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204-130
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/7/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240807 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 2-72 50029237810000 224016 6/27/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON RBT END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 7/20/2024 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/16/2024 HALLIBURTON MFC MPU E-19A 50029227460100 224010 6/22/2024 HALLIBURTON COILFLAG NS-10 50029229850000 200182 7/18/2024 HALLIBURTON MFC NS-10 50029229850000 200182 7/18/2024 HALLIBURTON TEMP NS-32 50029231790000 203158 7/16/2024 HALLIBURTON MFC NS-32 50029231790000 203158 7/15/2024 HALLIBURTON TEMP PBU H-13A 50029205590100 209044 7/23/2024 HALLIBURTON RBT PBU L-246 50029237650000 223078 7/23/2024 HALLIBURTON IPROF PBU R-26B 50029215470100 210025 7/5/2024 HALLIBURTON RBT PBU R-36 50029225220000 194144 6/21/2024 HALLIBURTON RBT PBU V-216 50029232160000 204130 7/11/2024 HALLIBURTON IPROF PBU V-217 50029233340000 206162 7/11/2024 HALLIBURTON IPROF Please include current contact information if different from above. T39365 T39365 T39365 T39366 T39367 T39368 T39369 T39369 T39370 T39370 T39371 T39372 T39373 T39374 T39375 T39376 PBU V-216 50029232160000 204130 7/11/2024 HALLIBURTON IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.07 13:19:30 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-216 PRUDHOE BAY UN ORIN V-216 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2024 V-216 50-029-23216-00-00 204-130-0 G SPT 4344 2041300 1500 939 943 942 943 250 256 256 256 4YRTST P Sully Sullivan 5/14/2024 tested to 2200 for 500psi dp 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN V-216 Inspection Date: Tubing OA Packer Depth 44 2248 2151 2133IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240530144550 BBL Pumped:2.8 BBL Returned:1.7 Monday, July 22, 2024 Page 1 of 1 MEMORANDUM To: JimRegg �n__ /0/t /l(.1ZD P.2I. Supervisor `�/% FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. V-216 PRUDHOE BAY ON ORIN V-216 Src: Inspector Reviewed By: P.I. Supry Jw— Comm Well Name PRUDHOE BAY UN ORIN V-216 API Well Number 50-029-23216-00-00 Inspector Name: Brian Bixby Insp Num: mitBD6200520134247 Permit Number: 204-130-0 Inspection Date: 5/20/2020 Rel Insp Num: Notes: Wednesday, May 20, 2020 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ell V 216 Type Inj O,�VD 4344 - Tubing I(o loo; .I 1654. 1651-- CD 2041300 - Type Test, SPT Test psi 1500 IA > OA 182 - X300 . 136 2724, 186 2712 186 - 3L Pumped: 2.5 - IBBL Returned: -- few. 71-- ---- 4YRTST IP/F --_1.4 P Notes: Wednesday, May 20, 2020 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,May 19,2016 TO: Jim Re P.I.Supervisor ` ?1c �1 1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. V-216 FROM: Jeff Jones PRUDHOE BAY UN ORIN V-216 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprKL-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-216 API Well Number 50-029-23216-00-00 Inspector Name: Jeff Jones Permit Number: 204-130-0 Inspection Date: 5/14/2016 Insp Num: mitJJ160515072405 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill V-216 - I Type Inj I W'ITVD 4344 . Tubing II 1180 . 1184711 184 - 1 1171 - 1165 - PTD' 2041300 - Type Test SPT Test psi 1500 - IA 1 438 2500 - 2434 - 2426 - 4YRTST � --_-----_---180 ---— 184 - 184 - 184 . H Interval P/F P OA Notes: 1 well inspected,no exceptions noted. SCANNED SEP. 2 7 2016 Thursday,May 19,2016 Page 1 of 1 Pl Z i3e° Regg, James B (DOA) From: Jones,Jeffery B (DOA) Sent: Tuesday, May 17, 2016 8:06 PM f, S I zc() R , To: AK, D&C Projects Well Integrity Engineer Cc: Regg, James B (DOA) Subject: RE:V-216 Flutes out of Conductor Beau, Can you address the fact that the well is designed to have the surface pipe landing joint flutes engaged inside the conductor thus preventing excessive well head movement that could cause stress cracking& possibly casing failure? I can physically grab onto the well head and shake it around with my hands. I don't believe that's how the well was designed to operate. I would also like BPXA to give me list of all the wells they operate that are in a similar condition (flutes not engaged w/conductor as designed). Thanks, Jeff B.Jones Petroleum Inspector Alaska Oil & Gas Conservation Commission SCANNED SEP 2 3 2016 N. Slope Ofc: 907-659-2714 Mobile: 907-744-4446 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 Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. From: AK, D&C Projects Well Integrity Engineer [mailto:AKDCProjectsWelllntegrityEngineer@bp.com] Sent: Monday, May 16, 2016 3:23 PM To: Jones, Jeffery B (DOA) Cc: AK, D&C Well Integrity Coordinatorcet Subject: V-216 Flutes out of Conductor / Jeff, This email is to respond to your observation about the flutes on V-216 being out of the conductor.As we discussed, have confirmed that we are aware of the potential for subsidence in this well, and we are periodically monitoring for differential settling. We do this by measuring from the top of the conductor to a fixed location on the wellhead (a yellow paint mark on the casing spool) and between the top of the tree cap and the wellhouse ceiling. We also note the condition of the flowlines behind the wellhouse, whether or not they are resting on the supports. Kind Regards, 1 • • Beau Beau Obrigewitch (Alt Ryan Hayes) Well Integrity Engineer BP Exploration (Alaska) Inc. PBOC—A210 Office: (907) 659-5766 Cell: (907) 952-6271 Harmony—2377 2 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 k~ ~R ~~~~. t,, i: .~ ~. ~~ i'.~lG~~ August 14, 2009 ~ ~~~~'' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~ bp ~~~~f~~~ OCT 0 6 20p9 ~ Oil & Gas Cons. Cammi~~ion Anchorap~ ~D t~ ~- I 30 v ~ ~ t ~O 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 . • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) r y~ Date V-pad 8/13/2009 Well Name PTD # AP! # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 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 5Q029233720000 NA 0.25 NA 1.7 6/2912009 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 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 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 500292316t0000 NA 1.5 NA 11.9 7l1212009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 5002923t950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-1i9 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-t21 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-20i 2012220 5oo2s2305a0ooo SC leak NA 4 NA 90.6 S/7/2009 V-2o2 2030770 5002923~53000o NA 1.75 NA ~2.a 7l11l2009 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 i3.6 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-211 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 6l29l2009 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 ~r~ 2080200 50029233830000 NA 1.75 NA ~b 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 Request: paperwork req'd for MI injection. Page 1 of 1 i • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 23, 2009 10:33 AM _ `~=~.mu~~~;~ F~~3 ~~ ~~ 20~ To: 'West, Taylor' Subject: RE: Request: paperwork req'd for MI injection. Taylor, I found our past email. Where WAG is approved without restrictions, as in Orion all that is needed for an operating injector is the 404 changing from WIND to WAG with the date of first MI injection noted. So far as I am aware, the only pool "out west" where individual well approvals are necessary to allow MI injection is Polaris. Regards, Tom Maunder, PE AOGCC From: West, Taylor [mailto:Taylor.West@bp.com] Sent: Monday, February 23, 2009 10:27 AM To: Maunder, Thomas E (DOA) Subject: Request: paperwork req'd for MI injection. Tom: ~ a~~- ~~ We are looking to put Orion wells V-216 and t_-210 on MI service this year. Both are approved for WAG service in the AIO, but were permitted as WINJ. Please let me know if I need to submit any paperwork other than the 404. Thx r~ ylc~r Vest Production Engineer Orion /Polaris Heavy Oil BP Exploration (Alaska), fnc. 907.564.4647 (desk) 907.632.0111 (cell) 907.564.5016 (fax) 2/23/2009 ~e~~ STATE OF ALASKA i1 l{~'- ~~(n~((}} 6 /o?-Od'' ALA OIL AND GAS CONSERVATION t~1~1~7~ REPORT OF SUNDRY W~ ~I~~~Q[~if~is~i~tr 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stir~t;J~ Other ~ CONVERTED TO Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ WAG ~ Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well ~ May-07 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 204-1300 3. Address: P.O. Box 196612 Stratigraphic Service '' 6. API Number: Anchorage, AK 99519-6612 50-029-23216-00-00 7. KB Elevation (ft): 9. Well Name and Number: 81.65 KB PBU V-216 8. Property Designation: 10. Field/Pool(s): ~rlo ,'i1V ~'\ ~ ADLO-028240 ~ PRUDHOE BAY Field/ PRUD B ool 11. Present Well Condition Summary: ~ l~~ Total Depth measured 6801 ~ feet .Plugs (measured) None true vertical 4908.45 - feet Junk (measured) None Effective Depth measured 6705 feet true vertical 4829.61 feet Casing Length Size MD TVD Burst Collapse Conductor 108' 20"x34" 215.5# A53 Surface - 106' Surface - 106' Surface 3511' 9-5/8" 40# L-80 Surface - 3511' Surface - 2683' 5750 3090 Production 6790' 7" 26# L-80 Surface - 6790' Surface - 4829' 7240 5410 Perforation depth: Measured depth: O 6214 - 6260 O 6298 - 6328 O 6348 - 6368 O 6480 - 6538 True Vertical depth: 4431.9 - 4468.34 4498.89 - 4523.05 4539.17 - 4555.32 4645.98 - 4693.09 _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 6087' 3-1/2" 9.3# ,,.,,~;~3,0_- _ -- - - 6087 - 6418' Packers and SSSV (type and measured depth) 7"x3-1/2" bkr pkr .---~1 6098' 'f~''' 7"x3-1/2" bkr pkr 6274' 7"x3-1/2" bkr pkr 6369' 0 0 12. Stimulation or cement squeeze summary: ~~~~~~~ ~U~ ~ ~QO~ Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf `Writer-Bbf Casing Pressure Tubing pressure Prior to well operation: 564 931 Subsequent to operation: 1627 200 993 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 Mike Warren Printed Name Mike Warren Title Production Engineer ~ ~ /~ Signature--~='~~~~~ ~,'L~t~!I,,h~~,(,~ Phone 564-4306 Date 6/10/2008 Form 10-404 Revised 04/2006 ~ ~ ~ ~ ~ ~ ~~' ~~,,, ,~Ut~ ~ ~LQflB Submit Original Only ~',~~ • ~ aoy-~3 MEC:3ANICAL INTEGRITY ~t EPORT BUD u_T:... 4 I ~ FIELD ~ ~~ ~ t'v~c ~jE.~c~ ~~h4`~ :..G r C~~~ ~... - ~ - ©~' ;.ALL NUMEER V a- n ~ LL t~AT ~_ TD : GSSO l ice.. ~~~~ TVD ; ?BTD : ~CiRC~ S Pm ~~~-c('Z'VD C;as irg : ~ Shoe : (~~Ci'~ t~ ~~ l T~VD ; liV : ~ ~ ?~ ~ ~ •Iti~ -=.,er . ~ ~ shoe . '~ '?'TJT ; =CP . >_-~ ~''iJ ~b i, ~ ~~~~~~~~~ P acK~~_ ~Q0~1~_~ T'JD ; S e C a t ~ ~~-~ =ole S«e _ ~~~~{ and t~l Q Per~s ~ to ~c ~-~~~ "` ' ' ~~S-O S ~ Ov C~C~SS ` ~% r .~?~=C~y ~ ~ITEGRTTY - PAST #? - ~Sg 5`a~ 'O ~ ~~.~. nnu~us ?ress Test: _? 0 nin ~ min ? S ` (~ ' CO~ents : aCr~ ~Ct~\~C"~ ~~' yv'V\ 3 ~` ~ c `~ k~CG~V ToC~~ C~/~\~\~~~ t~6 ' '_~*' CHA u ~ Cr ~ , f NTEGRI'?'~ - PART # 2 ~ ~° ~e ~~~ ~ Cement Volumes : Asnt. Liner ~ 1-'t ~ CsQ ~`Q' Sit DV ~ Sc» ~ e 3~ ~©XS C,u~ -rol to cover aer,s '~~~(jVj`S ~~_ S.~-'r'~-`~~Ce~~ C 3p`Z o `~ S ='~eo•_-et:~cal TOC ~~6~5~ ~~~~~ ~-o~~~`~ `^ t"E~s~ -O Cement Bond Log (Yes or No) In AOGCC File CBL Evaluation, zone above perfs ~L~~`E~ ~pp VJ~VCt Production Log: Tyve _ _____ ; Evaluation CONCLJS?ONS: Part #~: ~~~ ~ Z~ MEMORANDUM ~"'' To: Jim Regg P.I. Supervisor (~~~~-/ ~j'7~l( FROM: Chuck Scheve Petroleum inspector State of Alaska `""'~ Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 21, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-216 PRUDHOE BAY UN GRIN V-216 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv ~J'~~'L Comm Well Name: PRUDHOE BAY UN ORIN v-216 API Well Number• 50-029-23216-00-00 Inspector Name• Chuck Scheve Insp Num: mitCS080521063533 Permit Number: 204-130-0 ,~ Inspection Date: 5/20/2008 Rel Insp Num: Packer Dept Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. v-z16 a In 2041300 --I W ~ TVD 4344 r I(~ i 0 ~ 4000 3860 r 3840 ~ Well _ TYp J• I'SPT 1500 / QA 520 i 540 540 540 p,'I', ~TypeTest ; .Test psi - -- - - --- -~---- _. _..,__--- __ _ - -- -1--- ---I-- --- ,_ 4YRTST P i Tubin ~ 550 550 550 i 550 Interval------- ------P~._----------- --~--- - - g' Notes: ~ NE®MAY 2 2 2D0~ Wednesday, May 21, 2008 Page I of 1 • • .~ ,_ MICRC)FILMED 03/01 /2008 ~`, ~; ~~ ~'~~" ,„„o a DD NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc 01 /18/08 ~chlum~errer p j~ ~ ~ ZU~It NO. 4560 Alaska Data 8< Consulting Services ~J'~ ~~~ Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Pt. Mac, Orion, Borealis Well Job # Inn t7nsr_rintinn tt~to RI c..l..r r•n L-219 11966240 MDT ~ ~}- IG. 12/22/07 1 L-114A 11970807 LDL 12/30/07 1 L-116 11962777 LDL (- ( 12131/07 1 V-211 12021135 MEM INJECTION PROFILE OC( ~- a (~ 12129/07 1 V-216 12021136 MEM INJECTION PROFILE U 12/30/07 1 L-219 12017479 ISOLATION SCANNER CBL _ ~ 01102/08 7 P2-16 11975750 INJECTION PROFILE 12/31/07 1 F-32 11970707 LDL ~} - 01/04108 1 15-046 12005202 MEM CEMENT BOND LOG (~ - 12/28/07 1 G-31A 11962778 SCMT ~ - C 01/01108 1 S-26 11978425 USIT 12/29/07 1 02-16C 11628793 MCNL '~- ~ 08/28/07 1 1 G-04B 11628765 MCNL - ~ #t 04106/07 1 1 K-02D 11209613 MCNL - tb L 07/21/06 1 1 17-07B 11649940 MCNL - 1~ / 02/17/07 1 1 L2-28 11975742 RST = 12/05/07 1 1 Z-06 11968821 RST ~ 12/13/07 1 1 1'LGMJG liVl~IYVYYLGVVG RGV GIf 1 D7 JIVIVIIYl7 HIVU RC 1 URIYIIYU VIVC VVr'T CALM 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. - Anchorage, Alaska 99508 Date Delivered: ~~~~~,~~ ~. `,:`. i(~~.~.~3 nr,~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: • • r~- 10/19/06 Sclllulllberger NO. 4004 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Borealis Well Job # log Description Date BL Color CD V-106A 40011007 OH EDIT OF MWD/LWD 40011007 2 1 V-216 40010763 OH EDIT OF MWO/LWD 40010763 2 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Ine Petrotechnical Data Center LR2* 1 900 E Benson Blvd Anchorage AK 99508-4254 Sehlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Received by: Date Delivered . ()J: Œ. ÐCfI- /30 V~11o 'it 14 röS- PBU Orion V-216 . . Andy, No open hole logging data was submitted for: PBU Orion V-216 API 50-029-23216-00 Please send over bluelines, reproduceables, and digital logging data for this well as soon as possible. TNX Howard 1 of 1 10/3/2006 9:31 AM I L Òj:) À~\\tþ DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041300 Well Name/No. PRUDHOE BAY UN ORIN V-216 Operator BP EXPLORATION (ALASKA) INC A~'::oci-02î.;;l:~ ~ MD 6801../ TVD 4908 ~ Completion Date 9/11/2004'" Completion Status ~ Current Stat~ ~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD IGR, MWD 1 GR 1 RES 1 DEN 1 NEU 1 PWD, US IT 1 Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments 1.--- ~ DAsc Directional Survey 0 6801 Open 10/5/2004 ~ Directional Survey 0 6801 Open 1 0/5/2004 Cement Evaluation 5 Blu 4300 6695 Case 2/11/2005 USIT/GR/CCL --t"éQ Injection Profile 5 Blu 6018 6668 Case 6/23/2006 Injec Pro ***Revised 26- I Sept-05*** Spin, Temp, Pres, GR, CCL, Calipers 2- Jul-05 r- 14063 Injection Profile 5 Blu 5990 6665 Case 8/29/2006 Injection Profile 11-Jul- 2006 w/Graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments . . ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? .J:.L!::!.... Daily History Received? 29/N (!yN Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: Kl~ Date: J ðF=~ ~ . . WELL LOG TRANSMITTAL RECEI\/E[) t\t)[' " ~) "lUll' I . _I '.. . / t.., J ProActive Diagnostic Services, Inc. 4Iaska 011 & Gas ConS. Commission Anchorage To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage. Alaska 99501 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 : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1] 2] 3] 4] 5] 6] 7] 1 BL / EDE Disk 1 BL / EDE Disk v - 213i 10-Jul-06 Injection Profile v - 216i 11-Jul-06 Injection Profile Print Name: LtL--- ~f-,lAe m~ l" l.<.."AA Date: ?f / fJ9 / t) (c, f I Signed: PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Ro SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM C:IDoeumen1s and ScttingslPDS AneholBgc - MPLIDcslctoplTransmil_ Original.doc ú:::rc.. go4 - II (0 u r<!.. t- ()oL.¡ -t8Ö Sda_berger LJíG r2D L{ /" to 9° 06/21/06 NO. 3862 Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion, Aurora, Borealis, Polaris Well JOb # Log Description Date BL Color CD S-111 11216189 MEMORY INJECTION PROFILE 04115106 1 S-114A 10572082 RST UPFLOW WFL 03/01/03 1 V-105 10663005 INJECTION PROFILE 03112/04 1 E·.103 10560276 TEMPERATURE WARMBACK 06/22/03 1 V-214 11162720 UBI 11/24/05 1 V·213 11076450 INJECTION PROFILE 07/01/05 1 V·216 11076451 INJECTION PROFILE 07/02/05 1 V-221 11058523 INJECTION PROFILE 07/03/05 1 L·103 N/A INJECTION PROFILE 07/18/09 1 W-209 11076461 INJECTION PROFILE 08120/05 1 W-207 10980589 INJECTION PROFILE 07/20/05 1 W-212 NlA INJECTION PROFILE 07/19/05 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Oelivered: ('.fk Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth BP Exploration (Alaska> Inc. Petrotechnlcal Data Center LR2-1 900 E Benson Blvd. Anehorage AK 99508-4254 Received by: . RECEIVED JUN 2 3 2006 ~ Oil & Gas eons. Cc-mmission Anchmge Id- . }fJ1:- 010'5 ;'0'-1 - JJ,O .;¿O!? - I'/~ '1 /J-04/ '?Ju . Schlumbergel' NO. 3335 Schlumberger-DCS 2525 Gambell S~ Suit. 400 Anchorag., AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Well Color BL CD Job# Log De$cription Date L-216 10687775 USIT PDC 05/14/04 1 1 V-211 10919914 USIT 11/19/04 1 L-210 10687666 US IT 01/14/04 1 V-216 10687707 USIT 09/09/04 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered; 2/fs ~ &, ¡// /ÊJeJ 02111/05 vV"' ~ . STATE OF ALASKA a ALAS IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ !HI WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4882' NSL, 1605' WEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 3517' NSL, 674' WEL, SEC. 02, T11 N, R11 E, UM Total Depth: 3860' NSL, 631' WEL, SEC. 02, T11 N, R11 E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- ~90695_ y- ~970131 Zone- ~SP~ TP/: x- 591575 y- 5974057 Zone- ASP4 Total Depth: x- 591613 y- 5974400 Zone- ASP4 .u __ _ __ 18. Directional Survey !HI Yes __ __ n_u_ __ n__ __n ONo 2. CASING SIZE WT. PER FT. 215.5# 40# 26# GRADE A53 L-80 L-80 20" x 34" 9-5/8" 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Gun Diameter, 5spf MD TVD MD TVD 6204' - 6250' 4424' - 4460' 6288' - 6318' 4491' - 4515' 6338' - 6358' 4531' - 4547' 6470' - 6528' 4638' - 4685' 26. Date First Production: December 28, 2004 Date of Test Hours Tested 27. One Other 5. Date Comp., Susp., or Aband. 9/11/2004 6. Date Spudded 9/2/2004 7. Date T.D. Reached 9/6/2004 8. KB Elevation (ft): 81.65' 9. Plug Back Depth (MD+ TVD) 6705 + 4829 10. Total Depth (MD+ TVD) 6801 + 4908 11. Depth where SSSV set (Nipple) 3221' MD 19. Water depth, if offshore NIA MSL Revised: 01/17/05, Put on Injection 1 b. Well Class: o Development 0 Exploratory o Stratigraphic !HI Service 12. Permit to Drill Number 204-130 13. API Number 50- 029-23216-00-00 14. Well Name and Number: PBU V-216i 15. Field I Pool(s): Prudhoe Bay Field I Orion Schrader Bluff Ft 16. Property Designation: ADL 028240 17. Land Use Permit: .f:) ¡-- .- 2Ö. "I'hict~~C,F~.lpn. ",a!ro. st t /i .t9&&.~J1>ìpx.) ¡,11af;h:. (];;: .J.'" I g 2005 .... c;., Li1n. 'lnl'I k:.....:Z.'oIufr1mis· .... . :AM<>l.IN1' CEMENTI~'~D'" . SIQ PULl.ED ~60 sx Arctic Set (Approx.) 559 sx Arcticset Lite, 379 sx 'G' 310 sx Class 'G' Ft 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, L-80 6093' (XO) 3-1/2",9.2#, L-80 6093' - 6424' 6098',6274',6369' 25. AciD, FRACTÙRE, CEMEt(T Sq9t;EZE,~C. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 110 Bbls of Diesel WATER-Bsl GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) 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". .-., . 21. Logs Run: MWD I GR, MWD I GR I RES I DEN I NEU I PWD, US IT CASING, LINER AND liEMENTING HECORD ~ETTING DEPTH.MO ~ETTING DEPTH TVD HOLE lOP I BoTTOM lOP BoTTOM SIZE Surface 108' Surface 108' 48" 28' 3511' 28' 2677' 12-1/4" 25' 6790' 25' 4899' 8-314" PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection PRODUCTION FOR O'l-Bsl GAs-McF TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ........ Oll-BsL Press. 24-HoUR RATE-p" '.,,-: None ~~.~ ~~ .. _-",~~d Form 1 0-407 Revised 12/2003 RBDMS 8FL .IAN ~ 4 2005 CONTINUED ON REVERSE SIDE ,_ _,J' \,,)1' ,,~ 28. GEOLOGIC MARK 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 Ugnu Ma Ugnu MB1 UGnu MB2 Ugnu MC Schrader Bluff NA NB NC 3824' 5662' 5725' 5818' 5902' 2881' 4051' 4092' 4153' 4208' None 5999' 6028' 6089' 4274' 4294' 4338' Schrader Bluff OA OBa OBb OBc OBd OBe OBf Base Schrader OBf 6209' 6286' 6338' 6407' 6470' 6547' 6602' 6658' 4428' 4489' 4531' 4587' 4638' 4700' 4745' 4791' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ .. Signed Terrie Hubble Title Technical Assistant Date Ot.. ( PBU V-216i Well Number Prepared By NamelNumber: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 204-130 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 18: 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 1 0-407 Revised 12/2003 Submit Original Only MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 'Kêt;í ?'Z -: lOr" P.I. Supervisor {1 '1 7/':> DATE: Wednesday, January 05, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-216 PRUDHOE BAY UN ORIN V-216 dP\.f,1"30 FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: ~ P.I. Suprv Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN ORIN V-216 Insp Num: mitLG050102223352 Rei Insp Num: API Well Number: 50-029-23216-00-00 Permit Number: 204-130-0 Inspector Name: Lou Grimaldi Inspection Date: 1/1/2005 Well I P.T. Packer Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Interval Notes: P/F Tubing 830 SCANNED JAN 0 3 2007 Wednesday, January 05, 2005 Page 1 of 1 . STATE OF ALASKA _ ALAS~ _ AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED OCT 1 ~~ 2004 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Class: Anchorage 20AAC25.105 20AAC 25.110 o Development o Exploratory DGINJ 181 WINJ o WDSPL No. of Completions One Other o Stratigraphic 181 Service 2. Operator Name: 5. Date Comp.. Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/11/2004 204-130 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/2/2004 50- 029-23216-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/6/2004 PBU V-216i 4882' NSL, 1605' WEL. SEC. 11, T11N, R11E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 3517' NSL, 674'WEL, SEC. 02, T11N. R11E, UM 81.65' Prudhoe Bay Field I Orion Total Depth: 9. Plug Back Depth (MD+ TVD) Schrader Bluff 3860' NSL, 631' WEL, SEC. 02, T11N, R11E, UM 6705 + 4829 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 590695 y- 5970131 Zone- ASP4 6801 + 4908 Ft ADL 028240 TPI: x- 591575 y- 5974057 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 591613 y- 5974400 Zone- ASP4 (Nipple) 3221' MD 18. Directional Survey 19. Water depth. if offshore 20. Thickness of Permafrost 181 Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: MWD I GR, MWD I GR / RES I DEN / NEU / PWD, US IT 22. CASING, LINER AND CEMENTING RECORD ~ ~~~i~<3 ,n ~. ...~ .G~PÊ .§El"TI~ E;PTHMD ··~IN9DePT.fTVô HAir:. ···.;..;.}L LX..:;:'. / // vv ,rt:~F'. . "FOPi 6OtTOM ToP.'. BOtTOM ·sIiè"i.//...i[./ 1..,.iO.·......"'''''. 20" x 34" 215.5# A53 Surface 108' Surface 108' 48" 260 sx Arctic Set (ADDrox.) 9-5/8" 40# L-80 28' 3511' 28' 2677' 12-1/4" 559 sx Arcticset Lite, 379 sx 'G' 7" 26# L-80 25' 6790' 25' 4899' 8-3/4" 310 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 124. i ,¡,;,;;.. '/'i ., .... / iii/ ....// ..... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5spf 4-1/2". 12.6#. L-80 6093' (XO) MD TVD MD TVD 3-1/2". 9.2#, L-80 6093' - 6424' 6098', 6274', 6369' 6204' - 6250' 4424' - 4460' 2$, AF.li-o( "". ¡,.. """, 6288' - 6318' 4491' - 4515' /'. 6338' - 6358' 4531' - 4547' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6470' - 6528' 4638' - 4685' Freeze Protect with 110 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-Bsl CHOKE SIZE GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... Oll-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". r--~~;;.,-:-:2-7¡·{\~,Y .~ OR\G\NAL Non~ Clil\;'L~;¥;- \, ~\ r\.1"\. '" ~ GF Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~~rLS 0~'- Alaska Oil & Gas Cons. Commission 28. GEOLOGIC MARKERS 29. ORMATION 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 Ugnu Ma Ugnu MB 1 UGnu MB2 Ugnu MC 3824' 5662' 5725' 5818' 5902' 2881' 4051' 4092' 4153' 4208' None Schrader Bluff NA NB NC 5999' 6028' 6089' 4274' 4294' 4338' Schrader Bluff OA OBa OBb OBc OBd OBe OBf Base Schrader OBf 6209' 6286' 6338' 6407' 6470' 6547' 6602' 6658' 4428' 4489' 4531' 4587' 4638' 4700' 4745' 4791' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date J () -{ 3û PBU V-216i Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 204-130 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 12/2003 Submit Original Only AM 0:15:5 3/2004 9/ Printed: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-216 V-216 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/1/2004 Rig Release: 9/11/2004 Rig Number: Spud Date: 9/2/2004 End: 9/11/2004 9/1/2004 17:00 - 21 :00 9/2/2004 21 :00 - 00:00 00:00 - 04:00 04:00 - 05:30 05:30 - 06:00 06:00 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 12:00 12:00 - 12:30 12:30 - 18:30 18:30 - 19:30 19:30 - 00:00 9/3/2004 00:00 - 02:00 02:00 - 02:30 02:30 - 03:30 03:30 - 04:00 04:00 - 04:30 04:30 - 05:00 05:00 - 05:30 05:30 - 07:00 07:00 - 08:00 08:00 - 17:00 17:00 - 18:30 18:30 - 19:30 19:30 - 21:00 21 :00 - 21 :30 4.00 MOB P PRE 3.00 RIGU P 4.00 RIGU P PRE PRE 1.50 RIGU P 0.50 BOPSU P PRE PRE 2.00 DRILL P 0.50 DRILL P 0.50 DRILL P SURF SURF SURF 3.00 DRILL P SURF 0.50 DRILL P SURF 6.00 DRILL P SURF 1.00 DRILL P SURF 4.50 DRILL P SURF 2.00 DRILL P SURF 0.50 DRILL P SURF 1.00 DRILL P 0.50 DRILL P 0.50 DRILL P 0.50 DRILL P 0.50 DRILL P 1.50 DRILL P SURF SURF SURF SURF SURF SURF 1.00 DRILL P SURF 9.00 DRILL P SURF 1.50 DRILL P SURF 1.00 DRILL P SURF 1.50 DRILL P 0.50 DRILL P SURF SURF PJSM. Pull pits away from rig. Move rig from V-204 to V-216i. Tie onto surface stack and riser with bridge crane. Spot rig over V-216i. Spot pits and cuttings tank. Accept rig at 2100 hrs, September 1, 2004 Take on fresh water. Remove 16" boot. RU diverter. Prepare cellar. Install diverter. Install riser. Mix Spud Mud. Bring BHA tools to floor. PU and stand back HWDP, Jars and collars. Function test diverter. Witness of test waived by AOGCC Rep., John Spaulding. MU BHA #1 RU Gyro on e-line Held pre-spud safety meeting with all crew and service personnel. Fill all surface lines and check for leaks, OK. Spud well at 09:00 hours. Drill from 108' to 361'. 56K UP 55K DN 1 0-20K WOB 550 GPM 650-700 PSI ART =.73 AST =.68 CBU at drilling rate. POOH 2 stands from 361' to PU jars. 60K UP 58K DN Gyro survey at 361' and continue drilling directionally from 361' to 1,100'. 78K UP 68K DN 72K RT 185 SPM 550 GPM 1700 PSI ON 1460 PSI OFF 40 RPM 35-40K WOB 5-6K TO ON 2.2K TO OFF CBU at drilling rate and Gyro survey at 1,100'. RD and release Gyro-Data after this final survey. Continue drilling from 1,100' to 1,473'. 77K UP 69K DN 73K RT 185 SPM 550 GPM 1940 PSI ON 1680 PSI OFF 40 RPM 35-40KWOB 5-6K TO ON 2K TO OFF ART=2.33 AST =5.38 Continue drilling from 1,473' to 1,752'. 77K UP 69K DN 75K RT AST =.56 ART =1.42 CBU X2 at 650 GPM 2,500 PSI. Rotate and reciprocate pipe during circulation. POOH from 1,752'. 25-30K overpull at 1,100'. Stand back BHA. LD UBHO sub and bit. Clean rig floor MU new bit. Re-set motor bend to 1.5 degrees. Orient motor. Service TDS TlH to 1,050', taking weight. Work pipe, no success. MU TDS, orient high side and wash from 1,000' to 1,190'. Discontinue pumping and TIH to 1,656', began taking weight. MU TDS and stage pumps up to 600 GPM. Wash to bottom at 1,752'. Continue drilling from 1,752' to TD at 3,525'. 114K UP 74K DN 89K RT 30K WOB 650 GPM 3,080 PSI OFF 3,280 PSI ON 80 RPM 5-9K TO. AST =1.73 ART =4.68 CBU X2 at 650 GPM 3,080 PSI. Rotate and reciprocate pipe during circulation. POOH to 1,550'. Encountered 20-25K overpull and swabbing. Attempted to wipe without success. Backream from 1,550' to 1,004'. Shut down pumps and rotary. Continue POOH from 1,004' to Printed: 9/13/2004 10:15:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-216 V-216 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/1/2004 Rig Release: 9/11/2004 Rig Number: Spud Date: 9/2/2004 End: 9/11/2004 9/3/2004 21 :00 - 21 :30 0.50 DRILL P SURF 728'. 21 :30 - 23:30 2.00 DRILL P SURF RIH from 728' to 3,421 '. Wash from 1,220' to 1,250' and 1,995' to 2,029'. 23:30 - 00:00 0.50 DRILL P SURF MU TDS, fill pipe and wash from 3,421 to bottom at 3,525'. 9/4/2004 00:00 - 01 :30 1.50 DRILL P SURF Circulate 3 bottoms up to condition hole for casing run. 644 GPM 2,944 PSI 100 RPM 01 :30 - 03:30 2.00 DRILL P SURF Monitor well. Blow down surface equipment. POOH from 3,525' to 77'. No significant overpull noted. 03:30 - 05:30 2.00 DRILL P SURF LD BHA, stabilizers, MWD, NMLDC, Motor, Bit. 05:30 - 06:00 0.50 DRILL P SURF Clean and clear rig floor 06:00 - 06:30 0.50 CASE P SURF PU Mandrel hanger and make dummy run. 27.50' to landing ring. PU fill up tool. 06:30 - 08:00 1.50 CASE P SURF Rig up to run 9.625" csg 08:00 - 14:30 6.50 CASE P SURF RIH with 9.625", 40#, L-80, BTC casing as per running program. Casing went to setting depth of 3,511' without difficulty. 14:30 - 15:00 0.50 CEMT P SURF RD fill up tool. MU cement head. Loading of plugs witnessed by WSL. UP WT 155K, DN WT 82K. 15:00 - 17:00 2.00 CEMT P SURF Stage pumps to 10 BPM, 640 psi. Circulate and condition mud prior to cement job, Reciprocate pipe. 17:00 - 19:30 2.50 CEMT P SURF Pump 5 bbl water to clear lines. Test lines to 3500 psi. Reciprocate pipe. Pump 75 bbl viscosified MUDPUSH II at 10.0 ppg. Drop bottom plug. Pump 443 bbl (561 sxs) Arctic Set Lite lead slurry at 10.7 ppg per OS cementing program. Collect samples. Pump 79 bbl (380 sx) Premium G tail slurry at 15.8 ppg. Collect samples. Pipe recriprocated until tail slurry at shoe. Drop top plug. Chase cement and top plug with 10 bbl water from cementers to flush lines. Switch to rig pumps and displace cement with 250 bbl mud at 8-10 bpm, 850 psi. Cement to surface, full retrurns. Estimated 250 bbls back. Reduce rate to 2 bpm last 10 bbls and bump plug with 1,400 psi. Bleed off pressure. Check floats, OK. Cement in place at 19:15hrs. 19:30 - 21 :00 1.50 CEMT P SURF Flush diverter system. Break off and LD cement head. LD landing joint and clear casing tools from rig floor. 21 :00 - 23:00 2.00 DIVRTR P SURF Nipple down diverter system. 23:00 - 00:00 1.00 WHSUR P SURF Bring speed head and tubing spool into cellar. 9/5/2004 00:00 - 02:00 2.00 BOPSU P SURF NU BOPE 02:00 - 05:30 3.50 BOPSU P SURF RU and test BOPE to BP and AOGCC regulations (250 psi LO 14,000 psi HI). Witness of test waived by AOGCC Rep., John Spaulding. 05:30 - 06:00 0.50 BOPSU P SURF Install wear bushing. 06:00 - 08:00 2.00 DRILL P PROD1 PU 13 stands 4" DP and rack back in derrick. 08:00 - 11 :00 3.00 DRILL P PROD1 PU BHA #3, Bit, Motor, NMSTB, LWD, MWD and orient same. Load sources, MU collar and jar stand. Shallow test MWD, OK. 11 :00 - 12:00 1.00 DRILL P PROD1 PU 4" DP from pipe shed. 12:00 - 13:30 1.50 DRILL P PROD1 Slip and cut dri/lline. SeNice crown and TDS. 13:30 - 15:30 2.00 DRILL P PROD1 RIH by singling in to 3,250'. Tested casing to 1,000 psi at 1,100' after passing through TAM collar. Tested MWD at 2,120' 450GPM, 1,350 psi. 15:30 - 16:30 1.00 DRILL P PROD1 Break circulation and test 9.625" casing at 3,250' to 4,000 psi for 30 minutes. Good test. Printed: 9/13/2004 10:15:5B AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-216 V-216 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/1/2004 Rig Release: 9/11/2004 Rig Number: Spud Date: 9/2/2004 End: 9/11/2004 9/5/2004 16:30 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 00:00 9/6/2004 00:00 - 00:00 9/7/2004 00:00 - 01 :00 01 :00 - 04:00 04:00 - 04:30 04:30 - 05:30 05:30 - 07:30 07:30 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30 - 17:00 17:00 - 22:00 22:00 - 22:30 22:30 - 00:00 9/8/2004 00:00 - 05:30 05:30 - 06:00 06:00 - 07:30 07:30 - 08:00 0.50 DRILL P 1.00 DRILL P PROD1 PROD1 1.00 DRILL P 0.50 DRILL P PROD1 PROD1 4.50 DRILL P PROD1 24.00 DRILL P PROD1 1.00 DRILL P PROD1 3.00 DRILL P 0.50 DRILL P 1.00 DRILL P 2.00 DRILL P PROD1 PROD1 PROD1 PROD1 6.00 DRILL P PROD1 0.50 DRILL P 0.50 CASE P 1.00 CASE P PROD1 PROD1 PROD1 1.50 CASE P 5.00 CASE P PROD1 PROD1 0.50 CASE P PROD1 1.50 CASE P PROD1 5.50 CASE P PROD1 0.50 CEMT P PROD1 1.50 CEMT P PROD1 0.50 CEMT P PROD1 Wash from 3,350' to 3,395'. 450 GPM, at 1,700 psi, 45 RPM. Drill soft cement from 3,395' to 3,424'. Tag float collar. Drill float collar and hard cement. Tag and drill float shoe at 3,509'. Drill rat hole to 3,525' and 20' new hole to 3,545'. 125K UP 70K DN 72K RT 450 GPM 1,700 PSI 45 RMP 6.5K TO Displace mud system to 9.0 ppg LSND mud. Perform LOT to 810 psi, 14.79 EMW. Establish baseline parameters. Calculated ECD 9.59 ppg. Drill from 3,545' to 4,000'. Backream and survey each stand. 132K UP 77K DN 77 RT 550 GPM 1,285-1,436 PSI 100 RPM 4-7K TO 3-10 WOB. Calculated ECD 9.6 Actual ECD 10.2 Continue drilling 8.75" production section from 4,000' to 6,801' TD. 182K UP 92K DN 122K RT 545 GPM 2530-2725 PSI 100 RPM 10K TO ON 9K TO OFF Cal ECD=9.72 Act ECD=10.23 AST =4.32 ART =10.25 ROP held to 300 FPH CBU X 3. MW=9.1 ppg 2390 PSI 527 GPM 110 RPM Calculated ECD 9.74 ppg Actual ECD 9.95 ppg POOH from 6,801' to 3,429. Max UP WT 225K DN 75K. Monitor well. Service crown and TDS RIH from 3,429' to 6,801'. OK Circulate and condition hole with 9.1 ppg mud for casing run. Spot 10 ppb G-Seal pill on bottom. 2446 PSI 524 GPM 213 SPM 110 RPM RT WT UP=125K RT WT DN=120K RT TO=11.2K Starting ECD=10.43 ppg Ending ECD=9.95 ppg, Calculated ECD 9.74 ppg POOH from 6,801' to 2,038'. LD "Ghost" Reamer #2. Con't POOH to 1,004'. LD "Ghost" Reamer #1. Can't POOH, LD BHA. Clean and clear rig floor. Flush stack, pull wear ring, install test plug. Change top rams to 7". Test door seals to 3,500 PSI. Pull test plug. Make dummy run with 7" landing joint. RU to run 7"casing. PU 7" shoe track and check floats, OK. RIH with 7",26#, L-80, BTC-M casing to above shoe at 3.500'. MU TO=9200 ftllbs. Break circulation and stage pumps up to 7 BPM, 300 psi. Circulate 1.5 bottoms up. Continue RIH with 7" casing into open hole as per detailed running program. 90 jts run to 3,758' at midnight. 41 centralizers run. Continue RIH with 7",26#, L-80, BTC-M casing from 3,758' to 6,790'. CBU on the fly 5,500' - 6,100'. 205K UP 100K DN. LD fill up tool. RU cement head, cement hose and wash up line. Circulate and condition hole. Start at 2 BPM, 287 PSI. End at 7 BPM, 687 PSI. Pump 5 bbls water. Test lines to 4500 psi. Pump 20 bbls CW100. Pump 35 bbls Dowell Mud Push spacer weighted to 10.3 ppg at 5 bpm. Release bottom plug. Mix & pump 66 bbls Printed: 9/13/2004 10: 15:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-216 V-216 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 9/1/2004 9/11/2004 Spud Date: 9/2/2004 End: 9/11/2004 9/8/2004 07:30 - 08:00 0.50 CEMT P PROD1 (299sx) Class G (Gasblok) cement @ 15.8 ppg @ 6 bpm. Wash up cement lines. Release top plug. 08:00 - 09:00 1.00 CEMT P PROD1 Switch to rig pumps and displace cement with 262 bbls sea water. Bumped plug. Cement in place at 0840. TOC estimated at 4,440'. 09:00 - 09:30 0.50 CEMT P PROD1 Pressure up casing to 4,000 PSI for 30 minutes. Good test. 09:30 - 10:00 0.50 CEMT P PROD1 Bleed off pressure, check floats, OK. RD cement head. LD landing joint. 10:00 - 11 :00 1.00 CEMT P PROD1 RD and LD csg tools. Change out bales. 11 :00 - 12:00 1.00 WHSUR P PROD1 Install pack off. Run in lock down screws. Test to 5,000 psi, with 7" X 9.625" annulus open,OK. 12:00 - 13:30 1.50 BOPSU P PROD1 Change top rams to 3.5" X 6" variables. Test to 250 psi LO - 4,000 psi HI. Good test. 13:30 - 14:00 0.50 BOPSU P PROD1 RD test equipment, pull test plug and install wear bushing. 14:00 - 15:00 1.00 CASE P PROD1 Freeze protect 7" X 9.625" annulus as follows. Clear annulus w/110 bbls 9.2 ppg mud. (110%). Rig up Hot Oil line to the lower annulus valve. Test to 3500 psi, OK. Bullhead 72 bbl (2560' MD of annular volume) of dead crude oil down 7 x9 5/8" casing annulus. FCP=875 psi. SIP=700 psi. 15:00 - 15:30 0.50 P OTHCMP Hold PJSM. RU perf equipment. 15:30 - 17:00 1.50 P OTHCMP PJSM. PU perf gun assy and BHA. 17:00 - 20:30 3.50 P OTHCMP RIH to 6,468' at 1 minute per stand. Tested MWD at 1,237', OK. 20:30 - 23:30 3.00 EVAL P OTHCMP Log down from 6,468' to 6,704' (Float collar) to correlate and confirm depths. Displace to 9.0 brine while logging, circulate at 100-300 FPS, 240 GPM, 545 PSI. Logs matched. 23:30 - 00:00 0.50 P OTHCMP POOH to 6,528 to place guns on depth. Top perfs set at 6,204'. 155K UP 90K DN. 9/9/2004 00:00 - 01 :00 1.00 P OTHCMP PJSM. 155K UP WT, 85K DN WT. Fire perf guns following Schlumberger pressure schedule. Perf intervals: 6204' - 6250' 6288' - 6318' 6338' - 6358' 6470' - 6528'. Good surface and sonic indication of guns firing. 01 :00 - 01 :30 0.50 PERFO OTHCMP POOH to 6,187'. Monitor well. Losses estimated at .5 to 1 BPH. 155K UP 85K DN 01 :30 - 02:30 1.00 PERFO OTHCMP CBU. Monitor well. Losses.5 BPH. 02:30 - 07:00 4.50 PERFO OTHCMP POOH laying down DP. LD HWDP, MWD, X-O's. 07:00 - 09:30 2.50 PERFO OTHCMP LD Perf guns. All shots fired. 09:30 - 10:30 1.00 PERFO OTHCMP Remove perf equipment and clean rig floor. 10:30 - 11 :00 0.50 PERFO OTHCMP RIH with 11 stands DP. 11 :00 - 12:00 1.00 PERFO OTHCMP Slip and cut drill line 12:00 - 12:30 0.50 PERFO OTHCMP POOH LD all DP 12:30 - 14:00 1.50 EVAL OTHCMP RU Schlumberger Wireline. 14:00 - 15:30 1.50 EVAL OTHCMP Run #1. RIH to 6,704' with 6.09" GRlJB. POOH. Recover 2 cups perf debris. 15:30 - 17:00 1.50 EVAL P OTHCMP Run #2. Rerun 6.09" GRlJB to 6,704'. 17:00 - 17:30 0.50 EVAL P OTHCMP PU USIT tools. 17:30 - 19:30 2.00 EVAL P OTHCMP Log from 6,695' to 4,300'. Loss rate less than 1 BPH. Results of log indicate good cement with good zonal isolation. Top of cement at 4,513'. 19:30 - 20:30 1.00 EVAL P OTHCMP RD Schlumberger Wireline. Printed: 9/13/2004 10: 15:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-216 V-216 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: Spud Date: 9/2/2004 End: 9/11/2004 9/1/2004 9/11/2004 22:30 - 00:00 1.50 RUNCMP 9/10/2004 00:00 - 09:30 9.50 RUNCMP 09:30 - 10:00 0.50 RUNCMP 10:00 - 10:30 0.50 RUNCO RUNCMP 10:30 - 12:00 1.50 RUNCO RUNCMP 12:00 - 12:30 0.50 RUNCO RUNCMP 12:30 - 15:00 2.50 RUNCO RUNCMP 15:00 - 17:00 2.00 RUNCO RUNCMP 17:00 - 17:30 0.50 RUNCO RUNCMP 17:30 - 18:00 0.50 RUNCO RUNCMP 18:00 - 18:30 0.50 BOPSU WHDTRE 18:30 - 23:00 4.50 BOPSU WHDTRE 23:00 - 00:00 1.00 BOPSU WHDTRE 9/11/2004 00:00 - 00:30 0.50 WHSUR P WHDTRE 00:30 - 02:30 2.00 WHSUR P WHDTRE 02:30 - 03:00 0.50 WHSUR P POST 03:00 - 05:00 2.00 WHSUR P POST 05:00 - 06:00 1.00 WHSUR P POST Pull wear bushing. Make dummy run with tubing hanger. RU tubing running equipment. Run 3.5", 9.2#, L-80, TC-II completion jewelry as per detailed program. Continue RIH with 3.5" x 4.5" completion string as per detailed program. MU hanger & landing joint. Land hanger. Do not run in lock down screws. 105K UP WT 75K DN WT. Rig up Schlumberger wireline. RIH with GR on e-line to log packers on depth. Rig dowh Schlumberger wireline. Reverse circulate inhibited brine. 50 SPM, 122GPM, 200 PSI. Run in lock down screws. Drop ball/rod assembly to seat in RHC plug. Pressure up to 4200 psi to set the Premier packers. Hold 4200 psi for 30 minutes for tubing test, OK. Bleed tubing pressure slowly to 1500 psi and then pressure annulus to 4000 psi and hold for 30 minute test. Bleed off annulus pressure to zero and tubing pressure to zero. Chuck Scheave, AOGCC Rep waived witness of pressure test. LD landing joint. Blow down lines. Install TWC and test to 1,000 psi from below, good test. Blow down surface lines and TDS. Remove rams from BOP's. Prep for sumer shut down. Rig release will be backed out to reflect time. Nipple down BOP's, riser, choke line, kill line and set back same. NU adapter flange and test to 5,000 psi for 10 minutes, good test. NU tree and test to 5,000 psi for 10 minutes, good test. RU DSM, pull TWC with lubricator. Install one VR plug. RU Little Red. PJSM. Pump 110 bbls diesel at down 75/8" X 4 1/2" annulus to freeze protect the well and allow to U-Tube. Install BPV and test to 1000 psi from below, good test. Install all remaining VR plugs. Secure well Rig released for summer maintenance @ 06:00 hrs September 11, 2004 Printed: 9/13/2004 10: 15:58 AM Ö V-216 Surve Schlumberger .''"J..:.-'c.':<, art Report Date: 7 -Sep-04 Survey 1 DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 13.010° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: V-Pad 1 Plan V-216 (N-T) TVD Reference Datum: Rotary Table Well: V-216 TVD Reference Elevation: 81.65 ft relative to MSL Borehole: V-216 Sea Bed 1 Ground Level Elevation: 53.90 ft relative to MSL UWIIAPI#: 500292321600 Magnetic Declination: 24.802° Survey Name 1 Date: V-216 1 September 7,2004 Total Field Strength: 57588.588 nT Tort 1 AHD 1 DDII ERD ratio: 111.954° 14371.61 ft 15.8311 0.891 Magnetic Dip: 80.797" Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 05, 2004 Location Lat/Long: N 70.32812777, W 149.26445178 Magnetic Declination Model: BGGM 2004 . Location Grid N/E YIX: N 5970130.540 ftUS, E 590694.820 ftUS North Reference: True North Grid Convergence Angle: +0.69262294° Total Corr Mag North·) True North: +24.802° Grid Scale Factor: 0.99990934 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth TVD Sub·Sea TVD Closure NS EW DLS Northing Easting Latitude Longitude Depth ft RTE 0.00 N 70.32812777 W 149.26445178 First GYD-GC-MS 100.00 N 70.32812949 W 149.26444875 200.00 N 70.32813308 W 149.26444205 300.00 N 70.32814104 W 149.26443423 400.00 N 70.32815974 W 149.26443158 500.00 8.05 4.89 499.00 417.35 23.35 23.84 23.48 23.30 2.90 2.87 5970153.87 590697.44 N 70.32819141 W 149.26442825 600.00 10.52 5.70 597.68 516.03 39.34 39.98 39.60 39.36 4.41 2.47 5970169.94 590698.75 N 70.32823529 W 149.26441606 700.00 12.49 6.17 695.67 614.02 59.13 59.92 59.55 59.19 6.47 1.97 5970189.80 590700.58 N 70.32828948 W 149.26439928 800.00 15.13 9.50 792.77 711.12 82.90 83.78 83.40 82.82 9.79 2.76 5970213.47 590703.61 N 70.32835403 W 149.26437238 900.00 18.28 8.27 888.54 806.89 111.56 112.52 112.12 111.22 14.20 3.17 5970241.91 590707.68 N 70.32843161 W 149.26433661 Last GYD - GC - MS 1000.00 21.92 16.62 982.45 900.80 145.84 146.83 146.28 144.64 21.80 4.63 5970275.42 590714.87 N 70.32852292 W 149.26.9 First MWD+IFR+MS 1131.09 29.15 14.07 1100.66 1019.01 202.26 203.29 202.47 199.13 36.58 5.58 5970330.08 590728.99 N 70.32867178 W 149.26 3 1226.13 34.59 13.98 1181.35 1099.70 252.41 253.45 252.55 247.80 48.74 5.72 5970378.89 590740.55 N 70.32880474 W 149.26 7 1318.64 39.40 13.98 1255.21 1173.56 308.05 309.10 308.14 301.80 62.18 5.20 5970433.04 590753.34 N 70.32895227 W 149.26394754 1412.39 43.66 13.69 1325.38 1243.73 370.19 371.25 370.25 362.14 77.03 4.55 5970493.56 590767.46 N 70.32911712 W 149.26382708 1505.32 46.72 13.97 1390.86 1309.21 436.10 437.17 436.14 426.15 92.80 3.30 5970557.74 590782.45 N 70.32929198 W 149.26369925 1598.37 51.15 11.94 1451.98 1370.33 506.24 507.30 506.27 494.51 108.48 5.04 5970626.28 590797.30 N 70.32947872 W 149.26357207 1691.41 50.98 11.93 1510.45 1428.80 578.60 579.68 578.64 565.32 123.44 0.18 5970697.26 590811.41 N 70.32967216 W 149.26345068 1783.63 51.16 13.98 1568.40 1486.75 650.33 651.41 650.37 635.22 139.53 1.74 5970767.35 590826.65 N 70.32986314 W 149.26332024 1877.03 50.67 12.68 1627.29 1545.64 722.82 723.91 722.85 705.77 156.24 1.20 5970838.08 590842.51 N 70.33005585 W 149.26318466 1970.09 48.59 12.19 1687.56 1605.91 793.72 794.80 793.75 775.00 171.51 2.27 5970907.48 590856.94 N 70.33024499 W 149.26306080 2063.29 50.28 12.27 1748.17 1666.52 864.51 865.60 864.55 844.19 186.51 1.81 5970976.84 590871.10 N 70.33043401 W 149.26293915 2156.57 49.30 12.73 1808.39 1726.74 935.74 936.84 935.78 913.74 201.93 1.12 5971046.57 590885.67 N 70.33062401 W 149.26281411 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) Plan V-216 (N- T)\V-216\V-216\V-216 Generated 10/1/2004 2:03 PM Page 1 of 3 Comments Latitude Longitude N 70.33081380 W 149.26268295 N 70.33100298 W 149.26255112 2436.61 50.63 12.05 1989.06 1907.41 1149.69 1150.79 1149.73 1122.26 249.81 1.82 5971255.63 590931.03 N 70.33119367 W 149.26242570 2529.90 49.88 12.06 2048.70 1967.05 1221.41 1222.52 1221.45 1192.41 264.79 0.80 5971325.95 590945.16 N 70.33138531 W 149.26230418 2623.99 49.40 11.78 2109.64 2027.99 1293.09 1294.22 1293.15 1262.56 279.60 0.56 5971396.27 590959.12 N 70.33157695 W 149.26218406 2717.60 48.39 11.61 2171.18 2089.53 1363.61 1364.75 1363.67 1331.63 293.90 1.09 5971465.50 590972.58 N 70.33176564 W 149.26206807 2811.13 50.66 13.97 2231.89 2150.24 1434.74 1435.89 1434.81 1400.99 309.67 3.09 5971535.04 590987.51 N 70.33195513 W 149.26194013 2905.74 50.03 12.34 2292.27 2210.62 1507.58 1508.73 1507.64 1471.91 326.25 1.48 5971606.15 591003.23 N 70.33214889 W 149.26180562 2997.12 51.90 12.82 2349.82 2268.17 1578.55 1579.71 1578.61 1541.19 341.72 2.09 5971675.60 591017.85 N 70.33233813 W 149.26168018 3091.41 50.76 12.60 2408.73 2327.08 1652.17 1653.32 1652.23 1613.00 357.91 1.22 5971747.60 591033.18 N 70.33253431 W 149.26154877 3185.08 50.34 12.27 2468.25 2386.60 1724.49 1725.65 1724.56 1683.63 373.49 0.52 5971818.41 591047.90 N 70.33272727 W 149.26. 3277.84 49.94 12.00 2527.70 2446.05 1795.69 1796.86 1795.76 1753.24 388.46 0.49 5971888.19 591062.02 N 70.33291745 W 149.26 3372.62 49.56 12.07 2588.94 2507.29 1868.02 1869.20 1868.10 1823.99 403.54 0.40 5971959.11 591076.25 N 70.33311073 W 149.26117860 3465.79 51.25 11.88 2648.32 2566.67 1939.80 1940.99 1939.89 1894.22 418.44 1.82 5972029.50 591090.29 N 70.33330258 W 149.26105776 3554.70 49.57 12.18 2704.98 2623.33 2008.30 2009.50 2008.40 1961.23 432.71 1.91 5972096.68 591103.76 N 70.33348564 W 149.26094192 3648.16 48.29 12.81 2766.38 2684.73 2078.76 2079.96 2078.86 2030.02 447.95 1.46 5972165.64 591118.16 N 70.33367357 W 149.26081827 3741.83 49.72 13.09 2827.83 2746.18 2149.45 2150.66 2149.55 2098.92 463.80 1.54 5972234.72 591133.17 N 70.33386179 W 149.26068971 3836.08 50.00 14.00 2888.59 2806.94 2221.50 2222.71 2221.59 2168.96 480.68 0.80 5972304.96 591149.20 N 70.33405315 W 149.26055279 3929.71 49.69 14.75 2948.96 2867.31 2293.04 2294.27 2293.11 2238.28 498.44 0.70 5972374.48 591166.12 N 70.33424252 W 149.26040865 4022.37 49.90 15.07 3008.78 2927.13 2363.77 2365.04 2363.82 2306.67 516.65 0.35 5972443.07 591183.50 N 70.33442934 W 149.26026090 4115.02 50.26 15.38 3068.23 2986.58 2434.77 2436.09 2434.81 2375.23 535.31 0.47 5972511.85 591201.33 N 70.33461665 W 149.26010950 4210.22 49.74 15.61 3129.43 3047.78 2507.63 2509.02 2507.65 2445.51 554.79 0.58 5972582.35 591219.96 N 70.33480863 W 149.25995142 4303.43 49.69 15.40 3189.70 3108.05 2578.67 2580.13 2578.68 2514.03 573.80 0.18 5972651.08 591238.14 N 70.33499581 W 149.25979719 4398.23 50.47 15.39 3250.53 3168.88 2651.31 2652.83 2651.31 2584.12 593.10 0.82 5972721.40 591256.59 N 70.33518730 W 149.25964058 4490.35 50.50 15.53 3309.14 3227.49 2722.31 2723.90 2722.31 2652.62 612.05 0.12 5972790.12 591274.70 N 70.33537442 W 149.25948686 4582.31 50.42 15.42 3367.69 3286.04 2793.16 2794.82 2793.16 2720.96 630.97 0.13 5972858.68 591292.79 N 70.33556113 W 149.25933331 4676.23 50.86 15.44 3427.25 3345.60 2865.72 2867.43 2865.72 2790.96 650.29 0.47 5972928.90 591311.27 N 70.33575236 W 149.25917653 4768.64 51.04 16.58 3485.47 3403.82 2937.38 2939.20 2937.39 2859.94 670.08 0.98 5972998.11 591330.22 N 70.33594080 W 149.25901592 4861.06 51.56 16.44 3543.26 3461.61 3009.37 3011.32 3009.40 2929.10 690.58 0.57 5973067.50 591349.88 N 70.33612972 W 149.25. 4954.55 51.94 16.13 3601.13 3519.48 3082.67 3084.74 3082.72 2999.57 711.17 0.48 5973138.21 591369.61 N 70.33632224 W 149.25 5047.91 51.42 14.08 3659.03 3577.38 3155.86 3157.99 3155.93 3070.28 730.26 1.81 5973209.14 591387.84 N 70.33651540 W 149.25852760 5140.52 51.07 13.69 3717.00 3635.35 3228.07 3230.21 3228.14 3140.39 747.59 0.50 5973279.44 591404.32 N 70.33670693 W 149.25838694 5235.37 50.46 12.96 3776.99 3695.34 3301.54 3303.67 3301.61 3211.87 764.52 0.88 5973351.12 591420.39 N 70.33690222 W 149.25824951 5327.92 49.58 13.12 3836.46 3754.81 3372.46 3374.59 3372.53 3280.96 780.52 0.96 5973420.39 591435.55 N 70.33709096 W 149.25811964 5421.42 50.58 13.38 3896.46 3814.81 3444.16 3446.30 3444.23 3350.76 796.96 1.09 5973490.38 591451.14 N 70.33728164 W 149.25798624 5513.78 50.11 13.73 3955.40 3873.75 3515.27 3517.40 3515.34 3419.89 813.62 0.59 5973559.70 591466.97 N 70.33747048 W 149.25785097 5607.71 49.54 13.64 4015.99 3934.34 3587.03 3589.17 3587.11 3489.62 830.60 0.61 5973629.62 591483.11 N 70.33766098 W 149.25771316 5701.23 49.41 14.73 4076.76 3995.11 3658.10 3660.26 3658.19 3558.54 848.02 0.90 5973698.74 591499.69 N 70.33784925 W 149.25757177 5794.92 49.19 14.34 4137.86 4056.21 3729.11 3731.29 3729.20 3627.29 865.85 0.39 5973767.70 591516.68 N 70.33803708 W 149.25742708 5888.40 48.56 15.07 4199.34 4117.69 3799.49 3801.70 3799.60 3695.40 883.72 0.89 5973836.01 591533.73 N 70.33822314 W 149.25728202 5982.47 46.84 12.86 4262.65 4181.00 3869.05 3871.28 3869.16 3762.91 900.53 2.52 5973903.71 591549.72 N 70.33840756 W 149.25714560 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) Plan V-216 (N-T)\V-216\V-216\V-216 Generated 10/1/20042:03 PM Page 2 of 3 Comments Measured Inclination Azimuth TVD Sub· Sea TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure (ft) (dea) Idea) (ft) 1ft) 1ft) 1ft) 1ft) (ft) 1ft) (dea/100 ft) IftUS) IftUSI 6076.60 44.03 10.26 4328.70 4247.05 3936.07 3938.33 3936.17 3828.59 914.00 3.58 5973969.54 591562.39 N 70.33858698 W 149.25703624 6170.52 40.29 9.02 4398.31 4316.66 3998.99 4001.35 3999.07 3890.72 924.58 4.08 5974031.79 591572.22 N 70.33875671 W 149.25695035 6263.04 36.56 7.54 4470.78 4389.13 4056.28 4058.84 4056.33 3947.60 932.89 4.15 5974088.76 591579.84 N 70.33891211 W 149.25688288 6356.65 36.19 7.39 4546.15 4464.50 4111.54 4114.36 4111.57 4002.65 940.10 0.41 5974143.89 591586.38 N 70.33906249 W 149.25682430 6450.17 35.86 6.91 4621.79 4540.14 4166.25 4169.36 4166.26 4057.22 946.95 0.46 5974198.54 591592.57 N 70.33921158 W 149.25676869 6544.36 35.57 7.01 4698.27 4616.62 4220.93 4224.34 4220.93 4111.80 953.61 0.31 5974253.19 591598.57 N 70.33936068 W 149.25671458 6637.33 35.04 6.62 4774.14 4692.49 4274.35 4278.07 4274.35 4165.15 959.99 0.62 5974306.60 591604.30 N 70.33950643 W 149.25666278 Last MWD+IFR+MS 6730.53 34.78 6.49 4850.57 4768.92 4327.35 4331.41 4327.35 4218.14 966.07 0.29 5974359.66 591609.75 N 70.33965118 W 149.25661332 TD ( Projected) 6801.00 34.78 6.49 4908.45 4826.80 4367.28 4371.61 4367.30 4258.08 970.62 0.00 5974399.65 591613.81 N 70.33976030 W 149.25657642 Survey Type: Definitive Survey NOTES: GYD GC MS . ( Gyrodata - gyro compassing mls -- Older Gyrodata gyro multishots-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata multishot into open hole" model. ) MWD + IFR + MS - ( In-field referenced MWD with mult-station analysis and correction applied in post-processing.) . Le!!al DescriDtion: Surface: 4881 FSL 1605 FEL S11 T11 N R11 E UM BHL: 3859 FSL 631 FEL S2 T11 N R11 E UM Northing (Y) rftUS1 5970130.54 5974399.65 Eastin!! IX) rftUS1 590694.82 591613.81 . SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) Plan V-216 (N- T)\V-216\V-216\V-216 Generated 10/1/2004 2:03 PM Page 3 of 3 7" Short Joint &: RA Tag @5632 Top Ma sand (5653' MD) packoff seal bore. Nipple with 3.813" seal bore. XO 7" Short Joint &: RA Top OA (6208' MD) Production Packer 3~1/2" 'X' Landing Nipple with 2.813" seal bore. OA sand Perfs: 6204 - amco 3-1/2" x 1~1/2" MMG GLM RA Tag in 3112" @ 3-1/2" 'X' with 2.813" 7" x 3-112" Baker 'PRM' Production Packer 3-1/2" 'X' Landing Nipple with bore. OBa &: OBb sand Perfs: 6288 - 6318, 6338 - 6358 amco 3-1/2" x 1-1/2" MMG GLM 3-1/2" 'X' Nipple with 2.813" seal bore. 1" x 3-1/2" Baker 'PRM' Production Packer 3-1/2" WireUne 3~1/2" 'X' Landing Nipple with 2.813" seal bore. Guide (-50' above top OBdperf) 6470 ~ 7", PBTD 7", 26 If/ft, BTC-Mod B 3/4", TD Date 04/09/04 08/04104 08/18/04 Rev Ii.y TomS RBT RBT LV ctual Com WELL: V-216i API NO: SCHLUMBERGER Survey report Client.......... ....... ..: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: ORION Well. . . . . . . . . . . . . . . . . . . . .: V-216 API number......... ......: 50-029-23216-00 Engineer. . . . . . . . . , . . . . . . .: St. Amour Rig: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . , . . . . . . . . . . . . . .: Alas ka ----- 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.... ...: 53.90 ft KB above permanent. ,.....: N/A Top Drive DF above permanent.... ...: 81.65 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: 13.01 degrees 7-Sep-2004 04:22:49 1 of 4 Page Spud date. .. .. .. .. . .. .. .. : Last survey date.........: Total accepted surveys...: MD of first survey..... ..: MD of last survey... .....: 2-Sep-04 07-Sep-04 73 0.00 ft 6801.00 ft ----- Geomagnetic data ---------------------- Magnetic model........ ...: BGGM version 2003 Magnetic date............: 02~Sep-2004 Magnetic field strength..: 1151.51 HCNT Magnetic dec (+E/W-).. ...: 24.85 degrees Magnetic dip..... ...... ..: 80.82 degrees ----- MWD survey Reference Reference G.........,....: Reference H..............: Reference Dip.... ..... ...: Tolerance of G........ ,..: Tolerance of H,..........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1151.51 HCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.85 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.85 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 ( ( ~DG[ ---I ~ tJ SCHLUMBERGER Survey Report 7-Sep-2004 04:22:49 Page 2 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 None 2 100.00 0.84 30.73 100.00 100.00 0.70 0.63 0.37 0.73 30.73 0.84 GYR None 3 200.00 0.94 33.33 100.00 199.98 2.17 1.95 1.20 2.29 31.66 0.11 GYR None 4 300.00 2.62 12.98 100.00 299.93 5.22 4.86 2.16 5.32 24.01 1.77 GYR None 5 400.00 5.30 357.69 100.00 399.69 11.96 11.70 2.49 11.96 12.02 2.86 GYR None 6 500.00 8.05 4.89 100.00 499.00 23.35 23.30 2.90 23.48 7.10 2.87 GYR None 7 600.00 10.52 5.70 100.00 597.68 39.34 39.36 4.41 39.60 6.39 2.47 GYR None ( 8 700.00 12.49 6.17 100.00 695.67 59.13 59.19 6.47 59.55 6.24 1.97 GYR None 9 800.00 15.13 9.50 100.00 792.77 82.90 82.82 9.79 83.40 6.74 2.76 GYR None 10 900.00 18.28 8.27 100.00 888.54 111.56 111.22 14.20 112.12 7.28 3.17 GYR None 11 lcJOO.OO 21. 92 16.62 100.00 982.45 145.84 144.64 21.80 146.28 8.57 4.63 GYR None 12 1131.09 29.15 14.07 131.09 1100.66 202.26 199.13 36.58 202.47 10.41 5.58 MWD IFR MS - 13 1226.13 34.59 13.98 95.04 1181.35 252.41 247.80 48.74 252.55 11.13 5.72 MWD IFR MS - 14 1318.64 39.40 13.98 92.51 1255.21 308.05 301.80 62.18 308.14 11.64 5.20 MWD IFR MS 15 1412.39 43.66 13.69 93.75 1325.38 370.19 362.14 77.03 370.25 12.01 4.55 MWD IFR MS - 16 1505.32 46.72 13.97 92.93 1390.86 436.10 426.15 92.80 436.14 12.28 3.30 MWD IFR MS 1598.37 - 17 51.15 11.94 93.05 1451.98 506.24 494.51 108.48 506.27 12.37 5.04 MWD IFR MS 18 1691.41 1510.45 - 50.98 11.93 93.04 578.60 565.32 123.44 578.64 12.32 0.18 MWD IFR MS 1783.63 51.16 92.22 - 19 13.98 1568.40 650.33 635.22 139.53 650.37 12.39 1.74 MWD IFR MS 20 1877.03 93.40 722.82 - 50.67 12.68 1627.29 705.77 156.24 722.85 12.48 1.20 MWD IFR MS - 21 1970.09 48.59 12.19 93.06 1687.56 793.72 775.00 171.51 793.75 12.48 2.27 MWD IFR MS ( 22 2063.29 50.28 12.27 93.20 1748.17 864.51 844.19 186.51 864.55 12.46 1.81 MWD IFR MS 23 2156.57 49.30 12.73 93.28 1808.39 935.74 913.74 201.93 935.78 12.46 1.12 MWD IFR MS 24 2249.87 50.43 13.47 93.30 1868.53 1007.07 983.21 218.10 - 1007.11 12.51 1.35 MWD IFR MS 25 2343.07 49.07 12.94 93.20 1928.74 1078.20 1052.46 234.35 1078.23 12.55 1.52 MWD IFR MS - 26 2436.61 50.63 12.05 93.54 1989.06 1149.69 1122.26 249.81 1149.73 12.55 1.82 MWD IFR MS 27 2529.90 49.88 12.06 93.29 2048.70 1221.41 1192.41 264.79 1221.45 12.52 0.80 MWD IFR MS 28 2623.99 49.40 11.78 94.09 2109.64 1293.09 1262.56 279.60 1293.15 12.49 ·0.56 MWD IFR MS 29 2717.60 48.39 11.61 93.61 1363.61 - 2171.18 1331.63 293.90 1363.67 12.45 1.09 MWD IFR MS 30 2811.13 50.66 13.97 93.53 2231.89 1434.74 1400.99 309.67 1434.81 - 12.46 3.09 MWD IFR MS - SCHLUMBERGER Survey Report 7-Sep-2004 04:22:49 Page 3 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 2905.74 50.03 12.34 94.61 2292.27 1507.58 1471.91 326.25 1507.64 12.50 1.48 MWD IFR MS - 32 2997.12 51.90 12.82 91.38 2349.82 1578.55 1541.19 341.72 1578.61 12.50 2.09 MWD IFR MS - 33 3091. 41 50.76 12.60 94.29 2408.73 1652.17 1613.00 357.91 1652.23 12.51 1.22 MWD IFR MS 34 3185.08 50.34 12.27 93.67 2468.25 1724.49 1683.63 373.49 1724.56 12.51 0.52 MWD IFR MS - 35 3277.84 49.94 12.00 92.76 2527.70 1795.69 1753.24 388.46 1795.76 12.49 0.49 MWD IFR MS 36 3372.62 49.56 12.07 94.78 2588.94 1868.02 1823.99 403.54 1868.10 12.48 0.40 MWD IFR MS 37 3465.79 51.25 11.88 93.17 2648.32 1939.80 1894.22 418.44 1939.89 12.46 1.82 MWD IFR MS 38 3554.70 49.57 12.18 88.91 2704.98 2008.30 1961.23 432.71 2008.40 12.44 1.91 MWD IFR MS 39 3648.16 48.29 12.81 93.46 2766.38 2078.76 2030.02 447.95 2078.86 12.44 1.46 MWD IFR MS 40 3741.83 49.72 13.09 93.67 2827.83 2149.45 2098.92 463.80 2149.55 12.46 1.54 MWD IFR MS 41 3836.08 50.00 14.00 94.25 2888.59 2221.50 2168.96 480.68 2221.59 12.50 0.80 MWD IFR MS 42 3929.71 49.69 14.75 93.63 2948.96 2293.04 2238.28 498.44 2293.11 12.55 0.70 MWD IFR MS 43 4022.37 49.90 15.07 92.66 3008.78 2363.77 2306.67 516.65 2363.82 12.62 0.35 MWD IFR MS 44 4115.02 50.26 15.38 92.65 3068.23 2434.77 2375.23 535.31 2434.81 12.70 0.47 MWD IFR MS 45 4210.22 49.74 15.61 95.20 3129.43 2507.63 2445.51 554.79 2507.65 12.78 0.58 MWD IFR MS 46 4303.43 49.69 15.40 93.21 3189.70 2578.67 2514.03 573.80 2578.68 12.86 0.18 MWD IFR MS 47 4398.23 50.47 15 . 39' 94.80 3250.53 2651.31 2584.12 593.10 2651.31 12.93 0.82 MWD IFR MS 48 4490.35 50.50 15.53 92.12 3309.14 2722.31 2652.62 612.05 2722.31 12.99 0.12 MWD IFR MS 49 4582.31 50.42 15.42 91.96 3367.69 2793.16 2720.96 630.97 2793.16 13.06 0.13 MWD IFR MS 50 4676.23 50.86 15.44 93.92 3427.25 2865.72 2790.96 650.29 2865.72 13.12 0.47 MWD IFR MS - 51 4768.64 51.04 16.58 92.41 3485.47 2937.38 2859.94 670.08 2937.39 13.19 0.98 MWD I FR MS ( - 52 4861.06 51.56 16.44 92.42 3543.25 3009.37 2929.10 690.58 3009.40 13.27 0.57 MWD IFR MS 53 4954.55 51.94 16.13 93.49 3601.13 3082.67 2999.57 711.17 3082.72 13.34 0.48 MWD IFR MS - 54 5047.91 51.42 14.08 93.36 3659.03 3155.86 3070.28 730.26 3155.93 13.38 1.81 MWD IFR MS - 55 5140.52 51.07 13.69 92.61 3717.00 3228.07 3140.39 747.59 3228.14 13.39 0.50 MWD IFR MS - 56 5235.37 50.46 12.96 94.85 3776.99 3301.54 3211.87 764.52 3301.61 13.39 0.88 MWD IFR MS - 57 5327.92 49.58 13.12 92.55 3836.46 3372.45 3280.96 780.52 3372.53 13.38 0.96 MWD IFR MS 58 5421.42 50.58 13.38 93.50 3896.46 3444.16 3350.76 796.96 3444.23 13.38 1.09 MWD IFR MS 59 5513.78 50.11 13.73 92.36 3955.40 3515.27 3419.89 813.62 3515.34 13.38 0.59 MWD IFR MS 60 5607.71 49.54 13.64 93.93 4015.99 3587.03 3489.62 830.60 3587.11 13.39 0.61 MWD IFR MS - .. 't SCHLUMBERGER Survey Report 7-Sep-2004 04:22:49 Page 4 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 5701.23 49.41 14.73 93.52 4076.76 3658.10 3558.54 848.02 3658.19 13.40 0.90 MWD IFR MS - 62 5794.92 49.19 14.34 93.69 4137.86 3729.10 3627.29 865.85 3729.20 13.43 0.39 MWD IFR MS - 63 5888.40 48.56 15.07 93.48 4199.34 3799.49 3695.40 883.72 3799.60 13.45 0.89 MWD IFR MS - 64 5982.47 46.84 12.86 94.07 4262.65 3869.05 3762.91 900.53 3869.16 13.46 2.52 MWD IFR MS - 65 6076.60 44.03 10.26 94.13 4328.70 3936.07 3828.59 914.00 3936.17 13.43 3.58 MWD IFR MS - 66 6170.52 40.29 9.02 93.92 4398.31 3998.99 3890.72 924.58 3999.07 13.37 4.08 MWD IFR MS ( - 67 6263.04 36.56 7.54 92.52 4470.78 4056.28 3947.60 932.89 4056.33 13.30 4.15 MWD IFR MS - 68 6356.65 36.19 7.39 93.61 4546.15 4111.54 4002.65 940.10 4111.57 13.22 0.41 MWD IFR MS - 69 6450.17 35.86 6.91 93.52 4621.79 4166.25 4057.22 946.95 4166.26 13.14 0.46 MWD IFR MS - 70 6544.36 35.57 7.01 94.19 4698.27 4220.93 4111.80 953.61 4220.93 13.06 0.31 MWD IFR MS - 71 6637.33 35.04 6.62 92.97 4774.14 4274.35 4165.15 959.99 4274.35 12.98 0.62 MWD IFR MS - 72 6730.53 34.78 6.49 93.20 4850.57 4327.35 4218.14 966.07 4327.35 12.90 0.29 MWD IFR MS 73 6801.00 34.78 6.49 70.47 4908.45 4367.28 4258.08 970.62 4367.30 12.84 0.00 Projection to TD [(c)2004 IDEAL ID8_1C_02J ( '~ .~ Schlumberger Drilling & Measurements MWD/LWD Log Product Deliverv Customer BP Exploration (Alaskallnc. Dispatched To: Helen Warman Well No V-216 Date Dispatched: 2-Sep-04 Installation/Rig Nabors 9ES Dispatched By: J. Bosse Data No Of Prints No of Floppies Surveys 2 1 /\ J I I r/JrvWJJ ()jjJ Please sign and return to: James H. Johnson Received By: BP Exploration (Alaska) Inc. e) J;- )vJ-d !t Petrotechnical Data Center (LR2-1) ) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907 -564-4005 e-mail address: johnsojh@bp.com LWD Log DeliveryV1,1, 10-02-03 Schlumberger Private ?"- ô 0( - (J tJ ~ '\ -...~-- ~1f~lTŒ rnl~ (£ì n r;\~, ~. i7 r\ I Î\ \ III I f\ \ \ Cu V I. ¡ A\ w\ I /U\ '\.\ ~\ !Ll\ Lnj Lb iJlj ® u~ Lrù / I í FRANK H. MURKOWSKI, GOVERNOR I ¡ i AIfASKA. OIL AND GAS CONSERVATION COMMISSION í ¡ ! / 333 W. yrn AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay V-216i BP Exploration (Alaska) Inc. Permit No: 204-130 Surface Location: 4882' NSL, 1605' WEL, SEC. 11, T11N, RIlE, UM Bottomhole Location: 3807' NSL, 630' WEL, SEC. 02, T11N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for pennit to drill the above referenced service well. This permit to drill 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 pennits 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 tenns 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 ltn ss any required test. Contact the Commission's petroleum field inspector at (907) 659- 07 er). Si BY ORDER º~ THE COMMISSION DATED this~day of July, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. \íUòi\ I' I~fuv~, ~ STATE OF ALASKA ALASKAUíL AND GAS CONSERVATION COrv1MISSI~ PERMIT TO DRILL ., ~ 20 MC 25.005 E ~\/E?¡ II ! J l", b. 1 ö 2004 1a. Type of work a Drill o Redrill r b. Current Well Class o EXPI<?rato~ P~,yqtpPl11en.tOili i: fO rvtt!ltip, ~.;~~n~h ORe-Entry o Stratigraphic Test II Service fa' Ðevelbptne:nt~as ',' 'f:] Sfrrgle 'ZeM" - 0 2. Operator Name: 5. Bond: a Blanket o Single Well 11. Well Name'ahô?Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU V-216i ./ 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 6731 TVD 4829 Prudhoe Bay Field I Orion 4a. Location of Well (Governmental Section): 7. Property Designation: Schrader Bluff Surface: ADL 028240 4882' NSL, 1605' WEL, SEC. 11, T11N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: July 26, 2004 / 3520' NSL, 684' WEL, SEC. 02, T11N, R11E, UM ( Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: vi 111 .~ NSL, 630' WEL, SEC. 02, T11 N, R11 E, UM 2560 12,325' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: X-590695 y- 5970131 Zone- ASP4 (Height above GL):Plan 82.5 feet V-106 is 240' away at 6235' MD 16. Deviated Wells: Kickoff Depth: 300 feet, 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035), Maximum Hole Angle: 51 deQrees Downhole: 2109 Surface: 1638 ..-/ 18. Casing Program: Setting~pth-<, ". Quantity QfCement Size Specifications , '. .... '. Top .' ,'Bottom "" . ,..{cJ.or sacks} < · ...... , Hole Casino Weioht Grade Couplino Lenoth MD TVD MD TVD (includino staoe data) 48" 20" x 34" 215.5# A53 Welded 80' 29' 29' 109' 109' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 3472' 29' 29' 3501' 2683' 579 sx Arcticset Lite, 348 sx 'G' 8-3/4" 7" 26# L-80 BTC-M 6702' 29' 29' 6731' 4829' 269 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completedfór Redrill AND Re-eritry Operations) , .' '. - '., '.' .' '" ,.' Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length Size ,...'.'..... [-r...·". ·;Ü'O:X····'·è '}i"..c-'·"i '''',000'._ .' ..... :::0« Structural Conductor Surface Int -" te Production Liner Perforation Depth MD (ft): perfOration Depth TVD (ft): 20. Attachments a Filing Fee, $100 o BOP Sketch a Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis a Property Plat o Diverter Sketch o Seabed Report a Drilling Fluid Program a 20 AAC 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 Rob Tirpack, 564-4166 Printed Name ~'7'ell Crane Title Senior Drilling Engineer Signature ~~ ~"- Prepared By Name/Number: - Phone 564-4089 Date ~-~.-... ./ Terrie Hubble, 564-4628 V . .,........ " . '..... '·-.-'·L ..... .. oi.2:.'. ·./«.X ...·...-..C,s.¡.........< """..:-:.'.:." . .... "',,·>'s:.·.· .......<..... Permit To Drill I API Number: Permit AP~al '.Ä cf See cover letter for Number: ;2CJ ý' - / -5ð 50-02-9- 232../6 Date: 7 'é?'Cl ¿) other requirements Conditions of Approval: Samples Required 0 Yes $No Mud Log Required 0 Ye~ ~ No . ~~eMeasures DYes ~ND Directional Survey Required ~Yes 0 No Other:T-e S t Bo P f 4: JOO P s ¡. ¡Vi r T œ;'1/I- -éAA.t D.. ¿fa.. I¿ f 1. I D~ ,-'1"7 L.L( fV\£ d " ~, Peý~ '5 'S'S o..]('/)) QLt~k-,-te BoPE fest P;€J¡~~ I oS 'V}¡orc Vè ~¡'f· ADDroved Bv: ~ / APPROVED BY V r\ i'\ I ^ f f\ , A I THE COMMISSION Date Form 10-401 R~06/2~ -- U ;\ ! lJ II\J 1-\ I Stfbmit ~ Duofrcate Greater r ihoe Bay V-216i Permit to Drill ., ........- ~---- Well Plan Summar'l ·W';','o-.:;·:I··I··;-::::·::N: .:; ,,:.' ", ", I 'Vi':'" "":""':1' '·6:" ""0::,",": "·:":",:è',':,<":;,':',;·.:.~Cf:·""·' " .,' ··e· ':õ:, a·m'e.· ",·'0:".. '1·'.'i~:,.,;,,;,:~,:¡:~.:;,,:,,:::,}'::c:1..5'~;:i:' ,C,- . ~:, , " ,.:, " ,,', ~. ;" ,.r:::' .' " '.;' ~ . , '.',' ~,' "", :.,.~ ~:, < ':"; _", ~ ,,::<:~~::':., ,~: ',' ,::~': ::",~.:;'~~;::~~': :~:::':~~~~,- :~);:(-~:: ~:,:~_~~:~;'_~' :~~~: ,r J Type of Well (producer or injector): I USH Injector ,/ . I ~" " ,> -,', . ,,' )-i:~:1 Surface Location: As Staked V-216i Polygon 2 Target 1 To OA: V-216i Polygon 2 Target 2 To OBe: V-216i Polygon 2 BHL: 4,882' FSL, 1,605' FEL, Sec. 11, T11 N, R11 E /' X = 590,695 Y = 5,970,131 3,520· FSL, 684' FEL, Sec. 2, T11 N, R11 E X = 591,565 Y = 5,974,060 Z = 4,345' TVDss 3,720' FSL, 646' FEL, Sec. 2, T11 N, R11 E X = 600 Y = 5,974,260 Z = 4,625' TVDss ,80 FSL, 630' FEL, Sec. 2, T11 N, R11 E _=591,615 Y=5,974,347 Z=4,746'TVDss -1(- I AFE Number: I ORD5M3561 I Estimated Start Date: I July 26m 2004 I Rig: I Nabors 9ES /' I Operating days to complete: 112.8 Œ[] 6,731' I [!ÿ[j 4,829' I r Max Inc: [§E] r GL: 154.0' I [E[J 28.5' ( I KBE: @J Well Design: USH Grassroots Schrader Injector. 4-Ÿ2" X 3-Ÿ2" TCII Completion. The 0 sands will have a 4-Ÿ2" X 3-Ÿ2" TCII Completion in the Schrader Bluff. Current Well Information General Distance to Nearest Property: -12,325' at top OA to the nearest PBU property line Distance to Nearest Well in Pool: 240' from V-21?i top of OA at 6,235', MD to V-10,6 top OA,at 6,314'MD /" API Number: Well Type: Current Status: BHP: BHT: 50-029- ???? Development - Orion Schrader Injector New well, 20" X 34" insulated conductor 2,123 psi @ 4,746' TVDss (8.6 ppg EMW). Normal pressure gradient. 100°F @ 4,746' TVDss estimated (from L-pad Temp Log) Mechanical Condition V-216i: Nabors 9ES: Conductor: Cellar Box above MSL = 54.0' - as staked KB height = 28.5' 20" X 34",215.5 Iblft, A53 ERW set at 109' RKB - to be set % Mile Well bore Near Well bore Mechanical Integrity Summary: V-106: 240' at Top of the Schrader Kuparuk producer currently SI due to TXIA communication (assumed to be a leaking GL V). Planned TOC @ 500' MD above the Top Schrader. 1280' at Top of the Schrader Kuparuk producer. No AnnComm issues. Well is on production. Planned TOC @ 500' MD above the Top Schrader. 1 V-103: No Wellbore Near Wellbore integrity issues. Permit to Drill 07/14/04 Target Estimates Estimated Reserves: ,,-,. Greater rihoe Bay V-216i Permit to Drill '~ 1.933 MMBO Materials Needed - (use PES stock when possible) Surface Casing: Production Casing: L-80 Completion: 3,501' 1 each 1 each 25 each 1 assembly 1 lot 9-%", 40#, L-80 BTC Casing 9-%", BTC Float Shoe and Float Collar 9-%",40#, BTC Type TAM Port Collar 9-%" x 12"j4" Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 9-%" casing pups 5', 10', 20'. 6,731' 1 each 75 each 2 lots 2 each 2 each 7" 26# L-80 BTC-M Casing 7" BTC-M Float Shoe and Float Collar 7" x 8"j4" Rigid Straight Blade Centralizers 7" casing pups 5', 10', 20' 7" RA Tag 7" 26# L-80 BTC-M Casing Short Joint 6,250' 300' 2 each 1 each 2 each 6 each 1 each 1 each 1 each 4 each 1 each 4}2" 12.60 Ibltt, L-80, TCII tubing 3}2" 9.30 Ibltt, L-80, TCII tubing Baker PRM Production Packer 7" X 3-}2" Baker S-3 Production Packer 7" X 3-}2" Halliburton 4-}2" X-Nipple (3.813" 10) Halliburton 3-}2" X-Nipple (2.813" 10) 11" X 4-}2" FMC tubing hanger 4-1/16", 5m Cameron Tree 4-}2" x 1" KBG-2 GLM 3-}2" x 1-}2" MMG injection mandrels 3 }2" RA Tag Surface and Anti-Collision Issues Surface Shut-in Wells: / V-111 and V-1 03 will require surface shut-in and wellhouse removal in order to move over well V216i. V-110 should be evaluated before the rig move as to whether it will require wellhouse removal and shut in for rig move. V-106 and V-03 should not require wel/house removal, but should also be evaluated prior to the rig move for any potential interference. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close A roach Well List: '. Wen:Näme'''~:Ctr::CtfDistânce· V -103 15.29-ft V-111 19.52-ft V-106 42.71-tt V-03 45.48-ft V-105 90. 78-ft :Reference MD . 400-ft 501-ft 400-ft 602-tt 399-ft , Allowable Deviation ',,' 8.62-ft 10.55-ft 36.59-ft 36.07-ft 84.29-ft 2 Permit to Drill 07/14/04 Greater r1hoe Bay V-216i Permit to Drill '- ------ Survey and Logging Program 12-%" Hole Section: Surface Gyro will be needed (run to 1200' as conditions dictate) Open Hole: MWD J GR Cased hole: None 8-%" Hole Section: MWD I GR I Res / Dep/ Neu I PWD (All realtime with recorded porosity) Cased Hole: USIT Bond Log /' Mud Program Interval 3,501' to 6,731' MD YP 23-30 Spud - Freshwater Mud YP PH FL 50-70 8.5-9.0 NC-8.0 30-45 8.5-9.0 8.0 30-40 8.5-9.0 5.0-7.0 Freshwater Mud (LSNO) PH: 9.0-9.5 <600 Chlorides PV API Filtrate MBT 12-18 4-6 < 20 Interval Initial Base Perm Interval TO 8 3¡4" Intermediate Hole Mu Funnel vis 250-300 200-250 200-250 Formation Markers (Based on Schlumberger wp03b) Formation To S MD TVD _ TVDss H drocarbons SV6 988' 973' 890' No SV5 1,843' 1,648' 1,565' No SV4 2,060' 1,783' 1,700' Poss. Gas Hydrates Base Permafrost 2,060' 1,783' 1,700' No Fault 1 2,500' 2,058' 1,975' SV3 2,516' 2,068' 1,985' 913 8.8 Poss. Gas Hydrates SV2 2,796' 2,242' 2,160' 994 8.8 Poss. Gas Hydrates SVl 3,333' 2,578' 2,495' 1,148 8.8 Poss. Gas Hydrates UG4 3,789' 2,863' 2,780' 1,299 8.8 Thin coal 3,853' 2,903' 2,820' 1,316 8.8 Heavy Oil between UG4A 2820' and 3950' ss 4,502' 3,308' 3,225' 1 ,483 8.8 Thin coals/poss. UG3 Heavy oil UGl 5,191' 3,738' 3,655' 1,660 8.7 Poss. Heavy Oil Top Schrader Bluff/Ma 5,682' 4,045' 3,962' 1,787 8.7 No - Water Sand Mbl 5,751' 4,088' 4,005' 1,805 8.7 No - Water Mb2 5,847' 4,148' 4,065' 1,830 8.7 No - Water Mc 5,940' 4,208' 4,125' 1,854 8.6 No - Water Na 6,026' 4,268' 4,185' 1,879 8.6 No Nb 6,061' 4,293' 4,210' 1,889 8.6 Yes Nc 6,114' 4,333' 4,250' 1,906 8.6 Yes OA 6,229' 4,423' 4,340' 1 ,898 8.4 Yes OBa 6,310' 4,488' 4,405' 1,699 7.4 Yes OBb 6,359' 4,528' 4,445' 1,986 8.6 Yes OBc 6,433' 4,588' 4,505' 2,011 8.6 Yes OBd 6,495' 4,638' 4,555' 1,750 7.4 Yes OBe 6,579' 4,706' 4,623' 2,060 8.6 Yes OBf 6,634' 4,751' 4,668' 2,078 8.6 Yes OBf_Base 6,693' 4,798' 4,715' 2,098 8.6 No T.D.** 6,731' 4,829' 4,746' **TD is based on 250' MD below the top OBe marker.** 3 Permit to Drill 07/14/04 Greater r 1hoe Bay V-216i Permit to Drill c~ '-'- Casingrrubing Program ;;.I-Iole> ' ~~Csg:t :_>;~~':, ; .:;WtlA\,: ::G~de~' . Conn , ; Burst ' Collapse : Length . Top .;, Bottom' , Size' ' TbgO.D. . . .. ,". .'. ,. , (psi) (psi) MD"¡ TVDrkb ' 'MD I TVDrkb 48" 20" X 34" 215.5# A53 Welded 80' 29' / 29' 109' /109' 12-%" 9-%" 40# L-80 BTC 5,750 3,090 3,472' 29' / 29' 3,501' /2,683' 8-%" 7" 26# L-80 BTC-M 7,240 5,410 6,702' 29' / 29' 6,731' / 4,829' Tubinq 4%" 12.60# L-80 TCII 8,430 7,500 6,201' 29' / 29' 6,230' / 4,423' Tubinq 3%" 9.30# L-80 TCII 10,160 10,530 265' 6,230' / 4,423' 6,495' / 4,638' Cement Calculations ) In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Centralizer Recommendations 9-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,401' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar (contingency only). c) This centralizer program is subject to change due to actual hole conditions. 7" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 5,082' MD (600' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. Bit Recommendations , --BJ:fA. ;. Numbår. Surface Surface Interm. . ~~~{~~~~~i: :~f{~jf.·~~ :~,~:~)::> : 12-%" 0' - 2,060' 12- %" 2,060' - 3,501' 8-% 3,501' - 6,731 ': ·Bit:Type NO'zzles' ; : K-Revs Hours . - - - - - - .. , : : Hughes MXC-1 Hughes MXC-1 Hycalog DS70NPV 18/18/18/16 18/18/18/16 6x14 4 Permit to Drill 07/14/04 Greater r ihoe Bay V-216i Permit to Drill -- Motors and Required Doglegs '~ 1&2 . . Flow Rate 400 - 700 gpm RPMs 60-80 3 500 - 600 gpm 60-120 Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi../íJue to test pressures not exceeding 5,OOOpsi it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency for V-216i will be 14 days. - Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: 2,109 psi - Base of Schrader (8.6 ppg @ 4,715' TVDss) œ.1,6 p i-Based on a full column of gas@0.1 0 psi/ft ð<J9l?1>si/250 psi Rams , 00 psi/250 psi Annular 4,000 psi 11.9 ppg EMW LOT 20' from 9-5/8" shoe 50 bbls with an 11.9 ppg EMW LOT / Estimated 9.3 ppg Brine / 6.8 ppg Diesel · 7" Casing Test: · Integrity Test - 8-3/4" hole: · Kick Tolerance: · Planned completion fluid: Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class " wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 5 Permit to Drill 07/14/04 Greater r 1hoe Bay V-216i Permit to Drill "-' .- Drillinq Hazards and Continqencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in the Polygon 2 fault block is expected to be normal pressured at 8.5-8.8 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and Shallow gas A. Gas Hydrates are present at V-pad and have been encountered in wells as close as V-1 00 and V-111 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Both offset wells to V-100 and V-111 had to have the mud treated and were able to drill to section TD. In V-100 the hydrates came from the SV1. Occasionally hydrates are encountered below the SV1. III. Lost Circulation/Breathing A. Lost circulation is not expected due to the benign nature of the V Pad fault. In addition the fault will be crossed at high angle and move away quickly. . Note: Massive losses were encountered on L pad at L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 9-%" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal tail cement to 600' MD above the Ma sand -5,471' MD. C. The Kick Tolerance for the surface casing is 50 bbls with 9.3 ppg mud, 11.9 ppg LOT, and an 8.8 ppg pore pressure. D. Integrity Testing -11.9 ppg EMW V. Stuck Pipe A. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide / V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: V-115 10 ppm V-100 10 ppm Adjacent producers at TD: V-103 10 ppm V-106 10 ppm VII. Faults A. One fault is expected to be crossed at V-216i. The 'V-Pad Fault' and has been intersected in the surface hole by most wells drilled from V Pad to date. It has been crossed in a similar stratigraphic interval as V- 213PB1 in wells V-103 and V-106. No losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 (SV4): 2,500' MD 2,058' TVD 1,975' TVDss Throw: 65' West CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 6 Perm it to Dri II 07/14/04 Greater r 1hoe Bay V-216i Permit to Drill ~ - Drill and Complete Procedure Summary Pre-Rig Work: 1. The V-216i conductor has not been set. See As-Staked for coordinates. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Shut in V-100 and V-115 and remove well houses as necessary. Rig Operations: / 1. MIRU Nabors 9ES. / 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12-14" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,501' MD. The// actual surface hole TO will be +/-100' TVD below the top of the SV1 s~ 4. Run and cement the 9-%", 40.0-lb/ft. surface casing back to surface. A TAM Port Collar or stage tool should be on location. Cement was not circulated to surface on V-103 and V-106 1st stage surface cement job. Therefore a port collar/stage tool will be run in the casing string to allow secondary cementing, (in the event cement is not circulated to surface during primary cementing operations). /" 5. ND diverter spool and NU casing I tubing head. NU BOPE and test to 4,000 psi. /" 6. MU 8-%" drilling assembly with MWD/GR/Res/Den/Neu(recorded)/PWD and RIH to float collar. Test the 9-%" casing to 4,000 psi for 30 minutes. 7. Circulate and condition cement contaminated mud. Displace over to new 9.3 ppg mud 8. Drill new formation to 20' below 9-%" shoe and perform LOT (If a 11.9 ppg EMW is not obtained contact ODE). 9. Drill ahead to Polygon 2 Target TO at 6,731' MD, (250' below top OBe marker). / 10. Circulate and condition hole, make a short trip, TOOH to run casing. /- 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace the casing with 9.3 ppg mud during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Freeze protect the 7" x 9-%" annulus. 12. PU used bit and scraper and RIH with 4" DP while waiting on cement to PBTD ±6,651' MD. Displace out the mud with 9.3 ppg brine. POOH and LD BHA. Note: It is not necessary to change to pipe rams for scraper run as casing has been tested. 13. RU Schlumberger E-line and run a USIT/GR log. USIT will be primary depth control. / 14. RU Schlumberger, PU DPC guns and RIH wI -190' of 4.5" Power Jet 5 spf perf guns (total assembly length to be -350'). Space out utilizing GR and RA tags in 7" casing. Once spaced out correctly, perforate OA, OBa, OBb, and OBd. Depths based on USIT/GR logging run. 15. RIH with gage ring and junk basket to recover any perf debris. Repeat until clean. / 16. Run the 4-~" X 3-~", L-80 TCII completion with a 7" x 3-~" straddle packer assembly and injection mandrels. 17. Run in the lockdown screws and set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCK shear valve. 18. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 19. Freeze protect the well to -2,500' TVD. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-}-'2" annulus valve and secure the well. Assure that IAlOA are both protected with two barriers. 20. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod I RHC from the tailpipe. 2. Replace the DCK shear valve with a dummy GL V. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 7 Permit to Drill 07/14/04 Greater r 1hoe Bay V-216i Permit to Drill '-' .- V-216i Detailed Drilling Procedure Job 1: MIRU Critical Issues: ~ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well. ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ V-111 and V-103 will have to be shut in and require wellhouse removal before rig can be moved over the well. All surface flowlines and gas lift lines will need to be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. ~ V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: o Adjacent producers at Surface: V-115 10 ppm V-100 10 ppm o Adjacent producers at TO: V-103 10 ppm V-106 10 ppm Reference SOP .:. tlDril/ing/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drill12~" Surface Hole Critical Issues: ~ At V-Pad, no significant surface hole drilling problems are present. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost and particularly at ± 900-1000'. In several wells reaming and tight hole have been present with a few examples of lost circulation while cementing. ~ Close Approach: The V-111 and V-103 are required to be shut in and have their wellhouses removed due to surface location proximity to the V-216i. In addition there are several close tolerance wells in the surface interval. Follow the traveling cylinder / no-go plot per established procedures. A gyro should be run to at least 900'-1200'. ~ Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque / drag in the later hole sections and allow for easier 9 5/8" casing running. A graduated build profile is planned. It is preferred that DLS are not pushed ahead of plan on the surface hole, so as to minimize the chance for hole irregularity or obstructions that could cause problems while running casing. 8 Permit to Drill 07/14/04 Greater ~ dhoe Bay V-216i Permit to Drill ---- ~ ~ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to BO-rpm while drilling because of the 1.83° motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TD to raise the rotary speed to ~ 1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 650 - 700 GPM to increase hole cleaning. Before pulling out of the hole for the final time, make sure that the hole is clean, full returns are observedt and that the pipe pulls without significant overpull. Lost circulation is possible while cementing if these conditions are not satisfied. ~ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. ~ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SV1 sands. Reference RPs: .:. /lPrudhoe Bay Directional Guidelines" .:. /lWell Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations Job 3: Run 9-%" Surface Casing Critical Issues ~ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. Hydrates are prevalent on V-pad all the way into the SV1. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TD at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. ~ Casing drift: 9-%" special drift casing is being used (a.a3St' drift required). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-%" bit, i.e. float equipment, casing hanger, etc. ~ Cement to surface: A single-stage job will be done on this well using 2S00/0 excess in the permafrost and 30% excess below the permafrost. A TAM Port collar should be placed at 1,000-ft MD if losses are encountered or indications are that gravel is running or the whole is washing out. Several V-pad wells with similar directional plans and in this quadrant have required secondary cementing on surface due to losses during the primary job. ~ Losses during cement job: At V-Pad lost circulation has been experienced while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is at least 12.7 -Ib/gal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECO's during the entire cement job to help mitigate the potential for breaking down the formations. Reference RPs .:. /lCasing and Liner Running Procedure" .:. (Surface Casing and Cementing Guidelines" .:. /lSurface Casing Port Collar Procedure" 9 Permit to Drill 07/14/04 Greater r 1hoe Bay V-216i Permit to Drill '-- Job 4: Drill 8_3;4 II Intermediate Hole "- - Critical Issues ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period of time across the permeable Schrader Sands. ~ LOT: Perform a LOT (minimum 11.9 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the max expected Schrader reservoir pressure of 8.8 ppg and 9.3 ppg mud, a 11.9 ppg leak-off will provide 50 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.9 ppg. Based upon off-set drilling data on V-Pad, a minimum leak-off of 13 ppg is expected at the 9-%" shoe. ~ Penetration Rate: Penetration rates should not exceed 600 fph instantaneous. This should allow for EGOs not to exceed 0.6ppg above calculated. If EGOs are sustained above this threshold, it is advised that drilling should be stopped and the hole circulated before continuing. EGO should not exceed 11.0 ppg once the M sand has been penetrated. ~ Torque: Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. ~ Critical LWD Tools: It is critical to have the GR tool in order to pick the landing points for the intermediate hole sections. As mentioned above in the landing point discussion, the landing of this well depends on picking the base of the 08f and 08d sands using the Gamma Ray. Therefore if the GR tool is lost, a trip will have to be made to change it out. ~ Faults: One fault is expected to be crossed at V-216i. The 'V-Pad Fault' and has been intersected in the surface hole by most wells drilled from V Pad to date. It has been crossed in a similar stratigraphic interval as V-213P81 in wells V-103 and V-106. No losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 (SV4): 2,500' MD 2,058' TVD 1,975' TVDss Throw: 65' West ~ 7" casing landing point: The 7" casing setting point will be determined by depth based on changes in GR/Res curves associated with the top OBe marker. After seeing the top 08e, TD will be picked based on drilling 250' MD past this marker. This footage is critical for future well work. If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. ~ Directional Constraints: It is important to keep the wellbore smooth and the tangent angle close to plan to facilitate casing running and slickline access. It is important to design a 8HA to minimize inclination walking tendencies thus minimizing wellbore tortuousity. DLS should be kept as close as possible to :S;1° over planned. Dogleg will take priority over angle as long as mainbore tangent angle does not approach 68 degrees. ~ Survey program per JORPS: Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. uERD Operating Practices" 10 Permit to Drill 07/14/04 Greater ....dhoe Bay V-216i Permit to Drill ...~ "'-' Job 6: Run and Cement 711 Intermediate Casing Critical Issues ~ Tight hole, packing off and lost circulation have been experienced while drilling though this interval. Good hole cleaning, mud conditioning, and drilling practices are required for trouble free drilling. In numerous cases tight hole has made backreaming necessary with stuck pipe and lost returns on only two wells. ~ Cement Job: It is imperative to achieve a good cement job on this well to achieve zonal isolation and effective injection control. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job above the Ma sand. Keep cementing ECD's below 12.5 ppg EMW during the displacement. ~ Freeze Protection: Ensure the lower production cement has reached at least a 500 psi compressive strength prior to freeze protecting. After freeze protecting the 7" x 9-%" casing outer annulus with 72 bbls of dead crude (2,570' MD, 2,200'TVD), the hydrostatic pressure will be 8.0 ppg vs. 8.8 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 over 100 psi underbalance to the open hole. ~ Centralization/Differential Sticking: See centralizer strategy in the Well Plan Summary. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. ~ RA Tags: There will need to be 2 RA tags placed in the 7" casing for depth control. Placement strategy is: o Pip #1: Top Ma Sand o Pip #2: 40-60' above top OA sand ~ Mud Requirements: Thin the mud as per MI's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. ~ Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. ~ TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor before running casing. Reference RPs .:. tllntermediate Casing and Cementing Guidelines" .:. tlFreeze Protecting an Outer Annulus" 11 Permit to Drill 07/14/04 Greater r- 1hoe Bay V-216i Permit to Drill -- -.-- Job 7: DPC Perforate Well Critical Issues ~ Barriers: A wireline BOP with double downward rams should be used in conjunction with a packoff or stuffing box attached to a riser joint for wireline operations. While running DPC guns the well will be contain kill weight fluid and BOPs will be in place. After perforating, up to freeze protecting this will be adequate to provide two barriers. ~ The well will be perforated ±130 psi over-balanced. Ensure all personnel are well briefed on Shlumberger's perforating procedures and that all responsibilities are understood. ~ It should be stressed that while picking up and running the perforating string, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, Schlumberger perforating crew. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. ~ Contact Schlumberger to prepare for approximately 190' of 4-1/2" Power Jet guns at 5 spf to be run on DP. Exact perforation depths will be provided after reviewing the LWD logs. ~ Be prepared for fluid losses to the formation after perforating. Have ample seawater and brine on location and be prepared with LCM if necessary. Losses are not expected to be severe based on past perforation jobs. It is expected that the formation will take a little drink due to the extra pressure induced by the detonation of the perf guns. ~ It is planned to utilize LWD GR to correlate to the formation and casing RA tags to position the perforation assembly. The GR tool will be placed above the perforating assembly, the assembly is then RIH past the perf depth, the well will be logged up to correlate DP depth, and then the guns can be brought on depth and fired. The LWD GR tool requires a 150-260 gpm flowrate to establish a signal. Modeling indicates a maximum pressure of 2,400 psi will be seen when pumping @250 gpm. The previous USIT/GR will be used as the primary depth control. Reference RPs .:. "Wireline Pressure Control SOP" .:. {r.Alaska Wells Group Standard Operating Procedure: Perforating" .:. Follow Schlumberger perforating practices and recommendations Job 8: Run 4-1h" Completion Critical Issues ~ Barriers: o The well will have the OA, aBa, OBb, and OBd production intervals open with an 8.8 ppg EMW formation pressure during completion operations. o Completion will be run with BOPs in place and kill weight fluid for annulus side barriers. Tubing side barriers will be provided via TIW and kill weight fluid. o Once packers are set the annulus above the packer will be tested to 4,000 psi to verify packer/annulus integrity. Kill weight fluid and the tubing hanger provide additional annulus side barriers. At this point the ball and rod with kill weight fluid and a TIW valve comprise the tubing side barriers. o Since it is not feasible to test the lower packer/annulus integrity, when the DCK valve is sheared a casing annulus valve must be in place along with kill weight fluid to provide sufficient annular barriers. Tubing side barriers are still kill weight fluid on ball and rod and a TIW. 12 Permit to Drill 07/14/04 Greater ~ 'dhoe Bay V-216i Permit to Drill c___ .,--, o A TWC will be installed and tested from above to 1,000 psi for 30 minutes prior to nippling down the BOP's. With the DCK valve sheared the TWC in addition to kill weight fluid provide the tubing side barrier. The annular side is provided by a casing annulus valve and kill weight fluid. With the TWC in place BOPs can be nippled down and the tree nippled up. o With the tree nippled up freeze protecting removes the kill weight fluid as a barrier. We then count on the tree for tubing side barriers, and two casing annulus valves for annulus side protection. o Before rigging down a BPV tested from below to 1,000 psi will be left in the tubing hanger to provide an additional tubing side barrier once the rig is off. Since the DCK valve is still open it will be necessary to leave one casing annulus valve and a VR plug for annular barriers. Make sure that a lubricator is used to install the VR plug while both casing annulus valves are still in place. ~ Thread Dope: Jet Lube is the BP approved thread compound for Premium Carbon API connections. All TCII pipe should arrive on location with Jet Lube thread compound. It would still be good practice to look over each connection in the pipe shed prior to incorporating them into the tally. ~ Torque Turn: Injectors will be used for MI injection and therefore must have all connections torque turned and charted to help reduce risk of leaks. ~ Shear Valve: We will be using a DCK-2 shear valve due to the RP shear valve failure on numerous wells. The DCK-2 shear valve has had good success due to the locking mechanism that keeps the sleeve from migrating back down over the ports after the tool is sheared open. This valve does require a higher differential pressure to open. ~ Injection Mandrels: Remove the check valves from the MMGW waterflood mandrels. This will allow us the flexibility to circulate between mandrels and clean up the tubing/casing annulus later in the well life. Reference RPs .:. "Completion Design and Running" RP .:. 'Tubing Connections" RP Job 9: ND/NU/Release Rig Critical Issues ~ See Job 1 for adjacent well spacing. Identify hazards in a pre-move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ~ Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RPs .:. "Freeze Protecting an Inner Annulus" RP 13 Permit to Drill 07/14/04 20W X 34" 215.5 !blfl:, A53 ERW ~ 4-1/2" 'X' with 3_813" seal bore. 2_813" TBD c--------------- I J . E ~17Z --------- I I~ '" Ig Iz I I I I I I I I I I ) 15'00'oo"rD I - -.:r- z - PLAN T I · V-lIB · V-03 · V-ltD -,"-V-1I1 V-216i. V-t03 · V-106 · V-I 051 · SLOT Nt.! · V-t02 · V-201 · V-107 · V-02 V-210i! V-104i V- 202 · V-101 " V-lOB V-203-tp- · V-115 · V-100 · V-117 · SLOT S-R · V-01 · V¡;Jf~E · SLOT S-J VICINITY MAP N.T.S. I ~: ail Z I LEGEND -+- AS-STAKED CONDUCTOR . EXISTING CDNDUCTOR · V-1t4 · V-119 · V-109 · V-11J V-PAD -- NOTES 1. DAlE OF SURVEY; MAY 16, 2004. 2. REFERENCE FJELD BOOK: WOO4-07 PGS. 1-6. 3, ALASKA STATE PLANE COORDINAlES ARE ZONE +, NAD 27. GEODETIC POSITIONS ARE NAD-27. 4, BASIS Of HORIZONTAL CONlROL IS V-PAD OPERATOR MONUMENTAlION. 5. BASIS Of ELEVATION IS KUPARUK PIPELINE CONlROL. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. LOCATED \MlHlN PROlRACTED SEC. 11, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA A.S.P. PLANT GEODETIC GEODETIC GROUND SECTION COORDINATES COORDINATES POSITION OMS POSITION D.DD ELEV. OFFSETS Y=5,970,046.48 N=10,180.00 70'19'40.470" 70.3279085' 53.1' 4.801' FSL x- 590,381.05 E- +,6:50.00 14916'01.216" 1+9.2670045" 1,920' FEL Y=5,970,069.77 N=10,180.00 70'19' 40.689" 70.3279692' 5:5.2' 4,823' FSL x- 590,467.97 E- 4,720.00 149'15'58.670" 149.266297J· 1,833' FEL Y= 5,970,1,J0.59 N=1 0,1 BO.OO 70'9'41.260" 70.,J281279· 53.3' 4,882' fSL x- 590,694.94 E- 4,955.00 149'15'52.023" 149.2644508" 1,605' FEL WEll. NO. V-203 V-21Oi V-21ôi ~ aR"": Obp HAO<LfM"N Ç £QÐr JACOBS DAle. ::I/18/D4 DI^WIe $IIa:Ð FRIJC14 wav 07-(1;) GREA TER PRUDHOE 8A Y V-PAD !tImma .œ NO. !ICAI£! AS-STAKED CONDUCTORS 1 Dl'1 oN -.....--- WEll. V-2m, V- 21 Oi & V- 216i "'.., ... .. 1 "=15C)' IE\lBION 1Ft CHI ---- - bp o c-nts RTE KOP BId 1.5/100 Bid 3.51100 SV6 End Bid SV5 SV41 Base Perm Fault Ctos8Ing SV3 SV2 SV1 Schlumberger Proposal SurvIy 1 DLS CCIIII IIåIIon IItIIIod: Minimum Curvature 1 Lubinski V~ SecIIon AzImuth: 13.000· .... VIIIIcII SIctIon OrIgIn: N 0.000 ft, E 0.000 II ..~ TVDRelerlnceDllum: RotaryTabIe F_lblll'" st TVDRelerlnceElevlllon: 82.50lIreladvetoMSL .~ Sea Bed 1 Ground LIVII EIevIIIon: 54.00 1118IatIve to MSL .1 IIIIJc DlcllnIIIon: 24.846· Total FIIId SltlngIJI: 57574.844 nT III IIIIJc DIp: 80.821· DtcIInIIIon Dtú: September 08, 2004 ... DIcIIINIIIon 1IodII: BOOM 2003 NoIIh R"'cr. True North Total Carr IIIg NoIIh -» Tru. NoIIh: +24.846· LocIII CoordInIllI RIItnncId To: WeD Heed Report Dtú: July 13, 2004 ClIII!: BP Exploration Alaska FIIId: Prudhoe Bey UnH . WOA Slructu.., Slot: V-Pad IPIII1 Y-216 (N-T) WIll: Plan Y-216 (N-T) BorIholt: Plan Y-216 UWIIAPW: 50029 SUI'Vl1......./Dtú: Y-216 (P3b) 1 July 13, 2004 TOIt/AHD 1 DOl 1 ERD 1'1IIo: 66.881·/4316.1111/5.605/0.894 GrId CoonIInIIt SyIÞm: NAD27 Alaska Stale PIenes, Zone 04, US Feet LOCIIIon lIIILong: N 70.32812792, W 149.28444967 LœIIIon Grid HIE YIX: N 5970130.600 flUS, E 590695.080 flUS GrId Con¥II IIIcI Anf II: -to.69282493· GrId Selle FICIor: .99990934 . 700.00 12.00 13.25 614.99 697.49 36.52 36.52 35.55 8.37 3.50 0.000 3.50 0.00 5970166.24 590703.02 N 70.32822504 W 149.26438179 800.00 15.50 13.25 712.11 794.61 60.29 60.29 58.68 13.82 3.50 0.000 3.50 0.00 5970189.44 590708.19 N 70.32828823 W 149.26433761 900.00 19.00 13.25 607.60 890.10 89.93 89.94 87.54 20.61 3.50 O.OOG 3.50 0.00 5970218.38 590714.63 N 70.32838708 W 149,26428250 988.01 22.08 13.25 890.00 972.50 120.81 120.81 117.59 27.69 3.50 0.000 3.50 0.00 5970248.51 590721.35 N 70.32844918 W 149.26422511 1000.00 22.50 13.25 901.10 983.60 125.38 125.38 122.02 28.73 3.50 0.000 3,50 0.00 5970252.95 590722.33 N 70.32846127 W 149.26421688 1100.00 26.00 13.25 992.26 1074.76 166.42 166.42 161.99 38.15 3.50 O.OOG 3.50 0.00 5970293.03 590731.26 N 70.32857047 W 149.26414033 1200.00 29.50 13.25 1080.74 1183.24 212.98 212.98 207.31 48.82 3.50 0.000 3.50 0.00 5970338.46 590741.38 N 70.32889427 W 149.26405379 1300.00 33.00 13.25 1166.22 1248,72 264.85 264,85 257.80 60.71 3.50 O.OOG 3.50 0.00 5970389.09 590752.68 N 70.32883220 W 149.~ 1400.00 38.50 13.25 1248.37 1330.87 321.64 321.84 313.27 73.77 3.50 0.000 3.50 0.00 5970444,71 590785.05 N 70.32898375 W 149. 1500.00 40.00 13.25 1326.89 1409.39 383.73 383.74 373.52 87.98 3.50 0.000 3.50 0.00 5970505.12 590778.51 N 70.32914835 W 149.2637 1600.00 43.50 13.25 1401.49 1483.99 450.31 450.32 438.33 103.22 3.50 0.000 3.50 0.00 5970570,10 590792.98 N 70.32932539 W 149.26361261 1700.00 47.00 13.25 1471.88 1554.38 521.32 521.32 507.44 119.49 3.50 0.000 3.50 0.00 5970639.40 590808.42 N 70.32951421 W 149,26348061 1800.00 50.50 13.25 1537.60 1620.30 598.49 596.50 580.62 136.72 3.50 0.000 3.50 0.00 5970712.77 590824.76 N 70.32971411 W 149.26334086 1824.67 51.36 13.25 1553.35 1635,85 615.64 615.65 599.26 141.11 3.50 0.000 3.50 0.00 5970731.46 590828.93 N 70.32976504 W 149.26330526 1843.33 51.36 13.25 1585.00 1847.50 630.22 630.22 613.44 144.46 0.00 0.000 0.00 0.00 5970745.69 590832.10 N 70.32980380 W 149.26327817 2059.54 51.36 13.25 1700.00 1782.50 799.11 799.11 777.84 183.17 0.00 0.000 0.00 0.00 5970910.52 590868.81 N 70.33025290 W 149.26296419 2499.98 51.36 13.25 1975.00 2057.50 1143.14 1143.15 1112.71 262.02 0.00 O.ooG 0.00 0.00 5971246.30 590943.61 N 70.33116775 W 149.26232456 2516.00 51.36 13.25 1985.00 2067.60 1155.85 1155.66 1124.89 284.89 0.00 0.000 0.00 0.00 5971258.51 590946.33 N70.33120102 W149.26230130 2796.27 51.36 13.25 2160.00 2242.60 1374.56 1374.59 1337.99 315.07 0.00 0.000 0.00 0.00 5971472.18 590993.93 N 70.33178319 W 149.26189423 3332.81 51.36 13.25 2495.00 2577. 50 1793. 67 1793. 69 1745.93 411.14 0.00 0.000 0.00 0,00 5971881,21 591085.05 N 70.33289763 W 149.26111492 WeHDeslgn Vet 3.1 RT -SP3.03-HF4.oo Bid( d031rt-546 ) Plan V-216 (N-T)lPlan V-216 (N-T)lPlan V-216\v·216 (P3b) Generated 7/1312004 1:29 PM Page 1 of 2 CommentI 9-518" Csg PI UG4 UG4A UG3 UG1 Me 5682.34 51.36 13.25 3962.00 4044.50 3628.93 3628.96 3532.34 831.81 0.00 O.OOG 0.00 0.00 5973672.41 591484.05 N 70.33777785 W 149.25770125 Mb1 5751.21 51.36 13.25 4006.00 4087.50 3682.72 3682.76 3584. 71 844.14 0.00 O.OOG 0.00 0.00 5973724.92 591495.75 N 70.33792090 W 149.25760117 Mb2 5847.31 51.36 13.25 4085.00 4147.50 3757.78 3757.82 3657.77 861.34 0.00 O.OOG 0.00 0.00 5973798.18 591512.07 N70.33812050 W149.25746151 Drp 4/100 5847.56 51.36 13.25 4065.16 4147.66 3757.98 3756.01 3657.96 661.39 0.00 -174.22G 0.00 0.00 5973798.37 591512.11 N 70.33812102 W 149.25746115 5900.00 49.28 12.97 4098.64 4181.14 3798.34 3798.37 3697.27 870.54 4.00 -174.04G -3.98 -0.53 5973837.78 591520.79 N 70.33822840 W 149.25738682 Me 5939.77 47.69 12.75 4125.00 4207.50 3828.12 3828.15 3726.30 877.17 4.00 -173.89G -3.98 -D. 56 5973866.89 591527.07 N 70.33830771 W 149.257. 6000.00 45.30 12.39 4166.46 4248.96 3871.80 3871.64 3768.94 888.68 4.00 -173.64G -3.98 -0.60 5973909.63 591536.06 N 70.33842418 W 149.2572 Ne 6026.12 44.26 12.22 4185.00 4267.50 3890.20 3890.24 3786.91 890.60 4.00 -173.52G -3.97 -D.63 5973927.65 591539.76 N 70.33847330 W 149.25722 Nb 6060.63 42.89 11.99 4210.00 4292.50 3913.98 3914.02 3810.17 895.59 4.00 -173.36G -3.97 -D.66 5973950.97 591544.47 N 70.33853683 W 149.25718349 6100.00 41.33 11.72 4239.20 4321.70 3940.37 3940.42 3836.00 901.01 4.00 -173.15G -3.97 -0.70 5973976.88 591549.56 N 70.33860740 W 149.25713946 Ne 6114.31 40.76 11.61 4250.00 4332.50 3949.77 3949,82 3845.21 902.91 4.00 -173.08G -3.97 -D.73 5973986.08 591551.37 N 70.33863255 W 149.25712403 6200.00 37.36 10.93 4316.53 4399.03 4003.73 4003.60 3898.15 913.48 4.00 -172.55G -3.97 -0.79 5974039.14 591561.29 N 70.33877717 W 149.25703827 OA 6229.30 36.20 10.68 4340.00 4422.50 4021.26 4021.34 3915.38 916.77 4.00 -172.34G -3.97 -D.88 5974056.41 591564.37 N 70.33882425 W 149.25701157 End Drp / T erget 1 6235.49 35.95 10.62 4345.00 4427.50 4024.90 4024.99 3918.96 917.44 4,00 O.OOG -3.96 -0.91 5974060.00 591565.00 N 70.33883403 W 149.25700610 OBa 6309.61 35.95 10.62 4405.00 4487.50 4088.37 4088.50 3961.73 925.46 0.00 O.OOG 0.00 0.00 5974102.86 591572.50 N 70.33895086 W 149.25694101 OBb 6359.02 35.95 1D.62 4445.00 4527.50 4097.36 4097.51 3990.24 930.80 0.00 O.OOG 0.00 0.00 5974131.43 591577.50 N 70.33902875 W 149.25689761 OBc 6433.14 35.95 10.62 4505.00 4587.50 4140.83 4141.02 4033.01 938.82 0.00 O.OOG 0.00 0.00 5974174.29 591585.00 N 70.33914558 W 149.25683251 OBd 6494.90 35.95 10.62 4555.00 4637.50 4177.06 4177.28 4068.65 945.51 0.00 O.OOG 0.00 0.00 5974210.00 591591.25 N 70.33924294 W 149.25677826 OBa 6578.90 35.95 10.62 4623.00 4705.50 4226.33 4226.59 4117.12 954.59 0.00 O.OOG 0.00 0.00 5974258,57 591599.75 N 70.33937536 W 149.25670448 Target 2 6581.37 35.95 10.62 4625.00 4707.50 4227.78 4228.05 4118.54 954.66 0.00 0.000 0.00 0.00 5974260.00 591600.00 N 70.33937925 W 149.25670231 08f 6634.49 35.95 1D.62 4668.00 4750.50 4258.94 4259.23 4149.19 960,61 0.00 O.OOG 0,00 0.00 5974290.71 591605.37 N 70.33946298 W 149.25665565 08f Base 6692.55 35.95 10.62 4715.00 4797.50 4292.99 4293.31 4182.69 966.89 0.00 O.OOG 0.00 0.00 5974324.29 591611.25 N 70.33955450 W 149.25660465 TD /4-1/2" Lnr 8731.37 35.95 10.62 4746.43 4628.93 4315.77 4316.11 4205.09 971.09 0.00 O.ooG 0.00 0.00 5974346.74 591615.18 N 70.33961570 W 149.25657055 Lilli. DHcrIDtlon: Northlna M JftUS1 Eatfna 00 rftUS1 . Surface 4881 FSL 1605 FEL S11 T11N R11E UM 5970130.60 590695.08 Target 1 3520 FSL 884 FEL S2 T11N R11E UM 5974060.00 591565.00 Target 2 3720 FSL 647 FEL S2 T11N R11E UM 5974260.00 591600.00 BHL 3806 FSL 630 FEL 52 T11N R11E UM 5974346.74 591615.18 WeßDeslgn Ver 3.1RT-SP3.03-HF4.00 BId( d031rt-546) Plan V-216 (N- nIPlan V-216 (N- T)IPlan V-216\V-216 (P3b) Generated 7/1312004 1:29 PM Page 2 of 2 V-216 (P3b) 800 1600 2400 II m ~ ø a ~ 3200 4000 4800 o 800 1600 2400 3200 4000 o B1<11J11fOO o ~ 1800 ~O *0 Vertical Section (ft) Azlm '" 13", Scale '" 1(ín);~(ft) Origin'" 0 N/-S, 0 E/.W 3750 3000 ^ A ^ Z = Õ ~ 2250 ê ~ II ID ~ (j) (j) v v v 1500 750 o .,..., F$: -750 o 750 "750 o 750 «< W Scale'" 1(in):6oo(ft) IE »> 1500 . . Schlumberger Anticollision Report Compaay: BP Amoco Date: 7/1312004 1'iae;.. 13:52:52 rap: t FIekI: Prudhoe Bay Refereaee SIte: PB V Pad ~~: Well: Plan V-216 (N--T),T!'Üe I\IortI) Refereaee Well: Plan V·216 (N-T) VerdeaI(TVD)~ V-216 Plan N-T82.S Refereaee Wellpatb: Plan V·216 ~..~ NO GWBAL SCAN: Using user defined selection &: scan eriteria Reference: Principal Plan & PlANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 6731.37 ft &an Method: Trav Cylinder North Maximum Radius: 1??oo.00 ft Error Sarfaee: Ellipse + Casing Survey Program for Definitive Wellpath Date: 2/1912004 Validated: No Venion: 5 Planned From To Survey Tookode Tool Name ft ft 29.00 1400.00 Planned: Plan #3 Vi MWD MWD - Standard 29.00 6731.37 Planned: Plan #3 Vi MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole SùIe NIme ft ft in In . 3460.93 2657.50 9.625 12.250 9 518" 6731.37 4828.93 7.000 8.750 ¡- Summary <- Offset Wellpath ~ Refereaee otrset Qr-Ctr. Ne-Ge ~ SIte Well Wellpath MD MD DiItmee· ArU om.aø \V~ ft ft ft ft ft PB V Pad Plan V-112 (5-A) Plan V-112 Vi Plan: PI 346.24 350.00 372.12 6.51 365.62 Pass: Major Risk PB V Pad Plan V-118 (N-X) Plan V-118 V3 Plan: PI 401.14 400.00 60.52 7.13 53.39 Pass: Major Risk PB V Pad Plan V-203 (N-A) Plan V-203 VO Plan: V 348.59 350.00 325.43 7.69 317.74 Pass: Major Risk PB V Pad Plan V-204 (S-H) Plan V-204 OBd Vi Plan 437.65 450.00 284.77 7.73 277.03 Pass: Major Risk PB V Pad Plan V-204 (5-H) Plan V-204l1 OBb Vi PI 437.65 450.00 284.77 7.73 277.03 Pass: Major Risk PB V Pad Plan V-204 (5-H) Plan V-204l2 OBa Vi PI 437.65 450.00 284.77 7.73 277.03 Pass: Major Risk PB V Pad Plan V-204 (5-H) Plan V-204l3 OA Vi Pia 437.65 450.00 284.77 7.73 277.03 Pass: Major Risk PB V Pad Plan V-205 (S-P) Plan V-205 V2 Plan: PI 347.65 350.00 190.49 6.58 183.92 Pass: Major Risk PB V Pad Plan V-206 (5-S) Plan V-206 Vi Plan: PI 347.90 350.00 181.36 6.58 174.78 Pass: Major Risk PB V Pad Plan V-21 0 (N-G) - w Plan V-21 0 V2 Plan: PI 444.21 450.00 236.18 7.88 228.30 Pass: Major Risk PB V Pad Plan V-211 (N-C) - w Plan V-211 Vi Plan: V 397.03 400.00 295.63 8.67 286.95 Pass: Major Risk PB V Pad Plan V-212 (5-D) Plan V-212 VO Plan: V 393.41 400.00 333.94 8.63 325.31 Pass: Major Risk PB V Pad Plan V-213 (5-W) Plan V-213 V3 Plan: PI 856.31 900.00 181.04 15.37 165.67 Pass: Major Risk PB V Pad Plan V-213 (5-W) Plan V-213PB1 V3 Plan: 856.31 900.00 181.04 15.37 165.67 Pass: Major Risk PB V Pad Plan V-214 (N-R) Plan V-214 V3 Plan: V 400.07 400.00 30.69 8.16 22.53 Pass: Major Risk PB V Pad Plan V-2a06 (N-M) Plan V-2a06 VO Plan: V 399.23 400.00 106.00 8.70 97.30 Pass: Major Risk PB V Pad Plan V-3a06 (5-U) Plan V-3a06 Vi Plan: P 442.52 450.00 181.61 9.42 172.19 Pass: Major Risk PB V Pad V-Q1 V-Q1 28.60 -54.10 201.29 No Offset Stations PB V Pad V-Q1 V-Q1 V13 249.90 250.00 201.72 4.48 197.24 Pass: Major Risk PB V Pad V-Q2 V-Q2 V12 250.90 250.00 206.06 4.55 201.52 Pass: Major Risk PB V Pad V-Q3 V-03 V7 602.03 600.00 45.48 9.68 35.80 Pass: Major Risk PB V Pad V-1OO V-1OOV7 298.90 300.00 183.53 5.12 178.41 Pass: Major Risk PB V Pad V-101 V-101 V7 396.94 400.00 277.68 6.61 271.07 Pass: Major Risk PB V Pad V-102 V-102 V5 398.38 400.00 159.17 7.78 151.39 Pass: Major Risk PB V Pad V-103 V-103 V6 399.87 400.00 15.29 6.79 8.50 Pass: Major Risk PB V Pad V-104 V-104 V13 348.91 350.00 220.59 5.83 214.76 Pass: Major Risk PB V Pad V-105 V-105 V13 447.48 450.00 91.58 7.41 84.17 Pass: Major Risk PB V Pad V-106 Plan V-106A V5 Plan: P 448.45 450.00 43.24 7.33 35.91 Pass: Major Risk PB V Pad V-106 Plan V-106APB1 Vi Plan 448.45 450.00 43,24 7.22 36.02 Pass: Major Risk PB V Pad V-106 V-106 V10 399.12 400.00 42.71 6.24 36.47 Pass: Major Risk PB V Pad V-107 V-107 V5 445.12 450.00 190.72 6.78 183.94 Pass: Major Risk PB V Pad V-108 V-108 V7 250.18 250.00 312.40 4.35 308.05 Pass: Major Risk PB V Pad V-109 V-109 V2 347.67 350.00 321.60 6.04 315.55 Pass: Major Risk PB V Pad V-109 V-109PB1 V5 347.67 350.00 321.60 6.04 315.55 Pass: Major Risk PB V Pad V-109 V-109PB2 V2 347.67 350.00 321.60 6.04 315.55 Pass: Major Risk PB V Pad V-111 V-111 V25 500.90 500.00 19.52 9.11 10.41 Pass: Major Risk PB V Pad V-111 V-111PB1 V8 500.90 500.00 19.52 9.11 10.41 Pass: Major Risk PB V Pad V-111 V-111PB2 V2 500.90 500.00 19.52 9.11 10.41 Pass: Major Risk PB V Pad V-111 V-111PB3 V6 500.90 500.00 19.52 9.11 10.41 Pass: Major Risk PB V Pad V-113 V-113 V6 346.86 350.00 346.62 5.33 341.29 Pass: Major Risk PB V Pad V-114 V-114 V5 300.65 300.00 297.76 5.08 292.69 Pass: Major Risk PB V Pad V-114 V-114A V4 300.65 300.00 297.76 5.08 292.69 Pass: Major Risk PB V Pad V-114 V-114APB1 V4 300.65 300.00 297.76 5.08 292.69 Pass: Major Risk . . Schlumberger Anticollision Report Compaay: BPAmoco Field: Prudhoe Bay ReIereaee SIte: PB V Pad ReIereueè Well: Plan V-216(N-T) RefereDCé weap.da: Plàn V-216 o.te: 7/1312004 TIme: c-rdiute(NE) ReIeruee: Vertical (I'VD) Refereøce: Summary ~ 0fI'tet WeIIpatII ~ RefereDCé 0fI'tet etr-etr.. No:.Ge AlllÞwaItIe SIte Well Welpatlt MD MD DIstøce·· Area Dmadea It It It It It PB V Pad V-114 V-114APB2V2 300.65 300.00 297.76 5.08 292.69 Pass: Major Risk PB V Pad V-115 V-115 V5 347.85 350.00 190.32 5.71 184.61 Pass: Major Risk PB V Pad V-115 V-115PB1 V4 347.85 350.00 190.32 5.71 184.61 Pass: Major Risk PB V Pad V-117 V-117 V9 298.70 300.00 180.87 5.24 175.63 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 298.70 300.00 180.87 5.24 175.63 Pass: Major Risk PB V Pad V-117 V-117PB2 V6 298.70 300.00 180.87 5.24 175.63 Pass: Major Risk PB V Pad V-119 V-119V13 394.02 400.00 309.04 6.85 302.19 Pass: Major Risk PB V Pad V-201 V-201 V8 347.98 350.00 176.22 5.74 170.47 Pass: Major Risk PB V Pad V-202 V-202 V9 397.16 400.00 250.52 7.05 243.47 Pass: Major Risk PB V Pad V-202 V-202L 1 V5 397.16 400.00 250.52 7.00 243.52 Pass: Major Risk PB V Pad V-202 V-202L2 V5 397.16 400.00 250.52 7.00 243.52 Pass: Major Risk Field: Prudhoe Bay Site: PB V Pad Well: Plan V-216 (N-T) Wellpath: Plan V-216 94 Plan V-21O (N-G) - was V-209 (Plan V-21O) V-103 (V-103) 200 100 27 100 200 94 V-IOS (V-IOS) Y-I06 (V-I06) PI.. VP1J.f~~(V_03) 180 Plan ~mfš:~/ìIU.\ V-213rSl) PIariV~)~V-206) Travelling Cylinder Azimuth (TFO+A2I) [deg] vs Centre to Centre Separation [100ft/in) " . Site: PB V Pad Drilling Target Coni.: 95% Description: Map Northing: 5974060.00 ft Map Easting : 591565.00 ft Latitude: 70020'19.802N Shape: Circle Target: V-216 OA Tgt 1 .ell: V-03,Plan V-216 (N- T) Based on: Planned Program Vertical Depth: 4345.00 ft below Mean Sea Level Local +N/-S: 3918.95 ft Local +EI-W: 917.44 ft Longitude: 149"15'25.222W Radius: 150 ft o o 0 o 0 ~ o 0 ) J o ~ ) ^I J o o m o o u CJ CJ CJ CJ CJ CJ CJ N 4-300 4-200 4-100 4-000 3900 3800 3100 o CJ (Y) · Site: PB V Pad Drilling Target Conf.: 95% Description: Map Northing: 5974260.00 ft Map Easting : 591600.00 ft Latitude: 70020'21.765N Shape: Circle Target: V-216 OBd Tgt 2 aell: Plan V-216 (N-T) Based on: Planned Program Vertical Depth: 4625.00 ft below Mean Sea Level Local +N/-S: 4118.53 ft Local +FJ-W: 954.86 ft Longitude: 149°15'24.128W Radius: 150 ft o o 0 o 0 ø o 0 ( J o ~ J ,n ) CJ CJ CD CJ o u 4-4-00 4-300 4-200 4-100 4-000 3~00 CJ o CJ CJ o o o (í) CJ o N TERRIE l HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 125 "Mastercard Check" DATE D7-/S-óy ~.o~E. ~~~~ ,$JÖ(~,QO . :. . . CiJ1 . --- DOLLARS First National Bank Alaska AnChorV~AK 99501 ~ .. bf. ~ MEMO ;Z\~ ~t .. . ._ . -: ¡. 25 2000(;0-:1111 ¡'~"I(; 2 2 711' ¡. 5 5(;11- 0 ¡. 25 . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER J WELL NAME /gq¡J--2J£ / PTD# ¿ð<7-/3ò Exploration Stratigraphic Development »<! Service , CHECK WßA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a new wellbore segment of LATERAL existing weD , Permit No, API No. . (If API number Production. sbould continue to be reported as last two (2) digits a function 'of tbe original API number. stated are between 6.0-69) above. PILOT HOLE In accordance witb 2.0 AAC 25..0.05(1), aU (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API number (5.0 - 7.0/8.0) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fun EXCEPTION compliance with 2.0 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to the SAMPLE Commission must be in no greater ·tban 3D' sample intervals from below tbe permafrost or from where samples are first caugbt and 1.0' sample intervals tbrougb target zones. . . D D Well bore seg Annular Disposal Program SER On/Off Shore Do PRUDHOE BAY, ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN V-2161 ALASKA) INC nitial ClassfType ~ER/1WINJ GeoArea Unit - Administration P~rnJit fee attaçhe~ Yes. _ - - I~ .Leas~nt,lIrtber J3.pprOPJi¡:¡te _ - - - - - -- - - - - - . Y~s_ _UJliqµe welln_amß_anc! Ol!nJb_er _ _ _ _ _ _ . _ _ _ _ - - , , ' , , , ' . _'' Y~s_, - - - - - - - - - - - - - - - - - - ~ - - - - - - \: Wen JQc¡:¡tßd in.ad.efine~ppol - - - - - Y~s_ _ - - - - - - - - - ~ WeJUQc¡:¡tßd prpperdistaoce. from c!riJling µnitb_oµndary _ _, Y~s __ - - - - - - - - - - - I~ WenJQc¡:¡tßd proper _distance_ from other w~l]s, _ - - - - - Yes - - - - - - _S,utfiçieot J3.cr~ag.eaYailable in. dritliog l!n.it, - - Y~s __ - - - - - - - - - -- Jf.dßyi¡;¡tec!, js weJlbQre plaUncJu,ded _ Yßs. _ - - - - - - - 9 O-p~rator 001;, afteçt~d party _ - - - - - - - Yes, _ - - - - - - - - - - - - - - 10 ,O-p~rator has,apprppriate, Qond inJorce ' , , , . . ' , , , ' , . , ' , ' , - ."",. _ Yßs" - - - - - - - - - - - - - - - - - - - - - - - - - -- 11 P~rnJit c.an be iSSl!ed w.ithQut CO,nservation order _ - _ , , . - - - - Yes. _ - - - - - - - - - - -. Appr Date 12 P~rnJit can be issl!ed w.ithQut ad,nJioistrativ:eapprpvaJ . . - - - Y~s __ - - - - - RPC 7/15/2004 13 Can permit be approved before 15-day wait Yes 14 WeJIJQc¡:¡tßd within area alld_strata ,aµthorized by_lnjectiolJ Ordßr # (pµUOil in,cprnments).{for Y~s . . ,11.1026 - - - - - 15 ,AJI w~l]s, within .1l4,mile,are,a,of reyiew id~ntified (Fpr servjc,ewell 001;,), , ' ,,' " '."" Y,es, ' V-,1 06.; Y: 1.03, , , , . , ' , , , ' , , ' , _ , ' , 16 Pre-produced injector; ~uratiQnof pr~--prodµctipn Ißss th,m 3 months, (for_s~[\Iice well onJy) . NA - - -- - - - - - - - - - - - - 17 ACMP, filldingof ConsistenCY _ h,as been .issµed_ for tbis proieçt _ _ ,NA - - - - - - - - - -- Engineering 18 .C.onc!u,ctor st[illgprQvided _ _ - - - - - - - - - - - - - - - Y~s, _ 20" x34",@.109'., , _ 19 Surface,casingpJotec.ts allknowll USDWs . , _ - - - - - Yes_ _ - - - - - - - - - - - - 20 _CMTvpla.dequate-'o çirculJ3.te_on,cood_uctor,& surfq>g . _ _ _ , ' . _ _ _ Yes__ Me~uate excesS, _ - - - - - 21 .CMT voladequateJo tie-in Jong string to surf çsg_ _ _ _ , ' , - - - - No,. _ - - - - - - - - - - - 22 CMTwil] COYer_ail knownprodµctiYe bQri~ons . - - - - - - - Y~s __ - - ~ - - - - - - - - - - - -- 23 _C_asing designs ad.eç ua-'e to( C,.r, B& p-ermafrost. . _ Yes _ - - - - - - - - - - - - - -- 24 _A~equ¡;¡te_tankage_oJ re,se[\le pit _ - - - - - - .. Yes _. Nab_ors,9ES. . 25 Jfa,re-drill~ has,a, to:4_03 fOJ abandonment beeo apPJoved _ NA __ Newwell, , . . - - - - - - 26 A~equate ,wellbofe sep¡;¡r¡:¡tjo,n ,pro-ppsed, , , , , _ ' , , , ' . , , ' , , . , " ,Y~s, - - - - + . - - - - - - - - - - - . - - - - - - - -- 27 Jf.d.ivecter Jequired, dQes .it meet reguJatipns, . _ - - - - - - - . , .Y~s _ _ - - - - - - - - - - Appr Date 28 ,Drilliog fJu.id, program sc.hematic,& equip Jistadequ¡:¡t~, . . - - - - Yes __ M¡;¡x MW9~6. ppg. WGA 7/16/2004 29 _BOPEs"dothey meetreguJa-'ipo . Y~s, ' - - - - - - - - - - - - - - - 30 ,BOPEpre_s$ ra.tiog appropriate; test to (put psig in comments), _ , ' . _ _ .Yes _ _ Test t040QOpsi. .MS¡=> 16,38 psi. 31 .Chpkemanjfold cQmpJies, w/APtRF'-53 (May 84) . , , . . . . . ' , . Yes _ - - - - - - - - - 32 WQrk will pcc,ur withput.operatjon ,sbutc!own, , _ .Y~s _ _ - - -- - - - - - - 33 Js presence, Qf H2S 9¡;¡S, probable, , . - - - - - - - No_ NQt.as H2S pad.. . - - - - - - - - - - - 34 Meçha_nicalcpod,ition pf wells within 80R Yerified (fo(s_ervjee welJ Qnly) Yes, _ Cementing. œcoJds,ind,icateMLof 80R w~lJs, Geology 35 Pe(mit c.an be iSSl!ed wlo hydrogen sulfide measures. Y~s 36 D_ata,presented on. p-ote_ntial pveJpres,sure _zones, _ _ _ , ' , _ NA Appr Date 37 ,Seisrnicanalysjs Qf ShaJlow gas,zPoes , NA RPC 7/15/2004 38 Se¡;¡bedcOOditipo Sl!l"I{ey.(if off-shp(e) . . . _ , ' _ . - _ , ' . . _NA 139 . Contact oamelpl1Olle.for.weekly prpgress.reports [exploratpry .only] NA - - Geologic Date: Engineering Date Date Commissioner: Commissioner: IJTS ì( 16ft-
