safety Meeting w/ Crew & SWS personnel. 05:30 - 07:00 1.50 EVAL N DPRB COMP RlU SWS to run DPC Slim Hole Soniic - CBL / VDL. Test tool at surface-OK. M/U Slim Hole Sonic logging tool on bottom of 2-7/8" Pac DP. 07:00 - 10:00 3.00 EVAL N DPRB COMP TIH with SWS Slim Hole Sonic logging tool on 2-7/8" Pac DP to 3495. Break circulation at 2000'. 10:00 - 13:30 3.50 EVAL N DPRB COMP Change over to 4" HT-40 DP. Continue TIH to 7200'. Breaking circulation every 2000'. 13:30 - 16:30 3.00 EVAL N DPRB COMP RlU SWS e-line sheaves in derrick. M/U the SDES in 4" DP string. RIH inside DP with e-line to 6900'. Establish circulation. Pump down Wet-Connect receptacle & e-line @ 1.5 bpm w/ 540 psi. Latch up on DHWC @ 7160'. Sonic tool not working. Trouble shoot problem. Unable to rectify problem. 16:30 - 17:00 0.50 EVAL N DPRB COMP POOH with e-line & PDWC. 17:00 - 18:00 1.00 EVAL N DPRB COMP Found short in head connector. Re-head rope socket. 18:00 - 19:30 1.50 EVAL N DPRB COMP RIH inside DP with e-line to 6900'. Establish circulation. Pump down Wet-Connect receptacle & e-line @ 1.5 bpm w/ 540 psi. Latch up on DHWC @ 7160'. Check Sonic tool-OK. Install e-line clamp to SDES. Perform pull test on same-OK. 19:30 - 20:30 1.00 EVAL N DPRB COMP Continue TIH with SWS Slim Hole Sonic logging tool (DPC) on 2-7/8" x 4" DP work string from 7200' to 8048. Passed by 4.5" Liner Top @ 8024' with no problems. Encountered resistance inside 4.5" liner@ 8048'. Set down 1500# on Sonic tool (Tool compression strength rated @ 4400 Ib). 20:30 - 22:00 1.50 EVAL N DPRB COMP Work tool down from 8048' to 8080', resistance on Sonic tool increased to 3500#. Establish circulation @ 2.25 BPM w/ 990 psi pumping through SWS circ sub. Continue circulating & working string down to 8100'. After 8100' there was no excess downhole resistance on Sonic tool. Stop pumping. Blow down TDS. 22:00 - 00:00 2.00 EVAL N DPRB COMP Continue TIH performing DPC logging operations with Slim Hole Sonic logging tool to 10,000' (Midnight depth). No cement logged 11/18/2003 00:00 - 01 :30 1.50 EVAL N DPRB COMP Break circ. @ 10000' & circ for 5 min. 30 SPM @ 940 psi. Continue Logging down to 11,333'. TOP OF GOOD CEMENT @ 10,785'. 01 :30 - 02:00 0.50 EVAL N DPRB COMP Log repeat section from 11,333 to 10,082'. Confirm TOC @ 10,785'. 02:00 - 06:30 4.50 EVAL N DPRB COMP POOH to 7200' (logging up w/ SWS Slim Hole Sonic to 8000'). 06:30 - 08:00 1.50 EVAL N DPRB COMP Held PJSM. SWS unlatch from DHWC. POOH with e-line & PDWC. RID side entry sub, wireline sheaves & related equipment. 08:00 - 10:30 2.50 EVAL N DPRB COMP Flow check well static. Pump slug. POOH to top of 2-7/8" DP. 10:30 - 14:30 4.00 EVAL N DPRB COMP Change elevators & R/U to handle 2-7/8" DP. Continue POOH. Stand back 2-7/8" DP in derrick. 14:30 - 15:00 0.50 EVAL N DPRB COMP UD SWS Slim Hole Sonic logging tools & related equipment. 15:00 - 15:30 0.50 EVAL N DPRB COMP Clean up rig floor. 15:30 - 16:00 0.50 EVAL N DPRB COMP RID 2-7/8" DP handling equipment. 16:00 - 17:00 1.00 REMCM N DPRB COMP P/U Baker Oil Tools 5.25" OD Seal assembly with C-2 Packer setting tool + circ sub on top. M/U to 4" HWDP. 17:00 - 20:00 3.00 REMCM N DPRB COMP TIH with Baker Seal Assembly & C-2 Packer setting tool to 7996'. 20:00 - 20:30 0.50 REMCM N DPRB COMP M/U Baker's Plug Dropping Head. RlU cement hose. Continue Printed: 1112412003 8:32:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To ---.....-.. 11/18/2003 --...----..- 20:00 - 20:30 20:30 - 21 :30 21 :30 - 22:00 22:00 - 23:00 23:00 - 00:00 11/19/2003 00:00 - 00:30 ..... .. Page 25 of 28 BP Operations Summary Report 1.00 REMCM N 0.50 REMCM N DPRB COMP DPRB COMP V-114 V-114 DRILL +COMPLETE Start: 10/20/2003 NABORS ALASKA DRILLING I Rig Release: 11/22/2003 NABORS 9ES Rig Number: 9ES . I ; I . Hour:.;.Ta~k.~.~~1 NPT . Phase I 0.50 REMCM N DPRB COMP 1.00 REMCM N DPRB COMP 1.00 REMCM N DPRB COMP 0.50 REMCM N DPRB COMP 00:30 - 01 :00 0.50 REMCM N DPRB COMP 01 :00 - 01 :30 0.50 REMCM N DPRB COMP 01 :30 - 05:00 3.50 REMCM N DPRB COMP 05:00 - 06:00 1.00 CLEAN P COMP 06:00 - 08:30 2.50 CLEAN P COMP 08:30 - 09:30 1.00 CLEAN P COMP 09:30 - 13:00 3.50 CLEAN P COMP Spud Date: 10/22/2003 End: 11/22/2003 Description of Operations -----..-...-.. .- - ..... ------ T!H. Tag up on 4.5" liner top @ 8024'. Sting into PBR & apply 10k set down wt. P/U to neutral point. CBU from 8021' w/368 gpm @ 1280 psi. Take circulating rates through circ sub @ 1-5 bpm. Stop pumping. Shut-in well. Obtain injection rates at the following pump rates by bullheading down annulus with mud by-passing 4.5" liner top packer (Packer Not Set): 1 bpm = 200 psi 2 bpm = 440 psi 3 bpm = 630 psi 4 bpm = 875 psi 5 bpm = 1150 psi Stop pumping. Open BOP. Line up Dowell. Pump 5 bbl water. Test lines to 4000 psi. Dowell pump 80 bbl of 15.8 ppg Class 'G' slurry down 4" DP. Release drill pipe wiper dart. Dowell pump 5 bbl water. Switch over to rig pumps & displace cement from drill pipe with 80 bbl 9.2 ppg mud @ 5.5 bpm w/1130 psi. Lost 33 bbl to formation while displacing drill pipe with mud. Shut-in well. Squeeze 40 bbl @ 3 bpm, reduce pump rate to 1 bpm for the last 10 bbl with 1240 psi final pressure. CIP @ 22:55 hrs. Squeeze pressures listed below. BBL Pumped Pressure 10 bbl 640 psi 20 bbl 815 psi 30 bbl 925 psi 40 bbl 1125 psi 50 bbl 1240 psi Slack off 45k & set ZXP Liner Top packer @ 8024'. Perform a quick i minute pressure test to 3500 psi-OK. Bleed off pressure & open annulur BOP. Pull BOT seal assembly out of ZXP PBR. CBU from 8020' at 11.7 bpm with 2030 psi. Losses last 24 hrs. = 53 bbls Total losses for well = 3277 bbls Continue circulating @ 8020' @ 11.7 bpm w/1900 psi. Observed cement contaminated mud 12 bbl prior to having btms-up from 8020' (annulus vol = 182 bbl). Treat & dump same to cutting pit. Continue circulating another 91 bbl to ensure hole was clean. Test 4.5" Liner Top packer @ 8024' to 3500 psi for 30 minutes. Test was API. Pump slug. UD Baker's Plug Dropping Head. Blow down circulating lines. POOH with 4" DP & Baker 5.25" Seal Assembly + C-2 Packer setting tool. UD Seal Assembly & Packer setting tool. Clear & clean rig floor. Hoist BOT 2-7/8" Mud-motor up Beaver slide to rig floor. M/U Baker's 2-7/8" Mud-motor w/3.80" OD Diamond speed mill on 2-7/8" Pac DP & TIH to 3337'. M/U 7" casing scraper, 4" HWDP & Jars in drill string. Continue TIH with 3.8" Mill + Mud-motor + 2-7/8" DP + 7" casing scraper on 4" DP to 11300' (No problems with 3.80" mill Printed: 11/24/2003 8:32:44 AM ..... .. Page 26 of 28 BP Operations Summary Report legal Well Name: V-114 Common Well Name: V-114 Event Name: DRill +COMPlETE Contractor Name: NABORS ALASKA DRilLING I Rig Name: NABORS 9ES I : Date ! From - To ! Hours Task __----L__..__ ... "0 __.._ 11/19/2003 09:30 - 13:00 13:00 - 15:30 Start: Rig Release: Rig Number: I ' I Code' NPT: Phase: _____00___. .__._.__1. 3.50 CLEAN P 2.50 CLEAN P 15:30 - 19:00 3.50 CLEAN P 19:00 - 22:30 3.50 CLEAN P 22:30 - 23:00 0.50 BOPSUF P 23:00 - 00:00 1.00 BOPSUF P 11/20/2003 00:00 - 02:30 2.50 BOPSUF P 02:30 - 03:00 0.50 BOPSUF P 03:00 - 03:30 0.50 PERF P 03:30 - 04:30 1.00 PERF P 04:30 - 06:30 06:30 - 10:30 10:30 - 11 :00 2.00 PERF P 4.00 PERF P 0.50 PERF P COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP 11 :00 - 11 :30 0.50 PERF P COMP 11:30-12:30 1.00 PERF P COMP 12:30 - 16:00 3.50 PERF P COMP 16:00 - 17:00 1.00 PERF P COMP 17:00 - 20:00 3.00 PERF P COMP 20:00 - 20:15 0.25 PERF P COMP 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 Description of Operations --.----------. .. . n._ _. _._.. ______..._ passing through 4.5" Liner Top @ 8021 '). Break circulation. Stop pumping & tag up on Baker Landing Collar @ 11344' DPM (7" casing scraper @ 8000'). P/U 5'. Circulate one liner volume. Drop ball to open circ sub on 2-7/8" Mud-motor. Pressure up & open the circ sub. Spot 55 bbl Perf pill in 4.5" liner. Stop pumps. Drop ball-rod to open 4-3/4" circ sub postioned in string @ 7997'. Pressure up & open the 4-3/4" circ sub. Start displacing hole to completion fluid: Pump HV sweep + Safe Clean pill followed by 9.3# Filtered KCL Brine. Reciprocate while displacing hole. Pump rate = 490 gpm @ 2000 psi. (Clean out under shakers & possum belly). POOH to the top of 2-7/8" DP. LID 4" HWDP, 7" casing scraper & jars. Continue POOH. Stand back 2-7/8" Pac DP in derrick. LID 2-7/8" Mud-motor assembly. Pull wear bushing. Run BOP test plug on 4" DP. R/U to test BOP. Test BOP's: Test Annular BOP to 250/3500 psi. Test all pipe rams, Blind/Shear rams + all surface related equipment to 250/5000 psi. All test were API. Witness of BOP test waived by Chuck Scheve -AOGCC. Finish Tesing BOP's: Test Annular BOP to 250/3500 psi. Test all pipe rams, Blind/Shear rams + all surface related equipment to 250/5000 psi. All test were API. Witness of BOP test waived by Chuck Scheve -AOGCC. RID test equipment. Blow down all surface lines that were used for testing BOP. Pull BOP test plug. Run & install wear bushing. SAFETY --- Held PJSM with Rig Crew & Schlumberger TCP personnel regarding picking up perf guns & TCP operations. M/U SWS Perf Gun assembly. (235.30' of 2-1/2" HSD charge guns @ 4 spf). Note: Perf Guns will be spaced out to perforate from 11335.30' to 11100'. TIH with Perf Gun assembly on 2-7/8" PAC DP to 3408'. Change over to 4" DP handling tools. Continue TIH with Perf Gun assembly on 4" DP with no problems going through 4.5" Liner Top. Tag-up on Landing Collar @ 11344'. P/U & place TCP guns on depth to perforate 4.5" liner from 11335' to 11100'. Held PJSM prior to perforating. Close Annular BOP. Pressure up to 2500 psi down work string & annulus. Hold pressure for 2 minutes. Bled off pressure. Had good indication that Perf Guns fired. Open BOP. POOH 5 stands to 10868'. Monitor well. Well static. CBU from 10868'. Flow rate = 5.8 bpm @ 3140 psi. Flow check. Well static. Pump slug. POOH. Rack back 35 stands of 4" DP in derrick & LID 228 Jts of 4" DP to the top of 2-7/8" Pac DP. Slip & cut 95' of drill line. Re-set & check C-O-M. Continue POOH. LID 2-7/8" Pac DP to 470'. SAFETY--- Held PJSM with Rig Crew & Schlumberger Printed: 11/24/2003 8:32:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ...... - Page 27 of 28 BP Operations Summary Report V-114 V-114 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: NPT ' Phase I 10/20/2003 11/22/2003 9ES Spud Date: 10/22/2003 End: 11/22/2003 ... ..- -.... "....---- i From - To Hours ¡Task . Code ---------- .. Date 11/20/2003 20:00 - 20:15 20:15 - 21 :30 21 :30 - 22:00 22:00 - 23:00 23:00 - 23:30 23:30 - 00:00 11/21/2003 00:00 - 09:30 09:30 - 11 :00 11:00 -13:00 13:00 - 14:30 0.25 PERF P 1.25 PERF P COMP COMP 0_50 WHSUR P 1.00 RUNCor p 0.50 RUNCor p 0.50 RUNCor p COMP COMP COMP COMP 9.50 RUNCor p COMP 1_50 RUNCor p COMP 2.00 RUNCorf'p COMP 1.50 RUNcor p COMP 14:30 - 15:00 0.50 RUNcm p COMP 15:00 -16:30 1_50 BOPSU¡::; P COMP 16:30 -18:00 1.50 WHSUR P COMP 18:00 - 19:00 1.00 WHSUR P COMP 19:00-19:15 0.25 PULL N DPRB COMP 19:15 - 00:00 4.75 PULL N DPRB COMP 11/22/2003 00:00 - 00:30 0_50 PULL N DPRB COMP Description of Operations ....-... ..-. .... ____. ...... ---. ....-------.--.-----.. regarding laying down TCP guns & related equipment Continue POOH. UD remainder of 2-7/8" Pac DP & SWS 2-1/2" Perf Guns. Had 100% Detonation on perf guns. Pull wear bushing. Make dummy run with FMC Tubing Hanger. RlU 4.5" Tubing handling & running equipment Clean rig floor & held PJSM on running 4.5" tubing. M/U & RIH with 4_95" WLEG, Tail-pipe & bottom X-nipple assemblies + 4.5" 12_6# L-80 NSCT tubing with Baker 7" x 4.5" S-3 Packer & GLM assemblies_ Continue RIH with 4.95" WLEG, Tail-pipe & bottom X-nipple assemblies + 4_5" 12_6# L-80 NSCT tubing with Baker 7" x 4.5" S-3 Packer & 6 each GLM assemblies to to 7994'. M/U Torque 4000 FtLb using Jet-Lube Seal Guard RlU to circulate. Wash F/7994' to 8030' ( 7.4' inside TBR ) @ 3 bpm 120 psi. P/U and space out M/U FMC 11" x 4.5" Tubing Hanger & Pup Jt, Land Hanger & confirm correct space out-OK. FMC Service Rep RILDS. P/U Wt 127k S/O Wt 95k_ NOTE: Top connection on Tbg Hanger is 4_5" TC-II. Ran 250 Jts of 4_5" 12.6# L-80 NSCT tubing. Rig up to reverse circulate. Reverse circulate down 7" annulus & up tubing string @ 3 bpm w/11 0 psi with 20 bbl of treated 9.3 ppg corrosion inhibited brine followed by 130 bbls of 9_3 ppg clean filtered brine to put corrosion inhibitor in the annulus between the packer & DCK Shear valve @ 7150' MD. RID tubing pump-in sub. Drop 1-7/8" Ball-rod & allow to gravitate on seat UD the 4.5" Tubing Landing Jt Pressure up on tubing to 2800 psi to set Baker "S-3" packer. Continue pressuring tubing to 4000 psi. Hold test for 30 minutes. Test was API. Manually bled off tubing pressure to 2500 psi. Pressure up 4.5 x 7" annulus to 3500 psi. Hold test for 30 minutes to test casing integrity. Test was API. Manually bled off pressure on both tubing & annulus to 0 psi. Pressure up 4.5" x 7" annulus to 3000 psi & sheared DCK valve in the GLM @ 7150' (Pumping rate & pressure {2 bpm @ 2500 psi} indicates a partial shear. Tubing» annulus - unable to pump). Manually bled off pressure to 0 psi on tubing & annulus. Blow down all surface lines & pump out BOP. FMC install TWCV. Test TWCV from below to 2800 psi-OK. PJSM. NID BOP's. Set back & secure_ N/U FMC 11" 5K x 4-1/16" 5K Tubing head adapter & CIW 4-1/16" 5K Production Tree. Test tubing head adapter pack-off & tree to 5000 psi. RlU DSM lubricator & pull TWCV. SAFETY--- Held PJSM with Rig Crew & Halliburton Slick-line personnel regarding slick-line operations, rigging up lubricator & related equipment RlU HES Slick-line lubricator & related equipment M/U 4.5" OK-6 Kickover tool w/1.25" JDC Pulling tool on slick-line. Test Lubricator against Swab valve on tree to 3000 psi. RIH. The tool set down in #2 GLM @ 6508' & the JDC Pulling tool latched up on the Dummy valve_ HES sheared off. POOH with slick-line_ HES finish POOH with Slick-line. Printed: 11/24/2003 8:32:44 AM ,.,. - Page 28 of 28 BP Operations Summary Report Legal Well Name: V-114 Common Well Name: V-114 Event Name: DRILL +COMPLETE Start: 10/20/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2003 Rig Name: NABORS 9ES Rig Number: 9ES Date ! From - To ¡ Hours i Task Code NPT i Phase I .--....-. ...n. . -- ---..... 0.50 PULL N 1.50 PULL N -. .--- 11/22/2003 00:30 - 01 :00 DPRB COMP 01 :00 - 02:30 DPRB COMP 02:30 - 03:30 1.00 PULL N DPRB COMP 03:30 - 03:45 0.25 RUNCOI!P COMP 03:45 - 06:30 2.75 RUNCOI!P COMP 06:30 - 09:00 2.50 WHSUR P COMP Spud Date: 10/22/2003 End: 11/22/2003 Description of Operations ..--.... ~ ------. Re-pin HES 1.25" JDC Pulling tool. M/U lubricator. Test to 3000 psi. RIH with a 4.5" OK-6 Kickover tool w/1.25" JDC Pulling tool on slick-line to 7154'. Latch & pull free the DCK-2 shear valve from GLM #1. HES POOH with slick-line. Recover DCK-2 shear valve. Drain lubricator & RID HES Slick-line equipment. SAFETY--- Held PJSM with Rig Crew & Little Red Hot Oil Service personnel regarding freeze protecting operations. RlU Hot Oil & test lines to 3000 psi. Freeze protect 4.5" x 7" annulus. Reverse circulate 130 bbl of diesel down 4.5" x 7" annulus @ 2 bpm w/925 psi FCP. Let well U-Tube & equalize. Well freeze protected to 3850' MD / 3450' TVD. DSM install BPV in Tubing Hanger. Test to 1000 psi. Also install VR plugs in Tbg spool valve outlet. R/D Hoil Oil line & DSM. Secure well & clean up cellar area. Release Rig 9ES from V-114a @ 09:00 Hrs on November 22, 2003. Printed: 11/24/2003 8:32:44 AM SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Borealis Well. . . . . . . . . . . . . . . . . . . . .: V-114A API number...... .........: 50-029-23178-01 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..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 53.30 ft KB above permanent. . . . . . . : N/A (Topdrive) DF above permanent.. .....: 81.80 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 rotary table to target: 73.01 degrees 14-Nov-2003 17:12:16 Spud date.. . . . . . . . . . . . . . . : Last survey date... ......: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 8 22-0ct-03 14-Nov-03 192 0.00 ft 11444.00 ft . ----- Geomagnetic data ---------------------- Magnetic model..... ......: BGGM version 2003 Magnetic date............: 04-Nov-2003 Magnetic field strength..: 1151.01 HCNT Magnetic dec (+E/W-) .....: 25.21 degrees Magnetic dip....... ......: 80.81 degrees ----- MWD survey Reference Reference G..............: Reference H...... ........: Reference Dip............: Tolerance of G.... .......: Tolerance of H... ........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1151.01 HCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.21 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.21 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 . SCHLUMBERGER Survey Report 14-Nov-2003 17:12:16 Page 2 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Inc1 Azimuth Course TVD Vertical Disp1 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) 100£) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 257.92 0.66 188.16 257.92 257.91 -0.63 -1.47 -0.21 1.49 188.16 0.26 MWD IFR MSA - 3 287.55 0.77 186.67 29.63 287.54 -0.78 -1.84 -0.26 1. 86 188.00 0.38 MWD IFR MSA - 4 381.25 2.32 208.52 93.70 381.21 -2.39 -4.13 -1. 24 4.31 196.68 1. 74 MWD IFR MSA - 5 473.70 4.74 210.44 92.45 473.47 -6.54 -9.07 -4.07 9.94 204.15 2.62 MWD IFR MSA 6 565.46 7.84 212.40 91.76 564.67 -14.08 -17.62 -9.34 19.94 207.93 3.39 MWD IFR MSA . - 7 657.43 10.67 215.33 91.97 655.43 -25.59 -29.87 -17.63 34.68 210.55 3.12 MWD IFR MSA - 8 749.24 13.99 214.36 91.81 745.11 -40.98 -45.97 -28.81 54.25 212.08 3.62 MWD IFR MSA - 9 841. 20 15.77 215.34 91.96 833.99 -59.56 -65.34 -42.31 77.84 212.93 1. 95 MWD IFR MSA - 10 936.17 18.04 214.56 94.97 924.85 -81.29 -87.98 -58.12 105.44 213.45 2.40 MWD IFR MSA 11 1029.75 22.17 212.33 93.58 1012.71 -106.04 -114.84 -75.79 137.60 213.42 4.49 MWD IFR MSA - 12 1120.79 25.06 211.25 91.04 1096.11 -133.46 -145.85 -94.98 174.05 213.07 3.21 MWD IFR MSA - 13 1214.58 27.00 211.29 93.79 1180.39 -164.17 -181.03 -116.35 215.19 212.73 2.07 MWD IFR MSA - 14 1309.05 27.89 211.55 94.47 1264.22 -196.73 -218.18 -139.05 258.72 212.51 0.95 MWD IFR MSA 15 1402.90 28.41 211 . 94 93.85 1346.97 -230.01 -255.83 -162.34 302.99 212.40 0.59 MWD IFR MSA 16 1494.98 29.78 212.38 92.08 1427.43 -263.88 -293.73 -186.18 347.77 212.37 1. 51 MWD IFR MSA - 17 1591.68 30.29 212.11 96.70 1511.15 -300.54 -334.67 -212.00 396.17 212.35 0.55 MWD IFR MSA - 18 1684.09 29.77 212.49 92 .41 1591.15 -335.60 -373.76 -236.71 442.42 212.35 0.60 MWD IFR MSA - 19 1778.40 29.19 212.69 94.31 1673.25 -370.93 -412.87 -261.71 488.83 212.37 0.62 MWD IFR MSA - 20 1870.19 28.53 213.23 91.79 1753.64 -404.84 -450.04 -285.81 533.13 212.42 0.77 MWD IFR MSA 21 1961. 11 29.87 213.90 90.92 1833.00 -439.10 -487.00 -310.34 577.47 212.51 1. 52 MWD IFR MSA . - 22 2054.48 29.79 214.49 93.37 1914.00 -475.29 -525.41 -336.44 623.90 212.63 0.33 MWD IFR MSA - - 23 2148.61 31.01 212.33 94.13 1995.19 -511.97 -565.18 -362.65 671.52 212.69 1. 74 MWD IFR MSA - - 24 2241.64 30.74 211.67 93.03 2075.04 -548.00 -605.66 -387.95 719.26 212.64 0.47 MWD IFR MSA - 25 2335.80 30.20 211.30 94.16 2156.20 -583.74 -646.38 -412.89 766.99 212.57 0.61 MWD IFR MSA 26 2429.70 29.60 212.08 93.90 2237.60 -618.90 -686.21 -437.48 813.80 212.52 0.76 MWD IFR MSA 27 2523.88 29.24 211.72 94.18 2319.63 -653.75 -725.48 -461.92 860.06 212.49 0.43 MWD IFR MSA - 28 2617.94 29.48 212.09 94.06 2401.61 -688.50 -764.63 -486.30 906.17 212.46 0.32 MWD IFR MSA - 29 2711.16 29.07 211.75 93.22 2482.92 -722.86 -803.32 -510.40 951.75 212.43 0.47 MWD IFR MSA - 30 2804.57 29.90 212.28 93.41 2564.24 -757.56 -842.30 -534.77 997.73 212.41 0.93 MWD IFR MSA SCHLUMBERGER Survey Report 14-Nov-2003 17:12:16 Page 3 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Inc1 Azimuth Course TVD Vertical Disp1 Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2897.91 30.20 213.95 93.34 2645.03 -793.42 -881.45 -560.31 1044.46 212.44 0.95 MWD IFR MSA - 32 3015.13 28.63 214.17 117.22 2747.14 -838.19 -929.14 -592.55 1102.01 212.53 1. 34 MWD IFR MSA - 33 3108.41 29.61 215.56 93.28 2828.63 -873.89 -966.38 -618.50 1147.36 212.62 1.28 MWD IFR MSA 34 3201.92 31.53 213 .14 93.51 2909.14 -911.00 -1005.65 -645.31 1194.89 212.69 2.44 MWD IFR MSA - 35 3294.32 32.33 207.87 92.40 2987.57 -946.98 -1047.73 -670.07 1243.68 212.60 3.14 MWD IFR MSA 36 3388.10 32.40 202.80 93.78 3066.80 -980.75 -1093.07 -691.54 1293.45 212.32 2.89 MWD IFR MSA - . 37 3480.98 33.74 199.18 92.88 3144.64 -1011.91 -1140.38 -709.65 1343.16 211.89 2.57 MWD IFR MSA - 38 3574.42 34.03 197.16 93.44 3222.21 -1041.90 -1189.87 -725.89 1393.81 211.39 1.24 MWD IFR MSA - 39 3668.22 32.99 195.61 93.80 3300.42 -1070.39 -1239.55 -740.51 1443.89 210.85 1.44 MWD IFR MSA - 40 3761.20 32.95 194.09 92.98 3378.43 -1097.09 -1288.45 -753.48 1492.59 210.32 0.89 MWD IFR MSA 41 3854.83 32.47 194.10 93.63 3457.21 -1123.21 -1337.53 -765.80 1541.24 209.79 0.51 MWD IFR MSA - 42 3949.05 31. 88 193.81 94.22 3536.96 -1149.01 -1386.22 -777.90 1589.57 209.30 0.65 MWD IFR MSA 43 4041.71 32.70 194.96 92.66 3615.29 -1174.78 -1434.16 -790.20 1637.45 208.85 1.11 MWD IFR MSA 44 4135.13 32.75 195.66 93.42 3693.88 -1201.77 -1482.87 -803.54 1686.59 208.45 0.41 MWD IFR MSA 45 4228.17 32.08 194.76 93.04 3772.43 -1228.35 -1531. 00 -816.63 1735.17 208.08 0.89 MWD IFR MSA 46 4320.77 31.71 194.34 92.60 3851.05 -1253.94 -1578.35 -828.92 1782.78 207.71 0.47 MWD IFR MSA - 47 4413.70 32.87 195.79 92.93 3929.60 -1280.30 -1626.28 -841. 83 1831. 25 207.37 1. 50 MWD IFR MSA - 48 4507.16 34.07 196.54 93.46 4007.56 -1308.49 -1675.79 -856.18 1881.84 207.06 1. 36 MWD IFR MSA - 49 4600.80 34.12 196.74 93.64 4085.11 -1337.56 -1726.08 -871.22 1933.48 206.78 0.13 MWD IFR MSA 50 4694.47 34.15 194.91 93.67 4162.64 -1366.04 -1776.64 -885.55 1985.11 206.49 1.10 MWD IFR MSA 51 4787.31 33.28 195.75 92.84 4239.87 -1393.59 -1826.34 -899.17 2035.69 206.21 1. 06 MWD IFR MSA . 52 4881.13 32.72 196.62 93.82 4318.55 -1421. 55 -1875.41 -913.41 2086.02 205.97 0.78 MWD IFR MSA 53 4974.97 32.52 196.63 93.84 4397.59 -1449.55 -1923.89 -927.88 2135.95 205.75 0.21 MWD IFR MSA - 54 5068.65 32.30 196.36 93.68 4476.68 -1477.25 -1972.03 -942.14 2185.52 205.54 0.28 MWD IFR MSA - 55 5162.51 32.10 196.25 93.86 4556.10 -1504.71 -2020.03 -956.18 2234.91 205.33 0.22 MWD IFR MSA 56 5255.30 32.24 195.76 92.79 4634.65 -1531.61 -2067.52 -969.80 2283.67 205.13 0.32 MWD IFR MSA - 57 5348.47 31.93 194.86 93.17 4713.59 -1558.06 -2115.25 -982.87 2332.45 204.92 0.61 MWD IFR MSA - 58 5441.04 31.42 194.95 92.57 4792.37 -1583.74 -2162.23 -995.37 2380.33 204.72 0.55 MWD IFR MSA - 59 5535.04 31.05 194.39 94.00 4872.74 -1609.33 -2209.38 -1007.72 2428.34 204.52 0.50 MWD IFR MSA - 60 5628.07 30.90 194.94 93.03 4952.50 -1634.45 -2255.70 -1019.84 2475.53 204.33 0.34 MWD IFR MSA SCHLUMBERGER Survey Report 14-Nov-2003 17:12:16 Page 4 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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) 100£) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5721.85 31.34 190.90 93.78 5032.80 -1658.60 -2302.92 -1030.66 2523.03 204.11 2.28 MWD IFR MSA - 62 5815.62 31.79 182.37 93.77 5112.73 -1678.21 -2351.57 -1036.29 2569.78 203.78 4.78 MWD IFR MSA - 63 5908.35 32.92 175.33 92.73 5191.09 -1691. 68 -2401.11 -1035.25 2614.78 203.32 4.24 MWD IFR MSA 64 6001.95 31.10 171.25 93.60 5270.47 -1700.58 -2450.36 -1029.50 2657.84 202.79 3.02 MWD IFR MSA - 65 6095.01 29.59 164.07 93.06 5350.80 -1704.45 -2496.22 -1019.54 2696.40 202.22 4.22 MWD IFR MSA 66 6188.44 29.83 158.18 93.43 5431.97 -1702.92 -2539.99 -1004.57 2731.43 201.58 3.13 MWD IFR MSA . - 67 6283.14 30.90 153.33 94.70 5513 . 69 -1696.85 -2583.59 -984.89 2764.95 200.87 2.82 MWD IFR MSA - 68 6377.25 32.84 149.24 94.11 5593.62 -1686.71 -2627.12 -960.99 2797.37 200.09 3.08 MWD IFR MSA - 69 6470.36 35.18 140.95 93.11 5670.84 -1670.61 -2669.68 -931.16 2827.41 199.23 5.57 MWD IFR MSA 70 6563.60 37.88 130.77 93.24 5745.82 -1645.23 -2709.27 -892.52 2852.50 198.23 7.11 MWD IFR MSA 71 6656.63 39.33 122.82 93.03 5818.57 -1610.94 -2743.92 -846.08 2871. 41 197.14 5.55 MWD IFR MSA - 72 6749.03 37.27 117.21 92.40 5891.10 -1571.97 -2772.60 -796.57 2884.76 196.03 4.37 MWD IFR MSA 73 6843.14 35.41 110.71 94.11 5966.93 -1529.95 -2795.28 -745.70 2893.04 194.94 4.54 MWD IFR MSA - 74 6937.17 38.43 106.23 94.03 6042.11 -1483.93 -2813.09 -692.14 2896.99 193.82 4.30 MWD IFR MSA - 75 7029.75 42.47 105.94 92.58 6112.55 -1433.61 -2829.72 -634.44 2899.97 192.64 4.37 MWD IFR MSA 76 7123.42 48.32 106.40 93.67 6178.29 -1377.81 -2848.30 -570.42 2904.86 191.32 6.26 MWD IFR MSA - 77 7217.07 54.02 106.13 93.65 6236.99 -1316.82 -2868.72 -500.41 2912.04 189.89 6.09 MWD IFR MSA - 78 7309.62 59.95 105.01 92.55 6287.40 -1251.43 -2889.51 -425.68 2920.70 188.38 6.49 MWD IFR MSA - 79 7403.95 66.32 103.15 94.33 6330.00 -1179.38 -2909.94 -344.10 2930.21 186.74 6.98 MWD IFR MSA - 80 7497.83 66.36 96 .21 93.88 6367.72 -1102.60 -2924.38 -259.40 2935.86 185.07 6.77 MWD IFR MSA 81 7589.99 65.42 92.51 92 .16 6405.37 -1024.28 -2930.79 -175.55 2936.04 183.43 3.80 MWD IFR MSA . - 82 7683.39 66.16 92.39 93.40 6443.67 -943.95 -2934.43 -90.44 2935.82 181.77 0.80 MWD IFR MSA 83 7776.36 65.63 92.19 92.97 6481.64 -863.84 -2937.82 -5.65 2937.82 180.11 0.60 MWD IFR MSA - 84 7869.05 64.51 92.44 92.69 6520.71 -784.52 -2941.21 78.34 2942.25 178.47 1.23 MWD IFR MSA - 85 7962.85 65.33 92.73 93.80 6560.47 -704.47 -2945.04 163.21 2949.56 176.83 0.92 MWD IFR MSA 86 8056.33 66.73 94.92 93.48 6598.45 -624.64 -2950.75 248.43 2961.19 175.19 2.61 MWD IFR MSA - 87 8151.47 67.97 95.06 95.14 6635.09 -543.22 -2958.39 335.89 2977.40 173.52 1. 31 MWD IFR MSA - 88 8221.00 67.29 96.07 69.53 6661.55 -483.84 -2964.62 399.89 2991.47 172.32 1. 66 MWD ZERO - 89 8233.00 69.10 95.38 12.00 6666.01 -473.57 -2965.73 410.97 2994.07 172.11 16.00 MWD ZERO - 90 8266.79 71.74 93.89 33.79 6677 . 33 -443.97 -2968.30 442.70 3001.13 171 . 52 8.85 MWD TREND SCHLUMBERGER Survey Report 14-Nov-2003 17:12:16 Page 5 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8298.01 74.82 92.55 31. 22 6686.31 -415.92 -2969.98 472.55 3007.34 170.96 10.69 MWD TREND 92 8328.86 77.96 91.27 30.85 6693.57 -387.55 -2970.97 502.51 3013.17 170.40 10.95 MWD TREND 93 8360.77 81.16 89.97 31.91 6699.36 -357.65 -2971.31 533.89 3018.90 169.81 10.80 MWD TREND 94 8392.48 84.14 88.69 31.71 6703.41 -327.47 -2970.94 565.33 3024.25 169.23 10.21 MWD IFR MSA - 95 8424.33 87.06 89.68 31.85 6705.86 -296.97 -2970.49 597.08 3029.91 168.63 9.68 MWD IFR MSA 96 8448.72 89.64 86.56 24.39 6706.56 -273.44 -2969.69 621. 44 3034.02 168.18 16.59 MWD IFR MSA - . 97 8480.54 91.80 86.51 31.82 6706.16 -242.51 -2967.77 653.20 3038.80 167.59 6.79 MWD IFR MSA 98 8512.82 94.20 84.84 32.28 6704.47 -211.06 -2965.34 685.34 3043.51 166.99 9.05 MWD IFR MSA - 99 8544.60 94.20 80.58 31.78 6702.14 -179.83 -2961.32 716.77 3046.83 166.39 13.37 MWD IFR MSA 100 8576.29 94.10 78.18 31. 69 6699.85 -148.42 -2955.49 747.83 3048.64 165.80 7.56 MWD IFR MSA 101 8607.25 94.30 77.24 30.96 6697.58 -117.64 -2948.92 778.00 3049.82 165.22 3.10 MWD IFR MSA - 102 8637.10 93.75 74.90 29.85 6695.48 -87.91 -2941.75 806.90 3050.41 164.66 8.03 MWD IFR_MSA 103 8669.05 93.41 72.27 31.95 6693.49 -56.03 -2932.74 837.49 3049.98 164.06 8.28 MWD IFR MSA 104 8700.20 94.20 70.34 31.15 6691. 42 -24.96 -2922.78 866.93 3048.64 163.48 6.68 MWD IFR MSA - 105 8732.29 92.11 67.68 32.09 6689.65 7.00 -2911.31 896.84 3046.31 162.88 10.53 MWD IFR MSA 106 8763.41 89.81 66.35 31.12 6689.13 37.94 -2899.16 925.48 3043.29 162.30 8.54 MWD IFR MSA - 107 8792.84 88.13 64.19 29.43 6689.66 67.09 -2886.85 952.20 3039.83 161.75 9.30 MWD IFR MSA - 108 8824.31 88.02 64.64 31.47 6690.72 98.19 -2873.26 980.57 3035.98 161.16 1.47 MWD IFR MSA - 109 8855.94 90.77 71. 56 31.63 6691.05 129.68 -2861.48 1009.90 3034.46 160.56 23.54 MWD IFR MSA - 110 8894.29 89.05 73.46 38.35 6691.11 168.03 -2849.95 1046.47 3036.00 159.84 6.68 MWD IFR MSA 111 8917.48 87.75 73.45 23.19 6691.76 191.21 -2843.35 1068.69 3037.56 159.40 5.61 MWD IFR MSA . 112 8948.51 86.65 72.19 31.03 6693.28 222.20 -2834.20 1098.30 3039.56 158.82 5.39 MWD IFR MSA - 113 8980.18 86.72 74.09 31.67 6695.11 253.81 -2825.03 1128.56 3042.11 158.22 5.99 MWD IFR MSA - 114 9011.41 87.54 76.64 31.23 6696.67 284.98 -2817.15 1158.73 3046.14 157.64 8.57 MWD IFR MSA - 115 9043.85 88.26 79.96 32.44 6697.86 317.25 -2810.57 1190.47 3052.30 157.04 10.47 MWD IFR MSA 116 9073.52 88.78 82.30 29.67 6698.63 346.61 -2806.00 1219.78 3059.66 156.51 8.08 MWD IFR MSA - 117 9103.88 87.52 81. 21 30.36 6699.61 376.60 -2801.65 1249.81 3067.78 155.96 5.49 MWD IFR MSA - 118 9134.18 87.52 78.37 30.30 6700.92 406.66 -2796.29 1279.59 3075.15 155.41 9.36 MWD IFR MSA - 119 9164.89 88.62 77.46 30.71 6701.95 437.24 -2789.86 1309.61 3081.94 154.85 4.65 MWD IFR MSA - 120 9196.15 89.13 76.58 31.26 6702.57 468.42 -2782.84 1340.06 3088.68 154.29 3.25 MWD IFR MSA SCHLUMBERGER Survey Report 14-Nov-2003 17:12:16 Page 6 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Inc1 Azimuth Course TVD Vertical Disp1 Disp1 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) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 9227.53 87.66 72.99 31.38 6703.45 499.76 -2774.61 1370.32 3094.55 153.72 12.36 MWD IFR MSA - 122 9258.41 88.10 71. 50 30.88 6704.59 530.62 -2765.20 1399.71 3099.28 153.15 5.03 MWD IFR MSA - 123 9289.48 86.87 67.09 31.07 6705.95 561.58 -2754.23 1428.74 3102.75 152.58 14.72 MWD IFR MSA - 124 9321.84 87.90 62.83 32.36 6707.43 593.58 -2740.55 1458.02 3104.26 151. 99 13.53 MWD IFR MSA 125 9353.36 88.21 62.64 31.52 6708.50 624.58 -2726.12 1486.02 3104.83 151. 40 1.15 MWD IFR MSA 126 9385.73 88.48 63.70 32.37 6709.44 656.46 -2711.51 1514.90 3106.00 150.81 3.38 MWD IFR MSA . - 127 9415.59 89.72 66.46 29.86 6709.90 686.03 -2698.94 1541.97 3108.36 150.26 10.13 MWD IFR MSA - 128 9447.23 87.62 67.99 31.64 6710.64 71 7.50 -2686.69 1571.13 3112.36 149.68 8.21 MWD IFR MSA - 129 9478.33 86.42 68.96 31.10 6712.26 748.46 -2675.30 1600.02 3117.26 149.12 4.96 MWD IFR MSA - 130 9510.82 88.21 70.35 32.49 6713.78 780.85 -2664.01 1630.45 3123.35 148.53 6.97 MWD IFR MSA 131 9542.17 88.10 71.14 31. 35 6714.79 812.16 -2653.68 1660.03 3130.13 147.97 2.54 MWD IFR MSA - 132 9571.17 87.39 71.94 29.00 6715.93 841.13 -2644.51 1687.52 3137.06 147.46 3.69 MWD IFR MSA - 133 9601.77 86.08 73.04 30.60 6717.67 871.68 -2635.31 1716.65 3145.12 146.92 5.59 MWD IFR MSA - 134 9633.80 82.60 72.02 32.03 6720.83 903.54 -2625.75 1747.05 3153.84 146.36 11.32 MWD IFR MSA - 135 9664.89 81.84 69.97 31.09 6725.04 934.33 -2615.72 1776.17 3161.77 145.82 6.98 MWD IFR MSA 136 9696.18 82.14 70.37 31. 29 6729.40 965.27 -2605.21 1805.32 3169.59 145.28 1. 59 MWD IFR MSA - 137 9726.49 82.49 68.75 30.31 6733.45 995.26 -2594.72 1833.46 3177.13 144.75 5.42 MWD IFR MSA - 138 9757.41 82.32 67.60 30.92 6737.54 1025.80 -2583.32 1861. 92 3184.38 144.22 3.73 MWD IFR MSA - 139 9789.35 82.74 65.62 31.94 6741.69 1057.26 -2570.75 1890.98 3191.33 143.66 6.29 MWD IFR MSA - 140 9820.34 84.32 66.02 30.99 6745.18 1087.81 -2558.14 1919.07 3197.95 143.12 5.26 MWD IFR MSA 141 9850.45 87.18 64.70 30.11 6747.42 1117.57 -2545.62 1946.36 3204.45 142.60 10.46 MWD IFR MSA . - 142 9881.89 87.63 63.48 31.44 6748.84 1148.60 -2531.90 1974.61 3210.85 142.05 4.13 MWD IFR MSA - 143 9913 .24 87.63 64.09 31.35 6750.14 1179.52 -2518.06 2002.71 3217.37 141. 50 1. 94 MWD IFR MSA - 144 9943.82 88.00 62.58 30.58 6751. 30 1209.64 -2504.35 2030.02 3223.78 140.97 5.08 MWD IFR MSA - 145 9975.73 88.24 62.41 31. 91 6752.35 1240.99 -2489.62 2058.31 3230.30 140.42 0.92 MWD IFR MSA 146 10007.48 88.82 62.65 31.75 6753.16 1272.20 -2474.98 2086.47 3237.11 139.87 1. 98 MWD IFR MSA - 147 10038.23 89.37 62.83 30.75 6753.65 1302.46 -2460.89 2113.80 3244.09 139.34 1. 88 MWD IFR MSA 148 10069.74 89.72 62.37 31. 51 6753.90 1333.45 -2446.39 2141.77 3251.47 138.80 1. 83 MWD IFR MSA 149 10100.64 89.96 62.57 30.90 6753.98 1363.83 -2432.11 2169.17 3258.91 138.27 1. 01 MWD IFR MSA - 150 10131.44 89.34 62.13 30.80 6754.17 1394.09 -2417.82 2196.46 3266.54 137.75 2.47 MWD IFR MSA SCHLUMBERGER Survey Report 14-Nov-2003 17:12:16 Page 7 of 8 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 151 10162.80 89.78 61.61 31.36 6754.41 1424.86 -2403.03 2224.11 3274.33 137.21 2.17 MWD IFR MSA - 152 10194.39 90.23 63.08 31.59 6754.41 1455.91 -2388.37 2252.09 3282.72 136.68 4.87 MWD IFR MSA - 153 10226.54 91.16 63.92 32.15 6754.02 1487.61 -2374.03 2280.86 3292.16 136.15 3.90 MWD IFR MSA - 154 10258.57 92.01 68.76 32.03 6753.13 1519.40 -2361.18 2310.18 3303.35 135.63 15.34 MWD IFR MSA 155 10288.00 92.29 70.98 29.43 6752.03 1548.77 -2351.06 2337.79 3315.53 135.16 7.60 MWD IFR MSA 156 10318.94 93.22 73.16 30.94 6750.54 1579.66 -2341.55 2367.19 3329.63 134.69 7.65 MWD IFR MSA - . 157 10350.29 92.70 72.83 31.35 6748.92 1610.97 -2332.39 2397.13 3344.59 134.22 1. 96 MWD IFR MSA - 158 10381.09 93.42 73.50 30.80 6747.28 1641.73 -2323.49 2426.57 3359.58 133.76 3.19 MWD IFR MSA - 159 10410.80 92.56 73.15 29.71 6745.73 1671. 40 -2314.97 2454.99 3374.32 133.32 3.12 MWD IFR MSA - 160 10442.34 92.80 73.86 31.54 6744.26 1702.90 -2306.03 2485.20 3390.27 132.86 2.37 MWD IFR MSA 161 10474.58 93.11 74.22 32.24 6742.59 1735.09 -2297.17 2516.15 3407.06 132.40 1.47 MWD IFR MSA - 162 10505.40 93.15 74.47 30.82 6740.91 1765.86 -2288.87 2545.79 3423.44 131.96 0.82 MWD IFR MSA - 163 10537.12 91.91 73.42 31.72 6739.51 1797.54 -2280.11 2576.24 3440.33 131.51 5.12 MWD IFR MSA 164 10567.99 89.65 73.07 30.87 6739.09 1828.41 -2271.21 2605.79 3456.67 131.08 7.41 MWD IFR MSA - 165 10598.99 88.31 72.24 31. 00 6739.64 1859.40 -2261.97 2635.38 3473.00 13 0.64 5.08 MWD IFR MSA 166 10630.88 89.24 72.82 31.89 6740.32 1891.28 -2252.40 2665.79 3489.95 130.20 3.44 MWD IFR MSA - 167 10661.89 89.03 70.23 31.01 6740.79 1922.27 -2242.57 2695.19 3506.17 129.76 8.38 MWD IFR MSA 168 10693.91 89.20 70.10 32.02 6741.29 1954.25 -2231.71 2725.31 3522.48 129.31 0.67 MWD IFR MSA 169 10724.33 88.07 68.43 30.42 6742.01 1984.60 -2220.94 2753.75 3537.76 128.89 6.63 MWD IFR MSA - 170 10756.09 88.11 71.66 31.76 6743.07 2016.29 -2210.11 2783.58 3554.28 128.45 10.17 MWD IFR MSA 171 10786.80 89.06 75.26 30.71 6743.83 2046.99 -2201.37 2813.01 3571.98 128.05 12.12 MWD IFR MSA . - 172 10815.62 88.21 73.75 28.82 6744.51 2075.79 -2193.68 2840.77 3589.18 127.68 6.01 MWD IFR MSA - 173 10846.80 88.66 74.85 31.18 6745.37 2106.95 -2185.24 2870.78 3607.86 127.28 3.81 MWD IFR MSA - 174 10877.72 88.90 75.52 30.92 6746.02 2137.84 -2177.34 2900.66 3626.93 126.89 2.30 MWD IFR MSA 175 10909.65 90.75 76.18 31.93 6746.12 2169.73 -2169.53 2931. 62 3647.09 126.50 6.15 MWD IFR MSA 176 10941.45 91. 27 76.89 31.80 6745.56 2201.46 -2162.13 2962.54 3667.62 126.12 2.77 MWD IFR MSA - 177 10973.49 91.99 77.04 32.04 6744.65 2233.41 -2154.90 2993.75 3688.65 125.75 2.30 MWD IFR MSA - 178 11003.57 91.92 77 .41 30.08 6743.62 2263.39 -2148.26 3023.06 3708.63 125.40 1.25 MWD IFR MSA - 179 11034.91 92.36 77.25 31.34 6742.45 2294.62 -2141. 39 3053.62 3729.63 125.04 1.49 MWD IFR MSA - 180 11065.87 92.64 77.12 30.96 6741.10 2325.47 -2134.53 3083.78 3750.45 124.69 1. 00 MWD IFR MSA ~ SCHLUMBERGER Survey Report 14-Nov-2003 17:12:16 Page 8 of 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 181 11096.72 92.12 77.09 30.85 6739.82 2356.21 -2127.65 3113.82 3771.31 124.34 1. 69 MWD IFR MSA 182 11127.94 92.09 76.91 31. 22 6738.67 2387.34 -2120.63 3144.22 3792.52 124.00 0.58 MWD IFR MSA - 183 11159.55 91.09 76.94 31.61 6737.80 2418.86 -2113.48 3175.00 3814.11 123.65 3.17 MWD IFR MSA - 184 11191.66 90.72 76.84 32.11 6737.29 2450.89 -2106.20 3206.27 3836.18 123.30 1.19 MWD IFR MSA - 185 11223.01 91. 44 75.45 31.35 6736.70 2482.19 -2098.69 3236.70 3857.56 122.96 4.99 MWD IFR MSA 186 11253.27 91.06 75.04 30.26 6736.04 2512.42 -2090.99 3265.96 3877.98 122.63 1. 85 MWD IFR MSA . - 187 11285.40 88.73 74.05 32.13 6736.10 2544.54 -2082.43 3296.92 3899.51 122.28 7.88 MWD IFR MSA - 188 11316.49 90.27 75.88 31.09 6736.37 2575.60 -2074.36 3326.95 3920.66 121.94 7.69 MWD IFR MSA - 189 11346.93 91.88 74.86 30.44 6735.80 2606.01 -2066.68 3356.39 3941. 64 121.62 6.26 MWD IFR MSA - 190 11377.62 92.88 76.10 30.69 6734.52 2636.65 -2058.99 3386.08 3962.95 121.30 5.19 MWD IFR MSA 191 11395.50 94.39 75.11 17.88 6733.39 2654.47 -2054.55 3403.36 3975.43 121.12 10.09 MWD IFR MSA 192 11444.00 94.39 75.11 48.50 6729.68 2702.80 -2042.13 3450.09 4009.17 120.62 0.00 Projected to TD [(c)2003 IDEAL ID8 1C_OIJ . . . bp Report Date: 14-Nov-03 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure/Slot: Y-Padl Plan Y-114 (S-G) Well: Y-114 Borehole: Y-114A UWVAPI#: 500292317801 Survey Name/ Dale: Y-114A / November 14, 2003 Tort / AHD I DDI / ERD raUo: 364.556' / 7546.23 ft / 6.668 / 1.117 Grid Coordinate System: NAD27 Alaska State Planes. Zone 04, US Feet Location LaVLong: N 70 19 38.972, W 149 15 57.365 Location Grid WE Y/X: N 5969895.720 nus, E 590514.780 nus Grid Convergence Angle: +0.69122375' Grid Scale Factor: 0.99990931 V-114A Survey Report Survey / DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 73.010' Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: KB TVD Reference Elevallon: 81.80 ft relative 10 MSL sea Bed / Ground Level Elevation: 53.30 ft relative to MSL Magnetic Declination: 25.193' Total Reid Strength: 57550.125 nT Magnetic Dip: 80.808' Declination Dale: November 15, 2003 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North·> True North: +25. 1 93' Locat Coordinates Referenced To: Well Head Schlumberg8r 565.46 7.84 212.40 564.67 482.87 -14.08 -17.62 -9.34 3.39 3.38 2.14 5969877.99 590505.65 N 70 19 38.799 W 149 1557.638 657.43 10.67 215.33 655.43 573.63 -25.59 -29.87 -17.63 3.12 3.08 3.19 5969865.65 590497.52 N 70 1938.678 W 149 1557.880 749.24 13.99 214.36 745.11 663.31 ·40.98 -45.97 -28.81 3.62 3.62 ·1.06 5969849.41 590486.53 N 70 1938.520 W 1491558.206 841.20 15.77 215.34 833.99 752.19 -59.56 -65.34 -42.31 1.95 1.94 1.07 5969829.88 590473.26 N 70 1938.329 W 149 1558.600 936.17 18.04 214.56 924.85 843.05 -81.29 -87.98 -58.12 2.40 2.39 -0.82 5969807.05 590457.73 N 70 1938.107 W 149 15 59.062 1029.75 22.17 212.33 1012.71 930.91 -106.04 -114.84 -75.79 4.49 4.41 -2.38 5969779.98 590440.39 N 70 19 37.842 W 149 15 59.578 1120.79 25.06 211.25 1096.11 1014.31 -133.46 -145.85 -94.98 3.21 3.17 -1.19 5969748.75 590421.57 N 70 19 37.537 W 149 160.138 1214.58 27.00 211.29 1180.39 1098.59 -164.17 ·181.03 -116.35 2.07 2.07 0.04 5969713.32 590400.63 N 70 19 37.191 W 149 160.761 1309.05 27.89 211.55 1264.22 1182.42 -196.73 -218.18 -139.05 0.95 0.94 0.28 5969675.90 590378.39 N 70 19 36.826 W 149 161.424 1402.90 28.41 211.94 1346.97 1265.17 -230.01 -255.83 -162.34 0.59 0.55 0.42 5969637.97 590355.55 N 70 19 36.456 W149162.104 1494.98 29.78 212.38 1427.43 1345.63 -263.88 -293.73 -186.18 1.51 1.49 0.48 5969599.79 590332.17 N 70 19 36.083 W 149 162.800 1591.68 30.29 212.11 151'1.15 1429.35 -300.54 -334.67 -212.00 0.55 0.53 -0.28 5969558.55 590306.85 N 70 19 35.680 W 149 163.554 1684.09 29.77 212.49 1591.15 1509.35 -335.60 -373.76 -236.71 0.60 -0.56 0.41 5969519.16 590282.61 N 70 1935.296 W 149164.275 1778.40 29.19 212.69 1673.25 1591.45 -370.93 -412.87 -261.71 0.62 -0.61 0.21 5969479.77 590258.09 N 70 1934.911 W 149 165.005 1870.19 28.53 213.23 1753.64 1671.84 -404.84 -450.04 -285.81 0.77 -0.72 0.59 5969442.31 590234.44 N 70 1934.546 W 149 165.708 1961.11 29.87 213.90 1833.00 1751.20 -439.10 -487.00 -310.34 1.52 1.47 0.74 5969405.06 590210.37 N 70 1934.182 W 149 166.424 2054.48 29.79 214.49 1914.00 1832.20 -475.29 -525.41 -336.44 0.33 -0.09 0.63 5969366.34 590184.73 N 70 1933.804 W149167.186 2148.61 31.01 212.33 1995.19 1913.39 -511.97 -565.18 -362.65 1.74 1.30 -2.29 5969326.26 590159.01 N 70 1933.413 W 149 167.951 2241.64 30.74 211.67 2075.04 1993.24 -548.00 -605.66 -387.95 0.47 -0.29 -0.71 5969285.48 590134.20 N 70 1933.015 W 149 168.689 2335.80 30.20 211.30 2156.20 2074.40 -583.74 -646.38 -412.89 0.61 -0.57 -0.39 5969244.47 590109.76 N 70 1932.615 W 149 169.417 2429.70 29.60 212.08 2237.60 2155.80 -618.90 -686.21 -437.48 0.76 -0.64 0.83 5969204.35 590085.65 N 70 19 32.223 W 149 16 10.135 2523.88 29.24 211. 72 2319.63 2237.83 -653.75 -725.48 -461.92 0.43 -0.38 -0.38 5969164.79 590061.69 N 70 19 31.837 W 149 16 10.848 2617.94 29.48 212.09 2401.61 2319.81 -688.50 -764.63 -486.30 0.32 0.26 0.39 5969125.35 590037.79 N 70 19 31.452 W 1491611.560 2711.16 29.07 211.75 2482.92 2401.12 -722.86 -803.32 -510.40 0.47 -0.44 -0.36 5969086.37 590014.16 N 70 19 31.071 W 149 16 12.263 2804.57 29.90 212.28 2564.24 2482.44 -757.56 -842.30 -534.77 0.93 0.89 0.57 5969047.10 589990.25 N 70 19 30.688 W 149 16 12.975 2897.91 30.20 213.95 2645.03 2563.23 -793.42 -881.45 -560.31 0.95 0.32 1.79 5969007.66 589965.19 N 70 19 30.303 W 14916 13.720 3015.13 28.63 214.17 2747.14 2665.34 -838.19 -929.14 -592.55 1.34 -1.34 0.19 5988959.58 589933.54 N 70 1929.834 W 149 16 14.661 3108.41 29.61 215.56 2828.63 2746.83 -873.89 -966.38 -618.50 1.28 1.05 1.49 5968922.04 589908.04 N 70 1929.467 W 149 16 15.418 3201.92 31.53 213.14 2909.14 2827.34 -911.00 -1005.65 -645.31 2.44 2.05 -2.59 5968882.45 589881.71 N 70 19 29.081 W 149 16 16.200 3294.32 32.33 207.87 2987.57 2905.77 -946.98 -1047.73 -670.07 3.14 0.87 -5.70 5968840.08 589857.46 N 70 19 28.667 W 149 16 16.923 3388.10 32.40 202.80 3066.80 2985.00 -980.75 -1093.07 -691.54 2.89 0.07 -5.41 5988794.49 589836.54 N 70 19 28.221 W 1491617.549 3460.98 33.74 199.18 3144.64 3062.84 -1011.91 -1140.38 -709.65 2.57 1.44 -3.90 5968746.97 589819.00 N 70 1927.756 W 149 16 18.078 3574.42 34.03 197.16 3222.21 3140.41 -1041.90 -1189.87 -725.89 1.24 0.31 -2.16 5968697.29 589803.36 N 70 1927.269 W 149 16 18.552 3668.22 32.99 195.61 3300.42 3218.62 -1070.39 -1239.55 -740.51 1.44 -1.11 ·1.65 5968647.45 589789.34 N 70 19 26.781 W 149 16 18.979 3761.20 32.95 194.09 3378.43 3296.63 -1097.09 -1288.45 -753.48 0.89 -0.04 -1.63 5988598.39 589776.97 N 701926.300 W 149 16 19.357 3854.83 32.47 194.10 3457.21 3375.41 -1123.21 -1337.53 -765.80 0.51 -0.51 0.01 5968549.18 589765.24 N 70 19 25.817 W 1491619.716 3949.05 31.88 193.81 3536.96 3455.16 -1149.01 -1386.22 -777.90 0.65 -0.63 -0.31 5968500.35 589753.73 N 70 19 25.338 W 149 1620.069 4041.71 32.70 194.96 3615.29 3533.49 -1174.78 -1434.16 -790.20 1.11 0.88 1.24 5968452.26 589742.01 N 70 1924.867 W 149 1620.428 4135.13 32.75 195.66 3693.88 3612.08 -1201.77 -1482.87 -803.54 0.41 0.05 0.75 5968403.40 589729.26 N 70 1924.388 W 149 1620.817 4228.17 32.08 194.76 3772.43 3690.63 -1228.35 -1531.00 -816.63 0.89 -0.72 -0.97 5988355.13 589716.76 N701923.914 W1491621.199 4320.77 31.71 194.34 3851.05 3769.25 -1253.94 -1578.35 -828.92 0.47 -0.40 -0.45 5968307.63 589705.04 N 70 19 23.448 W 1491621.558 4413.70 32.87 195.79 3929.60 3847.80 -1280.30 -1626.28 -841.83 1.50 1.25 1.56 5968259.55 589692.71 N 70 19 22.977 W 1491621.935 4507.16 34.07 196.54 4007.57 3925.77 -1308.49 -1675.79 -856.18 1.36 1.28 0.80 5968209.88 589678.95 N 70 19 22.490 W 149 1622.353 4600.80 34.12 196.74 4085.11 4003.31 -1337.56 -1726.08 -871.22 0.13 0.05 0.21 5968159.42 589664.53 N701921.996 W1491622.792 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) Plan V-114 (S-G)IV-114IV-114AIV-114A Generated 11/25/20035:53 PM Page 1 of 4 . . 4694.47 34.15 194.91 4162.64 4080.84 -1366.04 -1776.64 -885.55 1.10 0.03 -1.95 5968108.69 589650.81 N 70 1921.498 W 1491623.210 4787.31 33.28 195.75 4239.87 4158.07 -1393.59 -1826.34 -899.17 1.06 -0.94 0.90 5968058.83 589637.79 N 70 1921.009 W 149 1623.607 4881.13 32.72 196.62 4318.55 4236.75 -1421.55 -1875.41 -913.41 0.78 -0.60 0.93 5968009.60 589624.15 N 70 1920.527 W 1491624.023 4974.97 32.52 196.63 4397.59 4315.79 -1449.55 -1923.89 -927.88 0.21 -0.21 0.01 5967960.96 589610.26 N 70 1920.050 W 1491624.445 5068.65 32.30 196.36 4476.68 4394.88 -1477.25 -1972.03 -942.14 0.28 -0.23 -0.29 5967912.65 589596.59 N 70 19 19.577 W 1491624.861 5162.51 32.10 196.25 4556.10 4474.30 -1504.71 -2020.03 -956.18 0.22 -0.21 -0.12 5967864.49 589583.13 N 70 19 19.104 W 149 1625.270 5255.30 32.24 195.76 4634.65 4552.85 -1531.61 -2067.52 -969.80 0.32 0.15 -0.53 5967818.84 589570.08 N 70 19 18.637 W 149 1625.668 5348.47 31.93 194.86 4713.59 4831.79 -1558.06 -2115.25 -982.87 0.61 -0.33 -0.97 5967768.96 589557.59 N 70 19 18.168 W 149 1626.049 5441.04 31.42 194.95 4792.37 4710.57 -1583.74 -2162.23 -995.37 0.55 -0.55 0.10 5967721.84 589545.66 N 70 19 17.706 W 149 1626.414 5535.04 31.05 194.39 4872.74 4790.94 -1609.33 -2209.38 -1007.72 0.50 -0.39 -0.60 5967674.55 589533.88 N 70 19 17.242 W 149 1626.774 5628.07 30.90 194.94 4952.50 4870.70 -1634.45 -2255.70 -1019.84 0.34 -0.16 0.59 5967628.09 589522.32 N 70 1916.787 W 149 1627.127 5721.85 31.34 190.90 5032.80 4951.00 -1658.60 -2302.92 -1030.66 2.28 0.47 -4.31 5967580.75 589512.07 N 70 19 16.322 W 149 1627.443 5815.62 31.79 182.37 5112.73 5030.93 -1678.21 -2351.57 -1036.29 4.78 0.48 -9.10 5967532.04 589507.02 N 70 1915.844 W 149 1627.607 5908.35 32.92 175.33 5191.09 5109.29 -1691.68 -2401.11 -1035.25 4.24 1.22 -7.59 5967482.52 589508.66 N 70 1915.357 W 149 1627.577 6001.95 31.10 171.25 5270.47 5188.67 -1700.58 -2450.36 -1029.50 3.02 -1.94 -4.36 5967433.35 589515.01 N 70 19 14.872 W 1491627.409 6095.01 29.59 164.07 5350.80 5269.00 -1704.45 -2496.22 -1019.54 4.22 -1.62 -7.72 5967387.61 589525.52 N 70 1914.421 W 1491627.118 6188.44 29.83 158.18 5431.97 5350.17 -1702.92 -2539.99 -1004.57 3.13 0.26 -6.30 5967344.03 589541.02 N 70 1913.991 W 149 1626.680 6283.14 30.90 153.33 5513.69 5431.89 -1696.85 -2583.59 -984.89 2.82 1.13 -5.12 5967300.68 589561.22 N 70 19 13.562 W 149 1626.106 6377.25 32.64 149.24 5593.62 5511.82 -1686.71 -2627.12 -960.99 3.08 2.06 -4.35 5967257.44 589585.64 N 70 19 13.134 W 149 1625.409 6470.36 35.18 140.95 5670.84 5589.04 -1670.61 -2669.68 -931.16 5.57 2.51 -8.90 5967215.25 589615.98 N 70 19 12.715 W 149 1624.538 6563.60 37.88 130.77 5745.82 5684.02 -1645.23 -2709.27 -892.52 7.11 2.90 -10.92 5967176.13 589655.09 N 70 19 12.326 W 149 1623.410 6656.63 39.33 122.82 5818.57 5736.77 -1610.94 -2743.93 -846.08 5.55 1.56 -8.55 5967142.04 589701.94 N 70 19 11.985 W 149 1622.055 6749.03 37.27 117.21 5891.10 5809.30 -1571.97 -2772.60 -796.57 4.37 -2.23 -6.07 5967113.97 589751.79 N 70 1911.703 W 1491620.610 6843.14 35.41 110.71 5966.93 5885.13 -1529.95 -2795.28 -745.70 4.54 -1.98 -6.91 5967091.91 589802.92 N 70 1911.480 W 1491619.126 6937.17 38.43 106.23 6042.11 5960.31 -1483.93 -2813.09 -692.14 4.30 3.21 -4.76 5967074.75 589856.69 N 70 1911.305 W 1491617.563 7029.75 42.47 105.94 6112.55 6030.75 -1433.61 -2829.72 -634.44 4.37 4.36 -0.31 5967058.81 589914.58 N 70 1911.142 W 1491615.879 7123.42 48.32 106.40 6178.29 6096.49 -1377.81 -2848.30 -570.42 6.26 6.25 0.49 5967041. 01 589978.81 N 70 19 10.959 W 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2702.80 -2042.13 3450.09 0.00 0.00 0.00 5967895.55 593988.93 N 70 19 18.880 W 1491416.677 Leaal DescriDtion: Sur1ace: 4649 FSL 1789 FEL S11 T11 N R11 E UM BHL: 2606 FSL 3620 FEL S12 T11N R11E UM Northing IY) [ftUSl 5969895.72 5967895.55 Eastina IX) [ftUSl 590514.78 593988.93 SurveyEditor Ver 3.1 RT-SP3.03·HF2.03 Bld( d031 rt-546 ) Plan V-114 (S-G)IV-114IV-114AIV-114A Generated 11/25/20035:53 PM Page 4 of 4 SCRLUMBERGER Survey report Client...................: BP Exploration (ALaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Borealis Well. ....................: V-114A PB1 API number............. ..: 50-029-23178-70 Engineer.. ...............: M. St Amour Rig: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 53.30 ft KB above permanent.......: N/A (Top Drive) DF above permanent.......: 81.80 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 rotary table to target: 168.30 degrees 2-Nov-2003 12:39:58 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 22-0ct-03 02-Nov-03 92 0.00 ft 8544.00 ft . ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2003 Magnetic date............: 22-0ct-2003 Magnetic field strength..: 1150.99 HCNT Magnetic dec (+E/W-).....: 25.22 degrees Magnetic dip.............: 80.81 degrees ----- MWD survey Reference Reference G..............: Reference H...... ........: Reference Dip............: Tolerance of G. ..........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1150.99 HCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.22 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.22 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 . SCHLUMBERGER Survey Report 2-Nov-2003 12:39:58 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 257.92 0.66 188.16 257.92 257.91 1.40 -1.47 -0.21 1.49 188.16 0.26 MWD IFR MSA 3 287.55 0.77 186.67 29.63 287.54 1. 75 -1.84 -0.26 1. 86 188.00 0.38 MWD IFR MSA - 4 381.25 2.32 208.52 93.70 381.21 3.79 -4.13 -1. 24 4.31 196.68 1. 74 MWD IFR MSA - 5 473.70 4.74 210.44 92.45 473.47 8.05 -9.07 -4.07 9.94 204.15 2.62 MWD IFR MSA - 6 565.46 7.84 212.40 91.76 564.67 15.36 -17.62 -9.34 19.94 207.93 3.39 MWD IFR MSA - 7 657.43 10.67 215.33 91.97 655.43 25.67 -29.87 -17.63 34.68 210.55 3.12 MWD IFR MSA - . 8 749.24 13.99 214.36 91. 81 745.11 39.17 -45.97 -28.81 54.25 212.08 3.62 MWD IFR MSA - 9 841. 20 15.77 215.34 91.96 833.99 55.40 -65.34 -42.31 77.84 212.93 1. 95 MWD IFR MSA 10 936.17 18.04 214.56 94.97 924.85 74.36 -87.98 -58.12 105.44 213.45 2.40 MWD IFR MSA - 11 1029.75 22.17 212.33 93.58 1012.71 97.09 -114.84 -75.79 137.60 213.42 4.49 MWD IFR MSA - 12 1120.79 25.06 211. 25 91.04 1096 .11 123.56 -145.85 -94.98 174.05 213.07 3.21 MWD IFR MSA - 13 1214.58 27.00 211.29 93.79 1180.39 153.67 -181.03 -116.35 215.19 212.73 2.07 MWD IFR MSA 14 1309.05 27.89 211. 55 94.47 1264.22 185.45 -218.18 -139.05 258.72 212.51 0.95 MWD IFR MSA - 15 1402.90 28.41 211 . 94 93.85 1346.97 217.60 -255.83 -162.34 302.99 212.40 0.59 MWD IFR MSA - 16 1494.98 29.78 212.38 92.08 1427.43 249.88 -293.73 -186.18 347.77 212.37 1. 51 MWD IFR MSA - 17 1591.68 30.29 212.11 96.70 1511.15 284.73 -334.67 -212.00 396.17 212.35 0.55 MWD IFR MSA 18 1684.09 29.77 212.49 92 .41 1591.15 317.99 -373.76 -236.71 442.42 212.35 0.60 MWD IFR MSA - 19 1778.40 29.19 212.69 94.31 1673.25 351.22 -412.87 -261.71 488.83 212.37 0.62 MWD IFR MSA 20 1870.19 28.53 213.23 91.79 1753.64 382.73 -450.04 -285.81 533.13 212.42 0.77 MWD IFR MSA 21 1961.11 29.87 213 .90 90.92 1833.00 413.94 -487.00 -310.34 577.47 212.51 1.52 MWD IFR MSA 22 2054.48 29.79 214.49 93.37 1914.00 446.27 -525.41 -336.44 623.90 212.63 0.33 MWD IFR MSA . - 23 2148.61 31.01 212.33 94.13 1995.19 479.89 -565.18 -362.65 671.52 212.69 1. 74 MWD IFR MSA - 24 2241.64 30.74 211.67 93.03 2075.04 514 .40 -605.66 -387.95 719.26 212.64 0.47 MWD IFR MSA - 25 2335.80 30.20 211.30 94.16 2156.20 549.22 -646.38 -412.89 766.99 212.57 0.61 MWD I FR MSA - 26 2429.70 29.60 212.08 -93.90 2237.60 583.23 -686.21 -437.48 813.80 212.52 0.76 MWD IFR MSA - 27 2523.88 29.24 211.72 94.18 2319.63 616.74 -725.48 -461.92 860.06 212.49 0.43 MWD IFR MSA - 28 2617.94 29.48 212.09 94.06 2401.61 650.13 -764.63 -486.30 906.17 212.46 0.32 MWD IFR MSA - 29 2711.16 29.07 211.75 93.22 2482.92 683.13 -803.32 -510.40 951.75 212.43 0.47 MWD IFR MSA - 30 2804.57 29.90 212.28 93.41 2564.24 716.36 -842.30 -534.77 997.73 212.41 0.93 MWD IFR MSA SCHLUMBERGER Survey Report 2-Nov-2003 12:39:58 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 2897.91 30.20 213.95 93.34 2645.03 749.51 -881.45 -560.31 1044.46 212.44 0.95 MWD IFR MSA - 32 3015.13 28.63 214.17 117.22 2747.14 789.67 -929.14 -592.55 1102.01 212.53 1. 34 MWD IFR MSA - 33 3108.41 29.61 215.56 93.28 2828.63 820.88 -966.38 -618.50 1147.36 212.62 1.28 MWD IFR MSA - 34 3201.92 31. 53 213 . 14 93.51 2909.14 853.90 -1005.65 -645.31 1194.89 212.69 2.44 MWD IFR MSA 35 3294.32 32.33 207.87 92.40 2987.57 890.08 -1047.73 -670.07 1243.68 212.60 3.14 MWD IFR MSA 36 3388.10 32.40 202.80 93.78 3066.80 930.12 -1093.07 -691.54 1293.45 212.32 2.89 MWD IFR MSA - 37 3480.98 33.74 199.18 92.88 3144.64 972.77 -1140.38 -709.65 1343.16 211.89 2.57 MWD IFR MSA . - 38 3574.42 34.03 197.16 93.44 3222.21 1017.95 -1189.87 -725.89 1393.81 211.39 1.24 MWD IFR MSA 39 3668.22 32.99 195.61 93.80 3300.42 1063.63 -1239.55 -740.51 1443.89 210.85 1.44 MWD IFR MSA 40 3761.20 32.95 194.09 92.98 3378.43 1108.89 -1288.45 -753.48 1492.59 210.32 0.89 MWD IFR MSA 41 3854.83 32.47 194.10 93.63 3457.21 1154.44 -1337.53 -765.80 1541.24 209.79 0.51 MWD IFR MSA - 42 3949.05 31.88 193.81 94.22 3536.96 1199.67 -1386.22 -777.90 1589.57 209.30 0.65 MWD IFR MSA - 43 4041.71 32.70 194.96 92.66 3615.29 1244.12 -1434.16 -790.20 1637.45 208.85 1.11 MWD IFR MSA 44 4135.13 32.75 195.66 93.42 3693.88 1289.11 -1482.87 -803.54 1686.59 208.45 0.41 MWD IFR MSA - 45 4228.17 32.08 194.76 93.04 3772.43 1333.58 -1531. 00 -816.63 1735.17 208.08 0.89 MWD IFR MSA 46 4320.77 31.71 194.34 92.60 3851.05 1377.46 -1578.35 -828.92 1782.78 207.71 0.47 MWD IFR MSA - 47 4413.70 32.87 195.79 92.93 3929.60 1421.78 -1626.28 -841.83 1831. 25 207.37 1.50 MWD IFR MSA - 48 4507.16 34.07 196.54 93.46 4007.56 1467.34 -1675.79 -856.18 1881.84 207.06 1. 36 MWD IFR MSA - 49 4600.80 34.12 196.74 93.64 4085.11 1513.54 -1726.08 -871.22 1933.48 206.78 0.13 MWD IFR MSA - 50 4694.47 34.15 194.91 93.67 4162.64 1560.15 -1776.64 -885.55 1985.11 206.49 1.10 MWD IFR MSA 51 4787.31 33.28 195.75 92.84 4239.87 1606.06 -1826.34 -899.17 2035.69 206.21 1. 06 MWD IFR MSA - I 52 4881.13 32.72 196.62 93.82 4318.55 1651.22 -1875.41 -913.41 2086.02 205.97 0.78 MWD IFR MSA 53 4974.97 32.52 196.63 93.84 4397.59 1695.75 -1923.89 -927.88 2135.95 205.75 0.21 MWD I FR MSA- - 54 5068.65 32.30 196.36 93.68 4476.68 1740.00 -1972.03 -942.14 2185.52 205.54 0.28 MWD IFR MSA - 55 5162.51 32.10 196.25 93.86 4556.10 1784.16 -2020.03 -956.18 2234.91 205.33 0.22 MWD IFR MSA 56 5255.30 32.24 195.76 92.79 4634.65 1827.90 -2067.52 -969.80 2283.67 205.13 0.32 MWD IFR MSA - 57 5348.47 31.93 194.86 93.17 4713.59 1871.99 -2115.25 -982.87 2332.45 204.92 0.61 MWD IFR MSA - 58 5441.04 31.42 194.95 92.57 4792.37 1915.45 -2162.23 -995.37 2380.33 204.72 0.55 MWD IFR MSA - 59 5535.04 31. 05 194.39 94.00 4872.74 1959.12 -2209.38 -1007.72 2428.34 204.52 0.50 MWD IFR MSA - 60 5628.07 30.90 194.94 93.03 4952.50 2002.02 -2255.70 -1019.84 2475.53 204.33 0.34 MWD IFR MSA SCHLUMBERGER Survey Report 2-Nov-2003 12:39:58 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5721.85 31.34 190.90 93.78 5032.80 2046.07 -2302.92 -1030.66 2523.03 204.11 2.28 MWD IFR MSA - 62 5815.62 31.79 182.37 93.77 5112.73 2092.56 -2351.57 -1036.29 2569.78 203.78 4.78 MWD IFR MSA 63 5908.35 32.92 175.33 92.73 5191.09 2141.28 -2401.11 -1035.25 2614.78 203.32 4.24 MWD IFR MSA - 64 6001.95 31.10 171.25 93.60 5270.47 2190.68 -2450.36 -1029.50 2657.84 202.79 3.02 MWD IFR MSA - 65 6095.01 29.59 164.07 93.06 5350.80 2237.61 -2496.22 -1019.54 2696.40 202.22 4.22 MWD IFR MSA 66 6188.44 29.83 158.18 93.43 5431.97 2283.50 -2539.99 -1004.57 2731.43 201.58 3.13 MWD IFR MSA - 67 6283.14 30.90 153.33 94.70 5513.69 2330.19 -2583.59 -984.89 2764.95 200.87 2.82 MWD IFR MSA . - 68 6377.25 32.84 149.24 94.11 5593.62 2377.66 -2627.12 -960.99 2797.37 200.09 3.08 MWD IFR MSA - 69 6470.36 35.18 140.95 93.11 5670.84 2425.38 -2669.68 -931.16 2827.41 199.23 5.57 MWD IFR MSA - 70 6563.60 37.88 130.77 93.24 5745.82 2471.99 -2709.27 -892.52 2852.50 198.23 7.11 MWD IFR MSA 71 6656.63 39.33 122.82 93.03 5818.57 2515.34 -2743.92 -846.08 2871.41 197.14 5.55 MWD IFR MSA 72 6749.03 37.27 117.21 92.40 5891.10 2553.46 -2772.60 -796.57 2884.76 196.03 4.37 MWD IFR MSA - 73 6843.14 35.41 110.71 94.11 5966.93 2585.98 -2795.28 -745.70 2893.04 194.94 4.54 MWD IFR MSA - 74 6937.17 38.43 106.23 94.03 6042.11 2614.28 -2813.09 -692.14 2896.99 193.82 4.30 MWD IFR MSA - 75 7029.75 42.47 105.94 92.58 6112.55 2642.27 -2829.72 -634.44 2899.97 192.64 4.37 MWD IFR MSA 76 7123.42 48.32 106.40 93.67 6178.29 2673.45 -2848.30 -570.42 2904.86 191. 32 6.26 MWD IFR MSA - 77 7217.07 54.02 106.13 93.65 6236.99 2707.64 -2868.72 -500.41 2912.04 189.89 6.09 MWD IFR MSA - 78 7309.62 59.95 105.01 92.55 6287.40 2743.15 -2889.51 -425.68 2920.70 188.38 6.49 MWD IFR MSA - 79 7403.95 66.32 103.15 94.33 6330.00 2779.70 -2909.94 -344.10 2930.21 186.74 6.98 MWD IFR MSA - 80 7497.83 66.36 96 .21 93.88 6367.72 2811. 02 -2924.38 -259.40 2935.86 185.07 6.77 MWD IFR MSA 81 7589.99 65.42 92.51 92.16 6405.37 2834.29 -2930.79 -175.55 2936.04 183.43 3.80 MWD IFR MSA 82 7683.39 66.16 92.39 93.40 6443.67 2855.12 -2934.43 -90.44 2935.82 181.77 0.80 MWD IFR MSA I - 83 7776.36 65.63 92.19 92.97 6481.64 2875.63 -2937.82 -5.65 2937.82 180.11 0.60 MWD IFR MSA - 84 7869.05 64.51 92 .44 92.69 6520.71 2895.99 -2941.21 78.34 2942.25 178.47 1.23 MWD IFR MSA - 85 7962.85 65.33 92.73 93.80 6560.47 2916.95 -2945.04 163.21 2949.56 176.83 0.92 MWD IFR MSA 86 8056.33 66.73 94.92 93.48 6598.45 2939.82 -2950.75 248.43 2961.19 175.19 2.61 MWD IFR MSA - 87 8151.47 67.97 95.06 95.14 6635.09 2965.04 -2958.39 335.89 2977.40 173.52 1.31 MWD IFR MSA 88 8244.23 67.06 96.41 92.76 6670.57 2990.71 -2966.95 421.17 2996.69 171 . 92 1. 66 MWD IFR MSA 89 8337.43 67.16 96.61 93.20 6706.82 3017.54 -2976.68 506.48 3019.46 170.34 0.22 MWD IFR MSA - 90 8431.08 65.95 97.14 93.65 6744.08 3044.91 -2986.97 591.78 3045.02 168.79 1. 39 MWD IFR MSA SCHLUMBERGER Survey Report 2-Nov-2003 12:39:58 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8472 .12 65.32 96.74 41. 04 6761.01 3056.86 -2991.48 628.89 3056.87 168.13 1. 77 MWD IFR MSA 92 8544.00 65.32 96.74 71. 88 6791.02 3077.52 -2999.15 693.75 3078.34 166.98 0.00 Projected to TD [(c)2003 IDEAL ID8 1C_01] I I '-, -. . . bp V.114APB1 Survey ReporlBChlumberger Report Date: 14-Nov-G3 Client: BP Exploration Alaska Field: Prudhoe Bay Unit· WOA Structure I Slot: V-Pad I Plan V-114 (S-G) Well: V-114 Borehole: V-114APB1 UWVAPli: 500292317870 Survey Name I Date: V-114APB11 November 14, 2003 Tort I AHD 10011 ERD ratio: 172.923' /4628.97 ft /6.003/ 0.682 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatILong: N 70 1938.972, W 149 15 57.365 Location Grid WE VIX: N 5969895.720 ftUS, E 590514.780 ftUS Grid Convergence Angle: +0.69122375' Grid Scale Factor: 0.99990931 Survey I DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 168.300' Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: KB TVD Reference Elevation: 81.80ft relative to MSL Sea Bed I Ground Level Elevation: 53.30 ft relative to MSL Magnetic Declination: 25.209' Total Reid strength: 57548.967 nT Magnetic Dip: 80.808' Declination Date: November 01 , 2003 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North .) True North: +25.209' Local Coordinates Referenced To: Well Head N 701938.972 W 149 1557.365 N 70 19 38.957 W 149 1557.371 N 70 19 38.954 W 149 1557.373 N 70 19 38.931 W 149 1557.401 N 70 19 38.883 W 14915 57.484 565.46 7.84 212.40 564.67 482.87 15.36 ·17.62 -9.34 3.39 3.38 2.14 5969877.99 590505.65 N 70 19 38.799 W 1491557.638 657.43 10.67 215.33 655.43 573.63 25.67 -29.87 -17.63 3.12 3.08 3.19 5969865.65 590497.52 N 70 19 38.678 W 1491557.880 749.24 13.99 214.36 745.11 663.31' 39.17 -45.97 -28.81 3.62 3.62 -1.06 5969849.41 590486.53 N 70 1938.520 W 149 15 58.206 841.20 15.77 215.34 833.99 752.19 55.40 -65.34 -42.31 1.95 1.94 1.07 5969829.88 590473.26 N 70 19 38.329 W 1491558.600 936.17 18.04 214.56 924.85 843.05 74.36 -87.98 -58.12 2.40 2.39 -0.82 5969807.05 590457.73 N 70 1938.107 W 149 15 59.062 1029.75 22.17 212.33 1012.71 930.91 97.09 -114.84 -75.79 4.49 4.41 -2.38 5969779.98 590440.39 N 70 19 37.842 W 149 1559.578 1120.79 25.06 211.25 1096.11 1014.31 123.56 -145.85 -94.98 3.21 3.17 -1.19 5969748.75 590421.57 N 70 19 37.537 W 149 16 0.138 1214.58 27.00 211.29 1180.39 1098.59 153.67 -181.03 -116.35 2.07 2.07 0.04 5969713.32 590400.63 N 70 19 37.191 W 149 16 0.761 1309.05 27.89 211.55 1264.22 1182.42 185.45 -218.18 -139.05 0.95 0.94 0.28 5969675.90 590378.39 N 70 19 36.826 W 149 16 1.424 1402.90 28.41 211.94 1346.97 1265.17 217.60 -255.83 -162.34 0.59 0.55 0.42 5969637.97 590355.55 N 70 19 36.456 W 149 162.104 1494.98 29.78 212.38 1427.43 1345.63 249.88 -293.73 -186.18 1.51 1.49 0.48 5969599.79 590332.17 N 70 19 36.083 W 149 162.800 1591.68 30.29 212.11 1511.15 1429.35 284.73 -334.67 -212.00 0.55 0.53 -0.28 5969558.55 590306.85 N 70 19 35.680 W 149 16 3.554 1684.09 29.77 212.49 1591.15 1509.35 317.99 -373.76 -236.71 0.60 -0.56 0.41 5969519.16 590282.61 N 70 19 35.296 W 149164.275 1778.40 29.19 212.69 1673.25 1591.45 351.22 -412.87 -261.71 0.62 -0.61 0.21 5969479.77 590258.09 N 70 19 34.911 W 149 16 5.005 1870.19 28.53 213.23 1753.64 1671.84 382.73 -450.04 -285.81 0.77 -0.72 0.59 5969442.31 590234.44 N 70 19 34.546 W 149 165.708 1961.11 29.87 213.90 1833.00 1751.20 413.94 -487.00 -310.34 1.52 1.47 0.74 5969405.06 590210.37 N701934.182 W 149 166.424 2054.48 29.79 214.49 1914.00 1832.20 446.27 -525.41 -336.44 0.33 -0.09 0.63 5969366.34 590184.73 N 70 19 33.804 W 149167.186 2148.61 31.01 212.33 1995.19 1913.39 479:89 -565.18 -362.65 1.74 1.30 -2.29 5969326.26 590159.01 N 70 1933.413 W 149 167.951 2241.64 30.74 211.67 2075.04 1993.24 514.41 -605.66 -387.95 0.47 -0.29 -0.71 5969285.48 590134.20 N 70 19 33.015 W 149 168.689 2335.80 30.20 211.30 2156.20 2074.40 549.22 -846.38 -412.89 0.61 -0.57 -0.39 5969244.47 590109.76 N 70 19 32.615 W 149 169.417 2429.70 29.60 212.08 2237.60 2155.80 583.24 -686.21 -437.48 0.76 ·0.64 0.83 5969204.35 590085.65 N 70 19 32.223 W 1491610.135 2523.88 29.24 211.72 2319.63 2237.83 616.74 -725.48 -461.92 0.43 -0.38 -0.38 5969164.79 590061.69 N701931.837 W1491610.848 2617.94 29.48 212.09 2401.61 2319.81 650.13 -764.63 -486.30 0.32 0.26 0.39 5969125.35 590037.79 N 70 19 31.452 W 1491611.560 2711.16 29.07 211.75 2482.9i· 2401.12 683.13 -803.32 -510.40 0.47 -0.44 -0.36 5969086.37 590014.16 N 70 19 31.071 W 149 16 12.263 2804.57 29.90 212.28 2564.24 2482.44 716.36 -842.30 -534.77 0.93 0.89 0.57 5969047.10 589990.25 N 70 19 30.688 W 149 16 12.975 2897.91 30.20 213.95 2645.03 2563.23 749.51 -881.45 -560.31 0.95 0.32 1.79 5969007.66 589965.19 N 70 19 30.303 W 149 1613.720 3015.13 28.63 214.17 2747.14 2665.34 789.67 -929.14 -592.55 1.34 -1.34 0.19 5968959.58 589933.54 N 70 19 29.834 W 14916 14.661 3108.41 29.61 215.56 2828.63 2746.83 820.88 -966.38 -618.50 1.28 1.05 1.49 5968922.04 589908.04 N 70 1929.467 W 149 16 15.418 3201.92 31.53 213.14 2909.14 2827.34 853.90 -1005.65 -645.31 2.44 2.05 -2.59 5968882.45 589881.71 N 70 19 29.081 W 1491616.200 3294.32 32.33 207.87 2987.57 2905.77 890.08 -1047.73 -670.07 3.14 0.87 -5.70 5968840.08 589857.46 N 70 19 28.667 W 149 16 16.923 3388.10 32.40 202.80 3066.80 2985.00 930.12 -1093.07 -691.54 2.89 0.07 -5.41 5968794.49 589836.54 N 70 19 28.221 W 1491617.549 3480.98 33.74 199.18 3144.64 3062.84 972.78 -1140.38 -709.65 2.57 1.44 -3.90 5968746.97 589819.00 N 70 1927.756 W 14916 18.078 3574.42 34.03 197.16 3222.21 3140.41 1017.95 -1189.87 -725.89 1.24 0.31 -2.16 5968697.29 589803.36 N 70 19 27.269 W 149 16 18.552 3668.22 32.99 195.61 3300.42 3218.62 1063.63 -1239.55 -740.51 1.44 -1.11 -1.65 5968647.45 589789.34 N 70 19 26.781 W 149 1618.979 3761.20 32.95 194.09 3378.43 3296.63 1108.89 -1288.45 -753.48 0.89 -0.04 -1.63 5968598.39 589776.97 N 70 19 26.300 W 1491619.357 3854.83 32.47 194.10 3457.21 3375.41 1154.44 -1337.53 -765.80 0.51 -0.51 0.01 5968549.18 589765.24 N 70 19 25.817 W 149 16 19.716 3949.05 31.88 193.81 3536.96 3455.16 1199.67 -1386.22 -777.90 0.65 -0.63 -0.31 5968500.35 589753.73 N 70 1925.338 W 149 1620.069 4041.71 32.70 194.96 3615.29 3533.49 1244.12 -1434.16 -790.20 1.11 0.88 1.24 5968452.26 589742.01 N 70 19 24.867 W 149 1620.428 4135.13 32.75 195.66 3693.88 3612.08 1289.11 -1482.87 -803.54 0.41 0.05 0.75 5968403.40 589729.26 N 70 19 24.388 W 149 1620.817 4228.17 32.08 194.76 3772.43 3690.63 1333.58 -1531.00 -816.63 0.89 -0.72 -0.97 5968355.13 589716.76 N 70 19 23.914 W 1491621.199 4320.77 31.71 194.34 3851.05 3769.25 1377.46 -1578.35 -828.92 0.47 -0.40 ·0.45 5968307.63 589705.04 N 70 19 23.448 W 149 16 21.558 441 3.70 32.87 195.79 3929.60 3847.80 1421.78 -1626.28 -841.83 1.50 1.25 1.56 5968259.55 589692.71 N 70 19 22.977 W 149 1621.935 4507.16 34.07 196.54 4007.57 3925.77 1467.34 -1675.79 -856.18 1.36 1.28 0.80 5968209.88 589678.95 N 70 19 22.490 W 149 16 22.353 4600.80 34.12 196.74 4085.11 4003.31 1513.54 -1726.08 -871.22 0.13 0.05 0.21 5968159.42 589684.53 N 70 19 21.996 W 149 1622.792 SurveyEditor Ver 3.1RT-SP3.03-HF2.03 Bld( d031rt-546) Plan V-114 (S-G)\V-114\V-114APBI\V-114APBI Generated 11/25/2003 6:35 PM Page 1 of 2 , , . . 4694.47 34.15 194.91 4162.64 4080.84 1560.15 -1776.64 -885.55 1.10 0.03 -1.95 5968108.69 589650.81 N 70 1921.498 W 149 1623.210 4787.31 33.28 195.75 4239.87 4158.07 1606.06 -1826.34 -899.17 1.06 -0.94 0.90 5968058.83 589637.79 N 70 19 21.009 W 149 1623.607 4881.13 32.72 196.62 4318.55 4236.75 1651.22 -1875.41 -913.41 0.78 -0.60 0.93 5968009.60 589624.15 N 70 1920.527 W 1491624.023 4974.97 32.52 196.63 4397.59 4315.79 1695.75 -1923.89 -927.88 0.21 -0.21 0.01 5967960.96 589610.26 N 70 19 20.050 W 149 1624.445 5068.65 32.30 196.36 4476.68 4394.88 1740.00 -1972.03 -942.14 0.28 -0.23 -0.29 5967912.65 589596.59 N 70 1919.577 W 149 1624.861 5162.51 32.10 196.25 4556.10 4474.30 1784.16 -2020.03 -956.18 0.22 -0.21 -0.12 5967864.49 589583.13 N 70 19 19.104 W 149 1625.270 5255.30 32.24 195.76 4634.65 4552.85 1827.90 -2067.52 -969.80 0.32 0.15 -0.53 5967816.84 589570.08 N 70 19 18.637 W 149 1625.668 5348.47 31.93 194.86 4713.59 4631.79 1871.99 -2115.25 -982.87 0.61 -0.33 -0.97 5967768.96 589557.59 N 70 19 18.168 W 149 1626.049 5441.04 31.42 194.95 4792.37 4710.57 1915.45 -2162.23 -995.37 0.55 -0.55 0.10 5967721.84 589545.66 N 70 19 17.706 W 149 1626.414 5535.04 31.05 194.39 4872.74 4790.94 1959.12 -2209.38 -1007.72 0.50 -0.39 -0.60 5967674.55 589533.88 N 70 19 17.242 W 149 1626.774 5628.07 30.90 194.94 4952.50 4870.70 2002.02 -2255.70 -1019.84 0.34 -0.16 0.59 5967628.09 589522.32 N 70 1916.787 W 1491627.127 5721.85 31.34 190.90 5032.80 4951.00 2046.07 -2302.92 -1030.66 2.28 0.47 -4.31 5967580.75 589512.07 N 70 19 16.322 W 149 1627.443 5815.62 31.79 182.37 5112.73 5030.93 2092.56 -2351.57 -1036.29 4.78 0.48 -9.10 5967532.04 589507.02 N 70 19 15.844 W 149 1627.607 5908.35 32.92 175.33 5191.09 5109.29 2141.28 -2401.11 -1035.25 4.24 1.22 -7.59 5967482.52 589508.66 N 701915.357 W 149 1627.577 6001.95 31.10 171.25 5270.47 5188.67 2190.68 -2450.36 -1029.50 3.02 -1.94 -4.36 5967433.35 589515.01 N 701914.872 W 149 1627.409 6095.01 29.59 164.07 5350.80 5269.00 2237.61 -2496.22 -1019.54 4.22 -1.62 -7.72 5967387.61 589525.52 N701914.421 W1491627.118 6188.44 29.83 158.18 5431.97 5350.17 2283.50 -2539.99 -1004.57 3.13 0.26 -6.30 5967344.03 589541.02 N 70 1913.991 W 149 1626.680 6283.14 30.90 153.33 5513.69 5431.89 2330.19 -2583.59 -984.89 2.82 1.13 -5.12 5967300.68 589561.22 N 70 19 13.562 W 149 1626.106 6377.25 32.84 149.24 5593.62 5511.82 2377.66 -2627.12 -960.99 3.08 2.06 -4.35 5967257.44 589585.64 N 70 1913.134 W 149 1625.409 6470.36 35.18 140.95 5670.84 5589.04 2425.38 -2669.68 -931.16 5.57 2.51 -8.90 5967215.25 589615.98 N 70 19 12.715 W 149 1624.538 6563.60 37.88 130.77 5745.82 5664.02 2471.99 -2709.27 -892.52 7.11 2.90 -10.92 5967176.13 589655.09 N 70 1912.326 W 149 1623.410 6656.63 39.33 122.82 5818.57 5736.77 2515.34 -2743.93 -846.08 5.55 1.56 -8.55 5967142.04 589701.94 N 70 19 11.985 W 149 1622.055 6749.03 37.27 117.21 5891.10 5809.30 2553.46 -2772.60 -796.57 4.37 -2.23 -6.07 5967113.97 589751.79 N701911.703 W1491620.610 6843.14 35.41 110.71 5966.93 5885.13 2585.98 -2795.28 -745.70 4.54 -1.98 -6.91 5967091.91 589802.92 N 70 19 11.480 W 149 16 19.126 6937.17 38.43 106.23 6042.11 5960.31 2614.28 -2813.09 -692.14 4.30 3.21 -4.76 5967074.75 589856.69 N 70 1911.305 W 1491617.563 7029.75 42.47 105.94 6112.55 6030.75 2642.27 -2829.72 -634.44 4.37 4.36 -0.31 5967058.81 589914.58 N 70 19 11.142 W 1491615.879 7123.42 48.32 106.40 6178.29 6096.49 2673.45 -2848.30 -570.42 6.26 6.25 0.49 5967041.01 589978.81 N 70 19 10.959 W 149 1614.010 7217.07 54.02 106.13 6236.99 6155.19 2707.84 -2868.72 -500.41 6.09 6.09 -0.29 5967021.44 590049.06 N 70 19 10.758 W 1491611.968 7309.62 59.95 105.01 6287.40 6205.60 2743.16 -2889.51 -425.68 6.49 6.41 -1.21 5967001.55 590124.02 N 70 19 10.554 W 149 169.787 7403.95 66.32 103.15 6330.00 6248.20 2779.70 -2909.94 -344.10 6.98 6.75 -1.97 5966982.11 590205.84 N 70 1910.353 W 149167.406 7497.83 66.36 96.21 6367.72 6285.92 2811.02 -2924.38 -259.40 6.77 0.04 -7.39 5966968.69 590290.70 N 701910.211 W 149 164.935 7589.99 65.42 92.51 6405.37 6323.57 2834.29 -2930.79 -175.55 3.80 -1.02 -4.01 5966963.30 590374.62 N 70 1910.148 W 149162.488 7683.39 66.16 92.39 6443.68 6361.88 2855.12 -2934.43 -90.44 0.80 0.79 -0.13 5966960.69 590459.75 N 70 1910.112 W 149 160.004 7776.36 65.63 92.19 6481.64 6399.84 2875.63 -2937.82 -5.65 0.60 -0.57 -0.22 5966958.32 590544.57 N 70 19 10.079 W 1491557.530 7869.05 64.51 92.44 6520.71 6438.91 2895.99 -2941.21 78.34 1.23 -1.21 0.27 5966955.94 590628.58 N 70 19 10.045 W 1491555.079 7962.85 65.33 92.73 6560.47 6478.67 2916.95 -2945.04 163.21 0.92 0.87 0.31 5966953.13 590713.49 N 70 19 10.008 W 149 15 52.603 8056.33 66.73 94.92 6598.45 6516.65 2939.82 -2950.75 248.43 2.61 1.50 2.34 5966948.45 590798.76 N 70 19 9.951 W 14915 50.116 8151.47 67.97 95.06 6635.09 6553.29 2965.04 -2958.39 335.89 1.31 1.30 0.15 5966941.87 590886.30 N 70 19 9.876 W 149 1547.564 8244.23 67.06 96.41 6670.57 6588.77 2990.71 -2966.95 421.17 1.66 -0.98 1.46 5966934.34 590971.67 N 70199.792 W 149 1545.075 8337.43 67.16 96.61 6706.82 6625.02 3017.54 -2976.68 506.48 0.22 0.11 0.21 5966925.64 591057.08 N 70 19 9.696 W 149 1542.586 8431.08 65.95 97.14 6744.08 6662.28 3044.91 -2986.97 591.78 1.39 -1.29 0.57 5966916.39 591142.49 N 70 199.595 W 149 1540.097 8472.12 65.32 96.74 6761.01 6679.21 3056.86 -2991.48 628.89 1.77 -1.54 ,0.97 5966912.32 591179.65 N 70 19 9.551 W 149 1539.014 8544.00 65.32 96.74 6791.02 6709.22 3077.52 -2999.15 693.75 0.00 0.00 0.00 5966905.43 591244.59 N 70 19 9.475 W 149 1537.121 LeQal Description: Northina IV) [fIUSl Eastina IX) [fIUSl Surface: 4649 FSL 1789 FEL S11 T11N R11E UM 5969895.72 590514.78 BHL: 1649 FSL 1098 FEL S11 T11N R11E UM 5966905.43 591244.59 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( do31 rt-546 ) Plan V-114 (S-G)\V-114\V-114APB1\V-114APB1 Generated 11/25/20036:35 PM Page 2 of 2 SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Borealis Well. . . . . . . . . . . . . . . . . . . . .: V-114A PB2 API number...............: 50-029-23178-71 Engineer.................: M. St Amour Rig: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS... . . . . . . . .: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 53.30 ft KB above permanent.......: N/A (Top Drive) DF above permanent.......: 81.80 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 rotary table to target: 73.01 degrees [(c)2003 IDEAL ID8_1C_OIJ 20-Nov-2003 11:16:20 Spud date.... ............: Last survey date...... ...: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 4 22-0ct-03 12-Nov-03 81 8151. 47ft 10677.00 ft ----- Geomagnetic data ---------------------- I Magnetic model...........: Magnetic date............: Magnetic field strength. . : Magnetic dec (+E/W-).....: Magnetic dip......... ....: ----- MWD survey Reference Reference G..............: Reference H..............: Reference Dip....... .....: Tolerance of G. ...... ....: Tolerance of H.. .........: Tolerance of Dip. ........: BGGM version 2002 04-Nov-2003 1151.01 HCNT 25.21 degrees 80.81 degrees Criteria --------- 1002.68 mGal 1151.01 HCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.21 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-}....: 25.21 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 I SCHLUMBERGER Survey Report 20-Nov-2003 11:16:20 Page 2 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 1 2 3 4 5 8151. 47 8221.00 8233.00 8266.79 8298.01 67.97 67.29 69.10 71.74 74.82 77.96 81.16 84.14 87.06 89.64 91.80 94.20 94.20 94.10 94.30 93.75 93.41 94.20 92.11 89.81 88.13 88.02 90.77 89.05 87.75 86.65 86.72 87.54 88.26 88.78 95.06 96.07 95.38 93.89 92.55 91.27 89.97 88.69 89.68 86.56 86.51 84.84 80.58 78.18 77.24 74.90 72.27 70.34 67.68 66.35 64.19 64.64 71.56 73.46 73.45 72.19 74.09 76.64 79.96 82.30 [(c)2003 IDEAL ID8_1C_01] 8328.86 8360.77 8392.48 8424.33 8448.72 8480.54 8512.82 8544.60 8576.29 8607.25 8637.10 8669.05 8700.20 8732.29 8763.41 8792.84 8824.31 8855.94 8894.29 8917.48 8948.51 8980.18 9011.41 9043.85 9073.52 0.00 69.53 12.00 33.79 31.22 30.85 31.91 31.71 31.85 24.39 31.82 32.28 31.78 31.69 30.96 29.85 31.95 31.15 32.09 31. 12 29.43 31.47 31.63 38.35 23.19 31. 03 31.67 31.23 32.44 29.67 6635.09 6661.55 6666.01 6677.33 6686.31 6693.57 6699.35 6703.41 6705.85 6706.56 6706.16 6704.47 6702.14 6699.84 6697.58 6695.48 6693.49 6691.42 6689.65 6689.13 6689.66 6690.72 6691.05 6691.11 6691.76 6693.27 6695.11 6696.67 6697.86 6698.63 -543.23 -2958.39 -483.85 -2964.62 -473.57 -2965.73 -443.98 -2968.30 -415.92 -2969.98 -387.56 -2970.98 -357.65 -2971.31 -327.47 -2970.95 -296.98 -2970.49 -273.45 -2969.69 -242.51 -2967.77 -211.06 -2965.34 -179.83 -2961.32 -148.42 -2955.50 -117.65 -2948.92 -87.92 -2941.76 -56.03 -2932.75 -24.97 -2922.78 6.99 -2911.31 37.93 -2899.16 67.09 -2886.85 98.19 -2873.27 129.68 -2861.48 168.02 -2849.95 191.20 -2843.35 222.19 -2834.20 253.81 -2825.03 284.97 -2817.15 317.25 -2810.58 346.61 -2806.00 335.89 399.88 410.97 442.70 472.55 502.51 533.88 565.33 597.08 621.44 653.19 685.34 716.77 747.83 778.00 806.90 837.48 866.92 896.83 925.48 952.20 980.57 1009.89 1046.47 1068.69 1098.30 1128.55 1158.73 1190.47 1219.77 2977.40 2991.47 2994.07 3001.13 3007.34 3013.17 3018.90 3024.25 3029.91 3034.02 3038.80 3043.51 3046.83 3048.64 3049.82 3050.41 3049.98 3048.64 3046.31 3043.29 3039.83 3035.98 3034.46 3036.01 3037.56 3039.56 3042.11 3046.14 3052.30 3059.66 173.52 172.32 172.11 171.52 170.96 170.40 169.81 169.23 168.63 168.18 167.59 166.99 166.39 165.80 165.22 164.66 164.06 163.48 162.88 162.30 161.75 161.16 160.56 159.84 159.40 158.82 158.22 157.64 157.04 156.51 DLS (degl 100f) 0.00 1. 66 16.00 8.85 10.69 10.95 10.80 10.21 9.68 16.59 6.79 9.05 13.37 7.56 3.10 8.03 8.28 6.68 10.53 8.54 9.30 1.47 23.54 6.68 5.61 5.39 5.99 8.57 10.47 8.08 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ TIP None Interpolation Extrapolation SLB_INC+TREND SLB_INC+TREND SLB_INC+TREND SLB_INC+TREND MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA I MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA I MWD __I FR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA SCHLUMBERGER Survey Report -------- ------ ------- -------- ------ ------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) 20-Nov-2003 11:16:20 Page 3 of 4 ------ -------- -------- ---------------- --------------- ------ -------- -------- ---------------- --------------- Course length (ft) TVD depth (ft) -------- ------ ------- ------ -------- -------- ------ ------- ------ -------- 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 9103.88 9134.18 9164.89 9196 .15 9227.53 9258.41 9289.48 9321.84 9353.36 9385.73 9415.59 9447.23 9478.33 9510.82 9542.17 9571.17 9601.77 9633.80 9664.89 9696.18 9726.49 9757.41 9789.35 9820.34 9850.45 9881.89 9913.24 9943.82 9975.73 10007.48 87.52 87.52 88.62 89.13 87.66 88.10 86.87 87.90 88.21 88.48 89.72 87.62 86.42 88.21 88.10 87.39 86.08 82.60 81.84 82.14 82.49 82.32 82.74 84.32 87.18 87.63 87.63 88.00 88.24 88.82 81. 21 78 .37 77.46 76.58 72.99 71.50 67.09 62.83 62.64 63.70 66.46 67.99 68.96 70.35 71.14 71.94 73.04 72.02 69.97 70.37 68.75 67.60 65.62 66.02 64.70 63.48 64.09 62.58 62.41 62.65 [(c)2003 IDEAL ID8_1C_Ol] 30.36 30.30 30.71 31.26 31.38 30.88 31.07 32.36 31. 52 32.37 29.86 31.64 31.10 32.49 31.35 29.00 30.60 32.03 31.09 31.29 30.31 30.92 31.94 30.99 30.11 31.44 31.35 30.58 31.91 31.75 6699.61 6700.92 6701.95 6702.57 6703.44 6704.59 6705.95 6707.43 6708.50 6709.43 6709.90 6710.64 6712.25 6713.78 6714.79 6715.93 6717.67 6720.83 6725.04 6729.40 6733.45 6737.54 6741.69 6745.18 6747.41 6748.84 6750.13 6751. 30 6752.35 6753.16 Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ---------------- --------------- ---------------- --------------- -------- 376.60 -2801.65 406.66 -2796.29 437.23 -2789.86 468.41 -2782.84 499.76 -2774.61 530.61 -2765.20 561.58 -2754.23 593.58 -2740.55 624.58 -2726.12 656.46 -2711.52 686.02 -2698.94 717.49 -2686.69 748.45 -2675.30 780.85 -2664.02 812.16 -2653.68 841.12 -2644.51 871.67 -2635.32 903.54 -2625.75 934.32 -2615.72 965.27 -2605.21 995.25 -2594.72 1025.79 -2583.32 1057.26 -2570.75 1087.81 -2558.14 1117.57 -2545.62 1148.59 -2531.90 1179.51 -2518.06 1209.63 -2504.35 1240.99 -2489.62 1272.20 -2474.98 1249.80 1279.59 1309.60 1340.06 1370.32 1399.71 1428.74 1458.02 1486.02 1514.89 1541.96 1571.13 1600.02 1630.45 1660.03 1687.51 1716.65 1747.05 1776.17 1805.32 1833.46 1861.91 1890.98 1919.07 1946.36 1974.61 2002.71 2030.02 2058.30 2086.46 3067.78 3075.15 3081. 95 3088.68 3094.55 3099.28 3102.75 3104.26 3104.83 3106.00 3108.36 3112.36 3117.26 3123.35 3130.13 3137.06 3145.12 3153.84 3161.77 3169.59 3177.13 3184.38 3191.33 3197.95 3204.45 3210.85 3217.37 3223.78 3230.30 3237.11 155.96 155.41 154.85 154.29 153.72 153.15 152.58 151. 99 151. 41 150.81 150.26 149.68 149.12 148.53 147.97 147.46 146.92 146.36 145.82 145.28 144.75 144.22 143.66 143.12 142.60 142.05 141. 50 140.97 140.42 139.87 DLS (deg/ 100f) 5.49 9.36 4.65 3.25 12.36 5.03 14.72 13.53 1.15 3.38 10.13 8.21 4.96 6.97 2.54 3.69 5.59 11. 32 6.98 1. 59 5.42 3.73 6.29 5.26 10.46 4.13 1. 94 5.08 0.92 1. 98 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA , MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA , MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA . SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) -------- -------- 61 62 63 64 65 10038.23 10069.74 10100.64 10131.44 10162.80 ------ ------ Incl angle (deg) ..,....----- ------ 89.37 89.72 89.96 89.34 89.78 90.23 91.16 92.01 92.29 93.22 92.70 93.42 93.77 94.35 94.70 94.83 93.74 91. 57 92.70 91.74 91.74 ------- ------- Azimuth angle (deg) ------- ------- 62.83 62.37 62.57 62.13 61.61 63.08 63.92 68.76 70.98 73.16 72.83 73.50 72.19 70.86 71.00 71.02 70.33 69.13 70.09 68.93 68.93 [(c)2003 IDEAL ID8_1C_01] 66 67 68 69 70 10194.39 10226.54 10258.57 10288.00 10318.94 71 72 73 74 75 10350.29 10381.09 10412.50 10443.30 10474.22 76 77 78 79 80 10506.27 10536.86 10568.35 10598.10 10624.72 81 10677.00 ------ ------ Course length (ft) -------- -------- TVD depth (ft) ------ -------- ------ -------- 30.75 31.51 30.90 30.80 31.36 31.59 32.15 32.03 29.43 30.94 31. 35 30.80 31.41 30.80 30.92 32.05 30.59 31. 49 29.75 26.62 52.28 6753.65 6753.90 6753.98 6754.17 6754.41 6754.41 6754.02 6753.13 6752.03 6750.54 6748.92 6747.28 6745.31 6743.13 6740.69 6738.03 6735.74 6734.28 6733.17 6732.14 6730.56 20-Nov-2003 11:16:20 -------- ---------------- -------- ---------------- Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) -------- ---------------- -------- ---------------- 1302.45 -2460.90 1333.44 -2446.40 1363.82 -2432.11 1394.09 -2417.82 1424.86 -2403.04 1455.90 -2388.37 1487.61 -2374.03 1519.40 -2361.19 1548.76 -2351.06 1579.66 -2341.55 1610.97 -2332.40 1641.72 -2323.49 1673.07 -2314.24 1703.78 -2304.51 1734.58 -2294.44 1766.50 -2284.04 1796.98 -2273.95 1828.39 -2263.05 1858.06 -2252.69 1884.61 -2243.38 2113.80 2141.77 2169.17 2196.45 2224.11 2252.09 2280.86 2310.17 2337.79 2367.19 2397.13 2426.56 2456.52 2485.65 2514.79 2544.99 2573.77 2603.28 2631.14 2656.06 1936.73 -2224.59 2704.82 Page 4 of 4 --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 3244.09 3251. 47 3258.91 3266.54 3274.33 3282.72 3292.16 3303.35 3315.53 3329.63 3344.59 3359.58 3374.94 3389.58 3404.20 3419.62 3434.41 3449.41 3463.75 3476.70 3502.13 139.34 138.80 138.27 137.75 137.21 136.68 13 6.15 13 5.63 135.16 134.69 134.22 133.76 133.29 132.83 132.38 131.91 131. 46 131.00 130.57 130.19 129.44 DLS (deg/ 100f) 1. 88 1. 83 1. 01 2.47 2.17 4.87 3.90 15.34 7.60 7.65 1. 96 3.19 4.31 4.70 1. 22 0.41 4.21 7.87 4.98 5.65 0.00 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Projected to TD . , I " . . . V-114APB2 Survey ReporlSChlUmberger Report Date: November 20, 2003 Client: BP Exploration Alaska Field: Prudhoe Bay Unit· WOA Structure I Slot: V-Pad I Plan V·114 (S-G) Well: V-114 Borehole: V-114APB2 UWI/API#: 500292317871 Survey Namel Date: V-114APB2 / November 20,2003 Tort I AHD I DDII ERD ratio: 331.053' /6779.36 II 16.550 11.004 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaVLong: N 70 1938.972, W 149 1557.365 Location Grid NlE Y/X: N 5969895.720 IIUS, E 590514.780 IIUS Grid Convergence Angle: +0.69122375' Grid Scale Factor: 0.99990931 Survey I DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 73.010' Vertical Section Origin: N 0.000 II, E 0.000 II TVD Reference Datum: KB TVD Reference Elevation: 81.80 II relative to MSL Sea Bed I Ground Level Elevation: 53.30 II relative to MSL Magnetic Declination: 25.195' Total Field Strength: 57549.959 nT Magnetic Dip: 80.808' Declination Date: November 13, 2003 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North -> True North: +25.195' Local Coordinates Referenced To: Well Head 565.46 7.84 212.40 564.67 482.87 -14.08 -17.62 -9.34 3.39 3.38 2.14 5969877.99 590505.65 N 70 19 38.799 W 149 15 57.638 657.43 10.67 215.33 655.43 573.63 -25.59 -29.87 -17.63 3.12 3.08 3.19 5969865.65 590497.52 N 70 19 38.678 W 149 15 57.880 749.24 13.99 214.36 745.11 663.31 -40.98 -45.97 -28.81 3.62 3.62 -1.06 5969849.41 590486.53 N 70 19 38.520 W 149 15 58.206 841.20 15.77 215.34 833.99 752.19 -59.56 -65.34 -42.31 1.95 1.94 1.07 5969829.88 590473.26 N 70 19 38.329 W 149 15 58.600 936.17 18.04 214.56 924.85 843.05 -81.29 -87.98 -58.12 2.40 2.39 -0.82 5969807.05 590457.73 N 70 19 38.107 W 149 15 59.062 1029.75 22.17 212.33 1012.71 930.91 -106.04 -114.84 -75.79 4.49 4.41 -2.38 5969779.98 590440.39 N 70 19 37.842 W 149 15 59.578 1120.79 25.06 211.25 1096.11 1014.31 -133.46 -145.85 -94.98 3.21 3.17 -1.19 5969748.75 590421.57 N 70 19 37.537 W149160.138 1214.58 27.00 211.29 1180.39 1098.59 -164.17 -181.03 -116.35 2.07 2.07 0.04 5969713.32 590400.63 N 70 19 37.191 W 149160.761 1309.05 27.89 211.55 1264.22 1182.42 -196.73 -218.18 -139.05 0.95 0.94 0.28 5969675.90 590378.39 N 70 19 36.826 W 149161.424 1402.90 28.41 211.94 1346.97 1265.17 -230.01 -255.83 -162.34 0.59 0.55 0.42 5969637.97 590355.55 N 70 19 36.456 W149162.104 1494.98 29.78 212.38 1427.43 1345.63 -263.88 -293.73 -186.18 1.51 1.49 0.48 5969599.79 590332.17 N 70 19 36.083 W 149162.800 1591.68 30.29 212.11 1511.15 1429.35 -300.54 -334.67 -212.00 0.55 0.53 -0.28 5969558.55 590306.85 N 70 19 35.680 W 149 163.554 1684.09 29.77 212.49 1591.15 1509.35 -335.60 -373.76 -236.71 0.60 -0.56 0.41 5969519.16 590282.61 N 70 19 35.296 W 149164.275 1778.40 29.19 212.69 1673.25 1591.45 -370.93 -412.87 -261.71 0.62 -0.61 0.21 5969479.77 590258.09 N 70 19 34.911 W 149 165.005 1870.19 28.53 213.23 1753.64 1671.84 -404.84 -450.04 -285.81 0.77 -0.72 0.59 5969442.31 590234.44 N 70 19 34.546 W 149 165.708 1961.11 29.87 213.90 1833.00 1751.20 -439.10 -487.00 -310.34 1.52 1.47 0.74 5969405.06 590210.37 N 701934.182 W 149 166.424 2054.48 29.79 214.49 1914.00 1832.20 -475.29 -525.41 -336.44 0.33 -0.09 0.63 5969366.34 590184.73 N 70 19 33.804 W149167.186 2148.61 31.01 212.33 1995.19 1913.39 -511.97 -565.18 -362.65 1.74 1.30 -2.29 5969326.26 590159.01 N 70 19 33.413 W 149 167.951 2241.64 30.74 211.67 2075.04 1993.24 -548.00 -605.66 -387.95 0.47 -0.29 -0.71 5969285.48 590134.20 N 70 19 33.015 W 149168.689 2335.80 30.20 211.30 2156.20 2074.40 -583.74 -646.38 -412.89 0.61 -0.57 -0.39 5969244.47 590109.76 N 70 19 32.615 W 149 169.417 2429.70 29.60 212.08 2237.60 2155.80 -618.90 -686.21 -437.48 0.76 -0.64 0.83 5969204.35 590085.65 N 70 19 32.223 W 149 16 10.135 2523.88 29.24 211.72 2319.63 2237.83 -653.75 -725.48 -461.92 0.43 -0.38 -0.38 5969184.79 590061.69 N 70 1931.837 W 149 16 10.848 2617.94 29.48 212.09 2401.61 2319.81 -688.50 -764.63 -486.30 0.32 0.26 0.39 5969125.35 590037.79 N 70 1931.452 W 149 16 11.560 2711.16 29.07 211.75 2482.92 2401.12 -722.86 -803.32 -510.40 0.47 -0.44 -0.36 5969086.37 590014.16 N 70 19 31.071 W 149 16 12.263 2804.57 29.90 212.28 2564.24 2482.44 -757.56 -842.30 -534.77 0.93 0.89 0.57 5969047.10 589990.25 N 70 19 30.688 W 149 1612.975 2897.91 30.20 213.95 2645.03 2563.23 - 793.42 -881.45 -560.31 0.95 0.32 1.79 5969007.66 589965.19 N 70 19 30.303 W 149 1613.720 3015.13 28.63 214.17 2747.14 2665.34 -838.19 -929.14 -592.55 1.34 -1.34 0.19 5968959.58 589933.54 N 70 1929.834 W 149 16 14.661 3108.41 29.61 215.56 2828.63 2746.83 -873.89 -966.38 -618.50 1.28 1.05 1.49 5968922.04 589908.04 N 70 19 29.467 W 149 1615.418 3201.92 31.53 213.14 2909.14 2827.34 -911.00 -1005.65 -645.31 2.44 2.05 -2.59 5968882.45 589881.71 N 70 19 29.081 W 149 1616.200 3294.32 32.33 207.87 2987.57 2905.77 -946.98 -1047.73 -670.07 3.14 0.87 -5.70 5968840.08 589857.46 N 70 19 28.667 W 149 16 16.923 3388.10 32.40 202.80 3066.80 2985.00 -980.75 -1093.07 -691.54 2.89 0.07 -5.41 5968794.49 589836.54 N 70 19 28.221 W 149 1617.549 3480.98 33.74 199.18 3144.64 3062.84 -1011.91 -1140.38 -709.65 2.57 1.44 -3.90 5968746.97 589819.00 N 70 19 27.756 W 149 1618.078 3574.42 34.03 197.16 3222.21 3140.41 -1041.90 -1189.87 -725.89 1.24 0.31 ·2.16 5968697.29 589803.36 N 70 1927.269 W 149 1618.552 3668.22 32.99 195.61 3300.42 3218.62 -1070.39 -1239.55 -740.51 1.44 -1.11 -1.65 5968647.45 589789.34 N 70 19 26.781 W 149 1618.979 3761.20 32.95 194.09 3378.43 3296.63 -1097.09 -1288.45 -753.48 0.89 -0.04 -1.63 5968598.39 589776.97 N 70 19 26.300 W 149 16 19.357 3854.83 32.47 194.10 3457.21 3375.41 -1123.21 -1337.53 -765.80 0.51 -0.51 0.01 5968549.18 589765.24 N 70 19 25.817 W 149 16 19.716 3949.05 31.88 193.81 3536.96 3455.16 -1149.01 -1386.22 -777.90 0.65 -0.63 -0.31 5968500.35 589753.73 N 70 19 25.338 W 149 1620.069 4041.71 32.70 194.96 3615.29 3533.49 -1174.78 -1434.16 -790.20 1.11 0.88 1.24 5968452.26 589742.01 N 70 19 24.867 W 149 16 20.428 4135.13 32.75 195.66 3693.88 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N 70 1913.052 W 149 157.270 9633.80 82.60 72.02 6720.83 6639.03 903.54 -2625.75 1747.05 11.32 -10.86 -3.18 5967291 .48 592293.21 N 70 1913.146 W 149 156.383 9664.89 81.84 69.97 6725.04 6643.24 934.33 -2615.72 1776.17 6.98 -2.44 -6.59 5967301.86 592322.21 N 70 19 13.244 W 149 15 5.533 9696.18 82.14 70.37 6729.40 6647.60 965.27 -2605.21 1805.32 1.59 0.96 1.28 5967312.72 592351.23 N 70 19 13.348 W 149 154.682 9726.49 82.49 68.75 6733.45 6651.65 995.26 -2594.72 1833.46 5.42 1.15 -5.34 5967323.55 592379.24 N 70 19 13.451 W 149 153.861 9757.41 82.32 67.60 6737.54 6655.74 1025.80 -2583.32 1861.92 3.73 -0.55 -3.72 5967335.28 592407.55 N 70 1913.563 W 149 153.031 9789.35 82.74 65.62 6741.69 6659.89 1057.26 -2570.75 1890.98 6.29 1.31 -6.20 5967348.20 592436.46 N 70 1913.686 W149152.182 9820.34 84.32 66.02 6745.18 6663.38 1087.81 -2558.14 1919.07 5.26 5.10 1.29 5967361.15 592464.39 N 70 19 13.810 W 149151.363 9850.45 87.18 64.70 6747.42 6665.62 1117.57 -2545.62 1946.36 10.46 9.50 -4.38 5967374.00 592491.53 N 70 19 13.933 W 149 15 0.566 9881.89 87.63 63.48 6748.84 6667.04 1148.60 -2531.90 1974.61 4.13 1.43 -3.88 5967388.06 592519.61 N 70 19 14.068 W 149 1459.742 9913.24 87.63 64.09 6750.14 6668.34 1179.52 -2518.06 2002.71 1.94 0.00 1.95 5967402.23 592547.54 N 70 19 14.204 W 149 1458.922 9943.82 88.00 62.58 6751.30 6669.50 1209.64 -2504.35 2030.02 5.08 1.21 -4.94 5967416.27 592574.67 N 70 19 14.339 W1491458.125 9975.73 88.24 62.41 6752.35 6870.55 1241.00 -2489.62 2058.31 0.92 0.75 -0.53 5967431.34 592602.78 N 70 19 14.484 W 149 1457.299 10007.48 88.82 62.65 6753.16 6671.36 1272.21 -2474.98 2086.47 1.98 1.83 0.76 5967446.32 592630.76 N 70 19 14.628 W 14914 56.477 10038.23 89.37 62.83 6753.65 6671.85 1302.46 -2460.90 2113.80 1.88 1.79 0.59 5967460.73 592657.91 N 70 19 14.766 W 149 14 55.679 10069.74 89.72 62.37 6753.90 6672.10 1333.45 -2446.40 2141.77 1.83 1.11 -1.46 5967475.57 592685.71 N 70 19 14.909 W 149 1454.863 10100.64 89.96 62.57 6753.98 6672.18 1363.83 -2432.11 2169.17 1.01 0.78 0.65 5967490.18 592712.93 N 70 1915.049 W 149 1454.063 10131.44 89.34 62.13 6754.17 6672.37 1394.10 -2417.82 2196.46 2.47 -2.01 -1.43 5967504.80 592740.04 N 70 1915.190 W 149 1453.267 10162.80 89.78 61.61 6754.41 6672.61 1424.86 -2403.04 2224.11 2.17 1.40 -1.66 5967519.91 592767.51 N 70 19 15.335 W 149 1452.460 10194.39 90.23 63.08 6754.41 6672.61 1455.91 -2388.37 2252.09 4.87 1.42 4.65 5967534.91 592795.31 N 70 1915.479 W 14914 51.643 10226.54 91.16 63.92 6754.02 6672.22 1487.61 -2374.03 2280.86 3.90 2.89 2.61 5967549.60 592823.90 N 70 19 15.620 W 1491450.803 10258.57 92.01 68.76 6753.13 6671.33 1519.40 -2361.18 2310.18 15.34 2.65 15.11 5967562.79 592853.06 N 70 19 15.746 W 149 1449.948 10288.00 92.29 70.98 6752.03 6670.23 1548.77 -2351.06 2337.79 7.60 0.95 7.54 5967573.25 592880.54 N701915.846 W1491449.142 10318.94 93.22 73.16 6750.54 6668.74 1579.66 -2341.55 2367.19 7.65 3.01 7.05 5967583.11 592909.82 N 70 19 15.939 W 1491448.284 10350.29 92.70 72.83 6748.92 6667.12 1610.97 -2332.39 2397.13 1.96 -1.66 -1.05 5967592.63 592939.65 N 70 19 16.029 W 1491447.410 10381.09 93.42 73.50 6747.28 6665.48 1641.73 -2323.49 2426.57 3.19 2.34 2.18 5967601.89 592968.97 N701916.117 W1491446.551 10412.50 93.77 72.19 6745.31 6663.51 1673.07 -2314.24 2456.52 4.31 1.11 -4.17 5967611.50 592998.81 N 70 19 16.208 W 149 1445.676 1 0443.30 94.35 70.86 6743.13 6661.33 1703.79 -2304.50 2485.66 4.70 1.88 -4.32 5967621 .58 593027.83 N 70 19 16.303 W 149 1444.826 10474.22 94.70 71.00 6740.69 6658.89 1734.59 -2294.43 2514.79 1.22 1.13 0.45 5967632.00 593056.83 N 70 1916.402 W 149 1443.976 10506.27 94.83 71.02 6738.03 6656.23 1766.51 -2284.04 2544.99 0.41 0.41 0.06 5967642.76 593086.90 N 70 19 16.504 W 149 1443.094 10536.86 93.74 70.33 6735.74 6653.94 1796.99 -2273.95 2573.78 4.21 -3.56 -2.26 5967653.20 593115.56 N 70 19 16.604 W 149 1442.254 10568.35 91.57 69.13 6734.28 6652.48 1828.39 -2263.05 2603.28 7.87 -6.89 -3.81 5967664.45 593144.93 N 70 1916.711 W 1491441.393 10598.10 92.70 70.09 6733.18 6651.38 1858.07 -2252.69 2631.15 4.98 3.80 3.23 5967675.14 593172.67 N 70 19 16.812 W 1491440.580 10624.72 91.74 68.93 6732.14 6650.34 1884.62 -2243.38 2656.06 5.65 -3.61 -4.36 5967684.75 593197.47 N 70 19 16.904 W 149 14 39.852 10677.00 91.74 68.93 6730.56 6648.76 1936.74 -2224.59 2704.83 0.00 0.00 0.00 5967704.12 593245.99 N 70 19 17.088 W 149 1438.429 LeQal DescriDtion: NorthinQ ¡y) [fIUSl EastinQ ¡X) [ftUSl Surface: 4649 FSL 1789 FEL S11 T11N R11E UM 5969895.72 590514.78 BHL: 2424 FSL 4366 FEL S12 T11 N R11 E UM 5967704.12 593245.99 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) Plan V-114 (S-G)\V-114\V-114APB2\V-114APB2 Generated 11/25/2003 7:06 PM Page 3 of 3 Scblumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job # W-207 'fJn:-:<- -()'-- I.....( V-114APB1 ~ - ~..... \c: rl:. V-202 ;;.q "\.,..( 'tJ:¡'"7 V-114A ;:.¡O~-- ~.r:::--; 10564457 10687655 10662969 10662970 Log Description USIT CH EDIT USIT (PDCL) SCMT CH EDIT CBUSONIC GR 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: RFC~E'\VED :,. '~...-.- DEC 22 2003 'K~~í\\ b Alaska Oil & \.:;f:1S -':.003. Lommis...O;jon Anchor¡:¡ge 12/151103 NO. 3071 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Borealis Orion e Date BL Color CD 04/16103 1 11/12103 1- 1 ) d ..-<ý...J. 7 11/15/03 2 11/17/03 ~ 1 Jd -:z.:::J I f'. - Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Received b~""""é\\ ,-t ~~~ 12/151103 Schlumberger NO. 3071 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Borealis Orion Color CD - Well Job# Log Description Date BL W-207 ;Q (')::Z- ~rf'lq 10564457 usn 04/16/03 1 V-114APB1 ~ -- " \~&? 10687655 CH EDIT USIT (PDCL) 11/12/03 1- 1 ) ;:¡ . -<rJ. T ' f V-202 ~ {';-< -n~'-::¡ 10662969 SCMT 11/15/03 2 V-114A ;:J( "),":2, .... ~_c.:::-, 10662970 CH EDIT CBUSONIC GR 11/17/03 ~ 1 J,:;¿ ~ ( f' II 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 RECEJVED DEC 22 2003 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth ÞJasKó1 J¡¡ Ò1. \.:;8.S I_DOS. \"ommìs..o.ion AnchOf3ge Received b~,-é"\ '--~ . ~~ Date Delivered: "K~~I\\ b . . MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No V-114A Date Dispatched: 29-0ct-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 1 RE CEIVE D D C 0 1 2003 AtOM! on è Gas Cons. Com niteion Anctunge Received By: ~C:\ ~ "": Please sign and return to: James H. Johnson '-- ","\,"") ...k0:. ~~^,..-.... BP Exploration (Alaska) Inc. - '" Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojh@bp.com LWD Log Delive V1.1, Dec '97 ~~~Ç\"S::, . ~ . . &03--\05 Schlumberger Drilling & Measurements 3940 Arctic Boulevard Suite 300 Anchorage AK 99503 Tel (907) 273-1700 Fax (907) 561-8317 Date: Well Name: Company: API Number: AFE Number: Location: Field: Rig: November 15, 2003 V114A BP Exploration (Alaska) Inc. 50-029-23178-01 BRD5M4l27 V-Pad Borealis Nabors 9ES Drilling and Measurements Field Support: Operations Manager: Field Service Manager: Service Quality Coach: Greg Nutter Gavin Rennick Franklin Alabi Drilling and Measurements Field Crew: Cell Manager(s): Silvia Roblero Mark St. Amour Cell Engineer(s): Sulyn Moy Aldo Benavides SERVICES PROVIDED Services (V -114 onlv) Directional Survey Service VISION* Service Annular Pressure While Drilling At Bit Inclination (AIM) Services Dates 22-0ct-03 to 15-Nov-03 27-0ct-03 to 15-Nov-03 27-0ct-03 to 15-Nov-03 05-Nov-03 to 15-Nov-03 Depth Intervals 108 ft to 11444 ft 2945 ft to 11444 ft 2945 ft to 11444 ft 8248ft to 11444 ft OPERATING STATISTICS Total MWD Pumping Time: Total MWD Time Below Rotary: Total MWD depth interval: Total MWD Runs: 234.8 hr 351 hr 11336 ft 7 Total L WD Pumping Time: Total L WD Time Below Rotary: Total L WD depth interval: Total L WD Runs: 209.6 hr 303 hr 8499 ft 5 JOB PERFORMANCE Directional The final MWD survey point was 11395.50 ft with an inclination of94.39 degrees and an azimuth of75.11 degrees. A survey was straight line projected ahead to TD using an inclination of 94.39 degrees and an azimuth of 75.11 degrees. The final bottom hole location is: Measured Depth: True Vertical Depth: Displacement at Azimuth: 11444 ft 6729.68 ft 4009.17 ft at 120.62 degrees RECEIVED DEC 0 1 2003 ÞJask8 011 & Gas Cons. Commieeion AnchOl'!ge 1 -1Ž~:~ í\\0::> . . Formation Evaluation 12 Y4 in Surface Hole Runs 1. 2 Run 1 was drilled from 108 to 1558 ft. A planned bit trip was done and Run 2 was drilled from 1558 to 2959 ft. MlO Gamma Ray was used to log the surface hole and set the 9 5/8 inch casing below the SVl sand at 2945 ft. No problems occurred with the surface hole. 8 3/4 inch Intermediate Hole Run 5 The original well (V-114) was plugged back to the 9 518 inch casing shoe because the primary target, the Kuparuk C sand, proved not to be economically viable. This well was kicked off with an open-hole cement plug at the 9 5/8 inch casing shoe and steered towards an alternate target. The planned intennediate hole section was drilled with Density Neutron - CDR Service (Resistivity, Density, Neutron), as well as Real-time APWD (Annular Pressure While Drilling). All data was delivered in real-time as well as recorded mode. Run 5 was drilled from 2946 to 8544 ft. No problems were encountered with the L WD tools on Run 5 and all of the recorded mode data was recovered and showed good data quality. 6 1/8 inch Production Hole Run s 6 - 9 The 6 1/8 inch production hole was drilled through a window cut in the 7 inch casing at 8221 ft. Run 6 was a mill run and the only service provided was gravity tool face. Runs 7 through 9 were 4 % inch VISION* Service (triple-combo) with AIM (At the Bit Inclination). Run 7 was a kick off and build to 90 degrees. On run 7 AIM failed at 9127 ft causing a trip out of the hole to replace it. The cause of this failure is still under investigation as of this writing. Run 8 had a real-time ADN and VPWD failure causing a trip from 10840 ft to replace tools. The problem has been isolated to the VPWD real-time bus. Run 9 had another AIM failure. The cause was a ruptured Lithium battery down- hole. Transverse Shocks Transverse shocks were monitored in the MWD and L WD tools. Near the surface casing point and while drilling the HRZ and the Kuparuk cap rock, a high rate of shocks (level 2 and 3) were detected on the L WD tools (Level 0: none, Levell: low severity, Level 2: medium severity, Level 3: high severity). Also, a high level of shock was encountered when milling the window. Shocks were low or none for all of the 6 1/8 inch production run. Lesson(s) Learned When programming the ADN prior to running in the hole for Run 9 we noticed that the battery voltage for our backup ADN was low and that the tool was running on the 2nd of two batteries. It was decided to change to a replacement tool that had just arrived. The temperature was about 20 below and the tool had just been unloaded off the truck. It required about ~ hour of steam to wann it up enough to run it. I believe that this was the correct decision and that had we ran the tool it would have died before the end of the run. 2 . 'I . . Innovation( s) All of the tools were programmed and recorded memories downloaded while placed on tool stands outside or in the pipe shed instead of on the rig floor leading to a substantial reduction in rig time required for the make up and breaking down of the BRA respectively. A data transmission rate of 6 bits per second was used to improve resolution and survey update rates for run 1 through 5. Schlumberger Oilfield Services - Drilling & Measurements appreciates the opportunity to provide BP Exploration (Alaska) Inc. with MWD and L WD services. Sincerely, ¡!'I/Mk.$ c:~ Mark St. Amour Cell Manager Drilling & Measurements 3 . . MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No V-114APB1 Date Dispatched: 3-Nov-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 1 R ECEIVI :0 DEC 01 20(3 ,AJaska C h & Gas Cons. C< mmia8i0n ~("'\s ' /~t Ç.. ('f¿~ ...Y'- -'" Received By: Please sign and return to: -. '- Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ~~~Îf\~ . . f)03 -) 3S MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No V-114APB2 Date Dispatched: 12-Nov-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 !~aaka 0 I & Gas Cons. Anchomge Received By: c::o.~ <1:- C;:.;;.:.:...;,. -~ ì '" '" ("j Ll At". :~ \. 0 ~~ <2'"'~'V""'....... Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ~~~''{\ 'b--;;. Clarifications on well V-114A . Subject: Clarifications on well V-114A Date: Wed, 12 Nov 2003 09:35:25 -0900 From: "Smith, James E" <smithjae@bp.com> To: Winton_Aubert@admin.state.ak.us CC: "Magee, D Neil" <MageeDN@bp.com> . 20 ~ ~ 1ft;. Winton, This note is in regards to well V-114A, Permit number 203-185, API No. 50-029-23178-01-00. The named well is a currently drilling horizontal injector in the Kuparuk Reservoir. To clarify forward planning in regards to the AOGCC requirement for placement of production packer within 200' of the reservoir I submit the following information. The top of the whipstock exit point is at 8221'MD (in the Kuparuk). This is the beginning of the 6-1/8" drilled horizontal in the Kuparuk. The top of the Kuparuk reservoir is 8212'MD We plan to run a 4-1/2" production liner into the Kuparuk and have about 150' of lap inside 7" casing above the whipstock exit point, this will place the top of the production liner at about 8071'MD. Above the production liner we will place the production tubing and production packer. Due to the expected length of the tailpipe (about 50') it will be necessary to place the production packer near 8021'MD. This leaves the packer at 191' above the top of the Kuparuk and does meet AOGCC regulations. Since the measured distance may vary due to pipe length, I wish to elucidate our plans in the event the final packer placement may slightly exceed 200' above the Kuparuk reservoir due to variation in casing and tool lengths. We will endeavor to comply as closely as possible to the 200' separation of the production packer and the reservoir of planned injection. Regards, Jim Smith BP Drilling 907-564-5773 . ([]~ ~~~~æ . FRANK H. MURKOWSKI, GOVERNOR A.I,A.SKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe bay Unit PBU V-114A BP Exploration (Alaska), Inc. Pennit No: 203-185 Surface Location: 4649' NSL, 1789' WEL, Sec. 11, T11N, RIlE, UM Bottomhole Location: 2669' NSL, 1771' EWL, Sec. 12, T11N, RIlE, UM Dear Mr. Crane Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). ... BY ORDER 0WHE COMMISSION DATED this~ day of October, 2003 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encI. Exploration, Production and Refineries Section wGJ+. J¡;> l !>, l z..oo s .. STATE OF ALASKA .. ALASKA ~ AND GAS CONSERVATION COfvWl!l!tSSION PERMIT TO DRILL / 20 MC 25.005 / 1a. Type of work o Drill ail Redrill 1b. Current Well Class ~;PloratOry fr'8:velopment Oil o Multiple Zone ORe-Entry o Stratigraphic Test Service At> Development Gas o Single Zone 2. Operator Name: 5. Bond: IBI Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU V-114A ,/ 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11521 TVD 6676 Prudhoe Bay Field I Borealis Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 028240 4649' NSL, 1789' WEL, SEC. 11, T11 N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 1679' NSL, 1442' WEL, SEC. 11, T11N, R11E, UM Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2669' NSL, 1771' EWL, SEC. 12, T11N, R11E, UM 2560 6900' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan RKB 15. Distance to Nearest Well Within Pool Surface: X-590515 y- 5969896 . Zone-ASP4 (Height above GL): = 83.8' feet V-109 & V·117 are 2400' away at 8140' MD 16. Deviated Wells: 17. Anticipated pressure (see 20 MC 25.035) ,/ 0 Kickoff Depth 3100ft Maximum Hole Angle 93 Max. Downhole Pressure: 3440 psig. Max. Surface Pressure: 2779 . psig 18. Casing Program ...... Setting Depth uuantltybf Cement Size Specifications Top Bottom (c.f. or sacks) Hole Casina Weiaht Grade Couolina Lenath MD TVD MD TVD IS4- (includina staae data) 8-3/4" 7" 26# L-80 BTC-M 8460' Surface Surface 8460' 6752' ~ sx Class 'G',-êetr'sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3466' 8055' 6561' 11521 ' 6676' ~sx Class 'G' '~CJ.z.. ~1'5 \l-I~ 19. PRESENT WELt.iCONDITIONSUMMARY(To be complete<;Jf()rRedrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 Junk (measured): 8340 6876 3698 3698 3330 NIA iI II Size) I:,·. I I'I;{i"I: ,Iii II I'i iI .",..I\I1!-;?iI 'c. TVD ~tfllctllr~1 Conductor 108' 20" 260 sx Arctic Set (Approx. 108' 108' ~ , 2946' 9-5/8" 525 sx AS Lite, 325 sx Class 'G' 2946' 2699' li~tA - Prnrh Ictinn -I"".; n . ....... I inAr - - -.. ¥. -. . ULI '0' ~7 Perforation Depth MD (ft): None perfOration Depth TVD (ft,. "¿Gas A. ConS. COffllllÎllkJn 20. Attachments IBI Filing Fee o BOP Sketch IBI Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report IBI Drilling Fluid Program 1B120 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Neil Magee, 564-5119 Printed Name Low~,Crane Title Senior Drilling Engineer ~.r<"'¿-( IC¿~ Prepared By Name/Number: Sianature - Phone 564-4089 Date je. - ~<:;,. - ~. > Terrie Hubble, 564-4628 (/ Commission Use Only Permit To Drill _j 131 ,API Number: I Permit APprçvat0 \ :~ I See cover letter for Number: 2D3 - S- 50-029-23178-01-00 Date: i L other requirements Conditions of Approval: Samples Required DYes ~_No Mud Log Required 'i Yes 'IXf No Hydrogen Sulfide Measures DYes [1(No Directional Survey Required Yes No Other: T.e.~t- ßOP£ +0 t;;O()O p!.l. Qdg\na\ Signed By /0 1~\ ~1)) Søh PaIn BY ORDER OF Aooroved Bv: ..--. '""' COMMI£SIDNER THE COMMISSION Date Form 10-401 Revised 3/2003 l.,i 1''':( l,.: [ r~/4' SUDmit I~- Duplicate e e IWell Name: IV-114A Drill and Complete Plan Summary I Type of Well (service I producer I injector): Injector Surface Location: X = 590,514.78' Y = 5,969,895.72' As-Built (Slot N-U) 4648'FSL, 1788'FEL, Sec. 11, T11N,R11E Target Location: X = 590,900.02' Y = 5,966,930.00' Top Kuparuk 1679'FSL, 1442'FEL,Sec. 11, T11N, R11E , Bottom Hole Location: X = 594,100.00' Y = 5,967,960.00' 2669'FSL,3508' FEL, Sec. 12,T11N,R11E I AFE Number: I BRD5M4127 I I Rig: 1 Nabors 9ES ~11521' I- 1 TVD: 16676' I· I RT/GL: 128.5' 1 I RKB: 183.8' I c I 1 1 Well Design (conventional, slim hole, etc.): 13 String Horizontal Injector I Objective: 1 Kuparuk Top of productive interval in V-114A (Kuparuk C target) is 2400 ft away from V-109 and V-117, /' the nearest wellbores. The depth of V-114A at this point is 8140' MD. The well approaches to within 6900 ft of the nearest Prudhoe Say property line. . CasingITubing Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tbg O.D. / / MDfTVD MDfTVD bkb 42" Insulated 20" 91.5# H-40 WLO 80' GL 110/110 * 12 ]4" 95/8" 40# L-80 BTC 2946' GL 2946/2792' * 8-3/4" 7" 26# L-80 BTC-m 8460' GL 8460'/6752' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3466' 8055'/6561 ' 11521 '/6676' TubinQ 31--2" 9.2# L-80 TC- 7927' GL 7927'/6526' * Indicates Existing * 9-5/8" Burst 5,750 psi, collapse 3,090 psi ** 7" Burst 7,240 psi, collapse 5,410 psi V-114A Drilling Program- AOGCC Page 1 e e Mud Program: 8-3/4" Intermediate Hole: Interval Density (ppg) UG-Ku B 9.7- .3- 2946'- 8460' : PV yp CI Ph LSND HTHP @100F 18-24 22-30 <600 9.0-9.5 4-8 6-1/8" Production Hole (8140' -11521'): Flo-Pro Interval Density Chloride yp PV pH API (ppg) Filtrate Upper 9.3 25-30K 24 10 9.0-9.5 4-6 Interva! Hydraulics: d" H I I " R D "II" nterme late o e: 8-3 4 otary rI mg Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 2946' - 8460' 550 - 4" 17.5# 240 4200 11.7 N/A 3x14,3x15 .969 600 Production Hole: 6 1/8" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 8140' - 11521' 300 4" 17.5# 200 3000 11.5 N/A 6x10 .460 Di rectional: Ver. I Anadrill V-114APB1(P15) KOP: 13100' Maximum Hole Angle: 93 deg at 8513' MD Close Approach Wells: All wells pass 1/200 minor risk criteria. IFR-MS corrected surveys will be used for survey validation. V-114A Drilling Program- AOGCC Page 2 -- e Lo ram: Production Hole Drilling: Open Hole: Cased Hole: Drilling: Time) Open Hole: Cased Hole: MWD/GR/AZM DENS/NEU,RES (Real Time) USIT cement evaluation MWD/PWD/GR/RES/NEU/AZM DENS/AIM(Real None None Formation Markers: Formation Tops TVDss Estimated pore pressure, PPG UG4A 2910 UG3 315 UG1 3660 Ma 3945 Hydrocarbon bearinq, 8.7 ppg EMW Na 4190 Hydrocarbon bearinq, 8.6 ppq EMW Oa 4350 Hydrocarbon bearing, 8.5 ppg EMW Obf Base 4705 Not Hydrocarbon bearing, 8.4 ppg EMW CM2 (Colville) 5085 Fault #1 5475 CM1 5720 Fault #2 6160 THRZ 6260 BHRZ (Kalubik) 6445 K-1 6490 TKUP 6535 Kuparuk C 6535 Hvdrocarbon Bearing, 3045 psi, 9.0 ppg EMW Fault #3 6560 LCU (Kuparuk B) 6615 Hydrocarbon Bearinq, 3440 psi, 10.0 ppg EMW Kuparuk A 6690 Not Drilled, 3440 psi, 9.9 ppq EMW Miluveach NA \o.~ I' Testin : Test Point Depth Test Type Surface Casing Shoe 20' min from LOT surface shoe Intermediate Casing 20' min from 7" shoe FIT Shoe EMW 14.4 ppg EMW Achieved 13.0 ppg EMW Target based on 9.3 ppg MW and a worst case 11.5 drillin ECD. V-114A Drilling Program- AOGCC Page 3 e e Cement Calculations: Casin Size 7" Intermediate Longstring Basis: Tail: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' shoe Cement Placement: From shoe to 7640' MD Lead: Based on TOC 500' above top of Schrader Ma +30% excess volume Cement Placement: From 7640' to 4026' MD 500' above Ma sand Total Cement Volume: Tail 32 bbls I 180ft I sks of Dowell Premium "G" at 13.5 and 1.80 cf/sk Lead 125 bbls I 703 ft I ~ sks of Dowell Premium "G" at 15.8 and 1.16 cf/sk Casin Size 4-1/2" Production Liner Basis: Tail: Based on TOC 150' above top of production liner (with 4" DP) formation + 30% excess + 80' shoe Cement Placement: From shoe to 7850' MD Total Cement Volume: Lead 78 bbls I 437ft I sks of Halliburton Premium "G" with Gasblock at 15.8 V-114A Drilling Program- AOGCC Page 4 e e Well Control: The intermediate/production hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test of 3500 psi for casing integrity considerations and a tubing test of 4000 psi, the BOP equipment will be tested to 5000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: 3440 psi @ 6615' TVDss - Kuparuk B Sand 2779 psi @ surface / (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Maximum surface pressure: · Planned BOP test pressure: · Planned completion fluid: 5000 psi ./' 9.2 ppg filtered brine / 6.8 ppg diesel Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-114A Drilling Program- AOGCC Page 5 e e SIDETRACK AND COMPLETION SUMMARY Summary of Rig Operations: 1. Mu 8-3/4" clean out assembly and clean out cement from surface casing to approximately 3000'. Swap over to new9.7 ppg LSND mud system. /' 2. MU 8-3/4" drilling assembly with MWD/LWD (page 3) and RIH to TOC. 3. Sidetrack well and drill ahead to =/- 100' above HRZ, ensure mud is in condition to 10.3 ppg and perform short trip as needed. 4. Drill ahead to intermediate hole TD 90' TVD below top Kuparuk C in order to log entire Kuparuk C interval. /' 5. Run and cement the 7" production casing. Test casing to 4000 for 30 minutes on plug bump. 6. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. 7. Rig up Schlumberger and run USIT from ETD to surface casing shoe. 8. RU e-line. RIH with GR-CCUjunk basket to float collar. Make up and run 7" EZSV and set on depth such that Baker window top is at top Kuparuk C. 9. Make up and RIH with 7" whipstock assembly. Set whipstock such that top of window is at to.£,..-r Kuparuk C. Displace mud to 9.3 ppg FloPro mud and mill window. 10. Perform FIT test to 12.0 ppg EMW. POOH and lay down milling assembly. 11. MU 6-1/8" directional assembly and drill ahead as per directional plan to proposed TD at 11,520' MD/6676'TVD. Short trip as required and condition hole for running 4-1/2" liner. 12. Run 4-1/2" solid liner. The liner will extend approximately 150' above the 7" window. Cement liner as directed. Set liner top packer. Release from liner and displace well to filtered 9.3 ppg filtered KCL brine and POOH. 13. TCP perforate liner in select Kuparuk C interval. . 14. RIH with casing scraper and POOH laying down drill pipe. (Contingency) 15. Run a 3-1/2",9.2#, TC-II, L-80 completion assembly. Set packer and test th~ing to 4000 psi and annulus to 3500 psi for 30 minutes. 16. Shear DCK valve and install TWC. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 18. RU hot oil truck and freeze protect well by pumping diesel to DCR shear GLM. Allow to equalize. Rig down and move off. / V-114A Drilling Program- AOGCC Page 6 e e V-114A Drilling Programme Job 4: Drillina Intermediate Hole Hazards and Contingencies þ> V-114A is expected to cross two faults in the intermediate hole section. The approximate location of the first fault is 5475'TVD ss (+/- 200') and has an estimated throw of 100'. The second fault is expected to be encountered at 6160' TVD ss(+/-200) and has a throw of 120'. Lost circulation is considered a minimum risk however losses have been encountered due to "breathing" in previous wellbores which encountered faults in the Colville. If losses/breathing is encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures and adjust drilling practices to reduce breathing phenomena. þ> KICK TOLERANCE: In the case scenario of 10.0 ppg pore pressure in Kuparuk B interval, gauge hole, a fracture gradient of 14.4 ppg at the surface casing shoe, 10.3 ppg mud in the hole the kick tolerance is 45 bbls. ~ There are no "close approach" issues with the intermediate hole interval of V-114A. ~ LWD data is critical in the lower interval of the intermediate hole section (Kuparuk interval). ROP restrictions/Mad passes are not anticipated in the Schrader/Ugnu interval for data collection. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. ERD Recommended Practice Section 5.2" Operating Practices" .:. "Shale Drilling- Kingak & HrZ" Job 6: Case & Cement Intermediate Hole Hazards and Contingencies þ> The interval is planned to be cemented with a lead and tail slurry. The lead slurry will cover from 500' above the Kuparuk to 500' above the Schrader Ma and the tail will cover from the shoe to 500' above the top of Kuparuk interval. þ> Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition a LCM pill composed of "G Seal" may be placed across the Schrader and Ugnu to help arrest mud dehydration if losses were experienced while drilling this interval. þ> Ensure a minimum hydrostatic equivalent of 10.3 ppg on the HRZ during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Ensure the lower production cement has reached at least a 70BC thickening value prior to freeze protecting. Pump approximately V2 volume of casing-casing annulus prior to freeze. After freeze protecting the 7" x 9-5/8" casing outer annulus with 55 bbls of dead crude (2240' MD, 2075'TVD), V-114A Drilling Program- AOGCC Page 7 e e the hydrostatic pressure will be 7.9 ppg vs 8.6 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 110 psi underbalance to the open hole. (Approximately 25 bbls of 12.5 ppg mud ahead of the diesel would be required to balance this pressure.) Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" Job 7: Set Whipstock and Drill 6-1/8" Horizontal Production Hole Hazards and Contingencies ~ A whipstock will be set in the 7" intermediate casing to facilitate kicking off the horizontal production hole. Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have accumulated there. ~ There are no "close approach" issues with the production hole interval of V-114A. ~ Mud losses of 10-80 bph have been encountered in offset horizontal sections. In particular V-117 lost 5400 barrels of mud while drilling this interval. Contingency LCM material and mud product should be available at the rigsite/mud plant. ~ There is one fault in the horizontal wellbore at approximately 10,000' (+/- 150'). The fault has an estimated throw of 30'. /' ~ Exercise caution that the well course does not deviate to the KuparuK B reservoir. The reservoir pressure is 10.0 ppg vs the 9.3 ppg mud weight to be utilized whilst drilling the Kuparuk C reservoir. . ).> Under no circumstances add any LCM (including Walnut sweeps, cellulose material) other than calcium carbonate for losses < 50 BPH without prior discussions with the Drilling Engineer/Asset Production Engineer. Significant mud losses> 50 BPH may include the use of cellulose material to arrest losses. See LCM discussion in MI Mud Program. ).> Expect a certain amount of geo-steering , but significant changes to the planned directional profile should be discussed with the Drilling Manager/Operations Drilling Engineer. ).> There are no restrictions concerning adding lubricants to the mud whilst drilling the horizontal hole. Ensure that there is 0.5% EP Mudlube in the mud prior to displacement. Lubetex/Flolube concentrations of 1.5% can be maintained as required once open hole is cut to improve weight transfer in the critical kick-off section. Reference RPs .:. "Standard Operating Procedure for Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" V-114A Drilling Program- AOGCC Page 8 e . .:. "Lubricants for Torque and Drag Management" .:. ERD Recommended Practice Section 5.2 Operating Practices .:. Whipstock Sidetracks- RP Operational Specifics Job 9: Install 41h" Production Liner Hazards and Contingencies ~ Differential sticking could be a problem. The mud system will be approximately 120 psi over balance to the Kuparuk formation. Minimize the time the pipe is left stationary while running the liner. ~ In the event additional weight is required to get the liner to TO, have 6 stands of weight pipe in the derrick. ~ Keep in mind that the Kuparuk interval will be open prior during swap to completion brine. Avoid introducing lighter than 9.8 ppg completion brines during swap after setting liner hanger. Reference RPs .:. "Running and Cementing a Liner Conventionally" Job 10: Perforate Well Hazards and Contingencies ~ The Kuparuk interval of the well will be TCP perforated prior to running the completion. After placing a KCL brine perf pill weighted to 9.3 ppg the well will be perforated across a 9.0 ppg EMW reservoir for an overbalance of 100 psi. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. ~ The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot reach depth due to cement/fill. Reference RPs .:. See attached Initial Perforating Procedures V-114A Drilling Program- AOGCC Page 9 e e Job 12: Run Completion Hazards and Contingencies ~ Keep in mind that the Kuparuk interval will be open during the running of the completion. Watch hole fill closely, verify no light fluids are introduced down hole and verify proper safety valves are on the rig floor while running this completion. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus Job 13: ND/NUlRelease Ria Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus V-114A Drilling Program- AOGCC Page 10 TREE;: 4-1/16"Crvv WELLHEAD = FMC ~~""",,,~_,~~>~_~,·.___·_.'''m~~~~w~~,w,'ú·''âh_.w_,Nm"~N . ACTUATOR= N/A KB:^ELE\T~~^~~m^'^'^^83:ã; =""","wmmNm=wN.-.-.-."'^?_"h-.y'_"W^~"='==''''''''''''''''''''~''W^V.' BF. ELEV = 55.8' KÓP~~~~_~^"'mm"mm~'m'mmw·'2rõo' ."""" w,~ ,~~~~~~.I~.~.....w..m.m...'.m~~~.'m~ ??' Datum MD = ·~=.==Y_W"'NN.W.=·N.____'·.w.w.'='== Datum lVD = ?' SS e V -114A ~NOTES' ~ I 9-5/8" CSG, 40#, L-80, 10= 8.835" 31/2" 9.2 # L-80 TC-II I Minimum 10 = 2.813" @ 2200' 7" Baker Whipstock (TOW) H 8140' I 9-5/8" HES 'EZSV' I- 7" CSG, 26#,L-80,O.0383 bPf,ID=6.276'H 8460' 1- 13-1/2" HES X Nippple , 10= 2.813" ST MD lVD DEV TYÆ VLV LATCH PORT DATE 1 6200 MMG Dum RK 2 5700 MMG Dum RK 3 5100 MMG DCK RKP 4 4200 MMG Dum RK 5 3300 MMG Dum RK 6 2600 MMG Dum RK H 7"x 4 1 /2 8-3 Baker Packer I H'x nipple with 2.813 ID H"X" nipple with 2.813 ID Î Saker HMC Liner Hanger with ZXP H pup JT WI RA TAG HPUPJTWI RA TAG I PUPJTWI RA TAG Perforation intervals: Gun Type: I PBTD H 11435' 1 4-112" Solid Liner, 12.6 #, L-80 (Top @ 8,055') H 11520' DATE REV BY COMMENTS DA TE REV BY 10/29/03 nm HORIZ COMPLETION (PB1/P15 COMMENTS PRUDHOE SAY UNrr WELL: V-114A PERMrr No: API No: BP Exploration (Alaska) e e V-114A Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Hole Section: ,¡ · The intermediate hole section will be drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 10.0 ppg pore pressure. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices and close monitoring of PWD data will contribute to favorable hole conditions. · V-114A is expected to cross two faults in the intermediate hole section. The approximate location of the fault is 5475'TVD ss (+/- 200') and has an estimated throw of 100'. The second fault is expected at 6160' TVD ss (+/-200') and has a throw of 120'. Lost circulation is considered a minimum risk however losses have been encountered due to "breathing" in previous wellbores which encountered faults in the Colville. Loss circulation is considered to be a minor risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. Production Hole Section: · Mud losses of 10-80 bph have been encountered in offset horizontal sections. In particular V-117 lost 5400 barrels of mud while drilling this interval. Contingency LCM material and mud product should be available at the rigsite/mud plant. · V-114A is expected to cross one fault in the horizontal section at approximately 10,000' MD. This fault has an estimated throw of 30' and lost circulation is considered a minimum risk. j . The horizontal section will be drilled with a mud weight of 9.3 ppg. Exercise caution that the wellbore does not dip down into the Kuparuk B interval which has a 10.0 ppg formation pressure. HYDROGEN SULFIDE - H2S l This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies V-114A PB1 (P2) Proposal Schlumberger Latitude N 70 1930.303 N 70 1930.294 N 70 1930.107 W 1491614.111 N701930.107 W1491614.111 N 70 1929.487 W 149 16 15.352 3200.00 30.06 210.11 2907.40 2825.60 565.07 -1006.48 -642.63 2.00 0.47 -3.91 -74.70G 5968881.65 589884.39 N701929.073 W1491616.122 3297.79 30.63 206.41 2991.80 2910.00 591.64 -1049.99 -666.00 2.00 0.58 -3.79 -71.50G 5968837.87 589861.55 N 70 1928.645 W 1491616.804 3300.00 30.64 206.32 2993.70 2911.90 592.28 -1051.00 -666.50 2.00 0.64 -3.72 -71.43G 5968836.86 589861.07 N 70 1928.635 W 149 16 16.819 3400.00 31.33 202.68 3079.44 2997.64 622.76 -1097.83 -687.83 2.00 0.69 -3.65 -68.30G 5968789.77 589840.31 N701928.174 W1491617.441 3500.00 32.12 199.18 3164.50 3082.70 656.47 -1146.94 -706.59 2.00 0.79 -3.50 -65.33G 5968740.45 589822.14 N 70 1927.692 W 149 16 17.989 3583.90 32.85 196.37 3235.27 3153.47 687.22 -1189.84 -720.33 2.00 0.87 -3.35 O.OOG 5968697.39 589808.92 N 70 1927.270 W 149 16 18.390 3657.14 32.85 196.37 3296.80 3215.00 715.03 -1227.96 -731.53 0.00 0.00 0.00 O.OOG 5968659.14 589798.19 N 70 1926.895 W 1491618.716 4186.85 32.85 196.37 3741.80 3660.00 916.19 -1503.67 -812.51 0.00 0.00 0.00 O.OOG 5968382.50 589720.55 N 70 1924.183 W 1491621.079 4526.11 32.85 196.37 4026.80 3945.00 1045.03 -1680.24 -864.37 0.00 0.00 0.00 O.OOG 5968205.33 589670.82 N 70 1922.446 W1491622.5e 4817.75 32.85 196.37 4271.80 4190.00 1155.78 -1832.04 -908.95 0.00 0.00 0.00 O.OOG 5968053.02 589628.08 N 70 1920.953 W 1491623.8 5008.20 32.85 196.37 4431.80 4350.00 1228.11 -1931.17 -938.07 0.00 0.00 0.00 O.OOG 5967953.56 589600. 16 N 70 19 19.978 W 1491624.742 5430.79 32.85 196.37 4786.80 4705.00 1388.59 -2151.11 -1002.67 0.00 0.00 0.00 O.OOG 5967732.87 589538.22 N 70 19 17.815 W 1491626.627 5643.97 32.85 196.37 4965.89 4884.09 1469.55 -2262.07 -1035.26 0.00 0.00 0.00 -113.12G 5967621 .54 589506.98 N 70 1916.724 W 149 16 27.577 5700.00 32.03 192.48 5013.18 4931.38 1491.29 -2291.16 -1042.76 4.00 -1.47 -6.94 -109.84G 5967592.36 589499.83 N 70 1916.438 W 149 1627.796 5800.00 30.88 185.13 5098.52 5016.72 1532.30 -2342.63 -1050.79 4.00 -1.15 -7.35 -103.57G 5967540.80 589492.42 N 70 19 15.932 W 149 16 28.030 5879.29 30.28 179.01 5166.80 5085.00 1566.73 -2382.90 -1052.26 4.00 -0.76 -7.72 -98.29G 5967500.52 589491.43 N 70 1915.536 W 1491628.073 5900.00 30.17 177.38 5184.69 5102.89 1575.98 -2393.31 -1051.94 4.00 -0.53 -7.88 -96.89G 5967490.11 589491.89 N 701915.433 W 149 1628.063 6000.00 29.93 169.40 5271.29 5189.49 1622.11 -2442.95 -1046.20 4.00 -0.24 -7.98 -89.98G 5967440.55 589498.22 N 70 19 14.945 W 149 16 27.896 6100.00 30.17 161.42 5357.88 5276.08 1670.47 -2491.31 -1033.60 4.00 0.24 -7.98 -83.07G 5967392.35 589511.41 N 70 19 14.469 W 149 16 27.528 6200.00 30.89 153.67 5444.05 5362.25 1720.82 -2538.15 -1014.20 4.00 0.71 -7.75 -76.39G 5967345.75 589531.37 N 70 19 14.009 W 149 1626.962 Report Date: Client: Field: Structure / Slot: Well: Borehole: UWIIAPI#: Survey Name / Date: Tort I AHD / DDI/ ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid NIE YIX: Grid Convergence Angle: Grid Scale Factor: October 28, 2003 BP Exploration Alaska Prudhoe Bay Unit - WOA ~:~~~/PlanV-114(S-G) øbility V-114APB1 Feasl 50029 V-114A PB1 (P2)/October29, 2003 125.757" /22644.48 It /6.552/3.354 NAD27 Alaska State Planes, Zone 04, US Feet N 70 1938.972, W 1491557.365 N 5969895.720 ItUS, E 590514.780 ItUS -+{).69122375· 0.99990931 Comments 9-5/8" Csg PI KOP Cry 211 00 UG4A End Cry UG3 UG1 Ma Na OA OBf Base Cry 4/100 CM2 Well Design Ver 3.1 RT -SP3.03-HF1.2 Bld( d031 rt-546 ) Survey / DLS Computation Method: Vertical Section Azimuth: S~.III udY Vertical Section Origin: , III TVD Reference Datum: TVD Reference Elevation: Sea Bed / Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Carr Mag North .> True North: Local Coordinates Referenced To: Minimum Curvature / Lubinski 150.800· N 0.000 It, E 0.000 It KB 81.8 It relative to MSL 54.000 It relative to MSL 25.212· 57548.719 nT 80.807· October 29, 2003 BGG M 2003 True North +25.212· Well Head e Plan V-114 (S-G)\V-114\V-114A PB1\V-114A PB1 (P2) Generated 10/29/20038:57 AM Page 1 of 2 Comments Fault #1 eM1 6632.53 38.42 125.95 5801.80 5720.00 1955.45 -2717.93 -854.95 4.00 2.35 -5.26 -53.40G 5967167.93 589692.76 N 70 19 12.241 W 1491622.314 6700.00 40.08 122.59 5854.05 5772.25 1993.62 -2741.95 -819.67 4.00 2.46 -4.99 -50.79G 5967144.34 589728.32 N 70 1912.005 W 14916 21.284 6800.00 42.71 118.02 5929.08 5847.28 2050.53 -2775.23 -762.58 4.00 2.62 -4.57 -47.36G 5967111.75 589785.80 N 70 1911.677 W 1491619.618 6900.00 45.49 113.89 6000.90 5919.10 2107.57 -2805.61 -700.02 4.00 2.79 -4.13 -44.39G 5967082.13 589848.72 N 70 1911.379 W 1491617.792 7000.00 48.41 110.15 6069.17 5987.37 2164.48 -2832.95 -632.28 4.00 2.92 -3.74 -41.84G 5967055.61 589916.78 N701911.110 W1491615.816 7100.00 51.44 106.74 6133.55 6051.75 2220.97 -2857.10 -559.70 4.00 3.03 -3.41 -39.64G 5967032.34 589989.64 N 701910.872 W 149 16 13.6jt 7200.00 54.57 103.61 6193.72 6111.92 2276.78 -2877.96 -482.63 4.00 3.12 -3.13 -37.76G 5967012.42 590066.95 N 701910.667 W 149 16 11.4 Fault #2 7285.83 57.31 101.11 6241.80 6160.00 2323.92 -2893.15 -413.18 4.00 3.19 -2.91 -36.36G 5966998.06 590136.57 N 70 19 10.518 W 149 169.4 7300.00 57.76 100.71 6249.40 6167.60 2331.62 -2895.41 -401.44 4.00 3.23 -2.80 -36.14G 5966995.94 590148.33 N 70 1910.496 W 149 169.080 7400.00 61.02 98.02 6300.32 6218.52 2385.24 -2909.38 -316.54 4.00 3.26 -2.70 -34.77G 5966983.00 590233.39 N 70 1910.358 W 149 166.602 Top HRZ 7489.87 64.00 95.74 6341.80 6260.00 2432.16 -2918.91 -237.41 4.00 3.31 -2.54 -33.72G 5966974.43 590312.62 N 70 19 10.265 W 149164.293 7500.00 64.33 95.49 6346.22 6264.42 2437.36 -2919.80 -228.33 4.00 3.33 -2.46 -33.61G 5966973.65 590321.71 N 70 1910.256 W 149 164.028 End Crv 7520.01 65.00 95.00 6354.78 6272.98 2447.59 -2921.45 -210.33 4.00 3.34 -2.44 O.OOG 5966972.21 590339.73 N 70 1910.240 W 149 16 3.503 Base HRZ 7927.05 65.00 95.00 6526.80 6445.00 2654.95 -2953.61 157.18 0.00 0.00 0.00 O.OOG 5966944.50 590707.56 N 70 199.923 W 1491552.779 K-1 8033.53 65.00 95.00 6571.80 6490.00 2709.19 -2962.02 253.31 0.00 0.00 0.00 O.OOG 5966937.25 590803.78 N 70 199.841 W1491549.973 Target 8140.01 65.00 95.00 6616.80 6535.00 2763.43 -2970.43 349.45 0.00 0.00 0.00 O.OOG 5966930.00 590900.00 N70199.758 W1491547.168 Top Kuparuk / e 8140.01 65.00 95.00 6616.80 6535.00 2763.43 -2970.43 349.45 0.00 0.00 0.00 O.OOG 5966930.00 590900.00 N 70 19 9.758 W 1491547.168 Fault #3 8199.16 65.00 95.00 6641.80 6560.00 2793.57 -2975.10 402.86 0.00 0.00 0.00 O.OOG 5966925.97 590953.46 N 70199.712 W 1491545.610 LeU / Kup B 8329.30 65.00 95.00 6696.80 6615.00 2859.86 -2985.38 520.35 0.00 0.00 0.00 O.OOG 5966917.11 591071.06 N 70 19 9.611 W 1491542.181 owe 8412.12 65.00 95.00 6731.80 6650.00 2902.05 -2991.92 595. 13 0.00 0.00 0.00 O.OOG 5966911.47 591145.90 N 70 199.546 W 1491539.999 TO / 7" Csg 8460.01 65.00 95.00 6752.04 6670.24 2926.45 -2995.70 638.36 0.00 0.00 0.00 O.OOG 5966908.21 591189.17 N 70 199.509 W 149 1538.737 Survey TVDe: Raw Proposal LeQal DescriDtion: e NorthinQ IY\ IftUS] EastinQ IX) IftUS] Surface: 4649 FSL 1789 FEL S11 T11N R11E UM 5969895.72 590514.78 Target: 1678 FSL 1442 FELS11 T11N R11E UM 5966930.00 590900.00 BHL: 1653 FSL 1153 FELS11 T11N R11E UM 5966908.21 591189.17 Well Design Ver 3.1 RT -SP3.03-HF1.2 Bld( d031 rt-546 ) Plan V-114 (S-G)\V-114\V-114A PB1\V-114A PB1 (P2) Generated 10/29/20038:57 AM Page 2 of 2 bp e e WELL FIELD Prudhoe Bay Unit - WOA STRUCT1JRE V-Pad V-114APB1 MagnetícParameters Model: BGGM2003 SurfaœLocation lat" N701938.972 Lon; W1491557.365 NAD27 Alaska stale Planes. Zone 04. US Feel Northing: 5969895.72f1.US GridConv; +0.69122375' Eastiog 590514.78 flUS Scale Fact: 0.999909307 Miscellaneous Slot: PlanV-114 (S-G) Plan V-114AP81 (P2) Dip: 8O.80r MagDec: +25.212' Date: October29,2003 FS' 5754B.7nT o 1000 2000 3000 o ......RRt.~!Y.)).~!~ 1000 2000 Schlumberger lVD Ref: KB (81.80 ftabove MSL) 5fvyDate: Odober29,2003 o 1000 2000 g 3000 3000 0 0 0 ~ ~ II Q) ~ en 4000 4000 0 > I- 5000 6000 7000 ............................................ 5000 6000 ......................... ..................................... ....................... ................................ 7000 o 1000 2000 3000 Vertical Section (ft) Azim = 150.8°, Scale = 1(in):1000(ft) Origin = 0 N/-S, 0 EI-W 80.807" +25.212' -2000 o -500 -1000 ^ ^ ^ z g o o ~ g ~ -1500 II Q) <õ <.> (j) (j) Y Y Y -2000 -2500 -3000 -3500 -2000 e FIELD Prudhoe Bay Unit - WOA Date' Octobet29,2003 FS: 57548.7nT Surface Location Lat: N701938.9n Lon: W1491557.365 NAD27 Alaska State Planas, Zone 04, US Feet Nofthing: 5969895.nflUS GriðConv: +0.69122375' Easting' 590514.78 ftUS Scale Fact: 0.999909307 -1500 -1000 -500 ,..........,,,....,,.....,,. · . ...",.........."...H......',......,.....,'...,.......,.,.........,......... · . · . · . ."...~.u ..............,............ ,'........,.,........... EndCrv Y·116Fn 1 .................H.......'......................., V-114 Field Surveys -1500 -1000 -500 0 <<< W Scale = 1 (in):500(ft) E >>> e Schlumberger STRUCTURE V _ Pad Miscellaneous Slot Plan V-114 (S-G) V.114APB1 (P2) TVDRef: KB (81.80 ftaboYaMSL) Srvy Dale: October 29, 2003 o 500 1000 .....,.,................-¡-......... ....,."................,.:-..... o ~. -V ....H.."..........."...........,,,........,...........,,,......... · . · . · . · . -500 · . · . · . · . · . · . · . ·.,·t····· ..,...... ........ ... .......... +.. ....".,.... .....,. ...... ...... ,+.... -1 000 / · , ..,".......................................................... · . · . · . -1500 "..t .,.,.!...... -2000 ............".........., ..................,_.... -2500 ß~t~ ! ,. .... , .," ··BI F' ' ».;.,.. -3000 , . ..,\-~ . I.' : Y·116Fn2· : TD/7"Csg . ...».............................,.. -3500 500 1000 bp Report Date: Client: Field: Structure / Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort / AHD I DDII ERD ratio: Grid Coordinate System: Location LatILong: Location Grid N/E Y/X: Grid Convergence Angle: Grid Scale Factor: Comments Top Whipstock Base Whipstock KOP Crv 10/100 V-114A (P15) Proposal Schlumberger October 28, 2003 BP Exploration Alaska Prudhoe Bay Unit - WOA ~:~~~ / Plan V·114 (S-G) II b 1111 ty V-114A Feasl I 50029 V-114A (P15) / October 28, 2003 173.734· /7651.05 It /6.360 /1.144 NAD27 Alaska State Planes, Zone 04, US Feet N 70 19 38.972, W 14915 57.365 N 5969895.720 ItUS, E 590514.780 ItUS <{).69122375· 0.99990931 Survey / DLS Computation Method: Vertical Section Azimuth: st dy Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed / Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: Minimum Curvature / Lubinski 150.800· N 0.000 It, E 0.000 It KB 81.8 It relative \0 MSL 54.000 It relative to MSL 25.214· 57548.637 nT 80.807" October 28, 2003 BGGM 2003 True North +25.214· Well Head e WellOesign Ver 3.1RT·SP3.03-HF1.2 Bld( d031rt-546) Plan V-114 (S-G)\V-114\V-114A\V-114A (P15) 8400.00 84.14 77.44 6686.80 6605.00 2868.78 -2952.78 596.97 10.00 7.67 -6.51 -39.40G 5966950.63 591147.27 N 70 19 9.931 W 149 15 39.945 90· PI 8475.70 90.00 72.64 6690.68 6608.88 2887.36 -2933.27 669.96 10.00 7.75 -6.34 -39.15G 5966971.02 591220.01 N 70 1910.123 W 1491537.815 8500.00 91.88 71.11 6690.28 6608.48 2892.03 -2925.71 693.05 10.00 7.75 -6.32 -39.17G 5966978.85 591243.00 N 70 1910.197 W 14915 37.142 End Crv 8513.33 92.92 70.27 6689.72 6607.92 2894.32 -2921.31 705.62 10.00 7.75 -6.32 O.OOG 5966983.41 591255.52 N 70 1910.241 W 149 15 36.775 Crv 4/100 9319.52 92.92 70.27 6648.70 6566.90 3026.73 -2649.45 1463.47 0.00 0.00 0.00 167.73G 5967264.36 592009.97 N 70 1912.913 W 149 15 14.659 V-116T2 9394.13 90.00 70.90 6646.80 6565.00 3039.41 -2624.66 1533.81 4.00 -3.91 0.85 167.67G 5967290.00 592080.00 N 70 1913.157 W 14915 12.606 9400.00 89.77 70.95 6646.81 6565.01 3040.44 -2622.74 1539.36 4.00 -3.91 0.85 167.67G 5967291.98 592085.52 N 70 1913.176 W 1491512.444 End Crv 9489.90 86.26 71.72 6649.93 6568.13 3056.86 -2593.99 1624.47 4.00 -3.91 0.86 O.OOG 5967321.76 592170.27 N 70 1913.459 W 14915 9.!It Crv 4/100 10005.80 86.26 71.72 6683.60 6601.80 3154.37 -2432.51 2113.28 0.00 0.00 0.00 17.39G 5967489.11 592657.05 N 70 19 15.045 W 14914 55. 10100.00 89.85 72.84 6686.79 6604.99 3173.11 -2403.86 2202.95 4.00 3.82 1.19 17.35G 5967518.83 592746.36 N 70 19 15.327 W 149 14 53.0 V-116 T3 10103.82 90.00 72.89 6686.80 6605.00 3173.91 -2402.74 2206.60 4.00 3.82 1.19 18.28G 5967520.00 592750.00 N 70 1915.338 W 149 14 52.971 End Crv 10114.51 90.41 73.02 6686.76 6604.96 3176.16 -2399.60 2216.82 4.00 3.80 1.25 O.OOG 5967523.25 592760.18 N 70 19 15.369 W 149 14 52.672 TO / 4-112" Lnr ~ 11520.82 90.41 73.02 6676.80 - 6595.00 3473.92 -1989.01 3561.82 0.00 0.00 0.00 O.OOG 5967950.00 594100.00 N 70 19 19.402 W 149 14 13.416 Leaal Descri Dtion: Northina lY\ [ftUS] Eastina IX) [ftUS] Surface: 4649 FSL 1789 FEL S11 T11N R11E UM 5969895.72 590514.78 V-116 T2 : 2024 FSL 257 FEL S11 T11N R11E UM 5967290.00 592080.00 V-116 T3 : 2246 FSL 4864 FEL S12 T11N R11 E UM 5967520.00 592750.00 TO /4-112" Lnr / BHL : 2659 FSL 3509 FEL S12 T11N R11E UM 5967950.00 594100.00 Generated 10/29/20039:04 AM Page 1 of 1 6000 is 0 0 ~ ~ 6500 ..... II () (ij c.> CI) 0 ç 7000 Prudhoe Bay Unit - WOA V-Pad S",laooLoœtion N701938.9n W1491557.i!65 NAD27A!oskaSta!&PIa"...Zo<I.04,VSfoMt 1\1<"'";"g GtidC_ Ëa.~ng Scale Fact: 0_900909301 Dip '""~ ~ " Plan¥-114(S-G¡ V-114A(P1S) TVDRGI KB(81.$OfI.bo>,o.USl) S"yOõoI' 0cI0ber2&2003 -500 o 500 1000 1500 2000 2500 3000 90· PI ~PB1 tlase 1K" , <;rv ..1<:"'"'."'._' ~ caun .. I /'-'-", "fö¡'Kù¡'ärük'í9 ~ I ""I --U::07KÙíi!" ~. -; Icrv 4/100 V.116T) "~,, > [ ,\c Targei I' ·114APB1 nd Cry .- KOP Cry 10/100 OWC T )/ ! -500 o 500 1000 1500 2000 Vertical Section (ft) Azim = 73.01°, Scale = 1(in):500(ft) Oriqin = 0 N/-S, 0 E/-I/' 2500 3000 e 6000 6500 7000 e ^ ^ ^ z g o o '!1 g ~ II Q) -¡;¡ u (f) (f) V V V bp Schlumberger FIELD Prudhoe Bay Unit - WOA SlRUCl1JRE V-Pad o -2000 -2500 -3000 Top Whipstuc ~ase Whipstock ¡ KOP Cry 10/100 -3500 '»'0>0..«<..·.......,·,. o Dip' 80.807" MagDec +25.214' Surface Location Lal: N701938.972 lon" W1491557.365 NAD27 Alaska Slate Planes. Zone 04. US Foot Northing" 5969895.72 nus Grid Conv: +0.69122375' Easting 590514.78ftUS Scale Fact: 0.999909307 Data October28,2003 FS: 5754S.6nT 500 1000 1500 2000 End Cry 'r?, .,.....,...«............. ".>0..,................ 500 1000 1500 2000 2500 <<< W Scale = 1 (in):500(ft) E >>> MisooIaneous Slot Plan V·114 (S-G) Plan" V-114A(P15} lVD Ref: KB (81.80 n above MSl) $Ivy Data: October 28, 2003 2500 3000 "~HO'« 3500 .~ :N' . -:;:...............,0............................. ··.,....······..H.....·· . m 3000 .......«...............,......... .p.................,.".. 3500 4000 e -2000 -2500 -3000 e -3500 4000 e Schlumberger Anticollision Report e Co y: Fi Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB V Pad V-114 V-114A Date: 10/29/2003 Time: 08:44:47 Co-ordinate(NE) Reference: Well: V-114, True Vertical (TVD) Reference: V-11481.8 I)b: Oracle --..-..-- -.-..---- . -- -- -- ..------ ... ....--.---....--- .. ......------- NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 100.00 ft Depth Range: 28.50 to 11520.82 ft Maximum Radius: 1349.23 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/28/2003 Validated: No Planned From To Survey ft ft 257.92 2897.91 2897.91 8140.00 8140.00 11520.82 Version: 2 Toolcode Tool Name Survey #1 (257.92-8266.19) (0) Planned: Plan #2 V1 (2) Planned: Plan #15 V1 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD + IFR + Multi Station MWD + IFR + Multi Station MWD + IFR + Multi Station Casing Points 2946.00 2686.72 9.625 12.250 95/8" 8140.00 6616.80 7.000 8.750 7" 11520.82 6676.80 4.500 6.125 4 1/2" Summary <--------------- Offset Well path --------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Well path }1D }1D Distance Area Deviation Warn~ fI ft fI fI ft .-.. - -... .--.. .. ...--- --. ..----- PB V Pad Plan V-01 (S-N) Plan V-01 ST OP (V-116 298.20 300.00 145.64 5.26 140.38 Pass: Major Risk PB V Pad Plan V-01 (S-N) Plan V-01 V10 Plan: PI 298.20 300.00 145.64 5.26 140.38 Pass: Major Risk PB V Pad Plan V-02 (N-I) Plan V-02 V5 Plan: Pia 296.51 300.00 184.49 5.13 179.36 Pass: Major Risk PB V Pad Plan V-112 (S-A) Plan V-112 V1 Plan: PI 712.95 700.00 90.16 12.73 77.43 Pass: Major Risk PB V Pad Plan V-112 (S-H) Plan V-112 Lat V1 Plan 498.33 500.00 18.05 9.48 8.57 Pass: Major Risk PB V Pad Plan V-112 (S-H) Plan V-112 V7 Plan: PI 498.33 500.00 18.05 7.91 10.15 Pass: Major Risk PB V Pad Plan V-115 (S-B) Plan V-115 V1 Plan: PI 503.82 500.00 74.11 8.34 65.76 Pass: Major Risk PB V Pad Plan V-2-08i (N-C) Plan V-208i V1 Plan: V 297.62 300.00 191.37 6.40 184.97 Pass: Major Risk PB V Pad Plan V-203 (N-A) Plan V-203 VO Plan: V 297.83 300.00 202.82 6.40 196.41 Pass: Major Risk PB V Pad Plan V-204 (S-O) Plan V (2-04HAW) VO PI 298.58 300.00 160.70 6.30 154.39 Pass: Major Risk PB V Pad Plan V-205 (S-P) Plan V-205 V2 Plan: PI 393.65 400.00 176.93 6.47 170.45 Pass: Major Risk PB V Pad Plan V-206 (S-S) Plan V-206 V1 Plan: PI 392.32 400.00 222.34 7.00 215.34 Pass: Major Risk PB V Pad Plan V-207i (N-E) Plan V-207i V1 Plan: V 297.41 300.00 184.29 6.40 177.89 Pass: Major Risk PB V Pad Plan V-211 i (S-Q) Plan V-211 i V1 Plan: P 297.89 300.00 190.69 5.20 185.49 Pass: Major Risk PB V Pad Plan V-2a06i (N-M) Plan V-2a06i VO Plan: 296.33 300.00 223.88 6.60 217.28 Pass: Major Risk PB V Pad Plan V-2a09i (N-G) Plan V-209i V1 Plan: V 297.20 300.00 181.94 6.40 175.55 Pass: Major Risk PB V Pad Plan V-Slot (S-H) Plan V-112 old V7 Plan 498.34 500.00 18.01 7.91 10.11 Pass: Major Risk PB V Pad V-101 V-101 V7 297.18 300.00 187.27 4.80 182.47 Pass: Major Risk PB V Pad V-102 V-102 V5 296.60 300.00 194.72 5.88 188.85 Pass: Major Risk PB V Pad V-104 V-104 V13 198.02 200.00 182.28 3.20 179.08 Pass: Major Risk PB V Pad V-105 V-105 V13 295.97 300.00 231.67 4.62 227.04 Pass: Major Risk PB V Pad V-107 V-107 V5 484.91 500.00 188.83 7.11 181.72 Pass: Major Risk PB V Pad V-108 V-108 V7 99.01 100.00 195.76 1.86 193.90 Pass: Major Risk PB V Pad V-109 V-109V2 501.68 500.00 27.17 7.87 19.31 Pass: Major Risk PB V Pad V-109 V-109PB1 V5 501.68 500.00 27.17 7.87 19.31 Pass: Major Risk PB V Pad V-109 V-109PB2 V2 501.68 500.00 27.17 7.87 19.31 Pass: Major Risk PB V Pad V-113 V-113V6 703.58 700.00 52.32 10.69 41.63 Pass: Major Risk PB V Pad V-117 V-117 V9 296.36 300.00 234.84 4.83 230.02 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 296.36 300.00 234.84 4.83 230.02 Pass: Major Risk PB V Pad V-117 V-117PB2 V6 296.36 300.00 234.84 4.83 230.02 Pass: Major Risk PB V Pad V-201 V-201 V8 196.70 200.00 190.25 3.33 186.92 Pass: Major Risk PB V Pad V-202 Plan V-202L OBb V2 Pia 488.39 500.00 184.08 7.41 176.68 Pass: Major Risk PB V Pad V-202 Plan V-202L 1 OBa V3 PI 488.44 500.00 182.31 8.21 174.10 Pass: Major Risk PB V Pad V-202 Plan V-202L2 OA V3 Pia 488.44 500.00 182.31 8.21 174.10 Pass: Major Risk PB V Pad V-202 V-202 V9 488.44 500.00 182.31 8.26 174.05 Pass: Major Risk PB Z Pad Z-101 Plan Z-101A V3 Plan: Z 10275.98 13200.00 387.65 253.07 134.58 Pass: Major Risk PB Z Pad Z-101 Plan Z-101APB1 VO Plan10683.21 12796.22 523.22 250.08 273.13 Pass: Major Risk 335 300 200 ·········100 100 -200 300 335 e Field: Prudhoe Bay Site: PB V Pad Well: V-114 Wellpath: V-114A e 27 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] e e V-114 A Cement Calculations: Casing Size 7" Intermediate Longstring Basis: Tail: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' shoe Cement Placement: From shoe to 7640' MD Lead: Based on TOC 500' above top of Schrader Ma +30% excess volume Cement Placement: From 7640' to 4026' MD 500' above Ma sand Total Cement Volume: Tail 32 bbls I 180ft I 154 sks of Dowell Premium "G" at 13.5 and 1.16 cf/sk Lead 125 bbls I 703 ft / 392 sks of Dowell Premium "G" at 15.8 and 1.80 cf/sk Casin Size 4-1/2" Production Liner Basis: Tail: Based on TOC 150' above top of production liner (with 4" DP) formation + 30% excess + 80' shoe Cement Placement: From shoe to 7850' MD Total Cement Volume: Lead 80 bbls 1448ft 1375 sks of Dowell Premium "G" with Gasblock at 15.8 and 1.20 cf/sk p055153 e e DATE 8/22/2003 CHECK NO. 055153 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 8/22/2003 INV# PR082003M PERMIT TO DRILL FEE V·\\Yf1 TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 AK99519-6612 NATIONAL CITY BANK Ashland, Ohio 56-389 412 No.P 055153 CONSOLIDATED COMMERCIAL ACCOUNT TO THE ORDER OF: OIL & GAS 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 AMOUNT PAY: *******$100.00****** 1110 5 5 ~ 5 ~ III I: 0 L. ~ 2 0 ~ B Ii 5 I: 0 ~ 2 7 B Ii b III ~ e e TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ~ßU V-//Vfil 2D3~/?S- WELL NAME PTD# CHECK WBA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI Tbe permit is for a new wellbore segment of LATERAL existing well . Permit No, API No. . (If API number Productionsbould continue to be reported as last two (2) digits a function· of tbe original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to tbe spacing . exception tbat may occur. DRY DITCH All dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals tbrough target zones. Rev: 07110/02 ajody\templates ~J;~~PERI\IIIT CHECK~I§J Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UN BORE V-114A Program DEV Well bore seg 0 PTD#: 2031850 Field & Pool PRUDHOE BAY, BOREALIS OIL - 640130 Initial ClasslType DEV 1 PEND GeoArea 890 Unit 11650 OnlOff Shore ~ Annular Disposal 0 Administration 1 P~rmitfee attache.cL Y~s 2 _Lease_number _ap¡::¡rOPJiate_ Yes 3 _UJlique weltn_a!1l~_aod ou.mb_e( .. . Y~s . . . . . . . . . 4 WeJlJoC<lt~d in_a_ d_efjneJ:Ipool Y~s Pr_udhoeBay, _Borealis.(CO 471)_ 5 WellJocat~d proper _distance_ from driJling unitb_ound~r:y_ Y~s 6 WellJocat~d proper _distance_ from other wells_ Y~s 7 _S.u{ficientacreage.ayailable in_drilJiOg u.nJt Y~s 8 Jf.d~viated, Js weJlbore platincJuded Y~s 9 _Oper_ator only: affected party. Y~s 10 .Operator bas.appropriate.bond inJQrce . . . _Y~s . . . . . . . 11 P~rmit c.ao be issu.ed wJthout co_nserva_tion Qrder _ Y~s Appr Date 12 P~rmitc.ao be issu.ed wJthout ad_ministratÌlle_approvaJ Y~s SFD 10/31/2003 13 Can permit be approved before 15-day wait Yes 14 WeJlJoC<lt~d within area and strata _authorized by_l[1jectioo Ord~r # (PutlO# in.com!1l~otsHFQr_ y~s AIO 24 e 15 .AJI wells_ within J 14.roite.area.of reyiew Jd~ot[fied (For !iiervJc_e IN.elJ only). .Y~s ~on.e .withio Jl4 .mile AOR. . . .. 16 Pre-produçed Î[1jector; .dur~tion_of pre-pro.duction I~S!ii than:3 months (For_service welt only) No . 17 ACMP_fjnding.of CQn,Si,Ste[1cy_h_as bee.nJssuedJorJbis project _NA _C.o[1duçtor string_provided .NA S!Jrface _C<lsing_prQtects alLknown USDWs _NA CMT v_ot adeQ u.ate. to circ_utate.o.n .cond_uctor_ & surt csgNA _CMT v_ot adeQ u_ate. to tie-in .long _stri[1g to surf C!iig_ NA .CMTwill coyeraJl knoJN.n_pro.ductiYe bori~Qns. Y~s _C_asi[1g desig[1s ad.eCua.te for C,,., B_&.perroafrosl y~s _Ä.dequate_tan_kage.or re.serve pit Yes ~ab.o(S9ES< JtaJe-.driIL bas_a_ to:403 for abandonment be~o apprQved Yes * A.dequateweJlbore !iieparatioJl.proposed. . . .. Y~s . . . . . . JtdJverter req!Jired, does .it meet reguJations. NA Sidetrack. .DriUiog fluJd. RrQ9fam sc.hematic.& eq.uipJisladequate_ y~s Max MW_ H),3.ppg._ .BOPEs..d9Jhey meetreguJation y~s .BOPE_pres$ ratiog appropriate; test to JpuJ psig in comments) Y~s Test to_50QO.psi. .MSf> 27}9 psi._ .C_hokeroanJfQld compJie!ii w/APtRf>-5:3 (May 84) Yes Work will occ!Jr withouloperation .sbu.tdoJN.n. y~s .Is presence. of H2S gas. Rrobable _. No. MeçlJa_nlC<lLcoodJtlo!1 ofweJls within .A.OR yerified (Fors.ervice welJ on.ly) Y~s ~o wells JnAOFL Appr WGA 18 19 20 21 22 23 24 25 26 27 Date 28 10/31/2003 29 30 31 32 33 34 Engineering Appr SFD 35 36 Date 37 10/31/2003 38 39 Geology Geologic Commissioner: - - - - - - e Permit C<![1 be issu.ed wfo_ hydrogen s.utfide meas.ures . _D.ata_ preseoted on_ pote_ntial ove.rpre!iisure _zone,S . .S~i'smic.analysjs_ of slJaJlow 9as_zooes .S~abedcondJtioo su.rvey(if off-sh_ore) _ Conla_ct nalTlelphoneJor_weekly progre!iis_re¡::¡orts [e~pIQrator:yo!1IYl Y~s Y~s .NA _NA _NA I:IRZ expected to,O_ ¡::¡pg _EMW.drilJe.dwJtb jQ.3 ppg mud~ Kup C e~p~cted 9.0 ppg EMW. drilled with 9.3 ppg_mu.d Date: /cJþ~ Engineering Commissioner: (""'I ..:?': 0;;;' -Oate ~ -- ::,. --- Date Public Commissioner